The URL can be used to link to this page

Home My WebLink About208-003Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250813 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 24-06RD 50133204990100 206013 4/2/2025 YELLOWJACKET GPT-PERF MPB-24 50029226420000 196009 7/9/2025 READ CaliperSurvey MPB-34 50029235690000 216139 7/7/2025 READ CaliperSurvey MPF-45 50029225560000 195058 7/30/2025 READ CaliperSurvey ODSK-41 50703205850000 208147 8/9/2025 READ CaliperSurvey ODSN-25 50703206560000 212030 6/22/2025 READ CaliperSurvey ODSN-31 50703205650000 208003 8/11/2025 READ CaliperSurvey PBU 06-11A 50029204280100 225042 7/13/2025 BAKER MRPM PBU 13-19 50029206900000 181180 6/4/2025 HALLIBURTON WFL-TMD3D PBU 14-18C 50029205510300 225040 6/24/2025 BAKER MRPM PBU 14-43A 50029222960100 225041 7/30/2025 BAKER MRPM PBU C-01B 50029201210200 212053 7/19/2025 BAKER MRPM SD-07 50133205940000 211050 7/27/2025 YELLOWJACKET SCBL SP 12-S3 50629235130000 214067 7/18/2025 YELLOWJACKET PERF Please include current contact information if different from above. T40771 T40772 T40773 T40774 T40775 T40776 T40777 T40778 T40779 T40780 T40781 T40782 T40783 T40784 ODSN-31 50703205650000 208003 8/11/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.15 10:11:56 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Punch____ 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 15,363 feet N/A feet true vertical 6,189 feet N/A feet Effective Depth measured 6,582 feet See attachment, pg. 3 feet true vertical 6,119 feet See attachment, pg. 3 feet Perforation depth Measured depth See attachment, pg. 2 feet True Vertical depth See attachment, pg. 2 feet Tubing (size, grade, measured and true vertical depth)2-7/8", 6.5# L-80, TH533/IBT 6435' MD 5,779' TVD Packers and SSSV (type, measured and true vertical depth)See attachment, pg. 3 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Nuiqsut 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 Digital Signature with Date:6/9/2023 Contact Name:Amjad Chaudhry Contact Email:amjad.chaudhry@eni.com Authorized Title:Well Operations Project Manager Contact Phone:907-865-3379 Liner 7,567' 7,912' Casing Structural 6,234' 4-1/2" 7,606' 15,358'6,190' 3,131'3,036' 16" 9-5/8" Size N/A 5,750 psi 7,240 psi measured TVD Production Plugs Junk measured 5,410 psi ACX will be submitted electronically 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 355036 / ADL 389958 Oooguruk - Nuiqsut Oil Pool Eni US Operating Co. Inc. 158' 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-003 50-703-20565-00-00 3700 Centerpoint Dr, Suite 500, 995033. Address: ODSN-31 MD Burst Collapse measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 501 30232 Length 110' 3,092' 158'Conductor Surface Intermediate N/A 3,090 psi 323-288 Sr Pet Eng: 7,500 psi Sr Pet Geo:Sr Res Eng: WINJ WAG 278 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 17 893395 296 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 790 1079 8,430 psi p k ft t Fra O s 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 annucci By Grace Christianson at 9:25 am, Jun 13, 2023 DSR-6/13/23 RBDMS JSB 071423 Top (MD)Top (TVD) 7,800 6,274 8,006 6,300 8,214 6,301 8,421 6,297 8,627 6,295 8,835 6,293 9,041 6,288 9,250 6,277 9,460 6,273 9,669 6,266 9,880 6,260 10,090 6,241 10,301 6,223 10,512 6,206 10,716 6,197 10,925 6,197 11,124 6,207 11,325 6,221 11,530 6,230 11,737 6,232 11,936 6,236 12,140 6,235 12,350 6,226 12,513 6,212 12,964 6,197 13,437 6,224 13,916 6,190 14,409 6,187 14,897 6,176 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 15,350 6,190 Attachment 2 Sundry Report Box 11 - Perforation Locations Well: ODSN-31 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Ported w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) AOGCC Form 10-404 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) SSSV MD TVD HES 'NE' TRSV w/ "X" Profile 1,997 1,964 PACKERS MD TVD 2,600 2,532 7,427 6,188 7,452 6,194 WFT Genesis Oil Base Swell Packer 12,657 6,200 WFT Genesis Oil Base Swell Packer 12,768 6,199 Attachment 3 WFT "NTH" Liner Top Packer WFT "NTH" Liner Top Packer AOGCC Form 10-404 Report of Sundry Box 11 - Packers & SSSV Well: ODSN-31 Halliburton ESP Packer ODSN-31 Nuiqsut Producer 158' 16" Conductor 3,131' (3,036' TVD) 9-5/8" 40# L80 BTC 7,606' (6,234' TVD) 7" 26# (on record) L80 BTC-M 15,363' (6,189' TVD) 6-1/8" TD 7231' Tag Fish: Tech line 11.5' + Check v/v and ¼” chemical injection line 32' (2022-08) As Run 2023-05-13 15,358' (6,190' TVD) 4-½” 12.6# L80 TH521 Liner WFT Genesis Oil Swell Packer 12,657' (6,200' TVD) 30 each 4' pup (6 each ½” holes) ~200' apart WFT Genesis Oil Swell Packer 12,768' (6,199' TVD) 7,452' (6,194' TVD) WFT NTH LTP/PHR Liner Hanger with 15' TBS 7,427' (6,188' TVD) WFT 7"x5" 15# NTH LTP/PHR Liner Hanger with 15' TBS 2200' Est. TOC 3673' Casing Leak 1 joint 7" 26# below hanger + 7" 23# (Caliper data 2022-8-17) SSSV GL GL GL 6,732' ES Stage Cementer 825' TAM Port Collar 103' XO 3-½” TH Blue x 2-7/8" TH533 1997' (1964' TVD) 19° TRSV, HAL 2.313 X Profile 2543' GLM#3, SLB w/DV 2600' (2532' TVD) 19° ESP Packer, HAL 2642' GLM#2, SLB w/DV 2694' 2.313 X Nipple 2704' XO TH533 B x IBT P 5933' GLM#1, SLB w/5/16" OV 6395' 2.313 XN Nipple, 2.205 No-Go 6541' (5805' TVD) 53° Bottom of ESP Completion: 2-7/8" 6.5# L80 TH533/IBT Well Head: Vault MB-233 2009-08-19 D&C 2010-03-31 Replace ESP 2017-08-27 Replace ESP 2019-07-27 Punch TBG 6462-6467' 2022-10-02 Patch CSG & Replace ESP 2022-12 Replace PKR & Upper Completion 2023-05 Punch TBG 6410-6411' 5922' XO IBT B x TH533 P 3654' SALTEL CSG Patch ID 5.646" Drift 5.315" (5.513" calculated) 3698' Bottom of CSG Patch 6435' Discharge Assembly 6411.19' and 6410.69' Holes (½” diameter)- punched May 2023 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 4/29/2023 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) -0.2 Wind NE @ 18 MPH Days LTI (days) 1,338.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Discuss and formulate a plan forward. 24h Summary Rig up PCE equipment and make up BHA #1.RIH with 2.34" No-Go centralizer to 1,997'. Make up BHA #2 with flapper checker and RIH to 1,997' to ensure flapper is open on TRSCSSSV. Make up BHA #3 and RIH with 2.19" centralizer & tag at 6,423' (12' of fill above ESP pump). Make up BHA #4 and RIH with Welltec stroker & drive down bailer. Tag at 6,423'. Stroke down with 1,000 lb increments to 15k. Pull out of hole with BHA #4. Operation at 07.00 Discuss and formulate a plan forward. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 06:00 11:00 5.00 5.00 PROD- MAN R 5 P Held PJSM. Hand well over from Production to Drilling. Install upper swab valve & WL Valves. Make up BHA #1. Function test WL valves & found a bad hydraulic hose. Changed out hose. Stab on well. Pressure test lubricator to 2500 psi for 10 minutes. Test good. 11:00 13:00 2.00 7.00 PROD- MAN R 15 P Run in the hole with BHA #1 as follows; Cable head, CCL, QC, 1.5" x 5' roller stem (X2), QC, 1.5" x 5' roller stem, QC, 1.5" x 5' stem, QC, Knuckle joint, spang jars, QC & 2.33" fluted centralizer. Tag Halliburton NE TRSCSSSV at 1997'. Pull out of hole & lay down BHA #1. 13:00 13:30 0.50 7.50 PROD- MAN R 5 P Make up BHA #2. Stab on well. Pressure test lubricator to 2500 psi for 10 minutes. Test good. 13:30 14:30 1.00 8.50 PROD- MAN R 15 P Run in the hole with BHA #2 - Cable head, CCL, QC, 1.5" x 5' roller stem (X2), QC, 1.5" x 5' roller stem, QC, 1.5" x 5' stem, QC, Knuckle joint, spang jars, QC, 2.33" fluted centralizer 1.25" x 1' stem & 2.25" flapper checker. Verify flapper is open at 1,997'. Pull out of hole & lay down BHA #2. 14:30 15:00 0.50 9.00 PROD- MAN R 5 P Make up BHA #3. Stab on well. Pressure test lubricator to 2500 psi for 10 minutes. Test good. 15:00 18:45 3.75 12.75 PROD- MAN R 15 P Run in the hole with BHA #3 - Cable head, CCL, QC, 1.5" x 5' roller stem (X2), QC, 1.5" x 5' roller stem, QC, 1.5" x 5' stem, QC, hydraulic jars, QC, knuckle joint, spang jars, QC, 1.25" x 1' stem & 2.19" fluted centralizer. Tag at 6,423' (12' of fill above ESP pump) correlated to GLM #1 from pipe tally. Pull out of hole & lay down BHA #3. 18:45 20:45 2.00 14.75 PROD- MAN R 5 P Make up BHA #4. Stab on well. Pressure test lubricator with 60 deg LVT to 2500 psi for 10 minutes. Test good. 20:45 00:00 3.25 18.00 PROD- MAN R 15 P Run in the hole with BHA #4 - Cable head, Welltec 218 stroker, WRD, S/R to QC XO, QC to S/R XO, 5' x 2" Drive down bailer. Tag at 6,423' (12' of fill above ESP pump). Engage stroker with 2k force & little movement, increased force 1000 lbs each stroke to15k with very little movement. Pull up hole each stroke to ensure pick up weight had not changed. Estimated 5.5" of movement total. Pull out of hole & check bailer for samples Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tyler Rush ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 4/30/2023 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 6.4 Wind NE @ 22 MPH Days LTI (days) 1,339.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Continue to run in hole with drive down bailer & Welltec stroker tool. Stroke down to 15k force & cleanout fill to top of discharge section of ESP pump. 24h Summary Pull out of the hole & recover fine mesh sand from bailer. Make up BHA #4 (2nd run). Run in hole & tag at 6423'. Stroke down on bailer. Pull out of hole & recovered 1.5' of fine mesh sand from bailer. Rehead wireline, service Welltec stroker, make up BHA #4 (3rd run). Operation at 07.00 Cleanout & recover debris captured in bailer. 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 PROD- MAN R 15 P Continue to pull out of the hole with BHA #4. Lay down lubricator & tool string. Recovered approximately a cup full of fine mesh sand from bailer. Shut well in & secure wellhead. 01:30 11:30 10.00 11.50 PROD- MAN R 1 P Clean up equipment & location, prep tools for upcoming runs. Held plan forward meeting with Anchorage to determine next steps. Held additional meeting with Halliburton management on site at ODS. 11:30 14:15 2.75 14.25 PROD- MAN R 5 P Make up BHA #4 (2nd run). Stab on well. pressure test lubricator with 60 deg LVT. Good test. 14:15 20:30 6.25 20.50 PROD- MAN R 15 P Run in the hole with BHA #4 - Cable head, Welltec 218 stroker, WRD, S/R to QC XO, QC to S/R XO, 5' x 2" Drive down bailer. Tag at 6,423' (12' of fill above ESP pump). Engage stroker with 15k force a total of 25 times with no significant changes from the previous stroker run & no additional depth made. POOH with BHA #4. Lay down lubricator & tool string. Recovered approximately 1.5' of fill from the bailer. 20:30 00:00 3.50 24.00 PROD- MAN R 5 P Rehead wireline. Service Welltec Stroker. Make up BHA #4 (3rd run). Stab on well. pressure test lubricator with 60 deg LVT. Good test. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/1/2023 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 12.7 Wind NE @ 26 MPH Days LTI (days) 1,340.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Continue to perform bailer runs applying 15k down force with 10' bailer to clean out fill above ESP pump. 24h Summary Run in hole & tag at 6423'. Stroke down on bailer with 15k force. Pull out of the hole & recover 1 cup of fine mesh sand from bailer. Troubleshoot PCE equipment. Run in the hole with BHA #7. Tag at 6,425' (10' of fill above ESP pump). perform 25 strokes at 15k down force. Operation at 07.00 Running in the hole with BHA #8. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:00 7.00 7.00 PROD- MAN R 15 P Run in the hole with BHA #4 (3rd run) as follows; Cable head, Welltec 218 stroker, WRD, S/R to QC XO, QC to S/R XO, 5' x 2" Drive down bailer. Tag at 6,423' (12' of fill above ESP pump). Engage stroker with 15k force a total of 25 times with pick up weights between strokes. Pull up hole to 5,933' (GLM #1) & correlate. Run in hole & tag at 6425' (10' of fill above ESP pump). POOH with BHA #4. Lay down lubricator & tool string. Recovered approximately .75' of fine mesh sand from the bailer. 07:00 19:30 12.50 19.50 PROD- MAN R 25 U Shut well in. Installed cap on well. Halliburton is trouble shooting PCE equipment due to line coming out wet from line wiper creating droplets to hit the pad. Trace out all pressure lines & label each to Alaska color codes. Verified each hose was color coded for the correct function of the equipment. 19:30 20:45 1.25 20.75 PROD- MAN R 5 P Make up BHA #7. Stab on well. Function test WL valves, Line wiper, head catcher & grease head. pressure test lubricator with 60 deg LVT. Good test. 20:45 00:00 3.25 24.00 PROD- MAN R 15 P Run in the hole with BHA #7 as follows; Cable head, Welltec 218 stroker, WRD, S/R to QC XO, QC to S/R XO, 5' x 5' x 2" Drive down bailer. Tag at 6,424' (11' of fill above ESP pump). Engage stroker with 15k force a total of 25 times with pick up weights between each stroke. Prepare to pull out of hole at report time. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/2/2023 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 19.0 Wind NE @ 22 MPH Days LTI (days) 1,341.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Production group flowing the well to check production rates. Continue E-line operations to clean debris from tubing. 24h Summary Pull out of hole with E-line from 6,424' to surface. No solids recovered from bailer. Run in hole with Welltec 218 stroker and 10' x 2" drive down bailer to 6,423.5'. Engage stroker with 15k force a total of 25 times with pick up weights between each stroke to 6,424.5' . Pull out of hole with E-line to surface. No solids recovered from bailer. Rig down wireline valves and secondary swab valve. Secure well with night cap. Hand well over to production group to bring well on line to check production rates. Operation at 07.00 Production group flowing the well to check production rates. 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 PROD- MAN R 15 P Pull out of hole with E-line from 6,424' at 60 FPM to surface. Lay down lubricator and tool string. No solids recovered from bailer. 02:30 05:00 2.50 5.00 PROD- MAN R 5 P Service Welltec stroker. Make up 2" drive down bailer. Stab on well. Pressure test lubricator with 60 deg LVT. Test good. 05:00 11:00 6.00 11.00 PROD- MAN R 15 P E-line Run #8; Run in hole with Welltec 218 stroker and 10' x 2" drive down bailer and correlate to GLM #1 at 5,933'. Set down at 6,423.5' (6,382' CCL + 41.5 offset). Engage stroker with 15k force a total of 25 times with pick up weights between each stroke. Max 500 LBs over pull above 1550 LBs line tension UW. Pick up and correlate to GLM #1 at 5,933'. Run back in hole and set down at 6,424.5' (6,383' CCL + 41.5 offset). Pull out of hole with E-line from 6,424.5' at 60 FPM to surface. Lay down lubricator and tool string. No solids recovered from bailer. 11:00 16:00 5.00 16.00 PROD- MAN R 5 P Service Welltec stroker tool and Halliburton tools. Cut 10' of E-line and re-head. Rig down wireline valves and secondary swab valve. Secure well with night cap. SITP 839 PSI, 1340 PSI A-Annulus. Prepare to hand well over to production group. 16:00 00:00 8.00 24.00 PROD- MAN R 1 P Hand well over to production group at 1600 HRS to bring well on line to check production rates. Production had flow to flow back tanks at 1630 HRS. Choke set at 36 beans with 1000 MSCFD gas lift. Tubing PSI 481, A-Annulus 1360 PSI, B-Annulus 634 PSI with 136 BBLs flowed thru test meter at 2400 HRS. Average Day Rate 412 BBLs per day. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.dillon@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/3/2023 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 18.9 Wind N @ 7 MPH Days LTI (days) 1,342.00 Days RI (days) POB 20.0 Daily Summary Operations 24h Forecast Production group flowing the well to check production rates. Continue E-line operations to clean debris from tubing. 24h Summary Production group flowing the well to check production rates. Operation at 07.00 Production group flowing the well to check production rates. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 11:00 11.00 11.00 PROD- MAN R 1 P Production group flowing the well to check production rates. Choke set at 36 beans with 1.2 MSCFD gas lift. Tubing PSI 461, A -Annulus 1409 PSI, B-Annulus 642 PSI with 366 BBLs flowed thru test meter at 1200 HRS. Average Day Rate 442 BBLs per day. Cycled ESP pump 10 minutes forward, then 7 minutes in reverse, then 4 minutes forward. No noticeable change in discharge pressure. 11:00 12:00 1.00 12.00 PROD- MAN R 1 P ENI Safety stand down with crews, topic: line of fire and stop work – video and discussion. 12:00 00:00 12.00 24.00 PROD- MAN R 1 P Production group flowing the well to check production rates. Choke set at 54 beans with 824,000 MSCFD gas lift (goal 1.2 MSCFD). Tubing PSI 143, A-Annulus 1770 PSI, B-Annulus 666 PSI with 542 BBLs flowed thru test meter at 2400 HRS. Average Day Rate 410 BBLs per day. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.dillon@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/5/2023 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 17.6 Wind W @ 5 MPH Days LTI (days) 1,343.00 Days RI (days) POB 22.0 Daily Summary Operations 24h Forecast Well handed over to Production group. 24h Summary Spot crane in position. Install secondary swab valve and wire line valves. Run in hole with Welltec 218 stroker and 5' x 2" drive down bailer to 6,423'. Engage stroker with 18K force a total of 25 times with pick up weights between each stroke. Pull out of hole with E-line from 6,424' to surface. 1/2 cup of solids recovered from bailer mule shoe. Rig down wireline valves and secondary swab valve. Secure well with night cap. Hand well over to production group. Operation at 07.00 Well handed over to Production group. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:30 7.50 7.50 PROD- MAN R 5 P Pre job safety meeting. Spot crane in position. Install secondary swab valve and wire line valves. Function test wire line valves. Make up 2" drive down bailer and stab on well. Pressure test lubricator with 60°F LVT to 500 PSI low and 2500 PSI high, good test. SITP 1056 PSI, 1436 PSI A-Annulus, 593 PSI B-Annulus. 07:30 09:30 2.00 9.50 PROD- MAN R 25 P Attempt to run in hole and unable slack off with E-line. Lay down lubricator and inspect pressure control equipment. Manual liner wiper was to tight. Pick up lubricator and pressure test to 500 PSI low and 2500 PSI high, good test. 09:30 14:30 5.00 14.50 PROD- MAN R 15 P E-line Run #9; Run in hole with Welltec 218 stroker and 5' x 2" drive down bailer and correlate to GLM #1 at 5,933'. Set down at 6,423' (6,386' CCL + 37' offset). Engage stroker with 18K force a total of 25 times with pick up weights between each stroke. Max 300 LBS over pull above 1550 LBS line tension UW. Pick up and correlate to GLM #1 at 5,933'. Run back in hole and set down at 6,424' (6,387' CCL + 37' offset). Pull out of hole with E-line from 6,424' to surface. Lay down lubricator and tool string. 1/2 cup of solids recovered from bailer mule shoe. 14:30 18:00 3.50 18.00 PROD- MAN R 5 P Rig down wireline valves and secondary swab valve. Secure well with night cap. SITP 1066 PSI, 1436 PSI A-Annulus, 597 PSI B-Annulus. Prepare to hand well over to production group. 18:00 00:00 6.00 24.00 PROD- MAN R 1 P Hand well over to production group. No further work on ODSN-31. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.dillon@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/11/2023 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 21.6 Wind N @ 10 MPH Days LTI (days) 1,344.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast Continue E-line operations to clear tubing of obstruction at 1,325'. 24h Summary Spot crane in position. Install secondary swab valve, wire line valves, and install night cap. Bleed down tubing pressure from 2509 PSI to 500 PSI. Run in hole with 2.03" gauge cutter and 2.19" fluted centralizer to 970'. Set down at 970'. Work thru obstruction at 970'. Run in hole and set down at 1,220'. Attempt to work thru obstruction at 1,220' without success. Pull out of hole and inspect tool string. Run in hole with 2.03" gauge cutter to 1,325' while LRS pumped 200°F LVT. Attempt to work thru obstruction at 1,325'. Operation at 07.00 E-line operations to clear tubing of obstruction at 1,325'. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 09:00 9.00 9.00 PROD- MAN R 2 P Pre job safety meeting. Spot crane in position. Lay out pressure control equipment and control lines. Install secondary swab valve, wire line valves, and install night cap. SITP 2509 PSI, 318 PSI A-Annulus, 582 PSI B-Annulus, 2177 PSI intake, 4759 PSI discharge. 09:00 15:00 6.00 15.00 PROD- MAN R 5 P Bleed down tubing pressure from 2509 PSI to 500 PSI. Function test wire line valves and pressure control lines. Make up 2.03" gauge cutter, 2.19" fluted centralizer, 1-1/2" long stroke spang jars, and 10' x 1-1/2" roller stem with 2" wheels. 40' 5" CCL to gauge cutter offset. Stab on well. Pressure test lubricator with LVT to 500 PSI low and 1500 PSI high, good test. 15:00 19:00 4.00 19.00 PROD- MAN R 15 P E-line Run #10; Run in hole with 2.03" gauge cutter and 2.19" fluted centralizer to 970'. Set down at 970' and wire on E-line drum bird nested. Secure well. Un-spool E-line from drum and re-spool on drum. Work thru obstruction at 970'. Run in hole and set down at 1,220'. Attempt to work thru obstruction at 1,220' without success. Pull out of hole and inspect tool string. No damages observed. 19:00 22:00 3.00 22.00 PROD- MAN R 25 U LRS pump truck unable to heat LVT due to fuel pump not turning on. Troubleshoot and determined alternator was not working. Mechanic in route from Deadhorse. Arrived on location at 2100 HRS and changed alternator on pump truck. 22:00 23:00 1.00 23.00 PROD- MAN R 12 P LRS heated LVT and pressure tested lubricator to 3500 PSI, good test. 23:00 00:00 1.00 24.00 PROD- MAN R 15 P E-line Run #11; Run in hole with 2.03" gauge cutter to 1,325' while LRS pumped 200°F LVT. 39' 7" CCL to gauge cutter offset.Tubing pressured up to 2500 PSI after pumping 1.6 BBLs LVT. Start SITP 277 PSI with 2683 PSI discharge pressure. With 2500 PSI tubing pressure applied discharge pressure increased to 1446 PSI. Attempt to work thru obstruction at 1,325'. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.dillon@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tyler Rush ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/12/2023 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 22.4 Wind W @ 7 MPH Days LTI (days) 1,345.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast E-line operations to punch holes in tubing to convert well to gas lift. 24h Summary Attempt to work thru obstruction at 1,381' without success. Pull out of hole with E-line. Pump 200°F LVT down A-Annulus. Run in hole with 2.03" gauge cutter to 6,425.5' and tag debris in tubing, cleared tubing of ice plugs'. Pull out of hole with E-line. Run in hole with 2.03" gauge cutter and 2.19" fluted centralizer to 6,423.5' and tag debris in tubing. Pull out of hole with E-line. Operation at 07.00 E-line operations as procedure. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 07:30 7.50 7.50 PROD- MAN R 15 P Work thru obstruction from 1,325' to 1,381' alternating applied pressure on tubing from 1500 PSI to 2500 PSI. No success working past 1,381'. Reduced tubing pressure to 500 PSI and started setting down at 1,346', 35' shallower. Pull out of hole to inspect gauge ring. No abnormal wear on gauge ring. 07:30 13:30 6.00 13.50 PROD- MAN R 9 P Stab on well and pressure test lubricator to 3500 PSI. Held pre job safety meeting with Production, LRS, and Halliburton to discuss plan forward. Installed bleed hoses from A & B Annulus to production header. Obtain pressures, 270 PSI tubing, 321 PSI A-Annulus, 583 PSI B-Annulus. Open packer vent valve on packer. Pump 60 BBLs of 200°F LVT down A-Annulus at an average rate 1/2 BPM. Final pressures, 256 PSI tubing, 205 PSI A-Annulus, 605 PSI B-Annulus. Close packer vent valve on packer. 13:30 19:30 6.00 19.50 PROD- MAN R 15 P E-line Run #12; Run in hole with 2.03" gauge cutter to 1,350' and set down 250 LBS line weight and went thru obstruction. Work thru ice plugs from 1,400' to 1,570'. Made three passes from 1,300' to 2,000' to scrap tubing wall of potential ice build up. Continue run in hole to 6,425.5' and tagged debris in tubing. Pull out of hole with E-line, work ice plug area three times from 1,300' to 2,000' to scrap tubing wall of potential ice build up. Continue pull out of hole with E-line. 19:30 00:00 4.50 24.00 PROD- MAN R 15 P E-line Run #13; Run in hole with 2.03" gauge cutter and 2.19" fluted centralizer to 6,423.5' and tag debris in tubing. Made correlation pass to GLM #1 at 5,932.86'. Pull out of hole with E-line. 88 PSI tubing, 6 PSI A-Annulus, 502 PSI B-Annulus. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.dillon@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tyler Rush ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/13/2023 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 20.7 Wind E @ 21 MPH Days LTI (days) 1,346.00 Days RI (days) POB 21.0 Daily Summary Operations 24h Forecast E-line operations as procedure. Freeze protect tubing. Hand well over to Production group. 24h Summary Continue pull out of hole with 2.03" gauge cutter and 2.19" fluted centralizer to surface on E-line. Replaced alternator and belts on Worley crane. Run in hole with Welltec 218 puncher to 6,421.34' and tag debris in tubing. Punch 1/2" diameter holes in tubing at 6,411.19' and 6,410.69'. Operation at 07.00 Prepare to hand well over to Production group. 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 PROD- MAN R 15 P Continue pull out of hole with 2.03" gauge cutter and 2.19" fluted centralizer to surface on E-line. Work ice plug area three times from 1,300' to 2,000' to scrap tubing wall of potential ice build up while pulling out of hole. Close swab valve and secondary swab valve. Unable to pop off well due to Worley crane alternator belt broken. 01:00 15:30 14.50 15.50 PROD- MAN R 25 U Worley mechanic arrived on location at 0530 HRS and troubleshoot crane. Determined the alternator he brought with him was not correct one. New alternator and belts arrived on location at 1400 HRS. Replaced alternator and belts on crane. 15:30 19:00 3.50 19.00 PROD- MAN R 5 P Lay down lubricator and 2.19" drift BHA. Cut off 80' of E-line and re-head 9/3, 3213 LBS weak point. Change out liner wiper element. 19:00 20:00 1.00 20.00 PROD- MAN R 5 P Make up Welltec 218 puncher, 2.126" max OD, 13.29' CCL to bit, 10.13' bit to bottom of tool, 23.42' CCL to bottom of tool. Pressure test lubricator with 60°F LVT to 500 PSI low and 2500 PSI high, good test. 20:00 00:00 4.00 24.00 PROD- MAN R 15 P E-line Run #14; Run in hole with Welltec 218 puncher to 6,421.34' and tag debris in tubing. Made three correlation passes and discussed with Anchorage team for hole placement. Punch 1/2" diameter holes in tubing at 6,411.19' and 6,410.69'. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.dillon@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tyler Rush ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/14/2023 Report #: 10 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 31.8 Wind SE @ 20 MPH Days LTI (days) 1,353.00 Days RI (days) POB 18.0 Daily Summary Operations 24h Forecast Well handed over to Production group. No further work on ODSN-31. 24h Summary Attempt to punch holes in tubing with Welltec 218 puncher. Welltec 218 puncher failed to apply force against tubing wall. Pull out of hole with E-line. Lay down lubricator. Rig down wireline valves and secondary swab valve. Secure well with tree cap. Freeze protect tubing with 17 BBLs of LVT. Hand well over to Production group. No further work on ODSN-31. Operation at 07.00 No further work on ODSN-31. 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 PROD- MAN R 15 U Attempt to punch holes in tubing with Welltec 218 puncher. Welltec 218 puncher failed to apply force against tubing wall. Troubleshoot. Suspect internal hydraulic failure. Pull out of hole with E-line. 04:00 07:00 3.00 7.00 PROD- MAN R 5 P Lay down lubricator. Inspect Welltec 218 puncher tool, found bit would spin but not extend out from tool. Rig down wireline valves and secondary swab valve. Secure well with tree cap. 07:00 08:00 1.00 8.00 PROD- MAN R 9 P Freeze protect tubing with 17 BBLs of LVT. Staged pump rate from 0.25 BPM to 1 BPM, 325 max PSI. SITP 250 PSI, 6 PSI A- Annulus, 492 PSI B-Annulus. Hand well over to Production group. No further work on ODSN-31. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Paul Dillon ASRC Energy Services Co. Man Paul.dillon@external.eni.com 907-670-6606 Eni representative Bob Smejkal ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tyler Rush ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/26/2023 Report #: 11 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 24.8 Wind NE @ 23 MPH Days LTI (days) 1,365.00 Days RI (days) POB 22.0 Daily Summary Operations 24h Forecast Continue e-line operations on ODSN-31. 24h Summary Mobilize from SID to ODS. MIRU Halliburton E-line, Worley Crane and LRS. Held lift plan meeting. Rebuilt grease injection head and install new grease tubes. Re-head wireline. Assemble lubricator. Function test and verify hydraulic system. Make up BHA #1. Stab on and PT lubricator to 2500 psi for 10 min. Run in hole with 2.34" drift to 1997' (TRSV) and no restrictions. Operation at 07.00 Run in hole. Correlate Welltec hole puncher. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 11:00 11.00 11.00 PROD- MAN A 1 P No activity at this time. 11:00 13:00 2.00 13.00 PROD- MAN A 1 P Mobilize crews from SID to ODS. 13:00 14:00 1.00 14.00 PROD- MAN A 1 P Held lift plan meeting with all parties involved. EIP walk down of the well bay. Handover well from Production to Drilling. 14:00 20:00 6.00 20.00 PROD- MAN R 5 P MIRU Halliburton E-line, Worley Crane and Little Red. Rebuild grease head and install new grease tubes. Re-head wireline. Assemble lubricator and make up BHA #1. Function test and verify tool trap, grease injector head and wireline BOP's working properly. 20:00 22:00 2.00 22.00 PROD- MAN R 15 P Shut in tubing pressure 1000 psi. Stab on well and pressure test lubricator to 2500 psi for 10 minutes. Test good. Run in the hole with BHA #1, CH-CCL, E/L-S/L crossover QC-5'-1.50" STEM-QC-5'-1.50" STEM-QC-10'-1.50" Roller stem-QC-LSS-QC- 2.34" NO-GO Centralizer. Set down at 1997' MD. Pulled out of the hole. 22:00 00:00 2.00 24.00 PROD- MAN R 15 P Shut in and bleed off unstab, Add CH-CCL-E/L-S/L crossover - QC-5'-1.50" STEM-QC-5"-1.50" STEM-QC-10'-1.5" Roller stem -QC-LSS-QC-2.34" No-go centralizer- 5'-1.25" stem-flapper checker. Stab onto well. Vault rep grease and service primary swab valve. LRS pressure test 250 psi low, 2,500 psi high. Good test. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-670-6606 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tyler Rush ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/27/2023 Report #: 12 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 27.1 Wind N @ 16 MPH Days LTI (days) 1,366.00 Days RI (days) POB 22.0 Daily Summary Operations 24h Forecast Continue Passport testing on ODSN-31. Hand well over to Production group. No further E-line work on ODSN-31. 24h Summary Perform flapper checker run at 1997'. Make up BHA #3 and tag at 6421'. Make up BHA #4. Run in the hole with WellTec tubing puncher and perform 3 correlation passes from 6395' to 5933'. Punch holes as procedure. Pull out of the hole, inspect WellTec tools and equipment. Conduct inflow test and passport test with Vault rep. Passport testing on ODSN-31. Operation at 07.00 Hand well over to Production group. No further E-line work on ODSN-31. 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 PROD- MAN R 15 P Continue run in hole with CH-CCL-E/L-S/L crossover-QC-5'-1.50" STEM-QC-5"-1.50" STEM-QC-10'-1.5" Roller stem-QC-LSS- QC-2.34" No-go centrilizer-5'-1.25" stem-flapper checker. Set down at 1997' MD. Made 3 passes to verify TRSV is fully open. Control line gauge holding 5,000 psi. Pulled out of the hole. 01:30 03:00 1.50 3.00 PROD- MAN R 25 P Shut in bleed off. Unstab, remove flapper checker- broken brass pins. Couple bent pins. Decided to replace flapper checker pines. Added repined flapper checker. Stab onto well. Begin LRS pressure testing with 250 psi/2,500 psi. Good test. 03:00 06:00 3.00 6.00 PROD- MAN R 15 P Run in hole with CH-CCL-E/L-S/L crossover-QC-5'-1.50" STEM-QC-5"-1.50" STEM-QC-10'-1.5" Roller stem-QC-LSS-QC- 2.34" No-go centrilizer-5'-1.25" stem-flapper checker. Set down at 1997' MD. Set down in TRSV. Closed TRSV and pulled light tension against flapper to ensure flapper was closed. Applied 5,000 psi and open TRSV. Pull out of hole with flapper checker. Shut in bleed off. Unstab remove flapper checker, 2 broken brass pins. CCL showing extra pick up weight at 1997' inside a profile. 06:00 09:30 3.50 9.50 PROD- MAN R 15 P Make up BHA #3. Stab on well. Pressure test lubricator. Run in the hole with CH-CCL-E/L-S/L crossover-QC-5'-1.50" STEM- QC-5"-1.50" STEM-QC-10'-1.5" Roller stem-QC-LSS-QC-XO-8'-2.125" STEM-XO-2.19" Centralizer. Tag at 6421' (No additional fill). Pull out of hole. Unstab and laydown tools string. 09:30 21:30 12.00 21.50 PROD- MAN R 15 P Make up BHA #4. Stab on well. Pressure test lubricator. Run in the hole with CH-2.125" SW 218 STD-WRD-CCL-WMS 218 SR02-2.125" Welltec Puncher 218 SR02 to 6421'. Perform 3 CCL passes from 6395' (XN-Nipple) to 5933' (GLM#1). Sent correlation passes to town and discuss tubing punch depths. Punched hole depths at 6,399', 6398' 0.5", 6398’, 6397' 0.5", 6397', 6396' 0.5". Pulled out of the hole, once the tool string was rigged down. WellTec hole puncher was inspected and verified it was functioning properly post run. Secured well. Rig down Halliburton E-line tools and equipment. 21:30 22:00 0.50 22.00 PROD- MAN K 12 P Vault rep conduct inflow test. Initial tubing pressure 1027 psi closed TRSV. Flapper tubing pressure was bleed down to 400 psi. Monitor tubing pressure 10 min increase to 450 psi, 50 psi increase in 10 min. 22:00 22:30 0.50 22.50 PROD- MAN C 1 P PJSM. Discuss work, JSA’s, EIP walk down, and acquire permit(s). 22:30 23:00 0.50 23.00 PROD- MAN C 12 P Perform tree inspection and testing procedures per Eni well integrity policies, Inspect each tree flange connections measuring gaps and bolt torque per specifications. Check flanges with hammer wrench: Flange F1, F5, F6 torqued to 953 ft lbs, F3 torqued to 2,570 ft lbs, F2 hammered to 0 gap, F4 hammered to even gap tolerance of .19", F7 & F8 torqued to 319 ft.lbs. 23:00 23:30 0.50 23.50 PROD- MAN C 12 P Fluid pack tree and lines, purge air out of system, and stabilize thermal expansion of fluid, Pressure test lines to 3500 psi, perform shell test at 3,000 psi for 10 minutes, (Good test) 23:30 00:00 0.50 24.00 PROD- MAN C 12 P Pressure test swab valve A to 3,000 psi for 30 minutes, (Good test) Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-670-6606 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Tyler Rush ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: RIGLESS WCEI: N/A Daily Report Date: 5/28/2023 Report #: 13 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name Contractor Rig Type Rig Num Daily Information Weather Overcast Temperature (°F) 30.7 Wind E @ 16 MPH Days LTI (days) 1,367.00 Days RI (days) POB 14.0 Daily Summary Operations 24h Forecast Hand well over to production group, No further work on ODSN-31. 24h Summary Perform passport test as procedure. Operation at 07.00 Hand well over to production group, No further work on ODSN-31. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 PROD- MAN C 12 P Pressure test swab valve A to 3,000 psi for 30 minutes, good test. 00:30 01:30 1.00 1.50 PROD- MAN C 12 P Re-align manifold to test wing valve (B), perform pressure test on wing valve (B) to 3,000 psi for 30 minutes, good test. 01:30 03:30 2.00 3.50 PROD- MAN C 12 P Remove TWC and install tree cap. Test tree cap to 3000 psi for 10 min, good test. Secure well. Rig down test equipment. Hand well over to Production group. No further work on ODSN-31 Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Jody Cornell ASRC Energy Services Co. Man jody.cornell@external.eni.com 907-685-0710 Eni representative Craig Smith ASRC Energy Services Co. Man Craig.Smith@external.eni.com 907-670-6606 Eni representative Yelyzaveta Saprykina ASRC Energy Services Rig Clerk AKRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE ODSSafety@eni.com 970-685-6622 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 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: Tubing punch 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 ODSN-31 9. Property Designation (Lease Number): 10. Field: Current Pools: Oooguruk Nuiqsut Oil Pool Nuiqsut Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15,363' 6189' 15,355' 6188' N/A N/A Casing Collapse Structural Conductor N/A Surface 3090 Intermediate 5410 Production N/A Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): See attachement-3 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: 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 See attachment 2 7912' See attachment 2 2-7/8" 4-1/2" 16" 9-5/8" 110' 3092' Perforation Depth MD (ft): 7"7567' N/A MD 7240 N/A 5750 158' 3036' 6233' 158' 3131' 6193' - 6189'7446' - 15,358' 7605' Length Size Proposed Pools: TVD Burst 1965 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355036 / ADL 389958 208-003 3700 Centerpoint Drive, Ste. 500, Anchorage, AK 99503 50-703-20565-00-00 Eni US Operating Co. Inc. Bryan Mclellan 5/12/2023 Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft):Tubing Size: L-80, TH533/IBT 5779 12-May-23 N/A See attachement-3 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 5/12/2023 amjad.chaudhry@eni.com Well Operations Project Manager 907-865-3379 P m n P s 2 6 5 6 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov orgio Iannucc By Grace Christianson at 9:41 am, May 15, 2023 323-288 BJM 6/5/23 SFD 5/17/2023 10-404 GCW 06/05/2023JLC 6/5/2023 DSR-6/5/23 06/06/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.06 07:05:08 -08'00' RBDMS JSB 060623 Top (MD)Top (TVD) 7,800 6,274 8,006 6,300 8,214 6,301 8,421 6,297 8,627 6,295 8,835 6,293 9,041 6,288 9,250 6,277 9,460 6,273 9,669 6,266 9,880 6,260 10,090 6,241 10,301 6,223 10,512 6,206 10,716 6,197 10,925 6,197 11,124 6,207 11,325 6,221 11,530 6,230 11,737 6,232 11,936 6,236 12,140 6,235 12,350 6,226 12,513 6,212 12,964 6,197 13,437 6,224 13,916 6,190 14,409 6,187 14,897 6,176 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 15,350 6,190 Attachment 2 Sundry Report Box 11 - Perforation Locations Well: ODSN-31 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Ported w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) AOGCC Form 10-404 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) SSSV MD TVD HES 'NE' TRSV w/ "X" Profile 1,997 1,964 PACKERS MD TVD 2,600 2,532 7,427 6,188 7,452 6,194 WFT Genesis Oil Base Swell Packer 12,657 6,200 WFT Genesis Oil Base Swell Packer 12,768 6,199 Attachment 3 WFT "NTH" Liner Top Packer WFT "NTH" Liner Top Packer AOGCC Form 10-404 Report of Sundry Box 11 - Packers & SSSV Well: ODSN-31 Halliburton ESP Packer 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Giorgio Iannucci Phone (907) 865-33 Email: Giorgio.iannucci@eni.com May 12th, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for ODSN-31 Rig less Intervention Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Rig less Intervention Sundry for well ODSN-31. ODSN-31 well currently shut in and plan for this Rig less intervention job is to punch hole in 2- 7/8” production tubing to create a flow path around ESP and start producing from Nuiqsut formation and put well back on production. Estimated date for beginning this work is May 12th, 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, Giorgio Iannucci Well Operations Project Manager ncerely, ODSN-31 Rig Less Intervention –Proposal Summary and Wellbore Schematic PTD#: 208-003 Current Status Well, ODSN-31 is currently shut down. Scope of Work Objective of this Rig-less intervention is to punch holes in the TBG to create a flow path around the ESP and produce the intended crude from the Nuiqsut formation General Well Info Reservoir Pressure/TVD: The estimated reservoir pressure in mid-March for ODSN-31 Nuiqsut is 2,600 psi at -6,350’ TVDss (chart below), yielding a maximum anticipated surface pressure (MASP) of 1,965 psi. ODSN-31 Estimated Nuiqsut Pressure March 2022 Depth 6,350 TVD, ss Pressure (estimated)2,600 psi Gradient 0.41 psi/ft PPGE 7.9 ppge MASP (0.1 psi/ft gradient to surface).1,965 psi Wellhead type/pressure rating: Vault PC, MB-233/5000 psi (/LQH3&(: Rig less Eline unit'XDO5DP BOPSVL Well type: Producer TIFL/MIT-IA/MIT-OA: Intermediate- (7”) casing was pressure tested to 2800 psi during the workover performed in September 2022. Estimated start date: May 12th, 2023 Drilling Rig: Rig-Less Halliburton Eline Unit Sr. Drilling Engineer: Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations Project Manager: Giorgio Iannucci Giorgio iannucci@eni.com Work: 907-865-3320 Procedure Summary x MIRU wireline over ODSN-31 x Tubing punch 2-7/8”make total 8 total holes first hole at 6413’MD 7 more hole every 6 inches above 6413’MD. x RD Welltec puncher and WL x Hand over well to production Current well schematic Proposed Completion will be the same as current completion, perforation in tubing will be added at +/- 6413’MD. From:McLellan, Bryan J (OGC) To:Chaudhry Amjad Subject:RE: [EXTERNAL] RE: rig less tubing punch on ODSN-31 PTD 208-003 Date:Friday, May 12, 2023 12:16:00 PM Amjad, ENI has verbal approval to proceed with the activity described below. Please follow up with a sundry within 3 days. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Sent: Friday, May 12, 2023 9:58 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: rig less tubing punch on ODSN-31 PTD 208-003 Bryan this is the summary program: MIRU wireline over ODSN-31 Tubing punch 2-7/8” make total 8 total holes first hole at 6413’ MD 7 more hole every 6 inches above 6413’ MD. RD Welltec puncher and WL Hand over well to production Thanks Amjad From: Chaudhry Amjad Security Warning: This email originated from outside of the organization. Do not click links or open attachments unless you have verified the sender’s email address and know the content is safe. Sent: Friday, May 12, 2023 9:39 AM To: 'McLellan, Bryan J (OGC)' <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: rig less tubing punch on ODSN-31 PTD 208-003 Bryan, The ultimate objective is to punch holes in the TBG to create a flow path around the ESP and produce the intended crude from the Nuiqsut formation. The ESP at this point is plugged with debris and cannot produce fluid to surface. Punching the intended holes will allow us to put the well on gas lift and still utilize the well as intended. Thanks Amjad From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, May 12, 2023 8:59 AM To: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Subject: [EXTERNAL] RE: rig less tubing punch on ODSN-31 PTD 208-003 Amjad, Could you send a wellbore diagram and let me know what is the objective of the tubing punch? I need a little more information before I can approve it. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 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: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Sent: Friday, May 12, 2023 8:12 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: rig less tubing punch on ODSN-31 PTD 208-003 Bryan, we are planning to tubing punch on ODSN-31 and since we don’t have a sundry matrix set yet so I thought I should apply for a sundry, but everything is on location and I am requesting for a verbal approval for this rigless operation I will submit a sundry application today later in the day, thanks this is general program outline, thanks Perform the drift run in the TBG with a 2.19” centralizer. Perform the Welltec TBG puncher perforation in the TBG as per program POOH and RD Best regards Amjad Chaudhry P.Eng Sr. Drilling Engineer Eni US Operating Co. Inc. 3700 Centerpoint Dr., Suite 500 Anchorage, AK 99503 (: 907-865-3379 D (: 907-346-0591 M E.mail: amjad.chaudhry@eni.com This document and any files or e-mail messages attached to it contain data or information that is confidential, privileged or otherwise restricted from disclosure. If you are not the intended recipient, be aware that any disclosure, copying, distribution or use of any of the data or information contained herein or in any of the attachments is strictly prohibited. If you have received this document or transmission in error, please immediately notify the sender and destroy, delete or erase this document and all attachments. ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ ODSN-31 Nuiqsut Producer 158' 16" Conductor 3,131' (3,036' TVD) 9-5/8" 40# L80 BTC 7,606' (6,234' TVD) 7" 26# (on record) L80 BTC-M 15,363' (6,189' TVD) 6-1/8" TD 7231' Tag Fish: Tech line 11.5' + Check v/v and ¼ chemical injection line 32' (2022-08) As Run 2022-12-16 15,358' (6,190' TVD) 4-½ 12.6# L80 TH521 Liner WFT Genesis Oil Swell Packer 12,657' (6,200' TVD) 30 each 4' pup (6 each ½ holes) ~200' apart WFT Genesis Oil Swell Packer 12,768' (6,199' TVD) 7,452' (6,194' TVD) WFT NTH LTP/PHR Liner Hanger with 15' TBS 7,427' (6,188' TVD) WFT 7"x5" 15# NTH LTP/PHR Liner Hanger with 15' TBS 2200' Est. TOC 3673' Casing Leak 1 joint 7" 26# below hanger + 7" 23# (Caliper data 2022-8-17) SSSV GL GL GL 6,732' ES Stage Cementer 825' TAM Port Collar 103' XO 3-½ TH Blue x 2-7/8" TH563 1997' (1964' TVD) 19° TRSV, HAL 2.313 X Profile 2543' GLM#3, SLB w/DV 2600' (2532' TVD) 19° ESP Packer, HAL 2642' GLM#2, SLB w/DV 2694' X Nippl3, 2.313 2704' XO TH563 B x IBT P 5933' GLM#1, SLB w/5/16" OV 6395' 2.313 XN Nipple, 2.205 No-Go 6541' (5805' TVD) 53° Bottom of ESP Completion: 2-7/8" 6.5# L80 TH533/IBT Well Head: Vault MB-233 2009-08 D&C 2010-03 Replace ESP 2017-08 Replace ESP 2019-07 Punch TBG 6462-6467' 2022-10 Patch CSG & Replace ESP 2022-12 Replace PKR & Upper Completion 5922' XO IBT B x TH563 P 3654' SALTEL CSG Patch ID 5.646" Drift 5.315" (5.513" calculated) 3698' Bottom of CSG Patch 6435' Discharge Assembly 1 Regg, James B (OGC) From:Henson, James <James.Henson@nabors.com> Sent:Monday, December 12, 2022 7:13 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Turcotte, Matthew; Holcomb, Sean; Beard, Seth; Ashley Timothy; Mbx ODSDrilling Subject:19E BOPE TEST REPORT 12-11-22 Attachments:Nabors 19AC 12-11-22.xlsx James Henson Jr. 19E Rig Manager NABORS ALASKA DRILLING, INC. Direct 907.670.6630 I Mobile 907.398.3080 james.henson@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:19AC DATE: 12/11/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #2080030 Sundry #322-661 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1965 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" X 5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2 7/8" X 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)2950 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1500 P Check Valve 0 NA 200 psi Attained (sec)13 P BOP Misc 0 NA Full Pressure Attained (sec)66 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6@2025 P No. Valves 15 FP ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 28 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0 NA #3 Rams 11 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:1 Test Time:8.5 HCR Choke 5 P Repair or replacement of equipment will be made within days. HCR Kill 5 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12-9-2022 10:20 Waived By Test Start Date/Time:12/11/2022 15:00 (date) (time)Witness Test Finish Date/Time:12/11/2022 23:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Test Jt's 2 7/8" & 4" , Choke manifold valve #1 Fail. Rebuild valve and re-test good. James Henson/Sean Holcomb ENI Tim Ashley/Paul Dillon Oooguruk ODSN-31 Test Pressure (psi): james.henson@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022) 2022-1211_BOP_Nabors19AC_Oooguruk_ODSN-31 Choke manifold valve #1 Fail. FP Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: Alaska Oil and Gas ConservaƟon Commissio 333 W. 7th Ave, Anchorage, AK 99501 January 19, 2023 Well:ODSNͲ31 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs EͲline logs 7" Multiginger Caliper Log x x 7" ACX x x 7" CAST x x PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. By Meredith Guhl at 10:24 am, Jan 19, 2023 208-003 T37448 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.19 10:24:38 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chaudhry Amjad Subject:RE: Eni sundry modification request for PTD: 208-003 ,SUndry 322-661 Date:Thursday, December 1, 2022 7:25:00 AM Amjad, ENI has approval to reduce the pressure test of the 2-7/8” x 7” annulus to 2500 psi, which is above MPSP of 1965 psi. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Sent: Wednesday, November 30, 2022 4:34 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Eni sundry modification request for PTD: 208-003 ,SUndry 322-661 Hello Bryan, I accidentally put in ODSN-31 sundry summited/approved a 3500psi annular test. The previous ODSN-31 sundry was redacted and reduced to 2500psi as per Alex’s email below, I apologize for the trouble for the same reason as per Alex’s email dated August 17th can I request for the Annulus pressure test to 2500 psi? Thanks again ODSN-31 approved sundry image002.jpg Amjad Begin forwarded message: From: Vaughan Alex <Alex.Vaughan@external.eni.com> Date: August 17, 2022 at 2:19:46 PM AKDT To: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Cc: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Subject: Eni sundry modification request for PTD: 208-003 ,212-030, 209-079, 208-040 Bryan, As discussed last week Eni is requesting to reduce the production casing string pressure test after setting the ESP packer from 3500psi to 2500psi. This request is intended to reduce cycle load on the ESP cable penetrator through our tubing hangers. This will have no change to the approved sundry’s obligating Eni to pressure test the production casing string with a casing test packer below to top of cement which occurs in a preceding step of each program. This will affect the following approved sundry’s: 1. ODSN-31 1. PTD: 208-003 2. Sundry #: 322-049 2. ODSN-25 1. PTD: 212-030 2. Sundry #: 322-217 3. ODST-45A 1. PTD: 209-079 2. Sundry #: 322-250 4. ODST-39 1. PTD: 208-040 2. Sundry #: 322-229 Example affected text from ODST-39: <image004.jpg> Alex Vaughan Sr. Drilling & Completions Compliance Engineer Eni US Operating Co. Inc. 3700 Centerpoint Dr. Suite 500 Anchorage, AK, 99503 (907) 748-5478 M <image006.jpg> ----------------------------------------------------------------------------------------------------------------------------------------- ------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:ODSN-31 (PTD 208-003) wellfile Date:Thursday, December 1, 2022 7:28:00 AM Attachments:RE Eni sundry modification request for PTD 208-003 SUndry 322-661.msg Please add the attached email to the wellfile in association with sundry 322-661. Thank you Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 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 Swap____ 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 15,363 feet N/A feet true vertical 6,189 feet N/A feet Effective Depth measured 6,582 feet See attachment, pg. 3 feet true vertical 6,119 feet See attachment, pg. 3 feet Perforation depth Measured depth See attachment, pg. 2 feet True Vertical depth See attachment, pg. 2 feet Tubing (size, grade, measured and true vertical depth)2-7/8", 6.5# L-80, TH533/IBT 6435' MD 5,779' TVD Packers and SSSV (type, measured and true vertical depth)See attachment, pg. 3 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Nuiqsut 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 Stefano Pierfelici 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 7,567' 7,912' Casing Structural 6,234' 4-1/2" 7,606' 15,358'6,190' Plugs Junk measured 3,131'3,036' 16" 9-5/8" Size 158' 7" 8,430 psi N/A 5,750 psi 7,240 psi Burst Collapse N/A 3,090 psi 5,410 psi ACX will be submitted electronically 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 355036 / ADL 389958 Oooguruk - Nuiqsut Oil Pool Eni US Operating Co. Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-003 50-703-20565-00-00 3700 Centerpoint Dr, Suite 500, 995033. Address: ODSN-31 MD 1064 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 1168 3453 Length 110' 3,092' 158'Conductor Surface Intermediate 322-661 Sr Pet Eng: 7,500 psi Sr Pet Geo:Sr Res Eng: WINJ WAG 1758 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf 70 2821582 312 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 496 p k ft t Fra O s 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 Stefano Pierfelici By Samantha Carlisle at 8:02 am, Jan 17, 2023 DSR-1/17/23 RBDMS JSB 012623 Top (MD)Top (TVD) 7,800 6,274 8,006 6,300 8,214 6,301 8,421 6,297 8,627 6,295 8,835 6,293 9,041 6,288 9,250 6,277 9,460 6,273 9,669 6,266 9,880 6,260 10,090 6,241 10,301 6,223 10,512 6,206 10,716 6,197 10,925 6,197 11,124 6,207 11,325 6,221 11,530 6,230 11,737 6,232 11,936 6,236 12,140 6,235 12,350 6,226 12,513 6,212 12,964 6,197 13,437 6,224 13,916 6,190 14,409 6,187 14,897 6,176 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 15,350 6,190 Attachment 2 Sundry Report Box 11 - Perforation Locations Well: ODSN-31 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Ported w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) AOGCC Form 10-404 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) 4-1/2" Perforated Pup (Porter w/ 6-1/2" Holes) SSSV MD TVD HES 'NE' TRSV w/ "X" Profile 1,997 1,964 PACKERS MD TVD 2,600 2,532 7,427 6,188 7,452 6,194 WFT Genesis Oil Base Swell Packer 12,657 6,200 WFT Genesis Oil Base Swell Packer 12,768 6,199 Attachment 3 WFT "NTH" Liner Top Packer WFT "NTH" Liner Top Packer AOGCC Form 10-404 Report of Sundry Box 11 - Packers & SSSV Well: ODSN-31 Halliburton ESP Packer ODSN-31 Nuiqsut Producer 158' 16" Conductor 3,131' (3,036' TVD) 9-5/8" 40# L80 BTC 7,606' (6,234' TVD) 7" 26# (on record) L80 BTC-M 15,363' (6,189' TVD) 6-1/8" TD 7231' Tag Fish: Tech line 11.5' + Check v/v and ¼” chemical injection line 32' (2022-08) As Run 2022-12-16 15,358' (6,190' TVD) 4-½” 12.6# L80 TH521 Liner WFT Genesis Oil Swell Packer 12,657' (6,200' TVD) 30 each 4' pup (6 each ½” holes) ~200' apart WFT Genesis Oil Swell Packer 12,768' (6,199' TVD) 7,452' (6,194' TVD) WFT NTH LTP/PHR Liner Hanger with 15' TBS 7,427' (6,188' TVD) WFT 7"x5" 15# NTH LTP/PHR Liner Hanger with 15' TBS 2200' Est. TOC 3673' Casing Leak 1 joint 7" 26# below hanger + 7" 23# (Caliper data 2022-8-17) SSSV GL GL GL 6,732' ES Stage Cementer 825' TAM Port Collar 103' XO 3-½” TH Blue x 2-7/8" TH563 1997' (1964' TVD) 19° TRSV, HAL 2.313 X Profile 2543' GLM#3, SLB w/DV 2600' (2532' TVD) 19° ESP Packer, HAL 2642' GLM#2, SLB w/DV 2694' X Nippl3, 2.313 2704' XO TH563 B x IBT P 5933' GLM#1, SLB w/5/16" OV 6395' 2.313 XN Nipple, 2.205 No-Go 6541' (5805' TVD) 53° Bottom of ESP Completion: 2-7/8" 6.5# L80 TH533/IBT Well Head: Vault MB-233 2009-08 D&C 2010-03 Replace ESP 2017-08 Replace ESP 2019-07 Punch TBG 6462-6467' 2022-10 Patch CSG & Replace ESP 2022-12 Replace PKR & Upper Completion 5922' XO IBT B x TH563 P 3654' SALTEL CSG Patch ID 5.646" Drift 5.315" (5.513" calculated) 3698' Bottom of CSG Patch 6435' Discharge Assembly Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/9/2022 Report #: 1 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 16.5 Wind SW @ 12 MPH Days LTI (days) Days RI (days) POB 44.0 Daily Summary Operations 24h Forecast Halliburton Slickline operations thru X-Mas tree as planned. Install BPV and nipple down X-Mas tree. Nipple up BOPs. Test BOPE with 2-7/8” and 4” tubulars as per AOGCC test requirements. 24h Summary Move Nabors Rig 19AC from ODSN-25 to ODSN-31 and spot over well center. Rig up and prepare for rig operations. Perform post rig remove Mast Drops inspection. Mobilize pressure control equipment into pipe shed and up beaver slide. Rig up Halliburton Slickline pressure control equipment and secondary swab valve. Operation at 07.00 Halliburton Slickline operations. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 06:00 12:00 6.00 6.00 MOB A 2 P PJSM, Move Nabors Rig 19AC from ODSN-25 to ODSN-31 and spot over well center. Rig accepted at 0601 HRS on 12-9-22. 12:00 18:00 6.00 12.00 W.O. A 2 P PJSM, Install berms around rig. Safe out rig egress areas, spot Geo-log unit, and spot accumulator unit. Install HUTZ hoses with wind block, PUTZ hoses, and beaver slide pedestal. Transfer fresh water to rig. 18:00 19:00 1.00 13.00 W.O. A 1 P Perform post rig remove Mast Drops inspection. 19:00 00:00 5.00 18.00 W.O. R 5 P PJSM, Mobilize pressure control equipment into pipe shed and up beaver slide. Rig up Halliburton Slickline pressure control equipment and secondary swab valve. On load 8.6 PPG brine with 3% KCL in mud pits. Simops: Production bleeding down A- Annulus. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/10/2022 Report #: 2 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 1.9 Wind SW @ 12 MPH Days LTI (days) Days RI (days) POB 53.0 Daily Summary Operations 24h Forecast Bullhead tubing and A-Annulus. Halliburton Slickline operations thru X-Mas tree as planned. Install BPV and nipple down X-Mas tree. Nipple up BOPs. Test BOPE with 2-7/8” and 4” tubulars as per AOGCC test requirements. Prepare rig floor to pull ESP upper completion string. 24h Summary Rig up Halliburton Slickline pressure control equipment. Halliburton Slickline operations thru X-Mas tree as planned. Fluid pack A-Annulus above packer and remove freeze protect. Operation at 07.00 Rigging down Halliburton slickline. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 W.O. R 5 P PJSM, Rig up Halliburton Slickline pressure control equipment. Function test wireline valves. Install 2" pump line and valve manifold to wireline pump in sub. Fluid pack lines and lubricator. Pressure test lubricator against swab valve to 300 PSI for 5 minutes and 3500 PSI for 10 minutes. Good test. 03:30 06:00 2.50 6.00 W.O. R 15 P Slickline operations; Run #1, Run in hole with 2.32” gauge ring to TRSV at 2,030’. Run #2, Run in hole with 2.33” No-Go centralizer and 2.31” flapper checker to TRSV at 2,030’. Run #3, run in hole with 2.30” gauge ring and 2-7/8” braided line brush to X-nipple at 2,667’. 06:00 11:30 5.50 11.50 W.O. R 15 P Slickline operations; Run #4, Run in hole with 2-7/8” XX plug and catcher sub to 2,030’. Unable to pass thru TRSV at 2,030’. Pull out of hole and redress 2-7/8” XX plug. Run #4 Re-run, Run in hole and set 2-7/8” XX plug in X-nipple at 2,667’. Pressure test tubing to 1,000 PSI for 10 minutes, good test. Run #5, Run in hole with 2-7/8” OK-6 kick over tool with 1-1/4” JDC pulling tool and pull dummy valve from GLM #3 at 2,517’. 11:30 14:00 2.50 14.00 W.O. R 9 P PJSM, Circulate 160 BBLs of 8.6 PPG brine around wellbore thru GLM #3 at 2,517’ MD to fluid pack A-Annulus above packer and remove freeze protect, 4 BPM, 440 PSI. Attempt to combo pressure test 2-7/8” tubing and A-Annulus to 2500 PSI. Unable to achieve a successful test. 14:00 19:00 5.00 19.00 W.O. R 20 P Slickline operations suspended until crew has rested from reaching 16 hour maximum working hours. Simops: rig maintenance and general housekeeping. 19:00 22:00 3.00 22.00 W.O. R 15 P Slickline operations; Run #6, Run in hole with 2-7/8” OK-6 kick over tool with JK running tool and set dummy valve in GLM #3 at 2,517’. Pressure test tubing to 1000 PSI for 10 minutes to ensure DV in GLM #3 is holding, good test. 22:00 00:00 2.00 24.00 W.O. R 15 P Slickline operations; Run #7, Run in hole with 2-7/8” OK-6 kick over tool with 1-1/4” JDC pulling tool and pull dummy valve from GLM #2 at 2,616’. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/11/2022 Report #: 3 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) -3.8 Wind E @ 18 MPH Days LTI (days) Days RI (days) POB 52.0 Daily Summary Operations 24h Forecast Pull 2-7/8” ESP upper completion string as planned. 24h Summary Halliburton Slickline operations thru X-Mas tree as planned. Bullhead tubing and A-Annulus. Install BPV and nipple down X-Mas tree. Nipple up BOPs. Test BOPE with 2-7/8” and 4” tubulars as per AOGCC test requirements, good tests. Operation at 07.00 Preparations to pull ESP completion. 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. R 9 P PJSM, Bullhead 240 BBLs of 8.6 PPG brine down tubing thru GLM #2 at 2,616’ MD and down A-Annulus, 3.2 BPM, 950 PSI. 02:00 04:30 2.50 4.50 W.O. R 15 P Slickline operations; Run #8, Run in hole with 2-7/8” GR profile with equalizing prong to XX plug set at 2,667’ and equalize pressure across XX plug. Run #9, Run in hole with 2-7/8” GR pulling tool and pull XX plug set at 2,667’. Bullhead 46 BBLs of 8.6 PPG brine down tubing, 4 BPM, 950 PSI. 04:30 07:00 2.50 7.00 W.O. R 5 P PJSM, Rig down Halliburton Slickline, pressure control equipment, and secondary swab valve. 07:00 08:30 1.50 8.50 W.O. C 5 P PJSM, Close TRSV. Install BPV and remove X-Mas tree with Vault representative. Install blanking sub. Terminate TRSV, packer vent valve control line, and chemical injection capillary line. 08:30 12:00 3.50 12.00 W.O. C 5 P PJSM, Nipple up BOPE and control lines. Function test upper pipe rams, lower pipe rams, blind shear rams, choke HCR, kill HCR, and annular preventer. Install flow riser with 2” fill line. 12:00 15:00 3.00 15.00 W.O. C 12 P PJSM, Rig up to test BOPE. Make up floor valves in preparation to test. Flood stack, choke manifold, and top drive. Purge air out of system. Perform shell test to 250 PSI low and 3500 PSI high. Good test. 15:00 23:30 8.50 23.50 W.O. C 12 P Test BOPE with 2-7/8” and 4” tubulars, 4” FOSV, 4” IBOP, choke and manifold as per AOGCC test requirements. Test to 250 PSI and 3500 PSI, annular BOP to 250 PSI and 2500 PSI, held each test 5 minutes and chart. Good test, one failure. Rebuilt # 1 choke manifold valve, re-test good. Perform accumulator drawdown test. Starting pressures; annular 1200 PSI, manifold 1500 PSI, accumulator 2950 PSI. 1600 PSI accumulator pressure after functioning all components with electric and air pumps turned off. 13 seconds to build 200 psi with electric pumps. 66 seconds for full recovery with both air and electric pumps. 2025 PSI 6 nitrogen bottle average PSI. Test H2S and LEL high/low gas alarms, PVT, and flow out indicator. BOPE test witness waived by Austin McLeod. 23:30 00:00 0.50 24.00 W.O. C 5 P Rig down BOPE test equipment. Blow down choke, kill, and top drive. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/12/2022 Report #: 4 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) 7.7 Wind S @ 7 MPH Days LTI (days) Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Run 2-7/8” ESP upper completion string as planned. Perform Halliburton Slickline operations as planned. Set production packer. Freeze protect A-Annulus. Pressure test production packer and A-Annulus to 2500 PSI. Bleed down A-Annulus as per Baker Centerlift procedures. Perform Halliburton Slickline operations as planned. 24h Summary Bullhead tubing and A-Annulus. Pull BPV from tubing hanger. Pull out of hole laying down 2-7/8” upper completion string form 6,442’ to 4004’. Found ESP Cable severed from penetrator above packer. Prepare rig floor to run 2-7/8” upper completion string. Operation at 07.00 Run in hole with 2-7/8" upper completion string. 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. C 9 P PJSM, Pressure underneath BPV. Install landing joint and bullhead 240 BBLs of 8.6 PPG brine down tubing thru GLM #2 at 2,616’ MD and down A-Annulus, 2 BPM, 740 PSI. 04:00 07:00 3.00 7.00 W.O. C 5 P PJSM, Monitor well. Remove landing joint and pull BPV with Vault representative. 07:00 10:00 3.00 10.00 W.O. L 1 P PJSM, Prepare rig floor to pull 2-7/8” upper completion string. Attach elephant truck to ESP cable sheave in derrick. 10:00 15:00 5.00 15.00 W.O. L 5 P PJSM, Unseat 2-7/8” tubing hanger with 140K UW. Packer released with 155K UW. Pull tubing hanger to rig floor. Test ESP cable for continuity witnessed by ENI electrician, test failed. Connect ESP cable to rope for ESP spool. Lay down tubing hanger, swivel joint, and 2 joints of 3-1/2” tubing. Change pipe handling equipment to 2-7/8”. Fill A-Annulus with 10 BPH of 8.6 PPG brine every hour plus pipe displacement. 15:00 20:00 5.00 20.00 W.O. L 4 P PJSM, Pull out of hole laying down 2-7/8” upper completion string form 6,442’ to 4,004’. Found ESP Cable severed from penetrator above packer. Fill A-Annulus with 10 BPH of 8.6 PPG brine every hour plus pipe displacement. 20:00 00:00 4.00 24.00 W.O. L 4 P PJSM, Remove ESP penetrator, packer vent valve, and capillary line from packer. Lay down production packer. Test ESP cable below packer to ESP pump for continuity witnessed by ENI electrician, good test. Pull out of hole from 4,004’ to 3,861’. Lay down 1 joint of tubing in order to have enough slack in ESP cable to make up to new production packer. Prepare rig floor to run 2-7/8” upper completion string. Fill A-Annulus with 10 BPH of 8.6 PPG brine every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/13/2022 Report #: 5 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) 1.9 Wind S @ 15 MPH Days LTI (days) Days RI (days) POB 46.0 Daily Summary Operations 24h Forecast Run 2-7/8” ESP upper completion string as planned. Perform Halliburton Slickline operations as planned. Set production packer. Freeze protect A-Annulus. Pressure test production packer and A-Annulus to 2500 PSI. Bleed down A-Annulus as per Baker Centerlift procedures. Perform Halliburton Slickline operations as planned. 24h Summary Prepare rig floor to run 2-7/8” upper completion string. Bullhead tubing and A-Annulus. Run in hole with 2-7/8” ESP upper completion string from 3,861’ to 4004’. Run chemical injection line from spooler over sheave in derrick and attach to packer. Attach ESP cable to PFT penetrator. Perform continuity test on ESP cable across production packer to ESP pump witnessed by ENI electrician, good test. Operation at 07.00 Mobilizing Halliburton packer. 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 PJSM, Prepare rig floor to run 2-7/8” upper completion string. Change out capillary line spools. Change out ESP cable in spooler unit. Arrange new jewelry in pipe shed to run in hole. Bring new ESP cable over sheaves to rig floor. Fill A-Annulus with 10 BPH of 8.6 PPG 3%KCL brine every hour. 06:00 07:00 1.00 7.00 W.O. K 4 P PJSM, Run in hole with 2-7/8” ESP upper completion string from 3,861’ to 4004’. 07:00 10:00 3.00 10.00 W.O. K 20 P PJSM, Splice ESP cable and attach to production packer, witnessed by ENI electrician. Installed packer vent valve and capillary line. 10:00 15:00 5.00 15.00 W.O. K 9 P PJSM, bullhead 40 BBLs of 8.6 PPG 3% KCL brine down tubing, 0.75 BPM, 840 PSI. Bullhead 323 BBLs of 8.6 PPG 3% KCL brine down A-Annulus in preparations of running in hole. 3.2 BPM, 840 PSI. Monitor well. Blow down top drive. 15:00 00:00 9.00 24.00 W.O. K 5 P PJSM, Run chemical injection line from spooler over sheave in derrick and attach to packer. Attach ESP cable to PFT penetrator. Perform continuity test on ESP cable across production packer to ESP pump witnessed by ENI electrician, good test. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Sean Holcomb Nabors Rig Manager Sean.Holcomb@nabors.com 907-670-6630 Safety Representative Erik Bohlen' Murphy Nabors HSE Erik.Bohlen@nabors.com 907-685-6632 Safety Representative Andrew Wright Nabors HSE Andrew.Wright@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/14/2022 Report #: 6 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) -2.7 Wind S @ 21 MPH Days LTI (days) Days RI (days) POB 55.0 Daily Summary Operations 24h Forecast Run 2-7/8” ESP upper completion string as planned from 5,087’ to 6,542’ MD landed on tubing hanger. Perform Halliburton Slickline operations as planned. Set production packer. Pressure test production packer and A-Annulus to 2500 PSI. Bleed down A-Annulus as per Baker Centerlift procedures. Perform Halliburton Slickline operations as planned. Install TWC. Nipple down BOPs. Install X-mas tree. Perform passport test. 24h Summary Observed gouge in 2-7/8” pup joint below packer. Mobilized packer to Halliburton to have pup joint replaced and tested. Attach ESP cable to production packer and PFT penetrator above packer. Perform continuity test on ESP cable across production packer to ESP pump witnessed by ENI electrician, good test. Run 2-7/8” ESP upper completion string as planned from 3,941’ to 5,087’ MD. Operation at 07.00 Terminating ESP cable on hanger. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 W.O. K 21 U Observed damage in 2-7/8” pup joint below packer. Mobilized packer to Halliburton to have pup joint replaced and tested. Simops; Service top drive and blocks, check motors on draw works, clean and organize rig. Fill A-Annulus with 10 BPH of 8.6 PPG 3% KCL brine every hour. Nabors crew training on WICF and WOCRM. 12:00 18:00 6.00 18.00 W.O. K 5 P PJSM, Make up production packer into string. Attach ESP cable to production packer and PFT penetrator above packer. Perform continuity test on ESP cable across production packer to ESP pump witnessed by ENI electrician, good test. Installed packer vent valve, capillary line and function test, good test. Install check valve in chemical injection line below packer. Fill A- Annulus with 10 BPH of 8.6 PPG 3% KCL brine every hour. 18:00 00:00 6.00 24.00 W.O. K 4 P PJSM, Run in hole picking up 2-7/8” 6.4 PPF, L-80, Wedge 533 tubing from 3,941’ to 5,087’ MD. Perform continuity checks on ESP cable every 1000’. Fill A-Annulus with 10 BPH of 8.6 PPG 3% KCL brine every hour. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Paul Dillon ASRC Energy Services Drilling Supv. Paul.Dillon@external.eni.com 907-685-0715 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Jon Castle Nabors HSE John.Castle@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/15/2022 Report #: 7 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Clear Temperature (°F) -10.1 Wind S @ 7 MPH Days LTI (days) Days RI (days) POB 53.0 Daily Summary Operations 24h Forecast Continued changing out water pump on Halliburton slick-line unit, continue Slick-Line operations as per plan, Drop ball and rod set and test packer, continue Slick-Line operations, Nipple down BOP stack, nipple up tree and test, 24h Summary Run ESP completion assembly as per plan, land hanger at 6540.84' MD. Rig up Halliburton Slick-Line full pressure control equipment, Halliburton mechanic arrived on location 22:00 hrs to change out water pump on slick-line unit. Operation at 07.00 Halliburton Slick-line operations. 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 4 P PJSM, Run in hole picking up 2-7/8” 6.4 PPF, L-80, Wedge 533 tubing from 5,087' to 6437'. Perform continuity checks on ESP cable every 1000’. Add 10 BPH of 8.6 PPG 3% KCL brine every hour to Annulus =A, 5,000 psi held on TRSV to hold open , Chem, Injection line 5,000 psi held open, s/o/w=87k 05:00 10:00 5.00 10.00 W.O. K 4 P Bring old tubing hanger to rig floor remove swivel off the bottom , bring up new hanger and install swivel on bottom of new hanger, Make up hanger to landing joint, Test safety valve per Halliburton Rep 6K psi for 15 min, good. Test on packer vent 5k, good. Cut ESP cable as per Baker rep, Hook ESP to hanger and test, good. Test chemical line as per baker Rep, good. Add 10 BPH of 8.6 PPG 3% KCL brine every hour to Annulus A, 10:00 12:00 2.00 12.00 W.O. K 1 P PJSM, Vault, Halliburton, Baker and SLB Reps perform packer vent line and TRSV hanger penetrations, pressure up TRSV to 5700 psi and hold psi, while Halliburton slick line operations, Install ESP umbilical wire lines prior to landing hanger. Land hanger at 6540.84' MD, with a P/U/W= 105K S/O/W= 85K Add 10 BPH of 8.6 PPG 3% KCL brine every hour to Annulus =A, 12:00 00:00 12.00 24.00 W.O. K 1 P PJSM, Vault Rep test hanger voids to 5,000 psi witnessed by ENI Company man and Driller (good), swap landing joint to wire line landing joint, Install floor safety valve, Prep to rig up Halliburton Slick -line with full pressure control Equipment. Halliburton mechanic arrived on location 22:00 hrs to change out water pump on slick-line unit. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Jon Castle Nabors HSE John.Castle@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/16/2022 Report #: 8 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) -13.4 Wind WSW @ 17 MPH Days LTI (days) Days RI (days) POB 61.0 Daily Summary Operations 24h Forecast Perform Passport test on tree, Final checks on ESP. Perform final Integrity test on PW and TRSV, Perform chemical injection valve pump through test. Pump into capillary line to ensure chemical Injection valve is open, Visual check each fittings for leaks. Remove BPV, secure well and hand over to Production. Move from ODSN-31 to ODSN-41. 24h Summary Halliburton Mechanic arrived on location 22:00 hrs. change out water pump on slick-line unit, Conduct Halliburton Slick-Line operations as per plan, seat ball and rod in X-Nipple set and test Packer (good). Proceed bleed off procedure as per Baker Hughes. Continue Slick-Line operations, Rig down Halliburton tools and equipment, Nipple down BOP stack, Nipple up tree and begin Passport test. Operation at 07.00 Rig moving from ODSN-31 to ODSN-41. Time Log Start Time End Time Dur (hr) Cum Dur (hr)Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 W.O. K 25 TS03 Finish installing water pump on Halliburton unit, (Tested Good) 01:30 04:00 2.50 4.00 W.O. R 15 P PJSM, Halliburton Slick-Line operations, Stab lubricator, test to 1,500 psi, (good) run in the hole with ball and rod set in the X- Nipple / RHC at 2697' ft. W/L/M, Pull out of the hole, Install night cap on top of lubricator, 04:00 06:30 2.50 6.50 W.O. K 12 P Fill tubing with 4 bbls. Pressure up on tubing to 3,900 psi, test 30 min charted, (Good Test). Bleed tubing pressure off to 1,500 psi. 06:30 11:00 4.50 11.00 W.O. K 12 P Fill Annulus A with 13 bbl. Pressure up to 2700 psi hold 30 min, charted, good. Baker Hughes rep witnessed bleed down procedure as per well plan, Monitor ESP cable through out bleeding off Annulus=A and Tubing. 11:00 13:00 2.00 13.00 W.O. R 15 P PJSM Halliburton Slick-Line operations, Run in the hole to 2697' pull ball and rod, pull out of the hole, Change out BHA, Run in the hole pulled RHC from X-Nipple, TRSV 4,600 psi, PI-2339 - 2336 psi, TI-140.5 TM-143.9 VX-.006 VZ-.010 VT-120.4 CT-9.9 13:00 14:30 1.50 14.50 W.O. R 5 P PJSM, Rig down Halliburton Slick-Line pressure control tools and equipment from rig floor, stage in pipe shed. 14:30 15:30 1.00 15.50 W.O. K 20 P Halliburton completions rep close TRSV, Baker Hughes rep disconnect ESP umbilical line, final ESP readings prior to disconnecting, PI-2312.5 psi PD-2310 psi, TI-141.8, TM- 145.4, VX- .007, VZ- .014.VT- 120.3, CT- 9.9, Pull 3-1/2 wire line landing joint, Install TWC Valve in well head profile as per Vault rep, offload fluid from mud pits and blow down all lines. 15:30 18:00 2.50 18.00 W.O. C 5 P PJSM Nipple down BOP's bleed Koomy unit off, Remove flow riser, Remove choke and kill lines from BOP stack, Remove drill riser lay down in pipe shed, disconnect lines in Putz, Rig down Geolog shack. 18:00 00:00 6.00 24.00 W.O. C 5 P PJSM. Nipple up tree, Vault Rep test tree void, Witnessed by ENI Company man, Begin Passport test on tree. Continued rigging down for rig move, LO/TO skate and raise skate extension, on load fuel and H2O to rig, Remove hoses in Putz, Remove bearming around rig and lay rig mats for rig move, remove beaver slide pedestal, remove ground wire from well head, Pull accumulator lines from cellar, Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Jon Castle Nabors HSE John.Castle@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date LINER 4 1/2 4.00 L80 7,452.3 15,358.0 6,188.5 7/14/2009 Well Name: ODSN-31 Wellbore Name: Original Hole Well Code: 25511 Job: WORKOVER WCEI: LEVEL 3 Daily Report Date: 12/17/2022 Report #: 9 Page: 1 of 1 Well Header Permit/Concession N° ADL-355038 Operator ENI PETROLEUM Subsidiary ENI Petroleum Co. Inc. Initial Lahee Code Rotary Table Elevation (ft) 56.20 Water Depth (ft) 0.00 First Flange (ft) 13.50 RKB - Base Flange (ft) 42.70 RKB - Tubing Spool (ft) 42.70 Rig Information Rig Name NABORS 19 AC Contractor NABORS ALASKA Rig Type LAND RIG Rig Num 0671 Daily Information Weather Overcast Temperature (°F) -13.7 Wind Calm Days LTI (days) Days RI (days) POB 62.0 Daily Summary Operations 24h Forecast Rig Move From ODSN-31 to ODSK-41 24h Summary Perform Passport test on tree, Final checks on ESP, Perform final Integrity test on PW and TRSV, Perform Chemical Injection Valve Pump through test, (all test good) Pump into Capillary line to ensure chemical Injection valve is open, Visual check each fittings for leak, Secure well and hand over to Production, Rig move From ODSN-31 to ODSk-41 Operation at 07.00 Job complete no activity on ODSN-31. 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 Passport test on tree, all test good. Final checks on ESP, Perform final Integrity test on PW and TRSV, Perform Chemical Injection Valve Pump Through Test, (all test good) Pump into Capillary line to ensure chemical Injection valve is open. Visual check each fittings for leak, Final checks PVV 5800 psi, TRSV 0 Psi, (Closed) PI-2430.70, PD-2424.0, TI-144.8, TM-148.7,VX-.015, VZ-.016,VT-120.2,CT-9.9, Pre Rig check list Secure well and hand over to Production, Release Rig at 05:00 on 12-17-2022. Daily Contacts Position Contact Name Company Title Email Office Mobile Eni representative Tim Ashley ASRC Energy Services Drilling Supv. Timothy.Ashley@external.eni.com 907-670-6606 Eni representative Craig Smith ASRC Energy Services Drilling Supv. ODSdrilling@eni.com 907-670-6606 Eni representative Mitch Billington ASRC Energy Services Clerk AkRigClerksDoyon15@eni.com 907-685-0722 Safety Representative Jack Potter ASRC Energy Services HSE jack.potter@external.eni.com 907-670-6622 Tool Push James Henson JR Nabors Rig Manager James.Henson@nabors.com 907-670-6630 Tool Push Seth Beard Nabors Tool Pusher Seth.Beard@nabors.com 907-670-6630 Safety Representative Jon Castle Nabors HSE John.Castle@nabors.com 907-685-6632 Safety Representative John French Nabors HSE John.French@nabors.com 907-685-6632 Last Casing Seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) TVD Bot. (ftKB) Landing Date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y Anne Prysunka at 4:18 pm, Nov 18, 2022 %23 WHVW WR SVL $QQXODU WHVW WR SVL ; '/% ; '65%-0 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.11.22 08:47:18 -09'00' RBDMS JSB 112322 dŽƉ;DͿ dŽƉ;dsͿ ϳ͕ϴϬϬ ϲ͕Ϯϳϰ ϴ͕ϬϬϲ ϲ͕ϯϬϬ ϴ͕Ϯϭϰ ϲ͕ϯϬϭ ϴ͕ϰϮϭ ϲ͕Ϯϵϳ ϴ͕ϲϮϳ ϲ͕Ϯϵϱ ϴ͕ϴϯϱ ϲ͕Ϯϵϯ ϵ͕Ϭϰϭ ϲ͕Ϯϴϴ ϵ͕ϮϱϬ ϲ͕Ϯϳϳ ϵ͕ϰϲϬ ϲ͕Ϯϳϯ ϵ͕ϲϲϵ ϲ͕Ϯϲϲ ϵ͕ϴϴϬ ϲ͕ϮϲϬ ϭϬ͕ϬϵϬ ϲ͕Ϯϰϭ ϭϬ͕ϯϬϭ ϲ͕ϮϮϯ ϭϬ͕ϱϭϮ ϲ͕ϮϬϲ ϭϬ͕ϳϭϲ ϲ͕ϭϵϳ ϭϬ͕ϵϮϱ ϲ͕ϭϵϳ ϭϭ͕ϭϮϰ ϲ͕ϮϬϳ ϭϭ͕ϯϮϱ ϲ͕ϮϮϭ ϭϭ͕ϱϯϬ ϲ͕ϮϯϬ ϭϭ͕ϳϯϳ ϲ͕ϮϯϮ ϭϭ͕ϵϯϲ ϲ͕Ϯϯϲ ϭϮ͕ϭϰϬ ϲ͕Ϯϯϱ ϭϮ͕ϯϱϬ ϲ͕ϮϮϲ ϭϮ͕ϱϭϯ ϲ͕ϮϭϮ ϭϮ͕ϵϲϰ ϲ͕ϭϵϳ ϭϯ͕ϰϯϳ ϲ͕ϮϮϰ ϭϯ͕ϵϭϲ ϲ͕ϭϵϬ ϭϰ͕ϰϬϵ ϲ͕ϭϴϳ ϭϰ͕ϴϵϳ ϲ͕ϭϳϲ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϭϱ͕ϯϱϬ ϲ͕ϭϵϬ ƚƚĂĐŚŵĞŶƚϮ ^ƵŶĚƌǇZĞƉŽƌƚ ŽǆϭϭͲWĞƌĨŽƌĂƚŝŽŶ>ŽĐĂƚŝŽŶƐ tĞůů͗K^EͲϯϭ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞĚǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ K'&ŽƌŵϭϬͲϰϬϯ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ^^^s Dds ,^dZ^sǁͬΗyΗWƌŽĨŝůĞ Ϯ͕Ϭϯϭ ϭ͕ϵϵϲ W<Z^Dds Ϯ͕ϱϳϰ Ϯ͕ϱϬϴ ϳ͕ϰϰϯ ϲ͕ϭϵϮ ϳ͕ϰϲϴ ϲ͕ϭϵϵ t&d'ĞŶĞƐŝƐKŝůĂƐĞ^ǁĞůůWĂĐŬĞƌ ϭϮ͕ϲϱϳ ϲ͕ϮϬϬ t&d'ĞŶĞƐŝƐKŝůĂƐĞ^ǁĞůůWĂĐŬĞƌ ϭϮ͕ϳϲϴ ϲ͕ϭϵϵ ƚƚĂĐŚŵĞŶƚϯ t&dΗEd,Η>ŝŶĞƌdŽƉWĂĐŬĞƌ t&dΗEd,Η>ŝŶĞƌdŽƉWĂĐŬĞƌ K'&ŽƌŵϭϬͲϰϬϯ ZĞƉŽƌƚŽĨ^ƵŶĚƌǇ ŽǆϭϭͲWĂĐŬĞƌƐΘ^^^s tĞůů͗K^EͲϯϭ ,^^WWĂĐŬĞƌ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¶0'WR ¶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±3URSRVDO6XPPDU\DQG:HOOERUH6FKHPDWLF 37' &XUUHQW6WDWXV :HOO2'61LVFXUUHQWO\VKXWGRZQ 6FRSHRI:RUN 6FRSHRIWKLVZRUNRYHULVWRSXOOH[LVWLQJ´FRPSOHWLRQDQGIDLOHG(635XQDQHZ (63FRPSOHWLRQLQFOXGLQJDFKHPLFDOLQMHFWLRQOLQHDQGEDFNXSJDVOLIW *HQHUDO:HOO,QIR 5HVHUYRLU3UHVVXUH79' 7KHHVWLPDWHGUHVHUYRLUSUHVVXUHLQPLG0DUFKIRU 2'61 1XLTVXW LV SVL DW ¶ 79'VV FKDUW EHORZ \LHOGLQJ D PD[LPXP DQWLFLSDWHG VXUIDFHSUHVVXUH0$63RISVL K^EͲϯϭƐƚŝŵĂƚĞĚEƵŝƋƐƵƚWƌĞƐƐƵƌĞDĂƌĐŚϮϬϮϮ ĞƉƚŚϲ͕ϯϱϬds͕ƐƐ WƌĞƐƐƵƌĞ;ĞƐƚŝŵĂƚĞĚͿϮ͕ϲϬϬƉƐŝ 'ƌĂĚŝĞŶƚϬ͘ϰϭƉƐŝͬĨƚ WW'ϳ͘ϵƉƉŐĞ D^W;Ϭ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚƚŽƐƵƌĨĂĐĞͿ͘ϭ͕ϵϲϱƉƐŝ :HOOKHDGW\SHSUHVVXUHUDWLQJ 9DXOW3&0%SVL %23FRQILJXUDWLRQ $QQXODU3LSH%OLQG3LSH :HOOW\SH3URGXFHU 7,)/0,7,$0,72$ ,QWHUPHGLDWH ´ FDVLQJ ZDV SUHVVXUH WHVWHG WR SVL GXULQJ WKH ZRUNRYHU SHUIRUPHG LQ 6HSWHPEHU (VWLPDWHGVWDUWGDWH 1RYHPEHUWK 'ULOOLQJ5LJ1DERUV 6U'ULOOLQJ(QJLQHHU $PMDG&KDXGKU\ $PMDGFKDXGKU\#HQLFRP :RUN :HOO2SHUDWLRQV3URMHFW0DQDJHU 6WHIDQR3LHUIHOLFL 6WHIDQRSLHUIHOLFL#HQLFRP :RUN 3URFHGXUH6XPPDU\ x0,581DERUV$& x,QVWDOOWHVWGDUW x1'7UHH18%23( x7HVW%23(SVLORZSVLKLJK$QQXODUWRSVL o7HVWMRLQWV´´´ x,QVWDOO´ODQGLQJMRLQWLQWKHWXELQJKDQJHUZ)269PDGHXS o%XOOKHDGEEOYLVSLOOGRZQWXELQJIROORZHGE\WXELQJYROXPHRI ILOWHUHGVHDZDWHU o%2/'6DQGSXOOWKHWXELQJKDQJHUDQGWKHSDFNHUIUHH 3DFNHUZLOOVKHDUUHOHDVHZLWKVWUDLJKWSXOO o%XOOKHDGDEEOVYLVSLOOIROORZHGE\DQQXODUYROXPHRIILOWHUHG VHDZDWHU x3XOOWKHò´[´(63FRPSOHWLRQVWULQJRXWRIWKHKROH o+DYH(FKRPHWHURQULJWRVKRRWIOXLGOHYHOV o5HVSRRO(63FDEOHó´7U669FDSWXEHó´399FDSWXEH ´&KHP FDSWXEH x38 5,+´[´(63FRPSOHWLRQ o1RWH5+&LQVWDOOHGLQ;QLSSOH o1RWHSVL'&.LQVWDOOHGLQ*/0 x/DQGKDQJHUDQGWHVWERWKWKHXSSHUDQGORZHUWXELQJKDQJHUERG\VHDOVWR SVL x5HOHDVHSDFNHUVHWWLQJEDOODQGURG o,IIOXLGLVZLWKLQ¶0'YLDHFRPHWHUGURSEDOODQGURGIURPVXUIDFH o,IIOXLGLVJUHDWHUWKDQ¶0'IURPVXUIDFHUXQRQVOLFNOLQH x)LOOWXELQJZLWKVHDZDWHUDQGVHW(63SDFNHU x3HUIRUPWXELQJDQGDQQXOXVSUHVVXUHWHVW o5HGXFHWXELQJSUHVVXUHIURP(63SDFNHUVHWWLQJSUHVVXUHWRSVL o3UHVVXUHWHVW´[´DQQXOXVWRSVL o%OHHGWXELQJSUHVVXUHGRZQWR]HURWRVKHDU'&.LQ*/0 5HGXFHSUHVVXUHSHU&HQWULOLIW$QQXOXV3UHVVXUH&RQWUROVFKHGXOH WRPLWLJDWHULVNRI(63FDEOHGDPDJH x&ORVH75669 x&RQILUP399LVFORVHG x6HW7:& x1'%23(187UHH x3HUIRUP3DVVSRUWWHVW x3XOO7:& x&LUFXODWH/97IUHH]HSURWHFWLRQWR(63SDFNHUGRZQDQQXOXVWRWXELQJ x52021DERUV$& &XUUHQWZHOOVFKHPDWLF 3URSRVHG&RPSOHWLRQZLOOEHWKHVDPHDVFXUUHQWFRPSOHWLRQRQO\IHHWGLIIHUHQFHLQ FRPSOHWLRQMHZHOU\ZLOOEHH[SHFWHG Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To: ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽ 333 W. 7th Ave, Anchorage, AK 99501 October 26, 2022 Well:ODSN-31 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs E-line logs ACX X X CAST X X PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. PTD:208-003 T37187 Kayla Junke Digitally signed by Kayla Junke Date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y Anne Prysunka at 8:38 am, Oct 14, 2022 /ŶŽǆϭϯĂŶŽƉƌŽĚƵĐƚŝŽŶĚĂƚĂŝƐĂǀĂŝůĂďůĞďĞĐĂƵƐĞ ǁĞůůŚĂƐŶŽƚƉƌŽĚƵĐĞĚƐŝŶĐĞƚŚĞZtK͘dŚĞ^WǁĂƐ ƐŚŽƌƚĞĚƵƉŽŶůĂŶĚŝŶŐĂŶĚǁĞĐĂŶŶŽƚŐĞƚŐĂƐůŝĨƚĚŽǁŶ ƚŚĞ/ƚŽůŝĨƚƚŚĞǁĞůů͘tŝůůůŝŬĞůǇŶŽƚƉƌŽĚƵĐĞƵŶƚŝůĂŶ ĂĚĚŝƚŝŽŶĂůZtKŝƐƉĞƌĨŽƌŵĞĚ͘ dŽƉ;DͿ dŽƉ;dsͿ ϳ͕ϴϬϬ ϲ͕Ϯϳϰ ϴ͕ϬϬϲ ϲ͕ϯϬϬ ϴ͕Ϯϭϰ ϲ͕ϯϬϭ ϴ͕ϰϮϭ ϲ͕Ϯϵϳ ϴ͕ϲϮϳ ϲ͕Ϯϵϱ ϴ͕ϴϯϱ ϲ͕Ϯϵϯ ϵ͕Ϭϰϭ ϲ͕Ϯϴϴ ϵ͕ϮϱϬ ϲ͕Ϯϳϳ ϵ͕ϰϲϬ ϲ͕Ϯϳϯ ϵ͕ϲϲϵ ϲ͕Ϯϲϲ ϵ͕ϴϴϬ ϲ͕ϮϲϬ ϭϬ͕ϬϵϬ ϲ͕Ϯϰϭ ϭϬ͕ϯϬϭ ϲ͕ϮϮϯ ϭϬ͕ϱϭϮ ϲ͕ϮϬϲ ϭϬ͕ϳϭϲ ϲ͕ϭϵϳ ϭϬ͕ϵϮϱ ϲ͕ϭϵϳ ϭϭ͕ϭϮϰ ϲ͕ϮϬϳ ϭϭ͕ϯϮϱ ϲ͕ϮϮϭ ϭϭ͕ϱϯϬ ϲ͕ϮϯϬ ϭϭ͕ϳϯϳ ϲ͕ϮϯϮ ϭϭ͕ϵϯϲ ϲ͕Ϯϯϲ ϭϮ͕ϭϰϬ ϲ͕Ϯϯϱ ϭϮ͕ϯϱϬ ϲ͕ϮϮϲ ϭϮ͕ϱϭϯ ϲ͕ϮϭϮ ϭϮ͕ϵϲϰ ϲ͕ϭϵϳ ϭϯ͕ϰϯϳ ϲ͕ϮϮϰ ϭϯ͕ϵϭϲ ϲ͕ϭϵϬ ϭϰ͕ϰϬϵ ϲ͕ϭϴϳ ϭϰ͕ϴϵϳ ϲ͕ϭϳϲ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϭϱ͕ϯϱϬ ϲ͕ϭϵϬ ƚƚĂĐŚŵĞŶƚϮ ^ƵŶĚƌǇZĞƉŽƌƚ ŽǆϭϭͲWĞƌĨŽƌĂƚŝŽŶ>ŽĐĂƚŝŽŶƐ tĞůů͗K^EͲϯϭ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞĚǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ K'&ŽƌŵϭϬͲϰϬϰ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ^^^s Dds ,^ΖEΖdZ^sǁͬΗyΗWƌŽĨŝůĞ Ϯ͕Ϭϯϭ ϭ͕ϵϵϲ W<Z^Dds Ϯ͕ϱϳϰ Ϯ͕ϱϬϴ ϳ͕ϰϰϯ ϲ͕ϭϵϮ ϳ͕ϰϲϴ ϲ͕ϭϵϵ t&d'ĞŶĞƐŝƐKŝůĂƐĞ^ǁĞůůWĂĐŬĞƌ ϭϮ͕ϲϱϳ ϲ͕ϮϬϬ t&d'ĞŶĞƐŝƐKŝůĂƐĞ^ǁĞůůWĂĐŬĞƌ ϭϮ͕ϳϲϴ ϲ͕ϭϵϵ ƚƚĂĐŚŵĞŶƚϯ t&dΗEd,Η>ŝŶĞƌdŽƉWĂĐŬĞƌ t&dΗEd,Η>ŝŶĞƌdŽƉWĂĐŬĞƌ K'&ŽƌŵϭϬͲϰϬϰ ZĞƉŽƌƚŽĨ^ƵŶĚƌǇ ŽǆϭϭͲWĂĐŬĞƌƐΘ^^^s tĞůů͗K^EͲϯϭ ,ĂůůŝďƵƌƚŽŶ^WWĂĐŬĞƌ 2'611XLTVXW3URGXFHU &RQGXFWRU 79' /%7& 79' RQUHFRUG /%7&0 79' 7' 7DJ)LVK 7HFKOLQH &KHFNYYDQGó´FKHPLFDOLQMHFWLRQOLQH $V5XQ 79' ò´ /7+/LQHU :)7*HQHVLV2LO6ZHOO3DFNHU 79' HDFK SXS HDFKò´KROHVa DSDUW :)7*HQHVLV2LO6ZHOO3DFNHU 79' 79' :)717+/733+5/LQHU+DQJHUZLWK 7%6 79' :)7[ 17+/733+5/LQHU+DQJHUZLWK 7%6 (VW 72& &DVLQJ/HDN MRLQW EHORZKDQJHU &DOLSHUGDWD 6669 */ */ */ (66WDJH&HPHQWHU 7$03RUW&ROODU ;2ò´7+%OXH[ 7+ 79' 7569 +$/;3URILOH 79' */0 6/%Z'9 79' (633DFNHU +$/ 79' */0 6/%Z'9 79' ;1LSSOH ;27+%[,%73 79' */0 6/%Z 29 ;11LSSOH 1R*R 79' %RWWRPRI(63 &RPSOHWLRQ /7+,%7 :HOO+HDG9DXOW0% ' & 5HSODFH(63 5HSODFH(63 3XQFK7%* 3DWFK&6* 5HSODFH(63 ;2,%7%[7+3 6$/7(/&6*3DWFK,' 'ULIW FDOFXODWHG %RWWRPRI&6*3DWFK 'LVFKDUJH$VVHPEO\ :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU &OHDU 7HPSHUDWXUH) :LQG 6(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHPRYH5LJWR2'616SRWDQGOHYHO5LJ3UHSIRUZHOORSHUDWLRQV K6XPPDU\ 0RYH5LJWR2'61 2SHUDWLRQDW &RQWLQXHPRYH5LJWR2'61 Time Log 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 $ 3 0RYH5LJWR2'616SRWDQGOHYHOULJ Daily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU &OHDU 7HPSHUDWXUH) :LQG 6#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 1LSSOHXS%23(3XOO%39DQGULJXSWRWHVW%23(5LJGRZQWHVWHTXLSPHQW5LJXS+DOOLEXUWRQ6OLFNOLQHWRUHWULHYH(92SOXJ K6XPPDU\ 0RYHULJIURP2'6.WR2'616SRWDQGOHYHOULJRQ2'61%OHHGSUHVVXUHEHWZHHQ(92SOXJDQG%39%OHHG%DQQXOXVWRSVL1LSSOHGRZQ7UHH 2SHUDWLRQDW 7HVWLQJ%23( Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 3DUWO\&ORXG\ 7HPSHUDWXUH) :LQG (#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 5LJXS6OLFNOLQHDQGUHWULHYH(92SOXJ5LJGRZQ6OLFNOLQHUHOHDVHSDFNHUDQGEXOOKHDGWXELQJDQG$DQQXOXV5LJXSDQG322+ZLWK(63FRPSOHWLRQ K6XPPDU\ %OHHGSUHVVXUHIURP$DQQXOXVDQGIXQFWLRQSDFNHUYHQWYDOYH1LSSOHXSPKLJKSUHVVXUHULVHUIORZHTXLSPHQWDQGFKRNHNLOOOLQHV3HUIRUPLQLWLDO%23(WHVW7HVWZLWQHVVZDLYHGE\$XVWLQ0F/HRG$2*&& RQ 2SHUDWLRQDW 3XPSLQJ%XOOKHDGLQJGRZQWXELQJDQG$DQQXOXV Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG :#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXH322+ZLWK(63FRPSOHWLRQ K6XPPDU\ 5LJXS6OLFNOLQHDQGSXOO(92YDOYH3ULRUWRPDNHXS7RS'ULYHLQWR7,:ODQGLQJMRLQWIORZLVREVHUYHGIURP7%*&ORVH7,:YDOYH5LJXSDQG%XOOKHDG%EOV33*IOXLGGRZQ7%*8QVHDW+DQJHUDQGSXOO XSDQGSDFNHUFDPHIUHH$IWHUSDFNHUUHOHDVHGSXOOXSDQGOHWVHDOVUHOD[/D\GRZQODQGLQJMRLQWDQGKDQJHU6WDUWKDQJLQJHOHSKDQWWUXQNIRU(63FDEOH3XPS%EOVGRZQ7EJ6KXWGRZQSXPSDQG322+ 2SHUDWLRQDW %XOOKHDGIOXLGVGRZQWXELQJDQG$DQQXOXV Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 6#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHWR322+ZLWK(63FRPSOHWLRQ K6XPPDU\ 322+IURP WR )ORZFKHFNPRQLWRUZHOO*DVEUHDNLQJRXWDWVXUIDFHDW &ORVHDQQXODUSUHYHQWHUDQGXSSHUSLSHUDPV&LUFXODWHGRZQ7%*WDNLQJUHWXUQVWKURXJKFKRNHPDQLIROGURXWHGWRWKH 3RRU%R\GHJDVVHUQRUHWXUQV3XPS7%*YROXPHWRWRSRISHUIRUDWLRQVZKLOHZRUNLQJ7%*3XPSHGEEOVIOXLG/LQHXSDQG%XOOKHDGGRZQWEJDQG$DQQXOXV 2SHUDWLRQDW 322+ZLWK(63FRPSOHWLRQDW 0' Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 322+ZLWK(63FRPSOHWLRQ0DNHXSDQG5,+ZLWKFOHDQRXW%+$SLFNLQJXSVLQJOHMRLQWVRI'3 K6XPPDU\ %XOOKHDGGRZQ7%*DQG$DQQXOXVLQSDUDOOHO6KXWGRZQSXPSDQGQRIOXLGPRYHPHQW322+IURP WR 2SHUDWLRQDW 3UHSWRPDNHXSFOHDQRXW%+$ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1:#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 322+DQGPDNHXSPRGLILHGVFUDSSHUDVVHPEO\DQG5,+322+DQGPDNH&6*WHVWUXQ K6XPPDU\ &RQWLQXH322+) WRVXUIDFHOD\GRZQ(63DVVHPEO\:KLOHLQVWDOOLQJ,'ZHDUEXVKLQJREVHUYHGFRQWUROOLQHVWXFNLQZHOOKHDG9HULI\VL]HRIDOOWXELQJRQ(63HTXLS1RFRQWUROOLQH PLVVLQJ08%27URSHVSHDUDQG5,+WRZHOOKHDGWRUHWULHYHFRQWUROOLQH5HWULHYHHDVHFWLRQVRIFRQWUROWXELQJ,QVWDOOZHDUEXVKLQJ38'3DQG5,+ZURSHVSHDUILVKLQJ%+$7 0'322+QR ILVK08PXOHVKRHDQGVLQJOHLQWKHKROH7 0'&XW6OLSGULOOLQJOLQH 2SHUDWLRQDW 5XQQLQJLQKROHZLWKFOHDQRXWDVVHPEO\ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 5DLQ 7HPSHUDWXUH) :LQG 6:#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 3XOORXWRIKROHVWUDSSLQJGULOOSLSHVWDQGV0DNHXSWHVW3.5DVVHPEO\DQG5,+DQGWHVW&6* K6XPPDU\ 322+ZLWK;7GULOOSLSHDQGPXOHVKRHVHUYLFHULJ08VWULQJPLOOVFUDSHU%+$DQGUXQLQKROH7URXEOHVKRRWGUDZRUNVSDUNLQJEUDNHFRQWLQXHUXQQLQJLQKROH:VWULQJPLOOVFUDSHU%+$WR DQGWDJ XSDWWHPSWWRZRUNSDVWREVWUXFWLRQZLWKQRVXFFHVV 2SHUDWLRQDW 3XOOLQJRXWRIKROHZLWKFOHDQRXWDVVHPEO\ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 6:#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQW322+:VWULQJPLOOVFUDSHU%+$DVSHUSODQ&OHDQDQGLQVSHFW%+$3XOOZHDUEXVKLQJULJXSDQGWHVW%23(0DNHXS767,,WHVWSDFNHU%+$5,+:767,,WHVWSDFNHU%+$ K6XPPDU\ 322+:VWULQJPLOOVFUDSHU%+$DVSHUSODQFOHDQDQGLQVSHFW%+$5,+%+$:VWULQJPLOOVFUDSHU7PG0L[DQGSXPS5LJIOXIIQVWXIIDVSHUSODQ322+:VWULQJPLOOVFUDSHU%+$DVSHU SODQ)PGWRPG 2SHUDWLRQDW 5LJJLQJXSWRWHVW%23V Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU &OHDU 7HPSHUDWXUH) :LQG 6#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWWHVWLQJ%23V0DNHXSWHVWSDFNHUUXQLQWKHKROHWR 0'7HVW,QWHUPHGLDWHFDVLQJSVLPLQFKDUWHGPLQ322+OD\LQJGRZQ GULOOSLSHLQWKHVKHG K6XPPDU\ &RQW322+:VWULQJPLOOVFUDSHU%+$DVSHUSODQFOHDQDQGLQVSHFW%+$3XOOZHDUEXVKLQJULJXSWHVWHTXLSPHQWDQGEHJLQWHVWLQJ%23( 2SHUDWLRQDW 7HVWLQJ%23V Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1:#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 322+ZLWK767OOWHVWSDFNHUWHVWLQJ33)FDVLQJHYHU\ SUHYLRXVWHVWIDLOHGVWDQGLQJGULOOSLSHEDFNLQGHUULFN,QVSHFWWHVWSDFNHUDWVXUIDFH5XQLQKROHZLWKEDFNXS767OOWHVWSDFNHUDQGSHUIRUP FDVLQJWHVW K6XPPDU\ &RPSOHWHWHVWLQJ%23(3LFNXS767OOWHVWSDFNHUUXQLQWKHKROHWR 0'WHVW33),QWHUPHGLDWHFDVLQJSVLPLQFKDUWHGPLQWHVWIDLOHG 2SHUDWLRQDW 3XOOLQJRXWRIKROHZLWK767OOWHVWSDFNHUWHVWLQJFVJHYHU\ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHWHVWLQJLQWHUPHGLDWHFDVLQJZLWK767,,SDFNHULQWDQGHPDERYH*7ORNVHWEULGJHSOXJ7HVWFDVLQJLQIWLQWHUYDOVIURPWRVXUIDFH K6XPPDU\ &RQWLQXHWHVWLQJLQWHUPHGLDWHFDVLQJIURP 0'ZLWK767OOWHVWSDFNHUXQDEOHWRJHWVROLGWHVWSXOORXWRIKROHWHVWLQJFDVLQJHYHU\ WRVXUIDFHZLWKSRRUUHVXOWV/D\GRZQLQVSHFWWHVWSDFNHUPDNH XSQHZ767,,SDFNHULQWDQGHPDERYH*7ORNVHWEULGJHSOXJ5XQLQWKHKROHILOOLQJGULOOSLSHHYHU\VWDQGV6HWSDFNHUDW 0' 2SHUDWLRQDW 7HVWLQJ,QWHUPHGLDWHFDVLQJ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 5DLQ 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 7ULSLQWKHKROHZLWK767,,SDFNHUDVVHPEO\DQGFRQWLQXHWHVWLQJFDVLQJDVSHUSODQ K6XPPDU\ &RQW7HVWLQJ,QWHUPHGLDWHFDVLQJZLWK767,,SDFNHULQWDQGHPDERYH*7/2.6HWEULGJHSOXJ7HVWFDVLQJLQIWLQWHUYDOVIURPWRVXUIDFH767,,SDFNHUIDLOHG'HFLVLRQZDVPDGHWULSRXW RIWKHKROH&KDQJHRXW767,,SDFNHU 2SHUDWLRQDW /D\LQJGRZQSDFNHUDVVHPEO\ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 6#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 7HVWFDVLQJIURP 0'WR6XUIDFH7ULSRXWRIWKHKROHWRVXUIDFHOD\GRZQSDFNHUDVVHPEO\5LJXS+DOOLEXUWRQZLUHOLQH K6XPPDU\ 7ULSLQWKHKROHZLWK767,,SDFNHUDVVHPEO\WR0'7HVWWRVXUIDFH7HVWIURP0'WRVXUIDFH7HVWIURP0'WR0'$OOWHVWIDLOHG&RQWLQXHWHVWLQJFDVLQJDVSHUSODQ 2SHUDWLRQDW 5LJJLQJXS+DOOLEXUWRQHOLQH Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 'UL]]OH0LVW 7HPSHUDWXUH) :LQG 1#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 5LJGRZQ+DOOLEXUWRQ(/LQHUXQNLOOVWULQJODQGKDQJHUQLSSOHGRZQ%23VDQGQLSSOHXSWUHH K6XPPDU\ &RQWWULSRXWRIWKHKROHIURP0'WRVXUIDFH5XQIWGULOOSLSHRQWKHERWWRPRISDFNHU7ULSLQKROHVHWFKDPSSDFNHUDW 0'WHVWFDVLQJIURP 0'WRVXUIDFHWHVWIDLOHG7ULSRXWRIWKHKROH WRVXUIDFHOD\GRZQSDFNHUDVVHPEO\5LJXS+DOOLEXUWRQ(OLQH5XQLQKROH:FDOLEHUORJWRROWR DQGORJWRVXUIDFH0DNHXSDMXQNEDVNHWDQGJDXJHULQJ5,+WR XQDEOHWRSDVV 322+ 'HFLVLRQPDGH5LJGRZQ(/LQH 2SHUDWLRQDW 5XQQLQJLQWKHKROHZLWKNLOOVWULQJ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 1LSSOHGRZQ%23VQLSSOHXSWUHHWHVWWUHHWRSVLIRUPLQPRYHULJWR2'61 K6XPPDU\ 5LJGRZQ+DOOLEXUWRQ(/LQHUXQNLOOVWULQJDQGODQGKDQJHUQLSSOHGRZQ%23VQLSSOHXSWUHHIUHH]HSURWHFWZHOO3UHS5LJWRPRYHWR2'61 2SHUDWLRQDW 1LSSOLQJXSWUHH Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU )RJ 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 2SHUDWLRQVVXVSHQGHGRQ2'61PRYHULJWR2'61 K6XPPDU\ %ORZGRZQOLQHVQLSSOHGRZQ%2361LSSOHXSWUHHWHVWWUHHJRRGWHVW5LJUHOHDVHGIURP2'61 2SHUDWLRQDW 1R$FWLYLW\ Time Log 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 & 3 5LJXSDQGEORZGRZQOLQHV1LSSOHGRZQ%23V :2 & 3 1LSSOHXSWUHHWHVWWUHHWR36,IRUPLQXWHVJRRGWHVW5LJGRZQWHVWHTXLSPHQW 1RWH :HOORSHUDWLRQVRQ2'61KDYHEHHQVXVSHQGHG 5LJUHOHDVHGIURP2'61DW Daily Contacts 3RVLWLRQ &RQWDFW1DPH &RPSDQ\ 7LWOH (PDLO 2IILFH 0RELOH (QLUHSUHVHQWDWLYH -XVWLQ+D\V $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY2'6GULOOLQJ#HQLFRP (QLUHSUHVHQWDWLYH &UDLJ6PLWK $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY&UDLJ6PLWK#H[WHUQDOHQLFRP (QLUHSUHVHQWDWLYH -RG\&RUQHOO $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY 2'6GULOOLQJ#HQLFRP 6DIHW\5HSUHVHQWDWLYH -DFN3RWWHU $65&(QHUJ\6HUYLFHV +6( MDFNSRWWHU#H[WHUQDOHQLFRP (QLUHSUHVHQWDWLYH 0LWFK%LOOLQJWRQ $65&(QHUJ\6HUYLFHV &OHUN $N5LJ&OHUNV'R\RQ#HQLFRP 7RRO3XVK 0DWW7XUFRWWH 1DERUV 5LJ0DQDJHU 0DWWKHZ7XUFRWWH#QDERUVFRP 7RRO3XVK -DPHV+HQVRQ-5 1DERUV 5LJ0DQDJHU -DPHV+HQVRQ#QDERUVFRP 6DIHW\5HSUHVHQWDWLYH -RQ&DVWOH 1DERUV +6( -RKQ&DVWOH#QDERUVFRP 6DIHW\5HSUHVHQWDWLYH (ULN%RKOHQ 0XUSK\ 1DERUV +6( (ULN%RKOHQ#QDERUVFRP Last Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 5DLQ 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 0RYLQJULJWR2'61 K6XPPDU\ 0RYLQJULJIURP2'61WR2'61 2SHUDWLRQDW 0RYLQJULJWR2'61 Time Log 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 $ 3 0RYHULJIURP2'61WR:HOO2'61 Daily Contacts 3RVLWLRQ &RQWDFW1DPH &RPSDQ\ 7LWOH (PDLO 2IILFH 0RELOH (QLUHSUHVHQWDWLYH 7LP$VKOH\ $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY 7LPRWK\$VKOH\#H[WHUQDOHQLFRP (QLUHSUHVHQWDWLYH 0DUN$VKOH\ $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY2'6GULOOLQJ#HQLFRP 6DIHW\5HSUHVHQWDWLYH -DFN3RWWHU $65&(QHUJ\6HUYLFHV +6( MDFNSRWWHU#H[WHUQDOHQLFRP (QLUHSUHVHQWDWLYH %RE6PHMNDO $65&(QHUJ\6HUYLFHV &OHUN $N5LJ&OHUNV'R\RQ#HQLFRP 7RRO3XVK 0DWW7XUFRWWH 1DERUV 5LJ0DQDJHU 0DWWKHZ7XUFRWWH#QDERUVFRP 7RRO3XVK 6HWK%HDUG 1DERUV 7RRO3XVKHU 6HWK%HDUG#QRERUVFRP 6DIHW\5HSUHVHQWDWLYH -RQ&DVWOH 1DERUV +6( -RKQ&DVWOH#QDERUVFRP 6DIHW\5HSUHVHQWDWLYH (ULN%RKOHQ 0XUSK\ 1DERUV +6( (ULN%RKOHQ#QDERUVFRP Last Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 5DLQ 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHWRQLSSOHXS%23(7HVW%23(DVSHU6XQGU\&RQWLQXHWRGHFRPSOHWH2'61 K6XPPDU\ 0RYHWKHULJIURP2'61WR2'615LJXSDQGSHUIRUPGHUULFNLQVSHFWLRQ'LVSODFHIUHH]HSURWHFWLRQIURPZHOO3XPSHGEEOVEULQHDW%30ZLWKSVL$WWHPSWWRWHVW&VJ3XPSHGEEOV WRUHDFKSVL)DLOHGWHVW6HW%39DQGQLSSOHGRZQWUHHDQGQLSSOHXS%23( 2SHUDWLRQDW 7HVWLQJ%23( Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU )RJ 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHWR5,+ZLWK57767HVWFDVLQJ322+ZLWK57765,+DQGUHWULHYHEULGJHSOXJ K6XPPDU\ )LQLVKQLSSOHXS%23(7HVW%23(DVSHU6XQGU\0DNHXSODQGLQJMRLQWDQGSXOOKDQJHUWRIORRU/D\GRZQ.LOOVWULQJ6HW:HDUEXVKLQJ0DNHXS5776DQG5,+RQ'3 2SHUDWLRQDW 5LJXSWRFKDQJHRXWGULOOLQJOLQHVSRRO Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 5DLQ 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 0RELOL]H+DOOLEXUWRQ(/LQHWR2'65LJXSPDNH$FRXVWLFDQG&DOLSHUUXQV K6XPPDU\ 5XQLQWKHKROHZLWK5776WR 7HVW$DQQXOXVWRSVLDQGEOHGRIIWRSVL)DLOHGWHVW322+DQGWHVWDW LQWHUYDOV8VH5776DQGGHWHUPLQHOHDNEHWZHHQ DQG 322+,QVSHFWDQG OD\GRZQ57760RELOL]H+DOOLEXUWRQ(/LQHIRU$FRXVWLFDQG&DOLSHUUXQV 2SHUDWLRQDW 0RELOL]LQJ(OLQHFUHZIURP6,'WR2'6 Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 3UHSDUH+DOOLEXUWRQ(OLQHWRROVDQGHTXLSPHQW5,+ZLWK+DOOLEXUWRQ(OLQHDQGSHUIRUP$&;ORJ5HWULHYHSOXJ# K6XPPDU\ :DLWLQJRQZHDWKHUWRPRELOL]HZLUHOLQHFUHZVDQGWRROV&OHDQDQGKRXVHNHHSLQJRQWKHULJ5XQLQWKHKROHZLWK5776DQGSLQSRLQWORFDWLRQRIWKHOHDNEHWZHHQ DQG 5,+ DQGVHW5776DW 7HVW$DQQXOXVWR3VLIRUPLQXWHVFKDUWHGIDLOHGWHVW5HOHDVH5776DQG322+WR IRU+DOOLEXUWRQ$FRXVWLFORJ3UHSDUH+DOOLEXUWRQ(OLQHWRROVDQGHTXLSPHQW 2SHUDWLRQDW 3HUIRUPLQJ$&;ORJ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations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ime Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations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ime Log 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 0 7: :DLWLQJRQZHDWKHUWRPRELOL]H&DVWORJJLQJWRROVWR2'6&OHDQDQGSDLQWULJ :2 0 3 0RELOL]HORJJLQJWRROVIURPWKHERDWWRWKHULJIORRU0DNHXSORJJLQJWRROVDQGSUHSIRU5,+ :2 - 3 5XQLQWKHKROHZLWK(OLQHZLWK&DVW*DPPD5D\DQG&&/ORJJLQJWRROVWR /RJJLQJXSWR #IWPLQ5XQEDFN GRZQWR DQGORJXSWR $OOGHSWKVDUH(OLQHGHSWK :2 5 3 3XOORXWRIWKHKROHZLWK(OLQHDQGULJGRZQ&OHDUULJIORRURIDOO(OLQHWRROVDQGHTXLSPHQW :2 0 3 0RELOL]HEULGJHSOXJUHWULHYDEOHWRROWRWKHULJIORRUDQGPDNHXSDVSHU%DNHU5HS5XQLQWKHKROHZLWKWKHEULGJHSOXJ UHWULHYDEOHWRROWR :2 0 76 7URXEOHVKRRWSUREOHPZLWKGUDZZRUNVVKXWWLQJGRZQ :2 0 3 &RQWLQXHWRUXQLQWKHKROH) WR 38RIMRLQWVRIGULOOSLSHIURPSLSHVKHG08WRSGULYHDQG5,+DQGWDJ5%3 UHWULHYDEOHEULGJHSOXJ# 0'83:7 .'1:7 .6ODFNRII.RQ5%3DQGODWFKXSDQGRSHQE\SDVV :HOORQ9$&3XOOXSWR.WRYHULI\SRVLWLYHODWFKXSWR5%36ODFNRIIZLWK.GRZQZHLJKWRQ5%3DQGDOORZHOHPHQWVWR UHOD[ :2 0 3 0RQLWRUZHOOEHIRUH322+ Daily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXH322+IURP WRVXUIDFH/'6FUDSHUDVVHPEO\/RDGSLSHVKHGZLWK(63FRPSOHWLRQWXELQJDQGSHUIRUPXSFRPLQJZHHNO\%23WHVW K6XPPDU\ 3XOORXWRIWKHKROHIURP WR ZRUNLQJEULGJHSOXJXSWKHKROH+DGSUREOHPVZRUNLQJRXWRIWKHKROHSXOOLQJDQGURWDWLQJWR 3LSHSXOOHGVPRRWKO\IURP WRVXUIDFH7KHSDFNHUKDGXSSHU GLHVPLVVLQJDQGFDSVFUHZ'HUULFNDQG7RS'ULYH'URSV,QVSHFWLRQ086FUDSHUDQG0DJQHWVDVSHU%DNHU5HSDQG5,+ZLWK6FUDSHUDVVHPEO\WR 6FUDSHWLPHVIURP WR 5,+WR 6FUDSHWLPHVIURP WR 'URSGULIWLQWRGULOOSLSHDQG322+ZLWK6FUDSHUDVVHPEO\WR 2SHUDWLRQDW /RDGLQJSLSHVKHGZLWK(63&RPSOHWLRQWXELQJ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHVOLSSLQJRQQHZGULOOLQJOLQHVSRRO5HOHDVH5776DQG322+:HHNO\%23WHVWLQJ K6XPPDU\ &RQWLQXH322+IURP WRVXUIDFH/'VFUDSHUDVVHPEO\/RDGSLSHVKHGZLWK(63FRPSOHWLRQWXELQJ5HSDLULURQURXJK QHFN385776DQG5,+ DQGVHWWHVWWR 3VLJRRGWHVW3-60DQG VOLSRQQHZGULOOLQJOLQHVSRRO 2SHUDWLRQDW &RQWLQXHVOLSSLQJRQQHZVSRRORIGULOOLQJOLQH Time Log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aily Contacts 3RVLWLRQ &RQWDFW1DPH &RPSDQ\ 7LWOH (PDLO 2IILFH 0RELOH (QLUHSUHVHQWDWLYH 7LP$VKOH\ $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY 7LPRWK\$VKOH\#H[WHUQDOHQLFRP (QLUHSUHVHQWDWLYH 0DUN$VKOH\ $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY2'6GULOOLQJ#HQLFRP 6DIHW\5HSUHVHQWDWLYH -DFN3RWWHU $65&(QHUJ\6HUYLFHV +6( MDFNSRWWHU#H[WHUQDOHQLFRP (QLUHSUHVHQWDWLYH 0LWFK%LOOLQJWRQ $65&(QHUJ\6HUYLFHV &OHUN $N5LJ&OHUNV'R\RQ#HQLFRP 7RRO3XVK -DPHV+HQVRQ-5 1DERUV 5LJ0DQDJHU -DPHV+HQVRQ#QDERUVFRP 7RRO3XVK 6HDQ+ROFRPE 1DERUV 7RRO3XVKHU 6DIHW\5HSUHVHQWDWLYH -RKQ)UHQFK 1DERUV +6( -RKQ)UHQFK#QDERUVFRP 6DIHW\5HSUHVHQWDWLYH (ULN%RKOHQ 0XUSK\ 1DERUV +6( (ULN%RKOHQ#QDERUVFRP Last Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 3DUWO\&ORXG\ 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations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ime Log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aily Contacts 3RVLWLRQ &RQWDFW1DPH &RPSDQ\ 7LWOH (PDLO 2IILFH 0RELOH (QLUHSUHVHQWDWLYH 7LP$VKOH\ $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY 7LPRWK\$VKOH\#H[WHUQDOHQLFRP (QLUHSUHVHQWDWLYH 0DUN$VKOH\ $65&(QHUJ\6HUYLFHV 'ULOOLQJ6XSY2'6GULOOLQJ#HQLFRP 6DIHW\5HSUHVHQWDWLYH :HV6WHHQKRYHQ $65&(QHUJ\6HUYLFHV +6( (QLUHSUHVHQWDWLYH 0LWFK%LOOLQJWRQ $65&(QHUJ\6HUYLFHV &OHUN $N5LJ&OHUNV'R\RQ#HQLFRP 7RRO3XVK -DPHV+HQVRQ-5 1DERUV 5LJ0DQDJHU -DPHV+HQVRQ#QDERUVFRP 7RRO3XVK 6HDQ+ROFRPE 1DERUV 7RRO3XVKHU 6DIHW\5HSUHVHQWDWLYH -RKQ)UHQFK 1DERUV +6( -RKQ)UHQFK#QDERUVFRP 6DIHW\5HSUHVHQWDWLYH (ULN%RKOHQ 0XUSK\ 1DERUV +6( (ULN%RKOHQ#QDERUVFRP Last Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 3DUWO\&ORXG\ 7HPSHUDWXUH) :LQG 6#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations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ime Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 5,+ZLWKSDWFKILOOLQJ'3HYHU\VWDQGVZLWKFOHDQILOWHUHG.&OEULQHDVSHUSODQ6SDFHRXWSDWFKDQG58DQG5,+ZLWK+DOOLEXUWRQ(OLQHIRUORJJLQJ K6XPPDU\ 0DNHXS5,+ZLWK5776WR 6HW5776DQGWHVWEHWZHHQ7$03.5# DQG5776WR3VLIRUPLQXWHVFKDUWHGJRRGWHVW5HOHDVH5776DQG322+/'57760RELOL]H&6*SDWFKLQWRSLSH VKHG3-60OLQHGXS56&WRIHHGULJIORRUZLWKFOHDQILOWHUHGPLFURQRUOHVVSSJ.&/EULQHWRILOOGULOOSLSH3LFNXSSDWFKIURPSLSHVKHG 2SHUDWLRQDW 5XQQLQJLQWKHKROHZLWKSDWFKDVVHPEO\ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 6:#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXH6/%SDWFKVHWWLQJSURFHGXUH322+DQGOD\GRZQVHWWLQJWRRO3UHVVXUHWHVWSDWFKWR3VLIRUPLQXWHV&KDUWHG5,+WRUHWULHYH7$03.5# K6XPPDU\ 5,+ZLWKVWDQGRIGULOOSLSHDQGWHVWSDWFKDQGWRROLQWHJULW\ZLWK3VL# LQKROH*RRGWHVW&RQWLQXH5,+ZLWKSDWFK) WR 58DQG5,+ZLWK(OLQHWRFRUUHODWHFDVLQJSDWFK322+(OLQH DQGULJGRZQ3UHSDUHDOO6/%SDWFKVHWWLQJHTXLSPHQWDQGVHWSDWFKDVSHUVHWWLQJSURFHGXUH3UHVVXUHWHVWVWULQJLQWHJULW\WR3VLIRUPLQXWHV2.7RSSDWFKZLOOEHVHWDW 2SHUDWLRQDW 6HWWLQJFDVLQJSDWFK Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXH6/%SDWFKVHWWLQJSURFHGXUH322+DQGOD\GRZQVHWWLQJWRRO3UHVVXUHWHVWSDWFKWR3VLIRUPLQXWHVFKDUWHG5,+WRUHWULHYH7$03.5# K6XPPDU\ 6HW6/%FDVLQJSDWFKDVSHUSURFHGXUHDW 0' 2SHUDWLRQDW 3XOOLQJRXWRIKROHZLWKSDWFKUXQQLQJWRRO Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 1ROLIH&ULWLFDO:RUNRQ2'6GXHWRRIIVLWHPHGLFDOPHGLYDFVLWXDWLRQ3UHSWRUXQ(63FRPSOHWLRQ K6XPPDU\ &RQWLQXH6/%6DOWHOSDWFKVHWWLQJSURFHGXUH322+ZLWKGULOOSLSHDQGOD\GRZQVHWWLQJWRRO3UHVVXUHWHVWSDWFKWR3VLIRUPLQXWHV&KDUWHG5,+WRUHWULHYH7$03.5# 322+VWDQGGULOOSLSH EDFNLQGHUULFNWR 0'%XOOKHDGEEOSSJGRZQ$DQQXDOVDWESP&RQW322+VWDQGEDFNLQGHUULFN/D\GRZQ7DPSDFNHUDQGVHWWLQJWRRO&OHDQDQGRUJDQL]HULJ 2SHUDWLRQDW 3UHSSLQJWRUXQFRPSOHWLRQ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHWHVWLQJ%23(5LJXSDQGUXQ(63FRPSOHWLRQ K6XPPDU\ 3HUIRUPJDVOLIWPDQGUHODQG(63FDEOHGXPP\UXQWKURXJKFDVLQJSDWFKDW 0'GULIWHGZLWKQRSUREOHPV7ULSRXWRIWKHKROHOD\GRZQ%+$5HPRYHZHDUEXVKLQJDQGLQVWDOOWHVWSOXJEHJLQWHVWLQJ%23( 2SHUDWLRQDW 0DNLQJXS(63DVVHPEO\ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWUXQQLQJLQKROHZLWK(63FRPSOHWLRQ K6XPPDU\ &RQWLQXHWHVWLQJ%23VDOOWHVWJRRG5XQ(63FRPSOHWLRQ) WR 0' 2SHUDWLRQDW &RQWLQXHUXQQLQJLQKROHZLWK(63FRPSOHWLRQDVVHPEO\ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &OHDQDQGRUJDQL]HULJ5XQ(63FRPSOHWLRQ K6XPPDU\ &RQWLQXHUXQQLQJ(63FRPSOHWLRQ) WR 0'WURXEOHWU\LQJWRSDVVWKURXJKFDVLQJSDWFKZLWK(63DVVHPEO\SHUIRUP(63FDEOHWHVWIDLOHG322+DQGOD\GRZQWXELQJDQG(63 DVVHPEO\&OHDQDQGRUJDQL]HULJ 2SHUDWLRQDW 3UHSDUDWLRQVWRUXQ(63FRPSOHWLRQ Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHUXQQLQJLQKROHZLWK(63FRPSOHWLRQ K6XPPDU\ &OHDQDQGRUJDQL]HULJ5XQLQKROHZLWK(63FRPSOHWLRQWR 0' 2SHUDWLRQDW 5XQQLQJLQKROHZLWK(63FRPSOHWLRQ Time Log 6WDUW 7LPH (QG 7LPH 'XUKU &XP'XU KU3KDVH 2SU $FW 3ODQ 2SHU'HVFU :2 . 3 6HUYLFHULJJUHDVHEORFNVDQGFURZQ :2 . 3 3XOO(63FDEOHEDFNRYHUVKHDYHWRULJIORRUPDNH(63FDEOHVSOLFHWRPRWRUOHDG3UHSWXELQJDQGMHZHOU\LQSLSHVKHG&KLS DQGSDLQWFHOODUDQGSXPSURRPDUHD6HUYLFHLURQURXJKQHFN$GMXVWWRUTWXEHIRUWRSGULYHDOLPHQWWRWXELQJVWXPS)LOOKROH :EEOHYHU\KDOIKRXURI33*.&/EULQH :2 . 3 &OHDQDQG2UJDQL]H&KLSDQGSDLQWSXPSURRPFHOODUDUHD)LOOKROH:EEOHYHU\KDOIKRXU33*.&/EULQH :2 . 3 3-60&RQQHFWPRWRUOHDGWR(63SXPSILOOFKHPOLQHDQGWHVWSVLIRUPLQJRRGWHVW)LOOKROH:EEOHYHU\KDOI KRXURISSJ.&/EULQH :2 . 3 7ULSLQWKHKROH) WR 0':(63FRPSOHWLRQSXZ NVRZ NWHVWFDEOHHYHU\IW)LOOKROH: EEOHYHU\KDOIKRXURISSJ.&/EULQH :2 . 3 7ULSLQWKHKROH) WR 0':(63FRPSOHWLRQSXZ NVRZ N7HVWFDEOHHYHU\IW)LOOKROH: EEOHYHU\KDOIKRXURISSJ.&/EULQH Daily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHUXQQLQJLQKROHZLWK(63FRPSOHWLRQODQGKDQJHU6HWDQGWHVWSDFNHU5LJXS+DOOLEXUWRQVOLFNOLQH K6XPPDU\ 5XQ(63FRPSOHWLRQDVSHUSODQI WR 0' 2SHUDWLRQDW 0DNLQJSHQHWUDWRUVSOLFH Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG (1(#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 1LSSOHGRZQ%23¶VWHVW(63FDEOHQLSSOHXSWUHH3DVVSRUWWHVWWUHH K6XPPDU\ &RQWLQXHUXQQLQJ(63FRPSOHWLRQ/DQGKDQJHU58+DOOLEXUWRQVOLFNOLQH5,+DQGVHWEDOODQGURG322+ZLWKVOLFNOLQH6HWDQGWHVWSDFNHUJRRGWHVW%OHHGRIISUHVVXUHDVSHUSURFHGXUH 2SHUDWLRQDW 1LSSOHXS%23V)DLOHG(63FDEOHWHVW Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG :#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW &RQWLQXHZLWK+DOOLEXUWRQVOLFNOLQHRSHUDWLRQVULJGRZQ+DOOLEXUWRQVOLFNOLQH3HUIRUPSDVVSRUWWHVW,QVWDOO%39DQGSUHSULJWRPRYH2'61 K6XPPDU\ 5LJGRZQ+DOOLEXUWRQVOLFNOLQH,QVWDOO%39QLSSOHGRZQ%23VWDFN7HVW(63FDEOHWHVWIDLOHG1LSSOHXS%23V&KDQJHRISODQV1LSSOHGRZQ%23V1LSSOHXSWUHHDQGVKHOOWHVWJRRGWHVW&RQGXFWVOLFNOLQH RSHUDWLRQV 2SHUDWLRQDW 6OLFNOLQHRSHUDWLRQV Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / :HOO1DPH2'61 :HOOERUH1DPH2ULJLQDO+ROH :HOO&RGH -RE:25.29(5 :&(,/(9(/ 'DLO\5HSRUW 'DWH 5HSRUW 3DJHRI Well Header 3HUPLW&RQFHVVLRQ1 $'/ 2SHUDWRU (1,3(752/(80 6XEVLGLDU\ (1,3HWUROHXP&R,QF ,QLWLDO/DKHH&RGH 5RWDU\7DEOH(OHYDWLRQIW :DWHU'HSWKIW )LUVW)ODQJHIW 5.%%DVH)ODQJHIW 5.%7XELQJ6SRROIW Rig Information 5LJ1DPH 1$%256$& &RQWUDFWRU 1$%256$/$6.$ 5LJ7\SH /$1'5,* 5LJ1XP Daily Information :HDWKHU 2YHUFDVW 7HPSHUDWXUH) :LQG 1#03+ 'D\V/7,GD\V 'D\V5,GD\V 32% Daily Summary Operations K)RUHFDVW 5LJPRYHWR2'61 K6XPPDU\ +DOOLEXUWRQVOLFNOLQH2SV5LJGRZQ+DOOLEXUWRQ3DVVSRUWWHVWJRRGWHVWV3UHSIRUULJPRYHWR2'61 5LJUHOHDVHGDW 2SHUDWLRQDW 5LJPRYHWR2'61 Time Log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aily Contacts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ast Casing Seat &DV7\SH 2'LQ ,'LQ *UDGH 7RSIW.% %RWWRPIW.% 79'%RWIW.% /DQGLQJ'DWH /,1(5 / 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW)ULGD\2FWREHU30 7R+HQVRQ-DPHV &F5HJJ-DPHV%2*& 6XEMHFW5($&%23(7(675(3257 $WWDFKPHQWV1DERUV$&[OV[ /ŵĂĚĞĂĐŽƵƉůĞŵŝŶŽƌĐŽƌƌĞĐƚŝŽŶƐ͕ƌĞŵŽǀŝŶŐ͞ƐĞĐ͟ĨƌŽŵƚŚĞŶƵŵĞƌŝĐŽŶůǇĨŝĞůĚƐĂŶĚƌĞŵŽǀŝŶŐŚŽƵƌƐĨƌŽŵƚŚĞϱ͘ϱƚĞƐƚ ƚŝŵĞ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗,ĞŶƐŽŶ͕:ĂŵĞƐф:ĂŵĞƐ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂǇ͕^ĞƉƚĞŵďĞƌϮϱ͕ϮϬϮϮϰ͗ϮϬWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗'ƵĞĐŽŚĂĚфĐŚĂĚ͘ŐƵĞĐŽΛĞǆƚĞƌŶĂů͘ĞŶŝ͘ĐŽŵх͖DďǆK^ƌŝůůŝŶŐфK^ƌŝůůŝŶŐΛĞŶŝ͘ĐŽŵх͖dƵƌĐŽƚƚĞ͕DĂƚƚŚĞǁ фDĂƚƚŚĞǁ͘dƵƌĐŽƚƚĞΛŶĂďŽƌƐ͘ĐŽŵх͖ĞĂƌĚ͕^ĞƚŚф^ĞƚŚ͘ĞĂƌĚΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ϭϵKWd^dZWKZdϵͲϮϱͲϮϮ :ĂŵĞƐ,ĞŶƐŽŶ:ƌ͘ ϭϵZŝŐDĂŶĂŐĞƌ EKZ^>^<Z/>>/E'͕/E͘ ŝƌĞĐƚϵϬϳ͘ϲϳϬ͘ϲϲϯϬ/DŽďŝůĞϵϬϳ͘ϯϵϴ͘ϯϬϴϬ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 2RRJXUXN2'61 37' ũĂŵĞƐ͘ŚĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ 1$%256(0$,/127,&(7KLVWUDQVPLVVLRQPD\EHVWULFWO\SURSULHWDU\DQGFRQILGHQWLDO,I\RXDUHQRWWKHLQWHQGHG UHFLSLHQWUHDGLQJGLVFORVLQJFRS\LQJGLVWULEXWLQJRUXVLQJWKHFRQWHQWVRIWKLVWUDQVPLVVLRQLVSURKLELWHG,I\RXKDYH UHFHLYHGWKLVLQHUURUSOHDVHUHSO\DQGQRWLI\WKHVHQGHURQO\DQGGHOHWHWKHPHVVDJH8QDXWKRUL]HGLQWHUFHSWLRQRIWKLV HPDLOLVDYLRODWLRQRIIHGHUDOFULPLQDOODZ7KLVFRPPXQLFDWLRQGRHVQRWUHIOHFWDQLQWHQWLRQE\WKHVHQGHURUWKHVHQGHU V SULQFLSDOWRFRQGXFWDWUDQVDFWLRQRUPDNHDQ\DJUHHPHQWE\HOHFWURQLFPHDQV1RWKLQJFRQWDLQHGLQWKLVPHVVDJHRULQ DQ\DWWDFKPHQWVKDOOVDWLVI\WKHUHTXLUHPHQWVIRUDZULWLQJDQGQRWKLQJFRQWDLQHGKHUHLQVKDOOFRQVWLWXWHDFRQWUDFWRU HOHFWURQLFVLJQDWXUHXQGHUWKH(OHFWURQLF6LJQDWXUHVLQ*OREDODQG1DWLRQDO&RPPHUFH$FWDQ\YHUVLRQRIWKH8QLIRUP (OHFWURQLF7UDQVDFWLRQV$FWRUDQ\RWKHUVWDWXWHJRYHUQLQJHOHFWURQLFWUDQVDFWLRQV STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:19AC DATE: 9/25/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2080030 Sundry #322-049 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1965 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 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2 7/8" X 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1700 P Check Valve 0NA200 psi Attained (sec)12 P BOP Misc 0NAFull Pressure Attained (sec)60 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2150 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 28 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 8 P Inside Reel valves 0NA #3 Rams 8 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 HCR Choke 4 P Repair or replacement of equipment will be made within days. HCR Kill 4 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9-24-22/17:48 Waived By Test Start Date/Time:9/24/2022 22:00 (date) (time)Witness Test Finish Date/Time:9/25/2022 3:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nabors Tested with 2 7/8".test joint. James Henson/Seth Beard ENI Chad Gueco/Craig Smith Oooguruk ODSN-31 Test Pressure (psi): james.henson@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022) 2022-0925_BOP_Nabors19AC_Oooguruk_ODSN-31 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW)ULGD\2FWREHU30 7R+HQVRQ-DPHV &F5HJJ-DPHV%2*& 6XEMHFW5($&%23(7(675(3257 $WWDFKPHQWV1DERUV$&5HYLVHG[OV[ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚŵŽǀŝŶŐƚŚĞ͞&W͟ƚŽϭKWDŝƐĐ͘&ůĂŶŐĞ͞&W͟ĂŶĚĐŚĂŶŐŝŶŐƚŚĞEƵŵďĞƌŽĨ&ĂŝůƵƌĞƐƚŽϭďĂƐĞĚ ŽŶƚŚĞϭ͞&W͘͟WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗,ĞŶƐŽŶ͕:ĂŵĞƐф:ĂŵĞƐ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗dƵĞƐĚĂǇ͕^ĞƉƚĞŵďĞƌϮϬ͕ϮϬϮϮϰ͗ϯϲWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖KK' WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх Đ͗dƵƌĐŽƚƚĞ͕DĂƚƚŚĞǁфDĂƚƚŚĞǁ͘dƵƌĐŽƚƚĞΛŶĂďŽƌƐ͘ĐŽŵх͖DďǆK^ƌŝůůŝŶŐфK^ƌŝůůŝŶŐΛĞŶŝ͘ĐŽŵх͖ƐŚůĞǇdŝŵŽƚŚǇ фƚŝŵŽƚŚǇ͘ĂƐŚůĞǇΛĞǆƚĞƌŶĂů͘ĞŶŝ͘ĐŽŵх͖ƐŚůĞǇDĂƌŬфŵĂƌŬ͘ĂƐŚůĞǇΛĞǆƚĞƌŶĂů͘ĞŶŝ͘ĐŽŵх͖,ŽůĐŽŵď͕^ĞĂŶ ф^ĞĂŶ͘,ŽůĐŽŵďΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ϭϵKWd^dZWKZdϵͲϭϴͲϮϮ :ĂŵĞƐ,ĞŶƐŽŶ:ƌ͘ ϭϵZŝŐDĂŶĂŐĞƌ EKZ^>^<Z/>>/E'͕/E͘ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 2RRJXUXN2'61 37' ƌĞǀŝƐĞĚƌĞƉŽƌƚ ŝƌĞĐƚϵϬϳ͘ϲϳϬ͘ϲϲϯϬ/DŽďŝůĞϵϬϳ͘ϯϵϴ͘ϯϬϴϬ ũĂŵĞƐ͘ŚĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:19AC DATE: 9/18/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2080030 Sundry #322-049 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1965 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 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2 7/8" X 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1725 P Check Valve 0NA200 psi Attained (sec)12 P BOP Misc 1 Flange FP Full Pressure Attained (sec)60 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2300 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 27 P #1 Rams 8 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 8 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:7.0 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9-16-22/08:18 Waived By Test Start Date/Time:9/18/2022 16:00 (date) (time)Witness Test Finish Date/Time:9/18/2022 23:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors Tested with 2 7/8" & 4" test joint. During test #11 2 7/8" jt. Lower pipe rams K1 flange to DSA leaked at 3500 psi test, bled off pressure & tighten connection - retest 3500 psi. good test James Henson/Sean Holcomb ENI Tim Ashley/Mark Ashley Oooguruk ODSN-31 Test Pressure (psi): james.henson@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022) 2022-0918_BOP_Nabors19AC_Oooguruk_ODSN-31 999 999 9 9 9 9 9 9 9 9 9 -5HJJ FP Lower pipe rams K1 flange to DSA leaked 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW0RQGD\6HSWHPEHU$0 7R7XUFRWWH0DWWKHZ &F5HJJ-DPHV%2*& 6XEMHFW5((%237(675(3257 $WWDFKPHQWV1DERUV$&[OV[ DĂƚƚ͕ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚŵĂŬŝŶŐĂŵŝŶŽƌƌĞǀŝƐŝŽŶ͕ƌĞŵŽǀŝŶŐ͞ƐĞĐ͟ĨƌŽŵƚŚĞƚŝŵĞĨŝĞůĚƐ;ƐŝŶĐĞƚŚĞǇĂƌĞŶƵŵĞƌŝĐŽŶůǇͿ͘ WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗dƵƌĐŽƚƚĞ͕DĂƚƚŚĞǁфDĂƚƚŚĞǁ͘dƵƌĐŽƚƚĞΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂǇ͕^ĞƉƚĞŵďĞƌϭϭ͕ϮϬϮϮϰ͗ϰϱWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖KK' WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖DďǆK^ƌŝůůŝŶŐфK^ƌŝůůŝŶŐΛĞŶŝ͘ĐŽŵх Đ͗,ĞŶƐŽŶ͕:ĂŵĞƐф:ĂŵĞƐ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх͖ĞĂƌĚ͕^ĞƚŚф^ĞƚŚ͘ĞĂƌĚΛŶĂďŽƌƐ͘ĐŽŵх͖,ŽůĐŽŵď͕^ĞĂŶ ф^ĞĂŶ͘,ŽůĐŽŵďΛŶĂďŽƌƐ͘ĐŽŵх͖,ĞŶƐŽŶ͕:ĂŵĞƐф:ŝŵ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗ϭϵKWd^dZWKZdϵͲϭϭͲϮϮ ,ĞƌĞŝƐŽƵƌϵͲϭϭͲϮϬϮϮƚĞƐƚ͘ dŚĂŶŬǇŽƵ 0DWW7XUFRWWH 1DERUV(5LJ0DQDJHU &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 2RRJXUXN2'61 37' 1$%256$/$6.$'5,//,1*,1& 3+21(,&HOO PDWWKHZWXUFRWWH#QDERUVFRP,ZZZQDERUVFRP ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ 1$%256(0$,/127,&(7KLVWUDQVPLVVLRQPD\EHVWULFWO\SURSULHWDU\DQGFRQILGHQWLDO,I\RXDUHQRWWKHLQWHQGHG UHFLSLHQWUHDGLQJGLVFORVLQJFRS\LQJGLVWULEXWLQJRUXVLQJWKHFRQWHQWVRIWKLVWUDQVPLVVLRQLVSURKLELWHG,I\RXKDYH UHFHLYHGWKLVLQHUURUSOHDVHUHSO\DQGQRWLI\WKHVHQGHURQO\DQGGHOHWHWKHPHVVDJH8QDXWKRUL]HGLQWHUFHSWLRQRIWKLV HPDLOLVDYLRODWLRQRIIHGHUDOFULPLQDOODZ7KLVFRPPXQLFDWLRQGRHVQRWUHIOHFWDQLQWHQWLRQE\WKHVHQGHURUWKHVHQGHU V SULQFLSDOWRFRQGXFWDWUDQVDFWLRQRUPDNHDQ\DJUHHPHQWE\HOHFWURQLFPHDQV1RWKLQJFRQWDLQHGLQWKLVPHVVDJHRULQ DQ\DWWDFKPHQWVKDOOVDWLVI\WKHUHTXLUHPHQWVIRUDZULWLQJDQGQRWKLQJFRQWDLQHGKHUHLQVKDOOFRQVWLWXWHDFRQWUDFWRU HOHFWURQLFVLJQDWXUHXQGHUWKH(OHFWURQLF6LJQDWXUHVLQ*OREDODQG1DWLRQDO&RPPHUFH$FWDQ\YHUVLRQRIWKH8QLIRUP (OHFWURQLF7UDQVDFWLRQV$FWRUDQ\RWKHUVWDWXWHJRYHUQLQJHOHFWURQLFWUDQVDFWLRQV STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:19AC DATE: 9/11/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2080030 Sundry #322-049 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1965 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 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2 7/8" X 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1750 P Check Valve 0NA200 psi Attained (sec)12 P BOP Misc 0NAFull Pressure Attained (sec)63 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2225 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 27 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.5 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 9-9-2022/05:54 Waived By Test Start Date/Time:9/11/2022 7:30 (date) (time)Witness Test Finish Date/Time:9/11/2022 13:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors Tested with 2 7/8" & 4" test joint. Matt Turcotte/Sean Holcomb ENI Tim Ashley/Mark Ashley Oooguruk ODSN-31 Test Pressure (psi): matthew.turcotte@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022) 2022-0911_BOP_Nabors19AC_Oooguruk_ODSN-31 9 9 9 9999 9 9 9 9 9 9 9 -5HJJ 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW7XHVGD\$XJXVW$0 7R7XUFRWWH0DWWKHZ &F5HJJ-DPHV%2*& 6XEMHFW5(1DERUV$& $WWDFKPHQWV1DERUV$&5HYLVHG[OV[ DĂƚƚ͕ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĐŚĂŶŐŝŶŐƚŚĞŶƵŵďĞƌŽĨĨĂŝůƵƌĞƐƚŽϰ͕ĐŚĂŶŐŝŶŐĂůůDŝƐĐƚĞƐƚƌĞƐƵůƚĨŝĞůĚƐƚŽ͞E͕͟ĂŶĚŵŽǀĞĚ ϮϮ͘ϱƚŽƚŚĞdĞƐƚdŝŵĞ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗dƵƌĐŽƚƚĞ͕DĂƚƚŚĞǁфDĂƚƚŚĞǁ͘dƵƌĐŽƚƚĞΛŶĂďŽƌƐ͘ĐŽŵх ^ĞŶƚ͗DŽŶĚĂǇ͕ƵŐƵƐƚϭϱ͕ϮϬϮϮϳ͗ϭϳWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖KK' WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖DďǆK^ƌŝůůŝŶŐфK^ƌŝůůŝŶŐΛĞŶŝ͘ĐŽŵх Đ͗,ĞŶƐŽŶ͕:ĂŵĞƐф:ĂŵĞƐ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх͖,ĞŶƐŽŶ͕:ĂŵĞƐф:ŝŵ͘,ĞŶƐŽŶΛŶĂďŽƌƐ͘ĐŽŵх͖,ĂŵĂƌ͕ZŽƐƐ фZŽƐƐ͘,ĂŵĂƌΛŶĂďŽƌƐ͘ĐŽŵх ^ƵďũĞĐƚ͗EĂďŽƌƐϭϵϴͲϭϯͲϮϬϮϮ ŚĞƌĞŝƐŽƵƌǁĞĞŬůǇKWdĞƐƚŽŶK^EͲϯϭ dŚĂŶŬǇŽƵ 0DWW7XUFRWWH 1DERUV(5LJ0DQDJHU &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 2RRJXUXN2'61 37' 1$%256$/$6.$'5,//,1*,1& 3+21(,&HOO PDWWKHZWXUFRWWH#QDERUVFRP,ZZZQDERUVFRP K ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:19AC DATE: 8/13/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2080030 Sundry #322-049 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1965 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1FP Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" X 5"P Flow Indicator PP #2 Rams 1 Blind/Shear P Meth Gas Detector PP #3 Rams 1 2 7/8" X 5"P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"FP Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1550 P Check Valve 0NA200 psi Attained (sec)14 P BOP Misc 0NAFull Pressure Attained (sec)70 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2233 P No. Valves 15 FP ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 23 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 7 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:4 Test Time:22.5 HCR Choke 3 P Repair or replacement of equipment will be made within days. HCR Kill 3 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 8-08-2022/06:13 Waived By Test Start Date/Time:8/12/2022 9:00 (date) (time)Witness Test Finish Date/Time:8/13/2022 7:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Nabors Tested with 2 7/8" & 4" test joints. Upper IBOP failed, chages it out tested good. Choke manifold valves # 1 & 5 failed rebuilt tested good. Choke valve #2. test plug rubbers leaking. Replaced rubbers good test. Matt Turcotte/Ross Hamar ENI Justin Hays/Crieg Smith Oooguruk ODSN-31 Test Pressure (psi): matthew.turcotte@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022) 2022-0813_BOP_Nabors19AC_Oooguruk_ODSN-31 9 9 9 999 9 9 9 9 9 9 9 9 9 9 9 FP FP FP Upper IBOP failed, Choke manifold valves # 1 & 5 failedj Choke valve #2. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Vaughan Alex Cc:Chaudhry Amjad; Regg, James B (OGC) Subject:RE: Eni sundry modification request for PTD: 208-003 ,212-030, 209-079, 208-040 Date:Wednesday, August 17, 2022 3:28:00 PM Alex, Approval is granted for the reduced AOGCC witnessed pressure tests as outlined in your email below, for all 4 wells listed. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Vaughan Alex <Alex.Vaughan@external.eni.com> Sent: Wednesday, August 17, 2022 2:20 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Chaudhry Amjad <Amjad.Chaudhry@eni.com> Subject: Eni sundry modification request for PTD: 208-003 ,212-030, 209-079, 208-040 Bryan, As discussed last week Eni is requesting to reduce the production casing string pressure test after setting the ESP packer from 3500psi to 2500psi. This request is intended to reduce cycle load on the ESP cable penetrator through our tubing hangers. This will have no change to the approved sundry’s obligating Eni to pressure test the production casing string with a casing test packer below to top of cement which occurs in a preceding step of each program. This will affect the following approved sundry’s: ODSN-31 PTD: 208-003 Sundry #: 322-049 ODSN-25 PTD: 212-030 Sundry #: 322-217 ODST-45A PTD: 209-079 Sundry #: 322-250 ODST-39 PTD: 208-040 Sundry #: 322-229 Example affected text from ODST-39: Alex Vaughan Sr. Drilling & Completions Compliance Engineer Eni US Operating Co. Inc. 3700 Centerpoint Dr. Suite 500 Anchorage, AK, 99503 (907) 748-5478 M ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer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y Samantha Carlisle at 8:03 am, Feb 02, 2022 'LJLWDOO\VLJQHGE\6WHIDQR3LHUIHOLFL '1&1 6WHIDQR3LHUIHOLFL& $' 'DWH 6WHIDQR 3LHUIHOLF L '/% ; '/% %-0 3UHVVXUH WHVW SURGXFWLRQ FDVLQJ WR SVL DIWHU SXOOLQJ WXELQJ ZLWK WHVW SDFNHU VHW LQ FVJ DV FORVH DV SUDFWLFDO WR SURGXFWLRQ OLQHU WRS %23 WHVW WR SVL DQQXODU WR SVL ; '65GWV -/& 5%'06 -6% &HQWHUSRLQW'ULYH6XLWH $QFKRUDJH$ODVND 6WHIDQR3LHUIHOLFL 3KRQH (PDLO6WHIDQRSHUIHOLFL#HQLFRP )HEUXDU\ $ODVND2LODQG*DV&RQVHUYDWLRQ&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$ODVND 5( $SSOLFDWLRQIRU6XQGU\$SSURYDOIRU2'615LJ:RUNRYHU 'HDU&RPPLVVLRQHUV (1,862SHUDWLQJ&R,QFKHUHE\DSSOLHVIRUD:RUNRYHU6XQGU\IRUZHOO2'61 2'61GULOOHGDQGFRPSOHWHGRQ2'6LQ-XQHDIWHUIUDFWXUHVWLPXODWLRQGRQHZHOO ZDVSXWRQSURGXFWLRQLQ-XO\:HOOZDVFRQWLQXHGRQSURGXFWLRQXQWLO ZKHQ(63IDLOHGRQ5LJZRUNRYHUZDVSHUIRUPHGIRUWKH(63FKDQJHRXWZHOO ZDV FRQWLQXHV RQ SURGXFWLRQ XQWLO -XQH ZKHQ (63 IDLOHG $ULJ ZRUNRYHU ZDV SHUIRUPHG IRU WKH (63 FKDQJHRXW 2Q 5:2 ZDV SHUIRUPHGIRU WKH (63 FKDQJHRXW SUHHPSWLYH ZLWK FKHPLFDO LQMHFWLRQ OLQH 2Q (63 IDLOHG 2Q WXELQJ ZDV SXQFKHG WXELQJ DERYH $'9 ¶0' WR ¶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±3URSRVDO6XPPDU\DQG:HOOERUH6FKHPDWLF 37' &XUUHQW6WDWXV :HOO2'61LVFXUUHQWO\VKXWGRZQ 6FRSHRI:RUN 6FRSHRIWKLVZRUNRYHULVWRSXOORXWIDLOHG(63FRPSOHWLRQDQGUHFRPSOHWHLWZLWKQHZ (63FRPSOHWLRQ *HQHUDO:HOO,QIR 5HVHUYRLU3UHVVXUH79' 7KHHVWLPDWHGUHVHUYRLUSUHVVXUHLQPLG0DUFKIRU 2'61 1XLTVXW LV SVL DW ¶ 79'VV FKDUW EHORZ \LHOGLQJ D PD[LPXP DQWLFLSDWHG VXUIDFHSUHVVXUH0$63RISVL K^EͲϯϭƐƚŝŵĂƚĞĚEƵŝƋƐƵƚWƌĞƐƐƵƌĞDĂƌĐŚϮϬϮϮ ĞƉƚŚϲ͕ϯϱϬds͕ƐƐ WƌĞƐƐƵƌĞ;ĞƐƚŝŵĂƚĞĚͿϮ͕ϲϬϬƉƐŝ 'ƌĂĚŝĞŶƚϬ͘ϰϭƉƐŝͬĨƚ WW'ϳ͘ϵƉƉŐĞ D^W;Ϭ͘ϭƉƐŝͬĨƚŐƌĂĚŝĞŶƚƚŽƐƵƌĨĂĐĞͿ͘ϭ͕ϵϲϱƉƐŝ :LUHOLQH WRROVWULQJ VWXFN LQ 6669 6HH XSGDWHG GLDJUDP EMP :HOOKHDGW\SHSUHVVXUHUDWLQJ 9DXOW3&0%SVL %23FRQILJXUDWLRQ $QQXODU3LSH%OLQG3LSH :HOOW\SH3URGXFHU 7,)/0,7,$0,72$ ,QWHUPHGLDWH ´ FDVLQJ ZDV WHVWHG WR SVL ZKHQZDOOZDVRULJLQDOO\GULOOHGDQGFRPSOHWHGLQ -XO\ (VWLPDWHGVWDUWGDWH )HEUXDU\ WK 'ULOOLQJ5LJ1DERUV 6U'ULOOLQJ(QJLQHHU $PMDG&KDXGKU\ $PMDGFKDXGKU\#HQLFRP :RUN :HOO2SHUDWLRQV3URMHFW0DQDJHU 6WHIDQR3LHUIHOLFL 6WHIDQRSLHUIHOLFL#HQLFRP :RUN :HOO ZDV GULOOHG DQG FRPSOHWHG LQ EMP 3URFHGXUH6XPPDU\ x0,581DERUV$& x,QVWDOOWHVWGDUW x1'7UHH18%23( x7HVW%23(SVLORZSVLKLJK$QQXODUWRSVL o7HVWMRLQWV´´´ x/ŶƐƚĂůůϯͲϭͬϮ͟ůĂŶĚŝŶŐũŽŝŶƚŝŶƚŚĞƚƵďŝŶŐŚĂŶŐĞƌǁͬ&K^sŵĂĚĞƵƉ͘ oƵůůŚĞĂĚ ϭϬ ďďů ǀŝƐ Ɖŝůů ĚŽǁŶ ƚƵďŝŶŐ ĨŽůůŽǁĞĚ ďǇ ϭϮϱй ƚƵďŝŶŐ ǀŽ ůƵŵĞ ŽĨ ĨŝůƚĞƌĞĚ ƐĞĂǁĂƚĞƌ oK>^ĂŶĚƉƵůůƚŚĞƚƵďŝŶŐŚĂŶŐĞƌĂŶĚƚŚĞƉĂĐŬĞƌĨƌĞĞ͘ WĂĐŬĞƌǁŝůůƐŚĞĂƌƌĞůĞĂƐĞǁŝƚŚƐƚƌĂŝŐŚƚƉƵůů oƵůůŚĞĂĚĂϮϬďďůƐǀŝƐƉŝůůĨŽůůŽǁĞĚďǇϭϮϱйĂŶŶƵůĂƌǀŽůƵŵĞŽĨĨŝůƚĞƌĞĚƐĞĂǁĂƚĞƌ͘ x3XOOWKHò´[´(63FRPSOHWLRQVWULQJRXWRIWKHKROH o+DYH(FKRPHWHURQULJWRVKRRWIOXLGOHYHOV o5HVSRRO(63FDEOHó´7U669FDSWXEHó´399FDSWXEH ´&KHP FDSWXEH x5,+ZLWK´FDVLQJFRQGLWLRQLQJDVVHPEO\WR¶0' x&RQWLQJHQF\5,+ZLWK´WHVWSDFNHUDVVHPEO\WR¶0' x38 5,+´[´(63FRPSOHWLRQ o1RWH5+&LQVWDOOHGLQ;QLSSOH o1RWHSVL'&.LQVWDOOHGLQ*/0 x/DQGKDQJHUDQGWHVWERWKWKHXSSHUDQGORZHUWXELQJKDQJHUERG\VHDOVWR SVL xZĞůĞĂƐĞƉĂĐŬĞƌƐĞƚƚŝŶŐďĂůůĂŶĚƌŽĚ o/ĨĨůƵŝĚŝƐǁŝƚŚŝŶϱϬϬ͛DǀŝĂĞĐŽŵĞƚĞƌĚƌŽƉďĂůůĂŶĚƌŽĚĨƌŽŵƐƵƌĨĂĐĞ o/ĨĨůƵŝĚŝƐŐƌĞĂƚĞƌƚŚĂŶϱϬϬ͛DĨƌŽŵƐƵƌĨĂĐĞƌƵŶŽŶƐůŝĐŬůŝŶĞ x&ŝůůƚƵďŝŶŐǁŝƚŚƐĞĂǁĂƚĞƌĂŶĚƐĞƚ^WƉĂĐŬĞƌ xWĞƌĨŽƌŵƚƵďŝŶŐĂŶĚĂŶŶƵůƵƐƉƌĞƐƐƵƌĞƚĞƐƚ oZĞĚƵĐĞƚƵďŝŶŐƉƌĞƐƐƵƌĞĨƌŽŵ^WƉĂĐŬĞƌƐĞƚƚŝŶŐƉƌĞƐƐƵƌĞƚŽϮϱϬϬƉƐŝ oWƌĞƐƐƵƌĞƚĞƐƚϮͲϳͬϴ͟ǆϳ͟ĂŶŶƵůƵƐƚŽϯϱϬϬƉƐŝ oůĞĞĚƚƵďŝŶŐƉƌĞƐƐƵƌĞĚŽǁŶƚŽǌĞƌŽƚŽƐŚĞĂƌ<ͲϮŝŶ'>Dηϯ ZĞĚƵĐĞƉƌĞƐƐƵƌĞƉĞƌĞŶƚƌŝůŝĨƚŶŶƵůƵƐWƌĞƐƐƵƌĞŽŶƚƌŽůƐĐŚĞĚƵůĞƚŽŵŝƚŝŐĂƚĞ ƌŝƐŬŽĨ^WĐĂďůĞĚĂŵĂŐĞ x&ORVH75669 x&RQILUP399LVFORVHG x6HW7:& x1'%23(187UHH x3HUIRUP3DVVSRUWWHVW x3XOO7:& x&LUFXODWH/97IUHH]HSURWHFWLRQWR(63SDFNHUGRZQDQQXOXVWRWXELQJ x52021DERUV$& 3RVW5LJ6OLFNOLQH x58VOLFNOLQHXQLW x+ROGRSHQ75669 x3XOO6KHDURXW9DOYHIURPXSSHU*/0*/0DQGLQVWDOO'XPP\9DOYH 6HW WHVW SDFNHU DV FORVH DV SUDFWLFDO WR WKH OLQHU WRS 3UHVVXUH WHVW FDVLQJ WR SVL EMP 7KH ILUVW EXOOHWV LQ WKLV SURFHGXUH KDYH EHHQ VXSHUVHGHG 6HH DWWDFKHG HPDLO IURP $OH[ 9DXJKQ EMP x3XOO%DOODQG5RG x3XOO5+& x)XQFWLRQWHVW75669 x5'VOLFNOLQHXQLW x6WDUWXS(63 &XUUHQWZHOOVFKHPDWLF 6XSHUVHGHG 3URSRVHG&RPSOHWLRQZLOOEHWKHVDPHDVFXUUHQWFRPSOHWLRQRQO\IHHWGLIIHUHQFHLQ FRPSOHWLRQMHZHOU\ZLOOEHH[SHFWHG dŽƉ;DͿ dŽƉ;dsͿ ϳ͕ϴϬϬ ϲ͕Ϯϳϰ ϴ͕ϬϬϲ ϲ͕ϯϬϬ ϴ͕Ϯϭϰ ϲ͕ϯϬϭ ϴ͕ϰϮϭ ϲ͕Ϯϵϳ ϴ͕ϲϮϳ ϲ͕Ϯϵϱ ϴ͕ϴϯϱ ϲ͕Ϯϵϯ ϵ͕Ϭϰϭ ϲ͕Ϯϴϴ ϵ͕ϮϱϬ ϲ͕Ϯϳϳ ϵ͕ϰϲϬ ϲ͕Ϯϳϯ ϵ͕ϲϲϵ ϲ͕Ϯϲϲ ϵ͕ϴϴϬ ϲ͕ϮϲϬ ϭϬ͕ϬϵϬ ϲ͕Ϯϰϭ ϭϬ͕ϯϬϭ ϲ͕ϮϮϯ ϭϬ͕ϱϭϮ ϲ͕ϮϬϲ ϭϬ͕ϳϭϲ ϲ͕ϭϵϳ ϭϬ͕ϵϮϱ ϲ͕ϭϵϳ ϭϭ͕ϭϮϰ ϲ͕ϮϬϳ ϭϭ͕ϯϮϱ ϲ͕ϮϮϭ ϭϭ͕ϱϯϬ ϲ͕ϮϯϬ ϭϭ͕ϳϯϳ ϲ͕ϮϯϮ ϭϭ͕ϵϯϲ ϲ͕Ϯϯϲ ϭϮ͕ϭϰϬ ϲ͕Ϯϯϱ ϭϮ͕ϯϱϬ ϲ͕ϮϮϲ ϭϮ͕ϱϭϯ ϲ͕ϮϭϮ ϭϮ͕ϵϲϰ ϲ͕ϭϵϳ ϭϯ͕ϰϯϳ ϲ͕ϮϮϰ ϭϯ͕ϵϭϲ ϲ͕ϭϵϬ ϭϰ͕ϰϬϵ ϲ͕ϭϴϳ ϭϰ͕ϴϵϳ ϲ͕ϭϳϲ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϭϱ͕ϯϱϬ ϲ͕ϭϵϬ ƚƚĂĐŚŵĞŶƚϮ ^ƵŶĚƌǇZĞƉŽƌƚ ŽǆϭϭͲWĞƌĨŽƌĂƚŝŽŶ>ŽĐĂƚŝŽŶƐ tĞůů͗K^EͲϯϭ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞĚǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ K'&ŽƌŵϭϬͲϰϬϯ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ϰͲϭͬϮΗWĞƌĨŽƌĂƚĞĚWƵƉ;WŽƌƚĞƌǁͬϲͲϭͬϮΗ,ŽůĞƐͿ ^^^s Dds ,^ΖEΖdZ^^^sǁͬΗyΗWƌŽĨŝůĞ Ϯ͕ϭϰϭ Ϯ͕Ϭϲϰ W<Z^Dds Ϯ͕ϰϵϮ Ϯ͕ϯϳϭ ϳ͕ϰϰϯ ϲ͕ϭϵϮ ϳ͕ϰϲϴ ϲ͕ϭϵϵ t&d'ĞŶĞƐŝƐKŝůĂƐĞ^ǁĞůůWĂĐŬĞƌ ϭϮ͕ϲϱϳ ϲ͕ϮϬϬ t&d'ĞŶĞƐŝƐKŝůĂƐĞ^ǁĞůůWĂĐŬĞƌ ϭϮ͕ϳϲϴ ϲ͕ϭϵϵ ƚƚĂĐŚŵĞŶƚϯ t&dΗEd,Η>ŝŶĞƌdŽƉWĂĐŬĞƌ t&dΗEd,Η>ŝŶĞƌdŽƉWĂĐŬĞƌ K'&ŽƌŵϭϬͲϰϬϯ ZĞƉŽƌƚŽĨ^ƵŶĚƌǇ ŽǆϭϭͲWĂĐŬĞƌƐΘ^^^s tĞůů͗K^EͲϯϭ t&d,ǇĚƌŽǁ//WĂĐŬĞƌ 2'615:2:HOO&RPSOHWLRQ &RQGXFWRU / %7&6XUIDFH &DVLQJ 0' 79' /%7&0 ,QWHUPHGLDWH &DVLQJ 0' 79' ½” /7XELQJ /RZHU &RPSOHWLRQ +ROH7'DW 0' 79' 3XSV6SDFHGa $SDUW 6669 */ */ */0 '*/9 */0 29 * . 2 ++ */6 : */0 '*/9 ,, (( $$ /,%70 7XELQJ 8SSHU &RPSOHWLRQ &KHPLFDO,QMHFWLRQ9DOYH $QQXODU,QMHFWLRQ# 0' &RQWURO/LQHWR6XUIDFH ” Control Line to top of VW 6HDO RISUHVVXUH GLVFKDUJHJDXJHWHFK OLQHORVWGRZQKROH ),1$/ 2'615:2:HOO&RPSOHWLRQ ),1$/ &RQGXFWRU / %7&6XUIDFH &DVLQJ 0' 79' /%7&0 ,QWHUPHGLDWH &DVLQJ 0' 79' ½” /7XELQJ /RZHU &RPSOHWLRQ +ROH7'DW 0' 79' 3XSV6SDFHGa $SDUW 6669 */ */ */0 '*/9 */0 29 * . 2 ++ */6 : */0 '*/9 ,, (( $$ /,%70 7XELQJ 8SSHU &RPSOHWLRQ RISUHVVXUH GLVFKDUJHJDXJHWHFK OLQHORVWGRZQKROH RISUHVVXUH GLVFKDUJHJDXJHWHFK OLQHORVWGRZQKROH &KHPLFDO,QMHFWLRQ9DOYH $QQXODU,QMHFWLRQ# 0' &RQWURO/LQHWR6XUIDFH ” Control Line to top of VW 6HDO 2'615:2:HOO&RPSOHWLRQ &RQGXFWRU / %7&6XUIDFH &DVLQJ 0' 79' /%7&0 ,QWHUPHGLDWH &DVLQJ 0' 79' ò´ /7XELQJ /RZHU &RPSOHWLRQ +ROH7'DW 0' 79' 3XSV6SDFHGa $SDUW 6669 */ */ */0 '*/9 */0 29 * . 2 ++ */6 : */0 '*/9 ,, (( $$ /,%70 7XELQJ 8SSHU &RPSOHWLRQ &KHPLFDO,QMHFWLRQ9DOYH $QQXODU,QMHFWLRQ# 0' &RQWURO/LQHWR6XUIDFH ´&RQWURO/LQHWRWRSRIVW 6HDO RISUHVVXUH GLVFKDUJHJDXJHWHFK OLQHORVWGRZQKROH EŽ͘ hƉƉĞƌŽŵƉůĞƚŝŽŶƋƵŝƉŵĞŶƚ D;ĨƚͿ ds;ĨƚͿ $ *(7XELQJ+DQJHU % ,%703LQ[7&,,3LQ/&URVVRYHU & /WXELQJMRLQW7&,,%R[[3LQ-RLQWV ' /7&,,%R[[,%703LQ&URVVRYHU ( /,%707XELQJ ) /,%70IW3XS-RLQW%R[[3LQ * 1( 7569Z;3URILOH,%70%R[[3LQ&RQWUROOLQHWRVXUIDFH + /,%70IW3XS-RLQW%R[[3LQ , /,%707XELQJ - /,%70IW3XS-RLQW%R[[3LQ . [*/0.%0*,%70%R[[3LQ / /,%70IW3XS-RLQW%R[[3LQ 0 /,%707XELQJ 1 /,%70IW3XS-RLQW%R[[3LQ 2 [:)7+\GURZ,,(633DFNHUZLWK3DFNHU9HQW9DOYH,%70%R[[3LQ 3 /,%70IW3XS-RLQW%R[[3LQ 4 /,%707XELQJ 5 /,%70IW3XS-RLQW%R[[3LQ 6 [*/0.%0*,%70%R[[3LQ 7 /,%70IW3XS-RLQW%R[[3LQ 8 /,%707XELQJ 9 IW,%70%R[[(8(3LQ/&URVVRYHU3XS-RLQW%R[[3LQ t ϮͲϳͬϴΗ ΗyΗEŝƉƉůĞ;Ϯ͘ϯϭϯΗ/ͿhŽǆǆWŝŶ Ϯϲϳϱ ϮϲϬϯ ; IW(8(%R[[,%703LQ/&URVVRYHU3XS-RLQW%R[[3LQ < /,%707XELQJ = /,%70IW3XS-RLQW%R[[3LQ $$ [*/0.%0*,%70%R[[3LQ %% /,%70IW3XS-RLQW%R[[3LQ && /,%707XELQJ '' IW,%70%R[[(8(3LQ/&URVVRYHU3XS-RLQW%R[[3LQ (( ;11R*R,%70%R[[3LQ )) IW(8(%R[[,%703LQ/&URVVRYHU3XS-RLQW%R[[3LQ ** /,%707XELQJ ++ $XWR'LYHUWHU9DOYH ,, (633XPS$VVHPEO\ (QGRI$VVHPEO\ &XUUHQW&RQGLWLRQ-XO\ )LVKVWXFNDFURVV7569 0D[2' /HQJWKIW 2'615:2:HOO&RPSOHWLRQ ),1$/ &RQGXFWRU / %7&6XUIDFH &DVLQJ 0' 79' /%7&0 ,QWHUPHGLDWH &DVLQJ 0' 79' ò´ /7XELQJ /RZHU &RPSOHWLRQ +ROH7'DW 0' 79' 3XSV6SDFHGa $SDUW 6669 */ */ */0 '*/9 */0 29 * . 2 ++ */6 : */0 '*/9 ,, (( $$ /,%70 7XELQJ 8SSHU &RPSOHWLRQ EŽ͘ >ŽǁĞƌŽŵƉůĞƚŝŽŶƋƵŝƉŵĞŶƚ D;ĨƚͿ ds;ĨƚͿ :)73%57LH%DFN6OHHYHIW :)717+/LQHU7RS3NU; :)73+55RWDWLQJ+\G6HW/LQHU+DQJHU; /+\GULO3XS-WZ)XOO0XOHVKRH End of Assembly :)73%57LH%DFN6OHHYHIW :)717+/LQHU7RS3NU :)73+55RWDWLQJ+\G6HW/LQHU+DQJHU /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV :)7*HQHVLV2LO%DVH6ZHOO3DFNHUZ6SLUDJOLGHU&HQWUDOL]HU :)7*HQHVLV2LO%DVH6ZHOO3DFNHUZ6SLUDJOLGHU&HQWUDOL]HU /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /+\GULO3XSMWIW3RUWHGZKROHV /LQHU6KRH3/8**(' End of Assembly RISUHVVXUH GLVFKDUJHJDXJHWHFK OLQHORVWGRZQKROH RISUHVVXUH GLVFKDUJHJDXJHWHFK OLQHORVWGRZQKROH &KHPLFDO,QMHFWLRQ9DOYH $QQXODU,QMHFWLRQ# 0' &RQWURO/LQHWR6XUIDFH ´&RQWURO/LQHWRWRSRIVW 6HDO &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRU RSHQDWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH )URP9DXJKDQ$OH[ 7R0F/HOODQ%U\DQ-2*& &F&KDXGKU\$PMDG 6XEMHFW5(>(;7(51$/@2'6137'5:26XQGU\ 'DWH0RQGD\-XO\30 $WWDFKPHQWVLPDJHSQJ LPDJHSQJ LPDJHSQJ LPDJHSQJ 2'615:26FKHPDWLF&XUUHQW&RQGLWLRQSGI ƌǇĂŶ͕ WůĞĂƐĞĨŝŶĚƚŚĞŶŝƌĞƐƉŽŶƐĞƚŽƚŚĞƋƵĞƐƚŝŽŶƐƌĞŐĂƌĚŝŶŐƚŚĞK^EͲϯϭƐƵŶĚƌǇĂƉƉůŝĐĂƚŝŽŶďĞůŽǁ͘ YƵĞƐƚŝŽŶϭ͗ĚĚƌĞƐƐĞĚŝŶƉƌĞǀŝŽƵƐĞŵĂŝůĨƌŽŵŵũĂĚ YƵĞƐƚŝŽŶϮ͗ƐƌĞƋƵĞƐƚĞĚŶŝǁŝůůƉĞƌĨŽƌŵĂĐĂƐŝŶŐƚĞƐƚďĞůŽǁƚŽƉŽĨĐĞŵĞŶƚŽŶƚŚĞƉƌŽĚƵĐƚŝŽŶ ĐĂƐŝŶŐ YƵĞƐƚŝŽŶϯ͗K^EͲϯϭŚĂƐĂƐůŝĐŬůŝŶĞĨŝƐŚƐƚƵĐŬĂĐƌŽƐƐƚŚĞdZ^sƚŚĂƚǁĞŚĂǀĞŶŽƚďĞĞŶĂďůĞƚŽ ƌĞŵŽǀĞǀŝĂƐůŝĐŬůŝŶĞŽƌĐŽŝůƚƵďŝŶŐŝŶƚĞƌǀĞŶƚŝŽŶ;ƐĞĞĂƚƚĂĐŚĞĚƐĐŚĞŵĂƚŝĐͿ͘dŚĞZtKƉƌŽŐƌĂŵǁŝůůƉƵůů ƚŚĞϮͲϳͬϴ͟^WĐŽŵƉůĞƚŝŽŶƐƚƌŝŶŐǁŝƚŚƚŚĞĨŝƐŚŝŶƉůĂĐĞ͘ŶĞǁ^WĐŽŵƉůĞƚŝŽŶǁŝůůďĞŝŶƐƚĂůůĞĚ ƚŚĞƌĞďǇƌĞƉůĂĐŝŶŐƚƵďŝŶŐĂŶĚĂŶŶƵůĂƌǁĞůůĐŽŶƚƌŽůďĂƌƌŝĞƌƐƚŽƌĞŐĂŝŶĐŽŵƉůŝĂŶĐĞ͘ WƌĞͲZŝŐ^ůŝĐŬůŝŶĞWƌŽŐƌĂŵ͗ 58VOLFNOLQHXQLW ,QVWDOO´(YR7ULHYHLQILUVWWZRMRLQWVRI´WXELQJEHORZKDQJHU 3UHVVXUHWHVW(YR7ULHYHWRSVLPLQFKDUWHG 5'+$/VOLFNOLQHXQLW ZŝŐWƌŽŐƌĂŵ͗ 0RYH1DERUV$&ULJRYHUZHOO 2IIFULWLFDOSDWKWDVNV D 9DXOWWRSHUIRUPSUHZRUNRYHU;PDVWUHHSUHVVXUHWHVWVSULRUWRVWDUWRSHUDWLRQ E 3URGXFWLRQWREOHHGJDVFDSIURPDQQXOXV³$´ F 3URGXFWLRQWRFRQILUPDELOLW\WREXOOKHDGWKURXJKWXELQJ G 9HULI\6F669DFWXDWLRQFORVHDQGYHULI\PRQLWRUFRQWUROOLQHSUHVVXUH ,QVWDOO%39DQG1LSSOHGRZQ;PDVWUHH 0DNHXSEODQNLQJSOXJRQWRSRI%39LQWXELQJKDQJHU 1LSSOHXS%23DQGSUHVVXUHWHVWDVSHUDSSURYHGVXQGU\ D 3LSHUDPVDQGDOO%23HTXLSPHQWWREHWHVWHGWRSVL E $QQXODUWHVWHGWRSVL F 7HVWMRLQWV´´ G 1RWLI\$2*&&KRXUVSULRUWR%23WHVW 3XOOWHVWMRLQWZLWKEODQNLQJSOXJ 3XOO%39IURPWXELQJKDQJHUDVSHU9DXOWSURFHGXUH 08ODQGLQJMRLQW9DXOW´/DQGLQJMRLQW %XOOKHDGWXELQJYROXPHRISSJEULQHGRZQWXELQJWKURXJK(63WRWXELQJWDLO %XOOKHDGDQQXOXVµ$¶YROXPHRI´[´DQQXODUYROXPHWR´VKRH )ORZFKHFNIRUKUWRHQVXUHZHOOLVGHDG %2/'6EDFNRXWORFNGRZQVFUHZV 8QVHDW´WXELQJKDQJHUDQG(63SDFNHU %XOOKHDGRI ´[´DQQXOXVYROXPH D $OORZ(63SDFNHUHOHPHQWVWRUHOD[ZKLOH58WXELQJSXOOLQJHTXLSPHQW L 5HFLSURFDWH(63SDFNHUDVUHTXLUHGWRDFFHOHUDWHSURFHVV LL 3HUIRUPUHFLSURFDWLRQPDLQWDLQLQJKDQJHUEHORZERWWRP%23UDP E 0RQLWRU´[´DQQXOXVIRUJDVPLJUDWLRQSDVWSDFNHUHOHPHQWDIWHUSDFNHUUHOHDVHV L %XOOKHDGDGGLWLRQDONLOOZHLJKWIOXLGGRZQDQQXODUµD¶YROXPHWR´VKRH F 0RQLWRU´WXELQJIRUJDVPLJUDWLRQWKURXJK(63DQGXSWXELQJ L %XOOKHDGDGGLWLRQDONLOOZHLJKWIOXLGGRZQWXELQJWRWXELQJWDLO 3UHSULJIORRUWRSXOOFRPSOHWLRQ 3XOOWXELQJKDQJHUWRURWDU\WDEOH D 3XPSDSSUR[LPDWHO\EEOKRXURISSJEULQHGRZQDQQXOXVWKURXJKRXWWKHRSHUDWLRQVWRPDLQWDLQZHOO ILOOHG ZĞĨĞƌĞŶĐĞK^EͲϯϭƉƌĞƐƐƵƌĞŝŶĨŽƌŵĂƚŝŽŶƉƌĞǀŝŽƵƐŝŶĐůƵĚĞĚŝŶK^EͲϯϭƐƵŶĚƌǇĂƉƉůŝĐĂƚŝŽŶ ĐŽƉŝĞĚďĞůŽǁ͗ ^ĐŽƉĞŽĨtŽƌŬ ^ĐŽƉĞ ŽĨ ƚŚŝƐ ǁŽƌŬŽǀĞƌ ŝƐ ƚŽ ƉƵůů ŽƵƚ ĨĂŝůĞĚ ^W ĐŽŵƉůĞƚŝŽŶ ĂŶĚ ƌĞĐŽŵƉůĞƚĞ ŝƚ ǁŝƚŚ ŶĞǁ ^W ĐŽŵƉůĞƚŝŽŶ͘ 'ĞŶĞƌĂůtĞůů/ŶĨŽ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞͬds͗dŚĞĞƐƚŝŵĂƚĞĚƌĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞŝŶŵŝĚͲDĂƌĐŚĨŽƌK^EͲϯϭ EƵŝƋƐƵƚŝƐϮ͕ϲϬϬƉƐŝĂƚͲϲ͕ϯϱϬ͛dsƐƐ;ĐŚĂƌƚďĞůŽǁͿ͕ǇŝĞůĚŝŶŐ ĂŵĂǆŝŵƵŵĂŶƚŝĐŝƉĂƚĞĚƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞ;D^WͿŽĨϭ͕ϵϲϱ ƉƐŝ͘ ŝŵĂŐĞϬϬϭ͘ƉŶŐ ŝŵĂŐĞϬϬϮ͘ƉŶŐ $OH[9DXJKDQ Sr. Drilling & Completions Compliance Engineer Eni US Operating Co. Inc. &HQWHUSRLQW'U6XLWH $QFKRUDJH$. 0 ŵũĂĚ͕ ĨĞǁƋƵĞƐƚŝŽŶƐ dŚĞ'ĞŶĞƌĂůtĞůů/ŶĨŽƌŵĂƚŝŽŶƐĞĐƚŝŽŶƐĂǇƐƚŚĂƚƚŚĞϳ͟ĐĂƐŝŶŐǁĂƐƚĞƐƚĞĚƚŽϯϱϬϬƉƐŝǁŚĞŶƚŚĞ ǁĞůůǁĂƐŽƌŝŐŝŶĂůůǇĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶ:ƵůǇϮϬϭϳ͘dŚŝƐǁĞůůǁĂƐĚƌŝůůĞĚĂŶĚĐŽŵƉůĞƚĞĚŝŶ ϮϬϬϴͬϮϬϬϵƚŝŵĞĨƌĂŵĞ͘ŽƵůĚƚŚĞƌĞďĞĂĐƵƚĂŶĚƉĂƐƚĞĞƌƌŽƌĨƌŽŵĂĚŝĨĨĞƌĞŶƚǁĞůů͍ĂŶǇŽƵ ĐŽŶĨŝƌŵƚŚĞůĂƐƚƚŝŵĞƚŚĞƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐǁĂƐƚĞƐƚĞĚ͍ zŽƵŚĂǀĞĂĐŽŶƚŝŶŐĞŶĐǇƚŽƌƵŶĂƚĞƐƚƉĂĐŬĞƌĂƐƐĞŵďůǇƚŽϯϬϬϬ͛D͘hŶĚĞƌǁŚĂƚ ĐŝƌĐƵŵƐƚĂŶĐĞǁŽƵůĚǇŽƵĚŽƚŚŝƐ͍/ĨƚŚĞůĂƐƚƚĞƐƚǁĂƐŵŽƌĞƚŚĂŶϴǇĞĂƌƐĂŐŽ͕ƚŚĞŶǁĞǁŝůůĂƐŬ ĨŽƌǇŽƵƚŽƉĞƌĨŽƌŵĂĐĂƐŝŶŐƚĞƐƚ͘dŚĞƚĞƐƚƉĂĐŬĞƌƐĞƚĚĞƉƚŚƐŚŽƵůĚďĞĐůŽƐĞƚŽƚŚĞƚŽƉŽĨƚŚĞ ƌĞƐĞƌǀŽŝƌǁŝƚŚŝŶƚŚĞĐŽŶĨŝŶŝŶŐǌŽŶĞĂŶĚďĞůŽǁdŽƉŽĨĐĞŵĞŶƚŽŶƚŚĞƉƌŽĚƵĐƚŝŽŶĐĂƐŝŶŐ͘ dŚĞŬŝůůƉƌŽĐĞĚƵƌĞĂƐǁƌŝƚƚĞŶǁŝůůŶŽƚĚŝƐƉůĂĐĞŚǇĚƌŽĐĂƌďŽŶƐĨƌŽŵƚŚĞĂŶŶƵůƵƐ͘/ƚǁŽƵůĚďĞ ŚĞůƉĨƵůƚŽŝŶĐůƵĚĞƚŚĞƉƌĞͲƌŝŐƉƌŽĐĞĚƵƌĞ͕ƐŝŵŝůĂƌƚŽǁŚĂƚůĞǆƐĞŶƚĨŽƌK^<Ͳϰϭ͘^ĞĞĂƚƚĂĐŚĞĚ ĞŵĂŝů͘ ƌǇĂŶDĐ>ĞůůĂŶ ^ĞŶŝŽƌWĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtϳƚŚǀĞ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀ нϭ;ϵϬϳͿϮϱϬͲϵϭϵϯ ------------------------------------------------------------------------------------------------------------------------- ----------------------------------------------- Message for the recipient only, if received in error, please notify the sender and read http://www.eni.com/disclaimer/ • STATE OF ALASKA AL.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations El Fracture Stimulate El Pull Tubing 0 Operations shutdown LI Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill El Perforate New Pool ❑ Repair Well El Re-enter Susp Wet❑ Other:ESP Swap El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Caelus Natural Resources Alaska,LLC Development 0 Exploratory❑ 208-003 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-703-20565-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL 355036/ADL 389958 ODSN-31 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk- Nuiqsut Oil Pool SEP 15 2017 11.Present Well Condition Summary: A OGCC Total Depth measured 15,363 feet Plugs measured N/A feet true vertical 6,189 feet Junk measured N/A feet Effective Depth measured 6,582 feet Packer measured See attachment,pg.3 feet true vertical 6,119 feet true vertical See attachment,pg.3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3,092' 9-5/8" 3,131' 3,036' 5,750 psi 3,090 psi Intermediate 7,567' 7" 7,606' 6,234' 7,240 psi 5,410 psi Production Liner 7,912' 4-1/2" 15,358' 6,190' 8,430 psi 7,500 psi t�DVV 101/ Perforation depth Measured depth See attachment,pg.2 feet SCOSED True Vertical depth See attachment,pg.2 feet Tubing(size,grade,measured and true vertical depth) 2-7/8",6.4# L-80,IBT-M 6,582'MD 6,119'TVD Packers and SSSV(type,measured and true vertical depth) See attachment,pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 547 123 0 316 361 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory El Development0 Service El Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-249 Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff Co ••letion Engineer Contact Email: rami.laSSer( caelusenercV.Com Authorized Signature: % /\', 9/�� 907-343-2182 9 Date: ��" Contact Phone: c L ci"27 /7 F/277 Form 10-404 Revised 4/2017 ® RBDMS iLv SEP 2 5 2017 Submit Original Only • • Attachment 2 AOGCC Form 10-404 Sundry Report Box 11 - Perforation Locations Well: ODSN-31 Top(MD) Top(TVD) 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 7,800 6,274 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,006 6,300 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,214 6,301 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,421 6,297 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,627 6,295 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,835 6,293 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,041 6,288 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,250 6,277 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,460 6,273 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,669 6,266 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,880 6,260 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,090 6,241 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,301 6,223 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,512 6,206 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,716 6,197 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,925 6,197 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,124 6,207 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,325 6,221 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,530 6,230 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,737 6,232 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,936 6,236 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,140 6,235 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,350 6,226 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,513 6,212 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,964 6,197 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 13,437 6,224 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 13,916 6,190 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 14,409 6,187 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 14,897 6,176 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 15,350 6,190 • • Attachment 3 AOGCC Form 10-404 Report of Sundry Box 11 - Packers & SSSV Well: ODSN-31 SSSV MD TVD HES 'NE' TRSSSV w/"X" Profile 2,141 2,064 PACKERS MD TVD WFT Hydrow II Packer 2,492 2,371 WFT "NTH" Liner Top Packer 7,443 6,192 WFT "NTH" Liner Top Packer 7,468 6,199 WFT Genesis Oil Base Swell Packer 12,657 6,200 WFT Genesis Oil Base Swell Packer 12,768 6,199 • Alaska *Operations Summary Report- Stat• Well Name: ODSN-31 CAELUS Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 7/26/2017 7/27/2017 15,363.0 00:00 7/26/17-00:00 7/27/17 Prep well for RWO. *MIRU HES Slickline to perform the Pre RWO program. *Drift the well to 2,710'slm to ensure all is clear to the X nipple. *Set a 2 7/8"RHC-M in the X nipple at 2,600'slm. *Pull the 1.5"DGLV from 2,539'slm.Due to false indication that the packer vent valve was in good working condition there was trapped pressure on the IA below the packer.This caused an overbalance in the IA to TBG pressure and it"popped"slickline when the valve was pulled. *Upon getting"popped"the slickline wire parted and all the wire was retrieved with the exception of 5-10'. *Slickline cut 250'of wire and retied the slickline rope socket and picked up all necessities to fish the toolstring. *Slickline unable to pass 233'slm.Trouble shoot the situation with several remedies. *Slickline able to pass through 233'after cutting another 250'of wire. *Tag the toolstring at 704'slm with a 2.035"gauge ring. *Latch the fish at 704'slm and jar 5x at 600#fish moves up to 689'slm and jar 7x at 600#. Pulling tool shears. *POOH to inspect tools. *Latch the fish at 689'slm and jar 5x 600#.Pull free.POOH to surface. *On surface with fish.Oil jars parted at the main mandrel on the oil jars. *Change out toolstring. 7/27/2017 7/28/2017 15,363.0 00:00 7/27/17-00:00 7/28/17 Prep well for RWO. *Continue fishing operations. *Verify the remainder of the fish is sitting at 2,584'slm on top of the RHC catcher. *Mobilize tools from deadhorse to retrieve the remainder of the fish. *Retrieve the remainder of the fish from 2,584'slm.1.5"GLV from GLM#2 recovered in KOT tray catcher. *Pull the DGLV from GLM#3 at 2,415'slm. *Pull the RHC-M from the X nipple at 2,600'slm. *Jar the RHC-M through the GLM#2 PKR and GLM#3.Unable to pass the 2.313"polish bore on the TRSV at 1,992'slm. *Discuss with Anchorage team and decide to jar the RHC-M back in the hole and leave it below the PKR at 2,504'slm. *Jar down on the RHC-M catcher and push down to X-nipple @ 2,600'slm. *Ran HES Maxfire memory tool to 2,477'slm to gather PSI/Temp data to set parameters. *Ran HES Maxfire memory tool&stringshot assembly,unable to work tools past GLM#3 @ 2,417'slm.Decision made to let stringshot fire @ 2,250'slm/2,270'MD due to lack of time to pull to surface.Good indication of stingshot firing.WFT Hydrow II Pkr @ 2,504'MD. *Discuss plan forward w/Wells Superintendent. *Ran HES Maxfire memory tool&"Dummy"stringshot assembly w/sucker rod crossover&2.25" centralizer.Unable to work past GLM#3 @ 2,417'slm. *Ran HES Maxfire memory tool&"Dummy"stringshot assembly w/sucker rod crossover&1.5" bow spring centralizer.Work tools past GLM#3 @ 2,417'slm.Tag RHC-M catcher @ 2,602' slm.Pull up hole 118'to WFT PKR&flag wire @ 2,484'slm. 7/28/2017 7/29/2017 15,363.0 00:00 7/28/17-00:00 7/29/17 (Pre-RWO) *Attempted to re-run HES Maxfire memory tool&stringshot assembly with several configurations but was unable to work past GLM#3 @ 2,417'slm.Had to jar for 30 minutes on last attempt to pull free from GLM#3 @ 2,417'slm.Possible damage to GLM#3. *Discuss plan forward w/Wells Superintendent. *RDMO HES Slickline. *GE installed BPV in tubing hanger w/HES crane support. ***Well status:Tubing freeze protected w/140 bbls of diesel. IA freeze protected w/75 bbls of diesel.GLM#3&GLM#2 have empty pockets.RHC-M plug w/.625"ID left in X-nipple @ 2,600'slm.TRSV in closed position.BPV set in tubing hanger and void tested to 5000 psi.*** Page 1/3 Report Printed: 9/14/2017 Operations Summary Report- State Well Name: ODSN-31 Al�ayn CALLtt Start Depth FootMeters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 8/22/2017 8/23/2017 15,363.0 8.50 NOTE:Rig 19AC accepted to well ODSN-31 at 00:00 hrs 8-22-2017 RU Lubricator Pull BPV RD Lubricator ODSN-31 Pre-Spud Bullhead 100bbIs down 2-7/8"x 7"IA Bullhead 285bb1s down 2-7/8"tubing Install BPV ND Tree&NU BOPE stack to riser Test BOPE per AOGCC PTD: -Test 1,Annular w/2-7/8"test joint to 250 psi low/2500 psi high. Passed -Test 2-6,Choke manifold to 250 psi low/3500 psi high.Passed -Test 7,Choke manifold to 250 psi low/3500 psi high.Passed r AOGCC Rep Jeff Jones waived witness on 8-22-2017,05:57 (t� 8/23/2017 8/24/2017 15,363.0 8.50 Cont testing BOPE -Test 8-9,Upper and lower 2-7/8"x5"VBR w/4"test joint to 250 psi/3500 psi. Passed -Test 10-11,Upper and lower IBOP valves to 250 psi low/3500 psi high.Passed -Test all floor valves to 250 psi low/3500 psi high. Passed -Test 12,Blind rams.250 psi low/3500 psi high.Passed AOGCC Rep Jeff Jones waived witness on 8-22-2017,05:57 Pull test dart and BPV Bullhead 285bb1s down tubing -Flow check,No flow Pull hanger to floor and terminate control lines POOH 4,074'to 83'with 2-7/8"6.4#L-80 IBT-M ESP completion and LD -Cont to fill IA with seawater,5bbls/30min plus 150%pipe displacement 8/24/2017 8/25/2017 0.0 3,165.00 8.50 Complete FSP LD RIH with cleanout BHA from surface to 3,165'. Circ&POOH RIH with 2-7/8"6.4#L-80 IBT-M ESP completion from surface'to 881' -Cont to fill IA with seawater,5bbls/30min plus 150%pipe displacement Notified AOGCC at 18:21 hrs on 24 August of upcoming BOPE test for ODSN-29 RWO. 8/25/2017 8/26/2017 3,165.0 0.00 8.50 RIH with 2-7/8"6.4#L-80 IBT-M ESP completion from 881'to 6,547' MU and Land hanger -Test hanger void between upper and lower seals to 5000psi for 10min -Cont to fill IA with seawater,5bbls/30min Page 2/3 Report Printed: 9/14/2017 • •Operations Summary Report- Stat• CAELUS a C Alaska. Well Name: ODSN-31 =rc ria ' Start Depth Foot/Meters Dens Last Start Date End Date (ftK6) (k) Mud(Ib/gal) Summary 8/26/2017 8/27/2017 3,165.0 0.00 8.50 RU ExPro lubricator slickline and RIH with ball and rod RD ExPro lubricator Set Weatherford ESP packer Pressure up to 2500psi to set packer Pressure test tubing to 3500osi.30min.good Pressure test IA to 2500psi,30min,good Shear DCK valve in upper GLM Install TWC Pressure test TWC from below to 1500psi, 10min,good ND BOPE&NU Tree Pressure test tree to 5000psi,10min,good Pressure test hanger void,good Pressure test TRSV 5000psi,10min,good -Lock open TRSV Pressure test PVV 3000psi, 10min,good Fill/test chemical injection line RU ExPro lubricator Pull TWC RD ExPro Lubricator Release rig from ODSN-31 at 00:00 on 8-27-2017 Page 3/3 Report Printed: 9/14/2017 ODSN-31 RWO WS Completion FINAL 8-28-2017 iiiii I No. Upper Completion Equipment MD(ft) TVDffti iiiii A 3E .- -- B 3-1 C • '2 28 1. u3 1-80 Crossover °.. C 3112 1-c #tubing a :-IlBaxxPin c2Jg-'- AN ,:: : z.i C 1 2"9,2 --6a. TC-IBo. . i 1?' t 44 131 ' ,ossover 16" E 2-718"6.4#L-80 IBT-U Tubing GLM#3i K Conductor F 2-7.8"6.4 -S01BT-M 15ft Pu; e. SOV /� a G 2-78"111 9Vwr2.313"X"F MB;. 'in-, Ign+ 2141 2061 I p I S H 2-7 "A 15ft Pup Jo.. • r Pias ., 1 2-715`, :-- Teti^. GLM#2 ,J S J 2-718"6441-801B7 ;:Joint Box x Pin DGLV K 2-718"x 1 = 4 IBT-MBox x Pin 2393 2312 X W 1 2-7 8"t.' •Al Pup Joint Box x Pin bi 2-7'8 -"—El,BT-I.!Tubing N 2-7;.8...... €d IBT-M 155 Pup Joint Box x Pine O 2 7 8"x? T Hvdrov,1 Packerwith P.,, IBT-M Bou x F'u 13'1 P r.3s-9-80 18T 1 Joint Box x Pin o 2."= c 44 L-80 16'J.''..c;-S R 8"&4#L-80161-M 15tt Pup Joint Box x Pin S 24 8"x 1"GLM#2 KBt.1G 13T-MBox x Pin 2578 2429 T 2-718"644 L-801ST-61 1501 Pup Joint Box x Pin I U 2-7/8"6.441-80 1137-M Tubing 2-7/8"6.5# 9-5/8"40#L-80 V 15 ft 2-718"6.44 IBT-M Baer x 2-718"6.4#EUE Pin L-80 Crossover Pup Joint Box x Pn L-80 IBT-M BTC Surface W 2-7/8""X"Nipple(2.313"113)EUE Box xPin 2675 2486 x 15ft2-7/8"6.4#EUE Box x2-7/8"6.4#1BT-MPn1-80Crossrp.•erPup Joint Box xPn Tubing Casing 3,131' Y 2-7/8"6.4#L-60 1ST4.1 Tubing (Upper MDl3,036'TVD Z 2-7/8"64#L-80IBT-M1501Pop Joint Box xPin Completion) AA 2-7/8"x 1"GLM41 KBMG 1BT-M Box x Pin 6154 5627 GLM#1 //^�,� BB 2-718"&4#L-60 IBT-M 15ft Pup Joint Box x Pin �J 5/16"OV CC 2-7/8"6.441-801ST-U Tubing CC 15 ft 2-718"6.4#IBT-M Box x 2-718"6.4#EUE Pin L-80 Crossover Pup Joint Bat x Pin EE "XN"2.313"2.205"No-Go IBT-M Box x Pin 6254 5916 FF 15 ft 2-7/8"6.4#EUE Box x 2-718"6.441ST-M Pin L-80 Crossover Pup Joint Box x Pin GG 2-718"6.4#L-80 IBT-U Tubing HH Auto Diverter Valve 6499 6105 I ESP Pump Assembly 6503 6106 End ofAssentrk 6.582 6,119 XN EE Chemical Injection Valve (Annular Injection)@ 6,495'MD 0 0 0 0 3/8"Control Line to Surface 1/4"Control Line to Bottom of ESP Pump 16.5'of pressure — <=>Q / \discharge te ® k ,g 19 line lost dg ch :; 4-1/2" 12.60# C 21 L-80 Tubing 23 (Lower Completion) 24 N/ IC)' 2 ` C5i: 51 01 \ 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 02 11 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7"26#L-80 BTC-M Intermediate 420 (DJEI _El 52 — __ED— 57 — — Casing 7,606'MD/ 6,234'TVD #26-49(24)Pups Spaced-200'Apart 6-1/8" Hole TD at 15,363'MD/6,189'TVD r ODSN-31 RWO Wet Completion FINAL 8-28-2017 rt,� tower Completion Equ meat 8,491,111 . T+aro lftj FT F5F.Tte 5a7.=ee.-1°f: 7,427 8138 2.0 ANFT5fll4 Lirr�T:,�4,.:T2','= = •e= 7,443 �Z.13d 21 '.FT Fr+ o -- - Ss'•t lirate ro-��,7 2 2 '''''.r ? - 0'133 li. • r..... ' 0 22 4-1215 . : c21 Fo 6 it er Full hftiuk h _ -• - 5.134 L16" =t r a: icy • 5.e:':1111197349:283 197 ;`FT T RAN shrwc 19t _ =134 GLM e 0 Conductor --'CH Lies T,. Pt; -. : _.1% SOV - _ _-PI-p Pati- -rd Set Liner-Hamer = 0 -'41 - 1 '594L = nt=ft'Peire,81f2heiesi .7.t _ IC - - Rtt=ft''Ported-.v'e 12 hetes, S 51.2" GLM#' ,I- .- ® :1 irrdra Fuei 4f;Ported&5 1.2 ter _- _ _ H`tdra FtiGi 4f'F-▪i„5 2I1,C1u DGLV ® - - =L-80Hvdr,lRyGi4 ▪ - - s -.1.!,-:..L-3,0 intdril Rei 4f• -_ - -:,L. __ - _ _SE= it dril FLet 4f„ 4-�= - _ -.-- -._-- __ - L TC-L-8:^4,,L-il Puri 4ft F -e2 - '2 nni. 2f 2.- 24 - •---_ _ - F. i4s- _- _ ' 2hni' 3.53 5 -' 3.',.8.8 f L_. 3".882 5.25'2 =L-85- _Gt.= -c v,: - _= 10090 __- - - i. L-05!-,-r.rupt4f' -d4•>? - __ 12.011 -_ - _ 2_-=L-8I Hy°eril RIO 4ft.F4:r-dyt'e12-,- '3-512 `_ A ` - -•: '-c:=L-ZCI Hydril Pup'4ft:Faced.x'8 12 ix4- "0,715 - -- 25 L- 1}11dxiJRei4ft#Foa'tcdwr'S12h , 10.925 _ 2-7/8"6.5# 9-5/8"40#L-80 42 --= 12 L-80504 H„dril P,et4ft Ceded iv 812 hdi5, 11.124 L-80 IBT-M BTC Surface 43 41:2 128 L-80 Reid Ft t eft:Poled re 5 12 ho4es, 11.325 5221 44 4-1:2 12504 L80 114dril Peet eft Ceded or 8 12 hcle,? 11,505 8,220 Tubing Casing 3,131' 4S - , Cei L-80 1-tydril Riej4ftiec ei iii e1,2nin1.1 11737 8^22 (Upper MD/3,036'TVD 45 - - 12504 L-0 Hvdril FIX 14ft IPCFIEd.v'e 1:2 rte': 11.930 5.. ,, Completion) 47 4. 2 1=500L80d4iFrani 4ft:Pe; d>~a812hc. .., 12140 5.225 48 4- 1',}YFF L-82 FN3ri1 Perm 4ftIFeirted.v 512 thks', 12353 8225 GLM#1AA 49 4-'2 12034 L-80 4rdril R4-t 4ft;Ceded'iv 8 1 2 hclE ) 12,513 8,212 GL J 5/16"OV 59 'OiFTGenesis Oil Base Se,e8 Peet erw:Srienlider Certalizer 12,E 5,22o El 'WFTGenre.e Oil Base 5.411 Fearer iv Scryelide•Certtal¢er 12752 8,198 52 4-1.2 1280=L-83 FNdril Rx>t 4ft 1Pert=0,4 8 1-2 holier', 12954 5.197 / 53 412 125,4 L80 F1adril Rx>t 4ft:Paced;i 8 12 holes', 12,437 5.224 ✓/ 5A 41 2 12 FOM L-8O Hy-aril Puci 4ft:Pcr�d.a e 1 2 hclEsi 13.915 5.150 55 41 2 12"OM L--80 lfydra Pt3t 4ft J F^..xted 4-5 112 hc) 14,409 5.127 5.0 4-12 12',4L-80 Hydra Pleat 4ft:Ceded a'e 112 tc t 14,897 5,175 57 4-1 2 12 L-30 Hydril Peet 4ft,P4 t=d&8 1.2 hole; 15:350 5.190 88 Lirrr Shoe!Ft1.IGGEC3 15,355, 5.190 4 414 0 Bad d A s ern LA' 15.358 8,130 Chemical Injection Valve (Annular Injection)@ 6,495'MD 0 0 0 0 3/8"Control Line to Surface 1/4"Control Line to Bottom of ESP Pump 16.5'ofpressure — �Q edischarge gauge tech 19 line lost downhole 2 0 a i�� J 4-1/2" 12.60# '' :' ( 21 L-80 Tubing CD , (Lower Completion) 2a C 22 . 4 ri k 51 58, ' 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 02 il 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7"26#L-80 BTC-M Intermediate 0 as 52 - - - ____c) — Casing 7,606'MD/ 16.5'of pressure 6,234'TVD discharge gauge tech #26-49(24)Pups Spaced-200'Apart 6-1/8" Hole TD at line lost downhole 15,363'MD/6,189'TVD • \11/7- •9 THE STATE Alaska Oil and Gas ,..".0. KA. -Z, � a� pf/e T /� � Conservation Commission ',015147L-:::::=4:E. 333 West Seventh Avenue 14 - 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wo- Main: 907.279.1433 0...A '.9.0` Fax: 907.276.7542 www.aogcc.alaska.gov Rami Jasser Senior Staff Completion Engineer Caelus Natural Resources Alaska,LLC scow3700 Centerpoint Dr., Ste. 500 U i 0 !, Anchorage,AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-31 Permit to Drill Number: 208-003 Sundry Number: 317-249 Dear Mr. Jasser: 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, L711 Cathy . Foerster Chair DATED this / day of June, 2017. RBDMS '- JUN 2 6 2017 1 • • :RECEIVED STATE OF ALASKA , , ejIJN 13 ?017 ALASKA OIL AND GAS CONSERVATION COMMISSION / j 5 / APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon a Plug Perforations a Fracture Stimulate ❑ Repair Well a Operations shutdown a Suspend ❑ Perforate a Other Stimulate ❑ Pull Tubing 0 Change Approved Program a Plug for Redrill a Perforate New Pool a Re-enter Susp Well D Alter Casing ❑ Other: Run ESP 0 2.Operator Name: 4.Current Well Class: 5 Permit to Drill Number: Caelus Natural Resources Alaska,LLC Exploratory a Development 0 ' 208-003 - 3.Address: Stratigraphic ❑ Service ii 6.API Number: 3700 Centerpoint Drive,Suite 500,Anchorage,AK 99503 50-703-20565-00-00 I 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A ODSN-31 . Will planned perforations require a spacing exception? Yes a No 0 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958 - Oooguruk-Nuiqsut Oil Pool , 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): 15,363' 6,189' , 15,355' ` 6,190' - 1,165 psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3,092' 9-5/8" 3,131' 3,036' 5,750 psi 3,090 psi Intermediate 1 7,567' 7" 7,606' 6,234' 7,240 psi 5,410 psi Production Liner 7,912' 4-1/2" 7,452'-15,358' 6,195'-6,190' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attachment pg.2 • See attachment pg.2 2-7/8" 6.5#,L-80,IBT-M 6,579' Packers and SSSV Type: See attachment pg.3 Packers and SSSV MD(ft)and TVD(ft): See attachment pg.3 . 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program a BOP Sketch a Exploratory a Stratigraphic a Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 8/18/2017 OIL 0 • WINJ a WDSPL ❑ Suspended a 16.Verbal Approval: Date: GAS ❑ WAG a GSTOR ❑ SPLUG ❑ Commission Representative: GINJ a Op Shutdown ❑ Abandoned 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: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff Completion Engineer Contact Email: rami.iasserUecaeluseneray.corn ®� ‘7/12147 Contact Phone: 907-343-2182 Authorized Signatures"\��'�� e Rte'J ( Date: �� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3I7- 2`fg- Plug Integrity a BOP Test n Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1E 35.00 po5:. h(i • jam. i Post Initial Injection MIT Req'd? Yes a No a RBDMS Ll. JUN Z 6 2017 Spacing Exception Required? Yes a Nod Subsequent Form Required: j C� `I D`1 Cf APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:C , is.- 7 At 2,1., 4 -/s"--/-7 Submit Form and Form 10-403 Revised 4/2017 0Iiplo�{8/�� Ii AIilid for 12 months from the date of approval. Attachments in Duplicate • CAEUJS June 8, 2017 RECEIVED JUN 1 3 2017 State of Alaska AOGCC Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-31 Sundry Application for ESP Change-Out REF: Approved Permit to Drill #208-003 Caelus Natural Resources Alaska, LLC. (CNRA) submits an Application for Sundry to replace a failed 2-7/8" ESP on ODSN-31 with a new 2-7/8" ESP Upper Completion. / See the proposed plan attachments and supporting documentation. Sincerely, Ka.- -Poe R.argti JaSSe( i Jasser Senior Staff Completion Engineer Attachments: Form 10-403 Supporting Information cc: ODSN-31 Well File 2 ODSN-31 Procedure Summary: Pre-Rig: 1. Pull OV from GLM #1) 2. Install DV in GLM #1 3. Pull DV from GLM #2 4, Pull DV from GLM #3 5. Bleed gas from tubing and IA 6. Bullhead Freeze Protect tubing with 20 bbl. diesel 7. Bullhead Freeze Protect IA with 100 bbl. diesel • 8. Set BPV 9. Test Pack-offs to 5000psi 10. Close ScSSSV Rig Work: 1. MIRU N19AC 2. Pull BPV ° 3. Open ScSSSV • 4. Bullhead IA with 100 bbl. treated/filtered seawater . 5. Bullhead Tubing with 350 bbl. treated/filtered seawater 6. Close ScSSSV and P 7. Set BPV d-16st dart 8. ND Tree/ NU BOPE e 9. Test BOPE to 250psi low/350 0psii high, annular to 2_5_,?1psi it' 10. Pull BPV and test dart �s.w 11. Bullhead Tubing with 350 bbl. treated/filtered seawater(� �N • 12. Monitor fluid level or confirm well on vacuum 13. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 14. BOLDS 15. Break tubing hanger free 16, Continue to pull and release packer 1,/ 17. Allow elements relax 18. Monitor fluid level or confirm well on vacuum 19. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 20. POOH with 2-7/8" ESP string and LD 21. RIH with bit, scraper and magnets to 2750' MD - 250' MD below packer setting depth 22. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation • 23. POOH Cleanout BHA 24. PU and RIH with 2-7/8" ESP upper completion as per attached schematic, with OV installed in GLM#1 25. Drop Ball-Rod 26. Set packer ,r 27. Pressure test tubing to 3500psi, Pressure test IA to 3300psi ti 28. Shear SOV in GLM#3 29. Freeze protect tubing and IA with diesel to 2,500' TVD 30. Close ScSSSV 31. Set BPV, test from below 32. ND BOPE/NU Tree 33. RDMO N19AC • • 3 Post Rig (Slick-line): 1. Pull Ball-Rod 2. Pull SOV from GLM#3 3. Set DV in GLM#3 4. Pull RHC Reservoir Pressures: Nuiqsut Pressure: 1,800 psi at 6,350' TVD after 30 days of shut-in = 0.28 psi/ft. = 5.5 ppge Maximum surface pressure: 1,800 psi at 6,350' TVD reservoir pressure with 0.1 psi/ft. gas gradient = 1,165 psi MASP ODSN-31 Nuiqsut Bottomhole Pressure Build Ups 3,500 —2009 Initial Pressure 3,000 — Seawater(8.55 ppge) —LVT/Diesel(6.8 ppge) 2,500 —06/10/14 PBU M vs 2,000 " •• 09/03/16 PBU est'd from WHP a ........••••.• 7 •• ` ••• •.+�• • • • • • • • • • • • • • • `• • • - '" •0. ••• Expected Pressure Build Up N1,500 •'" • •..�---- v a • —N25 PBU 06/29/15 • on 7 1,000 u O ce 500 0 0 5 10 15 20 25 30 Shut-in Time, Days • • 4 Original Well Schematic: ODSN-31 Final Well Completion Final 8-5-2014 No. Upper Co4rpktii MDtftt Tv ftt Li 'i9 Ovaj 7..40h3-T f 34 34 16"Conductor 8'°T4rT"'r'� 3 i-E3 IL '4555. nt pill.totopl '5.•% 4 .=-8'eT-911 4- ' - -; 15'.!-0 GLUE - 2.375 5 :s eT-61 T7r'g L: _, , ,:x :ai 3 •a ST-1."r Sing :s.$'!1: 9 -1 4 I! ra^' c.h4: :ss: 1: 2=5'IST-1)1'erg 1' }9I*1281 profile 2027 12 3 eT-u'r.7P © 13 ,5 4^C- GLM s, :' 11 3 t9 Tr Tiny GLM r' GL t5 N.pp,wiwt231 prone - 3CC tE 2-7 r 1:1T41T.71.1g DV i' A_to 04,lter Va4e'A7.V, E576 5784 18 6:- P"7*-3 Meter aro.ewe`^ E 5— 5-t2'1 0e.- E:v z'c 334-2, 5 3-9 5.u'�8 IX �, {�-/ No. Lower Coag khan MD(ft) 11/015t) '9 h"�64'k 6 a2 Seeve 155 -12 E'56 O22 ,y r-.\--..re�I±7 Pt r 3-3Y! 59 . 113 "9: GLM#2 GL — 2. ,� -? =x3crg y c Set..re•-a-ger 23-3:3 x s 'S: uE E,y, DV 22 4 cw--A VI 521PC. . w . hkx e' -457 E'91 Evxfu&',, -467 E'9- 9-5/8"40#L-80 23 A P!R le 93(7c Skeve 158 452 E 194 BTC Surface .i h`' 'LrerToe Pt 'iEs E tri X .5 hz"P-'?-ri0t3thg-Y09e?LeK-af*gPr 7371 6'.99 Casing 3,131'MD/ -€ 4-1 Z 12E)....-SC-:cti R,7a 41_Pc:4W w'6.2 roes 7 870 E 2-4 3,036'TVD 4-1.7 12 600 LA0-,cts Pupa at Pelee w 6 1 2 roes 3 706 E 177 23 4-17 12 609 L-ec-.CtliP.0 et PC5eew 6•.2roes 822 63C' GLM#1 GL _ ® 29 1-1:2'12600:-92-r1GP,,, 41 PCaeew 6•2roes 3 12' 65' 3: 1-1<126Y-AC-, Rit ro * 7aPeeeew 6•: es_ 362' E 1/4"QV 3' 1- '126L- 41 Potee w'612'1095, 3 Ea 6293 32 4-1:2'12601.4,30 7,00 Pupa at Potec* 61.2 roes'. 9341 5265 33 4-1'7'12 605 LAC-,cet P.7a Al POtee w 6•2 roes 9 257 6 2— ® 34 4-1:7'1263 L- -AO Ir.,{,�c41Pelee* 6':2'+ces 9462' E"3 X 35 1-1:2'12 600 LA0 nee WOa it Pace w 6•,:2 rots' 9 669 s 265 36 4-1 7'12 60■LAO nese P,,0,41 Pate:w 6 1:2 roes 9 387 t 252 3' 4-1 7'12 600 LA0-,CB P.pa 41 Pote0 w 6 1:2 roes' '0 792 6 24' 33 4-1:7'12 600 E-6D-,ell Pupa at.PoteC w 6 1,2 roes; 10 301 €223 39 4-1:7'12 604 LA0 Oel Puog at Potec re 6•'2 roes 10 5': E 27E ill 47 4-1.7'12504LA0-Cel Put*al.Potec i 6•2roes '0"E 6'9' 1• 4-1:7'12600LA0-jC111Pup¢41 POtetw:6'.2roes. '0925 E'9' 000 42 1-1:7'12609190-"iC*Pupa LI Potec'w 6':2 roes 1' 121 E22" 13 4-1.7'12 600 L-80 ,COC RI*4'Pelee* 6 1:409s. 5 22' 11 4-1.2'12 600 LAD-:jcet Puoa it:Pote0 w'6 t;2 rots, ''530 6 2.30 45 4-1'7'12 600 L110 fee PUPA 41 Po8e0 w 6 1'2 rots •'737 E 232 1g - s`` 1E 4-17'Y2600 LAD"`rc O $ 6 t Puit Pot.:w: •:2 rols: 1936 E 23E O C 4' 4-1.7'12 6014 LAD-103 P,pa 41'Pete:9'6 1,2 roes 12 140 E 235 48 1-1.7'126:14L610-4 Cie P,pa41 P0te0w'6' roes 12 350 E;;5 19 4-1.2'12 604 LAD-(CM P.pa it Pett:* 6 1-:roes12 5'3 E 2'2 57 A 5-aere9*OwSaw Swe11P3tter9.Speag+x•CMaaue 1265- 62X _ ,t.'Genesis Oil Sue Swe II 0 act erw.5 ohs lice r Cento ne 1275E 6 199 19 4-17'12604 LA0-IC*Pupa 41 P0te0* 61'2 roes' •2951 E19' l 4-1 7'12 604 L-90-.',009 R:aa at PoteC w 6 1.2 roes; 13 43- 6=4 2) 2 4-v2" 12.60#L-80 Tubing 54 4-1 7'126CN LS7-As Pupa 41 Pete:w'6 1 2 roes3 9'E e'47 4-12't26L7 LA0-•;CmP pf it Pcatl:w 61:2 rots' 'a 09 E'8- 21) (Lower Completion) !E 4-1 Z 12 604 LA0-'e P,71 41 Peaea w 6 1 2'Ats '4 39' 6•'S O4-1:7'12601L-30-rc9.P-05 at Pelee* 6•-2roes 45 367 E•47 23 58 Lre 3roe P. 555 E'9C fro Tftsem 5'v _,., E'47 24 / 551 ' _2 0 M 0 \ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 D 0 0 0 0 0 0 0 0 0 0 0 0 0 02 1 N. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7"26# BTC-M 26 CO ISL 52 — — — Intermerme diate — — J Casing 7,606'MD/ 6,234'TVD #26-49(24)Pups Spaced-200'Apart 6-1/8" Hole TD at 15,363'MD/6,189'TVD • 5 Proposed Well Schematic: ODSN-31 Final Well Completion DRAFT 6-6-2017 I '--- A▪ GE 7.0e0lime 31 34 �I E 2-7 5 6 a Loo 8T-40 Tong I 16"Conductor 2-:.s tE'TRW w2 x Prate-15 P40To;8ectbin-coxa to,.,10. - ��,�� ' : J 2-8'6411L-838741;ors ,•ww+� E 3.7.511-GL.t3 EG:-5 atn.KEW Gw ttt P up Top a 50841% e _-'.8'64eLaoET-.,;lona -17 tFT rg00^;+0:1ESP PaJ4t&014vsntvanw 2 560 J E - 2-.8'6 4$L-80 8 T-4.1 T O 2-71'11'OLP a EIK-5* .KBMGwttt-Pup Top&Botci1 2S6; 2-.8'6 41 L-80 8T-4A era SLB 'x 11pp;2:1S-w.'1SPup Top&Bottom � • 2-.8'6 4i Lao 87-64 Tupng i"t 1-GL44113K-5*tn,K8NGet 11 Pup TOP e.: IM-,, K t 2-.8'6 411 L-80 0 0-41' q 2ats-Ctensicy elector VaNe 14n+4lt#tnjact5on)-3' dna 16 surfloa $55.3 P 2.7.8'61$L-ao a T-t,3 7204'10 518X142:1;'22 S'rt-Ccw't r. PupTop&eottt4l 511; 1 2-7.8'61$L-00 137-44"'Jo i Aut ItwerterValve 9.10 E3?Pump A446na*sr 6,t End daa.rnbei E 179 6 119 a4a. Lmwcr t tx4-t .«t:-tis, thQakJ ' Tir"0 14 19 nz':5_'e=ll!See*151 '12' 6 188 2C 'A'=T �' _^er 1 PR r"7-23-33$45 151 744 3 6 192 2-7/8"6.5#L- 9-5/8"40#L-80 'APT a-4 %Van";-rs Set_ne'-.r-..e- 22--32",.! 'IS ?43E 6 193 80 IBT-M BTC Surface .- 4-1.2 '2s=.-s -r cm 52'P.0 4* =.t eles-de 7453 6194 Eroc;,,i sser a'� 7 460 6 197 Tubing Casing 3,131' 23 ,ti=rPER.neE3, See*151 7452 6 194 (Upper MD/3,036'TVD 24 ,TT 1T-' _e Too Ptr 74E5 E'99 Completion) newT P.-4 wiling-,e se miner-ager 7471 6'99 Com p ) 26 3-t.:'126011 Lao^*r on!P,.o6 41 Ported w'6 12 roes; 7800 6 rd 27 4-1.2'126011 Lao-'0*P.OR#t Parted w'6 1 roe6' 8306 6 300 GLM#1 Et,i) J 28 4.1.2'1260►Lao--ydnl PAR 41 Ported w'6 12 roe6} 8214 6 3G' DGLV 29 4-1.2'13601 Lap-rdnl P„pr 4t Ported w'6 12*dee; 8421 6 Zr 30 3-1.3'12606 Lao-rte Rog 4t Ported w'6 1.2 roes' 8E2- 6 5e 31 3-1.2'122606 Lao-roll PLO*#t Ported w'6 12 roes' 8835 653 32 4-1.2'12 601 L-80-gto PLO*LI Ported w'6 1 roes: 9:;41 6 288 33 Yt.:12 601A L-e2.•' w P o,F et Ponta w'6 12 roe6: 9257 6 Chemical 34 4-t.2'12601 Lao"0016 PL4t*4t.P vvc w'6 12 1oe6: 9 46 2 6 273 Injection Clv 35 4-1.2'12606 Lao waw PAif n Paten w'6 12 roP6; 9669 6 366 1 O 36 4-1.2'12601 L-80-row P.m#t Parted w 6 12 roes; 9880 6 26 Valve 37 4-1.2'12606 Lao-rte Pun*et Ported we 6 12 roes 10 09C 6 341 (Annular 38 4-1.2'12601 Lao-row Plot#t Ported w;6 12 roes: 10 301 6=3 39 4-1.2'12606 Lao...yam4t Ported w'6 12"Cu; 10 512 6:JE Injection) xN Q 40 4-1.3'12601 Lao-vin Roe 4t Paten w'6 12 vet,' 10 716 6 197 41 4-1.3'12601 Lao-ads PLO*4t Ported w'6 12 roes '095 6 19' 0 0 0 42 4-1.2'12601 Lao-ids%dig t Ported w'6 12 roes: 11 124 6 207 T 43 Yt2'126011 Lao-,dn!Pott 411 Ported w 6 12 rots; 11 325 6 41 44 4-1.2'12601L-0-ri*Roe 41pave If'612•»es' 1153C 6230 45 4-1 2'12 601vLai-x011!Pti.o,ft et Ported v4 5'2 roes; 1'737 6 232 46 4-1.2'12 601Lao..foe PAX et Ported w'6'2 10144. '1 936 6 235 47 4-1;2'12600 Lao-rdn!P.M 4 Ported v6'.2 n0es'. 2''4C 6 235 48 4-1.2'12600 L-80-ton!DA;#t Porten w 6 12 roes; 6 226 49 4-1,3'12600 Lao gall Rvf 4t Ported w'6 1.2+nes; ^2 513 6 212 50 Piller* _ca' 6 270 'WT / 19 51 Genesis On 6t Bait 5h Padre rw.'Spaa *dRoer C* I *r '65 6 195 , 20 52 3-t 2 26011 Lao Mice Pixie LI Ported w 6 12 roes} 2.964 6 19' 4'/z" 12.60# 53 3-t 2 1260 Lao 'iw P ort 11 Patna w 6 1:vas: 43- 6 224 D 21g 51 4-1.2 26011 Lao'✓adnl;wit 41 Parted w 6 12 roes; 91€ 6 190 L 80 Tubing 55 44: 26011 Lao moron P pR t1,Forte:w 6 12 Wolf; t 179 6 187 23 / (Lower 56 4-1.2 2636 Lao'~r0I6 P_pR et Ported w 6 roes. '439' 6/TE Completion) 57 3-1. .6 a•Lao-vane Pa►41 Ponta w 6 .2 roes' '5 3550 6 193 24 58 Lner Sr PL. ..E7 15 355 6 190 + 3 i! Ero a,Amac 0'y 15 358 6 19C 22 4 i??• ri a 2 1 \ 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 0 0 0 0 0 0 0 0 0 7"26#L-80 BTC-M Intermediate \ - 26 0 la C" 0 - - - ® - Casing 7,606' MD/ 6,234'TVD #26-49(24)Pups Spaced-200'Apart 6-1/8"Hole TD at 15,363' MD/6,189'TVD • • Attachment 2 n, ., e ,,,r�z«r,,,,uairrzu�a✓rrv�w^,a��,or,,,.,u�m. . r„w ,zn;�;,c.r��m,w,,,i.s✓mafrv�u�✓ru;.o,,, ,.�:,. „ .o,,...>,,.�,,.,,a.mw.aa,�oo-«,.� AOGCC Form 10-403 Sundry Application Box 11 - Perforation Locations Well: ODSN-31 Top(MD) Top(TVD) 4-1/2" Perforated Pup (Ported w/6-1/2" Holes) 7,800 6,274 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,006 6,300 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,214 6,301 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,421 6,297 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,627 6,295 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 8,835 6,293 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,041 6,288 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,250 6,277 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,460 6,273 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,669 6,266 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 9,880 6,260 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,090 6,241 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,301 6,223 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,512 6,206 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,716 6,197 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 10,925 6,197 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,124 6,207 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,325 6,221 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,530 6,230 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,737 6,232 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 11,936 6,236 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,140 6,235 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,350 6,226 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,513 6,212 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 12,964 6,197 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 13,437 6,224 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 13,916 6,190 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 14,409 6,187 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 14,897 6,176 4-1/2" Perforated Pup (Porter w/6-1/2" Holes) 15,350 6,190 • S Attachment 3 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-31 SSSV MD TVD HES 'NE' TRSSSV w/"X" Profile 2,020 1,986 PACKERS MD TVD WFT Hydrow II Packer 2,504 2,441 WET"NTH" Liner Top Packer 7,443 6,192 WFT"NTH" Liner Top Packer 7,468 6,199 WFT Genesis Oil Base Swell Packer 12,657 6,200 WFT Genesis Oil Base Swell Packer 12,768 6,199 Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site ODSN-31 PN6 Permit to Drill: 208-003 API: 50-703-20565-00 Definitive Survey Report 27 July, 2009 Ix Sperry Drilling Services 0 • 0 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-31 -Slot ODS-31 Project: Oooguruk Developement TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-31 North Reference: True Wellbore: ODSN-31 PN6 Survey Calculation Method: Minimum Curvature Design: ODSN-31 PN6 Surveys Database: .Pioneer Alaska Project Oooguruk Developement Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well ODSN-31 -Slot ODS-31 Well Position +NI-S 0.0 ft Northing: 6,031,090.65ft Latitude: 70°29'45.644 N +E/-W 0.0 ft Easting: 469,906.38 ft Longitude: 150° 14'45.872 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-31 PN6 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 6/16/2009 22.23 80.81 57,737 Design ODSN-31 PN6 Surveys Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,698.1 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (bearing) 42.7 0.0 0.0 347.93 Survey Program Date 7/27/2009 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 50.0 1,487.0 ODSN-31PB1 PN6 Gyros(ODSN-31B1 I CB-GYRO-SS Camera based gyro single shot 1/27/2009 t 1,529.3 12,698.1 ODSN-31PB1 PN6 MWD(ODSN-31B1 F MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 1/28/2009 1: 12,710.0 15,327.2 ODSN-31 PN6 MWD(ODSN-31 PN6) MWD+SAG+CA+IIFR+M MWD+SAG+CA+IIFR+Multi Station 7/7/2009 12: Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,090.7 469,906.4 0.0 0.00 UNDEFINED 50.0 0.23 331.51 50.0 -6.2 0.0 0.0 6,031,090.7 469,906.4 3.2 0.01 CB-GYRO-SS(1) 100.0 0.25 251.76 100.0 43.8 0.1 -0.2 6,031,090.7 469,906.2 0.6 0.10 CB-GYRO-SS(1) 169.0 0.43 343.80 169.0 112.8 0.3 -0.4 6,031,090.9 469,906.0 0.7 0.34 CB-GYRO-SS(1) 262.0 0.16 285.95 262.0 205.8 0.6 -0.6 6,031,091.3 469,905.8 0.4 0.75 CB-GYRO-SS(1) 354.0 0.33 137.94 354.0 297.8 0.5 -0.5 6,031,091.1 469,905.8 0.5 0.58 CB-GYR0-SS(1) 444.0 1.19 116.18 444.0 387.8 -0.1 0.5 6,031,090.5 469,906.8 1.0 -0.22 CB-GYRO-SS(1) 540.0 1.98 108.58 540.0 483.8 -1.1 2.9 6,031,089.5 469,909.3 0.8 -1.68 CB-GYRO-SS(1) 634.0 3.10 120.03 633.9 577.7 -2.9 6.7 6,031,087.7 469,913.0 1.3 -4.22 CB-GYRO-SS(1) 729.0 6.05 126.40 728.5 672.3 -7.1 12.9 6,031,083.5 469,919.3 3.1 -9.69 CB-GYRO-SS(1) 824.0 7.99 122.44 822.8 766.6 -13.7 22.5 6,031,076.9 469,928.9 2.1 -18.06 CB-GYRO-SS(1) 917.0 7.90 119.45 914.9 858.7 -20.3 33.6 6,031,070.3 469,939.8 0.5 -26.83 CB-GYRO-SS(1) 7/27/2009 3:47:40PM Page 2 COMPASS 2003.16 Build 428 0 • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-31 -Slot ODS-31 Project: Oooguruk Developement TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-31 North Reference: True Wellbore: ODSN-31 PN6 Survey Calculation Method: Minimum Curvature Design: ODSN-31 PN6 Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 1,012.0 8.27 118.80 1,009.0 952.8 -26.8 45.2 6,031,063.7 469,951.5 0.4 -35.63 CB-GYRO-SS(1) 1,106.0 9.40 120.29 1,101.9 1,045.7 -33.9 57.8 6,031,056.5 469,964.0 1.2 -45.23 CB-GYRO-SS(1) 1,199.0 9.49 118.11 1,193.6 1,137.4 -41.3 71.1 6,031,049.0 469,977.3 0.4 -55.29 CB-GYRO-SS(1) 1,296.0 10.25 117.87 1,289.2 1,233.0 -49.1 85.8 6,031,041.2 469,992.0 0.8 -65.99 CB-GYRO-SS(1) 1,392.0 11.01 119.53 1,383.5 1,327.3 -57.7 101.3 6,031,032.6 470,007.4 0.9 -77.56 CB-GYRO-SS(1) 1,487.0 12.15 118.56 1,476.6 1,420.4 -66.9 118.0 6,031,023.3 470,024.1 1.2 -90.09 CB-GYRO-SS(1) 1,529.3 13.73 119.16 1,517.8 1,461.6 -71.5 126.3 6,031,018.7 470,032.4 3.7 -96.30 MWD+SAG+CA+IIFR+MS(2 1,620.0 14.64 119.16 1,605.8 1,549.6 -82.3 145.7 6,031,007.8 470,051.7 1.0 -110.95 MWD+SAG+CA+IIFR+MS(2 1,718.4 16.89 119.20 1,700.4 1,644.2 -95.3 169.0 6,030,994.6 470,075.0 2.3 -128.57 MWD+SAG+CA+IIFR+MS(2 1,813.0 18.92 118.37 1,790.4 1,734.2 -109.3 194.5 6,030,980.5 470,100.4 2.2 -147.58 MWD+SAG+CA+IIFR+MS(2 1,907.2 19.20 119.85 1,879.5 1,823.3 -124.3 221.4 6,030,965.5 470,127.2 0.6 -167.83 MWD+SAG+CA+IIFR+MS(2 2,002.1 18.80 119.79 1,969.3 1,913.1 -139.7 248.2 6,030,950.0 470,154.0 0.4 -188.48 MWD+SAG+CA+IIFR+MS(2 2,096.9 20.46 120.23 2,058.5 2,002.3 -155.6 275.8 6,030,934.0 470,181.5 1.8 -209.81 MWD+SAG+CA+IIFR+MS(2 2,193.6 19.67 120.65 2,149.3 2,093.1 -172.4 304.4 6,030,917.0 470,210.0 0.8 -232.22 MWD+SAG+CA+IIFR+MS(2 2,288.8 19.01 117.26 2,239.2 2,183.0 -187.7 331.9 6,030,901.7 470,237.5 1.4 -252.92 MWD+SAG+CA+IIFR+MS(2 2,382.3 20.12 111.76 2,327.3 2,271.1 -200.6 360.4 6,030,888.6 470,266.0 2.3 -271.54 MWD+SAG+CA+IIFR+MS(2 2,477.4 20.56 107.96 2,416.5 2,360.3 -211.8 391.5 6,030,877.3 470,297.0 1.5 -289.00 MWD+SAG+CA+IIFR+MS(2 2,571.5 19.09 105.64 2,505.0 2,448.8 -221.1 422.0 6,030,867.9 470,327.5 1.8 -304.42 MWD+SAG+CA+IIFR+MS(2 2,666.8 18.62 100.36 2,595.2 2,539.0 -228.0 452.0 6,030,860.8 470,357.4 1.9 -317.47 MWD+SAG+CA+IIFR+MS(2 2,761.3 18.32 97.13 2,684.8 2,628.6 -232.6 481.6 6,030,856.2 470,387.0 1.1 -328.11 MWD+SAG+CA+IIFR+MS(2 2,854.8 18.23 95.92 2,773.6 2,717.4 -235.9 510.7 6,030,852.7 470,416.1 0.4 -337.46 MWD+SAG+CA+IIFR+MS(2 2,949.2 17.64 94.55 2,863.4 2,807.2 -238.6 539.7 6,030,849.9 470,445.0 0.8 -346.11 MWD+SAG+CA+IIFR+MS(2 3,044.7 17.75 94.61 2,954.4 2,898.2 -240.9 568.6 6,030,847.5 470,473.9 0.1 -354.43 MWD+SAG+CA+IIFR+MS(2 3,086.0 17.93 95.06 2,993.7 2,937.5 -241.9 581.2 6,030,846.4 470,486.5 0.5 -358.10 MWD+SAG+CA+IIFR+MS(2 3,142.4 18.38 94.92 3,047.3 2,991.1 -243.5 598.7 6,030,844.8 470,504.0 0.8 -363.26 MWD+SAG+CA+IIFR+MS(2 3,190.7 17.92 94.21 3,093.2 3,037.0 -244.7 613.7 6,030,843.5 470,519.0 1.1 -367.57 MWD+SAG+CA+IIFR+MS(2 3,284.8 17.22 94.01 3,182.9 3,126.7 -246.7 642.0 6,030,841.4 470,547.4 0.7 -375.48 MWD+SAG+CA+IIFR+MS(2 3,380.2 17.43 94.05 3,274.0 3,217.8 -248.7 670.4 6,030,839.3 470,575.7 0.2 -383.36 MWD+SAG+CA+IIFR+MS(2 3,472.3 17.25 94.06 3,361.9 3,305.7 -250.6 697.8 6,030,837.2 470,603.1 0.2 -390.99 MWD+SAG+CA+IIFR+MS(2 3,567.6 17.36 94.49 3,452.9 3,396.7 -252.8 726.0 6,030,835.0 470,631.3 0.2 -398.96 MWD+SAG+CA+IIFR+MS(2 3,662.5 17.86 91.71 3,543.4 3,487.2 -254.3 754.7 6,030,833.3 470,660.0 1.0 -406.46 MWD+SAG+CA+IIFR+MS(2 3,757.3 18.01 88.77 3,633.6 3,577.4 -254.4 783.9 6,030,833.1 470,689.2 1.0 -412.68 MWD+SAG+CA+IIFR+MS(2 3,851.7 18.27 84.60 3,723.2 3,667.0 -252.7 813.2 6,030,834.7 470,718.5 1.4 -417.14 MWD+SAG+CA+IIFR+MS(2 3,947.4 18.83 80.70 3,813.9 3,757.7 -248.8 843.4 6,030,838.5 470,748.6 1.4 -419.63 MWD+SAG+CA+IIFR+MS(2 4,042.5 20.39 73.52 3,903.6 3,847.4 -241.6 874.4 6,030,845.5 470,779.7 3.0 -419.10 MWD+SAG+CA+IIFR+MS(2 4,137.9 21.78 69.15 3,992.6 3,936.4 -230.6 906.9 6,030,856.4 470,812.3 2.2 -415.12 MWD+SAG+CA+IIFR+MS(2 4,232.6 23.46 65.72 4,080.0 4,023.8 -216.6 940.5 6,030,870.3 470,845.9 2.3 -408.45 MWD+SAG+CA+IIFR+MS(2 4,327.6 23.84 59.71 4,167.0 4,110.8 -199.1 974.3 6,030,887.6 470,879.8 2.6 -398.44 MWD+SAG+CA+IIFR+MS(2 4,420.3 25.19 55.18 4,251.4 4,195.2 -178.4 1,006.7 6,030,908.2 470,912.2 2.5 -384.95 MWD+SAG+CA+IIFR+MS(2 4,515.3 27.31 52.52 4,336.6 4,280.4 -153.6 1,040.6 6,030,932.8 470,946.2 2.6 -367.78 MWD+SAG+CA+IIFR+MS(2 7/27/2009 3:47:40PM Page 3 COMPASS 2003.16 Build 42B 0 • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-31 -Slot ODS-31 Project: Oooguruk Developement TVD Reference: 42.7'+13.5 @ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5 @ 56.2ft(Nabors 19AC) Well: ODSN-31 North Reference: True Wellbore: ODSN-31 PN6 Survey Calculation Method: Minimum Curvature Design: ODSN-31 PN6 Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,611.2 29.92 51.61 4,420.7 4,364.5 -125.4 1,076.8 6,030,960.9 470,982.5 2.8 -347.74 MWD+SAG+CA+IIFR+MS(2 4,705.2 32.52 48.67 4,501.1 4,444.9 -94.1 1,114.2 6,030,992.0 471,020.0 3.2 -324.98 MWD+SAG+CA+IIFR+MS(2 4,800.4 35.22 45.42 4,580.1 4,523.9 -58.0 1,152.9 6,031,028.0 471,058.9 3.4 -297.72 MWD+SAG+CA+IIFR+MS(2 4,895.3 37.72 42.03 4,656.5 4,600.3 -17.1 1,191.9 6,031,068.7 471,098.1 3.4 -265.96 MWD+SAG+CA+IIFR+MS(2 4,989.5 39.76 39.56 4,730.0 4,673.8 27.5 1,230.4 6,031,113.1 471,136.7 2.7 -230.37 MWD+SAG+CA+IIFR+MS(2 5,086.3 41.99 36.89 4,803.1 4,746.9 77.2 1,269.5 6,031,162.7 471,176.1 2.9 -189.89 MWD+SAG+CA+IIFR+MS(2 5,180.9 44.48 34.88 4,872.1 4,815.9 129.7 1,307.5 6,031,215.1 471,214.2 3.0 -146.48 MWD+SAG+CA+IIFR+MS(2 5,274.4 45.52 31.84 4,938.2 4,882.0 185.0 1,343.8 6,031,270.1 471,250.8 2.6 -100.08 MWD+SAG+CA+IIFR+MS(2 5,369.8 44.83 29.64 5,005.5 4,949.3 243.1 1,378.4 6,031,328.2 471,285.6 1.8 -50.41 MWD+SAG+CA+IIFR+MS(2 5,464.0 44.33 25.79 5,072.6 5,016.4 301.6 1,409.1 6,031,386.5 471,316.6 2.9 0.34 MWD+SAG+CA+IIFR+MS(2 5,557.3 43.73 20.79 5,139.7 5,083.5 361.2 1,434.8 6,031,446.0 471,342.5 3.8 53.22 MWD+SAG+CA+IIFR+MS(2 5,651.2 45.35 15.28 5,206.6 5,150.4 423.7 1,455.1 6,031,508.5 471,363.1 4.5 110.15 MWD+SAG+CA+IIFR+MS(2 5,745.7 45.20 12.99 5,273.1 5,216.9 488.8 1,471.5 6,031,573.5 471,379.7 1.7 170.38 MWD+SAG+CA+IIFR+MS(2 5,838.8 44.90 13.38 5,338.9 5,282.7 553.0 1,486.5 6,031,637.6 471,395.0 0.4 229.97 MWD+SAG+CA+IIFR+MS(2 5,934.5 44.39 13.56 5,407.0 5,350.8 618.4 1,502.2 6,031,702.9 471,410.9 0.5 290.66 MWD+SAG+CA+IIFR+MS(2 6,028.7 45.44 11.55 5,473.7 5,417.5 683.3 1,516.7 6,031,767.7 471,425.6 1.9 351.12 MWD+SAG+CA+IIFR+MS(2 6,123.3 46.63 10.03 5,539.4 5,483.2 750.2 1,529.4 6,031,834.6 471,438.6 1.7 413.86 MWD+SAG+CA+IIFR+MS(2 6,218.9 48.38 8.62 5,604.0 5,547.8 819.8 1,540.8 6,031,904.1 471,450.3 2.1 479.52 MWD+SAG+CA+IIFR+MS(2 6,314.0 50.17 5.76 5,666.0 5,609.8 891.2 1,549.8 6,031,975.5 471,459.6 3.0 547.50 MWD+SAG+CA+IIFR+MS(2 6,407.7 52.39 4.87 5,724.6 5,668.4 964.0 1,556.6 6,032,048.2 471,466.7 2.5 617.27 MWD+SAG+CA+IIFR+MS(2 6,502.6 52.76 4.32 5,782.3 5,726.1 1,039.2 1,562.6 6,032,123.4 471,473.0 0.6 689.51 MWD+SAG+CA+IIFR+MS(2 6,596.2 53.57 3.63 5,838.4 5,782.2 1,113.9 1,567.8 6,032,198.1 471,478.5 1.0 761.48 MWD+SAG+CA+IIFR+MS(2 6,692.3 56.27 1.58 5,893.6 5,837.4 1,192.4 1,571.3 6,032,276.6 471,482.4 3.3 837.52 MWD+SAG+CA+IIFR+MS(2 6,787.5 58.63 359.75 5,944.9 5,888.7 1,272.7 1,572.2 6,032,356.8 471,483.6 3.0 915.85 MWD+SAG+CA+IIFR+MS(2 6,881.4 61.44 359.19 5,991.8 5,935.6 1,354.0 1,571.5 6,032,438.2 471,483.2 3.0 995.54 MWD+SAG+CA+IIFR+MS(2 6,978.0 63.98 356.64 6,036.0 5,979.8 1,439.7 1,568.3 6,032,523.9 471,480.4 3.5 1,080.02 MWD+SAG+CA+IIFR+MS(2 7,072.0 66.68 354.55 6,075.3 6,019.1 1,524.9 1,561.8 6,032,609.1 471,474.2 3.5 1,164.72 MWD+SAG+CA+IIFR+MS(2 7,165.9 69.47 352.67 6,110.4 6,054.2 1,611.5 1,552.1 6,032,695.7 471,464.8 3.5 1,251.39 MWD+SAG+CA+IIFR+MS(2 7,260.9 72.16 350.92 6,141.5 6,085.3 1,700.2 1,539.3 6,032,784.5 471,452.4 3.3 1,340.84 MWD+SAG+CA+IIFR+MS(2 7,353.7 74.22 350.06 6,168.4 6,112.2 1,787.8 1,524.6 6,032,872.1 471,438.0 2.4 1,429.59 MWD+SAG+CA+IIFR+MS(2 7,449.2 75.06 348.92 6,193.7 6,137.5 1,878.4 1,507.8 6,032,962.7 471,421.6 1.4 1,521.65 MWD+SAG+CA+IIFR+MS(2 7,543.5 75.18 348.59 6,217.9 6,161.7 1,967.8 1,490.0 6,033,052.2 471,404.2 0.4 1,612.81 MWD+SAG+CA+IIFR+MS(2 7,582.5 75.38 348.13 6,227.8 6,171.6 2,004.7 1,482.4 6,033,089.1 471,396.7 1.3 1,650.47 MWD+SAG+CA+IIFR+MS(2 7,650.7 76.51 348.23 6,244.4 6,188.2 2,069.5 1,468.8 6,033,154.0 471,383.4 1.7 1,716.66 MWD+SAG+CA+IIFR+MS(2 7,747.1 79.35 348.69 6,264.5 6,208.3 2,161.8 1,450.0 6,033,246.4 471,365.0 3.0 1,810.93 MWD+SAG+CA+IIFR+MS(2 7,796.5 79.85 349.19 6,273.5 6,217.3 2,209.6 1,440.7 6,033,294.1 471,355.8 1.4 1,859.54 MWD+SAG+CA+IIFR+MS(2 7,844.2 80.67 348.86 6,281.5 6,225.3 2,255.7 1,431.7 6,033,340.3 471,347.1 1.9 1,906.49 MWD+SAG+CA+IIFR+MS(2 7,941.4 84.17 346.87 6,294.3 6,238.1 2,349.8 1,411.5 6,033,434.5 471,327.2 4.1 2,002.81 MWD+SAG+CA+IIFR+MS(2 8,037.3 87.51 345.22 6,301.3 6,245.1 2,442.7 1,388.4 6,033,527.4 471,304.5 3.9 2,098.40 MWD+SAG+CA+IIFR+MS(2 8,131.8 90.72 340.73 6,302.8 6,246.6 2,533.0 1,360.7 6,033,617.8 471,277.2 5.8 2,192.50 MWD+SAG+CA+IIFR+MS(2 7/27/2009 3:47:40PM Page 4 COMPASS 2003.16 Build 428 • • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-31 -Slot ODS-31 Project: Oooguruk Developement TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-31 North Reference: True Wellbore: ODSN-31 PN6 Survey Calculation Method: Minimum Curvature Design: ODSN-31 PN6 Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,230.0 91.32 334.34 6,301.0 6,244.8 2,623.7 1,323.2 6,033,708.7 471,240.1 6.5 2,289.07 MWD+SAG+CA+IIFR+MS(2 8,326.9 91.51 330.89 6,298.6 6,242.4 2,709.7 1,278.7 6,033,794.8 471,195.9 3.6 2,382.45 MWD+SAG+CA+IIFR+MS(2 8,423.6 90.39 323.30 6,297.0 6,240.8 2,790.7 1,226.2 6,033,876.1 471,143.8 7.9 2,472.70 MWD+SAG+CA+IIFR+MS(2 8,519.0 90.89 321.17 6,295.9 6,239.7 2,866.2 1,167.8 6,033,951.8 471,085.6 2.3 2,558.72 MWD+SAG+CA+IIFR+MS(2 8,615.5 90.70 317.83 6,294.6 6,238.4 2,939.5 1,105.1 6,034,025.4 471,023.3 3.5 2,643.52 MWD+SAG+CA+IIFR+MS(2 8,712.1 89.65 318.63 6,294.3 6,238.1 3,011.6 1,040.8 6,034,097.7 470,959.2 1.4 2,727.44 MWD+SAG+CA+IIFR+MS(2 8,807.8 91.20 323.70 6,293.6 6,237.4 3,086.1 980.8 6,034,172.4 470,899.6 5.5 2,812.84 MWD+SAG+CA+IIFR+MS(2 8,904.5 91.38 325.16 6,291.4 6,235.2 3,164.8 924.5 6,034,251.3 470,843.6 1.5 2,901.55 MWD+SAG+CA+IIFR+MS(2 9,000.8 91.51 322.45 6,289.0 6,232.8 3,242.4 867.7 6,034,329.2 470,787.1 2.8 2,989.39 MWD+SAG+CA+IIFR+MS(2 9,097.1 93.86 323.74 6,284.5 6,228.3 3,319.3 810.0 6,034,406.3 470,729.7 2.8 3,076.64 MWD+SAG+CA+IIFR+MS(2 9,194.4 92.36 323.42 6,279.2 6,223.0 3,397.5 752.3 6,034,484.8 470,672.3 1.6 3,165.17 MWD+SAG+CA+IIFR+MS(2 9,290.3 91.62 323.15 6,275.9 6,219.7 3,474.4 695.0 6,034,561.8 470,615.3 0.8 3,252.28 MWD+SAG+CA+IIFR+MS(2 9,387.7 90.57 322.46 6,274.0 6,217.8 3,551.9 636.1 6,034,639.6 470,556.8 1.3 3,340.44 MWD+SAG+CA+IIFR+MS(2 9,483.6 91.45 321.11 6,272.3 6,216.1 3,627.2 576.8 6,034,715.1 470,497.8 1.7 3,426.47 MWD+SAG+CA+IIFR+MS(2 9,579.6 92.81 323.20 6,268.7 6,212.5 3,703.0 517.9 6,034,791.1 470,439.2 2.6 3,512.88 MWD+SAG+CA+IIFR+MS(2 9,676.4 90.44 324.80 6,266.0 6,209.8 3,781.3 461.1 6,034,869.6 470,382.7 3.0 3,601.30 MWD+SAG+CA+IIFR+MS(2 9,708.7 90.56 325.00 6,265.7 6,209.5 3,807.7 442.5 6,034,896.1 470,364.3 0.7 3,631.02 MWD+SAG+CA+IIFR+MS(2 9,743.9 93.02 325.64 6,264.6 6,208.4 3,836.6 422.5 6,034,925.1 470,344.3 7.2 3,663.51 MWD+SAG+CA+IIFR+MS(2 9,772.4 88.83 323.27 6,264.2 6,208.0 3,859.8 405.9 6,034,948.4 470,327.9 16.9 3,689.62 MWD+SAG+CA+IIFR+MS(2 9,814.0 91.73 324.24 6,264.0 6,207.8 3,893.4 381.3 6,034,982.1 470,303.4 7.3 3,727.64 MWD+SAG+CA+IIFR+MS(2 9,869.0 94.56 324.32 6,260.9 6,204.7 3,938.0 349.2 6,035,026.8 470,271.5 5.1 3,777.92 MWD+SAG+CA+IIFR+MS(2 9,965.4 95.15 323.35 6,252.8 6,196.6 4,015.4 292.6 6,035,104.5 470,215.2 1.2 3,865.53 MWD+SAG+CA+IIFR+MS(2 10,046.8 95.58 323.40 6,245.2 6,189.0 4,080.5 244.2 6,035,169.8 470,167.1 0.5 3,939.30 MWD+SAG+CA+IIFR+MS(2 10,061.5 95.40 323.43 6,243.8 6,187.6 4,092.2 235.5 6,035,181.5 470,158.5 1.2 3,952.55 MWD+SAG+CA+IIFR+MS(2 10,093.6 95.52 323.17 6,240.7 6,184.5 4,117.9 216.4 6,035,207.2 470,139.4 0.9 3,981.65 MWD+SAG+CA+IIFR+MS(2 10,158.0 94.27 323.60 6,235.2 6,179.0 4,169.4 178.2 6,035,258.8 470,101.4 2.1 4,039.98 MWD+SAG+CA+IIFR+MS(2 10,254.2 95.28 324.67 6,227.2 6,171.0 4,247.1 122.0 6,035,336.8 470,045.5 1.5 4,127.73 MWD+SAG+CA+IIFR+MS(2 10,350.4 93.84 326.77 6,219.6 6,163.4 4,326.3 68.0 6,035,416.2 469,991.9 2.6 4,216.49 MWD+SAG+CA+IIFR+MS(2 10,417.9 94.82 327.83 6,214.5 6,158.3 4,383.0 31.6 6,035,473.0 469,955.7 2.1 4,279.51 MWD+SAG+CA+IIFR+MS(2 10,444.1 95.22 327.32 6,212.2 6,156.0 4,405.0 17.6 6,035,495.1 469,941.8 2.5 4,304.00 MWD+SAG+CA+IIFR+MS(2 10,477.5 95.29 327.59 6,209.1 6,152.9 4,433.0 -0.3 6,035,523.2 469,924.1 0.8 4,335.11 MWD+SAG+CA+IIFR+MS(2 10,543.6 93.84 326.18 6,203.9 6,147.7 4,488.2 -36.3 6,035,578.5 469,888.3 3.1 4,396.58 MWD+SAG+CA+IIFR+MS(2 10,638.8 92.17 324.36 6,198.9 6,142.7 4,566.4 -90.5 6,035,656.9 469,834.4 2.6 4,484.36 MWD+SAG+CA+IIFR+MS(2 10,736,7 89.64 325.03 6,197.3 6,141.1 4,646.2 -147.0 6,035,736.9 469,778.2 2.7 4,574.25 MWD+SAG+CA+IIFR+MS(2 10,834.5 91.08 327.99 6,196.7 6,140.5 4,727.8 -201.0 6,035,818.7 469,724.6 3.4 4,665.32 MWD+SAG+CA+IIFR+MS(2 10,929.3 88.77 327.52 6,196.8 6,140.6 4,807.9 -251.5 6,035,899.1 469,674.4 2.5 4,754.25 MWD+SAG+CA+IIFR+MS(2 10,955.2 88.73 327.65 6,197.4 6,141.2 4,829.8 -265.4 6,035,921.0 469,660.5 0.5 4,778.58 MWD+SAG+CA+IIFR+MS(2 11,026.3 86.10 326.38 6,200.6 6,144.4 4,889.3 -304.1 6,035,980.7 469,622.1 4.1 4,844.87 MWD+SAG+CA+IIFR+MS(2 11,100.8 86.75 327.69 6,205.2 6,149.0 4,951.8 -344.5 6,036,043.3 469,581.9 2.0 4,914.37 MWD+SAG+CA+IIFR+MS(2 11,122.3 87.06 327.66 6,206.4 6,150.2 4,969.9 -356.0 6,036,061.4 469,570.5 1.4 4,934.50 MWD+SAG+CA+IIFR+MS(2 7/27/2009 3:47:40PM Page 5 COMPASS 2003.16 Build 428 • • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-31 -Slot ODS-31 Project: Oooguruk Developement TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-31 North Reference: True Wellbore: ODSN-31 PN6 Survey Calculation Method: Minimum Curvature Design: ODSN-31 PN6 Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,219.6 85.75 327.62 6,212.5 6,156.3 5,051.9 -408.0 6,036,143.7 469,518.9 1.3 5,025.59 MWD+SAG+CA+IIFR+MS(2 11,315.6 85.38 328.22 6,219.9 6,163.7 5,133.0 -458.8 6,036,225.0 469,468.4 0.7 5,115.54 MWD+SAG+CA+IIFR+MS(2 11,411.6 85.88 329.70 6,227.2 6,171.0 5,215.1 -508.2 6,036,307.2 469,419.3 1.6 5,206.06 MWD+SAG+CA+IIFR+MS(2 11,508.1 91.01 331.59 6,229.9 6,173.7 5,299.0 -555.4 6,036,391.4 469,372.5 5.7 5,298.05 MWD+SAG+CA+IIFR+MS(2 11,563.0 89.95 330.83 6,229.4 6,173.2 5,347.2 -581.9 6,036,439.6 469,346.2 2.4 5,350.68 MWD+SAG+CA+IIFR+MS(2 11,605.7 88.83 330.09 6,229.9 6,173.7 5,384.3 -602.9 6,036,476.8 469,325.3 3.1 5,391.36 MWD+SAG+CA+IIFR+MS(2 11,701.5 89.35 328.98 6,231.4 6,175.2 5,466.9 -651.5 6,036,559.6 469,277.1 1.3 5,482.27 MWD+SAG+CA+IIFR+MS(2 11,798.5 88.28 326.92 6,233.4 6,177.2 5,549.0 -702.9 6,036,641.9 469,226.0 2.4 5,573.37 MWD+SAG+CA+IIFR+MS(2 11,894.5 89.41 323.84 6,235.3 6,179.1 5,628.1 -757.5 6,036,721.2 469,171.8 3.4 5,662.06 MWD+SAG+CA+IIFR+MS(2 11,991.0 90.21 322.41 6,235.6 6,179.4 5,705.3 -815.4 6,036,798.6 469,114.2 1.7 5,749.67 MWD+SAG+CA+IIFR+MS(2 12,087.0 90.15 322.30 6,235.3 6,179.1 5,781.3 -874.0 6,036,874.8 469,055.8 0.1 5,836.27 MWD+SAG+CA+IIFR+MS(2 12,182.1 91.58 323.68 6,233.9 6,177.7 5,857.2 -931.3 6,036,951.0 468,998.9 2.1 5,922.46 MWD+SAG+CA+IIFR+MS(2 12,280.1 92.74 325.78 6,230.2 6,174.0 5,937.1 -987.8 6,037,031.1 468,942.7 2.4 6,012.43 MWD+SAG+CA+IIFR+MS(2 12,376.4 94.67 325.16 6,224.0 6,167.8 6,016.3 -1,042.3 6,037,110.5 468,888.6 2.1 6,101.29 MWD+SAG+CA+IIFR+MS(2 12,473.5 95.22 323.26 6,215.6 6,159.4 6,094.7 -1,098.8 6,037,189.2 468,832.4 2.0 6,189.79 MWD+SAG+CA+IIFR+MS(2 12,552.4 95.92 318.35 6,208.0 6,151.8 6,155.6 -1,148.5 6,037,250.3 468,783.0 6.3 6,259.71 MWD+SAG+CA+IIFR+MS(2 12,570.3 96.15 318.17 6,206.1 6,149.9 6,168.9 -1,160.3 6,037,263.6 468,771.2 1.6 6,275.15 MWD+SAG+CA+IIFR+MS(2 12,663.5 92.23 315.40 6,199.3 6,143.1 6,236.6 -1,224.0 6,037,331.6 468,707.8 5.1 6,354.71 MWD+SAG+CA+IIFR+MS(2 12,698.1 89.30 313.71 6,198.8 6,142.6 6,260.9 -1,248.6 6,037,355.9 468,683.3 9.8 6,383.53 MWD+SAG+CA+IIFR+MS(2 12,710.0 89.59 313.86 6,198.9 6,142.7 6,269.1 -1,257.2 6,037,364.2 468,674.7 2.7 6,393.43 MWD+SAG+CA+IIFR+MS(3 12,766.4 87.66 315.58 6,200.3 6,144.1 6,308.8 -1,297.2 6,037,404.0 468,634.8 4.6 6,440.56 MWD+SAG+CA+IIFR+MS(3 12,862.1 91.47 318.02 6,201.0 6,144.8 6,378.5 -1,362.7 6,037,474.0 468,569.6 4.7 6,522.45 MWD+SAG+CA+IIFR+MS(3 12,958.1 93.00 320.01 6,197.3 6,141.1 6,450.9 -1,425.6 6,037,546.6 468,507.0 2.6 6,606.42 MWD+SAG+CA+IIFR+MS(3 13,056.6 93.86 321.55 6,191.4 6,135.2 6,527.1 -1,487.8 6,037,623.1 468,445.1 1.8 6,693.95 MWD+SAG+CA+IIFR+MS(3 13,154.0 91.68 324.68 6,186.6 6,130.4 6,604.9 -1,546.2 6,037,701.1 468,387.1 3.9 6,782.22 MWD+SAG+CA+IIFR+MS(3 13,248.2 89.71 323.53 6,185.5 6,129.3 6,681.2 -1,601.4 6,037,777.6 468,332.2 2.4 6,868.37 MWD+SAG+CA+IIFR+MS(3 13,344.8 88.34 330.36 6,187.1 6,130.9 6,762.1 -1,654.1 6,037,858.7 468,279.9 7.2 6,958.48 MWD+SAG+CA+IIFR+MS(3 13,441.4 86.31 332.11 6,191.7 6,135.5 6,846.7 -1,700.5 6,037,943.5 468,233.8 2.8 7,050.93 MWD+SAG+CA+IIFR+MS(3 13,538.3 88.50 331.73 6,196.0 6,139.8 6,932.1 -1,746.0 6,038,029.0 468,188.6 2.3 7,143.93 MWD+SAG+CA+IIFR+MS(3 13,565.6 89.15 330.06 6,196.6 6,140.4 6,955.9 -1,759.3 6,038,052.9 468,175.4 6.6 7,170.03 MWD+SAG+CA+IIFR+MS(3 13,605.6 93.03 329.82 6,195.8 6,139.6 6,990.5 -1,779.3 6,038,087.6 468,155.5 9.7 7,208.02 MWD+SAG+CA+IIFR+MS(3 13,634.7 92.87 329.60 6,194.3 6,138.1 7,015.6 -1,794.0 6,038,112.8 468,141.0 0.9 7,235.67 MWD+SAG+CA+IIFR+MS(3 13,731.1 90.51 327.89 6,191.5 6,135.3 7,098.0 -1,844.0 6,038,195.4 468,091.3 3.0 7,326.68 MWD+SAG+CA+IIFR+MS(3 13,827.5 90.27 325.78 6,190.8 6,134.6 7,178.7 -1,896.7 6,038,276.2 468,038.9 2.2 7,416.59 MWD+SAG+CA+IIFR+MS(3 13,924.5 90.64 327.32 6,190.1 6,133.9 7,259.7 -1,950.2 6,038,357.4 467,985.8 1.6 7,506.96 MWD+SAG+CA+IIFR+MS(3 14,020.8 90.96 329.27 6,188.7 6,132.5 7,341.6 -2,000.8 6,038,439.5 467,935.5 2.1 7,597.64 MWD+SAG+CA+IIFR+MS(3 14,117.0 90.33 332.00 6,187.6 6,131.4 7,425.3 -2,048.0 6,038,523.5 467,888.7 2.9 7,689.41 MWD+SAG+CA+IIFR+MS(3 14,215.8 89.78 331.72 6,187.6 6,131.4 7,512.5 -2,094.6 6,038,610.8 467,842.5 0.6 7,784.37 MWD+SAG+CA+IIFR+MS(3 14,309.9 89.84 331.30 6,187.9 6,131.7 7,595.2 -2,139.4 6,038,693.7 467,797.9 0.5 7,874.62 MWD+SAG+CA+IIFR+MS(3 14,407.3 90.84 333.73 6,187.3 6,131.1 7,681.6 -2,184.4 6,038,780.2 467,753.3 2.7 7,968.49 MWD+SAG+CA+IIFR+MS(3 7/27/2009 3:47:40PM Page 6 COMPASS 2003.16 Build 428 • • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-31 -Slot ODS-31 Project: Oooguruk Developement TVD Reference: 42.7'+13.5 @ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Well: ODSN-31 North Reference: True Wellbore: ODSN-31 PN6 Survey Calculation Method: Minimum Curvature Design: ODSN-31 PN6 Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (bearin (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 14,503.5 90.83 334.63 6,185.9 6,129.7 7,768.1 -2,226.3 6,038,866.9 467,711.8 0.9 8,061.91 MWD+SAG+CA+IIFR+MS(3 14,573.7 90.71 336.75 6,184.9 6,128.7 7,832.1 -2,255.2 6,038,931.0 467,683.2 3.0 8,130.50 MWD+SAG+CA+IIFR+MS(3 14,599.9 92.14 336.14 6,184.3 6,128.1 7,856.1 -2,265.7 6,038,955.1 467,672.8 5.9 8,156.21 MWD+SAG+CA+IIFR+MS(3 14,635.7 92.25 336.06 6,182.9 6,126.7 7,888.8 -2,280.1 6,038,987.9 467,658.4 0.4 8,191.22 MWD+SAG+CA+IIFR+MS(3 14,692.6 90.57 337.31 6,181.5 6,125.3 7,941.1 -2,302.7 6,039,040.2 467,636.1 3.7 8,247.00 MWD+SAG+CA+IIFR+MS(3 14,742.8 89.84 338.86 6,181.3 6,125.1 7,987.7 -2,321.4 6,039,086.9 467,617.6 3.4 8,296.50 MWD+SAG+CA+IIFR+MS(3 14,789.9 93.09 337.95 6,180.1 6,123.9 8,031.4 -2,338.7 6,039,130.6 467,600.4 7.2 8,342.87 MWD+SAG+CA+IIFR+MS(3 14,833.4 92.37 334.70 6,178.1 6,121.9 8,071.2 -2,356.2 6,039,170.5 467,583.2 7.6 8,385.42 MWD+SAG+CA+IIFR+MS(3 14,887.8 91.00 337.97 6,176.5 6,120.3 8,121.0 -2,378.0 6,039,220.4 467,561.5 6.5 8,438.71 MWD+SAG+CA+IIFR+MS(3 14,936.3 93.71 336.33 6,174.5 6,118.3 8,165.6 -2,396.8 6,039,265.1 467,542.9 6.5 8,486.28 MWD+SAG+CA+IIFR+MS(3 14,984.3 91.99 336.56 6,172.1 6,115.9 8,209.6 -2,416.0 6,039,309.2 467,523.9 3.6 8,533.31 MWD+SAG+CA+IIFR+MS(3 15,034.3 90.57 338.07 6,171.0 6,114.8 8,255.7 -2,435.2 6,039,355.3 467,504.8 4.1 8,582.41 MWD+SAG+CA+IIFR+MS(3 15,080.5 89.21 335.00 6,171.1 6,114.9 8,298.1 -2,453.6 6,039,397.8 467,486.6 7.3 8,627.73 MWD+SAG+CA+IIFR+MS(3 15,128.9 86.60 334.79 6,172.8 6,116.6 8,341.9 -2,474.2 6,039,441.7 467,466.3 5.4 8,674.83 MWD+SAG+CA+IIFR+MS(3 15,177.7 88.50 333.89 6,174.9 6,118.7 8,385.8 -2,495.3 6,039,485.7 467,445.3 4.3 8,722.21 MWD+SAG+CA+IIFR+MS(3 15,225.4 85.73 333.14 6,177.3 6,121.1 8,428.4 -2,516.5 6,039,528.3 467,424.3 6.0 8,768.29 MWD+SAG+CA+IIFR+MS(3 15,274.5 86.58 334.60 6,180.6 6,124.4 8,472.5 -2,538.1 6,039,572.5 467,402.9 3.4 8,815.88 MWD+SAG+CA+IIFR+MS(3 15,327.2 83.50 335.06 6,185.2 6,129.0 8,519.9 -2,560.4 6,039,620.0 467,380.8 5.9 8,866.95 MWD+SAG+CA+IIFR+MS(3 15,363.0 83.50 335.06 6,189.2 6,133.0 8,552.2 -2,575.4 6,039,652.4 467,365.9 0.0 8,901.66 PROJECTED to TD 7/27/2009 3:47:40PM Page 7 COMPASS 2003.16 Build 428 • • [7 -» ii Li 1 1 a i w 1 SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO.l'il►IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Joe Polya Sr. Drilling Engineer Pioneer Natural Resources Alaska Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Re: Oooguruk Field, Oooguruk Nuiqsut Undefined Oil Pool, ODSN -31 Pioneer Natural Resources Alaska Inc. Permit No: 208 -003 Surface Location: 2975' FSL, 1092' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 4188' FSL, 4021' FEL, SEC. 35, T14N, R7E, UM Dear Mr. Polya: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). • • Pioneer Natural Resources Alaska, Inc. ODSN -31 Permit: 208 -003 41 11 e n 1, . • rman � Chairman I DATED this a; of January, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. q , STATE OF ALASKA 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION I . PERMIT TO DRILL ' t Ails ,� !lit (' as Cents. Commission 20 AAC 25.005 1a. Type of Work: 1b. Current Well Class: Exploratory El Development Oil 0 1 c. Specify if well is proposed for: M nrhnra0e Drill 0 Redrill ❑ Stratigraphic Test ❑ Service ❑ s / Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone %&. , i PSingle Zone 2 /71 Shale Gas ❑ 2. Operator Name: i; 1 'f 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 ' ODSN -31 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 700 G Street, Suite 600 Anchorage, AK 99501 MD: 15,996' ' TVD: 6,396' 4a. Location of Well (Governmental Section): 7. Property Designation: , ",✓/ Oooguruk ni Surface: 2975' FSL, 1092' FEL, Sec. 11, T13N, R7E, UM ' ADL 355036 / ADL 389958 / /Itr.� / ,.. fd Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 5126' FSL, 4882' FEL, Sec. 12, T13N, R7E, UM 417497 1/28/2008 Total Depth: 9. Acres in Property: 14. Distance to Nearest 4188' FSL, 4021' FEL, Sec. 35, T14N, R7E, UM 8320 Property: 19750' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Ice : 5 ,0',S L.. 15. Distance to Nearest Well Surface: x- 469906.38 / y- 6031090.5 / Zone- ASP 4 (Height above GL): 46, , is, 5 48.66 eet .d Within Pool: N/A 16. Deviated wells: N/A Kickoff depth: e A, feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: ?5/ ' legreet Downhole: 3205 psig - Surface: 2513 psig 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H -40 Welded 115' Surface Surface 158' 158' Driven 12 -1/4" 9 -5/8" 40# L -80 BTC 3047' Surface Surface 3090' - 2939' . 513 sx Permafrost 'L'; 203 sx Class 'G' 8 -3/4" 7" 26# L -80 BTC -M 7784' Surface Surface 7827' - 6346' . 329 sx Class 'G' 6 -1/8" open hole 15966' - 6396' - 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch IS Drilling Program el Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat IS Diverter Sketch El Seabed Report ❑ Drilling Fluid Program El 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Joe Polya, 343 -2111 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Vance Hazzard Title Drilling Superintendent / / ; Signature Phone 343 -2116 Date 71`1 f Commission Use Only Permit to Drill API Number: eo Permit Appr val See cover letter for other Number: - D 5�S 50- 703 Date: i Z! / 06 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce co Ibed meths e, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes❑ No ❑ Mud log req'd: Yes No[/ �S O 1 � S� [✓ H measures: Yes❑ No " Dir tional svy req'd: Yesp No[] ES L -e €c ®r.� \ \ b 4 I(s - Ot � 5 �• - �� CA \ 1.k, LA I P S + APPROVED BY THE COMMtSSION , COMMISSIONER DATE: /� Z �� l II 10 -401 Revised 12/2005 0 1 N i Submit in Duplicate ,,,, ? v g 1 ; RECEIVED JAN 1 4 7008 PIONEER Alaska Oil & Gas Cans, Commission NATURAL RESOURCES ALASKA, INC. Anchorage January 7, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN -31 Surface Location: 2975' FSL, 1092' FEL, Sec 11, T13N, R7E, UM X = 469906.38, Y = 6031090.5, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a production well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a production well in the Oooguruk- Nuiqsut formation. PNRA requests the permit to drill based on Pool Rules and an Area Injection Order turned in, but yet to be approved. As indicated in the attachments, the drilling program will entail drilling a directional 12 surface hole to approximately 3,090' MD/ 2995' TVDrkb, where surface casing will be set. An 8 -3/4" directional wellbore will be drilled into and set at the top of the Oooguruk- Nuiqsut interval at approximately 7,827' MD / 6,346' TVDrkb. The horizontal production interval will be drilled to 15,996' MD / 6,396' TVDrkb, the final TD of the well. The proposed casing program will utilize 9%" surface casing and 7" intermediate casing. The injection interval will be left as an open hole completion. The completion will utilize 2 -7/8" tubing and an ESP. It is planned to batch set a series of surface casing strings from ODS Slot 36 to slot 31 to mitigate the risk of wellbore collision and to allow PNRA to run Magnetic Ranging tools to further aid in reducing the wellbore placement uncertainty. As such, PNRA plans to drill the surface casing string for this well and then suspend the well. Additionally, due to seasonal drilling restrictions and the current timing on the PNRA schedule, it may be necessary to drill the intermediate hole, set casing, suspend the well and move over to the next well in the schedule. By doing this, PNRA can ensure that we can get an injector / 700 G STREET STE 600 • ANCHORAGE ALASKA 99501 • MAIN: (907) 277 -2700 OR IGINA L • • Alaska Oil & Gas Conservation Commission January 3, 2008 Page 2 of 3�mw u PIONEER NATURAL RESOURCES ALASKA, INC. producer pair drilled and casing set across the Oooguruk- Kuparuk zone prior to the commencement of the restricted drilling season. If seasonal drilling restrictions preclude PNRA from being able to drill and set casing across the Oooguruk- Kuparuk prior to the commencement of the restrictions, the well will be suspended with the surface casing set until the following winters unrestricted season. Please find 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 per 20 AAC 25.005 (a). 2) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 3) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). e. A summary of the drilling operations. f. A summary of drilling hazards per 20 AAC 25.005 (c) (4). g. A wellbore schematic is also attached visually depicting the proposed well. 4) A copy of the Planned Directional Well Path. 5) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 6) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2s contamination in the drilling mud system will be maintained on the ODS. 700 G STREET, STE. 600 • ANCHORAGE, ALASKA 99501 • MAIN. (907) 277 -2700 • • Alaska Oil & Gas Conservation Commissio January 7, 2008 co Page 3 of 3 ° d ` PIONEER NATURAL RESOURCES ALASKA, INC. In the future, PNRA will provide information and permitting requesting annular disposal of drilling wastes on this well. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Joe Polya, Senior Drilling Engineer (20 AAC 25.070) 907/343 -2111 joe.polya @pxd.com 2) Geologic Data and Logs Tavia Jackson, Senior Operations Geologist (20 AAC 25.071) 907/343 -2133 tavia.jackson @pxd.com The anticipated spud date for this well is January 28, 2008. If you have any questions or require further information, please contact Joe Polya at 907/343 -2111. Sincerely, 4 ', ;,,,,,,,, 41 nce Hazzard Drilling Superintendent Attachments: Form 10 -401 Supporting permit information cc: ODSN -31 Well File 700 G STREET, STE 600 • ANCHORAGE, ALASKA 99501 MAIN: (907) 277 -2700 • • Oooguruk Well Plan Summary: Permit to Drill ODSN -31 — Oooguruk - Nuiqsut Production Well Surface Location: 2975' FSL, 1092' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469906.38 1 Y = 6031090.5 ' 1 Target: 5125.7' FSL, 4882.2' FEL, Sec 12, T13N, R7E, UM X = 471403.19 1 Y = 6033234.83 1 6,346' TVDrkb Bottom Hole Location: 4187.7' FSL, 4021.5' FEL, Sec 35, T14N, R7E, UM X = 466839.54 1 Y = 6039945.73 1 6,396' TVDrkb AFE Number: TBD Est. Start Date: January 28, 2008 1 Rig: Nabors 19AC Operating days: 3.9 days Drill Surface and Suspend 6.1 days Drill Intermediate and Suspend 14.6 days Drill Production and Complete TD: 15,996 MD / 6,396 TVDrkb Objective: Nuiqsut 1 Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Ultra -slim hole — Producer Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' - RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' ' Conductor: 157.66' MDrkb - Well Control: Based on calculations below, BOP equipment will be tested to 3,500 psi. Surface Section: • Maximum anticipated BHP: 1314 psi CO 2939' TVDss (Based on seawater gradient of 0.4472 psi/ft) • Maximum surface pressure: 991 psi © surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Intermediate Section: • Maximum anticipated BHP: 3205 psi CO 6290' TVDss • Maximum surface pressure: 2513 psi CO surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Production Hole Section: • Maximum anticipated BHP: 3205 psi @ 6290' TVDss • Maximum surface pressure: 2513 psi @ surface (Based on BHP and a full column of gas from TD © 0.11 psi/ft) Planned BOP test pressure: 3500 psi (annular to 2500 psi) Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 1 of 9 Diverter (see attached schematic): Hydril 21 -1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w/flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 9 -5/8" Surface Shoe Rathole + 20' to 50' from 9 -5/8" shoe LOT 12.0 ppg 7" Intermediate Shoe Rathole + 20' to 50' from 7" shoe FIT 13.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 12 -1/4" hole S ud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 / 150 -200 35 - 50 15 -25 10 —15 unrestricted Final 9.2 -9.6 - 70 -100 25 — 35 15 — 25 10 —15 <12 Intermediate Hole Mud Properties: 8-3/4" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 8.8 -9.3 -, 40 -60 15 -25 15 -20 <12 6 -8 HRZ to TD 11.0 - 40 -60 15 -25 20 -30 <15 3 — 5 (8-10 HTHP) Production Hole Mud Pro rties: 6 -1/8" hole Baradril -N Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 10.4 40 - 60 15 - 25 15 — 20 0 <4 Disposal: Annular Iniection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44 Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1-44 Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 2 of 9 Hydraulics: Surface Hole: 12 -1/4" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf to BPRF 550 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 BPRF to TD 650 4" 15.7# 110 2400 10.2 N/A 18,18,18,16 .942 Intermediate Hole: 8- Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf Shoe to TD 550 4" 15.7# 215 3500 11.0 N/A 5x16 0.982 Production Hole: 6-1/8" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Int Shoe to TD 275 4" 15.7# 275 2800 11.57 N/A 3x14 0.451 Formation Markers: Formation Tops MD TVD (ss) Pore Press. EMW Comments (Psi) (PPM Base Permafrost 1678 1600 Top West Sak 2423 2309 1044 8.7 Tuffaceous Shales 3090 2939 Hue Shale 4238 3970 Top Torok Sand 5538 4996 2260 8.7 Top of Disposal Zone Base Torok Sand 5877 5264 Base of Disposal Zone Top HRZ 6482 5700 Base HRZ 6657 5810 Top Kuparuk C 6952 5975 3045 9.8 Base Kuparuk C 6971 5985 Top Nuiqsut 7827 6290 3205 Base Nuiqsut (heel) N/A 6380 Not penetrated Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 3 of 9 • Logging Program: 12 -1/4" Section: Drilling: Mud logging / Magnetic Ranging on the adjacent well Dir /GR Open Hole: N/A Cased Hole: N/A 8 -3/4" Section: Drilling: Mud logging Dir / GR / Res / Dens / Neut Open Hole: N/A Cased Hole: N/A 6-1/8" Section: Drilling: Mud logging Dir / GR / Res / Dens (Azm) / Neut Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkbiTVDrkb 24" 16" 109# H -40 Welded 115' Surface 157.7' / 157.7' 12 -'/4" 9 -5/8" 40# L -80 BTC 3047' Surface 3090' / 2939' 8 44' 7" 26# L -80 BTC -M 7784' Surface 7827' / 6346' 6 -1/8" OH N/A N/A N/A N/A N/A 15966' / 6396' Tubing 2 -7/8" 6.5# L -80 IBT -M 7634' Surface 7677' / 6307' Casing Properties Size Weig Grade ID Drift ID Conn. Internal Collapse Tensile ht Yield (psi) Strength (psi) Joint 1 Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 9 -5/8" 40# L -80 8.835" 8.679" BTC 5750 3090 916 M 916 M 7" 26# L -80 6.276" 6.151" BTC -M 7240 5410 604 M 604 M Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 4 of 9 • • Cement Calculations: Casing Size: 1 9-5/8" Surface Casing - single stage Basis: Lead: 250% excess over gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 2590' MD (500' MD above shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 379 bbls / 513 sx of 10.9 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 43 bbls / 203 sx of 15.9 ppg Premium "G" + adds. 1.18 cf /sk, 5.23 gps water req. Displ 216 bbls Seawater Temp BHST -55° F, BHCT -60° F estimated In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. During drilling operations, should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar will be run in the casing string and a staged cement job will be performed, if needed. Casing Size: 1 7" Intermediate Casing - single stage ** 1 Basis: Lead: 1789' of open hole with 30% excess Lead TOC: -5038' MD (500' MD above top of disposal interval) Tail: 1000' of open hole with 30% excess, plus 85' shoe track Tail TOC: -6827' MD (1000' above the shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 11.5 ppg Dual Spacer Lead 62 bbls / 148 sx of 12.5 ppg Premium "G" + adds. 2.36 cf /sk, 13.38 gps water req. Tail 38 bbls / 181 sx of 15.8 ppg Premium "G" + adds. 1.18 cf /sk, 5.18 gps water req. Temp BHST - 165° F at 6100' TVDrkb, -135° F BHCT * *This well is within Y2 mile of the disposal well at the well path intersection with the disposal zone and will need the calculated top of the cement to be 500' MD above the top of the disposal interval. Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 5 of 9 • 1 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. 2. The Oooguruk Drill Site Class 1 / Class 2 Disposal Well, ODSDW1 -44, has been drilled and commissioned for disposal. 3. Surface Slot 32 should have the surface casing set due to the need to have magnetic ranging tools run in it to reduce the risk for collision while drilling the surface hole of slot 31 Riq Activity: Batch Drill Surface Hole and Set Surface Casing 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up and function test the 21 -1/4" diverter system prior to spud. (Notify the AOGCC Field Inspectors 48 hours prior to diverter function test). 3. MU 12 -1/4" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point at -3090' MD / 2995' TVDrkb, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 9 -5/8 ", 40# surface casing - a Port Collar may be run based on hole conditions at Company Rep discretion. Displace the cement with seawater. 5. Ensure floats are holding. WOC if needed. 6. RIH with enough drill collars and HWDP to displace a volume equivalent to the pipe displacement of 2100' of 3 -1/2" tubing. Note: This is to remove the seawater from the upper part of the 9 -5/8" casing and allow for the installation of a 3 -1/2" or 2 -7/8" tubing circulation string. 7. ND Diverter and NU wellhead. 8. RIH with enough 3 -1/2" or 2 -7/8" tubing to allow for the circulation of diesel freeze protection fluid to -2000' TVDrkb. 9. Land the tubing and RILDS. Install TWC. 10. NU Tree and test. 11. Pull TWC. Circulate diesel freeze protection fluid to freeze protect the well to -2000' TVDrkb 12. Temporarily suspend the well. RDMO. Note: With the conductors on 7' centers, the well will be temporarily suspended due to the need to batch drill the surface casing strings. Batch drilling of the surface casing strings will aid in avoiding a wellbore collision along with reducing the hazards associated with a wellbore collision, should one occur. Rig Activity: Batch Drill Intermediate Hole and Set Intermediate Casing 1. MIRU to ODSK -31. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 2. Install TWC. ND Tree and NU BOPE. Test BOPE to 250/3500 psi. 3. Pull circulation tubing string from the well. 4. MU 8 -3/4" directional drilling, MWD /LWD assembly. RIH and cleanout the casing to landing collar. Displace the well over to intermediate hole drilling fluid. 5. Test the 9 -5/8" casing to 3,500 psi for 30 min. 6. Drill out shoe tract, cement, rat hole and 20' of new formation below 9 -5/8" shoe. Pull the bit back into the 9 -5/8" casing and perform LOT. 7. Drill 8 -3/4" intermediate hole to casing point at -7827' MD/ 6346' TVDrkb. Circulate and condition the drilling fluid to run casing. Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 6 of 9 • 8. Run and cement the 7 ", 26# intermediate casing. Displace the well with seawater. 9. Ensure floats are holding. WOC if needed. 10. RIH with enough 3 -1/2" or 2 -7/8" tubing to allow for the circulation of diesel freeze protection fluid to -2000' TVDrkb. 11. Land the tubing and RILDS. Install TWC. 12. ND BOPE, NU Tree and test. 13. Pull TWC. Circulate diesel freeze protection fluid to freeze protect the well to -2000' TVDrkb 14. Temporarily suspend the well. RDMO to slot 31 to drill and complete the next well. Note: The suspension of the well at this point will allow us flexibility in the drilling schedule and reduce the chances of drilling though a Kuparuk section that is capable of flow to the surface during the seasonally restricted timeframe. Rio Activity: Drill Production Interval and Complete Well 15. MIRU to ODSK -31. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 16. Install TWC. ND Tree and NU BOPE. Test BOPE to 250/3500 psi. 17. Pull circulation tubing string from the well. 18. MU 6 -1/8" directional drilling, MWD /LWD assembly. RIH and cleanout to landing collar. 19. Pressure test the 7" casing to 3,500 psi for 30 min. 20. Drill out shoe tract, cement, rat hole and 20' of new formation below 7" shoe. Pull the bit back into the 7" casing and perform an FIT. 21. Displace the well over to production hole drilling fluid. 22. Drill the 6 -1/8" production hole to TD at - 15966' MD/ 6396' TVDrkb. 23. Circulate and condition the hole to run liner. POH. 24. Run 4 -1/2" Slotted liner on 4" DP 25. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine. POH. 26. MU completion with ESP and RIH. 27. Land the tubing and RILDS. Install TWC. 28. ND BOPE, NU tree and test to 5,000 psi. 29. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u- tube. 30. Drop ball and rod and allow to seat. Pressure test the tubing to 3,500 psi - chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 3,500 psi - chart and hold for 30 minutes. Bleed off pressure. 31. RU Slickline and pull the ball and rod. Pull the RHC -m plug. 32. RD Slickline. RDMO to next well. Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 7 of 9 0 • Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in Y/a bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in /out. Pull up into the casing shoe. 5. Perform a Leak Off Test: • Calculate the required test pressure to reach leak off with the actual • mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 — 0.50 bpm. Maintain a constant rate. • Record the pressure for every 1 /4 of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the Leak Off Test pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 8 of 9 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • A ConocoPhillips well drilled to the south of the Oooguruk development showed communication with the main body of the Kuparuk field. In that well, they took a 2 ppg kick • over planned mud weight - to -12.5 ppg. Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outlined hightened awareness and kick detection o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation/Breathing /Formation Stability • Lost circulation is not expected, but if encountered, consult the Lost Circulation Decision Tree. • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. • A formation study was conducted by GMI which indicated mud weights >12.5 ppg to maintain hole stability across the HRZ above the Kuparuk. Should shale instability be observed, pay close attention to the cuttings returned to surface and attempt to make small changes to mud weight to regain stability. o Splintered shales - indicates the mud weight may be too low o Tabular shales - indicates the mud weight may be too high Kick Tolerance/Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Interval Maximum Influx Mud Exp Pore Min LOT / FIT Volume Weight Press 9 -5/8" Surface / 8 -3/4" hole 35 bbls 10.2 3205 12.0 ppg (LOT) 7" Intermediate / 6 -1/8" hole Infinite 10.2 3205 13.5 ppg (FIT) NOTE: All LOT / FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating Procedures for H precautions should be followed at all times. Faults • No seismically visible faults are expected to be crossed although sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. Fault Location MD TVDss Throw Direction Uncertainty N/A CONSULT THE ODS DATA SHEET AND WELL PLAN FOR ADDITIONAL INFORMATION Pioneer Natural Resources Last Revised: January 7, 2008 ODSN -31 Permit To Drill Page 9 of 9 ODSN -31 Pi luction Well Proposedkompletion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal Vent Valves Control Line 16" Conductor 158' MDrkb / 158' TVDrkb 2 -7/8" ScSSSV, 2.313" ID @ - -750' eZ„ 2 -7/8" GLM @ 3816' MDrkb / 3671' TVDrkb 9 -518 ", 40# L -80 BTC, 8.835" ID 3090' MDrkb / 2995' TVDrkb ■ X Nipple, 2.313" ID @ 3866' MD 7" x 2 -7/8" Packer @ -3906' MDrkb / —3750' TVDrkb X Nipple, 2.313" ID w RHC -M Profile © 3946' MD 2 -7/8" GLM © 7127' MDrkb / 6115' TVDrkb 2 -7/8 ", 6.5# L -80 IBT-M Estimated Top of Cement © 6731' MD / —4751' TVDss ESP Cable 0 0 0 2 -7/8" Durasleeve Sliding Sleeve, 2.313" ID @ 7177' MDrkb • XN Nipple, 2.205" ID Nogo © 7207' MDrkb 65 degrees ESP © 7677' MDrkb 7827' MDrkb / 6346' TVDrkb 6 -1/8" Open Hole Completion 7 ", 26# L -80 BTC -M, 6.276" ID 15996' MDrkb / 6396' TVDrkb �.., Date: Revision By: Comments 1/7/08 JDF /AJB Proposed Completion ' ODSN -31 Producer t � Well Schematic PIONEER NATURAL RESOURCES • • PIONEER Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site ODSN -31- Slot ODS -31 ODSN -31 PN6 Plan: ODSN -31 PN6 wp07 Standard Planning Report - Geographic 19 December, 2007 HA,LLIBURT ©N Drilling and Formation Evaluation �. WELL DETAILS: ODSN -31 REFERENCE INFORMATION / Ground Level: 13.5 Co-ordinate (N/E) Reference: Well ODSN -31 - Slot ODS -31, True North ' 1p HQLLIBURTON ' +N / -S +E/-W Northing Easting Latittude Longitude Slot a (TVD) Reference: 56' RKB @ 56.00 g g MeMeassuu d Depth Reference: 56' RKB @ 56.00 Sperry Drilling Services 0.0 0.0 6031090.65 469906.38 70.496 - 150.246 ODS -31 Calculation Method: Minimum Curvature PIONEER CASING DETAILS WELLBORE TARGET DETAILS (MAP CO- ORDINATES) TVD MD Name Size Project: Oooguruk Developement Drill Site Well; ODSN -31 Name TVD +N / - +E / -W Northing Easting Shape 2806.0 2890.2 9 5/8" 9 -5/8 PN6 v7 T1A 4056.0 -205.1 1016.5 6030881.46 470921.96 Point 6346.0 7827.3 7" 7 Site: 000 urur PN6 v7 T1 6346.0 2150.5 1488.3 6033234.87 471403.18 Point g PN6 v7 T3 6373.0 3838.7 365.3 6034927.48 470287.19 Point PN6 v7 T5 6383.7 5535.8 -791.5 6036629.00 469137.40 Point Wellbore: ODSN -31 PN6 PN6 v7 T9 6396.0 8843.5 - 3103.0 6039945.75 466839.52 Point COMPANY DETAILS: Well Planning - Pioneer - Ooogunil PN6 v7 T7 6406.0 7131.3 - 2010.3 6038229.27 467925.12 Point Plan: ODSN -31 PN6 wpO7 PN6 v7 T2 6431.0 3047.0 1004.7 6034133.28 470923.31 Point Calculat on Method: Minimum Curvature PN6 v7 T4 6441.0 4640.8 -263.4 6035732.02 469661.81 Point Error System: ISCWSA PN6 v7 T6 6450.0 6348.2 - 1364.0 6037443.64 468568.20 Point Scan Method: Tray. Cylinder North PN6 v7 T8 6471.0 8029.5 - 2497.0 6039129.37 467442.15 Point Error Surface: Elliptical Conic Warning Method: Rules Based _ DDI = 6.83 FORMATION TOP DETAILS SECTION DETAILS TVDPathTVDssPath MDPath Formation Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target • 0 - 1656.0 1600.0 1678.3 Base of Permafrost 1 0.0 0.00 0.00 0.0 0.0 0.0 0.00 0.00 0.0 - Start Dir 1.00/100' 400.00' MD, 400.00' TVD 2365.0 2309.0 2423.8 Top West Sak 2 400.0 0.00 0.00 .400.0 0.0 0.0 0.00 0.00 0.0 - _ _ _ - 2947.0 2891.0 3039.3 Hue Shale 3 900.0 5.00 120.00 899.4 -10.9 18.9 1.00 120.00 -19.8 - - - - 2995.0 2939.0 3090.1 Tuffaceous Shales 4 1150.0 10.00 120.00 1147.1 -27.2 47.1 2.00 0.00 -49.3 600 Start Dir 2.00/100' 900.00' MD, 899.40' TVD 4 026.0 3970.0 4238.9 Confining Shale 5 1383.3 17.00 120.00 1373.9 -54.4 94.3 3.00 0.00 -98.7 _ _ _ _ - 5052.0 4996.0 5538.2 Top Torok Sand 6 2038.0 17.00 120.00 2000.0 -150.1 260.1 0.00 0.00 -272.1 _ _ - - - 5320.0 5264.0 5877.5 Base Torok Sand 7 2095.4 19.00 120.42 2054.5 -159.1 275.4 3.50 3.88 -288.2 Start Dir 3.00/100' 1150.00' MD, 1147.10' TVD 5756.0 5700.0 6482.6 Top HRZ 8 3209.3 19.00 120.42 3107.7 -342.7 588.1 0.00 0.00 -618.0 - __ 566 5810.0 6657.3 Base HRZ 9 4277.8 40.00 50.00 4056.0 -205.1 1016.5 3.50 -94.32 -751.1 PN6 v7 T1A 1200 f0° 5956.0 5900.0 6812.0 Kalubik Marker 10 4617.0 37.51 34.20 4321.2 -49.2 1158.4 3.00 - 110.25 -704.8 - End Dir 1383.30' MD, 1373.90' TVD 6031.0 5975.0 6952.0 Top Kuparuk C 11 5738.0 37.51 34.20 5210.5 515.3 1542.1 0.00 0.00 -462.4 Base of Permafrost 6041.0 5985.0 6971.6 Base Kuparuk 12 7627.3 75.00 340.00 6294.2 1968.9 1554.3 3.00 -69.65 721.3 6346.0 6290.0 7827.3 Top Nuiqsut 13 7827.3 75.00 340.00 6346.0 2150.5 1488.3 0.00 0.00 907.9 PN6 v7 T1 1800 f7. Start Dir 3.5/100' 2038.00' MD, 2000.00' TVD 6436.0 6380.0 10708.2 Base Nuiqsut 14 8445.4 89.63 328.47 6428.7 2699.1 1222.3 3.00 -38.94 1510.0 _ - - - - - - 15 8739.4 89.63 328.47 6430.6 2949.7 1068.5 0.00 0.00 1803.4 - _ _ 16 8855.7 90.00 325.00 6431.0 3047.0 1004.7 3.00 -83.90 1919.7 PN6 v7 T2 c _ T op West Sak End Dir 2095.40' MD, 2054.50' TVD 17 9049.3 93.88 320.67 6424.5 3201.1 887.9 3.00 -48.06 2112.9 18 9746.0 93.88 320.67 6377.3 3738.9 447.4 0.00 0.00 2806.1 2400 19 9875.4 90.00 320.50 6373.0 3838.7 365.3 3.00 - 177.42 2935.0 PN6 v7 T3 9 5/8" Start Dir 3.0/100' 8739.40' MD, 6430.60' TVD 20 10041.7 85.01 320.69 6380.2 3967.1 259.9 3.00 177.80 3100.6 o Hue Shale j Start Dir 3.5/100' 3209.30' MD, 3107.70' TVD 21 10583.8 85.01 320.69 6427.3 4384.9 82.2 0.00 0.00 3639.1 t( _ - ` _ _ - - - - 22 10898.0 90.00 328.70 6441.0 4640.8 -263.4 3.00 58.29 3952.6 PN6 v7 T4 .c 3000 _ - _ _ - - - - - End Dir 9049.30' MD, 6424.40' TVD 23 11030.3 93.75 330.00 6436.7 4754.6 -330.8 3.00 19.02 4084.5 Start Dir 3.0/100' 4277.80' MD, 4056.00' TVD 24 11737.9 93.75 330.00 6390.3 5366.0 -683.9 0.00 0.00 4787.9 N T uffaceous Shales 25 11939.0 90.00 325.27 6383.7 5535.8 -791.5 3.00 - 128.38 4988.6 PN6 v7 T5 - PN6 V7 T1 A - - ' 26 12095.2 85.31 325.30 6390.1 5664.0 -880.3 3.00 179.58 5144.6 N 3600 , - Start Dir 3.0/100' 9746.00' MD, 6377.30' TVD 27 12721.4 85.31 325.30 6441.3 6177.1 - 1235.6 0.00 0.00 5768.6 U _ , - 28 12935.6 90.00 320.90 6450.0 6348.2 - 1364.0 3.00 -43.32 5982.5 PN6 v7 T6 34% - End Dir 4617.00' MD 4321.20' TVD -' 29 13037.7 92.91 319.93 6447.4 6426.8 - 1429.1 3.00 -18.39 6084.2 • Confining Shale _ - , - _ - - - End Dir 10041.70' MD, 6380.20' TVD 30 13757.6 92.91 319.93 6410.9 6977.0 - 1891.8 0.00 0.00 6800.3 > - - - -- ' 31 13952.2 90.00 325.00 6406.0 7131.3 - 2010.3 3.00 119.76 6994.7 PN6 v7 T7 N 4200 _ _ - - - ' 32 14265.5 85.18 333.07 6419.2 7399.3 - 2171.2 3.00 120.98 7306.5 2 - Start Dir 3.0/100' 5738.00' MD, 5210.50' TVD ' Start Dir 3.0/100' 10583.80' MD, 6427.30' TVD 33 14786.5 85.18 333.07 6463.0 7862.2 - 2406.3 0.00 0.00 7820.5 I- - TO Torok Sand 34 14977.0 90.00 330.00 6471.0 8029.5 - 2497.0 3.00 -32.58 8009.6 PN6 v7 T8 p - 35 15287.1 94.98 322.13 6457.5 8286.2 - 2669.7 3.00 -57.52 8319.0 " 4800 - ' End Dir 7627.30' MD, 6294.20' TVD-' , End Dir 11030.30' MD, 6436.70' TVD 36 15995.7 94.98 322.13 6396.0 8843.5 - 3103.0 0.00 0.00 9024.0 PN6 v7 T9 Base Torok Sand Start Dir 3.0/100' 7827.30' MD, 634 Start Dir 3.0/100' 12721.40' MD, 6441.30' TVD End Dir 14265.50' MD, 6419.20' TVD 5400 Start Dir 3.0/100' 11737.90' MD, 6390.30' TVD -5400 _ Top HRZ _ A5 End Dir 13037.70 MD, 6447.40' TVD Start Dir 3.0/100' 14786.50' MD, 6463.00' TVD - End Dir 8445.40' MIX 6428.70' TVD End Dir 12095.20' MD, 6390.10' TVD - - - - - - 6000- - Base HRZ re ,' • Start Dir 3.0/100' 13757.60' MD, 6410.90 TVD End Dir 15287.10' MD, 6457.50' TVD -6000 - ' ,, � ' . . _ - - - = Kalubik Marker �_'' i / / : _ _ _ - _ _ _ _ _ _ - - ODSN -31 PN6 wp07 - -6600 6600 _ Top Kuparuk C , ' Top Nuiqsut 7 ,' - . . . • , • Total Depth at 15995.70' MD, 6396.00' TVD - PN6 v7 T2 PN6 v7 T3 PN6 v7 T4 PN6 v7 T5 Ta _ - Base Kuparuk PN6 v7 T11 PN6 v7 T PN6 v7 T71 PN6 v7 PN6 v7 T9 7200- -7200 1 1 1 1 I 1 1 I I r 1 1 1 1 1 1 1 1 I I J 1 1 1 1 1 t 1 I( l i r 1 1 1 1 1 r l 1 l 1 -r , 1 1 1 1 1 1 1 1 1 1 1 1 1 , 1 1 1 1 1 r l I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 r 1 l 1 1 1 r ..r 1 - i rr77 1 1 I ..T f 1 1 IT[1 - 1 - T -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 Vertical Section at 325.00bearing (1500 ft/in) WELL DETAILS: ODSN -31 REFERENCE INFORMATION HALL) B L! RTON G round Level: 13.5 Co-ordinate (N/E) Reference: Well ODSN-31 - Slot ODS -31, True North Vertical (TVD) Reference: 56' RKB @ 56.05 +W.S +E/ Northing Easting Latitude Longitude Slot Measured Depth Reference: 56' RKB @ 56.0ft Sperry 'Drilling Services 0.0 0.0 6031090.65 469906.38 70.496 - 150.246 ODS -31 Calculation Method: Minimum Curvature PIONEER WELLBORE TARGET DETAILS (MAP CO- ORDINATES) COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Name TVD +N / -S +E / -W Northing Easting Shape - PN6 v7 T1A 4056.0 -205.1 1016.5 6030881.46 470921.96 Point Calculation Method: Minimum Curvature Error System: Minimum P N6 v7 T1 6346.0 2150.5 1488.3 6033234.87 471403.18 Point Project: Oooguruk Developement PN6 v7 T3 6373.0 3838.7 365.3 6034927.48 470287.19 Point Scan Method: Tray. Cylinder North, Error Surface: Elliptical Conic Site: Oooguruk Drill Site PN6 v7 T5 6383.7 5535.8 -791.5 6036629.00 469137.40 Point Warning Method: Rules Based Well: ODSN -31 PN6 v7 T9 6396.0 8843.5 - 3103.0 6039945.75 466839.52 Point PN6 v7 T7 6406.0 7131.3 - 2010.3 6038229.27 467925.12 Point - - Wellbore: ODSN -31 PN6 PN6 v7 T2 6431.0 3047.0 1004.7 6034133.28 470923.31 Point Plan: ODSN -31 PN6 wp07 PN6 v7 T4 6441.0 4640.8 -263.4 6035732.02 469661.81 Point CASING DETAILS PN6 v7 T6 6450.0 6348.2 - 1364.0 6037443.64 468568.20 Point 1 PN6 v7 T8 6471.0 8029.5 - 2497.0 6039129.37 467442.15 Point TVD MD Name Size 8800- ODSN -31 PN6 wp07 - - 6346.0 28900.2 9 5/8" 9 -5/8 - I Total Depth at 15995.70' MD, 6396.00' TVD 7" 7 _ I PN 6 v7 I ' T9 r End Dir 15287.10' MD, 6457.50'TVD DDI =6.83 - 8000- - - SECTION DETAILS • - I - - - - - Start Dir 3.0/100' 1478650' MD, 6463.00' TVD Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target 1 0.0 0.00 0:00 0.0 0.0 0.0 0.00 0.00 0.0 IPN6 v7 TS End Dir 14265.50' MD, 6419.20' TVD 1 2 400.0 0.00 0.00 400.0 0.0 0.0 0.00 0.00 0.0 7200- _ - 3 900.0 5.00 120.00 899.4 -10.9 18.9 1.00 120.00 -19.8 - I Start Dir 3.0/100' 13757.60' MD, 6410.90' TVD 4 1150.0 10.00 120.00 1147.1 -27.2 47.1 2.00 0.00 -49.3 5 1383.3 17.00 120.00 1373.9 -54.4 94.3 3.00 0.00 -98.7 - IPN6 v7 T7 1 - _ End Dir 13037.70' MD, 6447.40' TVD 6 2038.0 17.00 120.00 2000.0 -150.1 260.1 0.00 0.00 -272.1 6400- _ _ - 7 2095.4 19.00 120.42 2054.5 -159.1 275.4 3.50 3.88 -288.2 - . Start Dir 3.0/100' 12721.40' MD, 6441.30' TVD 8 3209.3 19.00 120.42 3107.7 -342.7 588.1 0.00 0.00 -618.0 IPN6 -V-771 9 4277.8 40.00 50.00 4056.0 -205.1 1016.5 3.50 -94.32 -751.1 PN6 v7 T1A End Dir 12095.20' MD, 6390.10' TVD 10 4617.0 37.51 34.20 4321.2 -49.2 1158.4 3.00 - 110.25 -704.8 _ _ - - - -- 11 5738.0 37.51 34.20 5210.5 515.3 1542.1 0.00 0.00 -462.4 5600 - - Start Dir 3.0/100' 11737.90' MD, 6390.30' TVD 12 7627.3 75.00 340.00 6294.2 1968.9 1554.3 3.00 -69.65 721.3 - _ 1 13 7827.3 75.00 340.00 6346.0 2150.5 1488.3 0.00 0.00 907.9 PN6 v7 T1 - PN6 v7 T5 End Dir 1103030' MD, 6436.70' TVD 14 8445.4 89.63 328.47 6428.7 2699.1 1222.3 3.00 -38.94 1510.0 _ _ _ _ - 15 8739.4 89.63 328.47 6430.6 2949.7 1068.5 0.00 0.00 1803.4 C 4800- _ _ - - 16 8855.7 90.00 325.00 6431.0 3047.0 1004.7 3.00 -83.90 1919.7 PN6 v7 T2 Start Dir 3.0/100' 10583.80' MD, 6427.30' TVD 17 9049.3 93.88 320.67 6424.5 3201.1 887.9 3.00 -48.06 2112.9 End D r 10041 MD 6380.20' TVD 18 9746.0 93.88 320.67 6377.3 3738.9 447.4 0.00 0.00 2806.1 0 _ 19 9875.4 90.00 320.50 6373.0 3838.7 365.3 3.00 - 177.42 2935.0 PN6 v7 T3 IPN6 v7 T4 - - - 20 10041.7 85.01 320.69 6380.2 3967.1 259.9 3.00 177.80 3100.6 v 4000 _ _ _ _ _ _ Start Dir 3.0/100' 9746.00' MD, 6377.30' TVD 21 10583.8 85.01 320.69 6427.3 4384.9 -82.2 0.00 0.00 3639.1 - - - 22 10898.0 90.00 328.70 6441.0 4640.8 -263.4 3.00 58.29 3952.6 PN6 v7 T4 + I End Dir 9049.30' MD, 6424.40' TVD 23 11030.3 93.75 330.00 6436.7 4754.6 -330.8 3.00 19.02 4084.5 PN6 v7 T3I .0 - - - - 24 11737.9 93.75 330.00 6390.3 5366.0 -683.9 0.00 0.00 4787.9 G 3200- 25 11939.0 90.00 325.27 6383.7 5535.8 -791.5 3.00 - 128.38 4988.6 PN6 v7 T5 _ T2r I Start Dir 3.0/100' 8739.40' MD, 6430.60' TV 26 12095.2 85.31 325.30 6390.1 5664.0 -880.3 3.00 179.58 5144.6 PN6 v7 "1 End Dir 8445.40' MD, 6428.70' TVD 27 12721.4 85.31 325.30 6441.3 6177.1 - 1235.6 0.00 0.00 5768.6 28 12935.6 90.00 320.90 6450.0 6348.2 - 1364.0 3.00 -43.32 5982.5 PN6 v7 T6 2400- - 1 _ 7" 29 13037.7 92.91 319.93 6447.4 6426.8 - 1429.1 3.00 -18.39 6084.2 '� _ _ Start Dir 3.0/100' 7827.30' MD, 6346.00' TVI 30 13757.6 92.91 319.93 6410.9 6977.0 - 1891.8 0.00 0.00 6800.3 31 13952.2 90.00 325.00 6406.0 7131.3 - 2010.3 3.00 119.76 6994.7 PN6 v7 T7 - - IPN6 v7 TII - _ _ - - - - - 32 14265.5 85.18 333.07 6419.2 7399.3 - 2171.2 3.00 120.98 7306.5 1600- End Dir 7627.30' MD, 6294.20' TVE 33 14786.5 85.18 333.07 6463.0 7862.2 - 2406.3 0.00 0.00 7820.5 34 14977.0 90.00 330.00 6471.0 8029.5 - 2497.0 3.00 -32.58 8009.6 PN6 v7 T8 6000 35 15287.1 94.98 322.13 6457.5 8286.2 - 2669.7 3.00 -57.52 8319.0 - 36 15995.7 94.98 322.13 6396.0 8843.5 - 3103.0 0.00 0.00 9024.0 PN6 v7 T9 - Start Dir 1.00 /100' 400.00' MD, 400.00' TVD 800- _ 800 _ F P v7TI _ -,, - Start Dir 2.00 /100' 900.00' MD, 899.40' TVD ■ - - - - _ - - ' St Dir 3.0/100' 5738.00' MD, 5210.50' TVD -0 0 art Start Dir 3.00/100' 1150.00' MD, 1147.10' TVD _ - - - � `I 4 _ _ _ - - _ I ' / / U 1 End Dir 1383.30' MD, 1373.90' TVD - - - / 9 5 /8" $ End Dir 4617.00' MD, 4321.20' TVD --800 -800- Start Dir 3.5/100' 2038.00' MD, 2000.00' TVD ' � _ - End Dir 2095.40' MD, 2054.50' TVD 1 Start Dir 3.0/100' 4277.80' MD, 4056.00' TVD -1600- -1600 - Start Dir 3.5/100' 3209.30' MD, 3107.70' TVD 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 1 1 1 1 1 1 - f 1 1 1 1 I 11 r f I 11 1 1 1 1 1 r 1 1 1 1 1 1 1 1 - 1 1 1 1 I 1 i I 1 1 I 1 1 1 1 1 1 1 I I I 1 1 1 I I 11 I I 1 1 1 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I I -5600 -4800 -4000 -3200 -2400 -1600 -800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 West( - )/East( +) (2000 8/in) SURVEY PROGRAM Well Planning - Pioneer - Oooguruk ANTI - COLLISION SETTINGS Date: 2008 -01- 09T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Interpolation Method: MD, interval: 25.0 Error System: ISCWSA Depth Range From: 0.0 To 15995.7 Depth From Depth To Survey/Plan Tool Scan Method: Tray. Cylinder North Centre Distance: 1799.6 0.0 300.0 ODSN -31 PN6wp07 CB- GYRO -SS Error Surface: Elliptical Conic Reference: Plan: ODSN -31 PN6 wp07 300.0 15995.7 ODSN -31 PN6 wp07 MWD+SAG+CA +IIFR +MS Warning Method: Rules Based ODSN -4 PS3 ODSN-6 PS5 ODSN -31 IS ODSK•71 10 ` ODgN -5i IS' ' ODSN -2 PS' ODSN -27i IN From Color To MD (hearing) vs 0 1 7 , r r ODSN - 26 PN1 ■ ` ■ 1 y:'q/J r g1:4 � - 0 250 � \ 1 1330 � ,•�` ;; .✓/ I�r` 1 ika it , 30 250 -- 500 , r °a'• �� ..•r.;/ ODSN - 5i Ig ODSN - 4 PS ODSN - 3i ISi ODSN - 2 P ::::: ' \ \ " r e a " ►� ` ,y ��' . & ;, MO 750 - _ _ - - - - \� '0 i� ��s if/ 750 1000 - rODSN - 27i IN ODSN- 12 r � - ' r , ` i 1000 1250 i sr _ -26 r`l'•-.7 ' a r e�• ODSN -29i IN 1250 1500 ODSK -71 IS7� r •�0^ f r♦ !• p a • ODSK -33 K� A` `\ / 7`. 1 ' ��+ ° 1500 1750 �/a 400 y� 4 ODSN -29i IN R s , ac i o j5 • a \ ODSN 8 PS � � F ` �\ ` 300 � i Y NN / ' � `` h O + r -4i � ,1 � 10� t r o k% 69 1750 2000 _ .. ''''S,:- 7- ' � ODSK- 35 . yx �. � 4 / . j �� + �" .° `°°° „ ° + V1►i% /k 1 2000 22 50 ODSN -9 , ' : 4 � -, /'/ , � ` , 'n '. '" ; :s i � �� • +i aU 2250 2500 i �� i a ''" ODSN -15 PS111-, A � ► TiS, „ ' - 6 ' � ; ( ii . ° 4 V:SV � �� t 4 O DSN- :vy� (fr�� 1 c a :+, . , 14 4 1 ��,�, r ,' ° ► 2500 2750 p ;�� +� +1 ) 1 + �� + .• ri'1 4 10 • m . 2750 3000 r ' i f �� (i+ ; ,'1` • ODSN - 14i I S1 t ��r , 4+ l j � l j 0tI� t rte d .-. " �. ,:'17.:;:::',--./ `''� " - . i A + 1w + i� 1 V � „� 3000 3250 ° r - i i�.. �.,�,� - s C� r i /► � il� �� 3250 3500 • ODSN -17 PS1 ' / � ODSN - 13 PS1 't r r� 1 . 0 ODSN 6 PS 3599 3750 '' �0 r �(/ g (III i l e . y r - . r i .. • ► r . ■ - ' , + i � �•r �� r7t�� p.rr ��r�" 4 � °�� 9 3750 4000 : , ..910li 4 ��/ -- �, / q ii/ /11/001/ /�/4� uf/// / „.4, •r i w i' 4000 � 5000 /� ODSN - 16i I518 ' &//,'" 1, 1 fl l��I� t c + °� / - : 4: + 0 plfi/ ��1 �f yl o l 5000 -- 6000 ._n�'�l�tlri ,�� r \�� ♦ �j � l 1 r , t , ODSN�2i IN i F " �\ , : ::� ► r�f � �� 4 , AI1 6000 7000 ` �... / + + 1 1 4r 1 =- :�� +t'. 7000 8000 - � M i� ODSK -41i KupG . +++ 'z ,,, s ` , ; ; •:: :•tZr ODSN - 8000 9000 240 120 � 9000 10000 ODSN -37 P 11141. �I 249 I '• 10000 11000 1 ll lr . 1 ii i ` �� 120 1109 ' 0 - 12000 , , 1, • t � JD5x : ■ nu r 1 t �, .r ' V �- , .I " •, 13000 14000 ODSN - PN# 210 i ir : .'..±...g.71%. 1:7;:::•." ;; 4_No __ 'T , ... i iV 15000 14000 - ' . t 150 ODSN.43i IN1 ., I !1 i _ -_ • it 15000 16000 IODS I 180 �' -c'� . `•1 ‘..!,-0`, , 16000 17000 ODSK$61 KupD ODSN 39i IN1 • �. - -- '7 - .0� I) Centre to Centre Separation 140 ft/inl 210 - ., -- - , '".f.: , •;.* _ - - -._ .' � 1 50 17000 18000 ravelling Cylinder Azimuth (TFO+AL ODSN -45 PN74 r ; r4 , 18000 -'- 19000 SECTION DETAILS ' Sec MD Inc A71 TVD +14/-5 +E/ -W OLe9 57202 VSec Target i 180 ODSK -361 Ku 19000 - 20000 1 0.o o00 000 00 0.0 0.0 000 900 00 ODSN-40 PN12 2 21000 2 4000 0.00 000 400.0 00 00 000 000 00 3 800.0 5.00 12000 499.4 -109 189 1.00 12000 -198 ODSN -34I IN 4 1150.0 1000 120.00 11471 -272 471 200 0.00 -49.3 21000 22000 5 1383.3 1700 120.00 1373.9 -54.4 943 3.00 0.00 -98.7 ODSN -38 PN1t1 6 2038.0 17.00 120.00 2000.0 -150.1 2601 000 000 -272.1 22000 0 7 2095.4 19.00 120.42 2054.5 -159.1 2754 350 388 -288.2 8 3209.3 1900 120.42 3107.7 - 3427 588.1 000 000 -618.0 9 4277.8 4000 5000 4056.0 -205.1 1016.5 3.50 -9432 -751.1 PN6 v7 T1A 10 4817.0 37.51 3420 4321.2 -49.2 1158.4 3.00 -11025 -704.8 Travelling Cylinder Azimuth (TFO+AZI) [bearing] vs Centre to Centre Separation [ 100 ft/inl 11 5738.0 37.51 34.20 5210.5 5153 1542.1 000 000 -4624 12 7827.3 7500 34000 6294.2 19689 1554.3 3.00 -69.85 721.3 13 78273 7500 34000 6346.0 21505 1488.3 000 000 907.9 PN6 v7 71 14 84454 8963 32847 64287 28991 1222.3 3.00 -38.94 1510.0 NAD 27 ASP Zone 4 : WELL DETAILS: ODSN -31 15 87394 8963 32847 64306 29497 1066.5 0.00 000 16034 16 8855.7 9000 32500 64310 30470 10047 3.00 -8390 1919.7 PN6 v7 72 17 9049.3 9388 32067 64245 3201.1 8879 3.00 -4806 2112.9 Ground Level: 13.5 18 97460 9388 320.67 63773 37389 447.4 0.00 000 2806.1 +N/-S +E/-W Northing Easting Latittude Longitude Slot 19 98754 90.00 320.50 6373.0 38387 365.3 3.00 - 177.42 2935.0 PN6 v7 T3 9 9 9 20 10041.7 8501 32089 83802 3967.1 2599 300 17780 3100.8 0.0 0.0 6031090.65 469906.38 70.496 - 150.246 ODS -31 21 105836 8501 320.69 64273 43849 -822 000 000 3639.1 22 10898 0 90 00 32870 64410 4640 8 -2834 300 58 29 3952 6 PN6 v7 54 23 11030 3 93 330 00 6436.7 4754.8 -330 8 300 1902 4084.5 24 11737.9 9375 33000 83903 5366.0 -6839 000 000 4787.9 REFERENCE INFORMATION 26 120 2 85 00 1 325.30 6390 5 -8803 300 17966 51144 6 PN6 v7T5 27 12721.4 85.31 325.30 6441 3 6177.1 -1235 6 0 00 0 00 5768 6 28 12935.6 90.00 32090 64500 6348.2 -1364 0 3 00 -43 32 5982 5 PN6 07 76 Co- ordinate (N /E) Reference: Well ODSN -31 - Slot ODS -31, True North 29 13037.7 9291 31993 6447.4 64268 -14291 300 -18.39 8084.2 Vertical TVD Reference: 56' RKB 56.Oft 30 13757.6 92.91 31993 6410.9 6977.0 -18918 000 0.00 8800 3 ( ) erence: 31 13952.2 9000 325.00 8408.0 7131.3 -20103 300 11978 89947 PN6 v7 T7 Section (VS) Reference: Slot - ODS- 31(0.0N, 0.0E) 32 14285.5 8518 333.07 8419.2 73993 -21712 300 120.98 7306.5 Measured Depth Reference: 56' RKB 56.Oft 33 14786.5 8518 33307 6463.0 78822 - 2406.3 000 0.00 78205 p 34 14977.0 90.00 330 00 6471.0 8029 5 - 2497.0 300 -32 58 8009.6 PN6 v7 T8 Calculation Method: Minimum Curvature 35 15287.1 9498 32213 6457.5 82862 -26897 300 57.52 83190 36 15995.7 94 98 322 13 63960 8843.5 - 3103.0 0.00 0 00 9024.0 PN6 v7 Te S • - - - - - Algska State Plane - S?E.tIQ Q • et ..-- - • • - WC11 - 119, -- - --- --- -- -- -- - --- --- -- --? (N) . 1:•219 A U. 409,920,45 - 70 20 40,2'41 - 15 - 0 - 1 - 4 - a - 3035 101 - 15:50 2 0,051,140,55 459,916,52 7Q29461 10. 14 45,60922 5050 1052 1 5 5 ---- e9:09 70 29 - 4 - 571 - 9 -- g5 - 54 I60 14 45,7 3o2e 1087 - 13 - .50 4 .. - 0,05 - 1,1 - 56:40 -- , 169,905,57 -- 7 1 - 0 Zg 460 - 150 1445,09709 5020 1092 ------ 5 6,031,131, 409,900,74 • 70 29 4 .6,vm3 160 14 45,04262 3015 1097 . 13,50 6 - 6,031,126,51 409,395.6V 29 46,99360 • 160 14 3010 1102 13,50 - 7 ' 6,031,115,75 - 469,555,1$ 70 29 150 14 46:55379 207 1115 13,50 ---- 5,031 469,6178.21 729581 15 400505 2992 1120 . 15,50 9 0,0 469, - 673,3 70 39 46.7 T0014 40.54514 2957 1125 - 15,50 10 • 0,051,095,79 460,563,56 20 45,72250 - 160 14 2962 - 1130 13,50 II 3,031,093,84 09,863,30 • 70 29 0,67:-,98 10 1 47.1S70 2971 1105 13,50 • IiiMPAIIIII ..9 q8 47 7 - 9 -- : - 46..6 96 i6014 2972 1140 15,50 15 5,01,070,06 09,346,61 70 29 46,49640 160 14 47,06236 2900 1152 13,5 Ell -5,031 ,071 09 --- 49, - 640,51 - 70 29 45 ,4 1514 41,79.770 2965 1114V:Al 13;50 5,051,066.16 s.9,83,96 - 70 29 46 - 16014 47,94155 2950 11 15,50 16 5,01,061,15 469,831,04 70 29 43,36145 160 1446,03636 2945 MAI 13,50 17 6,031,050,25 469,326,11 70 2946 ,30277 150 14 46:23042 2940 fin 13 ,50 16 --- --- 6,031 -- ,06 - 117 -- 459, - 5:21 -- ,1t - 70 29 1 14 46,37;45 - 2935 1177 • 13.50 ----- 19 5,(/3108, 459,305,60 1024f276 2() - 60:1,01,W - 469,.03 :59 - 70 29 46,07614 160 14 40006i 2917 1194 13,00 11.61. 6,031,029,65 459,7 a: a 70 2:9 - 150 144,VP:02 2912 1199 13,00 MI 6,031,023,56 - 439,793,67 70 29 44,96014 160 14 4918144 2907 1204 13,50 - 6,03 7 1,06,5T -7- -4M736.76 70 3 15Q14493237 - 2902 _ 1209 1350 • 24 6,031,013,60 459,73.3,64. 70 29 44.,36159 160 1.4 -49,45960 2397 1214 13,50 __. .._ _ • ""‘ OF •Ak , . ..W:....- •-• • ...r gi --- ---- -: .. ,------ .4• ---.4 - . .. . % 1 9 7 .!':'.‘ V* 51 / - r. - -- le ii ' • !' •- : ix : 00 g , 1 Philip G. Doris :k , .........,....40..„..,:.. . ...:7......4,.....v.,„*.,,..... . •,:a..,:s; .. , of 1 4 1 VA: 9 % 0 • .0 ar I ' - .. ..t :4. - .3.:-Ar - 4. - ,,, t•tc -.14 - ‘‘....A....../.:" ;-. • .i.t. .w.... 1, rievetion; or toted on VP Mean Sea Level, __ .. 2, Coordinotee ore be Qn Aloeico mote Phone Nod 27, Zorne 4, 3, M conductore ore within Protrooted Section 11, Pioneer N.:Awl-01 Regouces - --- JOB NAME: Opc Drill Site C9ndVctQrS. DRAWN e3Y; OL CHECKED BY: m.0 LOCATION, Prgtrcctcd scctim ii SCALE: N/A Townthip 1 North Ron9e 7 Ecizt DATE; 7-12-0 Urniot Meridion - t\TAIICCT R5 LT SHEET DESCRIPTION: . . Ae-bwit Coordmotes 1 --- 0204 3 of 4 ---- -- - • • Alstke Side Plane Section Line Offset - Welt Y x - -6t a'e4. = - or�c,it -vd, al - � S '' .d -E-1- 25 6,031,128.32 469,943.64 7029 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469,938.69 70 29 45 :96722 150 14 44 .92442 3008 1060 13.50 NM 6,031,118.33 469,933.76 70 29 45.91766 150 14 45.06695 300 1065 .13.50 MU 6,031,113.39 469,928.86. 70 29 45.86887 150 14 45.21260 2997 1070 13.50 29." 6,031, 108.44 469,923.95 , 70 29 45.81999 150 14 45.35655 • 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50. 31 6,031,090.65 469,906.38 70 29 45.64431. 150 14 45.87163 2975 1092. 13.50 ® 6,031,0E5.68 469,901,39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128. 2965 1102 13.50 Mal 6, 031 ,075.73 469,891.57 70 29 45,49698 150 14 46.30581 2960 1106 13.50 ® 6,031,070.76 469,886.60 70 29 45.44789 150 14 46.45152 MOB 1111 • 13.50 36 6,031,065.83- 469,881.69 70 29 45.29921 150 14 46.69547 2950 EMI 13.50 • ,''3170 .. 5 70 20 4 &.27 251 ---1-50 -14-48 6-7x! • 111102MINSTE1111111W5111 ME= 6,031,047.99 4 69,864.14 70 29 45.22304 150 14 47.10995 2932 1134• 13.50 39 6,031,043.03 469,659.20 7029 45.17406 150 14 47.25478 2927 1139 13.50 Man 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 .•1144 13.50 6,031,033.05 469,849.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 42 6,031,028.13 469,844.38 70 29 45.02692 150 14 47.68925 2912 MEM 13.50 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6,031,010.49 469,826.79 70 29 44.85272 150 14 48.20493 2894 1171 13.50 UM 6,031,005.53 459,821.86 70 29 44.80373 150 14 48.34946 2889 MEM 13.50 46 6,031,000.54 469,816.94 70 29 44.75446 150 14 48.49369 - 2884 1181 13.50 NUM 6,030,995.50 469,811.98 70 2944.70469 150 14 48.63910 2879 1186 13.50 4 8 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 1191 • 13.50 .... • OF A�t�� SURVEYOR'S CERTIFICATE • - �y'1/4Letr____ - I :+11 HEREBY C ERTIF,Y THAT I AM • . o :' oar.' •• ' F - - - - - _ PR REGTSTEREIS -AND-- -`µ M -- -- -•__ -_••_ « t 4 . 1H •,. i LICENSED TO PRACTICE LAND .F �. SURVEYING IN THE STATE OF 1(4. • • • ALASKA AN THAT THIS PLAT N :` :a . •% M A1 t REPRESENTS A SURVEY DONE $Y``^�`Y Ffl • • ili G ; Davis • o �go.10 -S . p�'� ME OR UNDER MY SUPERVISION r`' � # a':' -% � � .. s „ «...•• = ° AND THAT I BELIEVE THAT ALL 414441S-VW: DIMENSIONS AND OTHER DETAILS - '- ;.. Orr:SIDN o ff ::. . ' ' 4 1....,..... ? „,-...••• � ARE CORRECT AS SUBMITTED TO^' ~ r; - • ME BY NANUO, INC. AS OF JULY r- 12TH, 2007. Pioneer Natural Resouces • JOB NAME :' Ooccuruk Drill Site Conductors DRAWN BY: BL I CHECKED BY: MJD. LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 Eost DATE: 7- 12-=07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As -built Cocrdinotes 05204 4 of 4 • • TRANSMITTAL LETTER CHECKLIST WELL NAME , u -3 ( PTD# z v Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: 0 Q vcvN-- POOL: 00 vxv\4_ \- kK 17 ©`< \ 'C'oo 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(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 W WELL PERMIT CHECKLIST Field & Pool OOOGURUK, NUIQSUT UNDEF OIL - 576150 Well Name: 000GURUK NUQ ODSN -31 Program DEV Well bore seg ❑ PTD#: 2080030 Company PIONEER NATURAL RESOURCES ALASKA INC. Initial Class/Type DEV / PEND GeoArea 973 Unit 11550 On /Off Shore Off Annular Disposal ❑ Administration '1 Permit fee attached NA 2 Lease numberappropriate Yes Surface location and top prod interval in ADL 355036; TD inADL_388958. 1 3 Unique well name and number Yes 14 Well located in a defined pool No Pool rules in progress; until then, Nuiqsut Undefined Oil Pool 5 Welliocated proper distance from drilling u nit boundary Yes 16 Welllocated proper distance from other wells Yes Yes, conforms to statewide spacing regulation within pool. 1 7 Sufficient acreage_available in_drilling u nit Yes 8 If deviated, is welibore plat included Yes 19 Operator only affected party Yes 110 Operator has_appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Poot rules are in progress. Appr Date 112 Permit can be issued without adrninistrativ_e_approval Yes SFD 1/17/2008 j 1 3 Can permit be approved before 15 -day wait Yes III 14 Welllocated within area and_strata authorized by_ Injection Order # (put 1 0# in comments) (For NA 15 A l wells_within 1 /4mile area review identified (F or service well only) NA 116 Pre - produced injector; duration of pre -Production less than 3 months (For service welt only) NA 17 Nonconven, gas conforms to AS31.05.0300_.1 -D) NA Engineering 18 Conductor string provided - Yes 1 19 Surface casing protects all known USDWs Yes Surface location is offshore. No known USDWs. ,20 CMTvot adequate to circulate_on_conductor & surf csg Yes 21 CMT_ v_ot adequate to tie -in Jong string to surf csg No Planned TOC 500' above disposal zone. 22 CMT wilt cover all knownproductive horizons No Open_ hole completion planned, 123 Casing designs adequate for C, 7, B & permafrost Yes 24 Adequate tankage_or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well. 25 Ifa_ re-drill has a 10 -4.03 for abandonment b een approved NA 126 Adequate wellbore separationproposed Yes Traveling cylinder path calculated. Byros and magnetic ranging planned in surface section. i 27 if diverter_required, does it meet reg ulations Yes Appr Date 28 Drilling fluid program Schematic_& eq_uip list adequate Yes Maximum expected formation pressure 9.8 EMW. Planned mud weight up to 11.0 ppg. TEM 1/24/2008 129 BOPEs,_do they meet regulation Yes • 9* �30 BOPE_press rating appropriate, test to_(pu_i psig in comments) Yes MASP calculated at 2513 psi. 3500 psi BOP testplanned. 31 Choke_ manifold compiles_ w /API RP-53 (May 8 4) Yes ,32 Work will occur without operation shutdown No Surface section will be batch drilled. Plan is to drill remainder of well in about a year. 33 is presence of H2S gas probable No H2S has not been reported in any offset wells. 134 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures Yes H2S not expected in this new reservoir, but operator will take precautions. 1 136 Data_presented on potential overpressure zones Yes Expected reservoirpressure is 9.8 ppg; _production will be drilled with 10.4 ppg mud. Appr Date 1 37 Seismic analysis of shallow gas zones NA SFD 1/17/2008 38 Seabed condition survey (if off- shore) NA 39 Contact name /phone for weekly_progress reports [exploratory only] NA Geologic Date: Engineering Date Date Commissioner: Com ,� issioner: C Co, fr� - ioner