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Home My WebLink About197-037By Grace Christianson at 1:38 pm, Jun 07, 2024 Abandoned 5/18/2024 JSB RBDMS JSB 061824 xG DSR-7/9/24MGR23DEC2025 Drilling Manager 06/07/24 Monty M Myers Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.06.07 13:01:52 - 08'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: JNL 6/3/2024 SCHEMATIC Milne Point Unit Well: MPE-19 Last Completed: 3/14/2024 PTD: 197-037 TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 58.55/ GL Elev.: 24.5’ 7” 2a 5b 9-5/8” 1a 9-5/8” Howco ‘ES’ Cementer @ 1,296’ KUP C Sands Whipstock set @ 7889’ PBTD =7,889’ (MD) / PBTD = 7,004’(TVD) KUP B Sands 2 & 3 TOC 5,000’ MD Leak below 4,640’ MD 3a 4a6b 7b/8b/9b CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.892 Surface 7,611’ 0.0232 4-1/2” Scab Liner 12.6 / L-80 / TXP 3.958 7,611’ 7,760’ 0.0152 TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / EUE 2.992 Surface 7,609’ 0.0087 TUBING JEWELRY DETAIL (a) No Depth Item 1a 7,482’ Viking Sliding Sleeve (Opens Down) 2a 7,539’ 5-1/2”x3-1/2” D&L Permanent Packer 3a 7,597’ X-Nipple (Min ID=2.813”) 4a 7,608’ WLEG – Btm @ 7,609’ PERFORATION DETAIL Sands Tofp (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 24" 250 sks of Arcticset I 12-1/4" 1,195 sks PF “E”, 725 sx Class G 8-1/2” 334 sks Class G WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Install Kill String by ASR – 4-12-2023 CTD Prep by ASR – 3/14/2024 SCAB LINER JEWELRY DETAIL (b) No Depth Item 5b 7,611’ 5-1/2”x4-1/2” XO 6b 7,658’ NCS Frac Sleeve 7b 7,718’ 7”x4-1/2” D&L Iso Packer 8b 7,597’ X-Nipple (ID=3.813”) w/ 3-1/2” Reducer (Min ID=2.813” 9b 7,756’ WLEG – Btm @ 7,760’ ACTIVITYDATE SUMMARY 3/25/2024 *** CONTINUE WSR FROM 3-24-24.*** TAG SOFT BOTTOM AT 8,000' SLM W/ 20' x 2.70" DUMMY WHIPSTOCK (No issues). RAN READ 24 ARM CALIPER FROM 8,000' TO 7,400' SLM, (No data recovered)). RIG-DOWN SLICKLINE. PULLED FROM JOB TO ASSIST RIG. BACK FROM RIG JOB, RIG-UP SLICKLINE. *** CONTINUE WSR ON 3-26-23.*** 3/26/2024 *** CONTINUE WSR FROM 3-25-24.*** RAN READ 24 ARM (extended reach) caliper from 8,000' - 7,400' slm (good data). SHIFT XD-SS CLOSED AT 7,500' MD W/ 3-1/2" 42BO. PRESSURE TEST IA TO 700psi (Holding). *** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.*** Daily Report of Well Operations PBU MPE-19 From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20240528 1425 APPROVAL MP E-19 AOGCC PTD: 224-010 Date:Tuesday, May 28, 2024 2:28:26 PM From: Rixse, Melvin G (OGC) Sent: Tuesday, May 28, 2024 2:24 PM To: Brian Glasheen <Brian.Glasheen@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: RE: MP E-19 AOGCC PTD: 197-037 Brian, Approved to follow PTD perforating with service coil for final perf run(s). Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). Brian, Approved to follow PTD perforating with service coil for final perf run(s). Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell From: Brian Glasheen Sent: Tuesday, May 28, 2024 10:54 AM To: melvin.rixse@alaska.gov; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: MP E-19 AOGCC PTD: 197-037 Mel, Thanks for taking my call today. MPE-19 Was perf’d on the rig however the last 443 feet out of 1000’ did not fire. We are currently bringing the well online to flow back any perf debris, while we wait on service coil to complete that last 443 feet post rig. Per our phone call we plan to use the existing PTD attached for the post rig perforating. Thanks Brian Glasheen Ops Engineer 907-545-1144 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/21/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240521 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 5/11/2024 HALLIBURTON Coilflag MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey MPU F-66A 50029226970100 196162 5/8/2024 READ CaliperSurvey MPI 1-27 50029216930000 187009 5/7/2024 READ PPROF MPU L-17 50029225390000 194169 5/8/2024 READ CaliperSurvey NCI A-12B 50883200320200 223053 5/2/2024 READ MAPP NCI A-17 50883201880000 223031 5/3/2024 READ MAPP PBU 11-41 50029237820000 224017 5/11/2024 HALLIBURTON RBT/Coilflag PBU D-31B 50029226720200 212168 5/12/2024 HALLIBURTON RBT PBU F-31A 50029216470100 212002 5/8/2024 READ CaliperSurvey PBU J-19 50029216290000 186135 5/2/2024 HALLIBURTON RBT PBU L-292 50029237510000 223025 5/6/2024 HALLIBURTON PPROF Please include current contact information if different from above. T38831 T38832 T38833 T38834 T38835 T38836 T38837 T38838 T38839 T38840 T38841 T38842 MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.22 09:57:50 -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: CTD Prep 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 8,249 feet 7,893 feet true vertical 7,310 feet N/A feet Effective Depth measured 8,089 feet 7,579 & 7,700 feet true vertical 7,174 feet 6,739 & 6,842 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2 / L-80 / EUE 7,591' 6,749' 5-1/2”x 3-1/2” Perm. Packers and SSSV (type, measured and true vertical depth)7” x 4-1/2” Perm. N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 324-041 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Brian Glasheen Brian.Glasheen@hilcorp.com 907-564-5277 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 115' 260 Size 115' 3,590' 01500 0 00 0 measured TVD 5-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-037 50-029-22746-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025518 & ADL0047437 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT E-19 Plugs Junk measured Length Scab liner 7,594' 148' Casing Conductor 6,752' 6,878' 7,594' 7,742' 8,247' 3,955'Surface Production Scab liner 20" 9-5/8" 7" 115' 3,955' 6,390psi 7,500psi 5,750 psi 7,240 psi 7,740psi 8,430psi 8,247' 7,308' Burst N/A Collapse N/A 3,090 psi 5,410 psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:32 am, Apr 24, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.23 14:13:55 - 08'00' Taylor Wellman (2143) DSR-4/29/24 RBDMS JSB 043024 WCB 2-13-2025 _____________________________________________________________________________________ Revised By: TDF 1/22/2024 SCHEMATIC Milne Point Unit Well: MPE-19 Last Completed: 4/12/2023 PTD: 197-037 TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 58.55/ GL Elev.: 24.5’ 7” 2a 5b 9-5/8” 1a 9-5/8” Howco ‘ES’ Cementer @ 1,296’ KUP C Sands Whipstock set @ 7893’ PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 2 & 3 TOC 5,000’ MD Leak below 4,640’ MD 3a 4a6b 7b/8b/9b CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.767 Surface 7,594’ 0.0232 4-1/2” Scab Liner 12.6 / L-80 / TXP 4.833 7,594’ 7,742’ 0.0152 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 2.992 Surface 7,591’ 0.0087 TUBING JEWELRY DETAIL (a) No Depth Item 1a 7,464’ Sliding Sleeve 2a 7,521’ 5-1/2”x3-1/2” Permanent Packer 3a 7,579’ X-Nipple (Min ID=2.813”) 4a 7,590’ WLEG – Btm @ 7,591’ PERFORATION DETAIL Sands Tofp (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Install Kill String by ASR – 4-12-2023 CTD Prep by ASR – 3/14/2024 SCAB LINER JEWELRY DETAIL (b) No Depth Item 5b 7,593’ 5-1/2”x4-1/2” XO 6b 7,640’ NCS Sleeve 7b 7,700’ 7”x4-1/2” Permanent Packer 8b 7,727’ XN-Nipple (ID=3.725”) w/ 3-1/2” Reducer (Min ID=2.813” 9b 7,739’ WLEG – Btm @ 7,742’ Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 Fullbore 50-029-22746-00-00 197-037 2/15/2024 3/26/2024 No operations to report. No operations to report. 2/17/2024 - Saturday No operations to report. 2/20/2024 - Tuesday 2/18/2024 - Sunday No operations to report. 2/19/2024 - Monday 2/16/2024 - Friday No operations to report. 2/14/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/15/2024 - Thursday T/I/O = 233/235/58 Pump down OA looking for injection, Pumped 1.8 bbls pressured up to 2500 psi, Pressure fell off, Pumped 1 bbls at 0.30 bpm down OA 1850 psi, FWP = 194/128/127 Confirming an open OA is a COA on Sundry 324-041. -WCB ump down OA looking for injection, Pumped 1.8 bbls pressured up to 2500 psi, Pressure fell off, Pumped 1 bbls at 0.30 bpm down OA Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 Eline & ASR 50-029-22746-00-00 197-037 3/3/2024 3/26/2024 3/1/2024 - Friday No operations to report. 2/28/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/29/2024 - Thursday No operations to report. RIH w/ reverse out BHA on 3-1/2" 9.5# workstring T/ 5,900' Monitor pipe displacement. Well on a .5 BPH loss. Rig service to regen engine on rig. VMS called out to force regen rig engine. Rig fully operational. Cont. RIH w/ reverse out BHA on 3-1/2" 9.5# workstring T/ tag at 7,820' with 5 K down. Rig up kelly hose. Swivel up. Begin reverse circ to clean out. Pump at 4.5 BPM w/ 550 psi. Fluid returns coming back lights. Weight up as needed to 9.2 ppg. Cont. to reverse down at 2.6 BPM w/ 380 psi. Pump 10 bbl high vis sweeps. Increasing sand returns upon surf. to surf. Reversed clean out to 7,960' No operations to report. 3/2/2024 - Saturday WELLHEAD; Pulled CTS plug and BPV after BOP Test. M/U 2 7/8 EUE landing joint to hanger BOLDS to out measurement 4 3/4. Offseat at 16K pulled hanger to the floor and laydown. 3/5/2024 - Tuesday 3/3/2024 - Sunday Adjust service loop. Flood BOP stack. P/U test Mandrel. Preform shell test of BOPE. AOGCC Rep onsite. Test gas alarms. Test # 1 pass. During test #2 found fluid coming from BOPE weep holes on doors of lower rams. Verify hanger / BPV holding by preforming test on blind rams. Good test. Blow down stack and fluid lines. Replace shaft seals on VBR rams. Close doors and pressure up hydraulics. Continue to BOPE test as per approved sundry. BOPE test AOGCC rep. witnessed. Test t/ 250 psi low & 3,000 psi high f/5/5 charted mins. 3/4/2024 - Monday Cont. RIH w/ reverse out BHA on 3-1/2" 9.5# workstring T/ tag at 7,820' with 5 K down. Rig up kelly hose. Swivel up. Begin reverse circ to clean out. Pump at 4.5 BPM w/ 550 psi. Fluid returns coming back lights. Weight up as needed to 9.2 ppg. Cont. to reverse down at 2.6 BPM w/ 380 psi. Pump 10 bbl high vis sweeps. Increasing sand returns upon surf. to surf. Reversed clean out to 7,960' Pulled CTS plug and BPV after BOP Test. M/U 2 7/8 EUE landing joint to hanger BOLDS to out measurement 4 3/4. Offseat at 16K pulled hanger to the floor and laydown BOPE test AOGCC rep. witnessed Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 ASR, EL & SL 50-029-22746-00-00 197-037 3/3/2024 3/26/2024 3/8/2024 - Friday Current wellwork: P/U landing joint & casing hanger. M/U PCE. Drain stack. Prep fluted casing hanger & packoff. Obtain final P/U wt = 125K S/O wt = 85K. Land 5-1/2¿ at final WLEG depth = 7741.59'. RILDS, wellhead reps. verify packoff engagement. (good) Change handling equipment to 2-7/8". Prep for Slick line. R/U sheave. P/U tools & equipment. WLIH w/ 3-1/2" Px plug body on RX running tool. WLOH, Make up Prong, WLIH to set prong. Ensure 5 1/2'' casing is full and circulate across the top of the hole to remove the air. Shut Blind rams. Pressure up 5-1/2" casing to 3,850 PSI to set packer. Continue to hold pressure for an MIT on the 5 1/2'' casing - F/ 30 charted mins. Good test. Bleed off. Rig up slick line & run dump baler to load sand on top of the plug. Make up the Sleeve Shifting BHA - Total length - 17.67'. RIH w/ shifting BHA on 2 7/8'' PH-6 workstring. T/ 3,703'. Pipe displacement returning as calc. P/U wt = 28K S/O wt= 19K. 3/6/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Current wellwork: Clean out to 7,960' P/U = 91K S/O = 45K Pump 30 bbls high vis sweep. Pump a surf to surf. Sand decreasing to minimal. Shut down, open bag & monitor well. Slight returns from well. Tubing fluid dropping, well slightly out of balance. Line up to circulate down tubing. Pump at 5 BPM w/ 550 psi. Pump 27 bbls of 9.2 ppg brine. Returns begin coming back even at 9.2 ppg. Shut down & monitor well (static). B/D lines POOH w/ reverse clean out BHA on 3-1/2" 9.5# workstring F/ 7,900' Monitor pipe displacement. Well on a .5. L/D reverse clean out BHA. All BHA components intact. Rack & tally 5-1/2" 17# L-80 TSH 511. Tally pipe & jelwery. Change out handling equip. Pull wear ring. Begin picking scab liner jewelry. 3/7/2024 - Thursday Current wellwork: Cont. picking scab liner jewelry. WLEG, X nipple, PKR, NCS frac sleave, Begin RIH w/ 5-1/2" L-80 TSH 511 17#. F/ 148'. Running speed 60 fpm. per vendor. Monitor pipe displacement returns. RIH T/ 7,718'. Losses for trip 12.4 bbls. P/U wt = 125K S/O wt= 85K . Current wellwork: Cont. T/ RIH w/ Sleeve shifting BHA with 2 7/8'' PH-6 workstring. F/ 3,703' T/ 7,000'. Pipe displacement returning as calc. . P/U wt = 52K S/O wt= 39K. Rig is down. Work on the rig, change out fuel filters and troubleshoot engine running issues, along with hydraulic issues. Cementers on location. Rig up hardline while troubleshooting rig issues. R/U pump lines in cellar. Cont. trouble shoot rig RPM issue. Completed rig up. Test rig -- Cont. to RIH w/ Sleeve shifting BHA with 2 7/8'' PH-6 workstring. F/ 7,121'. Pipe displacement returning as calc. P/U wt = 50K S/O wt= 30K. Cont to trouble shoot rig. Fuel pressure issue. Begin changing injection pump. Simops: Complete EAM's. Tool cleaning & organizing. Monthly inspections on fire extinguisher & escape packs. 3/9/2024 - Saturday 3/10/2024 - Sunday Current wellwork: Cont changing injection pump on rig. Simops: Complete EAM's. Tool clean & organizing. Monthly inspections on fire extinguisher & escape packs. Finish with injection pump install. Heat hydraulic system & function test rig. P/U 3-1/2" workstring. Work rig with weight cont. testing function.( Good) RIH t/ 7,645' & locate frac sleeve. Space out frac sleeve locate with pups for working height while cementing. Rig up circ. lines on rig floor. Pump dw tbg at 2.5 BPM w/ 700 psi for a total of 170 bbls. Establish loss rate of 7.5 BPH. R/U little red & pump 30 bbls of diesel down tbg prior to cementing as contingency for job. R/D little red & tie Halliburton cementing crew into TBG, Remove fluid from pits for room for monitoring during cement job. Begin cementing, Current wellwork: Clean out to 7,960' P/U = 91K S/O = 45K Pump 30 bbls high vis sweep. Pump a surf to surf. Sand decreasing to minimal. Ensure 5 1/2'' casing is full and circulate across the top of the hole to remove the air. Shut Blind rams Continue to hold pressure for an MIT on the 5 1/2'' casing - F/ 30 charted mins. Good test P/U landing joint & casing hanger. M/U PCE. Drain stack. Prep fluted casing hanger & packoff. Obtain final P/U wt = 125K S/O wt = 85K. Land 5-1/2¿ at final WLEG depth = 7741.59'. RILDS, wellhead reps. verify packoff engagement. (good) Change Pressure up 5-1/2" casing to 3,850 PSI to set packer Begin cementing, Begin RIH w/ 5-1/2" L-80 TSH 511 17#. Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 ASR, EL & SL 50-029-22746-00-00 197-037 3/3/2024 3/26/2024 Hilcorp Alaska, LLC Weekly Operations Summary Current wellwork: Remove BOP stack from CSG head. P/U & install new TBG head. Set down & torque all bolts. Test CSG pack off to 500 psi low & 5000 psi high for 5/10 mins. (good test). Simops: Grease choke manifold for BOPE testing. Cont. Torquing up BOPE bolts & install flow & spacer spool. Prep to BOPE test. Begin BOPE testing as per approved sundry. AOGCC waived witness to test. Test to 250 psi low & 3500 psi high for 5/5 charted mins. Annular has internal oil leak. Yellow jacket called out to service, change out annular adapter ring seals. Cont. BOPE testing as per approved sundry. AOGCC waived witness to test. Test to 250 psi low & 3500 psi high for 5/5 charted mins. On test #4. Current wellwork: PJSM with Halliburton Cement crew. Pumped 10 bbls spacer, 50 bbls lead & 40 bbls tail 13.0 PPG cement, 10 bbls water spacer, and displaced with 29 BBLS of 9.2 PPG brine, observing 20 BBLS of cement returned at surface, setting cement in place at 03:00 HRS. Shifted frac sleeve closed and reverse circulated out approximately 2 BBLS of cement verifying well clean. Pumped a 9.2+ PPG pill down the work string as the well was out of balance. POOH with the 2 7/8'' worksting to 3,600' Set Baker 5 1/2'' Retrievamatic storm packer. Rig up to pull BOP stack & install TBG head. 3/12/2024 - Tuesday 3/11/2024 - Monday change out annular adapter ring seals. Cont. BOPE testing as per approved sundry. AOGCC waived witness to test. Test to Cont. BOPE testing as per approved sundry. AOGCC waived witness to test Pumped 10 bbls spacer, 50 bbls lead & 40 bbls tail 13.0 PPG cement, 10 bbls water spacer, and displaced with 29 BBLS of 9.2 PPG brine, observing 20 BBLS of cement returned at surface, setting cement in place at 03:00 HRS Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 ASR, EL & SL 50-029-22746-00-00 197-037 3/3/2024 3/26/2024 WELL S/I ON ARRIVAL. PULL BALL & ROD @ 7590' MD. PULL RHC PLUG BODY @ 7590' MD. BAIL CEMENT FROM 7656 TO 7700' SLM. LAY DOWN FOR THE NIGHT. WELLHEAD: Completion, clean hgr void install SBMS metal seal, RX54 gasket. Install and NU 3 1/8" tree/adapter, torque to spec and test 500/5000 5/10 min (PASS). Bled void and pull Bpv with T bar. All valves in closed position. 3/16/2024 - Saturday CONTINUE ON WEATHER HOLD DUE TO 35+ MPH WINDS. WELL S/I ON DEPARTURE. 3/19/2024 - Tuesday 3/17/2024 - Sunday WELL S/I ON ARRIVAL. SHIFT SLIDING SLEEVE OPEN @ 7467' MD. WEATHER HOLD, WINDS OVER 35 MPH. 3/18/2024 - Monday 3/15/2024 - Friday PU JT# 233 - PUW = 71K, SOW = 43K. Tag 4-1/2¿ XO 7,592¿ MD & space out placing EOT @ 7,590.63¿ MD. Land Hanger, RILDS. Pump 78bbls 1% KCL w/ corrosion inhibitor followed by 25bbls 80* diesel. Allow IA and TBG to U-Tube. Pressure up and set D&L Packer w/ 4100psi - MIT-T - Good test. MIT-IA to 3650psi - Good test. Install BPV, Begin RDMO. Plug bottom CL ports of 11" x 3 1/2" tbg hgr. MU hgr to 3 1/2 TC11 LJ, PU and MU to comp string. Five ft into profile RKB 16.03' RILDS and pull LJ. SB for pumping and testing. Set 3" Bpv through stack for RD. 3/13/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RIG UP POLLARD #58 TO ASSIST ASR RIG 3/14/2024 - Thursday SL RIH w/ 4.760" G.Ring / Barbell setup to 4-1/2" XO @ 7,595' SLM no issues. MU WLEG to 2.813 X-Nipple w/ RHC-M installed, 1JT, Tripoint D&L 5-1/2 x 3-1/2" Retrievable Packer, 1JT, Viking SSD (down to open). RIH T/ 7,543" MD. PUW = 70K, SOW = 43K. Pressure up and set D&L Packer w/ 4100psi - MIT-T - Good test. MIT-IA to 3650psi - Good test PU JT# 233 - PUW = 71K, SOW = 43K. Tag 4-1/2¿ XO 7,592¿ MD & space out placing EOT @ 7,590.63¿ MD. Land Hanger, RILDS. Pump 78bbls 1% KCL w/ corrosion inhibitor followed by 25bbls 80* diesel. Allow IA and TBG to U-Tube. Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 ASR, EL & SL 50-029-22746-00-00 197-037 3/3/2024 3/26/2024 WORK CONTINUES FROM PREVIOUS DAY. RAN READ 24 ARM (extended reach) caliper from 8,000' - 7,400' slm (good data). SHIFT XD-SS CLOSED AT 7,500' MD W/ 3-1/2" 42BO. PRESSURE TEST IA TO 700psi (Holding). WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. No operations to report. 3/23/2024 - Saturday WORK CONTINUES FROM PREVIOUS DAY. TAG SOFT BOTTOM AT 8,000' SLM W/ 20' x 2.70" DUMMY WHIPSTOCK (No issues). RAN READ 24 ARM CALIPER FROM 8,000' TO 7,400' SLM, (No data recovered). RIG-DOWN SLICKLINE. PULLED FROM JOB TO ASSIST RIG. BACK FROM RIG JOB, RIG-UP SLICKLINE. 3/26/2024 - Tuesday 3/24/2024 - Sunday RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 8' x 1-7/8" ROLLER STEM (2.60" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). RAN 10' x 2.50" PUMP BAILER TO TOP OF PRONG AT 7,743' - 7,750' SLM (recovered 3-3/4gallons of sand/cement slurry mix). PULL P-PRONG FROM PLUG BODY AT 7,745' MD. RAN MULTIPLE SIZE BAILERS TO 3-1/2" PLUG BODY AT 7,745' MD ((recovered 6 gallons of sand/cement slurry mix). PULL 3-1/2" PX PLUG BODY FROM 7,745' MD. 3/25/2024 - Monday 3/22/2024 - Friday MIRU. PT W/ NITROGEN 200 PSI TRIPLEX W/ DIESEL TO 2500 PSI. BAIL CEMENT FROM 7705' SLM. OBTAIN IMPRESSION OF PX PRONG W/ LIB @ 7707' SLM. ATTEMPT TO LATCH PX PRONG @ 7707' SLM ( UNABLE TO LATCH). RIG DOWN TO GO TO G-18. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 3/20/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MIRU. PT W/ NITROGEN 200 PSI TRIPLEX W/ DIESEL TO 2500 PSI. BAIL CEMENT, MUD & SAND MIXTURE @ 7698' TO 7703 SLM. (4 CUPS OF CEMENT). (7 GALLONS OF MUD W/ SOME SAND MIXED IN). LAY DOWN FOR THE NIGHT. 3/21/2024 - Thursday MIRU. PT W/ NITROGEN 200 PSI TRIPLEX W/ DIESEL TO 2500 PSI. BAIL THICK MUD/SMOOH AND COME CEMENT @ 7,700- 7,706' SLM. (4 GALLONS RECOVERED). LAY DOWN FOR THE NIGHT. PULL 3-1/2" PX PLUG BODY FROM 7,745' MD. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/12/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240412 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey MPU G-18 50029231940000 204020 3/21/2024 READ CaliperSurvey MPU L-07 50029220280000 190037 3/30/2024 READ CaliperSurvey PBU 01-19C 50029208000300 213171 2/22/2024 BAKER MRPM PBU 01-28B 50029215970200 223089 1/21/2024 BAKER MRPM PBU 11-42 50029237750000 223117 3/5/2024 HALLIBURTON RBT PBU N-11D 50029213750300 223083 2/14/2024 BAKER MRPM PBU N-21A 50029213420100 196196 3/28/2024 BAKER SPN PBU S-201A 50029229870100 219092 4/8/2024 READ LeakPointSurvey Please include current contact information if different from above T38705 T38706 T38707 T38708 T38709 T38710 T38711 T38712 T38713 MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.16 11:46:27 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT E-19 JBR 04/11/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Tested with 2 7/8", 3 1/2" and 5 1/2" test joints. Precharge bottles = 12 @ 1100psi each. I relieved Bob Noble on this inspection. Bob witnessed the Gas Alarms, PVT's and the Blinds. He said they all passed. The LPR mud seal failed and was repaired and passed and then on the last test it failed again was repaired again and passed. Test Results TEST DATA Rig Rep:C. Pace / J. WerlingerOperator:Hilcorp Alaska, LLC Operator Rep:A. Haberthur / R. Gallen Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1970370 DATE:3/4/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopBDB240306052454 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 21.5 MASP: 2543 Sundry No: 324-041 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 5 1/2"P #2 Rams 1 2 7/8"x5"FP #3 Rams 1 Blinds P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 3 2 1/16"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1800 200 PSI Attained P9 Full Pressure Attained P62 Blind Switch Covers:PYES Bottle precharge P Nitgn Btls# &psi (avg)P4@2337 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P12 #1 Rams P7 #2 Rams P7 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0       1 Junke, Kayla M (OGC) From:Taylor Wellman <twellman@hilcorp.com> Sent:Thursday, February 15, 2024 10:11 AM To:Rixse, Melvin G (OGC); McLellan, Bryan J (OGC) Subject:RE: MPU E-19 (PTD 197-037) Approved Sundry 324-041 Updated BHP Gentlemen, MPU E‐19 is conﬁrmed to have an open SC shoe. During the MIT‐OA, it broke over and had injecƟon of 0.3bpm at ~1,850psi and falling. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777‐8449 Cell: (907) 947‐9533 Email: twellman@hilcorp.com From: Taylor Wellman Sent: Wednesday, February 14, 2024 9:16 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: MPU E‐19 (PTD 197‐037) Approved Sundry 324‐041 Updated BHP Mel and Bryan, For MPU E‐19 (PTD 197‐037) under Approved Sundry 324‐041 we performed a recent BHP survey to conﬁrm the BHP. The results were 3,256psi @ 6,929’ TVD. This increased the MASP from 2,543psi to 2,563psi. No pressure tests are affected by this. The plans are to increase our KWF from 9.0 to 9.2ppg to allow for some trip margin during the RWO. If there is any issue with this course of acƟon please let me know. As an update to the open OA shoe, the well has passed an MIT‐OA to 1,500psi. We will be moving towards aƩempƟng to break down the SC shoe in the next day or two. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777‐8449 Cell: (907) 947‐9533 Email: twellman@hilcorp.com 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. Drilling Manager 02/13/24 Monty M Myers By Kayla Junke at 3:52 pm, Feb 14, 2024 324-084 * BOPE pressure test to 3500 psi. * Variance to 20 AAC 25.112 (i) with fully cemented liner in upcoming CTD sidetrack. 10-407 MGR15FEB24 DSR-2/14/24 *Well Completion Report received 8/29/97 SFD SFD 2/15/2024 7309*8249* *&:JLC 2/16/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.16 13:28:31 -06'00'02/16/24 RBDMS JSB 022024 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: February 13, 2024 Re: MPU E-19 Sundry Request Sundry approval is requested to set a whipstock and abandon well MPE-19 as part of the drilling and completion of the proposed MPE-19A CTD lateral. Proposed plan for E-19A Producer: See MPU E-19 Sundry request for complete pre-rig details - Prior to drilling activities, a RWO will be completed to repair a casing leak in the 7" casing using a 5-1/2" scab casing and complete with 3-1/2" tubing (Separate Sundry). Post RWO, screening will be conducted to drift and caliper for whipstock. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will set a 3-1/2"x7" flow through whipstock and mill a single string 2.80" window + 10' of formation. The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 2-3/8” L-80 solid liner and cemented. This completion WILL abandon the parent Kuparuk perfs. This Sundry covers plugging the existing Kuparuk perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in March 1st 2024) x Reference MPU E-19 Sundry submitted in concert with this request for full details. 1. RWO : Pull tubing, run 5-1/2” Scab and 3-1/2” tubing, MIT (Separate Sundry) 2. Slickline : Drift for whipstock and Caliper 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in April 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,492 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set top of 3-1/2" x 7" whipstock at 7893' - 0 deg ROHS 3. Mill 2.80” Window. 4. Drill build section: 3.25" OH, ~462' (40 deg DLS planned). 5. Drill production lateral: 3.25" OH, ~1850' (12 deg DLS planned). Swap to KWF for liner. 6. Run 2-3/8” 13Cr solid liner 7. Pump primary cement job: 25 bbls, 15.3 ppg Class G, TOC at TOL*. 8. Only if not able to do with service coil extended perf post rig – Perforate Liner 9. Freeze protect well to a min 2,200' TVDss. 10. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Post rig perforate (~500’) See extended perf procedure attached 3. Slickline : Set JP PTD Sundry 324-084 ppp This completion WILL abandon the parent Kuparuk perfs. flow through whipstock Ryan Ciolkosz CC: Well File Drilling Engineer (907-244-4357) Joseph Lastufka _____________________________________________________________________________________ Revised By: TDF 4/20/2023 SCHEMATIC Milne Point Unit Well: MPE-19 Last Completed: 4/12/2023 PTD: 197-037 TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’ 7” 9-5/8”1 9-5/8” Howco ‘ES’ Cementer @ 1,296’ KUP C Sands PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 2 & 3 TOC 5,000’ MD Leak below 4,640’ MD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 2.867 Surface 2,664’ 0.0058 JEWELRY DETAIL No Depth Item 1 2,660’ Mule shoe pup –Btm @ 2,664’ 2 8,164’ 7” Float Collar 3 8,247’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Install Kill String by ASR – 4-12-2023 _____________________________________________________________________________________ Revised By: TTW 1/22/2024 PROPOSED SCHEMATIC Milne Point Unit Well: MPE-19 Last Completed: 4/12/2023 PTD: 197-037 TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 58.55/ GL Elev.: 24.5’ 7” 2a 5b 9-5/8” 1a 9-5/8” Howco ‘ES’ Cementer @ 1,296’ KUP C Sands Whipstock set @ 7893’ PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 2 & 3 TOC 5,000’ MD Leak below 4,640’ MD 3a 4a6b 7b/8b/9b CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.767 Surface ±7,700’ 0.0232 4-1/2” Scab Liner 12.6 / L-80 / TXP 4.833 ±7,700’ ±7,780’ 0.0152 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 2.992 Surface ±7,700’ 0.0087 TUBING JEWELRY DETAIL (a) No Depth Item 1a ±7,500’ Sliding Sleeve 2a ±7,540’ 5-1/2”x3-1/2” Permanent Packer 3a ±7,590’ X-Nipple (ID=2.813”) 4a ±7,630’ WLEG PERFORATION DETAIL Sands Tofp (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Install Kill String by ASR – 4-12-2023 SCAB LINER JEWELRY DETAIL (b) No Depth Item 5b ±7,635’ 5-1/2”x4-1/2” XO 6b ±7,675’ NCS Sleeve 7b ±7,725’ 7”x4-1/2” Permanent Packer 8b ±7,745’XN-Nipple (ID=3.725”) w/ 3-1/2” Reducer (ID=2.813”) 9b ±7,755’ WLEG _____________________________________________________________________________________ Revised By: JNL 2/6/2024 PROPOSED SCHEMATIC Milne Point Unit Well: MPE-19A Last Completed: TBD PTD: TBD TD =10,205’ (MD) / TD = 7,009’(TVD) 20” Orig. KB Elev.: 58.55’/ GL Elev.: 24.5’ 7” 2a 5b 9-5/8” 1a 9-5/8” Howco ‘ES’ Cementer @ 1,296’ PBTD = 10,150’(MD) / PBTD = 7,008’(TVD) TOC 5,000’ MD Leak below 4,640’ MD 3a 4a 6b 7b/8b/9b 7533’-2.7” DPY SLV 3-1/2” x 7”WS 7893’ MD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.767 Surface ±7,700’ 0.0232 4-1/2” Scab Liner 12.6 / L-80 / TXP 4.833 ±7,700’ ±7,780’ 0.0152 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 2-3/8” Liner 4.6 / L-80 / H511 1.901 7,533’ 10,205’ 0.0039 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 2.992 Surface ±7,700’ 0.0087 TUBING JEWELRY DETAIL (a) No Depth Item 1a ±7,500’ Sliding Sleeve 2a ±7,540’ 5-1/2”x3-1/2” Permanent Packer 3a ±7,590’ X-Nipple (ID=2.813”) 4a ±7,630’ WLEG PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status OPEN HOLE / CEMENT DETAIL 24" 250 sks of Arcticset I (Approx.) 12-1/4" 1,195 sks PF “E”, 725 sx Class “G” 8-1/2” 334 sks Class “G” 3-1/4” 113 sx Class G WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-01-00 Drilled and Cased by Nabors 27E - 3/21/1997 Install Kill String by ASR – 4-12-2023 A Sidetrack: TBD SCAB LINER JEWELRY DETAIL (b) No Depth Item 5b ±7,635’ 5-1/2”x4-1/2” XO 6b ±7,675’ NCS Sleeve 7b ±7,725’ 7”x4-1/2” Permanent Packer 8b ±7,745’XN-Nipple (ID=3.725”) w/ 3-1/2” Reducer (ID=2.813”) 9b ±7,755’ WLEG Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 1 Davies, Stephen F (OGC) From:Ryan Ciolkosz <ryan.ciolkosz@hilcorp.com> Sent:Thursday, February 15, 2024 12:56 PM To:Davies, Stephen F (OGC) Cc:Rixse, Melvin G (OGC); Roby, David S (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL] MPU E-19 (Permit 197-037, Sundry 324-084) - Question Steve, Sorry,thismaynothavebeenclearintheSundry.TheactualabandonmentoftheexisƟngEͲ19perforaƟonswillbewith theEͲ19Alinercementjob,whichwillextendabovetheexisƟngperforaƟonsintothenewtubingtail.Seetheproposed EͲ19AschemaƟcbelow.AlthoughthedrillingandcompleƟonoftheEͲ19Awellborefallsunderthenewpermittodrill,I believetheabandonmentoftheEͲ19perfsviathatnewsidetrackandcompleƟonneedstobeapprovedthroughtheEͲ 19Sundry. LetmeknowifyouhaveanyotherquesƟons. Youdon'toftengetemailfromryan.ciolkosz@hilcorp.com.Learnwhythisisimportant CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 3 Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From:Davies,StephenF(OGC)<steve.davies@alaska.gov> Sent:Thursday,February15,202412:32PM To:RyanCiolkosz<ryan.ciolkosz@hilcorp.com> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Dewhurst,Andrew D(OGC)<andrew.dewhurst@alaska.gov> Subject:[EXTERNAL]MPUEͲ19(Permit197Ͳ037,Sundry324Ͳ084)ͲQuestion Ryan, AccordingtotheschemaƟcdrawingaccompanyingtheplugͲforͲredrillSundryApplicaƟonforMPUEͲ19,aŇowͲthrough whipstocksetat7,893’MDdoesn’tappeartoabandontheKupCperforaƟonsthatextendfrom7,837’to7,860’MDor theporƟonoftheKupBperfsthatextendfrom7,872’tothewhipstockat7,893’MD,asstatedinthecoverleƩerfor Hilcorp’sapplicaƟon.IfI’mcorrect,thismeansthattheplannedwellboreexiƟngthewindowwouldbemoreproperly termedEͲ19L1ratherthanEͲ19A,andthatallproducƟonfromthatlateralwouldbereportedagainsttheEͲ19 wellbore.PleasehelpmeunderstandthisbeƩer. ThanksandBeWell, CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 4 SteveDavies AOGCC CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyaƩachments,containsinformaƟonfromtheAlaskaOilandGasConservaƟonCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).ItmaycontainconĮdenƟaland/orprivilegedinformaƟon.Theunauthorizedreview,use ordisclosureofsuchinformaƟonmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutĮrstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer SFD 2/15/2024 197-037 MPU E-19 SFD 2/15/2024 324-084 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: CTD Prep 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,249 8,089 (Fill) Casing Collapse Conductor 520 psi Surface 3,090 psi Production 5,410 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A and N/A N/A and N/A Taylor Wellman twellman@hilcorp.com 777-8449 Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" 115' 20" 9-5/8" 7" 3,955' 8,247' MD 1,530 psi 5,750 psi 7,240 psi 3,590' 7,308' 3,955' 8,247' Length Size Proposed Pools: 115' 115' 6.5# / L-80 / EUE TVD Burst 2,664' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047437 197-037 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22746-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 2/10/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT E-19 MILNE POINT KUPARUK RIVER OIL N/A 7,310 8,089 7,174 2,543 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 10:29 am, Jan 31, 2024 324-041 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533) Date: 2024.01.30 09:06:49 - 09'00' David Haakinson (3533) B DSR-1/31/24 , ADL0025518 SFD SFD 1/31/2024 * BOPE pressure test to 3000 psi. Annular to 2500 psi. * Monitorable OA at surface casing shoe to assure no power fluid to the overburden. 10-404 BJM 2/9/24 Confirm OA shoe is open prior to returning to production. JLC 2/9/2024 2/9/24Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.09 17:45:30 -05'00' RBDMS JSB 021324 Well: MPU E-19 PTD: 197-037 API: 50-029-22746-00-00 Well Name:MPU E-19 API Number:50-029-22746-00-00 Current Status:SI Producer – Kill String Rig:ASR Estimated Start Date:02/10/2024 Estimated Duration:8 days Regulatory Contact:Tom Fouts Permit to Drill Number:197-037 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Current Bottom Hole Pressure: 3,234 psi @ 6,910’ TVD MPU E-19 2023 RWO (KWF used) |9.0 PPGE Max Proposed Surface Pressure: 2,543 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 33° at 3,500’ MD Brief Well Summary: E-19 is a shut-in Kuparuk slant producer that has been shut-in since 2017. The well has solids on top of the pump (6/7/22 slickline tagged fill @ 7636’). Fill remains 42’ above discharge head @ 7,688’ RKB. The last four ESPs have lasted an average on 314 days making another ESP workover uneconomic. During an April 2023 workover, the ESP was pulled and a casing leak was identified at ±4,640’ MD. A kill string was run and the workover was cancelled until a repair plan could be made to address the casing leak. Objectives: x Run & cement 5-1/2” tie-back liner to isolate 7” casing leak x Run 3-1/2” jet pump completion Notes Regarding Wellbore Condition: x 7” casing leak identified at ±4,640’ MD during April 2023 RWO Pre-Rig Procedure (Non-sundried steps) Slickline & Pumping 1. MIRU SL unit and pressure test PCE to 250 / 2,500 psi. 2. Run SBHP survey to confirm BHP. RDMO. Pumping & Well Support 3. Clear and level pad area in front of well. Spot rig mats and containment. 4. RD well house and flowlines. Clear and level area around well. 5. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 6. Pressure test lines to 3,000 psi. 7. Circulate at least one wellbore volume with 9.0ppg brine down tubing, taking returns up casing to 500 barrel returns tank. a. Note that the kill string is run to 2,660’ MD and freeze protected down to this depth with criesel. b. Take return fluid weight measurements to ensure 9.0ppg around before considering bullheading to formation. 8. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. ...in preparation for CTD sidetrack. -bjm ESP was pulled in Apr 2023. -bjm Well: MPU E-19 PTD: 197-037 API: 50-029-22746-00-00 9. RD Little Red Services and reverse out skid. 10. Set BPV. ND tree. Brief RWO Procedure (Approved Sundry Required) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with 9.0ppg brine prior to setting CTS. 3. NU BOPE. 4. Test BOPE to 250 psi low/ 3,000 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 4-1/2” test joint. e. Test Fixed ram’s and annular with 5-1/2’’ test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 9.0ppg brine as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 6. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Expected PU ~14kips – 2023 RWO landed the kill string with 11kips SOF. 7. Confirm hanger free, lay down tubing hanger. 8. POOH and lay down the 2-7/8” tubing. Number all joints. 9. PU and RIH w/ 3-1/2” workstring and 6-1/8” reverse circ junk mill BHA. a. Use gel sweeps and reverse circulation as needed. b. Target depth to clean out to 7,950’ MD. c. 2023 RWO had rig depths of 7,900’ MD / 7,865’ ELMD. Whipstock setting depth is 7,925’ MD / 7,890’ ELMD. 10. RIH with 5-1/2” casing and obtain string weights. a. Note PU and SO weights on tally. Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 4-1/2''10'WLEG 12.6 L-80 WLEG at ±7,755’ MD 4-1/2''10'Pup Joint 12.6 L-80 4-1/2''3' XN nip with 3-1/2” nipple reducer installed 12.6 L-80 Ensure nipple reducer (ID=2.813”) is installed 4-1/2''10'Pup Joint 12.6 L-80 Test VBR rams on 2-7/8” and 4-1/2” test joint. e. Test Fixed ram’s and annular with 5-1/2’’ test joint. k setting depth is 7,925’ MD / 7,890’ ELMD. Well: MPU E-19 PTD: 197-037 API: 50-029-22746-00-00 4-1/2''10'Pup 12.6 L-80 4-1/2'' 7” X 4-1/2” Packer 12.6 L-80 Set Packer ±7,725’ MD 4-1/2''10'Pup 12.6 L-80 4-1/2'' 40’ 1 joint 12.6 L-80 4-1/2''6'Pup Joint 12.6 L-80 4-1/2''NCS Frac sleeve 11.2 L-80 4-1/2''10'Pup Joint 12.6 L-80 4-1/2'' 1 joint 17 L-80 4-1/2''10' XO 5.5'' to 4.5'' Joint 12.6 L-80 Crossover at ±7,635’ MD 5-1/2''Joints 17 L-80 5-1/2''Space out PUPS 17 L-80 5-1/2'' 1 joint 17 L-80 5-1/2''PUP 17 L-80 5-1/2''Tubing Hanger 17 L-80 11. Space out and make up to existing tubing hanger. a. Contact OE to discuss if spaceout is required or if landing on full joint is acceptable. 12. RILDS. Lay down landing joint. 13. RU SL, RIH and set 3-1/2” PX plug at ±7,745’ MD. 14. Complete loading the 5-1/2’’ tie back and hydraulically set the packer as per manufacturers setting procedure. 15. MIT 5-1/2’’ casing to 3600 psi (Power fluid pressure test). Bleed off pressure. 16. SL RIH and dump sand or beads on top of plug and prong. RD SL unit. 17. Make up NCS sleeve shifting BHA + drill collar(s) on 2-7/8’’ workstring and TIH to sleeve to cement tieback to surface. a. See cementing appendix. 18. After sleeve is closed, pressure test the 5-1/2’’ casing to 2000 psi to verify sleeve is closed a. Assuming the pressure test passed in step 15. b. Open the 7” x 5-1/2” casing valve to verify 5-1/2” primary packoff integrity. 19. Set TWC and pressure test to 2000 psi. 20. Confirm no flow, then break BOP stack and stack new tubing spool with secondary packoff. 21. Test packoffs to 3,500psi. 22. NU BOPs, Test break to 3,000 psi, then pull TWC. 23. PU and MU the following Tubing completion: Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/ft Material Notes 3-1/2''10'WLEG 9.5 L-80 WLEG at ±7,630’ MD 3-1/2''10'Pup Joint 9.5 L-80 3-1/2''3'X Nipple w/ RHC installed 9.5 L-80 secondary packoff. MIT 5-1/2’’ casing to 3600 psi (Power fluid pressure test). What is this packoff? On the 5-1/2"? RU SL, RIH and set 3-1/2” PX plug at ±7,745’ MD. Open the 7” x 5-1/2” casing valve to verify 5-1/2” primary packoff integrity. Step 18b will be done with 2000 psi on the 5-1/2" casing. -bjm Well: MPU E-19 PTD: 197-037 API: 50-029-22746-00-00 3-1/2''10'Pup Joint 9.5 L-80 3-1/2'' 40’ 1 joint 9.5 L-80 3-1/2''10'Pup 9.5 L-80 3-1/2'' 5-1/2” X 3-1/2” Packer 9.5 L-80 Set Packer ±7,540’ MD 3-1/2''10'Pup 9.5 L-80 3-1/2'' 40’ 1 joint 9.5 L-80 3-1/2''10'Pup Joint 9.5 L-80 3-1/2''Sliding Sleeve 9.5 L-80 3-1/2''10'Pup Joint 9.5 L-80 3-1/2''Joints 9.5 L-80 3-1/2''Space out PUPS 9.5 L-80 3-1/2'' 1 joint 9.5 L-80 3-1/2''PUP 9.5 L-80 3-1/2''Tubing Hanger 9.5 L-80 24. Pump 5 barrels 1% KCL with 1% corrosion inhibitor by volume down the annulus, followed by 55 barrels 1% KCL, and 26 barrels of freeze protect fluid taking returns up the tubing. a. This is to protect the area between the packer and sliding sleeve from corrosion. b. Coordinate with Wells Foreman if the IA freeze protect is needed with the expected time to bring well online. 25. Drop ball & rod, and load tubing with FP while pumping ball and rod down to seat. Take returns to formation. Pressure up and set packer per vendor instructions. 26. Perform 30 minute charted MIT-T to 3,000 psi. 27. Perform 30 minute charted MIT-IA to 3,650 psi. 28. Set BPV. RDMO ASR. Post-Rig Procedure: Well Support 29. RD mud boat. RD BOPE house. Move to next well location. 30. RU crane. ND BOPE and NU tree. 31. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 32. RD crane. Move 500 bbl returns tank and rig mats to next well location. 33. RU well house and flowlines. Slickline 1. RU SL and test PCE to 3,000 psi. 2. RIH and Retrieve Ball and Rod and 3-1/2” RHC Plug from ±7,590’ MD. 3. Bail sand/beads from PX plug @ ±7,745’ MD. 4. Pull 3-1/2” PX Plug from ±7,745’ MD. 5. Drift for whipstock. 6. Run GR/CCL from deepest possible to 7,450’ MD. 7. RD SL Unit. Take returns to formation. Plug and sand below? Can't pump into formation due to plugged perfs, but ball & rod will fall in this low-angle well. -bjm Perform pressure test on the 7" x 5-1/2" annulus to 1000 psi with diesel, per Taylor Wellman email dated 2/8/24. -bjm Well: MPU E-19 PTD: 197-037 API: 50-029-22746-00-00 8. Turn Well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic Well: MPU E-19 PTD: 197-037 API: 50-029-22746-00-00 1. Cementing Appendix: Objective: Cement 7” x 5-1/2” annulus to surface to repair a hole in the 7” at ±4,640’ MD. Well conditions: Hole in the 7” production casing at ±4,640’ MD. Identified with a test packer during a RWO. The well was static with 9.0 ppg brine. Injection rate into the casing leak was 1.25 bpm @ 400psi with 9.0 ppg brine. Capacity Volume to NCS sleeve @ ±7,675’ MD 2-7/8” workstring 0.00524 bbl/ft 41 bbl 7” x 5-1/2” annulus 0.0089 bbl/ft 69 bbl / 27 bbls (to csg leak @ ±4,640’ MD 5-1/2” x 2-7/8” annulus 0.0152 bbl/ft 117 bbl Surface to surface volume down 2-7/8” workstring and up 7” x 5-1/2” annulus = 110 bbl Steps: 1. Circulate a 5 bbl gel pill inside the 5-1/2” x 2-7/8’’ annulus to be above the sleeve and assist in reversing out. 2. Shift NCS sleeve open per vendor recommendation. a. It should have shear pins installed requiring a total force of per vendor reccomendation down to open. This is light enough that slacking off the workstring should open the sleeve, however it is possible to pressure up the backside of the workstring to help shift the sleeve. 3. Circulate a bottoms up taking returns from the 7” x 5-1/2” annulus casing valve, and verify 1 for 1 returns. a. Monitor 2-7/8”x5-1/2” annulus to verify no leakage past the NCS sleeve. 4. Cement the 7” x 5-1/2” annulus with the following: a. 30 bbl diesel b. 5 bbl fresh water c. 5 bbl mudpush d. 89 bbl 15.3ppg Glass G cement (20 bbl excess) e. 10bbl fresh water spacer f. Displace with 9 bbls 1 percent KCL leaving 1 bbls of cement to reverse out. 5. Slow rate once cement reaches surface, and choke back returns if possible in an attempt to squeeze cement in to the leak. Contingency: 6. If no cement returns are seen at surface, ensure a minimum of 18 bbls of diesel is in the 7” x 5-1/2” annulus to freeze protect to ~2000MD by returned diesel pumped or by bullheading through the leak. 7. Shift sleeve closed with strait pull, per vendor. 8. Bleed off pressure from 5-1/2”X 2-7/8’’ workstring annulus to verify sleeve is closed. a. Pressure should bleed off very quickly and if it does not bleed off quick sleeve is likely still open and we need to pressure up to keep cement from swapping. 9. RU to start reversing out. 10. Begin reversing out at max rate and drop 10-20’ below NCS sleeve while reversing out. a. Consider running to top of X Nipple at ±7,745’ MD while reversing out. 11. Perform 2 bottoms up before POOH. 12. POOH The diesel will underbalance the well and it will start flowing from the casing hole, contaminating cement as it is being placed. Maintain backpressure while pumping cement to avoid flowing well. See attached email from Taylor Wellman dated 2/8/24 -bjm Well: MPU E-19 PTD: 197-037 API: 50-029-22746-00-00 2. NCS sleeve shifting steps 1. Locate the Target Frac Sleeve 1.1. RIH 20 ft below the target sleeve. Pick up to the target frac sleeve and locate the sleeve by a measured overͲpull of tubing weight. Mark the tubing at the locate depth. 1.2. Pull through the sleeve to confirm sleeve position. Pull up and lay down the joint of tubing if necessary 1.3. Repeat Step 1.1 to stop at the marked sleeve depth. 2. Set the Packer 2.1. Space out as necessary to achieve a floor height connection for the tubing cementing head. 2.2. The packer is set to isolate the current zone from the well below the BHA. 2.3. Engage the setting slips. 3. Pressure Test the Packer 3.1. A pressure test is performed to ensure that the packer is set and holding pressure. 4. Shift the Sleeve Open 4.1. Frac sleeves are shifted open to expose the frac ports to the formation. By pumping down the tubing at controlled rates the annulus above the packer pressures up. When the pressure above the packer reaches the correct force, the sleeve shifts open. 5. Pull the Sleeve Closed 5.1. Picking up on the SFC BHA when in compression set mode cycles the packer into tension set mode. In tension set mode, the packer grips and closes the sleeve while pulling out of hole. 6. Cycle BHA to Pull Out of Hole Mode 6.1. The SFC BHA is cycled into POOH mode to pick up past the current sleeve. _____________________________________________________________________________________ Revised By: TDF 4/20/2023 SCHEMATIC Milne Point Unit Well: MPE-19 Last Completed: 4/12/2023 PTD: 197-037 TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’ 7” 9-5/8”1 9-5/8” Howco ‘ES’ Cementer @ 1,296’ KUP C Sands PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 2 & 3 TOC 5,000’ MD Leak below 4,640’ MD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 2.867 Surface 2,664’ 0.0058 JEWELRY DETAIL No Depth Item 1 2,660’ Mule shoe pup –Btm @ 2,664’ 2 8,164’ 7” Float Collar 3 8,247’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Install Kill String by ASR – 4-12-2023 _____________________________________________________________________________________ Revised By: TTW 1/22/2024 PROPOSED SCHEMATIC Milne Point Unit Well: MPE-19 Last Completed: 4/12/2023 PTD: 197-037 TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’ 7” 2a 5b 9-5/8” 1a 9-5/8” Howco ‘ES’ Cementer @ 1,296’ KUP C Sands PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 2 & 3 TOC 5,000’ MD Leak below 4,640’ MD 3a 4a6b 7b/8b/9b CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 5-1/2” Scab Liner 17 / L-80 / Hyd 511 4.767 Surface ±7,700’ 0.0232 4-1/2” Scab Liner 12.6 / L-80 / TXP 4.833 ±7,700’ ±7,780’ 0.0152 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 2.992 Surface ±7,700’ 0.0087 TUBING JEWELRY DETAIL (a) No Depth Item 1a ±7,500’ Sliding Sleeve 2a ±7,540’ 5-1/2”x3-1/2” Permanent Packer 3a ±7,590’ X-Nipple (ID=2.813”) 4a ±7,630’ WLEG PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Install Kill String by ASR – 4-12-2023 SCAB LINER JEWELRY DETAIL (b) No Depth Item 5b ±7,635’ 5-1/2”x4-1/2” XO 6b ±7,675’ NCS Sleeve 7b ±7,725’ 7”x4-1/2” Permanent Packer 8b ±7,745’XN-Nipple (ID=3.725”) w/ 3-1/2” Reducer (ID=2.813” 9b ±7,755’ WLEG Updated 8/25/2023 11” BOPE Shaffer 11'’-5000 CIW-U 4.30'Hydril GK 11" - 5000 2-7/8" x 5" VBR Blind 11'’- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual 2-7/8" x 5" VBR Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 2023 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Taylor Wellman To:Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] PTD 197-037 MPU E-19 Questions Attachments:image001.png image002.png Mel, Please see answers in red below. I can/will provide the results of the MIT-OA once it is completed. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Saturday, February 3, 2024 4:06 PM To: Taylor Wellman <twellman@hilcorp.com> Subject: [EXTERNAL] PTD 197-037 MPU E-19 Questions Taylor, Not clear to me how you take returns to formation when you have a plug in the 5-1/2” and sand below. Can you explain? You’re correct. We won’t be taking returns to formation but we shouldn’t need to. This well is very vertical (max deviation = 32 deg) so I don’t fear the ball & rod having an issue make it down. Short version = bad wording on my part and that line can be removed. For concerns on the freeze protection of the tubing, we typically get on the wells fast enough after rig departure to be able to either shift open a sleeve or pull plugs to circ in a full freeze protection as needed. Is the surface casing shoe currently open to monitor the overburden? I had this one planned and is scheduled for tomorrow. The OA has not been pumped on since the FIT during drilling. Is this the secondary packoff on the 5-1/2” – The referenced spool and pack-off would be a new tubing spool for the 3-1/2” providing isolation between the 3-1/2”x5- 1/2”. The currently existing (pre-RWO) tubing spool will have been used to land the 5- 1/2” tie-back in. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907- 793-1231 ) or (Melvin.Rixse@alaska.gov). CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Taylor Wellman To:McLellan, Bryan J (OGC) Cc:Rixse, Melvin G (OGC) Subject:RE: [EXTERNAL] MPU E-19 (PTD 197-037) RWO sundry questions Date:Thursday, February 8, 2024 4:55:04 PM Attachments:MPE-19 Wellhead & Tree.pdf Bryan, Please see below and let me know if the diagram is what you were looking for. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, February 8, 2024 7:52 AM To: Taylor Wellman <twellman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU E-19 (PTD 197-037) RWO sundry questions Taylor, I have a couple of concerns about the cementing plan. 1. The diesel and fresh water pumped ahead of the cement will underbalance the well, allowing it to flow through the casing leak and contaminate the cement as it passes the hole. This may result in inadequate cement from the casing hole to surface and sustained casing pressure. You need to take measures to avoid underbalance while pumping cement. I agree with you and holding backpressure on a choke to match the 1:1 or slightly under (losing slightly to the leak vs. underbalancing) is the goal/how we plan to achieve this. The bigger concern to me would be if we left the entire system at a brine and then had to inject in F/P at the end and potentially push TOC down to the leak point. 2. After the cement job is pumped, you may get cement returns to surface because you are pumping faster than the cement leaks out of the hole, but with 15.3 ppg cement in the hole, it is likely to fall back after you stop pumping, draining out through the hole and leaving a void in the annulus at surface. If there is a leak past the wellhead packoff during the negative test in step 18b, you won’t see fluid coming out the casing valve because it will be falling into the annulus void. That being said, you’ll still be able to verify the packoff is holding if the casing test passes, you just might miss a small leak. Either way, you’ll need to be careful to avoid getting non-freezable fluid into that annulus since there’s no way to get it out after the 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. cement sets and needs freeze protection. Risk having freezing fluid in a trapped annulus leading to casing damage. I do understand where you are coming from if there is cement fallback if we do see returns to surface. The big portion from that point forward would be non-freezable fluids for the reasons mentioned to fill up and PT mentioned in #3 below. 3. To answer your question about PT the 7” x 5-1/2” casing, I can write in a step if you tell me what test pressure and when exactly to do it, with what fluid, etc… Post Rig Procedure – Between Well Support and Slickline Perform MIT-OA (5-1/2” x 7” annulus) to 1,000psi w/ diesel Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Taylor Wellman <twellman@hilcorp.com> Sent: Wednesday, February 7, 2024 9:01 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MPU E-19 (PTD 197-037) RWO sundry questions Bryan, Attached is an email that I sent back to Mel yesterday with some questions. Also see answers below in red. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC: Wells Manager – Milne Point Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Sent: Tuesday, February 6, 2024 7:14 AM To: Taylor Wellman <twellman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] MPU E-19 (PTD 197-037) RWO sundry questions Taylor, I see this well is on your weekly priority list and I’m covering for Mel while he is out. A couple questions about the sundry application: 1. Could you send current and proposed wellhead diagrams? - Attached 2. How will the step in 18b verify packoff integrity? At this point of the job, a PT of the 5-1/2” casing will test the 5-1/2” casing up through to on top of the 5-1/2” hanger and pack-off. The pressure on top of the 5-1/2” hanger & pack-off will test it from above. It’s not a traditional test done with a test port but will achieve the same objective. I can draw something up by hand (it won’t be pretty) to help illustrate if you’d like. 3. Did you and Mel already have some correspondence about this sundry? If so, please forward it to Mel and I. - Attached 4. I think it’s unlikely that you will have cement at surface unless the frac pressure at the casing leak is greater than the 15.3 ppg cement density plus ECD while circulating cement in place. Can you pressure test the 7” x 5-1/2” annulus to make sure the leak is isolated at some point after placing cement. I see no issue putting a PT on this after the cement sets up. Would you like to write this into the COA’s or I can add to the program. Whichever way you’d like to handle. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. FMC FMC FMC FMC FMC Tree Cap Swab Valve 2-9/16" 5M SSV 2-9/16" 5M Flow Cross 2-9/16" 5M Master Valve 2-9/16" 5M Tbg Head 11" 5M Top x 11" 5M Btm Casing Head 11" 5M Top x 11" 5M Btm Tree Cap Swab Valve 3-1/16" 5M Flow Cross 3-1/16" 5M SSV 3-1/16" 5M Master Valve 3-1/16" 5M Tbg Head: 3-1/2" 11" 5M Top x 11" 5M Btm Casing Head: 7" 11" 5M Top x 11" 5M Btm Casing Head: 7-1/2" 11" 5M Top x 11" 5M Btm MPU E-19 ProposedCurrent Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 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: 06/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230418 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KU 12-17 50133205770000 208089 4/19/2023 YELLOW JACKET PERF MPU C-42 50029231960000 204028 3/22/2023 YELLOW JACKET PERF MPU E-19 50029227460000 197037 4/11/2023 YELLOW JACKET SCBL-CALIPER MPU H-15 50029232840000 205159 3/8/2023 YELLOW JACKET PERF MPU L-12 50029223340000 193011 4/2/2023 YELLOW JACKET CUT PBU 01-31 50029216260000 186132 5/1/2023 YELLOW JACKET SCBL PBU L-117 50029230390000 201167 3/5/2023 YELLOW JACKET SCBL PBU V-02 50029232090000 204077 3/27/2023 YELLOW JACKET SCBL SRU 231-33 50133101630100 223008 3/31/2023 YELLOW JACKET GPT-PERF SRU 231-33 50133101630100 223008 4/14/2023 YELLOW JACKET GPT-PLUG-PERF Please include current contact information if different from above. T37746 T37747 T37748 T37749 T37750 T37751 T37752 T37753 T37754 T37754 MPU E-19 50029227460000 197037 4/11/2023 YELLOW JACKET SCBL-CALIPER Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.14 14:53:01 -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: Installed Kill String 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 8,249 feet N/A feet true vertical 7,310 feet 8,089 (Fill)feet Effective Depth measured 8,089 feet N/A feet true vertical 2,285 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)2-7/8' 6.5# / L-80 / EUE 6,664' 2,500' Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 323-062 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Scott Pessetto scott.pessetto@hilcorp.com 907-564-4373 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 115' 1520 Size 115' 3,590' 0 15200 0 00 0 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-037 50-029-22746-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047437 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT E-19 Plugs Junk measured LengthCasing Conductor 8,247' 3,955'Surface Production 20" 9-5/8" 7" 115' 3,955' 5,750 psi 7,240 psi8,247' 7,308' Burst 1,530 psi Collapse 520 psi 3,090 psi 5,410 psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 9:23 am, Apr 21, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.20 14:45:41 -08'00' David Haakinson (3533) 197-037 Installed Kill String 323-062 MILNE PT UNIT E-19 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown MILNE POINT / KUPARUK RIVER OIL _____________________________________________________________________________________ Revised By: TDF 4/20/2023 SCHEMATIC Milne Point Unit Well: MPE-19 Last Completed: 4/12/2023 PTD: 197-037 TD =8,249(MD) / TD = 7,310(TVD) 20 Slickline Tag 4/28/2002 @ 8,089 WLM Orig. KB Elev.: 34.05/ GL Elev.: 24.5 7 9-5/81 9-5/8 Howco ES Cementer @ 1,296 KUP C Sands PBTD =8,164 (MD) / PBTD = 7,237(TVD) KUP B Sands 2 & 3 TOC 5,000 MD Leak below 4,640 MD CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247 0.0383 TUBING DETAIL 2-7/8 Tubing 6.5 / L-80 / EUE 2.867 Surface 2,664 0.0058 JEWELRY DETAIL No Depth Item 1 2,660 Mule shoe pup Btm @ 2,664 2 8,164 7 Float Collar 3 8,247 7 Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837 7,860 6,958 6,978 23 5/3/1997 Open Kup. B Sands 7,872 7,902 6,989 7,014 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24 Hole 9-5/8" Cmt w/ 1,195 sks PF E, 725 sx Class G in 12-1/4 Hole 7 Cmt w/ 334 sks Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 350 Max Hole Angle = 32 to 33 deg. f/ 2,500 to 3,650 Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16- 5M Cameron Wellhead 11 x 11 5M FMC Gen 5, w/ 11 x 2-7/8 FMC ESP/HT 2-7/8 EU 8rd threads, 2.5 CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES 5/4/1997 ESP RWO w/ 4-ES 12/3/2004 ESP RWO w/ 3S 6/20/2008 ESP RWO w/ 4-ES 10/17/2010 ESP RWO w/ Doyon 16 7/19/2012 WFD Set Lower Packer / Patch Set 6/30/2013 ESP RWO w/ Doyon 16 4/11/2014 ESP RWO w/ Nordic 3 1/31/2015 ESP RWO w/ Nordic 3 12/26/2015 Install Kill String by ASR 4-12-2023 Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 LRS 50-029-22746-00-00 197-037 4/2/2023 4/12/2023 3/31/2022 - Friday No operations to report. 3/29/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/30/2022 - Thursday No operations to report. Perform accumulator checks. Function test BOPE. Accept rig at 20:00 4/4/23. P/U & M/U landing JT, & R/U to pump. Wait on vac trucks due to high mud plant activity. Cont. to rig up cat walk & spot pipe sheds. Pump 294 bbls of 8.9 ppg NACL brine. Pump down tubing through BPV returning to IA. ICP at 3BPM = 700 psi. FCP 600 psi. Returns to tiger tank = 248 bbls Open IA. Static. R/D pumping equip. & L/D landing JT. Install CTS. Line up to test CTS to 4000 psi. P/U & M/U landing joint. with test pump pressure test CTS t/ 4,000 psi f/ 5 mins good test. R/D equip. Test BOPE as per approved sundry. All tests preformed at 250 psi low & 2500 psi high. AOGCC waived witness No operations to report. 4/1/2022 - Saturday WELLHEAD: Bled packoff void hooked up test equipment and tested packoff 500 low 5min 3500 high 10 mins. Test good. 4/4/2023 - Tuesday 4/2/2023 - Sunday T/I/O=1562/1535/110 (Well Kill) Pumped 20 bbls of 110* diesel followed by 390 bbls of 80* source water down TBG up IA taking returns to tank. Freeze protected surface lines with a total of 10 bbls 60/40. Pumped 3 bbls 60/40 down TBG and 3 bbls 60/40 down IA to freeze protect. Turned well over to Well support to install BPV. Final Whps=86/77/20. WELLHEAD: Lubricated in BPV bled void and attempted to bleed control line through needle valve had flow. pumped 7 gallons of 9.3 brine down line. No flow so N/D tree and adapter. set CTS dart and tested BPV/dart 500 low 5000 high test good. 4/3/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 LRS 50-029-22746-00-00 197-037 4/2/2023 4/12/2023 4/7/2022 - Friday Cont. T/ POOH w/ 2-7/8" heat traced ESP completion. F/ 5,337' T/ 2,990' Filling hole w/ 2x calculated displacement. P/U WT = 20 k S/O = 17 K. Found pin hole on tubing & cap line on JT # 104 depth in OG tally = 4,522'. Service Rig. Cont. T/ POOH w/ 2-7/8" ESP completion. F/ 2,990' T/ 57' Filling hole w/ 2x calculated displacement. Sand packed off joint prior to discharge head. L/D ESP Assy. DS head, 2x pump, GS, Upper & lower TD seals, Motor, Phoenix gauge, & cent. Filling hole w/ 2x calculated displacement. ESP packed w/ sand. Remove sheave from derrick. L/D all ESP equip. Secure clamps & tally. Monitor w/ continuous hole fill. Losing 10 BPH. Service Rig. Clean & clear floor, Extended clean up, due to sand packed off ESP & crude laden equipment. Test used BOP equipment as per. AOGCC Industry guidance bulletin No. 06-01. Tests preformed to 250 psi low & 2500 psi high F/ 5 charted mins. Good test B/D equip. IA open & static. P/U & M/U landing joint to test plug. Pull test plug & L/D. Fill well. 2 bbls to fill. 4/5/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue testing BOPE to 250 low 2500 high as per approved sundry. AOGCC waived witness by Guy Cook. Observed slight weep out if IA, Installed low pressure gauge. IA unable to build to discernable pressure on gauge. Remove gauge. IA continued to flow. Stop testing operations & Line up to bull head kill. R/U hoses on IA & to tubing. Blow through lines to ensure clear. Bullhead 44 bbls of 9.0 ppg brine down tubing. ICP @ 2 BPM = 400 psi & FCP = 500 psi. Switch over to IA. Bullhead 110 bbls of 9.0 ppg brine down IA. ICP @ 2.5 BPM = 300 psi & FCP = 470 psi. Shut down . Blow down lines. IA on a vacuum. L/D landing JT. P/U tee bar, pull BPV for inspection. IA open and static. Replace BPV w/ new. Run & install CTS plug in BPV. L/D tee bar. Test against CTS plug to 2700 psi. Over all pressure test good. During test observed in cellar BOPE weep hole in ram door leaking externally. Service rig. Prep for BOPE repair. Blow down & remove fluid from stack. Open blind ram door. Replace blind ram mud/oil seal assy. Reinstall. Change out ram rubbers on both Blind ram bodies, Close up BOPE & function test. Apply shell pressure test. Good test. Test BOPE to 250 psi low 2500 psi high as per approved sundry. AOGCC waived witness. Preform accumulator drawdown test. Blow down lines. 4/6/2022 - Thursday P/U tee bar, remove CTS plug & BPV. L/D tee bar. IA open & static. P/U & M/U landing JT to hanger. BOLDS. P/U to 60k hanger off seat, P/U WT = 60K. Pull hanger to floor & secure heat trace, ESP cable & cap line. Hole full w/ 5 bbls. Well static. POOH w/ 2-7/8" heat traced ESP completion. F/ 7,744' T/ 6,621' Extend L/D time ,due to crude laden heat race line & 5' heat trace clamps. Filling hole w/ calculated displacement. Observed well flow on IA side. stop pulling operations. Prep to shut in. Affix heat trace cap line & ESP cable to pipe. Well flowing return crude & 8.6 ppg brine. Shut bag. Monitor wellbore through closed choke. Well building to 15 psi. Decision made to bullhead & achieve 9.0 ppg in & out wts. Bull head 75 bbls f/ 9.0 ppg to perfs down tubing. Tubing clear. Shut down pumps & open choke to gas buster. Cont. to pump down tubing to returning to pits. At bottoms up returns = 8.6 ppg. Cont to pump. F/ 288 bbls 88 bbls over btu. Achieve 9.0 ppg in & out. Shut down. Well static open bag. With continuous hole fill establish well loss rate of 14 BPH. Simops: weight up returned 8.6 ppg to 9.0 ppg in pits. Cont. T/ POOH w/ 2-7/8" heat traced ESP completion. F/ 6,621' T/ 5,337' Extend L/D time, due to crude laden heat trace line & 5' heat trace clamps. Filling hole w/ 2x calculated displacement. P/U wt = 36k S/O = 27K. End of heat traced joints. Remove heat trace clamps & equipment from floor. Run heat trace cable over sheave & secure. Cont. T/ POOH w/ 2-7/8" heat traced ESP completion. F/ 5,337' T/ 2,990' Filling hole w/ 2x calculated displacement. P/U off seat, P/U WT = 60K. Pull hanger to floor & secure heat trace, ESP cable & cap line. Hole full w/ 5 bbls. Well static. POOH w/ 2-7/8" heat traced ESP completion. F/ 7,744' T/ 6,621' Extend L/D time ,due to crude laden heat race line & 5' heat trace WT = 20 k S/O = 17 K. Found pin hole on tubing & cap line on JT # 104 depth in OG tally = 4,522'. Service Rig. Cont. T/ POOH w/ 2-7/8" ESP completion. F/ 2,990' T/ 57' Filling hole w/ 2x calculated displacement. Sand packed off joint prior to Cont. T/ POOH w/ 2-7/8" heat traced ESP completion. F/ 6,621' T/ 5,337' Extend L/D time, due to crude laden heat trace line Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 LRS 50-029-22746-00-00 197-037 4/2/2023 4/12/2023 Hilcorp Alaska, LLC Weekly Operations Summary Remove testing tools & tee bar from cat walk. Load Scraper. Tally loaded workstring. P/U 7" casing scraper & M/U 6.125" junk mill on BTM. Check IA, Static. Open well. Fill wellbore w/ 5 bbls. RIH w/ 7" casing scraper on 3-1/2" 9.5# DP T/ 3,379'. lost 12 bbls during trip. Service rig. RIH w/ 7" casing scraper on 3-1/2" 9.5# DP T/ 3,379'. lost 12 bbls during trip. Scraper interval 7,700' - 7,600' 3x. Tagged at 7,883'. Set DW 15k P/U WT = 78k SO = 56k. Screw in w. TD. Pump dw string at 3 BPM w/ 550 psi. Set dw 5k/ Work past obstruction. No further tags. RIH T/ 7,903'. Line up to reverse out sand debris. Pump at 3 BPM w/ 570 psi. Unable to establish returns. Well taking all volume pump 20 bbls. Pump dw string at 3 BPM for BTU. Light amount of sand observed. Return brine wt 9.1 ppg. FCP 300 psi . B/D lines. DP out of balance mix dry job. IA static. P/U wt 80K SO = 59k. Build 25 bbls 9.3ppg dry job. Pump at 3 BPM w/200 psi. Unscrew string on vac. B/D line. Prep to POOH. POOH w/ 7" casing scraper on 3-1/2" 9.5# DP F/ 7,903' T/ 6,060' Monitor displacement via hole fill. Service rig. POOH w/ 7" casing scraper on 3-1/2" 9.5# DP F/ 6,060' T/ 616'. Monitor displacement via continuous hole fill. 4/8/2022 - Saturday 4/9/2023 - Sunday L/D casing scraper, no excess wear. Unload f/ shed. M/U 7" test PKR, actuate PKR ensuring function. RIH W/ test PKR on 3- 1/2" 9.5# DP T/ 1,500' Well giving correct displacement. Service Rig. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 1,500' T/ 7,650'. Lost 5 bbls for trip. Set test PKR @ 7661' Attempt to test casing T/ 3650 psi. Unable to pressure up over 500 psi. Shut dw, IA bleeding pressure. P/U to 7651' & test. Fail. P/U 7,632' same result. Unable to pressure up over 500 psi & IA bleeding off. Unset PKR. PKR staying in run position. Reverse cir at 2 BPM w/ 330 psi to clean out PKR J-slot. Pulling in tension 20K. Able to unset, S/O results in setting. Cont. to work torque in pipe. Able to to unset. POOH 100' to retest. Set test PKR @ 7550' Attempt to test casing T/ 3650 psi. Unable to pressure up over 600 psi. Shut dw, IA bleeding dw. PKR unsetting remains difficult. S/O places PKR in set position. POOH 100' to retest. Pump 20 bbls 9.25 ppg in tubing to balance. Set test PKR @ 7,450' Attempt to test casing T/ 3,650 psi. Unable to pressure up over 600 psi. Shut dw pump, IA bleeding dw. Decision made, PKR issues remain & possible casing leak. POOH for new test PKR. BD test lines. Service rig. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 7,450' T/ 2,782' Pumping double displacement. difficult. S/O places PKR in set position. POOH 100' to retest. Pump 20 bbls 9.25 ppg in tubing to balance. Set test PKR @ 7,450' Attempt to test casing T/ 3,650 psi. Unable to pressure up over 600 psi. Shut dw pump, IA bleeding dw. Decision made, unset, S/O results in setting. Cont. to work torque in pipe. Able to to unset. POOH 100' to retest. Set test PKR @ 7550' Attempt to test casing T/ 3650 psi. Unable to pressure up over 600 psi. Shut dw, IA bleeding dw. PKR unsetting remains 7,450' Attempt to test casing T/ 3,650 psi. Unable to pressure up over 600 psi. Shut dw pump, IA bleeding dw. Decision made, PKR issues remain & possible casing leak. POOH for new test PKR. BD test lines. Service rig. POOH W/ test PKR on 3-1/2" 9.5# L/D casing scraper, no excess wear. Unload f/ shed. M/U 7" test PKR, actuate PKR ensuring function. RIH W/ test PKR on 3- 1/2" 9.5# DP T/ 1,500' Well giving correct displacement. Service Rig. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 1,500' T/ 7,650'. Lost 5 bbls for trip. Set test PKR @ 7661' Attempt to test casing T/ 3650 psi. Unable to pressure up over 500 psi. Shut dw, IA bleeding pressure. P/U to 7651' & test. Fail. P/U 7,632' same result. Unable to pressure up over 500 psi & IA bleeding off. Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 LRS 50-029-22746-00-00 197-037 4/2/2023 4/12/2023 Hilcorp Alaska, LLC Weekly Operations Summary Set Test PKR @ 4,640' w/ 20K DW. Pressure test T/ 3,650 psi. Hold for 30 charted mins. Good MIT at 4,640'. RIH 60' & retest. Set Test PKR @ 4,700' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 600 psi. Establish injection rate at 1.5 BPM W/ 525 psi. W/ Pumps off IA bleeding off. Failed test. POOH. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 4,700 T/ 1,260' Well taking correct displacement. Service rig. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 1,260 T/ Surface. ' Well taking correct displacement. L/D test PKR, Inspect, No issues. Clean & clear floor. Prep for E-line. PJSM. Hang sheave. M/U cement bond log tools. CH, CCL, Cent, SCBL, Cent & GR. RIH W/ Bond log on E-line . Tag bottom 7,865' POOH logging at 60 FPM. Monitor hole via hole fill. Swap E-line Tools. M/U Caliper BHA. CH, CCL, Cent, XIPE 40 Arm caliper, Cent. RIH W/ Caliper on E-line . Tag bottom 7,865' POOH logging at 45 FPM. Monitor hole via hole fill. R/D E-line, Clean & clear floor. Service rig. RIH W/ 2-7/8" 6.5# L-80 Kill string. M/U cut mule shoe. & RIH T/ 2,664' Lost 1.5 bbls for trip. P/U WT = 14k S/O WT = 11k POOH W/ test PKR on 3-1/2" 9.5# DP F/ 7,450' T/ 2,782'. Pumping double displacement. L/D 7" test PKR, Inspect, found debris in collet blocking operation of manual setting on surface by hand. Unload f/ shed. M/U new test. RIH W/ test PKR on 3- 1/2" 9.5# DP T/ 500' Well giving correct displacement. Set test PKR pressure test t/ 500 psi to ensure function. Good test. Unset PKR. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 500' T/ 860' Well giving correct displacement. Service rig. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 860' T/ 7650' P/U WT = 78K S/O WT = 48K Well giving correct displacement. Set Test PKR @ 7,652' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 400 psi. W/ Pumps off IA bleeding off. Failed test. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 7,652' T/ 6,930' P/U WT = 73K S/O WT = 42K Well taking correct displacement. Trip out 500' from prior failed test with 1st test PKR & retest. Set Test PKR @ 6,930' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 400 psi. W/ Pumps off IA bleeding off. Failed test. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 6,930' T/ 6,485' P/U WT = 68K S/O WT = 40K Well taking correct displacement. Set Test PKR @ 6,485' w/ 30K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 450 psi. W/ Pumps off IA bleeding off. Failed test. Trip out 1,000' & retest. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 6,485' T/ 5,485' P/U WT = 68K S/O WT = 40K Well taking correct displacement. Set Test PKR @ 5,485' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 470 psi. W/ Pumps off IA bleeding off. Failed test. Trip out 1000', directly below TOC & retest. Service RIG. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 5,485' T/ 4,490' P/U WT = 68K S/O WT = 40K Well taking correct displacement. Set Test PKR @ 4,490' w/ 20K DW. Pressure test T/ 3,650 psi. Hold for 5 charted mins. Good test. RIH 500' & retest. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 4,490' T/ 4,996' P/U WT = 49K S/O WT = 32K Well giving correct displacement. Set Test PKR @ 4,996' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 500 psi. W/ Pumps off IA bleeding off. Failed test. POOH 240' & retest. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 4,996' T/ 4,764' P/U WT = 44 K S/O WT = 28 K Well taking correct displacement. Set Test PKR @ 4,764' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 500 psi. W/ Pumps off IA bleeding off. Failed test. POOH ~ 125' & retest. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 4,764 T/ 4,640' P/U WT = 40 K S/O WT = 32 K Well taking correct displacement. 4/11/2023 - Tuesday 4/10/2023 - Monday WT = 68K S/O WT = 40K Well taking correct displacement. Set Test PKR @ 6,485' w/ 30K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 450 psi. W/ Pumps off IA bleeding Well taking correct displacement. Set Test PKR @ 5,485' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 470 psi. W/ Pumps off IA bleeding off. Failed test. Trip out POOH W/ test PKR on 3-1/2" 9.5# DP F/ 7,450' T/ 2,782'. Pumping double displacement. L/D 7" test PKR, Inspect, found debris in collet blocking operation of manual setting on surface by hand. Unload f/ shed. M/U new test. RIH W/ test PKR on 3- M/U cement bond log tools. CH, CCL, Cent, SCBL, Cent & GR. RIH W/ Bond log on E-line . Tag bottom 7,865' POOH logging at 60 FPM. Monitor hole via hole fill. Swap E-line Tools. M/U Caliper BHA. CH, CCL, Cent, XIPE 40 Arm caliper, Cent. RIH W/ Caliper on E-line . Tag bottom 7,865' POOH logging at 45 FPM. Monitor hole via hole fill. R/D E-line, Clean & clear floor. Serv Unset PKR. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 500' T/ 860' Well giving correct displacement. Service rig. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 860' T/ 7650' P/U WT = 78K S/O WT = 48K Well giving correct displacement. Set Test PKR @ 7,652' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM 6,930' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 400 psi. W/ Pumps off IA bleeding off. Failed test. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 6,930' T/ 6,485' P/U Well taking correct displacement. L/D test PKR, Inspect, No issues. Clean & clear floor. Prep for E-line. PJSM. Hang sheave. WT = 40K Well taking correct displacement. Set Test PKR @ 4,490' w/ 20K DW. Pressure test T/ 3,650 psi. Hold for 5 charted mins. Good test. RIH 500' & retest. RIH W/ test PKR on 3-1/2" 9.5# DP F/ 4,490' T/ 4,996' P/U WT = 49K S/O WT = 32K Well Set Test PKR @ 4,640' w/ 20K DW. Pressure test T/ 3,650 psi. Hold for 30 charted mins. Good MIT at 4,640'. RIH 60' & retest. Set Test PKR @ 4,700' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 600 psi. Establish 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 400 psi. W/ Pumps off IA bleeding off. Failed test. POOH W/ test PKR on 3-1/2" 9.5# DP F/ 7,652' T/ 6,930' P/U WT = 73K debris in collet blocking operation of manual setting on surface by hand. Unload f/ shed. M/U new test. RIH W/ test PKR on 3- 1/2" 9.5# DP T/ 500' Well giving correct displacement. Set test PKR pressure test t/ 500 psi to ensure function. Good test. rig. RIH W/ 2-7/8" 6.5# L-80 Kill string. M/U cut mule shoe. & RIH T/ 2,664' Lost 1.5 bbls for trip. P/U WT = 14k S/O WT = 11k S/O WT = 42K Well taking correct displacement. Trip out 500' from prior failed test with 1st test PKR & retest. Set Test PKR @ 6,930' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at giving correct displacement. Set Test PKR @ 4,996' w/ 20K DW. Attempt to pressure test T/ 3,650 psi. Unable to build Pressure above 500 psi. Establish injection rate at 1.25 BPM W/ 500 psi. W/ Pumps off IA bleeding off. Failed test. POOH 240' Well Name Rig API Number Well Permit Number Start Date End Date MP E-19 LRS 50-029-22746-00-00 197-037 4/2/2023 4/12/2023 4/14/2022 - Friday No operations to report. 4/12/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Begin R/D operations, Detach tongs, R/D bird bath and top riser spool, Drained gas buster and blew down choke, kill and mud lines, empty pits and uprights. Rig released @ 12:00 hrs 4/13/2022 - Thursday No operations to report. No operations to report. No operations to report. 4/15/2022 - Saturday No operations to report. 4/18/2023 - Tuesday 4/16/2023 - Sunday No operations to report. 4/17/2023 - Monday Begin R/D operations, Detach tongs, R/D bird bath and top riser spool, Drained gas buster and blew down choke, kill and mud lines, empty pits and uprights. Rig released @ 12:00 hrs 1 Regg, James B (OGC) From:Scott Heim - (C) <Scott.Heim@hilcorp.com> Sent:Friday, April 7, 2023 8:18 AM To:DOA AOGCC Prudhoe Bay; David Haakinson; Monty Myers; William Kruskie; Nick Frazier Cc:Russell Gallen - (C); Aaron Haberthur - (C); Scott Heim - (C) Subject:BOP used for well control. Good Morning, This is a report for use of the BOP for well control. Date / TimeͲ4Ͳ6Ͳ20231700 HRS MPU – EͲ19, PTD #Ͳ197Ͳ037 Rig – ASR Scott Heim – 907Ͳ685Ͳ1266 or 907Ͳ982Ͳ9226 Cell. The ASR rig had started out of the hole pulling the 2 7/8’’ tubing with the ESP cable, Heat trace cable and the CAP line, spooling all into the spooling unit. At 17:00 HRS, after laying down 30 joints, we confirmed that our displacement was off, and in fact observed a 2 BBL gain in the pits. ASR stopped pulling pipe, observed the well and confirmed a small stream of flow, no gas. We cut the cable and CAP string, secured to the tubing, and immediately installed the safety joint with the valve on it. The well was shut in using the annular. After 30 minutes, we observed a 15 LB increase in pressure. Discussed with the OE and agreed to pump 9.0 PPG fluid to the perforation, and pumped 80 BBLS, bull heading. We then lined up and circulated through the choke, observing 8.6 PPG fluid on the returns, and 9.0 PPG being pumped. We continued circulating the hole until we recognized good 9.0 PPG fluid in and out of the well. Well was static.Opened the annular and continued circulating across the top of the hole observing the well was now at a 14 BPH loss rate. Shut down and monitored well seeing fluid drop in the well. At 21;30 HRS, continued pulling out of the hole with the 2 7/8’’ tubing, cables and cap line with no issues, keeping the hole full continuously with the same fluid loss at 14 BPH. Our plan forward is to continue POOH laying down the 2 7/8’’ assembly. Then we will set a test plug and test the annular as per our Sundry 323Ͳ062, to 250 /2500 PSI. Scott Heim Rig Supervisor – ASR 907Ͳ685Ͳ1266 Office 907Ͳ982Ͳ9226 Mobile Scott.heim@hicorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Some people who received this message don't often get email from scott.heim@hilcorp.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 0LOQH3RLQW8QLW( 37' 9 9 9 9 pulling the 2 7/8’’tubing displacement was off,and in fact observed a 2 BBL gain in the pits. The well was shut in using the annular. 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: Convert to Jet Pump 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? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,249 8,089 (Fill) Casing Collapse Conductor 520 psi Surface 3,090 psi Production 5,410 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager 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 9-5/8" 7" 3,955' 8,247' Perforation Depth MD (ft): MD 1,530 psi 5,750 psi 7,240 psi 3,590' 7,308' 3,955' 8,247' Length Size Proposed Pools: 115' 115' TVD Burst PRESENT WELL CONDITION SUMMARY 7,310 8,089 7,174 2,285 N/A 115' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047437 197-037 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22746-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT E-19 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.6#/ L-80/ IBT 7,746' 2/19/2023 N/A and N/A N/A and N/A See Schematic See Schematic 4-1/2" 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 scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Taylor Wellman for David Haakinson By Samantha Carlisle at 7:36 am, Feb 01, 2023 323-062 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2023.01.31 19:55:38 -09'00' Taylor Wellman (2143) X DLB 02/02/2023MGR13FEB23 * BOPE test to 2500 psi. 10-404 Conditions of Approval * Approved for reverse circulating jet pump. * 30 minute charted inner casing pressure test from surface to 7650' MD to maximum power fluid injection pressure of 3650 psi. * IA SSV high pressure trip pressure not to exceed 3650 psi. IA low pressure trip pressure not to be lower than 1800 psi. * Production tubing SSV low pressure trip not to be lower than 100 psi. * SSV closure on IA will initiate closure within 2 minutes on SSV on production tubing and visa versa. * Reservoir pressure gradient to remain below 8.55 ppg to operate well with jet pump. *Quadrennial MIT-IA to 3650 psi. 2,285 DSR-2/1/23GCW 02/14/23JLC 2/14/2023 2/14/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.14 15:31:03 -09'00' RBDMS JSB 022123 Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 Well Name:MPE-19 API Number:50-029-22746-00-00 Current Status:Shut-in Producer Rig:ASR Estimated Start Date:2/19/2023 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:197-037 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer:Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Current Bottom Hole Pressure: 2,976 psi @ 6,910’ TVD ESP Intake Sensor |8.28 PPGE Max Proposed Surface Pressure: 2,285 psi Gas Column Gradient (0.1 psi/ft) Max Angle:33° @ 3,500’ MD Brief Well Summary: E-19 is a shut-in Kuparuk slant producer that has been shut-in since 2017. The well has solids on top of the pump (6/7/22 slickline tagged fill @ 7636’). Fill remains 42’ above discharge head @ 7,688’ RKB. The last four ESPs have lasted an average on 314 days making another ESP workover uneconomic. The proposed workover will recomplete E-19 as a reverse circulating jet pump. Objectives: Pull failed ESP completion, run 4-1/2” jet pump completion. Notes Regarding Wellbore Condition: Last production casing test was 2,500 psi on 7/18/2012. Pre-Rig Procedure Pumping & Well Support 1. Power on ESP, read latest downhole pressure reading prior to disconnecting well for RWO. 2. Clear and level pad area in front of well. Spot rig mats and containment. 3. RD well house and flowlines. Clear and level area around well. 4. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 5. Pressure test lines to 3,000 psi. 6. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 7. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 8. RD Little Red Services and reverse out skid. 9. Set BPV. ND tree. Brief RWO Procedure 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. NU BOPE. ESP Intake Sensor |8.28 PPGE Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 4. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 6. Call out Centrilift for ESP pull. 7. RU spoolers to handle ESP cable, 3/8” capillary string, and 2,500’ of heat trace. a. Use extreme care in spooling the capillary string to promote reuse of the string. 8. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Expected PU ~75k – 2015 Nordic 3 WO recorded 115k PU (including blocks) prior to landing hanger. 9. Confirm hanger free, lay down tubing hanger. 10. POOH and lay down the 2-7/8” tubing. Number all joints. a. Keep joints 1-40 b. Previous tubing caliper shows joints past joint #40 are not worth keeping. c. Keep ported discharge head and centralizer for future use. d. Note any sand or scale inside or on the outside of the ESP on the morning report. e. Look for over-torqued connections from previous tubing runs. f. Recover the following amount of clamps from the completion: i. 5’ Dual Channel: 351 ii. 2’ Dual Channel: 70 iii. 2’ Cannon: 90 iv. Protectrolizers: 5 v. Flat Guard: 2 vi. Pump Clamps: 4 vii. SS Bands: 6 11. Lay Down ESP. 12. Pressure test pulled 3/8” capillary tubing to 3500 psi. If PT passes, plan to save for future work. 13. PU 3-1/2” workstring, 7” casing scraper, and muleshoe. RIH to 7,902’ MD (bottom of B-sand perforations). a. Last tag 1/30/2015 @ 8,017’ MD b. Scrape casing interval from 7700’ to 7600’ MD. Planned packer set depth is 7,617’ MD. 14. POOH while filling hole with 2x pipe displacement. 15. PU and RIH with 7” x 3-1/2” test packer to 7,650’ MD. 16. Test casing to 3650 psi. Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 a. If casing test fails, pull up hole 100’ and retest. Repeat if needed. b. Do not set packer above TOC. c. 7” Production Casing Calculated TOC: 4,484’ MD (122 bbl cement, 30% loss) 17. POOH with test packer, rig down slickline. 18. RIH with 4.5” JP completion to 7,717’ and obtain string weights. a. Note PU and SO weights on tally Nom. Size ~Length Item Lb/ft Material Notes 4-1/2”41 4-1/2" WLEG - Mule Shoe 12.6 L-80 4-1/2” 41 4-1/2" TXP 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”2 3.813” X Nipple 12.6 L-80 RHC Plug Installed 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP L-80 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”7 Hydraulic Set Packer 7" x 4-1/2"L-80 TriPoint Permanent 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP L-80 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”2 Baker Zenith Gauge Carrier L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”2 3.813” X Nipple 12.6 L-80 No plug 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 41 4-1/2" TXP L-80 12.6 L-80 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2”5 4-1/2" Sliding Sleeve - 3.813” X L-80 Blanked Port 4-1/2”10 4-1/2' TXP Pup Jt 12.6 L-80 4-1/2” 4-1/2" TXP Joints 12.6 L-80 4-1/2” Hanger Pup 12.6 L-80 4-1/2” Tubing Hanger 12.6 L-80 b. Clamp I-wire every other joint 19. Space out and make up tubing hanger. Terminate I-wire cap string to hanger. Test I-wire. RILDS. 20. Pump 5 barrels 1% KCL with corrosion inhibitor down the annulus, followed by 90 barrels KCL, and 46 barrels of freeze protect fluid taking returns up the tubing. a. This is to protect the area between the packer and sliding sleeve from corrosion. 21. Drop ball & rod, and load tubing with FP while pumping ball and rod down to seat. Take returns to formation. Pressure up and set packer per vendor instructions. Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 22. Perform 30 minute charted MIT-T to 3,000 psi. 23. Perform 30 minute charted MIT-IA to 3,650 psi. 24. Set BPV. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline 1. RU SL and test PCE to 3,000 psi. 2. RIH and Retrieve Ball and Rod and RHC Plug. 3. Open sliding sleeve. 4. RIH W/ 7A Jet Pump and set. 5. RD SL Unit. 6. Turn Well over to production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 Current Schematic TD = 8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’ 7” 3 5 & 6 7 8& 9 9 9-5/8” 1 9-5/8” Howco ‘ES’ Cementer @ 1,296’ MIN ID= 2.250 @ 7,646’ KUP C Sands PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 10 2 1413 12 4 3/8” SS Capstring 11 Heat Trace @ 2,341’ CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surface 7,746’ 0.00579 3/8” Capstring Stainless Steel N/A Surface 7,746’ N/A JEWELRY DETAIL No Depth Item 1 139’STA #2: Camco 2-7/8” x 1” KBMM GLM w/C/O to Dummy 2-4-17 2 7,492’STA #1: Camco 2-7/8” x 1” KBMM GLM Pulled Dummy 2-04-17 3 7,646’ XN-Nipple: w/ 2.313” landing Profile (2.250 No-go ID) 4 7,688’ Discharge Head: FPHVDIS 5 7,689’ Pump #1: SXD 124-P4 6 7,702’ Pump #2: SXD 124-P4 7 7,715 Gas Separator: GRSFTXAR H6 8 7,720’ Upper Seal Section: GSB3DBUT SB/SB PFSA 9 7,727’ Lower Seal Section: GSB3DBLT SB/SB PFSA 10 7,734’ Motor - MSP3-250: 84HP, 2,210 volt & 23 amps 11 7,742’ Phoenix Sensor 12 7,744’ Centralizer / Bottom @ 7,746’ 13 8,164’ 7” Float Collar 14 8,247’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packert / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 Proposed Schematic TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’ 7” 3 9-5/8” 1 9-5/8” Howco ‘ES’ Cementer @ 1,296’ MIN ID= 3.750 KUP C Sands PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 4 0 2 76 5 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.833 Surface 7,717’ JEWELRY DETAIL No Depth Item 1 7,507’ 4-1/2” Sliding Sleeve, 3.813” X 2 7,557’ Baker Zenith Gauge Carrier 3 7,617’ 4-1/2” x 7-5/8” Tubing Packer 4 7,667’ XN Nipple – Min ID – 3.75” 5 7,717’ Wireline entry guide 6 8,164’ 7” Float Collar 7 8,247’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 BOPE Schematic Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 Current Schematic TD = 8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’ 7” 3 5 & 6 7 8& 9 9 9-5/8” 1 9-5/8” Howco ‘ES’ Cementer @ 1,296’ MIN ID= 2.250 @ 7,646’ KUP C Sands PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 10 2 1413 12 4 3/8” SS Capstring 11 Heat Trace @ 2,341’ CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.347 Surface 7,746’ 0.00579 3/8” Capstring Stainless Steel N/A Surface 7,746’ N/A JEWELRY DETAIL No Depth Item 1 139’STA #2: Camco 2-7/8” x 1” KBMM GLM w/C/O to Dummy 2-4-17 2 7,492’STA #1: Camco 2-7/8” x 1” KBMM GLM Pulled Dummy 2-04-17 3 7,646’ XN-Nipple: w/ 2.313” landing Profile (2.250 No-go ID) 4 7,688’ Discharge Head: FPHVDIS 5 7,689’ Pump #1: SXD 124-P4 6 7,702’ Pump #2: SXD 124-P4 7 7,715 Gas Separator: GRSFTXAR H6 8 7,720’ Upper Seal Section: GSB3DBUT SB/SB PFSA 9 7,727’ Lower Seal Section: GSB3DBLT SB/SB PFSA 10 7,734’ Motor - MSP3-250: 84HP, 2,210 volt & 23 amps 11 7,742’ Phoenix Sensor 12 7,744’ Centralizer / Bottom @ 7,746’ 13 8,164’ 7” Float Collar 14 8,247’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packert / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Duplicate Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 Proposed Schematic TD =8,249’(MD) / TD = 7,310’(TVD) 20” Slickline Tag 4/28/2002 @ 8,089’ WLM Orig. KB Elev.: 34.05’/ GL Elev.: 24.5’ 7” 3 9-5/8” 1 9-5/8” Howco ‘ES’ Cementer @ 1,296’ MIN ID= 3.750 KUP C Sands PBTD =8,164’ (MD) / PBTD = 7,237’(TVD) KUP B Sands 4 0 2 76 5 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor 91.1 / H-40 / N/A N/A Surface 115' 0.355 9-5/8" Surface 40 / L-80 / Btc. 8.679 Surface 3,955’ 0.0759 7" Production 26 / L-80 / Btc 6.151 Surface 8,247’ 0.0383 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP 3.833 Surface 7,717’ JEWELRY DETAIL No Depth Item 1 7,507’ 4-1/2” Sliding Sleeve, 3.813” X 2 7,557’ Baker Zenith Gauge Carrier 3 7,617’ 4-1/2” x 7-5/8” Tubing Packer 4 7,667’ XN Nipple – Min ID – 3.75” 5 7,717’ Wireline entry guide 6 8,164’ 7” Float Collar 7 8,247’ 7” Float Shoe PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 7,837’ 7,860’ 6,958’ 6,978’ 23 5/3/1997 Open Kup. B Sands 7,872’ 7,902’ 6,989’ 7,014’ 30 5/3/1997 Open OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 250 sks of Arcticset I in 24” Hole 9-5/8" Cmt w/ 1,195 sks PF “E”, 725 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 334 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 350’ Max Hole Angle = 32 to 33 deg. f/ 2,500’ to 3,650’ Hole Angle through perforations = 31 deg. TREE & WELLHEAD Tree 2-9/16”- 5M Cameron Wellhead 11” x 11”” 5M FMC Gen 5, w/ 11” x 2-7/8” FMC ESP/HT 2-7/8” EU 8rd threads, 2.5” CIW H BPV Profile GENERAL WELL INFO API: 50-029-22746-00-00 Drilled and Cased by Nabors 27E - 3/21/1997 Completed with ESP by Nabors 4ES – 5/4/1997 ESP RWO w/ 4-ES – 12/3/2004 ESP RWO w/ 3S – 6/20/2008 ESP RWO w/ 4-ES – 10/17/2010 ESP RWO w/ Doyon 16 – 7/19/2012 WFD Set Lower Packer / Patch Set – 6/30/2013 ESP RWO w/ Doyon 16 – 4/11/2014 ESP RWO w/ Nordic 3 – 1/31/2015 ESP RWO w/ Nordic 3 – 12/26/2015 Duplicate Well: MPE-19 PTD: 197-037 API: 50-029-22746-00-00 BOPE Schematic Duplicate STATE OF ALASKA • AlIkKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon u Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ESP Change Out Q 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory❑ 197-037 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22746-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047437 MILNE PT UNIT KR E-19 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL JAN 2 1 2016 11.Present Well Condition Summary: Total Depth measured AOGCC P 8,249 feet Plugs measured N/A feet true vertical 7,310 feet Junk measured 8,089'(Fill) feet Effective Depth measured 8,089 feet Packer measured N/A feet true vertical 7,174 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 115' 20" 115' 115' 1,530psi 520psi Surface 3,955' 9-5/8" 3,955' 3,590' 5,750psi 3,090psi Production 8,247' 7" 8,247' 7,308' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached SchematicSCASy}.V y LI F Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80/IBT 7,746' 6,881' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,080 0 Subsequent to operation: 78 115 226 200 193 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ 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: �/ 315-716 Contact Ted Kramer-. Email tkramer(a�hilcorp.com Printed Name Bo York Title Operations Engineer Signature Oi" Phone 777-8345 Date 1/21/2016 �..a g-/c 4'44 RBDM L-- JAN 2 2 2016 Form 10-404 Revised 5/2015 Submit Original Only H . Milne Point Unit • Well: MPE-19 SCHEMATIC Last Completed: 12/26/2015 lilcorp Alaska,LLC PTD: 197-037 TREE&WELLHEAD Orig.KB Elev.:34.05'/GL Elev.:24.5' Tree 2-9/16"-5M Cameron Wellhead 11"x 11""5M FMC Gen 5,w/11"x 2-7/8"FMC ESP/HT A 2-7/8"EU 8rd threads,2.5"CIW H BPV Profile 20" OPEN HOLE/CEMENT DETAIL I,' 1, 20" Cmt w/250 sks of Arcticset I in 24"Hole 1 9-5/8" Cmt w/1,195 sks PF"E",725 sx Class"G"in 12-1/4"Hole 7" Cmt w/334 sks Class"G"in 8-1/2"Hole r: ,# ',, CASING DETAIL ►, Size Type Wt/Grade/Conn Drift ID Top Btm BPF f 20" Conductor 91.1/H-40/N/A N/A Surface 115' 0.355 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 3,955' 0.0759 35/8 7" Production 26/L-80/Btc 6.151 Surface 8,247' 0.0383 9-5/8"Howco'ES' Heat Trace@ TUBING DETAIL 2,341 Cementer @1,296' 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 Surface 7,746' 0.00579 3/8" Capstring Stainless Steel N/A Surface 7,746' N/A 3/8ng WELL INCLINATION DETAIL KOP @ 350' Max Hole Angle=32 to 33 deg. f/2,500'to 3,650' Hole Angle through perforations=31 deg. JEWELRY DETAIL No Depth Item 1 139' STA#2:Camco 2-7/8"x 1"Sidepocket KBMM GLM w/SOV Dummy 2 7,492' STA#1:Camco 2-7/8"x 1"Sidepocket KBMM GLM Dummy 3 7,646' XN-Nipple: w/2.313" landing Profile(2.250 No-go ID) 4 7,688' Discharge Head:FPHVDIS 5 7,689' Pump#1:SXD 124-P4 6 7,702' Pump#2:SXD 124-P4 7 7,715 Gas Separator:GRSFTXAR H6 8 7,720' Upper Seal Section:GSB3DBUT SB/SB PFSA 9 7,727' Lower Seal Section:GSB3DBLT SB/SB PFSA 2 10 7,734' Motor-MSP3-250:84HP,2,210 volt&23 amps 11 7,742' Phoenix Sensor 12 7,744' Centralizer/Bottom @ 7,746' 13 8,164' 7"Float Collar MIN I D=2.250 ,t It @ 7 say 14 8,247' 7"Float Shoe 3 h PERFORATION DETAIL gi*, 4 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ' i Kup.C Sands 7,837' 7,860' 6,958' 6,978' 23 5/3/1997 Open 5&6 Kup.B Sands 7,872' 7,902' 6,989' 7,014' 30 5/3/1997 Open ,lii'. 7 GENERAL WELL INFO ,8&9 API:50-029-22746-00-00 taw Drilled and Cased by Nabors 27E -3/21/1997 Completed with ESP by Nabors 4ES-5/4/1997 f4•10 ESP RWO w/4-ES-12/3/2004 ESP RWO w/3S-6/20/2008 14$ ESP RWO w/4-ES-10/17/2010 = 11 ESP RWO w/Doyon 16-7/19/2012 ,k1, 12 WFD Set Lower Packert/Patch Set-6/30/2013 A ESP RWO w/Doyon 16-4/11/2014 &Mine Tag .KUP C Sands 4/28/2002 @ to ESP RWO w/Nordic 3-1/31/2015 8,089'VtIM 1 KUP B Sands ESP RWO w/Nordic 3-12/26/2015 sem► it y' t,13 14 TD=8,249'(MD)/TD=7,310'(TVD) PBTD=8,164'(MD)/PBTD=7,237'(TVD) Revised By:TDF 1/20/2016 • • Hilcorp Alaska, LLC IlHcorpAlaska,l.LC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPE-19 Nordic 3 50-029-22746-00-00 197-037 12/22/2015 12/26/2015 12/23/15-Wednesday Remove leaking portion of choke line and replace with backup piece that was available on location.Note:continue to monitor I/A,maintain hole fill 20 bph.Continue to attempt full body test on BOPE.Observing na 90-100 psi loss in 5 minutes. Check surface equipment.No leaks observed.NOTE:Notified Drilling Engineer Stan Porhola of the situation.Notified AOGCC Rep.Lou Grimaldi that were observing a slow leak.Lou Grimaldi agreed that if it didn't get better to coninue on per the Well Program contingency&waived witness of test.Continue checking surface equipment for leaks.No leaks observed.PU 2 7/8"test joint&screw into hanger.Close bottom rams to isolate leak.Appears that leak is going down hole.Attempt a low press.test at 250 psi.Good test.Press.to 1800 psi.Good test. Increase pressure to 3000 psi.Hold press.f/10 min. Observed slow bleed off but achieved a straight line on chart for 5 minutes.Discussed with town Engineer Stan Porhola.Decision made to test BOPE as long as pressure stabilized and achieved a straight line for 5 minutes.Testing BOPE per AOGCC Sundry Approval#315-716. Test BOP components,12 choke manifold valves,upper and lower IBOP,FOSV,dart valve, mud cross valves,HCR kill,HCR choke to 250 psi low and 3000 psi high 5 min ea.Test annular to 250 psi low,2500 psi high 5 min ea.Chart record all tests.Perform accumulator draw down test,3000 psi system pressure,1900 psi after closure,200 psi attained in 17 sec,full pressure attained in 95 sec.N2 average 4 @ 1900 psi.Note:1 F/P on choke valve#8,function and re-test good. Electrician calibrate and test LEL gas alarms.All tests performed w/2 7/8"test joint.R/D test equipment blow down lines.Pull TWC per wellhead rep.M/U 2 7/8"landing jt.BOLDS,PJSM with rig crew,Centrilift,wellhead hand,TP and DSM.Unseat hanger @ 125kL pull hanger to rig floor from 7749'@ 120k_ P/U wt.Check ESP continuity,terminate cap line,cut ESP and heat trace cables.Pull 1 std,string cables thru sheave.L/D 1st GLM and pups. Note:Maintain hole fill 20 bph using trip tank.POH with ESP assembly from 7600'to 4534'spooling ESP/heat trace cables and cap line,Rack 2 7/8"tubing in derrick,SLM and tally same.(end of heat trace @ 5329') Note:continue to maintain hole fill 20 bph using trip tank while POOH. 1 /15; " esY ,1,41 ��pu� � Decompletion:POH f/7554'standing back 2 7/8"EUE tubing.Recover ESP&Heat Trace Cable+3/8"CAP line.PUW 120k. NOTE:LD last 3 singles below lower GLM.Bottom 3 were fully packed w/sand.Will replace bottom 3 jts when RIH w/completion.LD ESP assembly. Continue to LD ESP assembly(entire assembly packed off w/sand&shaft would not turn). Recovered:All tubing jts,pups and jewelry: 357-5'Dual Channels: 107-2'Dual Channels(Cross Collars): 85 Cannon Clamps: 2 Heat Trace Clamps: 4 Pump Clamps: 84 S.S.Clamps, 3 Protectorlizers&2 Flat Guards.Pull cables back to Ground Spooler.Wrap spools in absorb&plastic.Clean/Clear floor. Kick out tools not needed for upcoming operation.Strap replacement jts. New GLM's,pups,etc.PU ESP Motor assembly.Service motor&seals while waiting on broke down crane to change out CAP Spool.Centrilift Purge and test 3/8 cap string that was POOH.Test cap string to 4000 psi,good test Note:Continue to monitor and fill I/A @ 20 bph.Re-run cap string.Connect cap string to check valve,function @ 2500 psi,pull ESP cable over sheave, connect MLE,Install flatgaurd,protectolizer and pump clamps,M/U pup jt,meg test cable. M/U1 jt tubing,XN nipple and pup jt.Run 4 singles,M/U pup jt,GLM w/dummy valve,pup jt. Note:drift all 2 7/8"tbg with 2.347"drift,RIH with ESP completion per tally from 263'to 3880'with 2 7/8"6.5#L80 EUE tbg from derrick,Top joint on stand#40,it would not drift.L/D single. 12/2015 1114; 0" Continue to RIH w/2 7/8"ESP Completion w/ / "CAP line per tally to 4,634HPUW 75k-SOW 70k.Test cables&CAP line every 2000'. Drift from derrick w/2.347"drift.LD stands that would not drift and drift in pipe shed.Replace as needed.Continue to RIH w/2 7/8"ESP Completion w/ 3/8"CAP line per tally f/4634'to 5440'.PUW 75k-SOW 70k.Test cables&CAP line every 2000. Drift from derrick w/2.347"drift.LD stands that would not drift and drift in pipe shed.Replace as needed. At 5045',tubing began to drift with less difficulty.Continue to RIH to 5440'.Pull Heat Trace Cable to rig floor f/ground spool.Pull over sheave.Install starting clamp on string,Continue to RIH with 2 7/8"ESP Completion w/3/8"CAP line per tally f/5440'to 7588',M/U pup jt,GLM and pup jt.run last stand to 7712'(236 total jts of tubing ran),M/U Pup,hanger and landing jt.P/U 115k,S/O 90k.(Note:35k top drive wt included)M/U ESP cable and heat trace penetrators on hanger,terminate 3/8"cap line and pressure test same to 2000 psi.Meg test ESP and heat trace cables,Splice ESP and heat trace cables,install lower plugs for penetrators. , un� iPlu�Vq�I( �� E -it--- 12/26:745^Sa "i�u� tihi Splice ESP and heat trace cables,connect cables to hanger,meg test cables. Note:(5'dual channel clamps=351) (2'dual channel clamps=70)(2'cannon clamps=9.0)(SS bands=6)(pump clamps=4)(flat guards=2) protectolizers=5),Land hanger 28.2'in @ 7745.58'.RILDS per wellhead rep.L/D landingjt,Install TWC.ND BOPE,NU tree.Test Void&Tree w/diesel to 250 psi low,5000 psi high on chart.Continue to to test Tree&Void.RD test equipment.Pull TWC per Wellhead Rep.Perform final MEG test on ESP&Heat Trace cables.Dress Tree.Secure Well,RDMO Well#MP E-19. NOTE:released rig at 14:30 hrs. i �� OF "F-11 �� • • �w�`'��/j��s� THE STATE Alaska Oil and Gas �� , ofLASKA Conservation Commission \itiV:t-: • -) RECEIVFn STATE OF ALASKA NOV 2 O 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS '''‘ PPROVALSir",C 20 AAC 25.280 1 V 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ ' Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Change Out Lit 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ . 197-037 • 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 50-029-22746-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT KR E-19 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0047437 MILNE POINT/KUPARUK RIVER OIL 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): 8,249• 7,310 8,089 7,174 , 800 N/A 8,089(Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1,530 psi 520 psi Surface 3,955' 9-5/8" 3,955' 3,590' 5,750 psi 3,090 psi Intermediate Production 8,247' 7" 8,247' 7,308' 7,240 psi 5,410 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic J See Attached Schematic 2-7/8" 6.5#/L-80/8RD 7,749' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development [A. Service [ i 14. Estimated Date for 15.Well Status after proposed work: 12/12/2015 Commencing Operations: OIL Q ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact STAN PORHOLA Email sporhola@hilcorp,com Printed Name Title BO YORK OPERATIONS MANAGER Signature '-',,; - •L u Ye,-//. _ Phone 907-777-8345 Date 11/20/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 - -11(4 Plug Integrity ❑ BOP Test �r Mechanical Integrity Test ❑ Location Clearance ❑ Other: I 3OV p5 361 f rRBDM ` n q \ Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No i Subsequent Form Required: / Ci "'l 0`- (/ � APPROVED BY / Approved by: j (�/JY"� COMMISSIONER THE COMMISSION Date: l�-ZS- f us- Submit Form and Fo 1Q-403Revisjd 11/2015/ epRvide3plicNrAkt for 12 rr}Q`ths from the date of approval. ` .v ttachments in Duplicate • H • • Well Prognosis • Well: MPU E-19 Ailcorp Alaska,IAD Date: 11/20/2015 Well Name: MPU E-19 API Number: 50-029-22746-00 Current Status: SI Oil Well [ESP] Pad: E-Pad Estimated Start Date: December 12th, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-037 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,403 psi @ 7,000' TVD (Last BHP measured 8/12/2014) Maximum Expected BHP: 1,403 psi @ 7,000' TVD (No new perfs being added, EN /= 3.85 ppb,. Max. Predicted Surf Pressure: 800 psi (Based on current SITP w/exis g-ffuitt-CdTumn) Brief Well Summary: r lo,t ,vc / "`� 5L. N� g L LPA i1!tom , p ' C 0 3=108 a-2,1.6' MPU E-19 was drilled in 1997 using Nabors 27E and completed in the Kuparuk C and B sands. The well has had multiple ESP changeouts since 1997, (2004, 2008, 2010, 2012, 2014 and the most recent was an ESP changeout in 2015 using Nordic #3 to run a new ESP). According to well records, downhole heat trace was installed in 2011 due to need for constant flowing scrapes and also this well has had tendency for scaling. A casing caliper was run in April 2014 during the RWO, and no subsidence issues were seen. In December 2014 a 20' and 10' 2.20" drift was unable to be run past 5 ft in tubing. No subsequent restrictions were seen when running tubing caliper and gauge ring or pulling GLVs. The tubing caliper indicated buckling of the top two 2- 7/8" pup joints. Notes Regarding Wellbore Condition • Casing last tested to 2,500 psi for 30 min down to 7,505' MD on 7/18/2012. • Well has a history of scale. Objective: The purpose of this work is to pull the failed ESP, and run a new ESP.. Brief Procedure: Pre-Rig Procedure: (dalc s 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Reverse circulate at least one wellbore volume with 8.5 ppg sea water down casing, taking returns up tubing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. Pull BPV. Set TWC. 9. Fill w/non-freezing fluid above TWC. 10. Shell/Pressure test above TWC to 3,000 psi for 5 min. • • Well Prognosis Well: MPU E-19 • it dem")Alaska,LL Date: 11/20/2015 a. Shell/Pressure test conducted since BOPE will be NU several days in advance of rig. 11. Pull TWC. Set BPV. RD crane. 12. NU BOPE house. Spot mud boat. WO Rig Procedure: 13. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 14. Pull BPV. Bleed any pressure off tubing and casing. 15. Kill well w/8.5 ppg seawater as needed. Set TWC. 16. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ScrC ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. I t a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 17. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure 01-- c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor ,�y the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking /1.z anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 1:. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 19. MU 2-7/8" landing joint (EUE) and BOLDS. 20. Pull over string weight (approx. 75k PU) on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 21. POOH. Lay 2-7/8" tubing on the pipe rack (plan to re-run tubing) Lav down ESP. Gv a. Replace bad joints of tubing as necessary. f-� , Jt 3. B .'-k(e� ? - b. Look for over-torqued connections from previous Doyon#16 tubing runs. 22. PU new 513 series ESP and RIH with existing 2-7/8" 8RD EUE L-80 tubing. >`A- Q a. Run 2-7/8" XN profile. /617./ b. Run Upper GLM at+/- 150' w/valve and Lower GLM at+/- 7,500' w/valve. c. Run 3/8" external capillary string w/clamps down to base of ESP. d. Run heat trace to+/- 2,500'. e. Ensure correct and adequate clamps for capillary string and heat trace. 23. Set base of ESP at+/-7,750' (Pump intake around +/-7,720'). H • . • Well Prognosis Well: MPU E-19 • Metal)Alaska,LL Date: 11/20/2015 24. Land tubing hanger. RILDS. Lay down landing joint. a. Note PU (Pick Up)and SO (Slack Off)weights on tally. 25. Set BPV.Test tubing hanger to 250/5,000 psi thru test port. 26. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. Pull BPV. Set TWC. ND BOPE. 3. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. • 4. Move 500 bbl returns tank and rig mats to next well location. 5. Replace IA x OA pressure gauge if removed (7"x 9-5/8"). 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form Milne Point Unit Well: MPE-19 . •H 0 SCHEMATIC Last Completed: 1/31/2015 Mewl)Alaska,LLC PTD: 197-037 CASING DETAIL Orig.KB Elev.:34.05'/GL Elev.:24.5' Size Type Wt/Grade/Conn Drift ID Top Btm e ;a 20" Conductor 91.1/H-40/N/A N/A Surface 115' 20'� }' 9-5/8" Surface • 40/L-80/Btc. 8.679 Surface 3,955' 7" Production 26/L- 80/Btc 6.151 Surface 8,247' 9 1 ! TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.347 Surface 7,749' i. 3/8" Capstring N/A N/A Surface 7,749' I JEWELRY DETAIL 1 .;3 4. ) , 2 x. No Depth Item 9-5/8":. + 1 137' Camco 2-7/8"x 1"Sidepocket KBMM GLM(DGLV set 9/30/15) 2 2,530' Centrilift Heat Trace 9-5/8"Howco'ES' 3 7,488' Camco 2-7/8"x 1"Sidepocket KBMM GLM(Open Pocket 10/13/15) Cementer @1,296' 4 7,642' XN-Nipple w/2.313" landing Profile(2.250 No-go ID) 5 7,685.7' Discharge Head-FPHVDIS 6 7,686' Tandem Pump -SXD 141-P6 x(2) SS Cap String7 7,718' Gas Separator -GRSFTXAR H6 8 7,723' Tandem Seal Section-GSB3DBUT SB/SB PFSA&GSB3DBLT SB/SB PFSA 9 7,737' Motor-MSP1-250:84HP,2,210 volt&23 amps 10 7,745' Phoenix Sensor 11 7,747' Centralizer/Bottom @ 7,749' 12 8,164' 7"Float Collar 13 8,247' 7"Float Shoe PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Kup.C Sands 7,837' 7,860' 6,958' 6,978' 23 5/3/1997 Open Kup.B Sands 7,872' 7,902' 6,989' 7,014' 30 5/3/1997 Open WELL INCLINATION DETAIL KOP @ 350' Max Hole Angle=32 to 33 deg. f/2,500'to 3,650' Hole Angle through perforations=31 deg. 3 OPEN HOLE/CEMENT DETAIL `w '14 14 20" Cmt w/250 sks of Arcticset I in 24"Hole 9-5/8" Cmt w/1,195 sks PF"E",725 sx Class"G"in 12-1/4"Hole Note:Pump is i, i A r" 7" Cmt w/334 sks Class"G"in 8-1/2"Hole equipped w/ y ,. 4 Discharge Head, 1 TREE&WELLHEAD Model FPHVDIS , w Tree 2-9/16"-5M Cameron x• 't 5 11"x 11""5M FMC Gen 5,w/11"x 2-7/8"FMC ESP/HT 2-7/8"EU Wellhead 6 8rd threads,2.5"CIW H BPV Profile i� GENERAL WELL INFO I API:50-029-22746-00-00 8 Drilled and Cased by Nabors 27E -3/21/1997 0 tgMCompleted with ESP by Nabors 4ES-5/4/1997 19 ESP RWO w/4-ES-12/3/2004 ESP RWO w/35-6/20/2008 . i*10 ESP RWO w/4-ES-10/17/2010 1* ESP RWO w/Doyon 16-7/19/2012 11 WFD Set Lower Packert/Patch Set-6/30/2013 ESP RWO w/Doyon 16-4/11/2014 SlicklineTag KUP C Sands ESP RWO w/Nordic 3-1/31/2015 4/28/2002 @ 8,089 VLM_ }KUP B Sands 7'A ii12 13 TD=8,249'(MD)/TD=7,310'(TVD) PBTD=8,164'(MD)/PBTD=7,237'(1VD) Created By:STP 11/12/2015 H . IIIMilne Point Unit . H Well: MPE-19 • PROPOSED SCHEMATIC Last Completed: Proposed Hitcorp Alaska,LLC PTD: 197-037 CASING DETAIL Orig.KB Elev.:34.05'/GL Elev.:24.5' Size Type Wt/Grade/Conn Drift ID Top Btm '.N * 20" Conductor 91.1/H-40/N/A N/A Surface 115' 20'� i ; I 9-5/8" Surface 40/L-80/Btc. 8.679 Surface 3,955' 7" Production 26/L-80/Btc 6.151 Surface 8,247' *04 1 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.347 0 ±7,749' i'+ JEWELRY DETAIL ; 2 No Depth Item � e 1 ±137' Camco 2-7/8"x 1"Sidepocket KBMM GLM 95/g, ° 2 ±2,530' Centrilift Heat Trace Heat Trace @ 9-5/g'Howco'ES' 3 ±7,488' Camco 2-7/8"x 1"Sidepocket KBMM GLM ±2500' Cementer@1,296' 4 ±7,642' XN-Nipple w/2.313" landing Profile(2.250 No-go ID) 5 ±7,685' Discharge Head-FPHVDIS 6 ±7,686' Tandem Pump -SXD 141-P6 x(2) 3i8 Capstnng 7 ±7,718' Gas Separator -GRSFTXAR H6 f---...." 8 ±7,723' Tandem Seal Section-GSB3DBUT SB/SB PFSA&GSB3DBLT SB/SB PFSA 9 ±7,737' Motor-MSP1-250:84HP,2,210 volt&23 amps 10 ±7,745' Phoenix Sensor 11 ±7,747' 3/8"External Capillary String 12 ±7,747' Centralizer/Bottom @ 7,749' 13 8,164' 7"Float Collar 14 8,247' 7"Float Shoe PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 7,837' 7,860' 6,958' 6,978' 23 5/3/1997 Open Kup.B Sands 7,872' 7,902' 6,989' 7,014' 30 5/3/1997 Open WELL INCLINATION DETAIL KOP @ 350' Max Hole Angle=32 to 33 deg. f/2,500'to 3,650' Hole Angle through perforations=31 deg. 3 OPEN HOLE/CEMENT DETAIL x* 20" Cmt w/250 sks of Arcticset I in 24"Hole Note:Pump is ,, t j "; 9-5/8" Cmt w/1,195 sks PF"E",725 sx Class"G"in 12-1/4"Hole equipped w/ IS 4 ' 7" Cmt w/334 sks Class"G"in 8-1/2"Hole Discharge Head, ‘. Model FPHVDIS ', - TREE&WELLHEAD rAlla '5 Tree 2-9/16"-5M Cameron k 6 Wellhead 11"x 11""5M FMC Gen 5,w/11"x 2-7/8"FMC ESP/HT 2-7/8"EU 3 8rd threads,2.5"CIW H BPV Profile .Y GENERAL WELL INFO 1 r: 116 Vii' 8 API:50-029-22746-00-00 Drilled and Cased by Nabors 27E -3/21/1997 *' i4 9 Completed with ESP by Nabors 4ES-5/4/1997 ESP RWO w/4-ES-12/3/2004 +;10 ESP RWO w/3S-6/20/2008 11 } ESP RWO w/4-ES-10/17/2010 12 ; ESP RWO w/Doyon 16-7/19/2012 WFD Set Lower Packert/Patch Set-6/30/2013 SlicidMi2� KIP CSands ESP RWO w/Doyon 16-4/11/2014 8,08g ykM a}KUP B Sands ESP RWO w/Nordic 3-1/31/2015 0 7" dt1314 TD=8,249'(MD)/TD=7,310'(TVD) PBTD=8,164'(MD)/PBTD=7,237(TVD) Created By:STP 11/12/2015 . • • Milne Point 2015 ASR Rig 1 �� r! ��, Knight Oil Tools BOP e . / Stripping Head w Shaffer -'''- 11" - 5000 111 ift tit t#1ll i M lilLMM ilii27/8" -5" VBR CI HCILL -U N 0 ---itl_ H ( 04 11" 000 �� H Blind 1 / 2" Kill Line 2" Choke Line i 7-19 .1\--).11 t. °) 5 - . t -1--(ip'. f E. E 5L_ ( )(it Manual Manual I Manual HCR Updated 11/03/15 • . • Choke Manifold ASR#1 11/01/2015 tt"h,,,p %I i.t..,.I II Digital Reverse line back to Kill Manifold Pressure Readout PI -11 *.'' 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O c N E r v Q. �( � O ca 0 70 A cn 0 m x 3 a) - d w X c 'c 0 a 0 O a) N 6, Q) C) x Q ii �, o U a) x E 0 23 v � a Q COo 0Q 0a) Q U - STATE OF ALASKA AL,,�KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS • 1.Operations Abandon LI Repair Well U Plug Perforations U Perforate Li Other ESP Changeout Performed: Alter Casing ❑ Pull Tubing E Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 197-037 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22746-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047437 MILNE PT UNIT KR E-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE PT FIELD/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 8,249 feet Plugs measured N/A RE C E I V E D true vertical 7,310 feet Junk measured 8,089(FILL) fee .EB 17 2015 Effective Depth measured 8,089 feet Packer measured N/A feet ��true vertical 7,174 feet true vertical N/A fee a Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1,530psi 520psi Surface 3,955' 9-5/8" 3,955' 3,590' 5,750psi 3,090psi Intermediate Production 8,247' 7" 8,247' 7,308' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic %AWE) ,', True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5/L-80/8rd EUE 7,749' 6,884' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 122 8 281 0 208 Subsequent to operation: 151 21 232 0 217 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑� Gas ❑ WDSPL❑ 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: 314-683 '/ Contact Chris Kanyer Email ckanverCa�hilcorp.com Printed Name Xr Chris Kanyer Title Operations Engineer Signature a Phone 907-777-8377 Date 2/16/2015 3--(i-is RBDMS FEB 2 3 2015 Form 10-404 Revised 10/20127 L4 Submit Original Only 3474 . Milne Point Unit Well: MPE-19 SCHEMATIC Last Completed: 1/31/2015 Ililcorp Alaska.LLC PTD: 197-037 CASING DETAIL Orig.KB Elev.:34.05'/GL Elev.:24.5' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surf 115' 20'.41 9-5/8" Surface 40/L-80/Btc. 8.679 Surf 3,955' ii 7" Production 26/L-8:NR/GYB tc6.151Surface8,247' 1 TUBIDETAIL 41\ 2-7/8" Tubing6,5/L-80 8rd EUE2.347Surf 7,749' JEWEDETAIL No Depth Item • �. 2 1 137' Camco 2-7/8"x 1"Sidepocket KBMM GLM 2 2,530' Centrilift Heat Trace 9-5/8" 3 7,488' Camco 2-7/8"x 1"Sidepocket KBMM GLM 9-5/8"How o'ES' 4 7,642' XN-Nipple w/2.313" landing Profile(2.250 No-go ID) Cementer @ 1,296' 5 7,685.7' Discharge Head-FPHVDIS 6 7,686' Tandem Pump -SXD 141-P6 x(2) 7 7,718' Gas Separator -GRSFTXAR H6 8 7,723' Tandem Seal Section-GSB3DBUT SB/SB PFSA&GSB3DBLT SB/SB PFSA 9 7,737' Motor-MSP1-250:84HP,2,210 volt&23 amps 10_ 7,745' Phoenix Sensor 11 7,747' Centralizer/Bottom @ 7,749' 12 8,164' 7"Float Collar 13 8,247' 7"Float Shoe PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.C Sands 7,837' 7,860' 6,958' 6,978' 23 5/3/1997 Open Kup.B Sands 7,872' 7,902' 6,989' 7,014' 30 5/3/1997 Open WELL INCLINATION DETAIL KOP @ 350' Max Hole Angle=32 to 33 deg. f/2,500'to 3,650' Hole Angle through perforations=31 deg. OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole 5, 3 9-5/8" Cmt w/1,195 sks PF"E",725 sx Class"G"in 12-1/4"Hole 7" Cmt w/334 sks Class"G"in 8-1/2"Hole r. TREE&WELLHEAD Note:Pump is equipped w/ 1 4 Tree 2-9/16"-5M Cameron Discharge Head, t. i 11"x 11""5M FMC Gen 5,w/11"x 2-7/8"FMC ESP/HT 2-7/8"EU Model FPI-WENS �1 (� 5 Wellhead 8rd threads,2.5"CIW H BPV Profile '.. GENERAL WELL INFO 6 API:50-029-22746-00-00 Drilled and Cased by Nabors 27E -3/21/1997 . 118:: 7 Completed with ESP by Nabors 4ES-5/4/1997 4'8 ESP RWO w/4-ES-12/3/2004 ESP RWO w/3S-6/20/2008 ESP RWO w/4-ES-10/17/2010 N ' 9 ESP RWO w/Doyon 16-7/19/2012 WFD Set Lower Packert/Patch Set-6/30/2013 i- 10 )' ESP RWO w/Doyon 16-4/11/2014 i' M11 ESP RWO w/Nordic 3-1/31/2015 k n Sliddine Tag :a -}KUP C Sands 4...) c:.i 4.1 4-"-- 4/28/2002 @ e4' �/ 8,089 VeLM ._1 KUP B Sands 34 z.12___ . 7" 'a x•12 13 TD=8,249'(MD)/TD=7,310'(TVD) 1,L. PBTD=8,164'(MD)/PBTD=7,237'(TVD) 3./Y Created By:TDF 2/13/2015 Hilcorp Alaska, LLC ,,:,,k:,_,,,, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP E-19 50-029-22746-00-00 197-037 1/26/2015 2/2/2015 Daily Operations: 1/21/15-Wednesday No operations to report. 1/22/15-Thursday No operations to report. 1/23/15-Friday No operations to report. 1/24/15-Saturday No operations to report. 1/25/15-Sunday No operations to report. 1/26/15-Monday Begin rig move from MPE-18,spot,and set down. Pull BPV plumb kill tanks finish RU.Order hot seawater. Install 2-7/8"- 5-1/2"VBRs. Spot spooler mats and pit liner. BOPE Witness waived @ 20:22 hours by Chuck Scheve.Offload 8.5 ppg 140 degree seawater.JSA for well kill procedures.SITP 0 SICP 40. Line up&pump down tbg 52 bbls,0 psi tbg on vac. SICP 80 psi. Line up down annulus, pump 252 bbls,0 psi. Shut down pumps observe well,tbg on light vacuum,annulus static.Total Volume pumped 304 bbl.Observe well, install TWC,annulus climbed to 75 psi. Bleed off annulus and observe well. 1/27/15-Tuesday PTSM-Monitor well.Annulus pressure up to 75 psi, bleed down to Opsi, annulus on slight vacuum. ND tree, NU 13-5/8" BOPE, route accumulator hoses.Warm stack. Install bell nipple. Fill stack. Perform body test.Tighten flange leaks. HCR choke failed function test. Replace HCR choke. Blind ram door seal failed. Replace same. Leak from weep hole on blind rams.Disasemble blind ram shaft assembly.Wait on parts. RU ESP spooler. Hilcorp Alaska, LLC HileorpAIaska, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP E-19 50-029-22746-00-00 197-037 1/26/2015 2/2/2015 Daily Operations: 1/28/15-Wednesday PTSM,Continue waiting on parts for doublegate ram shaft seal. Decide to change out double gate with two single gates. Prep BOPS and nipple down. Remove VBR rams from double gate. Drain pits to vac truck&cuttings tank.Blow down steam to cuttings tank. R/D testing equipment. N/D double gate and annular from stump. Hang in cellar.Run rig moving hydraulics and warm running gear. Move rig off of well.Set down&replace double gate with two single gates. Rack back on stump. PJSM,Spot sub over well.Spot equipment&tanks, Berm cellar, N/U BOPs&torque to sprc. Install 2-7/8"X 5"VBR Rams in the top&Blinds in the bottom.Total seawater losses to the well 416 bbl. 1/29/15-Thursday Install VBR rams in upper&blinds in lower cavity. Perform body test,good. Rig Back on company time at 7:30am.Test BOPs wit 2-7/8"test joint to 250psi low/3,000psi high.Test annular to 250psi low/2,500psi high.Good. Perform accumulator drawdown test.Good.Install heat trace spool on rig floor with Crane.Adding 5 bph seawater to the annulus.Annulus building to 30 psi.Whitness was waved by BOB Noble @ 7:25am on 1-29. Pull TWC. Monitor annulus. Bleed down 30 psi. M/U landing joint. Pump 43 bbl down tubing.Tubing on a vac. B.O.L.D.Pull hanger free @ 115k. Monitor well.OK.Pull hanger to the rig floor.Baker checking penetrator. Terminate penetrator&L/D hanger. Pull ESP &heat trace lines. Hang sheaves on the rig floor. Pull 2 stands R/U spooler&ESP equipment. POOH with 2-7/8" EUE ESP completion with heat trace. F/7,770'T/4,380'. End heat trace. Laid down joints 140&141.Continue to POOH with 2- 7/8" EUE ESP completion F/4,380'T/3,400'. Daily losses 157 bbl 8.5 seawater.Total losses to the well 573 as of Midnight. 1/30/15-Friday POOH F/3,400'T/ESP Pump. Tubing looked good.XN nipple had pitting in the profile. L/D ESP pumps&assembly. Pump locked up. P/U scraper&mule shoe. P/U 21, 2-7/8" EUE singles.7 stands. RIH to above top perfs. @ 7,837' UP/DN 90/75k. RIH T/8,017'Tag 4k dn. No problem going through perfs.POOH standing back stands. Filling the hole with 1.5 Pipe displacement.Having to add a little water to the tubing to keep fumes off the rig floor while pulling. Service&L/D scraper. Clear floor&Prep to P/U ESP Assembly. P/U ESP pump&assembly as per vender.M/U discharge head.Prep to install cable in sheaves. Daily fluid losses 157 bbl.Total fluid losses 733 bbl 8.5 bbl seawater. 1/31/15-Saturday Finish picking up pump&ESP equipment. Hang sheaves&string up ESP cable&capstrinj. Connect cable to discharge head.Connect cap string and test.Good test on both.Continue to RIH testing cap string and ESP cable every 2,000'. Good. RIH T/3,000'.Change out joint on stand 30 joint#33.Gauled threads.Change Collar on joint 87.RIH from derrick with 2-7/8"6.5#EUE ESP assembly. F/3,000'T/5,270'. Meg cable while rigging up heat trace.Test cap line.Good. RIH with ESP Completion with heat trace on 2-7/8"out of the derrick. F/5,200'T/5,900'. Daily lossses @ 130bbI.Total losses to well 863 bbl. 2/1/15-Sunday RIH with ESP Completion with heat trace on 2-7/8"out of the derrick. F/ 5,900'T/7,535'. P/U two singles&GLM. RIH last stand#78 T/7,716'. M/U hanger&landing joint.Terminate cap lines, ESP cable&heat trace.Splice ESP&heat trace in to penetrators.Test Good. Landing depth 7,748.91'. Install BPV in hanger. UP/DN 115/90K NORDIC TD& BLOCKS 37,000K.SET 53,000 ON HANGER. Land hanger&verify. RILD.Good. L/D landing joint.236 JOINTS TOTAL. XN NIPPLE 7,642.29' FROM TUBING SPOOL.Total clamp count in the hole.CROSS COLLAR-BEFORE HT-71 USED CLAMPS CROSS COLLAR-BEFORE HT-14 NEW CLAMPS DUEL CHANNEL CROSS COLLAR-108 USED CLAMPS 5'CANNON CLAMPS- 354 USED CLAMPS DUEL PURPOSE-ESP/HT-2 USED CLAMPS PROTECTROLIZERS-3FLAT GUARD-2PUMP CLAMPS-4CAP LINE BANDS-84. Prep For N/D operation. Remove ESP,Cap String& Heat trace lines from derrick.Sent state 24 hr notification of upcoming BOP test @ 0452 2-2-2015. Daily Lossses to well @ 163bblTotal losses to well 1,026bb1. 2/2/15-Monday N/D BOPs, N/U Tree.Test void 250psi low/5,000psi high.Good. Pull BPV&install TWC.Test tree to 5,000psi good. Release rig @ 1130. Pull BPV. Little red freeze protect E-19. Remove rig mats.Clean up well area. Prep for move to E-11. Move rig to E-11. 2/3/15-Tuesday No operations to report. -Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Thursday,January 15, 2015 2:22 PM To: 'Chris Kanyer' Subject: RE: MPE-19 Sundry#314-683 (waive casing test) (PTD 197-037) Chris, Looks like a recent test was done on this one also. Casing test is Waived for MPE-19 also. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Chris Kanyer [mailto:ckanyer@hilcorp.com] Sent:Thursday, January 15, 2015 2:13 PM To: Schwartz, Guy L(DOA) Cc:Tom Fouts Subject: MPE-19 Sundry #314-683 Guy, After further review of the well history on MPE-19(PTD 195-037 API#50-029-22746-00-00),the well had the charted 7"casing test to 2,500psi on 7/18/2012 (see attached pressure test documentation).Can you please review and waive the 7"casing test to 1,500psi requirement? Thanks. Chris Kanyer I Operations Engineer Ibk.i-1. tla.L.a.I.I( ckanyer@thilcorp.com Direct: (907) 777-8377 Mobile: (907) 250-0374 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~ -~-- ~ ~z ~ File Number of Well History File PAGES TO DELETE RESCAN Color items- Pages: [] Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type 'OVERSIZED .Logs of various kinds Other Complete COMMEN'F~: D Scanned by: ~ever~ Mildred-D'aretha ~1 TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si STATE OF ALASKA AL ,I:A OIL AND GAS CONSERVATION CO,_ ,SSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS MAY 0 7 2014 1. Operations Performed: AO/3CC ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Wellt�...•11 ❑Alter Casing ® Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change Approved Program 0 Operation Shutdown ❑Stimulate-Other 0 Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑Exploratory 0 Stratigraphic • 197-037 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 A 50-029-22746-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 047437 a • MPE-19 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): • Milne Point/Kuparuk River Oil 11. Present well condition summary: Total depth: measured ‘ 8249' feet Plugs:(measured) None feet true vertical 7310' feet Junk:(measured) None feet Effective depth: measured 8164' feet Packer: (measured) None feet true vertical 7237' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3930' 9-5/8" 3955' 3590' 5750 3090 Intermediate Production 8222' 7" 8247' 7308' 7240 5410 Liner SCANNED JUL 1 6 2014 Perforation Depth: Measured Depth: 7837'-7902' feet True Vertical Depth: 6959'-7014' feet Tubing(size,grade,measured and true vertical depth): 2-7/8",6.5# L-80 7771' 6902' Packers and SSSV(type,measured and true vertical depth): None None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: RBDMS MAY 17 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1100 0 Subsequent to operation: 85 26 104 210 177 14.Attachments: 0 Copies of Logs and Surveys run 15.Well Class after work: • 0 Exploratory 0 Stratigraphic ®Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: • ®Oil 0 Gas 0 WDSPL ®Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 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: Contact: J.E.B.Bolen,564-5110 Email:J.E.B.Bolen@bp.com N/A Printed Name: Joe Lastu a/ Title: Drilling Technologist Signature: A Ph ne: 564-4091 Date: 5,4,//ip Form 10-404 Revised 10/2012 v Submit Original Only 1/LF 5-/Z 4 / 14- A iAl/,/l' North America-ALASKA-BP Page 1 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date:4/10/2014 X4-00YGM-E:(1,850,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/me:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292274600 Active datum:32.19 5/4/1998 12:00 @84.10usft(above Mean Sea Level) Date From-To Hrs Task i Code NPT NPT Depth Phase Description of Operations (hr) L .... (usft) 4/4/2014 18:00 - 20:00 • 2.00 MOB P PRE PJSM.MOBILIZE EQUIPMENT IN PREPARATION FOR RIG MOVE FROM MPC-05A TO MPE-19. -LOAD EQUIPMENT ONTO TRAILERS. MOVE CREW TRAILER. -BRIDLE UP AND LAY DERRICK OVER. 20:00 - 21:30 1.50 MOB P PRE PJSM.MOVE RIG OFF OF MPC-05A. NIGHT TOOLPUSHER AND NIGHT WSL PRESENT. -PAD OPERATOR NOTIFIED. PULL OFF OF MPC-05A. '-REMOVE BOPE STACK AND INSTALL ON :TRAVEL SKID. -INSTALL REAR BOOSTER TIRES. 21:30 - 00:00 2.50 MOB P PRE MOVE OFF MPC-PAD TOWARDS MPE-PAD. 4/5/2014 00:00 - 01:00 1.00 MOB P PRE MOVE RIG FROM MPC-PAD TO MPE-PAD. 01:00 - 04:00 3.00 MOB P PRE ARRIVEATMPE-PAD. --REMOVE REAR BOOSTERS. -INSTALL BOPE STACK ON STUMP IN CELLAR. ;-RAISE DERRICK AND R/U FLOOR 1 I EQUIPMENT. ;-LAY MATS AND PREPARE AREA AROUND MPE-19. 04:00 06:00 2.00 MOB P PRE PJSM.BACK OVER MPE-19. '-PAD OPERATOR NOTIFIED. WSL AND TOOLPUSHER PRESENT. -SPOT RIG OVER MPE-19. ' -SHIM UP AROUND RIG AND LEVEL SAME. ' SPOT CUTTINGS TANK AND CREW CHANGE TRAILER. ACCEPT DOYON 16 AT 06:00 HRS ON ' '04/05/2014. 06:00 - 0730 1.50 RIGU P DECOMP PJSM.RIG UP TO KILL WELL. -TAKE ON 8.4 PPG 120°F BRINE. -RIG UP LINES IN CELLAR. 07:30 - 09:30 2.00 KILLW PDECOMP !PJSM.PRESSURE TEST SURFACE ' EQUIPMENT. 1-FLUID PACK MUD PUMP. -PRESSURE TEST PRESSURE RELIEF VALVE AND SURFACE LINES. -TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 'CHARTED MINUTES. 09:30 - 10:00 0.50 KILLW P DECOMP CONDUCT RIG EVACUATION DRILL,H2S RELEASE IN THE CELLAR. I-AAR ALL HANDS ACCOUNTED FOR AT THE MUSTER AREA. -LOADER BLOCKING ENTRANCE TO THE I PAD. ' j-DRILL SITE OPERATOR AND MILNE POINT FRONT SECURITY ALERTED. -GOOD RESPONSE TIME AND WELL SECURED BEFORE LEAVING THE RIG. Printed 4/21/2014 11:58:14AM North America-ALASKA-BP Page 2 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date:4/10/2014 X4-00YGM-E:(1,850,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor DOYON DRILLING INC. UWI:500292274600 Active datum:32.19 5/4/1998 12:00 t@84.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) , 10:00 - 12:00 2.00 WHSUR P • DECOMP PJSM.PULL BPV. -PRESSURE TEST LUBRICATOR TO 250 PSI , LOW,3500 PSI HIGH FOR 5 CHARTED ' MINUTES. -PULL BPV. • -R/D LUBRICATOR. • -SITP=1200 PSI,IA=1250 PSI,OA=0 PSI. -NOTE:MASTER VALVE DOES NOT COMPLETELY HOLD PRESSURE FROM I -- 'BELOW. 12:00 - 13:00 1.00 KILLW P DECOMP CONDUCT RIG EVACUATION DRILL,FIRE IN 'THE BOILER ROOM. -ALL HANDS AND TRUCK DRIVERS ACCOUNTED FOR AT THE MUSTER AREA ' -DRILL SITE OPERATOR AND MILNE POINT FRONT SECURITY ALERTED. ' -AAR DISCUSSED ATTACKING FIRE WITH(1) EXTINGUISHER PRIOR TO EVACUATING RIG. -DISCUSSED EGRESS ROUTES AND CLOSING DOORS BEHIND YOU. GOOD RESPONSE TIME AND WELL 'SECURED BEFORE LEAVING THE RIG. 1300 - 19:30 6.50 KILLW P DECOMP PJSM.WELL KILL. -INSPECT KILL MANIFOLD AND EQUIPMENT. -ASSURE PROPER VALVE ALIGNMENT. -ALERT DRILL SITE OPERATOR AND MILNE POINT OF GAS VENTING OPERATIONS. i -BLEED GAS FROM IA THROUGH CHOKE TO FLOW BACK TANK,150 PSI DOWNSTREAM PRESSURE. -BLEED FOR APPROXIMATELY 1/2 HR TO 900 I 'PSI,STILL ALL GAS COMING BACK. -LINE UP TO PUMP DOWN TUBING AND 1 I EQUALIZE PRESSURE WITH MUD PUMP. i II-PUMP 8.4 PPG BRINE AT 3 BPM=950 PSI , ICP.PUMP 44 BBLS,FCP=40 PSI. • PUMPED 20 BBLS DEEP CLEAN PILL DURING TUBING CIRCULATION. -CLOSE CHOKE AND BULLHEAD 15 BBLS AT 6.5 BPM=190 PSI. -LINE UP AND CIRCULATE DOWN TUBING TAKING GAS RETURNS UP IA -PUMP 135 BBLS,NO FLUID IN RETURNS, ' ,MAINTAINING 150 PSI DOWNSTREAM OF CHOKE MAX. -SHUT IN CHOKE AND LINE UP TO BULLHEAD ' DOWN IA. BULLHEAD DOWN IA20 BBLS DEEP CLEAN PILL FOLLOWED WITH 8.4 PPG BRINE. ,-340 BBLS TOTAL BULLHEADED DOWN THE IA AT 6 BPM=660 PSI ICP. i-FINAL BULLHEAD PRESSURE AT 6 BPM=710 j PSI. i-SHUT DOWN PUMPS AND MONITOR WELL. -IA ON A STRONG VACUUM,TUBING STATIC. MONITOR FOR 45 MINUTES. I-BULLHEAD 50 BBLS DOWN TUBING AT 6 ' I BPM=150 PSI ICP.6.5 BPM=920 PSI FCP. .-MONITOR WELL FOR 30 MINUTES.TUBING AND IA ON A VACUUM. -BLOW DOWN LINES,R/D KILL MANIFOLD, R/U SECONDARY KILL LINE. Printed 4/21/2014 11:58:14AM • l North America-ALASKA-BP Page 3 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date:4/10/2014 X4-00YGM-E:(1,850.000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292274600 Active datum:32:19 5/4/1998 12:00©84.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth• Phase Description of Operations (hr) i (usft) 19:30 - 20:00 0.50 KILLW P DECOMP LINE UP AND ATTEMPT TO FILL BACK SIDE IA I =20 PSI. 20:00 - 23:30 1 3.50 KILLW P 1 DECOMP PJSM.BULLHEAD DOWN TUBING AND IA. -R/U KILL MANIFOLD AND TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -BULLHEAD 20 BBLS 8.4 PPG DOWN TUBING AT7BPM. -ICP=180 PSI,FCP=900 PSI. ' -OPEN UP TO BULLHEAD 8.4 PPG DOWN IA AND TUBING AT 7.5 BPM. ICP=230 PSI,FCP=1180 PSI. -PUMP 380 BBLS 8.4 PPG BRINE(-1.5 X WELLBORE VOLUME)TOTAL. SHUT DOWN PUMP.MONITOR WELL FOR 30 MINUTES. i -TUBING AND IA BOTH ON STRONG VACUUM. R/D MANIFOLD,BLOW DOWN LINES. 23:30 - 00:00 0.50 WHSUR I P i DECOMP I PJSM.SET TWC. R/U AND TEST WELL SUPPORT LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. • 24 HOUR FLUID LOSS=652 BBLS 8.4 PPG BRINE. CUMULATIVE FLUID LOSS=652 BBLS 8.4 PPG _ _ BRINE. --a-- — 4/6/2014 00:00 - 00:30 0.50 WHSUR P DECOMP PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. 1 PJSM.SET TWC. -SET TWC. -R/D LUBRICATOR. _GREASE MASTER VALVE. 00:30 - 02:00 1.50 WHSUR P DECOMP PJSM.PRESSURE TEST TWC. -PERFORM ROLLING TEST FROM BELOW ' TWC TO 500 PSI FOR 5 CHARTED MINUTES. -TEST TWC FROM ABOVE TO 250 PSI LOW, • 3500 PSI HIGH FOR 5 CHARTED MINUTES. GOOD TEST. 02:00 - 03:30 1.50 WHSUR ! P DECOMP PJSM.N/D TREE. 1 -FMC REP BLEED VOID. -N/D TREE. -INSPECT HANGER THREADS:2-7/8"8RD 7.5 I TURNS. -1- 03:30 - 06:00 2.50 I BOPSUR P DECOMP i PJSM.NIPPLE UP BOPE. -N/U 13-5/8"BOPE STACK. -INSTALL TURNBUCKLES AND FLOW NIPPLE. _ ARE-ENERGIZE ACCUMULATOR SYSTEM. Printed 4/21/2014 1 1:58:14AM North America-ALASKA-BP Page 4 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date:4/10/2014 X4-00YGM-E:(1,850.000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor:DOYON DRILLING INC. 'UWI:500292274600 Active datum:32:19 5/4/1998 12:00©84.10usft(above Mean Sea Level) Date From-To • Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 10:00 . 4.00 BOPSUR P DECOMP PJSM.TEST FOUR PREVENTER 13-5/8"BOPE , AND RELATED EQUIPMENT. I ! -TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES. TEST ANNULAR WITH 2-7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. '-TEST UPPER 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8"AND 4"TEST JOINT TO 250 PSI, '3500 PSI HIGH FOR 5 CHARTED MINUTES. '-TEST LOWER 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8"AND 4"TEST JOINT TO 250 PSI, 3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST WITH FRESH WATER. . -PERFORM ACCUMULATOR DRAW DOWN TEST WITH WSL PRESENT. ' -NO FAILURES. '-CONTINUOUS HOLE FILL AT 25 BPH DURING 'ALL OPERATIONS. • CHARLES SCHEVE OF AOGCC WAIVED STATES RIGHT OF WITNESS FOR BOPE • _ TEST. - — 10:00 10:30 0.50 BOPSUR P : DECOMP !PJSM.RIG DOWN TEST EQUIPMENT. I -BLOW DOWN LINES AND DRAIN BOPE I -1--- - I STACK. 10:30 - 12:00 1.50 WHSUR P DECOMP PJSM.RIG UP OFF SET LUBRICATOR. -PRESSURE TEST LUBRICATER TO 250 PSI • LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. 12 HOUR FLUID LOSS=259 BBLS 8.4 PPG ' BRINE. — - -+ W + — 12:00 - 13:00 1.00 HSUR T P DECOMP PJSM.PULL TWO WAY CHECK VALVE. -LAY DOWN LUBRICATOR AND WELL 'SUPPORT EQUIPMENT. ;13:00 - 13:30 0.50 PULL P i DECOMP PJSM.BRING CENTRILIFT EQUIPMENT TO RIG FLOOR. {-RIG UP FLOOR TO POOH WITH 2-7/8" --- + . COMPLETION STRING. + G... 13:30 - 14:00 i 0.50 PULL P ' DECOMP •PICKUP LANDING JOINT AND MAKE UP TO • j 'TUBING HANGER. MAKE UP TO TOP DRIVE AND BACK OUT • _ LOCK DOWN SCREWS 14:00 - 15:00 : 1.00 PULL P • DECOMP JP SM.PULL HANGER TO RIG FLOOR. •-PUW=121K,SOW=94K.INCLUDES 40K TOP DRIVE. -LAY DOWN HANGER AND LANDING JOINT. '-BLOW DOWN TOP DRIVE. 15:00 - 16:00 1 1.00 PULL P DECOMP •PJSM.PICKUP SINGLES FROM PIPE SHED. I •-RIH WITH 2-7/8"6.5#EUE 8RD L-80 TUBING. I -RUN IN HOLE TO 8030'MD,NO CONTACT MADE WITH FILL. -POOH AND LAY DOWN JOINTS USED TO — __ RIH. Printed 4/21/2014 11:58:14AM • j North America-ALASKA-BP Page 5 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date:4/10/2014 X4-00YGM-E:(1,850,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor:DOYON DRILLING INC. UVVI:500292274600 Active datum:32:19 5/4/1998 12:00©84.10usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) •16:00 - 18:00 2.00 PULL P DECOMP PJSM.PULL ESP CABLE AND HEAT TRACE OVER WINDWALL. • -PULL ESP CABLE OVER WINDWALLAND ATTACH IN SPOOLING UNIT. I -PULL HEAT TRACE OVER WINDWALL ' ATTACH ON HEAT TRACE SPOOL. -POH FROM 7752'MD TO 7342'MD. 18:00 - 00:00 6.00 PULL P DECOMP PJSM.POH WITH 2-7/8'6.5#EUE 8RD L-80 ESP COMPLETION. -CONTINUOUS HOLE FILL AT 25 BPH. COMMUNICATION BETWEEN DRILLER AND SPOOLER OPERATOR AT ALL TIMES. I -CENTRILIFT REPRESENTATIVE REMOVE AND RECORD ALL CLAMPS RECOVERED. • • -POH FROM 7342'MD TO 5224'MD. • ' 24 HOUR FLUID LOSS=578 BBLS 8.4 PPG BRINE. ' CUMULATIVE FLUID LOSS=1230 BBLS 8.4 PPG BRINE. 4/7/2014 00:00 - 00:30 0.50 PULL P DECOMP PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. — — 1 T 00:30 - 08:00 7.50 PULL j P DECOMP •PJSM.POH WITH 2-7/8"6.5#EUE 8RD L-80 rESP COMPLETION. ' CONTINUOUS HOLE FILL AT 25 BPH. 1 I I-COMMUNICATION BETWEEN DRILLER AND I SPOOLER OPERATOR AT ALL TIMES. '-CENTRILIFT REPRESENTATIVE REMOVE AND RECORD ALL CLAMPS RECOVERED. 08:00 - 10:30 2.50 PULL P DECOMP PJSM.PERFORM CONDUCTIVITY CHECK, TERMINATE ESP CALBE. -LAY DOWN PUMP AND MOTOR ASSEMBLY. ' � !-ALLCLAMPSRECOVERED. ' -TOP PUMP HAD BROKEN SHAFT. -LOWER TANDEM SEAL.TOP SHAFT FREE, BOTTOM SHAFT FROZEN. -MOTOR TESTED GOOD. -CABLE TESTED BAD JT#291&#292. 10:30 - 12:00 ; 1.50 PULL P DECOMP PJSM.CLEAR/CLEAN RIG FLOOR. -RIG DOWN DUAL SHEAVE&TRUNK,MAKE ' UP TEST PLUG. i 12 HOUR FLUID LOSS=328 BBLS 8.4 PPG BRINE. _ _ —I--__- . ._.____ -_ __ ,OUTER ANNULUS PRESSURE=60 PSI. 12:00 - 12:30 0.50 PULL • P I DECOMP PJSM.MOVE SPOOLING UNIT AND MATTING BOARDS. — 12:30 - 13:30 1.00 EVAL • P I INTERV PJSM.SPOT WIRE LINE UNIT. BRING SCHLUMBERGER TOOLS TO RIG 13.30 - 14:00 0.50 EVAL P FLOOR. INTERN PJSM.FILL HOLE AND KEEP HOLE FULL TO I DETERMINE LOSS RATE. II-122 BBLS TO FILL HOLE AND LOSS RATE APPROXIMATELY 280 BBLS/HR. _ j-WILL USE FULL PRESSURE CONTROL. 14:00 - 18:00 4.00 EVAL P INTERV I PJSM.R/U SCHLUMBERGER EQUIPMENT. -INSTALL TEST PLUG. L/D RUNNING TOOL. -INSTALL DUTCH RISER,RILDS. • 1-R/U SCHLUMBERGER FULL PRESSURE , CONTROL EQUIPMENT. Printed 4/21/2014 11:58:14AM North America-ALASKA-BP Page 6 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date:4/10/2014 X4-00YGM-E:(1,850,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292274600 Active datum:32:1 9 5/4/1998 12:00 ajt34.10usft(above Mean Sea Level) Date From-To Hrs • Task Code NPT i NPT Depth Phase Description of Operations 18:00 - 19:00 1.00 EVAL P INTERV PJSM.PRESSURE TEST LUBRICATOR AND DUTCH RISER TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. PULL LUBRICATOR AND DUTCH RISER. PULL TEST PLUG. -SET WEAR RING:ID=7-1/16",RILDS. 19:00 - 22:00 3.00 EVAL P INTERV M/U PDS TOOLS AND RIH AND LOG FROM 1000'MD TO SURFACE. 22:00 - 23:00 t 1.00 j EVAL P INTERV R/D SCHLUMBERGER EQUIPMENT. -CLEAN AND CLEAR RIG FLOOR. ' -P/U RUNNING TOOL. '-PULL WEAR RING. ;-L/D RUNNING TOOL AND WEAR RING. 23:00 - 00:00 1.00 RUNCOM P RUNCMP ,PJSM.HANG DUAL SHEAVE. 24 HOUR FLUID LOSS=801 BBLS 8.4 PPG .BRINE. • CUMULATIVE FLUID LOSS=2031 BBLS 8.4 PPG BRINE. OUTER ANNULUS PRESSURE=60 PSI. 4/8/2014 00:00 - 02:30 2.50 RUNCOM P RUNCMP PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. SPOT SPOOLING UNIT AND LOAD REEL. -BRING CLAMPS TO RIG FLOOR. -PULL ESP CABLE TO RIG FLOOR. -NOTE:ESP CABLE WAS CRIMPED WHILE • BRINGING TO RIG FLOOR.CENTRILIFT RECOMMEND RE-SPLICE. 02:30 - 08:00 T 5.50 T RUNCOM N HMAN RUNCMP SPLICE ESP CABLE AT RIG FLOOR. 08:00 - 12:00 4.00 RUNCOM P RUNCMP PJSM.MAKE UP AND SERVICE ESP ASSEMBLY AS PER CENTRILIFT TECH. 12:00 - 12:30 ' 0.50 RUNCOM P RUNCMP SERVICE AND INSPECT FLOOR EQUIPMENT. 12:30 - 20:00 7.50 RUNCOM P RUNCMP RIH WITH 2 7/8"6.5#L-80 EUE 8RD ESP j COMPLETION. -P/U FROM SHED 1 X 1. -TORQUE ALL CONNECTIONS TO 2300 FT-LBS. 1 -USING BEST-O-LIFE 2000 PIPE DOPE. -BREAK CIRCULATION EVERY 2000'. •-CHECK CONDUCTIVITY OF ESP CABLE EVERY 2000'. i-CONTINUOUS HOLE FILL AT 25 BPH. ' -RIH FROM SURFACE TO 3,402'MD. 20:00 - 21:00 1.00 RUNCOM P • RUNCMP PJSM.PULL HEAT TRACE OVER SHEAVE. •-CENTRILIFT ATTACH HEAT TRACE IN SPOOLING UNIT. BRING 4'AND 2'CANNON CLAMPS TO RIG + ... FLOOR. Printed 4/21/2014 11:58:14AM • • North America-ALASKA-BP Page 7 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date.4/10/2014 X4-00YGM-E:(1,850,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292274600 Active datum:32:19 5/4/1998 12:00 t84.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) —� (usft) 21:00 - 00:00 3.00 RUNCOM P RUNCMP RIH WITH 2 7/8"6.5#L-80 EUE 8RD ESP COMPLETION. -P/U FROM SHED 1 X 1. -TORQUE ALL CONNECTIONS TO 2300 FT-LBS. -USING BEST-O-LIFE 2000 PIPE DOPE. ' -BREAK CIRCULATION EVERY 2000'. -CHECK CONDUCTIVITY OF ESP CABLE I EVERY 2000'. -CHECK CONDUCTIVITY OF HEAT TRACE EVERY 1000'. -CONTINUOUS HOLE FILL AT 25 BPH. -RIH FROM 3,402'MD TO 4,757'MD. 24 HOUR FLUID LOSS=607 BBLS 8.4 PPG BRINE. CUMULATIVE FLUID LOSS=2638 BBLS 8.4 'PPG BRINE. OUTER ANNULUS PRESSURE=140 PSI. 4/9/2014 00:00 - 13:30 13.50 RUNCOM P RUNCMP PERFORM SPCC AND EQUIPMENT CHECKS. -CROWN-O-MATIC CHECK. 'RIH WITH 2 7/8"6.5#L-80 EUE 8RD ESP COMPLETION. -P/U FROM SHED 1 X 1. : -TORQUE ALL CONNECTIONS TO 2300 FT-LBS. -USING BEST-O-LIFE 2000 PIPE DOPE. -BREAK CIRCULATION EVERY 2000'. -CHECK CONDUCTIVITY OF ESP CABLE EVERY 2000'. I -CHECK CONDUCTIVITY OF HEAT TRACE EVERY '. CONTINUOU1000S HOLE FILL AT 25 BPH. tRIH FROM 4,757'MD 7,734'MD. 13:30 - 19:30 6.00 t RUNCOM P I RUNCMP PJSM.TERMINATE ESP AND HEAT TRACE AT HANGER. INSTALL TWC IN HANGER AT RIG FLOOR. -P/U LANDING JOINT AND M/U IN HANGER. -INSTALL PENETRATOR. -SPLICE ESP AND HEAT TRACE CABLES. PLUG IN AND TEST CONDUCTIVITY OF BOTH • ESP AND HEAT TRACE.GOOD TESTS. -R/D SHEAVE. I I EQUIPMENT RUN:CANNON CLAMPS=508, DUAL CLAMPS=114,SINGLE CLAMPS=71. 19:30 - 20:30 1.00 RUNCOM P RUNCMP 'PJSM.LAND HANGER. -PUW=115K,SOW=95K. i LAND HANGER. -FMC REP RILDS. -UD LANDING JOINT. 20:30 - 21:00 0.50 RUNCOM P RUNCMP PRESSURE TEST TWC. -ATTEMPT ROLLING TEST ON TWC FROM BELOW,PUMP 50 BBLS AT 4 BPM=0 PSI. -PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. I-BLOW DOWN LINES. t — __ _ -DRAIN BOPS STACK 21:00 - 22:30 1.50 RUNCOM P ^_* RUNCMP PJSM.N/D BOPE. -BLEED DOWN ACCUMULATOR. Printed 4/21/2014 11:58:14AM North America-ALASKA-BP Page 8 of 8 Operation Summary Report Common Well Name:MPE-19 AFE No Event Type:WORKOVER(WO) Start Date:4/4/2014 End Date:4/10/2014 X4-00YGM-E:(1,850,000.00) Project:Milne Point Site:M Pt E Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/27/2002 12:00:00AM Rig Release:4/10/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292274600 Active datum:32:19 5/4/1998 12:00 @84.10usft(above Mean Sea Level) Date From-To Hrs Task Code i NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 , 1.50 RUNCOM P RUNCMP PJSM.NIPPLE UP ADAPTER FLANGE. -N/U ADAPTER FLANGE. 24 HOUR FLUID LOSS=649 BBLS 8.4 PPG 'BRINE. ,CUMULATIVE FLUID LOSS=3287 BBLS 8.4 [ ' , PPG BRINE. 'OUTER ANNULUS PRESSURE=140 PSI. 4/10/2014 00:00 - 01:00 1.00 j RUNCOM P RUNCMP PERFORM SPCC AND EQUIPMENT CHECKS. ' L-CROWN-0-MATIC CHECK. 'PJSM.PRESSURE TEST ADAPTER FLANGE TO 250 PSI LOW FOR 5 CHARTED MINUTES, 5000 PSI HIGH FOR 30 CHARTED MINUTES. GOOD TEST. 01:00 02:00 1.00 RUNCOM P RUNCMP PJSM.N/U 2-9/16"TREE. NIPPLE UP TREE WITH NEW MASTER VALVE. -CENTRILIFT PERFORM FINAL ESP AND HEAT TRACE CHECKS.GOOD TESTS. -BHP=1972 PSI,BHT=114°F. 02:00 - 04:00 2.00 RUNCOM , P RUNCMP •PJSM.PULL TWC. -R/U DSM LUBRICATOR TO TREE. , i-PRESSURE TEST TREE AND LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH FOR 5 ' CHARTED MINUTES.GOOD TEST. -PULL TWC. -PRESSURE TEST LUBRICATOR TO 250 PSI , LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. -SET BPV. -R/D DSM LUBRICATOR. 04:00 08:00 4.00 RUNCOM P 1 RUNCMP PJSM.FREEZE PROTECT WITH LRS. -R/U AND PRESSURE TEST LRS LINES. I-FREEZE PROTECT 15 BBLS DOWN TUBING, 85 BBLS DOWN IA. -LRS ATTEMPT ROLLING TEST FROM BELOW BPV AT 2 BPM=0 PSI. + 4-- 08:00 - 09:00 ' 1.00 1 RUNCOM P RUNCMP SECURE TREE AND CELLAR.PREPARE FOR RIG MOVE. 9 HOUR FLUID LOSS=126 BBLS 8.4 PPG BRINE. CUMULATIVE FLUID LOSS=3413 BBLS 8.4 PPG BRINE. ' OUTER ANNULUS PRESSURE=120 PSI. RELEASE DOYON 16 FROM MPE-19 AT 09:00 j _— I _ ___ :HRS ON 04/10/2014 FOR MOVE TO MPE-24A. - Printed 4/21/2014 11:5814AM Tree: 2 9/16"- 5M Camel Orig. i .lev. = 58.55' (N 27E) Wellhead: 11" x 11" 5M FMC, MPU E-1 9 Orig. GL Elev. =24.5' Gen 5 w/ 11"X 2 7/8" FMC ESP/HT ;'� DF To Tbg. 7" Hgr. = 33.75' (N 27E) 2 7/8" EUE Threads , and 2.5" % CIW H BPV profile / 20" 91.1 ppf, H-40 115' / '� / ,1 / ill II Camco 2 7/8"x 1" 145' KOP @ 350' / 't sidepocket KBMM GLM Max. hole angle = 32 to 33 deg. % '' f/ 2500'to 3650' / V ' Hole angle thru' perfs= 31 deg / ')1 0 9 5/8"Howco'ES'Cementer 1296' iI 9 5/8", 40 ppf, L-80 BTC 3,955' A / �. , Centrilift Heat Trace 3413' 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. = 0.00579 bpf) 7" 26 ppf, L-80, BTC prod. casing (drift ID=6.151", cap. = 0.0383 bpf) / 1 Camco 2 7/8"x 1" sidepocket KBMM GLM 7515' / : XN Nipple-2.250"ID 7671' • Centrilift ESP SXD/ 161-P11 7715' AWE 1 Centrilift Gas Separator 7737 GSTHVEVXH6 ii - Tandem Centrilift seal section GSB3 DB UT SB/SB PFSA 7743' GSB3 DB LT SB/SB PFSA A Centrilift MSP-1/ 126 hp motor 7757' Stimulation Summary 2300 volts/34 amps Mt none performed - XTO PumpMate-XT150 7768' PumpMate ND-6860' owl --' Centralizer 7770' Perforation Summary Ref log:GR/CCL 4/14/97 Size SPF Iterval (TVD) C-Sands 7" short joint from 7710"to 7752'and 4.5" 5 7,837'-7,860' 6,958'-6,978' B- ands 4.5" 5 7,872'-7,902' 6,989'-7,014' Slickline tag 4/28/02 8089'wlm 7"float collar(PBTD) 8,164' 7"float shoe 8,247' DATE REV.BY COMMENTS MILNE POINT UNIT 03/22/97 JBF Drilled&Cased by Nabors 27 E 05/06/97 MDO ESP Conviction 4ES/ESP RINo05/06/98/ESP RWO U39/02 WELL E-19 12/03/04 MDO .SP RWO Completion 4ES 6/20/08 LH ESP RWO Recomoletion 3S API NO: 50-029-22746 10/17/10 REH ESP RWO-Nabors 4E5 07/19/12 B.Bixby ESP RWO-Doyon 16 06/30/13 B.Bixby WFD Set Lower Packer/Patch Set BP EXPLORATION (AK) 04/11/14 B.Bixby ESP RWO Doyon 16 • RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM1kION „i U L 2 2 2013 REPORT OF SUNDRY WELL OPERATIONS (�► 1 1 1.Operations Abandon U Repair Well L.] Plug Perforations U Perforate U Other U �° Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ O erat.Shutdown0 Stimulate-Other ❑ Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 151 . Exploratory ❑ 197-037-0 ' 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22746-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047437 KUP MPE-19 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted MILNE POINT,KUPARUK RIVER OIL . 11.Present Well Condition Summary: Total Depth measured 8280 feet Plugs measured None feet true vertical 7336.03 feet Junk measured None feet Effective Depth measured 8164 feet Packer measured None feet true vertical 7237.41 feet true vertical None feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 90 20"91.1#H-40 25-115 25-115 1530 520 Surface 3930.5 9-5/8"40#L-80 24.5-3955 24.5-3590.22 5750 3090 Intermediate None None None None None None Production 8222.5 7"26#L-80 24.5-8247 24.5-7307.96 7240 5410 Liner None None None None None None Perforation depth Measured depth 7837-7857 feet 7857-7860 feet 7872-7882 feet 7882-7902 feet True Vertical depth 6958.69-6975.74 feet 6975.74-6978.3 feet 6988.54-6997.07 feet 6997.07-7014.15 feet Tubing(size,grade,measured and true vertical depth) 2-7/8"6.5#L-80 23-7753 23-6887.16 Packers and SSSV(type,measured and true vertical depth) None None None Packer None None None SSSV 12.Stimulation or cement squeeze summary: sQ'��NED N 0 V 3 2 0}'zi Intervals treated(measured): • 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: 117 20 110 140 220 Subsequent to operation: 124 33 240 140 221 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 6 ' Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil [J. Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC-❑ 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: N/A Contact Nita Summerhays Email Nita.SummerhaVS(c7BP.com Printed Name Nita Summer -ys Title Petrotechnical Data Technician ,iA%%///J1 S'. a 3 I/4.4f'., e %/- Phone 564 4035 Date 7/22/2013 ■ftsmiiii...' �,L� BBDAS JUL 24 201& q-/ 3) 113 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0047437 ***WELL S/I ON ARRIVAL *** (E-LINE SET LOWER PACKER ELEMENT) INITIAL T/I/O = 250/1000/0 PSI SET 2-7/8"WFD LOWER PACKER ELEMENT @ 4670 TOP OF PACKER SET @ 4667.8', ID = 1.468", OAL=2.64' FINAL T/I/O =250/1000/0 PSI WELL S/I ON DEPARTURE PAD OP NOTIFIED OF STATUS 6/19/2013 ***JOB COMPLETE*** ***WELL S/1 ON ARRIVAL*** (set patch) SET SPACER PIPE W/ LOWER ANCHOR (OAL-28') @ 4658' SLM. SET UPPER PACKER W/SPACER PIPE (oal-15') W/ HALIBURTON DPU @ 4628' SLM. PULLED 1" DGLV FROM ST#2 @ 142' MD. 6/27/2013 ***CONTINUE ON 06-28-13. *** *** CONTINUED FROM 06-27-13 *** (set patch) SET 1" DPSOV IN ST#2 @ 142' MD. PULLED 2.5"A-1 SLIP STOP (used as catcher) FROM 2511' SLM. 6/28/2013 ***WELL LEFT S/I ON DEPARTURE*** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL Tree: 2 9/16" - 5M WKI MPU E-�9 OriOF Elev. = 58.55'(N 27E) Wellhead: 11" x 11" 5M FMC, Orig. GL Elev. =24.5' Gen 5 w/ 11"X 2 7/8" FMC ESP/HT I LV DF To Tbg. 7" Hgr. = 33.75' (N 27E)Hi 2 7/8" EUE Threads , and 2.5" / ��i CIW H BPV profile 0 20" 91.1 ppf, H-40 115' / � 0 tj Camc o 2 7/8"x 1" 142` KOP @ 350' / sidepocket KBMM GLM t Max. hole angle = 32 to 33 deg. 0 / ,:N f/2500'to 3650' 0 ',A Hole angle thru' perfs= 31 deg / V 0 9 5/8"Howco`ES'Cementer 1296' 9 5/8", 40 ppf, L-80 BTC 3,955' A v k Centrilift Heat Trace 3488' WFD Patch Set 6/27/13-42.84"OAL @ 4624'MD Minimum ID-1.31"Upper Pkr 14.6 OAL, / 0 ■ Spacer Pipe 27.9'OAL 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg. & 2 7/8"WFD Lower Packer Element,ID=1.468" ( drift ID = 2.347", cap. = 0.00579 bpf) / 4670'MD(OAL=2.64"-Top of Pkr.Set @ 4667' / Set-6/24/13 7" 26 ppf, L-80, BTC prod. casing (drift ID=6.151", cap. = 0.0383 bpf) 0 Camco 2 7/8"x 1" 0 :. sidepocket KBMM GLM 7489 r XN Nipple-2.313"landing 7640' NOTE: PUMP IS EQUIPPED WITH 0 - profile,2.205"No-Go.II 2-7/8" BY 2-3/8" DISCHARGE HEAD Centrilift SP, ID= 1.769" Model FPDIS 400 Series 00' 98 P8 Model PMSXD 98 P8 Model PMSXD 0 al 98 P8 Model PMSXD 7707' / - Centrilift Gas Separator ' i 7719' GSTHVER/Gas Master O Mr Tandem Centrilift seal section /s GSB3 DB UT SB/SB PFSA 7724' 60 GSB3 DB LT SB/SB PFSA � `� Centrilift KMH, 114 hp motor 7738' Stimulation Summary Almw,. 2330 volts/30 amps A. none performed Phoenix XTO PumpMate 7749' aI PumpMate TVD-6860' Centralizer 7751' Perforation Summary Ref loq:GR/CCL 4/ 14/97 Size SPF Iterval (TVD) I I 11 n n cCiaaacia. II II " II 7" short joint from 7710"to 7752'and 4.5" 5 7,837'-7,860' 6,958'-6,978' II I. II B-Sands II �' 4.5" 5 7,872'-7,902' 6,989'-7,014' ii II II II VI n II n n n II n II /1 Slickline tag 4/28/02 8089'wlm PI II V _#_+.i_1`'t'*44 7"float collar(PBTD) 8,164' 7" float shoe 8,247' DATE REV BY COMMENTS MILNE POINT UNIT 03/22/97 JBF Drilled &Cased by Nabors 27 E 05/06/97 MDO ESP Carrpk4on 4-ES/ESP RiNO 06/06/98/ESP RWO 4/29/02 WELL E-19 12/03/04 MDO iSP RWO Completion 4ES 6/20/08 LH ESP RWO Recompletion 3S API NO: 50-029-22746 10/17/10 REH ESP RWO-Nabors 4ES 07/19/12 B.Bixby ESP RWO-Doyon 16 06/30/13 B.Bixby WFD Set Lower Packer/Patch Set BP EXPLORATION (AK) • STATE OF ALASKA ALL OIL AND GAS CONSERVATION COOSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing Pull Tubing . ❑ Stimulate - Frac ❑ Waiver .1 Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change Out ESP ' 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory — 197 - 037 • 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22746 - 00 - 00 . 7. Property Designation (Lease Number): . 8. Well Name and Number: ADL 047437 • MPE -19 . 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands , 11. Present well condition summary Total depth: measured 8249 feet Plugs (measured) None feet true vertical 7310 • feet Junk (measured) None feet Effective depth: measured 8164 feet Packer: (measured) None feet true vertical 7237 feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3930' 9 -5/8" 3955' 3590' 5750 3090 Intermediate Production 8222' 7" 8247' 7308' 7240 5410 Liner M EDAUG 2 'U Perforation Depth: Measured Depth: 7837' - 7902' True Vertical Depth: 6959' - 7014' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L - 7753' 6887' Packers and SSSV (type, measured and true vertical depth): None 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): AUG 06 2012 Treatment description including volumes used and final pressure: AOGCC 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 126 23 366 210 173 Subsequent to operation: 115 65 306 220 181 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: — ❑ Exploratory ►_ Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations 16. Well Status after work: ®® Oil • ❑ Gas ❑ WDSPL 0 Well Schematic Diagram ❑ 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: Contact David Bjork, 564 -5683 N/A Printed Na Joe : 1 Title Drilling Technologist Signature Phone 564 -4091 Date f5 5/ / Prepared By Name /Nu / Jo e Lastufka, 564 - \ � Form 10-404 Revised 11/2011 . . s irY��7 D ec+ AUG 0 7 2O fi r) I _ se•71 Z/ixf Submit Original Only x to • • R f Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- 00WM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/14/2012 18:00 - 19:30 1.50 MOB P PRE PJSM, WELL TO WELL RIG MOVE - PREP RIG FOR MOVE, RUN AND INSPECT MOVING EQUIPMENT, SPCC CHECKS - NOTIFY PAD OPERATOR OF RIG MOVE - WSL, DAY AND NIGHT TOOLPUSHERS AND DDI RIG SUPERINTENDENT PRESENT - MOVE RIG OFF MPE -04 19:30 - 22:00 2.50 MOB P PRE POSITION RIG OVER WELL MPE -19 - MOVE RIG DOWN PAD AND POSITON TO PULL OVER WELL - BACK OVER WELL, ENSURE CENTER OF RIG IS OVER WELL - SET RIG DOWN AND SHIM - PREP CELLAR AREA FOR RIG UP 22:00 - 00:00 2.00 MOB P PRE POSITION CUTTINGS TANK - PREP PITS TO TAKE ON SEA WATER - HARDLINE RIGGED UP BY HARDLINE CREW - PREP FOR RIG ACCEPT 7/15/2012 00:00 - 01:30 1.50 WHSUR P WHDTRE ACCEPT RIG AT 00:00 HOURS , - R/U CIRCULATING LINES IN CELLAR FILL PITS WITH 120 DEGREE 8.5 SEA WATER -- HARD -LINE CREW COMPLETED R/U OF HARDLINE TO FLOW TANK 01:30 - 02:00 0.50 WHSUR P WHDTRE HARD -LINE CREW TESTED LINE TO FLOW TANK - TEST TO 300 PSI LOW, 4000 PSI HIGH, TESTED GOOD 02:00 - 02:30 0.50 WHSUR P WHDTRE PRESSURE TESTED KILL MANIFOLD SURFACE LINES - 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - CYCLE AND FUNCTION TEST SSV WITH REMOTE ESD PANEL ON RIG FLOOR - TESTED HIGH LEVEL ALARM ON FLOW BACK TANK = GOOD 02:30 - 03:30 1.00 MOB P DECOMP HOLD RIG EVACUATION DRILL WITH D CREW AND ALL PERSONEL ON LOCATION - CONDUCT AAR WITH CREW AND WSL 03:30 - 05:00 1.50 MOB P DECOMP CONTINUE R/U - P/T ALL LINES FROM MUD PUMP TO RIG FLOOR - WORK ORDER - PREP FOR WELL KILL OPERATIONS 05:00 - 07:00 2.00 WHSUR P DECOMP PJSM, WELL SUPPORT ON LUBRICATOR OPS - M/U WELL SUPPORT LUBRICATOR TO TREE - PRESSURE TEST 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED 07:00 - 08:00 1.00 WHSUR P DECOMP PULL BPV - TBG =1200 PSI , IA =1150 - RD LUBRICATOR Printed 7/30/2012 10:25:55AM ' , , Common Well Name: MPE-1 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- 00WM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 ©84.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 14:30 6.50 WHSUR P DECOMP PJSM FOR BULL HEAD WELL KII L OPFRATI(')NS WITH flfll CRFW WSL AND RWO SUPT - BULL HEAD 70 BBLS DOWN THE TUBING WITH 3 -4 BPM, ICP 1150, FCP 0. - LINE UP TO BULLHEAD DOWN THE IA. PUMP 350 BBLS WITH 7 -8 BPM, ICP 1420 PSI , FCP 1100 PSI. - MONITOR WELL FOR 30 MIN. - IA SHOWING ZERO PRESSURE AND IS ON A STRONG VAC. - OPEN TUBING TO CHECK FOR PRESSURE, TUBING SHOWING 1350 PSI. TALKED TO ODE AND PLAN FORWARD WAS AGREED TO PUMP 60 MORE BBL DOWN THE TUBING. - PUMPED 3.5 BPM WITH ICP OF 1400 PSI AND FCP OF ZERO - SHUT DOWN AND MONITOR FOR 30 MIN. - CHECK PRESSURES, BOTH THE IA AND TBG ARE BETWEEN 450 -500 PSI. DISCUSSED PLAN FORWARD WITH ODE. WE BOTH AGREED TO PUMP ANOTHER 70 BBLS DOWN THE TBG & IA AT THE SAME TIME. - PUMPED 7 -8 BPM WITH 500 -550 PSI, SHUT DOWN AND MONITOR FOR 20 MIN AND CHECK PRESSURES - THE TUBING IS ON A STRONG VAC AND THE IA IS STILL AT 450 PSI. 14:30 - 17:30 3.00 WHSUR P DECOMP DISCUSSION WITH ODE AND RWO TL - DECISION WAS MADE TO DO A CONTROLLED FLOW CHECK TO THE TIGER TANK - HELD A PJSM FOR CHANGE IN SCOPE OF WORK. TO INCLUDE BLEEDING PRESSURE TO THE TIGER TANK. RIG CREW DOING PRE CHECKS OF THE TANK. - VERIFY LINE UP FROM THE MANIFOLD TO THE TIGER TANK WITH THE TP. STARTING PRESSURES: IA -450 PSI , OW- ON A STRONG VAC - BLEED IA FROM 450 PSI TO 350 PSI AND MONITOR FOR 10 MIN, NO INCREASE IN PRESSURE. - REPEAT THE PROCESS OF CONTRLLED FLOW CHECK ON IA IN 100 PSI INCRIMENTS AND MONITORING FOR 10 MIN UNITIL ZERO PSI IS REACHED, SHUT IN FOR 10 MIN & MONITOR. - IA PRESSURE INCREASE TO 10 PSI IN 10 MIN. - CHECK TUBING, NOW SHOWING SLIGHT PRESSURE @ 10 PSI. - CALLED ODE AND LET HIM KNOW WHERE WE WERE AT WITH PRESSURES. - MONITOR PRESSURES FOR 30 MIN. 17:30 - 19:30 2.00 WHSUR N HMAN DECOMP MONITORING TUBING AND IA - BOTH ARE SHOWING LESS THAN 10 PSI - DISCUSS OPTIONS WITH TOWN ODE - DECIDED TO PUMP 20 BBLS DOWN TUBING Printed 7/30/2012 10:25:55AM x a Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- 00WM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 20:00 0.50 WHSUR N HMAN DECOMP PUMP 20 BBLS 8.5 SEA WATER DOWN TUNING - 3 BPM = 30 PSI - SHUT DOWN AND MONITOR TUBING AND IA - TUBING IS ON A STRONG VAC 20:00 - 22:30 2.50 WHSUR N HMAN DECOMP CONTINUE MONITORING IA AND TUBING - AI = 0 PSI WITH SLIGHT AIR "EXHALING" TUBING VAC SLOWED DOWN TO A "SLIGHT' VAC DISCUSS OPTIONS WITH TOWN ODE - FLOW CHECK IA FOR 30 MINUTES - SHUT IN AND MONITOR IA PRESSURE FOR 10 MINUTES - PRESSURE READING 0 PSI, BUT STILL SLIGHT "EXHALE" THROUGH IA - DISCUSS OPTIONS WITH TOWN ODE - TUBING IS STILL ON A SLIGHT VAC - DECIDE TO SET TWC AND PERFORM ROLLING TEST FROM BELOW 22:30 - 00:00 1.50 WHSUR N HMAN DECOMP PJSM ON R/U OF WELL SUPPORT LUBRICATOR AND SETTING TWC - R/U LUBRICATOR AND TWC RUNNING TOOLS TEST LUBRICATOR 250 PSI LOW, 3500 PSI HIGH 5 MIN, CHARTED = GOOD - SET TWC - TOTAL 24 HOUR FLUID LOSS = 600 BBLS 7/16/2012 00:00 - 00:30 0.50 WHSUR N HMAN DECOMP CREW CHANGE OUT, SPCC CHECKS - CONTINUE TO SET TWC WITH WELL SUPPORT CREW - SET COMPLETE - R/D LUBRICATOR RUNNING TOOLS 00:30 - 01:30 1.00 WHSUR N HMAN DECOMP PJSM TO PERFORM ROLLING TEST ON TWC FROM BELOW - OBSERVED IA HAD BUILT TO 24 PSI OVER THE APPROXIMATE 3 HOURS WHILE RIGGING UP, TESTING AND SETTING TWC - PUMP IN THE IA FOR ROLLING TEST AT 3 BPM = 50 PSI - 37 BBLS PUMPED AWAY - SHUT DOWN PUMPS, SHUT IN IA TO GAGE - IA PRESSURE INCREASED TO 38 PSI - OBSERVED LOW PRESSURE LEAKING PAST THE TWC - CALLED DAY WSL AND TOWN ODE TO DISCUSS PLAN FORWARD - DECIDE TO PULL TWC - PLAN TO BULL HEAD DOWN TUBING AND IA AT SAME TIME 01:30 - 04:00 2.50 WHSUR N HMAN DECOMP PJSM TO PULL TWC - M/U WELL SUPPORT LUBRICATOR - TEST LUBRICATOR, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - PULL TWC, SECURE WELL - IA =8 PSI - TUBING = 32 PSI 04:00 - 08:00 4.00 WHSUR N HMAN DECOMP PREPARE FOR BULLHEAD OPERATION - CALL FOR ADDITIONAL 8.5 SEAWATER - WAITING FOR FINAL DECISION FOR BULL HEAD KILL Printed 7/30/2012 10:25:55AM H $ Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- 00WM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 09:30 1.50 WHSUR N HMAN DECOMP PJSM FOR BULL HEAD KILL OPERATIONS - DISCUSS DDI SOP AND BULL HEAD LINE UP - PREP CELLAR AND LINE UP KILL MANIFOLD, FOR WSL & TP TO SIGN OFF ON. - LINE UP VAC UNIT FOR OFF LOAD DURING BULL HEAD OPS 09:30 - 11:30 2.00 WHSUR N HMAN DECOMP CONFIRM LINE UP OF KILL MANIFOLD BULL HEAD 550 BBLS OF 8.5 PPG SEA WATFR AT 7 - 8.5 BPM, TBG -100 PSI, IA -100 PSI - MONITORING THE OA DURING BULL HEAD. - PUMPED 291 BBLS AT 8.5 BPM WITH 100 PSI ICP & 400 PSI FCP , SHUT DOWN AND BLEED THE PRESSURE OFF THE OA - CONT: BULL HEADING 260 BBLS OF 8.5 PPG SEA WATER. @ 8.5 BPM, FCP -925 PSI 11:30 - 12:30 1.00 WHSUR P DECOMP MONITOR THE WELL - IA AND TUBING ON VAC - RU FOR CONTINUOUS HOLE FILL. =GREW CHANGE - PJSM FOR PICKING UP AND TESTING LUBRICATOR 12:30 - 14:30 2.00 WHSUR P DECOMP RU AND PRESSURE TEST LUBRICATOR 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN - INSTALL TWC & ATTEMPT ROLLING TEST FROM BELOW WITH 3 BPM , @ 40 PSI, FOR 10 CHARTED MIN. PRESSURE TEST FROM ABOVE TO 250 LOW AND 3500 HIGH - RD LUBRICATOR 14:30 - 16:30 2.00 WHSUR P DECOMP RD CELLAR LINES AND CIRC MANIFOLD. - ND TREE, ADAPTER FLANGE AND SET BACK - FMC VERIFIED THE ORIENTATION FOR PROPER COMPLETION LATER & INSPECTED HANGER LIFTING THREADS - CONTINUOUS HOLE FILL AT 20 BPH 16:30 - 19:30 3.00 BOPSUR P DECOMP PJSM ON N/U BOPE - N/U BC)PF - INSPECT AIR BOOTS, INSTALL RISER, MOUSE HOLE, TURNBUCKLES - R/U TEST EQUIPMENT - P/U 2 7/8 TEST JT, AND INSTALL IN BOP - FILL WITH WATER AND PURGE AIR FROM TEST EQUIPMENT - VEHICLE BACKING INCIDENT AT 17:30 HRS, SEE #IR- 4181906 - NOTIFIED OPS SUPERINTENDENT OF INCIDENT Printed 7/30/2012 10:25:55AM - „ Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- 00WM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 19:30 - 00:00 4.50 BOPSUR P (ft) DECOMP PJSM, TEST BOP'S AS PER DOYON TEST PROCEDURE - TEST ALL BOPE AND CHOKE MANIFOLD VALVES TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES, CHARTED - TEST ANNULAR USING 2 7/8" TEST JOINT - TEST VBR PIPE RAMS USING 2 7/8" AND 4" TEST JOINTS - TEST BOTH SETS OF 2 7/8" AND 4" FLOOR VALVES - TEST USING FRESH WATER - PERFORM DRAW DOWN TEST ON ACCUMULATOR 200 PSI INITIAL PRESSURE RECOVERY = 10 SECONDS - FULL PRESSURE RECOVERY = 99 SECONDS - FAIL TEST ON HCR KILL, WILL CHANGE OUT AND RE- TEST - CHUCK SCHEVE OF AOGCC WAIVED STATES RIGHT TO WITNESS BOP TEST MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH W/ 8.5 SEA WATER - TOTAL 24 HOUR FLUID LOSS = 773 BBLS 7/17/2012 00:00 - 01:00 1.00 BOPSUR P DECOMP PJSM, CREW CHANGE, SPCC CHECKS, INSPECT RIG AND BOP EQUIPMENT LINE UPS - CONTINUE TO TEST BOP'S - PERFORM DRAW DOWN TEST ON ACCUMULATOR - 200 PSI INITIAL PRESSURE RECOVERY = 10 SECONDS - FULL PRESSURE RECOVERY = 99 SECONDS - CHUCK SCHEVE OF AOGCC WAIVED STATES RIGHT TO WITNESS BOP TEST 01:00 - 03:30 2.50 BOPSUR N RREP DECOMP PJSM ON C/O OF HCR KILL - ENSURE PROPER RIGGING AND IDENTIFY HAZARDS - BLOW DOWN KILL AND CHOKE LINES, AND BOP STACK - REMOVE BAD HCR KILL - REPLACE WITH NEW HCR KILL VALVE 03:30 - 04:30 1.00 BOPSUR P DECOMP FILL KILL LINE AND BOP TO TEST HCR KILL - TEST HCR KILL TO 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED = GOOD - R/D TEST EQUIPMENT 04:30 - 06:30 2.00 BOPSUR P DECOMP RIG DOWN ALL TEST LINES AND EQUIPMENT - BLOW DOWN ALL LINES AND SUCK OUT STACK - ENSURE ALL VALVES ON STACK ARE LINED UP PROPERLY - M/U OPSO LOPSO TO HANGER 06:30 - 08:00 1.50 WHSUR P DECOMP RIG UP WELL SUPPORT LUBRICATOR AND PRESSURE TEST TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MINUTES EACH TEST. PULL THE TWC AND RIG DOWN WELL SUPPORT. 08:00 - 09:00 1.00 PULL P DECOMP RIG UP THE SHEAVE AND TRUNK WITH DOUBLE ROPES TO STRING ESP CABLE AND HEAT TRACE. Printed 7/30/2012 10:25:55AM Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- 00WM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 09:30 0.50 PULL P DECOMP HOLD KICK DRILL WITH RIG CREW, CENTRILIFT HAND, DOYON TOOL PUSHER , AND BP WSL. 09:30 - 11:30 2.00 PULL P DECOMP MAKE UP THE LANDING JOINT WITH FOSV TO HANGER, BOLDS, PULL THE HANGER TO THE FLOOR. UP WT 115K / DOWN WT. 97K. LAY DOWN THE HANGER AND MAKE UP LANDING JOINT. 11:30 - 12:00 0.50 PULL P DECOMP BULLHEAD 45 BBLS @ 3 BPM WITH 80 PSI. MONITOR THE WELL FOR 10 MINUTES. 12:00 - 22:30 10.50 PULL P DECOMP PJSM, DISCUSS WELL CONTROL. PULL OUT OF THE HOLE WITH THE 2 -7/8" EUE 8RD COMPLETION WITH ESP CABLE AND HEAT TRACE LINE. 4JP WT 115K / DOWN WT 97K. REPLACE JOINTS 86, 88, 92, 93, 94 COMING OUT OF THE HOLE. 22:30 - 00:00 1.50 PULL P DECOMP , I AY ROWN THE CENTRILIFT PUMP ASSEMBLY AS PER THE CENTRILIFT HAND. RECOVERED 242 TOTAL JOINTS, 547'5' HEAT TRACE CLAMPS, 91 2 HEAT TRACE CLAMPS, 71 2" CANNON CLAMPS, 5 MOTOR LEAD CLAMPS, 2 ARMSTERS, 5 PROTECTOLIZERS. -MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH W/ 8.5 SEA WATER -TOTAL 24 HOUR FLUID LOSS = 460 BBLS 7/18/2012 00:00 - 00:30 0.50 PULL P DECOMP FINISH LAYING DOWN THE CENTRILIFT PUMP ASSEMBLY AS PER THE CENTRILIFT HAND. 00:30 - 01:00 0.50 PULL P DECOMP CLEAR AND CLEAN THE RIG FLOOR. 01:00 - 01:30 0.50 PULL P DECOMP RIG DOWN THE ESP SHEAVE AND TRUNK. 01:30 - 02:00 0.50 WHSUR P DECOMP INSTALL 9" ID WEAR BUSHING. 02:00 - 04:00 2.00 WHSUR P DECOMP SLIP AND CUT 115' OF DRILLING LINE. 04:00 - 09:30 5.50 EVAL P DECOMP MAKE UP CHAMP PACKER AND RUN IN THE HOLE ON 2 -7/8" TUBING. , - F/ SURFACE T/ 7500' 09:30 - 11:30 2.00 EVAL P DECOMP PUWT = 95K, SOWT = 77K - CIRCULATE 5 BPM = 50 PSI, NO RETURNS - SET PACKER AT 7505' MD WITH 20K DOWN WT. - FILL IA, ALLOW AIR TO WORK OUT OF WELL - CLOSE PIPE RAMS 11:30 - 13:30 2.00 EVAL P DECOMP R/U TEST EQUIPMENT AND TEST 7" 26# L -80 CASING - MIT-IA, 250 PSI LOW 5 MIN, 2500 PSI HIGH 30 MIN, CHARTED = GOOD TEST - NOTIFY WTL OF RESULTS, RECEIVE AUTHORIZATION TO PROCEED - BLEED OFF PSI, OPEN RAMS, RELEASE PACKER - MONITOR WELL 10 MIN = WELL ON VAC - BLOW DOWN ALL LINES, R/D TEST EQUIPMENT 13:30 - 18:00 4.50 EVAL P DECOMP PJSM, POOH F/ 7505' T/ SURFACE - L/D CHAMP PACKER - CLEAR RIG FLOOR 18:00 - 19:00 1.00 RUNCOM P RUNCMP PULL THE WEAR RING, RIG UP THE ESP SHEAVE AND PREPARE TO RUN 2 -7/8" COMPLETION. Printed 7/30/2012 10:25:55AM I t•a,4 a " Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- 00WM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 21:00 2.00 RUNCOM P ■- RUNCMP ASSEMBLE SERVICE T CENTRILIFT PUMPS MPS AND MOTOR R AS S PER THE CENTRILIFT REP. ATTACH THE ESP LEAD. 21:00 - 00:00 3.00 RUNCOM P RUNCMP RUN IN THE HOLE WITH 2 -7/8" L80 6.5LB/FT FIIF RRf) TURING WITH ESP CABLE AS PER PIPE TALLY TO 3000'. UTILIZE BOL 2000 PIPE DOPE TORQUING ALL CONNECTIONS TO 2300 FT /LBS. CHECK THE CONDUCTIVITY AND CIRCULATE 5 BBLS AT .5BPM EVERY 2000'. - MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH W/ 8.5 SEA WATER - TOTAL 24 HOUR FLUID LOSS = 538 BBLS 7/19/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP SERVICE THE TOPDRIVE, TONGS, AND SLIPS. 00:30 - 02:00 1.50 RUNCOM P RUNCMP CONTINUE TO RUN IN THE HOLE WITH THE 2 -7/8" ESP COMPLETION FROM 3000' TO 4264' - 7752' AS PER RUNNING ORDER. CHECKING CONDUCTIVITY EVERY 2000' AND PUMPING 02:00 - 02:30 0.50 RUNCOM P RUNCMP CONNECT THE HEAT TRACE. 02:30 - 17:30 15.00 RUNCOM P RUNCMP CONTINUE TO RUN IN THE HOLE WITH THE 2 -7/8" ESP COMPLETION FROM 4264' - 7752'. UTILIZE BOL 2000 PIPE DOPE TORQUING ALL CONNECTIONS TO 2300 FT /LBS. CHECK THE CONDUCTIVITY AND CIRCULATE 5 BBLS AT .5BPM EVERY 2000'. FCP 40 PSI AT 2 BPM. 17:30 - 18:30 1.00 RUNCOM P RUNCMP PICK UP AND MAKE UP THE HANGER, CUT THE ESP AND HEAT TRACE CABLES. RIG DOWN THE ESP SHEAVE. 18:30 - 22:30 4.00 RUNCOM P -_ RUNCMP TERMINATE ESP /HEAT TRACE CABLES AT THE HANGER. 22:30 - 23:00 0.50 RUNCOM P RUNCMP CHECK CONDUCTIVITY ON THE ESP AND HEAT TRACE CABLES. GOOD. LAND THE TUBING HANGER AND VERIFY. RILDS. 23:00 - 00:00 1.00 RUNCOM P RUNCMP RIG UP AND TEST TWC. PERFORM A ROLLING TEST FROM BELOW FOR 10 MINUTES PUMPING AT 3 BPM AT 0 PSI. TEST FROM ABOVE TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MINUTES EACH TEST. GOOD TEST. - MAINTAIN CONTINUOUS HOLE FILL AT 20 BPH W/ 8.5 SEA WATER - TOTAL 24 HOUR FLUID LOSS = 551 BBLS 7/20/2012 00:00 - 01:00 1.00 BOPSUR P ■- WHDTRE RIG DOWN THE LINES EQUIPMENT, AND SUCK OUT BLOW T DOWN ALL THE LIN AND SUCK OUT THE STACK. 01:00 - 02:00 1.00 BOPSUR P WHDTRE NIPPLE DOWN THE BOPE. 02:00 - 04:30 2.50 WHSUR P WHDTRE NIPPLE UP THE ADAPTOR FLANGE AND TREE. CENTRILIFT PERFORM CONDUCTIVITY TEST. FMC TEST THE ADAPTOR FLANGE TO 250 PSI FOR 5 MINUTES AND 5000 PSI FOR 30 MINUTES. GOOD TEST. Printed 7/30/2012 10:25:55AM �� e • ".,,,,,/,0„.„v,„07, r*, ,;;,‘,44,4,, we ,-;:-, ,,47;:„,,,,,,gcs—A- , Commo mon Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 7/14/2012 End Date: 7/20/2012 X4- OOWM7 -E: (950,000.00 ) Project: Milne Point Site: M Pt E Pad n Name /No.: DOYON 16 Spud Date/Time: 4/27/2002 12:00:00AM Rig Release: 7/20/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 32:19 5/4/1998 12:00 @84.10ft (above Mean Level) Date From - To HIS Code Sea NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 06:30 2.00 WHSUR P WHDTRE FILL THE WITH DIESEL PRESSURE TEST TO 250 PSI LOW AND 5000 PSI HI FOR 5 MINUT EA TEST. GOOD TEST. 06:30 - 08:00 1.50 WHSUR P WHDTRE R/U WELL SUPPORT TREE LUBRI CATOR CH TEST, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED PULL TWC H 08:00 - 09:30 1.50 L BPV WHSUR P WHDTRE M/U BPV RUNNING TOOL iBH T EST LUBRICATOR 250 PSI LOW, 3500 PSI IGH, 5 MIN, CHARTED INSTAL - PERFORM 500 PSI ROLLING TEST FROM D ELOW, 3BPM = 70 PSI, 32 BBLS PUMPE RID W/S LUBRICATOR AND EQUIP. 09:30 - 10:00 0.50 WHSUR P WHDTRE SECURE TREE AND CELLAR CLEAN PITS HE AND CUTTING TANK / TOTAL 10 OUR FLUID LOSS = 166 BBLS ✓ 10:00 - 12:00 2.00 WHSUR P WHDTRE PREP THE RIG FOR MOVING, JACK UP THE RIG AND REMOVE THE MATS, STAGE THE SLOP TANK ON THE NEXT WELL. RELEASE T RIG AT 12:00 Printed 7/30/2012 10:25:54AM Tree: 2 9/16" - 5M WK• Orig. Elev. = 58.55' (N 27E) Wellhead: 11" x 11" 5M FMC, MPU E-19 Orig. GL Elev. = 24.5' Gen 5 w/ 11 X 2 7/8 FMC ESP /HT % ;'► ' DF To Tbg. 7" Hgr. = 33.75' (N 27E) 2 7/8 EUE Threads, and 2.5" 0 �, CIW H BPV profile 4 V 20" 91.1 ppf, H -40 115' % 1. 0 LA 0 � ; Camco 2 7/8" x 1" 142' KOP @ 350' 0 1 s idepocket KBMM GLM Max. hole angle = 32 to 33 deg. 0 ,I f/ 2500' to 3650' / Hole angle thru' perfs = 31 deg �, O 9 5/8" Howco 'ES' Cementer 1296' 'f 9 5/8 ", 40 ppf, L -80 BTC 3,955' A / 7, Centrilift Heat Trace I 3488' /° 2 7/8" 6.5 ppf, L -80, 8rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00579 bpf) 7" 26 ppf, L -80, BTC prod. casing 1 ( drift ID = 6.151", cap. = 0.0383 bpf) / It Camco 2 7/8" x 1" 0 sidepocket KBMM GLM 7489' / 0 XN Nipple - 2.313" landing 7640' aim / profile, 2.205" No -Go. NOTE: PUMP IS EQUIPPED WITH / / 2 -7/8" BY 2 -3/8" DISCHARGE HEAD / �/ ID= 1.769" Model FPDIS 400 Series 4 Centrilift ESP, /," "7 98 P8 Model PMSXD 0 Ni 98 P8 Model PMSXD I 7707' /_ tmiii 98 P8 Model PMSXD O7-1,-„Aava.„ - - Centrilift Gas Separator 7719' / GSTHVER / Gas Master / Tandem Centrilift seal section I GSB3 DB UT SB /SB PFSA 7724 0 7 .x D . GSB3 DB LT SB /SB PFSA Centrilift KMH, 114 hp motor I 7738' Stimulation Summary m inlm, 2330 volts / 30 amps none performed In Phoenix XTO PumpMate 7749' 1 1 , 1 PumpMate TVD - 6860' C entralizer 7751' Perforation Summary Ref log: GR /CCL 4 /14 / 97 1:4)-) 1;l �� Size SPF Iterval (TVD) 2 C -Sands 7" short joint from 7710" to 7752' and 4.5" 5 7,837'- 7,860' 6,958'- 6,978' B -Sands 4.5" 5 7,872'- 7,902' 6,989'- 7,014' in III Slickline tag 4/28/02 8089' wlm :te..` .,,* f7 7" float collar (PBTD) 8,164' S .es..f i . +..+4►, 7" float shoe 8,247' DATE REV. BY COMMENTS MILNE POINT UNIT 05/ /s7 /97 MDO ESP Cased iEESP by 06/06 /98 / EESP RW os / 0 4/29/03 os WELL E -19 12/03/04 MDO ESP RWO Completion 4ES API NO: 50 -029 -22746 6/20/08 LH ESP RWO Recompletion 3S 10/17/10 REH ESP RWO - Nabors 4ES 07/19/12 B. Bixby ESP RWO - Doyon 16 BP EXPLORATION (AK) * v erg: a ..: .: s u. W . ",re «q�. +^c.*s a , r .^qv: ;xr. ",s• s n ry • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box Anchorage, Alaska 99519 -6612 s oNNED FEB December 30, 2011 197^ ©3 �f / r fr. ! n Mr. Tom Maunder \A4 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue r+tn p Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE -09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 .----,P MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory - 197 - 037 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 ' 50 -029- 22746 -00 -00 7. Property Designation: % 8. Well Name and Number: ADL 025518 & 047437 ` MPE -19 9. Field / Pool(s): Milne Point Unit / Kuparuk River ®IL h(5 1c 10. Present well condition summary Total depth: measured 8249 feet Plugs (measured) None true vertical 7310 feet Junk (measured) None Effective depth: measured 8164 feet Packer: measured None feet true vertical 7237 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 1 �''_'.. "'"" "`1490 470 Surface 3930' 9 -5/8" 3955' 3590' 5750 3090 Intermediate Production 8222' 7" 8247' 7308' 7240 5410 Liner ii AVAWNG`V I � 0 Perforation Depth: Measured Depth: 7837'- 7902' True Vertical Depth: 6959'- 7014' Tubing (size, grade, measured and true vertical depth): 2- 7/8 ",.5# L -80 7748' MD 6883' TVD Packers and SSSV (type, measured and true vertical depth): None - 7 11. Stimulation or cement squeeze summary: Intervals treated (measured): NOV 0 4 201 Treatment description including volumes used and final pressure: 4.13 ! oil & Gds Cons. co 440 Aahoroop 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 1120 0 Subsequent to operation: 164 74 192 1 0 179 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: • Daily Report of Well Operations - ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic • Well Schematic Diagram 15. Well Status . ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564 -5683 NIA Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Phone 564 -4750 Date (_l 5`1 t0. Sondra Stewman, 564 -4750 Form 10-404 Revised 07/2009 RBDMS NOV 0 5 2010 ll,G ,�� Submit Original Only e X t` Tree: 2 9/16" - 5M FMC Or ig. F Elev. = 58.55' N 27E � ( ) Wellhead: 11" x 7" 5M FMC, 7 9 Orig. GL Elev. = 24.5' Gen 5A w/ 2 7/8" WKM Tbg. Hgr. DF To Tbg. 7" Hgr. = 33.75'(N 27E) w/ 3" Acme Threads , and 2.5" CIW H BPV profile 20" 91.1 ppf, H -40 115' Camco 2 7/8" x 1" 170` KOP @ 350 sidepocket KBMM GLM Max. hole angle = 32 to 33 deg. f/ 2500' to 3650' Hole angle thru' perfs = 31 deg 9 5/8" Howco'ES' Cementer F 1296 9 5/8 ", 40 ppf, L -80 BTC 3,955' Centrilift Heat Trace 3386 2 7/8" 6.5 ppf, L -80, 8rd EUE tbg. ( drift ID = 2.347 ", cap. = 0.00579 bpf) 7" 26 ppf, L -80, BTC prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf) Carrico 2 7/8" x 1" 7519' ' sidepocket KBMM GLM XN Nipple - 2.313" landing 7660 profile, 2.205" No -Go. NOTE: PUMP IS EQUIPPED WITH 2 -718" BY 2 -3/8" DISCHARGE HEAD o' Automatic Diverter Valve 7705' ID= 1.769" Centrilift ESP, 112 P6 Model SXD 7710` 141 P6 Model SXD Centrilift Gas Separator 7739 GRSSFTXAR Tandem Centrilift seal section 7751' GS83DBFERHLSSCVH6PFSA GS83DBFERHLSSCVH6PFSA Centrilift KMH, 114 hp motor, 775g` Stimulation Summary 2330 v. / 30 amps. none performed Phoenix XTO PumpMate 7769` PumpMate TVD - 6870' Centralizer 7771' Perforation Summary Ref loci : GR /CCL 4 / 14 / 97 Size SPF Iterval (TVD) - 7" short joint from 7710" to 7752' and 4.5" 5 7,837' - 7,860' 6,958' - 6,978' B -Sands 4.5" 5 7,872' - 7,902' 6,989' - 7,014' Slickline tag 4/28/02 8089' wlm 7" float collar (PBTD) 8,164' 7" float shoe 8,247' DATE REV. BY COMMENTS MILNE POINT UNIT 03/22/97 JBF D rilled ase by Nabors 27 L 05/06/97 MDO ESPC_pWdm4ES /ESPRwo 05/06/981 ESP RWO 4 /29/02 WELL E -19 12/03/04 MDO ESP RWO Completion 4ES API NO: 50- 029 -22746 6/20/08 LH ESP RWO Recompletion 3S 10/17/10 REH ESP RWO - Nabors 4ES B EXPLORATION (AK) MPE -19 Well History Date Summary 06/27/10 MIRU CTU #8. Objective: FCO to pump, get pump running. MU 1.75" JSN. Bleed gas off wellhead. Jet diesel from surface @ 1 bpm /80 fpm. Tag plug Q 7637 (ctm). Jet top of plug, circ bottoms up. No luck getting injection so we called for acid. Continue to hold pressure on well. 06/27/10 (Coil) Heat diesel to 90* 06/28/10 CTU #8. Objective: FCO to pump, get pump running. * * ** Continued from 6/27/10 * * * * ** Spot acid at pump attempt to squeeze. Unable to squeeze acid across pump. Allow to soak retry squeeze. Nothing across pump. POOH. MU /RIH w/ 1.75" DJ nozzle. Tag pump @ 7644'. Jet on pump with diesel. Attempt to squeeze diesel through pump. Have Centrilift rep run pump. Jet to 7669'. Establish 0.1 -0.2 bpm injectivity across pump. Can't get pump to restart. POOH. FP wellbore to 2500'w/ water /meth. RDMO 06/29/10 ** *WELL S/I ON ARRIVAL * * *(esp troubleshoot, Bixby Bump) RAN 2.12" CENT, Tx 1 -1/2" STEM, 2.05" CENT, Tx 1 -1/2" STEM, 1.75" BLIND BOX. TAG PUMP @ 7,651' SLM (7,677' MD) -26' ft CORRECTION. beat on ESP for 15 min w /pad -op attempting to start pump, unsuccessful. BEAT ADDITIONAL 20 MIN ON ESP W /CENTRILIFT ATTEMPTING TO START PUMP. DID NOT START, START RIG PREP. PULL 1" BK -DGLV FROM ST #1 @ 7,490' MD. « « « < » » »> PULL 1" BEK -DPSOV FROM ST #2 @ 172' MD. SET 1" BK -DGLV IN ST #2 Q 172' MD. WELL LEFT S /I, TURN OVER TO DSO. ** *JOB COMPLETE * ** 08/02/10 Flushed both production and test lateral lines with 2bbls 60/40, 3bbls 80 *F diesel, 2bbls 60/40. 08/22/10 MPU ST ,,,,,SET BPV,,,,,, with slick, Demobed the well house flowlines and foundation , All flanges have been TQ to spec. 08/25/10 ** *WELL S/I ON ARRIVAL * ** (sbhp) RAN 1.735" CENT, S. ABSORBER, DUAL SPARTEK GAUGES. MADE 15 MIN GRADIENT STOP @ 7,157' SLM (7,183' MD). TAG ESP Q 7,651' SLM (7,677' MD). -26' ft CORRECTION. MADE 3 HR BHP STOP @ 7,646' SLM (7,672' MD). ASSIST WELL SUPPORT SET BPV. WELL LEFT S /l, TURN OVER TO DSO. ** *JOB COMPLETE * ** 09/01/10 T /I /O =BPV /1100/0 +, Temp =Sl. PPPOT-T (PASS), PPPOT -IC (PASS). Pre RWO. PPPOT -T: Stung into test port (1100 psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Pressured void to 5000 psi for 30 min test, lost 100 in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (100 psi), bled to 0 psi. Functioned LDS, all moved freely (.75 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. C 09/15/10 Trip to Ku aruk for diesel. � 10/15/10 SURFACE WORK 4 -ES INSTALL DPSOV IN TOP SPM AND DUMMY IN BOTTOM SPM 10/17/10 T /1 /0 =0/0/0 (Post RWO Freeze protect Tbg & IA). Pump 15 bbls crude down Tbg. Pump 65 bbls crude down IA. Hang F/P tags. FWHP = 0/0/0. Rig 4ES has control of well Q LRS departure. 10/25/10 MPU ST Rehooked well, Set foundation flowlines then well house, all flanges were TO to spec and BPV was PULLED from well, Both Test and Production Flowlines were PT to 1150 PSI with diesel for 10 min, Passed. Page 1 of 2 MPE -19 Well History Date Summary 10/28/10 *** WELL S/I ON ARRIVAL' "' (trouble shoot esp) DRIFT TUBBING W/ 2.23 CENT,SAMPLE BAILER S/D Q 7610' SLM. BAILER EMPTY. PULL 1" DPSOV & RESET NEW DPSOV IN ST #2 Q 170' MD. LRS PUMPED 3 BBLS 60/40 FOLLOWED BY 20 BBLS DIESEL. SET 2.5" CAT VALVE @ 7610' SLM.LRS UNABLE TO CATCH PRESSURE. PULLED CAT VALVE FROM 7610' SLM. RAN 2.5" KOT W/ 1.25" LIB TO GET CORRECTION FROM ST #1 @ 7519' MD.LOCATED Q 7471' SLM (48' correction). RAN 2.5" KOT W/ 1.25" LIB TO ST #2 @ 170 MD TO VERIFY DPSOV SET.RECOVERED LATCH IMPRESSION. RAN 2.5" CAT VALVE @ 7660' MD.LRS PERFORMED MIT- T,PASSED (see Irs log). " "" WELL LEFT S/I ON DEPARTURE *** 10/31/10 T /I /0 =0/0/0 Load Tbg Pumped 40 bbls crude down Tbg. DSO brought well on -line. FWHP's =0/0/0 10/31/10 T /1 /0 =0/0/0 IA Flush Pumped 125 bbls crude down IA. DSO brought well on -line. FWHP's =0/0/0 I III Page 2 of 2 North America - ALASKA BR, Pie *Qf a Qperaf�on Summar�i Report. Well Common W II Name: MPE -19 AFE No Event Type: WORKOVER WO Start Date: 10/12/2010 End Date: X4- OORF9 -E (415,000.00) Y p ( ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 4/27/2002 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 32: 1 9 5/4/1998 12:00 @84.1 Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/12/2010 00:00 - 06:00 6.00 MOB P PRE WAITING ON TRUCKS FOR RIG MOVE, (TRUCKS UNAVAILABEL DUE TO OTHER RIG(S) MOVING. 06:00 - 08:30 2.50 MOB P PRE TRUCKS ON LOCATION AT 0800 HRS LEFT MESAGE ON 659 -3607 AOGCC, NOTICE OF BOPE TEST ON MPE -19, 08:00 HRS 10/12/2010. 08:30 15:30 7.00 MOB P PRE PRE JOB SAFETY MEETING WITH CREW AND PEAK DRIVERS. - MOVE RIG AND RIG COMPONENTS TO MOE -19. 15:30 - 18:00 2.50 MOB P PRE SEQJ EIC SUB, PITS, ED AND RIG COMPONENTS. . 18:00 19:00 1.00 MOB P PRE PTSM. CONTINUE TO SPOT RIG COMPONENTS. CONDUCT PRE TOUR CHECKS. - CONDUCT WALK THRU DERRICK INSPECTION. - 19:00 - 21:00 2.00 MOB P PRE PJSM. RAISE AND SCOPE UP DERRICK. RIG ACCEPTED @ 21:00,10/12/2010. -'RIG UP MUD LINES, LOWER SLIDE, LEVEL RIG. 21:00 - 22:30 1.50 KILLW P DECOMP TEST TIGER TANK LINES W/ STEAM / AIR. PREPARE CELLAR & LINES TO WELLHEAD. TEST SURFACE LINES TO 3500 PSI, OK. 22:30 - 00:00 1.50 KILLW P DECOMP P/U LUBRICATOR, TEST @ 250 / 1100 PSI, 5 MIN /CHARTED. - PULL BPV. PREP CELLAR AND WELLHEAD FOR KILL. 10/13/2010 00:00 - 01:00 1.00 KILLW P DECOMP CONTINUE TO RIG UP AND TEST LINES FOR KILL. CONDUCT PRE KILL SAFETY MEETING. 00:00 - 01:00 1.00 KILLW P DECOMP CONTINUE TO RIG UP AND TEST LINES FOR KILL. CONDUCT PRE KILL SAFETY MEETING. 101:00 - 02:00 1.00 KILLW P DECOMP SITP = 1200 PSI, VA = 1200 PSI, O/A = 0 PSI. - BLEED GAS OFF TUBING, THRU CHOKE TO TIGER TANK. - BLEED GAS OFF VA, THRU CHOKE TO TIGER TANK - CIRCULATE DOWN TUBING @ 4 BPM 120 PSI, PUMP 50 BBLS. 01:00 - 02:00 1.00 KILLW P DECOMP SITP = 1200 PSI, VA = 1200 PSI, O/A = 0 PSI. - BLEED GAS OFF TUBING, THRU CHOKE TO TIGER TANK. - BLEED GAS OFF VA, THRU CHOKE TO TIGER TANK - CIRCULATE DOWN TUBING @ 4 BPM 120 PSI, PUMP 50 BBLS. 02:00 - 04:00 2.00 KILLW P DECOMP BULLHEAD DOWN TBG 5 BPM / 150 PSI, 50 BBLS. - CIRCULATE @ 5 BPM / 130 PSI, 150 BBLS, GAS RETURNS UP ANNULUS - AFTER PUMPING 150 BBLS, GAS RETURNS NEGLIGIBLE. -SHUT DOWN, VA IS DEAD, TUBING IS DEAD - BULLHEAD 450 BBLS HEATED SEAWATER DOWN VA @ 5 BPM 1320 PSI MAX PRESSURE. Printed 1114/2010 12:23:05PM North America -- ALASKA BP ' Fag �ofiS; Qpera� ion: Summary Report 11 Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 10/12/2010 End Date: X4- OORF9 -E (415,000.00) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 4/27/2002 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 32: 19 5/4/199 12:00 @84.10ft (a bove Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 04:00 2.00 KILLW P DECOMP BULLHEAD DOWN TBG @ 5 BPM / 150 PSI, 50 BBLS. - CIRCULATE @ 5 BPM / 130 PSI, 150 BBLS, GAS RETURNS UP ANNULUS - AFTER PUMPING 150 BBLS, GAS RETURNS NEGLIGIBLE. - SHUT DOWN, VA IS DEAD, TUBING IS DEAD - BULLHEAD 450 BBLS HEATED SEAWATER DOWN VA @ 5 BPM / 320 PSI MAX PRESSURE. 04:00 - 04:30 0.50 KILLW P DECOMP MONITOR WELL, TUBING AND VA ARE ON A i VACUUM. 04:00 - 04:30 0.50 KILLW P DECOMP MONITOR WELL, TUBING AND VA ARE ON A VACUUM. 04:30 - 06:00 1.50 WHSUR P DECOMP PJSM. SHOOT FLUID LEVEL, FLUID @ 3200 - 4000' - SET TWC. ATTEMPT TO PRESSURE TEST FROM BELOW -BULL HEAD @ 5 BPM / 120 PSI, 50 BBLS PUMPED 04:30 06:00 1.50 WHSUR P DECOMP PJSM. SHOOT FLUID LEVEL, FLUID @ 3200 - 4000' - SET TWC. ATTEMPT TO PRESSURE TEST FROM BELOW - BULL HEAD @ 5 BPM / 120 PSI, 50 BBLS 'PUMPED - PRESSURE TEST FROM THE TOP @ 3500 PSI / 10 MIN CHARTED. 06:00 07:00 1.00 WHSUR P DECOMP PRE TOUR CHECKS, SERVICE RIG. 07:00 - 08:00 1.00 WHSUR P DECOMP PRESSURE TEST TWO WAY CHECK, 3500 PSI / 10 MIN / CHARTED. 08:00 09:30 1.50 WHSUR P DECOMP PJSM. BLEED VOID N /D TREE. 09:30 - 12:00 2.50 BOPSUR P DECOMP PJSM N/U 13 5/8" X 5M BOPE. - RIG UP TEST EQUIPMENT. 112:00 - 13:30 1.50 BOPSUR P DECOMP ATTEMPT TO GET TEST ON BOPE. - BLIND/ SHEAR RAMS LEAKING. 13:30 - 17:00 3.50 BOPSUR N RREP DECOMP PJSM. PULL BLIND SHEAR RAMS OUT OF STACK. - REPLACE "T" SEAL, DRILLER'S SIDE. - REPLACE RAMS, RE CONNECT CHOKE LINE. 17:00 - 18:00 1.00 BOPSUR N RREP DECOMP ATTEMPT TO GET TEST ON BLIND SHEAR RAMS, STILL LEAKING. 18:00 - 18:30 0.50 BOPSUR P DECOMP PRE TOUR CHECKS, SERVICE RIG. 18:30 - 00:00 5.50 BOPSUR P DECOMP COND UC LILL TEST ON ROPE, EXCEPT FOR BLIND SHEAR RAMS - TEST ALL EQUIPMENT @ 250 / 3500 PSI / 5 Qb P MIN EA /CHARTED. - TEST VBRS W/ 2 7/8" & 3 V2" TEST JT. - TEST ANNULAR PREVENTER W/ 2 7/8" TEST JT.. 10/14/2010 100:00 - 01:00 1.00 BOPSUR P DECOMP FINISH TESTING BOPE, CONDUCT DRAWDOWN TEST ON ACCUMULATOR. STATE REP JOHN CRISP WAIVED WITNESSING THE TEST. 01:00 - 01:30 0.50 BOPSUR P DECOMP UD TEST TOOLS, DRAIN BOP STACK. 01:30 - 04:30 3.00 BOPSUR N RREP DECOMP PJSM. REMOVE BLIND SHEAR RAMS FROM BOP STACK. - INSTALL REPLACEMENT SET OF BLIND SHEAR RAMS. i - RE INSTALL CHOKE LINE. Printed 11/4/2010 12:23:05PM Norffi, America,- ALASKA BP -' Page of'8 ,... Operation;Summary Report Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 10/12/2010 End Date: X4- OORF9 -E (415,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 4/27/2002 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.1 Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 05:30 1.00 BOPSUR P DECOMP PRESSURE TEST BLIND SHEAR RAMS @ 250 / 3500 PSI, OK. 05:30 - 06:00 0.50 BOPSUR P DECOMP PJSM. N/U DUTCH RISER. 06:00 - 07:00 1.00 BOPSUR P DECOMP PRETOUR CHECKS. - CHECK AND SET PVT ALARMS - ENVIRONMENTAL WALK AROUNDS 07:00 - 08:30 1.50 BOPSUR P DECOMP NU LUBRICATOR. PT LUBRICATOR AND DUTCH RISER TO 250 / 1100 PSI -- GOOD TEST. 08:30 - 09:00 0.50 BOPSUR P DECOMP P ULL TWC AND LD LUBRICATOR 109:00 - 10:00 1.00 PULL P DECOMP P ULL TUBING HANGER. - MU LANDING JOINT TO TUBING HANGER, - FMC WELLHEAD TECH B.O.L.D.S. ON TUBING SPOOL. DRILLER PULLED HANGER FREE AT 79 -80K LBS. - PULLED HANGER TO FLOOR AND LD DOWN. 10:00 10:30 0.50 PULL P DECOMP RU AND CIRCULATED A TUBING VOLUME, —45 BBLS, AT MAX RATE, 6 BPM AND 60 PSI. 10:30 - 11:30 1.00 PULL P DECOMP PJSM: RU TO RIH WITH SINGLES FROM PIPE SHED. PICKED UP 9 JTS OF 2 7/8" TUBING FROM THE PIPE SHED AND RIH TO TAG FILL. DID NOT ENCOUNTER ANY FILL AND RIH TO A FINAL DEPTH OF 8019' MD. 11:30 - 12:30 1.00 PULL P DECOMP RU AND CIRCULATED A TUBING VOLUME, —46 BBLS, AT MAX RATE, 6 BPM AND 60 PSI 12:30 - 13:30 1.00 PULL P DECOMP PJSM. RU AND POH, LAYING DOWN THE 9 _ JOINTS OF 2 7/8" TUBING TO THE SHED. 13:30 - 18:00 4.50 PULL P DECOMP PJSM. RU AND POH. STANDING BACK 2 7/8" TUBING IN DERRICK. RU ESP AND HEAT TRACE LINES TO _ SPOOLS IN SPOOLING UNIT. 18:00 - 18:30 0.50 PULL P DECOMP PRE TOUR CHECKS, SERVICE RIG. 18:30 - 00:00 5.50 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" EUE 8 RND ESP COMPLETION. - MAINTAINING N8TANT HOLE FILL @ 40 BPH. 10/15/2010 00:00 03:30 3.50 PULL P DECOMP PJSM. L/D PUMP ASSEMBLY. - LOCKED UP, FORMATION SAND. MAINTAIN CONSTANT HOLE FILL, 40 BPH. 03:30 05:00 1.50 PULL P DECOMP COUNT BANDS, C/O SPOOLS, PREP TO RUN ESP COMPLETION. 05:00 06:00 1.00 RUNCOM P RUNCMP PJSM. PICK UP AND SERVICE PUMP _ ASSEMBLY. 06:00 - 07:00 1.00 RUNCOM P RUNCMP PRE TOUR CHECKS, SERVICE RIG. 07:00 09:30 2.50 RUNCOM P RUNCMP PJSM. PULL MLE OVER SHEAVE. - PLUG IN MOTOR, TEST ESP. 09:30 - 14:30 5.00 RUNCOM P RUNCMP PJSM. RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION. - TEST CONTINUITY OF ESP CABLE EVERY 2000' - USING BEST -O -LIFE 2000 PIPE DOPE, TORQUING EACH CONNECTION TO 2300 FT /LBS. CONSTANTLY FILLING HOLE @30-40 BPH. Printed 11/4/2010 12:23:05PM North America - ALASKA_ Bp Page d of .operation Summary Repot Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 10/12/2010 End Date: X4- OORF9 -E (415,000.00) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 4/27/2002 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.1 Oft (above Mean S ea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 15:30 1.00 RUNCOM P RUNCMP PJSM. BRING CHANNEL CLAMPS TO RIG FLOOR. PULL HEAT TRACE OVER SHEAVE ATTACH TO BOTTOM O STAND 44. 15:30 18:00 2.50 IRUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" EUE 8RND ESP COMPLETION. . RUNNING CANNON CLAMPS ON ESP CABLE AND HEAT TRACE CABLE. - CHECKING CONTINUITY EVERY 2000' AND AT ALL SPLICES. 18:00 - 19:00 1.00 RUNCOM P RUNCMP SERVICE RIG AND CONDUCT PRE TOUR CHECKS. 19:00 - 00:00 5.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ ESP COMPLETION - SECURING HEAT TRACE AND ESP CABLES W/ CANNON CLAMPS - PICKING UP CLAMPS AS NEEDED - CHECKING CONTINUITY EVERY 2000' - CONSTANT HOLE FILL @ 30 - 40 BPH. 10/16/2010 00:00 - 06:00 6.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION. CHECKING CONTINUITY EVERY 2000' - CONSTANT HOLE FILL @ 30 -40 -BPH. - USING BEST -O -LIFE 2000 PIPE DOPE - TORQUING EACH CONNECTION TO 2300 FT /BS. - FLUSHING MOTOR @ 1 BPM / 60 PSI EVERY 2000' 06:00 - 07:00 1.00 RUNCOM P RUNCMP PRE -TOUR CHECKS. SET AND TEST PVT ALARMS. INSPECT DERRICK. PERFORM ENVIRONMENTAL WALKAROUNDS. 07:00 - 08:30 1.50 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION. - CHECKING CONTINUITY EVERY 2000' - CONSTANT HOLE FILL @ 30 -40 -BPH. - USING BEST -O -LIFE 2000 PIPE DOPE - TORQUING EACH CONNECTION TO 2300 FT /BS. - FLUSHING MOTOR @ 1 BPM / 60 PSI EVERY 2000' 08:30 - 12:30 4.00 RUNCOM P RUNCMP PJSM. P/U LANDING JOINT, KU HANGER. - INSTALL PENETRATORS, ATTACH FIELD CONNECTIONS ON H.T. AND ESP CABLES. - PLUG IN BOTH AND TEST, OK. 12:30 - 13:30 1.00 RUNCOM P RUNCMP PJ LAND HANGER & RILDS 13:30 15:00 1.50 WHSUR P RUNCMP PJSM. SET TWC, ATTEMPT TO TEST FROM THE BOTTOM. - BULLHEAD BELOW TWC @ 2 BPM 140 PSI / 10 MIN, CHARTED - TEST TWC FROM THE TOP @ 3500 PSI / 10 MIN / CHARTED, OK. 15:00 - 18:00 3.00 BOPSUR P RUNCMP R/D ESP SHEAVE, WASH RIG FLOOR. - WASH STACK, FLUSH LINES W/ FRESH WATER. 18:00 - 21:00 3.00 BOPSUR P RUNCMP SERVICE RIG, CLEAN FLOOR. - CLEAN BUSHINGS & PIPE HANDLING EQUIPMENT. - CLEAN ROTARY BRAKE, & SUBS, PALLETIZE IN PIPE SHED. Printed 11/4/2010 12:23:05PM ;North America - ALASKA --BP X, age of O: Operation Summary Report Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 10/12/2010 End Date: X4- OORF9 -E (415,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 4/27/2002 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: 32 : 19 5/4/1998 12:00 @84.1 Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 BOPSUR P RUNCMP FLUSH STACK & CHOKE MANIFOLD W/ FRESHWATER. - FLUSH FLOW LINE, DRAIN & BLOW DOWN STACK. -FLUSH KELLY & BLOW DOWN CHOKE MANIFOLD. 10/17/2010 00:00 - 01:30 1.50 BOPSUR P RUNCMP PJSM. N/D DUTCH RISER AND SPACER SPOOLS. PULL RISER, INSTALL SAVER SLEEVE, WD DUTCH FLANGE. 01:30 - 04:00 2.50 BOPSUR P RUNCMP PJSM. CHANGE RAMS, N/D CHOKE AND KILL LINES. - REMOVE BLIND / SHEAR & VARIABLE RAMS. - PREP SHAFTS & WEAR PLATES FOR STORAGE. CLOSE OPERATER DOORS. 04:00 - 06:00 2.00 BOPSUR P RUNCMP PJSM. N/D BOPE, DRAIN ROTARY CHAIN. SERVICE MUD CROSS & CHOKE MANIFOLD. SET BACK AND SECURE BOPE. 06:00 07:00 1.00 BOPSUR P RUNCMP PRE -TOUR CHECKS - INSPECT EQUIPMENT - PERFORM ENVIRONMENTAL WALK AROUNDS. 07:00 - 09:00 2.00 BOPSUR P RUNCMP NU ADAPTER FLANGE AND 2 9/1 . - TESTED HANGER VOID TO 5000 PSI FOR 30 MINUTES - GOOD TEST. - CENTRILIFT PERFORMED FINAL TESTS - GOOD TEST. - FILLED TREE WITH DIESEL AND TESTED ADAPTER FLANGE AND TREE TO 5000 PSI - GOOD TEST. 09:00 10:30 1.50 BOPSUR P RUNCMP PJSM. RU LUBRICATOR. - TEST TO 250 / 1100 PSI FOR 5 CHARTED MINUTES -- GOOD TEST. PULL TWC AND LD. INSTALL BPV. RD LUBRICATOR AND LD. - ATTEMPT TO TEST BPV FROM BELOW TO 500 PSI. 10:30 - 15:00 4.50 WHSUR P RUNCMP PJSM. RIG UP LITTLE RED, TEST LINES - FREEZE PROTECT WELL - PUMP 12 BBLS DIESEL DOWN TUBING & 65 BBLS DIESEL DOWN VA PUMPING @ 3 BPM / 60 PSI WELL SECURED. WOW TO LAY OVER DERRICK 15:00 18:00 3.00 DEMOB P POST REMOVE ALL LIFTING EQUIPMENT FROM FLOOR F/ CLEANING REMOVE ALL POWER TONG EQUIPMENT, SEND TO CASING SHOP REMOVE ALL ELECTIRCAL GAUGES AND BATTERIES, COAT W/ LP S3. - REMOVE DIES FROM RIG TONGS AND SLIPS, COAT W/ ANTI SIEZE CLEAN PITS, REMOVE SHAKER SCREENS GREASE AGITATORS & CHANGE OIL, COAT ALL VALVES AND SWITCHES W/ LP S3. - PULL SWABS AND LINERS ON MUD PUMP, COVER ELEC MOTORS ON SHAKER AND AGITATORS. Printed 11/4/2010 12:23:05PM North America- ALASKA-:- BP Page 6'!"Sf6 ration Summary Report Common Well Name: MPE -19 AFE No Event Type: WORKOVER (WO) Start Date: 10/12/2010 End Date: X4- OORF9 -E (415,000-00) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 4/27/2002 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: A ctive Datum: 32 19 5/4/1998 12:00 @84.1 Oft (above M Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 00:00 6.00 DEMOB P POST CONTINUE TO WOW. CONTINUE TO PREP RIG FOR COLD STACK. - COAT TUGGER CABLES & DRILL LINE WHERE POSSIBLE W/ PRE LUBE 19. - FILL CHOKE MANIFOLD W/ HYDRAULIC OIL. 10/18/2010 00:00 06:00 6.00 DEMOB P POST - DISCONNECT MUD LINES, GREASE AND COVER W/ PLASTIC. CAP GAS BUSTER LINE, SERVICE & PREP LAY DOWN MACHINE. - PREP SHOCK HOSES, GREASE AND COVER WITH PLASTIC. - CLEAN POSSUM BELLY 06:00 - 00:00 18.00 DEMOB P POST CONTINUE TO WAIT ON WIND. (GUSTING TO 39 MPH) - CONTINUE TO PREP RIG FOR COLD STACK. - PULL SEATS ON MUD PUMP, GREASE BODIES, GREASE LINER CAPS. - SHRINK WRAP MOTORS AND CHARGE PUMPS - GREASE AND LUBE VARIOUS PIECES OF EQUIPMENT. 10/19/2010 00:00 - 06:00 6.00 DEMOB P POST CONTINUE TO WAIT ON WIND TO LAY OVER DERRICK. CONTINUE TO PREP EQUIPMENT FOR COLD STACK. - BOX UP ALL AEROSOL CANS AND LIQUID LUBRICANTS. - BREAK DOWN RIG TONGS - CONTINUE TO SHRINK WRAP EQUIPMENT. 06:00 - 20:00 14.00 DEMOB P POST WINDS DIED DOWN TO A SUSTAINED 10 -15 MPH. SCOPED AND LOWERED DERRICK. j FINISH RIGGING DOWN FOR RIG MOVE, FINISH CLEANING PITS. 20:00 - 22:00 2.00 DEMOB P POST PREP FOR RIG MOVE TO TEXACO PAD - PEAK TRUCKS ON LOCATION, PRE JOB WITH DRIVERS AND RIG CREW - MOVING GENERATOR, SHOP & TRAILER TO TEXACO PAD 22:00 00:00 2.00 DEMOB P POST PREP SUB, PIPE SHED AND PITS FOR MOVE - MOVE SUB OFF OF MPE -19 , WSL & NABORS TP WITNESSED. 10/20/2010 00:00 - 05:00 5.00 DEMOB P POST MOBOLIZE SUB, PITS, PIPE SHED & CAMP FROM MPE -19 TO MILNE PT TEXACO PAD F COLD STORAGE. 05:00 - 00:00 19.00 DEMOB P POST MAUNUVER EACH MODULE TO PLACED OVER HERCULITE AND BERMED. - SECURED RIG MODULES OVER THE HERCULITE. - DEMOBING THE RIG CAMP FOR COLD STACK - CONT TO COLD STACK OPERATIONS -REMOVING ALL SAA/RAA/UAA MATERIAL Printed 11/4/2010 12:23:05PM STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMI'~ION REPORT OF SUNDRY WELL OPERATIONS til [.~l , ~ ~ 2008 1. Operations Performed: ' "~ y~~ ~ ~; ~~~ ~~~5 „ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate sp''~'~i'~Otf ^ ~t~ ~u f ~ r ~ ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-037 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22746-00-00 ' 7. KB Elevation (ft): 58.55' 9• Well Name and Number: MPE-19 8. Property Designation: 10. Field /Pool(s): ADL 047437 ~ Milne Point Unit ! Kuparuk River Sands 11. Present well condition summary Total depth: measured 8249 feet true vertical 7310 feet Plugs (measured) N/A Effective depth: measured 8164 feet Junk (measured) N/A true vertical 7237 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3930' 9-5/8" 3955' 3590' 5750 3090 Intermediate Production 8222' 7" 8247' 7308' 7240 5410 Liner ~~~~~~ ~u~ ~ ~ ~~~$ Perforation Depth MD (ft): 7837' - 7902' Perforation Depth TVD (ft): 6959' - 7014' 2-7/8", 6.5# L-80 7737' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In~ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: . ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. We I Status after work: ® Well Schematic Diagram Md~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Nick Frazier, 564-5633 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By NamelNumber: ignature Phone 564-4750 Dat ~ b~ Sondra St Form 10-404 Revised 0412006 ~ ~- ~ ~ zoos ewman, 564-4750 (~ Submit Original Only ~. ,~; oa J ~~i.~~~ Tree: 2 9/16" - 5M FM~ Wellhead: 11" x 7" 5M FMC, Gen 5A w/ 2 7/8" WKM Tbg. Hgr. w/ 3" Acme Threads ,and 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 115' KOP @ 350' Max. hole angle = 32 to 33 deg. f/ 2500' to 3650' Hole angle thru' perfs = 31 deg Orig Elev. = 58.55' (N 27E) Orig. Elev. = 24.5' DF To Tbg. 7" Hgr. = 33.75' (N 27E) Camco 2 7/8" x 1" sidepocket KBMM GLM 9 5/8" Howco'ES' Cementer 172' 1296' I 9 5/8", 40 ppf, L-80 BTC 3,955' ~ 2 7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. = 0.00579 bpf ) 7" 26 ppf, L-80, BTC prod. casing ( drift ID = 6.151", cap. = 0.0383 bpf ) NOTE: PUMP IS EQUIPPED WITH 2-7/8" SY 2-3/8" DISCHARGE HE/ ID= 1.769" Stimulation Summary none performed , Centrilift Heat Trace Camco 2 7/8" x 1" sidepocket KBMM GLM XN Nipple - 2.313" landing profile, 2.205" No-Go. Centrilift ESP, 112 P6 Model PMSXD 1:7 141 P6 Model PMSXD 1:7 Centrilift Gas Separator GRSSFTXAR Tandem Centrilift seal section GSB3DBFERHLSSCVH6PFSA GSB3DBFERHLSSCVH6PFSA Centrilift KMH, 76 hp motor, 1360 v. / 34 amps. Phoenix XTO PumpMate PumpMate TVD - 6870' 3348` 7490' I 7632` I 7677' 7706' 7711` 7725' 7733` Perforation Summary Ref loa: GR /CCL 4 / 14 / 97 Size SPF Iterval (TVD) 4.5" 5 _ and, 7,837'-7,860' 6,958'-6,978' . B-Sands 4.5" 5 7,872'-7,902' 6,989'-7,014' Centralizer 7735` I 7" short joint from 7710" to 7752' and Slickline tag 4/28/02 8089' wlm DATE REV. BY COMMENTS 03/22/97 JBF Drilled & Cased by Nabors 27 E 05/06/97 MDD ESP C°r^Pletion 4FS /ESP RVND 05/06198 I ESP RWO 4/29/02 12/03/04 MDO ESP RWO Completion 4ES 6/20/08 LH ESP RWO Recompletion 3S 7" float collar (PBTD) 8,164' 7" float shoe 8,247' MILNE POINT UNIT WELL E-19 API NO: 50-029-22746 BP EXPLORATION • BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPE-19 Common Well Name: MPE-19 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date !, From - To .Hours Task Code NPT Spud Date: 4/27/2002 Start: 6/18/2008 End: Rig Release: 6/24/2008 Rig Number: Phase Description of Operations 6/18/2008 15:00 - 21:30 6.50 RIGD P PRE R/D pipe shed, scope down and lower Derrick, R/D and move pitts, move carrier off well with WSL, Toolpusher and Pad operator present at 20:30 hrs. 21:30 - 00:00 2.50 MOB P PRE PJSM with Truck drivers and crew. Move off MPJ-Pad to MPE-Pad, on E-Pad at 23:00 hrs. 6/19/2008 00:00 - 03:30 3.50 RIGU P PRE Place Well Head equipment and the BOP cradle behind cellar box. Lay rig mats and herculite, back Carrier over Well with WSL, Toolpusher and Pad operator present at 01:30 hrs. Spot pipe shed, pits and camp units. 03:30 - 06:00 2.50 RIGU P PRE PJSM, Raise and scope up Derrick. 06:00 - 09:00 3.00 RIGU P PRE Acce t ri at 06:00 hrs. Make up kill lines to Tree. Take on hot Sea Water in Pits. 09:00 - 09:45 0.75 WHSUR P DECOMP Pick up Lubricator. Test at 500 psi. Good test. Pull BPV. Lay down same. TP = 560, CP = 940 psi, OA = 120 psi. 09:45 - 10:00 0.25 KILL P DECOMP PJSM. Discuss Well Kill operations. 10:00 - 12:30 2.50 KILL P DECOMP Beed pressure (Gas) from IA down to 160 psi through Choke to Tiger Tank. Bring Pump on line down Tubing with hot Sea Water at 2.0 bpm 490 psi. Maintain 160 psi on IA through Choke. Increase pump rate to 4.0 bpm. After pumping two complete tubing volumes, no returns, Tubing on vacuum. Shut down Pump. Close in Tubing. Bullhead down Annulus at 4.0 bpm/300 psi. Finally caught fluid with 190 bbls pumped. Continue bullheading down Annulus at 4.0 bpm/450 psi. Shut down pump with 260 bbls away. Pressure fell to 0 psi. Total bbls pumped = 345. Monitor well on vacuum. 12:30 - 13:00 0.50 WHSUR P DECOMP Install TWCV. Pressure test to 3,500 psi x 10 minutes. Good 13:00 - 18:00 5.00 WHSUR P DECOMP Monitor Well very slight blow. Gravity feed 30 bbls down Annulus. Nipple down Production Tree. 18:00 - 23:00 5.00 WHSUR P DECOMP PU the BOPE off the Cradle and NU the 13-5/8" 5K BOP, hook up koomey, choke and kill lines. 23:00 - 00:00 1.00 WHSUR P DECOMP Test ROPE Choke Manifold, and Floor Valves to 250 psi low pressure and 3,500 psi high. VBR's and Hydril were tested with 2-7/8" test joints. Each test was held for 5 minutes on the chart. Perform draw down test on Koomey system. AOGCC witness of BOPE Test was waived by John Crisp (at 19:00 hrs). Test was witnessed by BP WSL and Nabors Tourpusher. Continue feeding the well down the IA with 20 bph of seawater. 6/20/2008 00:00 - 02:30 2.50 WHSUR P DECOMP Continue BOPE test. H2S and Meth gas detector tested. 02:30 - 05:00 2.50 WHSUR P DECOMP PU / MU Opso Lopso and lubricator, Tested lubricator 500 psi for 5 minutes Well su ort techs II oqi on tubing, IA on a Vac. Pumped 56 bbls down tubing with no return, stop pumping and tubing and IA on a Vac. RD lubricator. 05:00 - 06:00 1.00 WHSUR P DECOMP PU / MU landing joint, FMC rep BOLDS, tubing and IA on Vac, pull hanger to floor with 64K. 06:00 - 16:00 10.00 PULL P DECOMP Pull 2 7/8" ESP Com letion standin to in Spool ESP cable. Pulled 242 Joints, 2 GLMs, XN-Nipple. Inspect XN-Nipple (OK for re-run) 16:00 - 19:30 3.50 PULL P DECOMP Lay down ESP Assembly. Problems found: broken shaft and 19:30 - 20:00 0.50 PULL P DECOMP Rig service. 20:00 - 00:00 4.00 CLEAN P DECOMP MU 6" bit and 7" csg. scraper. RIH to 20 stands of 2-7/8" tbg. from Derrick. Pump -25 BPH into Well during trip with no Printed: 7/7/2008 11:50:1 S AM ~ ~ r BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPE-19 Common Well Name: MPE-19 Spud Date: 4/27/2002 Event Name: WORKOVER Start: 6/18/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/24/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ' Task Code NPT i Phase Description of Operations 6/20/2008 20:00 - 00:00 4.00 CLEAN P DECOMP returns. 6/21/2008 00:00 - 03:00 3.00 CLEAN P DECOMP ontinue RIH from Derrick with Bit & csg. scraper to 99 stands, 90' PUW = 50K, SOW = 39K. Pump -25 BPH into Well durning trip with no returns. 03:00 - 07:00 4.00 CLEAN P DECOMP POH from -6,090 standing 2-7/8" tubing in Derrick 07:00 - 07:30 0.50 DHB P DECOMP PJSM. Pick up Halco Setting Tool and 7" RBP. 07:30 - 13:30 6.00 DHB P DECOMP Run in hole with RBP on 2 7/8" Tubin ,PUW = 50K, SOW = 37K. 13:30 - 14:00 0.50 DHB P DECOMP Set RBP at 6 041-ft. Pull 3 stands. 14:00 - 15:00 1.00 DHB P DECOMP Fill hole with 60 bbls of Sea Water. (Static FL was -2,000'). 15:00 - 18:00 3.00 DHB P DECOMP Circulate Well at 4.0 bpmJ 340 psi to recover diesel and oil left in well duriing bullhead operations. 225 bbls pumped. 18:00 - 20:30 2.50 DHB P DECOMP UD 1 bad joint 2-7/8" tubing, PU and set Storm Packer at 38 ft. per Halliburton rep, tested 1,000 psi for 10 charted minutes. 20:30 - 00:00 I 3.501 WHSUR I P 6/22/2008 100:00 - 05:00 I 5.001 WHSUR I P 05:00 - 06:00 I 1.001 WHSUR I P 06:00 - 06:30 0.50 WHSUR P 06:30 - 09:30 3.00 DHB P 09:30 - 13:30 4.00 DHB P 13:30 - 14:00 0.50 DHB P 14:00 - 15:00. 1.00 BUNCO 15:00 - 15:15 0.25 RU 15:15 - 19:30 4.25 RU 19:30 - 00:00 4.50 RU 6/23/2008 100:00 - 06:00 I 6.001 RU DECOMP N/D BOPE, LOTO accumulator, pull flow riser, choke and kill lines, DSA and remove FMC 11" X 7-1/16" 5M tubing spool with FMC tech. DECOMP Install new FMC 11" X 11" 5M tubin spool, add second annulus 13-5/8' X 11" 5M DSA flan e, hook up accumulator lines, choke and kill lines. FMC tech tested tubing spool connection to 5,000 psi for 15 minutes, witnessed by BP/ WSL. DECOMP Function test BOPE an accumulator. Pressure test BOPE to 250 / 3,500 psi for 5 charted minutes per BP/AOGCC. Tested BOPE body, choke line and kill line, with test plug in tubing spool. Witnessed by BP/WSL and Nabors Toolpusher. DECOMP Held Abandon Rig Drill. DECOMP Release and ull 7" Halco RTTS storm acker. Lay down same. Run in with 2 7/8" Tubing. Latch 7" Halco RBP. Open equalizer valve. Well on vacuum. Allow well to equalize. DECOMP POOH with 2 7/8" Tubing, standing back in Derrick. DECOMP Lay down Halco 7" RBP comoJete. Lay down Running Tool. RUNCMP Clear and clean floor. Stage ESP equipment and GLMs in Pipe Shed. Rig up floor to handle ESP Completion. RUNCMP PJSM. Discuss picking up ESP Assembly. RUNCMP Pick up and service ESP Assembly. RUNCMP RIH with E P " 6. # E E 8 rd tubin from D Install LaSalle Cable protectors on first nine joints then every second joint. Centrilift teck checked conductivity of cable every 2000' & filled tubing and flush pump with 10 bbls of seawater. MU torque of 2,300 ft-Ibs. Using Best-O-Life 2000 pipe dope. RIH to joint #68 Continue to feed Well with - 25 bph seawater with no returns. RUNCMP PU flat guards and clamps to rig floor. Continue to RIH with ESP completion on 2-7/8" tubing from the Derrick. Use Best-O-Life pipe dope on connections. Began installing Heat trace with flat guards clamps on jt # 135. Check conductivity every 2000' and flush pump with 10 bbls of seawater, 1/2 BPM ~ 820 psi. Start Heat Trace on joint # 135 in hole. Continue to feed well with no returns, with -25 BPH seawater. 175 joints in Printed: 7!712008 11:50:1 S AM r BP EXPLORATION Page3of3 Operations Summary Report Legal Well Name: MPE-19 Common Well Name: MPE-19 Spud Date: 4/27/2002 Event Name: WORKOVER Start: 6/18/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/24/2008 Rig Name: NABOBS 3S Rig Number: Date From - To ~ Hours Task ', Code' NPT i Phase Description of Operations 6/23/2008 00:00 - 06:00 6.00 BUNCO RUNCMP the hole at 05:30 hrs. 06:00 - 18:30 12.50 BUNCO RUNCMP Continue to run 2 7/8" ESP/HT Completion. 18:30 - 19:30 1.00 BUNCO RUNCMP MU TIW and Headpin. Fill the Tubing and flush the ESP Pump with 10 bbls of seawater at a rate of 0.5 bpm at 850 psi 19:30 - 20:30 1.00 BUNCO RUNCMP PU Landing Joint and MU Tubing Hanger (2-7/8 EUE 8rd threads) with FMC rep. Install ESP and Heat Trace Penetrators in the Hanger. PUW = 80K and SOW = 55K. 20:30 - 23:30 3.00 BUNCO RUNCMP Perform Penetrator splices on the ESP and Heat Trace cables with Centrilift reps. 23:30 - 00:00 0.50 BUNCO RUNCMP Land Tubina Hanger as per FMC wellhead tech. Ran 242 joints„ 2-7/8" 6.5 Ib/ft EUE 8rd, with XN, two GLM's, and ESP pump assembly set at 7,737' MD. Ran 39 - 3 foot Flat Guards, 511- 6 foot Flat Guards, 4 Protectolizers, 2 Armstraguards, 1,724 bands. 6/24/2008 00:00 - 03:00 3.00 BUNCO RUNCMP Continue land tubing hanger, RILDS and torque to 450 fVlbs. FMC tech set TWC with Dry rod, tested to 3,500 psi from abovg for 10 charted minutes. 03:00 - 06:00 3.00 BOPSU P RUNCMP Blown down lines, drain BOP, glean pits. ND BOPE and UD in shipping cradle. 06:00 - 07:45 1.75 WHSUR P RUNCMP NU tubing head adapte and production Tree. 07:45 - 08:30 0.75 WHSUR P RUNCMP Test Hanger void at 5,000 psi x 10 minutes. Good test. Fill Production Tree with diesel and test at 5,000 psi x 10 minute. Good test. 08:30 - 09:30 1.00 WHSUR P RUNCMP Plck-up Lubricator. Test to 500 psi. Pull TWCV. Lay down same. 09:30 - 12:00 2.50 WHSUR P RUNCMP Remove second annulus valve and normal-up Tree and secure cellar.Centrifilt rep took final ESP and Heat Trace checks, HT Phase to phase = 3.9 ohms, ESP cable phase to phase = 3.4 ohms, Motor temp = 62.4 deg, intake temp = 67.4 deg, HT megs = 92.4 G ohm, ESP cable Megs = 2.06 G ohm. The Rig was released at 12:00 hours 6/24/2008 for move to MPE-14. Printed: 7/7/2008 11:50:18 AM '~ STATE OF ALASKA ° 11114!07 OIL AND GAS CONSERVATION COMMISSfON ROPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 6/22/2008 Rig Rep.: J. Henson / R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: L.HinkeUD.Rhodes Field/Unit & Well No.: MP E-19 PTD # 1970370 Operation: Drlg: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular 250/3500 Valves: 250/3500 TES7 DATA MISC. INSPECTIONS: Test Result Location Gen.: P Wei Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Test Result P P P Test Result Annular Preventer ISF Pipe Rams NT Lower Pipe Rams NT Blind Rams 1 Blind P Choke Ln. Valves NT HCR Valves rTf Kill Line Valves NT Check Valve NT MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 NT Inside BOP 1 NT CHOKE MANIFOLD: Quantity Test Result No. Valves 3 P Manual Chokes 1 NT Hydraulic Chokes 1 NT ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure P Press~e After C~sure P 200 psi Attained P FuN Pressure Attained P Bfmd Switch Covers: All stations P Nitgn. Bottles (avg): Number of Failures: 0 Test Time: .5 Hours Components tested 5 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: Remarks: Tested choke and kill line breaks and bottom break on stack after tubing head change out against a test plug. Two mechanical barriers set and tested in the weH before tut>~g head change out. 24 HOUR NOTICE GIVEN YES x NO Waived By Jeff Jones Date 09/20/08 Time 18:30 Witness R.B'orhus / D.Rhodes Test start 5:30 Firmsh 6:00 BOP Test (for rigs) BFL 11/14/07 ~~~~~ ~~~~ ~ ~ 2~0$ Nabors 3s BOP Test MP E-19 6-22-08 Revised.xls STATE OF ALASKA 11/14!07 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 6/19/2008 Rig Rep.: J, Henson / R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: L.HinkeUD.Rhodes Field/Unit & Well No.: MP E-19 PTD # 1970370 Operation: Drlg: Test: Initial: x Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P Wei Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Workover: x Weekly: Anrx~ar: 25013500 TEST DATA Test Result P P P Quantity Size Test Result Annular Preventer 1 13 5/8 50~ P Pipe Rams i 2 7/8 X 5 P Lower Pipe Rams 0 NA Blind Rams 1 Blind P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUO SYSTEM: Usual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results Exptor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Bad Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1800 P 200 psi Attained 32sec P FuN Pressure Attained 169 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 1915 Number of Failures: 0 Test Time: 3.5 Hours Components tested ALL Repair or replacement of equipment w~ be made wifl~ days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Tested with 2 7!8" test joint. 24 HOUR NOTICE GIVEN YES x NO Waived By John Cri Date O6/17108 Time 9:00 Witness R.B'orhus / D.Rhodes Test start 23:00 Fintsh 2:30 BOP Test (for rigs) ~~~N~® JUN 2 0 2D08 BFL 11/14/07 Nabors 3s BOP Test MP E-19 6-19-08.x1s , STATE OF ALASKA, ALASKA 1 AND GAS CONSERVATION CO...MISSION ~ECEIVED REPORT OF SUNDRY WELL OPERATIONs' DEC 2 12004 1. Operations Performed: D Abandon D Alter Casing D Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 58.55' 8. Property Designation: ADL 047437 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 1m Repair Well D Plug Perforations 1m Pull Tubing D Perforate New Pool D Operation Shutdown D Perforate A'asK~<t'jH~t¡S~ons. ComnissiOI D Stimulate iii" Ot~ifchorage D Waiver D Time Extension D Re-Enter Suspended Well 8249 7310 8164 7237 115' 3930' 8222' 4. Current Well Class: 1m Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number: 197-037 6. API Number: 50-029-22746-00-00 9. Well Name and Number: MPE.19 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) N/A feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 115' 115' 1490 470 9-5/8" 3955' 3590' 5750 3090 7" 8247' 7308' 7240 5410 SCANNED DEC '2. 7 2004 7837' - 7902' 6959' - 7014' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# L-80 7723' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None Treatment description including volumes used and final pressure: RBDMS BFL DEe 2 2 2004 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run 1m Daily Report of Well Operations 1m Well Schematic Diagram 15. Well Class after proposed work: D Exploratory 1m Development D Service 16. Well Status after proposed work: 1m Oil D Gas D WAG D GINJ D WINJ D WDSPL -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: Contact David Reem, 564-5743 Title Technical Assistant Printed Name Sondra Stewman - . ~~:Ð . Form 10-404 Revised 04/2004 Phone .., , . i.1 Prepared By Name/Number: ~ate ¿ - Z,{--C'~J>ondra Stewman, 564-4750 ! Submit Original Only Tree: 2 9/16" - 5M FM) Wellhead: 11" x 7" 5M FMC, Gen 5a wi 2 7/8" WKM Tbg. Hgr. wi 3" Acme Threads, and 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 115' KOP @ 350' Max. hole angle = 32 to 33 deg. fl 2500' to 3650' Hole angle thru' perfs = 31 deg 95/8",40 ppf, L-80 Btrc.1 3,955' Iii 7" 26 ppf, L-80, Btrc. prod. casing (drift 10 = 6.151", cap. = 0.0383 bpf) 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00579 bpf ) Stimulation Summary none performed Perforation Summary Ref log: GR /CCL 4/14/ 97 Size SPF Iterval (TVD) C-Sands 4.5" 5 7,837'-7,860' 6,958'-6,978' B-Sands - - 4.5" 5 7,872'-7,902' 6,989'-7,014' =- I~ MPU E-19 . 7 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ = or1F Elev. = 58.55' (N 27E) Orig. GL Elev. = 24.5' OF To Tbg. T' Hgr. = 33.75' (N 27E) ... Cameo 27/8" x 1" side pocket KBMM GLM I 170' I 0 9 5/8" Howeo 'ES' Cementer 1,296' I ~ Camco 2 7/8" x 1" 7,488' I sidepocket KBMM GLM XN Nipple - 2.313" landing 7,610' I profile, 2.205" No-Go. Centrilift FC 650 ESP, 7,676' I 204 stg. FPMTAR 1:1 Tandem Gas separator 7,692' I Centrilift GRSFTXAR Tandem Centrilift seal section 7,697' I GSB3DBAB/HSNPFSA GSB3DBL T AB/HSNFSA Centrilift KMH, 57 hp motor, 7,711' I 1315 v. 126 amps. Centrilift Pumpmate 7,717' I Centralizer 7,723' I 7" short joint from 7710" to 7752' md = Slickline tag 4/28/02 8089' wlm ..tX>~x.~ 7" float collar (PBTO) 7" float shoe 8,164' 8,247' DATE REV. BY COMMENTS 03/22/97 JBF Drilled & Cased by Nabors 27 E 05/06/97 MOO ESP Completion 4ES / ESP RWO 05106198 / ESP RWO 4/29/02 12/03/04 MDO ESP RWO Completion 4-es MILNE POINT UNIT WELL E-19 API NO: 50-029-22746 BP EXPLORATION (AK) ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-19 MPE-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/1/2004 Rig Release: 12/3/2004 Rig Number: 4ES Spud Date: 4/27/2002 End: 12/3/2004 Pate . From..To Hours.. . Task Code NPT Phåsê. Descriptio!J .ofQpe~~fiq!J§ 12/1/2004 06:00 - 07:30 1.50 RIGD P PRE Scope down and lower Derrick. Pick-up Rig Mats and Herculite. 07:30 - 10:30 3.00 MOB P PRE Move Rig and Equipment from MPK-Pad to MPE-19 Well Slot. 10:30 -11:30 1.00 RIGU P PRE Spot Sub Base over Well. Spot rig Pits. 11 :30 - 12:30 1.00 RIGU P PRE Raise and Scope Derrick. 12:30 - 13:30 1.00 RIGU P PRE Spot Pipe Shed and Camp. 13:30 - 14:00 0.50 RIGU P PRE Spot Tiger Tank. Lay Lines. Install HCR Valve on Annulus. Accept Rig at 14:00 hrs. Wait on Sea Water. 14:00 - 15:00 1.00 WHSUR P DECOMP Pick-up Lubricator and Pull BPV. Lay down same. Tbg = 1,000 psi. Annu = 1,000 psi. 15:00 - 17:30 2.50 KILL DECOMP Steam & check tiger tank lines. Wait on seawater...Take on seawater. 17:30 - 18:00 0.50 KILL P DECOMP Presure test lines to 3500 psi, OK. 18:00 - 18:30 0.50 KILL P DECOMP Hold PJSM & Pre-Spud meeting wI all hands. 18:30 - 20:30 2.00 KILL P DECOMP Open well bleed off 400 psi of pressure & kill well. SITP 1080 psi, SICP 1140 psi. Pump 120 Degree heated seawater down tubing @ 4 BPM, 525 psi. Pumped tbg volume. Increased pump rate to 5 BPM. Tubing pressure increased from 170 to 775 psi. Pumped 390 Bbls until had water returns. SID & circ into pits checked losses. Lost 13.7 Bbls of fluid in 10 min. SID & monitor well. Well on vacum. Pumped total of512 bbls. Recovered 150 bbls of 95+% oil to tiger tank. 20:30 - 21 :00 0.50 WHSUR P DECOMP Set TWC & test same. Blow down lines. RID kill lines. 21 :00 - 22:30 1.50 WHSUR P DECOMP N/D adapter flange & tree. 22:30 - 00:00 1.50 BOPSUR P DECOMP N/U BOPE. 12/2/2004 00:00 - 03:00 3.00 BOPSUR P DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi. HP 3500 psi. BOP test witnessing waived by Jeff Jones wI AOGCC. 03:00 - 03:30 0.50 BOPSUR P DECOMP Blow down lines. RID test equip. 03:30 - 04:00 0.50 WHSUR P DECOMP P/U lubricator. Pull TWC & UD lubricator. 04:00 - 04:30 0.50 PULL P DECOMP M/U landing jt. BOLDS. Pull hanger to floor. P/U wt = 70 K. 04:30 - 05:00 0.50 PULL P DECOMP UD landing jt & hange. RlU to pull completion. Pull ESP line over sheave. 05:00 - 09:00 4.00 PULL P DECOMP POOH wi ESP completion on 2 7/8" tbg. 09:00 - 10:00 1.00 PULL P DECOMP Stop to change Cable Reels. 10:00 - 11 :30 1.50 PULL P DECOMP Continue to POOH. 11:30 -13:30 2.00 PULL P DECOMP Inspect, break out & UD ESP. 13:30 - 15:00 1.50 RUNCO~ RUNCMP Unload new ESP & load out old ESP. Change out reels. Remove elephant trunk. Unpack re-conditioned LaSalle clamps. 15:00 - 17:30 2.50 RUNCO~ RUNCMP M/U & service new ESP. Pull cable over sheave & connect to ESP. Check & test same. 17:30 - 19:00 1.50 RUNCO~ RUNCMP P/U 4 singles & 19 stands of 27/8" tubing & RIH wI ESP 19:00 - 20:00 1.00 RUNCO~ RUNCMP Make reel to reel splice in ESP cable. 20:00 - 21 :00 1.00 RUNCO~ RUNCMP Cut & slip 84' of drilling line. Finish making reel to reel splice. 21 :00 - 00:00 3.00 RUNCO~ RUNCMP RIH wI ESP completion. Test cable & pump thru pump every 2000'. 12/3/2004 00:00 - 02:30 2.50 RUNCO~ RUNCMP Con't to RIH wI ESP on 2 7/8" tubing. Check pump & cable every 2000'. Used 127 LaSalle Clamps, 3 Flat Guards, 5 Protectolizers. 02:30 - 05:00 2.50 RUNCO~ RUNCMP M/U hanger & landing jt. Install penetrator. Made field splice. Plug into penetrator & test same. 05:00 - 06:00 1.00 RUNCO~ RUNCMP Land completion. P/U 64K, SIO 50K. RILDS. UD landing jt. Printed: 12/6/2004 10:55:00 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/3/2004 06:00 - 07:30 07:30 - 09:00 09:00 - 09:30 09:30 - 10:00 ) BP"'J::XPEQRATIOf\J ()¡pef~tio;Ij~;.¡;"SÛm'J1~t¥:;;;;'.~~'p()tt MPE-19 MPE-19 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours Taák"Code . NPT 1.50 BOPSUR P 1.50 WHSUR P 0.50 WHSUR P 0.50 WHSUR P Start: 12/1/2004 Rig Release: 12/3/2004 Rig Number: 4ES Spud Date: 4/27/2002 End: 12/3/2004 RUNCMP Install TWC and test. ND BOPE. RUNCMP NU Production Tree and test at 5,000 psi. Good. RUNCMP Perform final ESP Cable check. Pick-up Lubricator and pull TWC. Install BPV. RUNCMP Secure Cellar. Release Rig at 10:00 hrs. Prep to rig down. Printed: 12/6/2004 10:55:00 AM '~ ' Milne Point 2001 Shut In Wells Date Reason for Future Utility Plans & Sw Name Shut-In WeE Shut-tn ~ Current Mechanical Condition of Well2 Possibilities a Comments MPB-O'7' " Jul"-97 ' A No k~°wn p'r'o'~'l~s ........... i ....... High GOR' W~il, Facilities can ~ot handle gas. Possible production after gas .... exp, ension roject, MPB-08 ..... May-9,4,, 'E ' ' No known problem's' , .... i ' '~ . ' Futher use as an injector not'required MPB-13' Jan-86 B ' GL Well that was shut'in due tO high 3 Wellhouse and flowlines removed water cut. Possible channel into water zone. MPB. 17 ' ja~96 " E NO mechanical problems. Qui~k ........ 3, . Wellhous~.a,d flo'wli~es removed ' ., communication with producer ...... MPB-19 Jul-91' ~ " ~GL well, High water cut producer. 3 W~/Ihouse and flowlines remoVed Possible frac into water zone MISC.1'1'' 'Feb.96 ' , E ' , ~No known Problems ' 3 Further use as a"n i~jector not required " while associated pr. oducer' shut-in., , MPc-12~ Jan'O0 " E " Fis"'h' ~n'hole', 'dr#lin~ problems ..... 3 ' Suspended due to drilling problems. 12a MPC-16 ~ug-93 ' A ..... High GoR '~ell, parts a'nd ~ompleti°n 3 WellhOuse and flowlines removed ,, . abandoned , MPC-17 May. O0 ' 'D" Le"a'k in 9 5/8" casing'to 'surface "I ' Evaluating po~sib'le plans fo~'sol~tion to ................ problem. , MPc'20 Apr. O0 ' B High water cut well, no mechanical .... I E~aluating'possible plans 'f~r 'soiut~on to , problems Iproblem, MPC-21 F~-02 D Problems wi'th Jet Pump ~ompletion I Evaluating pOssible plans for solution to ........ pro. blem., ....... MPD'01 Dec-9'O ' C Dead EsP Completion, no support to I Evaluating possible plans for Solu'tion to block problem. Possible alternative uses for we#bore Mi~D-02/ Aug-99 B '" Dead ESP"comPletion, very high'water ~ ' I ' Evaluating Possible plans. ' 02a ~ cut well MPE-02 J~n.-O$~ ' " .' C" .. ~io ~nown problems '" .. ' ' '~ ' .. Recompiete t~.upper Kup zon~ .. ~MPE~19: Aug.99 .... C Failed..ESP On tub. lng String 2 ' Well brought on line in 2002 =MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole MPL- I o Feb-99 E No,, proof that is supports other wells ' 1 EValuating side track'po, ssibiliti, e,s '" MPL. I~ "Apr. oo ' 8 ' No menchanical problems, de~d ESP I Evaluating side track possibilities ..... '~fP~'-21 0ct.98 '-~- ' ~High~ressure :bloCk '- 5000 'p'si, no .... 1 ....... Possible Use fo~ inject/on whe'n' PresSure support needed for producers lowers MPL-37a Nov~9 ' 'C .. Dead. ESP. no other mecha'nical .... ~' E~aluati~g 'p°S~ible Side track plan's I issuses recPmpletions MPL~39 jan-99 "E i CoUld not ~nj~ct gas i"nto well, no use I " Evaluating possib/e side ~r'ac'k'p'lans"or" ............. for it. .............. ! r, eco. mpl, etions .................. , , , ... ~ .... ~ , , .... ~:., , ,, , , ~ . , ,,, , ,,. .... , , ,, ,., . .. ~ .... . . ,~, , .:. ,, , . , . ., · .... . ,,. , . ~ .... ~ , ~ , · :. ...- :.:. .:,:. .:. 'i:l::::::giraiua.lfing r. erned~ai!:. ~'~l~'a~k.-. ...... ..... .....-....., ..... ... -.., . . .:-,: ..', · :' "· ~ :%": :3 '.'::: '~i.. :.'..: :.::-.: -.- -'; ,-,::.-:. -, :..a.:, :,. . .:... *Note- Wells were shut in 100% during 2001 SCANNED JUN % 4 2002 Milne Pt Shut In Wells 2001.xls -; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE -- 58.55' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 3711' NSL, 1812' WEL, SEC. 25, T13N, R10E, UM MPE-19 At top of productive interval 9. Permit Number / Approval No. 197-037 687' NSL, 4282' WEL, SEC. 24, T13N, R10E, UM 10. APl Number At effective depth 50-0299-22746-00 812' NSL, 4402' WEL, SEC. 24, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 844' NSL, 4434' WEL, SEC. 24, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 8249 feet Plugs (measured) true vertical 7310 feet Effective depth: measured 8164 feet Junk (measured) true vertical 7237 feet Casing Length Size Cemented M D TVD Structural Conductor 90' 20" 250 sx Arcticset I (Approx.) 115' 115' Surface 3930' 9-5/8" 1195 sx PF 'E', 725 sx Class 'G' 3955' 3590' Intermediate Production 8220' 7" 334 sx Class 'G' 8247' 7308' Liner Perforation depth: measured Open: 7837'- 7860' 7872'- 7902' :.:"' i ~ ~-"' ~-" ~ ~ .~ ~-- :~'.'.~ :,..._, :._ ,... :. :;; ?., ;... true vertical Open: 6959' - 6978', 6988' - 7014' !." "~, "~" '; ; :.' ';-'"i-i fi Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 7726' Packers and SSSV (type and measured depth) None ~; 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Elbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the f,~r.~ioing is true and.correct to the best of my knowledge so dra~Stewm~.___ Title TechnicalAssistant Date Signed ?¥ ~,,.._~ ,~ ......~ Prepared By Name/Number: Sondra Stewman, 564-4750 r ...... ~ ,. Form 10-404 Rev. 06/15/88 Submit In Duplicate : i ii'i i operationS Summary Report Legal Well Name: MPE-19 Common Well Name: MPE-19 Spud Date: 4/27/2002 Event Name: W©RKOVER Start: 4/27/2002 End: 4/29/2002 Contractor Name: NABORS Rig Release: 4/29/2002 Rig Name: NABORS 4ES Rig Number: : ~ Date~ : ]ii~Fr°m ~iT° I H°uis Activity code iNPT~ phase I Description of Operations 4/27/2002 00:00 - 08:00 ! 8.00 RIGU P PRE MI/RU 08:00 - 09:00I 1.00 KILL P DECOMP RIG HCR VALVE & HARD LINE TO TREE 09:00 - 10:30 1.50 KILL P DECOMP SET TIGER TANK & RIG LINES TO SAME & TAKE ON SEA .00 H20 10:30 - 11:30 1 KILL P DECOMP RIG LUB & PULL BPV 11:30 - 15:30 4.00] KILL P DECOMP , REPLACE WELL BORE INFLUX WITH SEA WATER 15:30- 16:00 0.50 WHSUR P DECOMP SET TWC 16:00 - 17:00 1.00 WHSUR P DECOMP NIPPLE DN TREE 17:00 - 19:30 2.50 BOPSUF P DECOMP NIPPLE UP BOP 19:30 - 22:00 2.50 BOPSUF P DECOMP TEST BOP EQUIP TO 250 LOW & 3500 HIGH (TEST WAIVED BY JOHN SPAULDING WITH AOGC) 22:00 - 22:30 0.50 BOPSUF:P DECOMP RIG LUBRICATOR & PULL TWC 22:30 - 23:00 0.50 PULL P DECOMP 'RIG LANDING JT. & PULL HANGER & LAY DN. 23:00 - 00:00 1.00 PULL P DECOMP POOH WITH ESP COMPLETION. 4/28/2002 00:00 - 03:30 3.50 PULL P DECOMP POOH WITH ESP COMPLETION 03:30 - 07:00 3.50 PULL P DECOMP LAY DN ESP & DESANDER & EQUIPMENT. 07:00 - 10:00 3.00 CLEAN C COMP RIG HES & R H W TH 5.95" GR/JB & RECOVER RUBBER FROM DE-SANDER & JUNK TD WLM 8089' 10:00 - 14:30 4.50 RUNCOI~ COMP MU ESP ASSY, & SERVICE SAME. (NOTE:HAD TO ! CHANGE PUMP OUT DUE TO DROPPING) 14:30 - 21:00 6.50 RUNCO ,N~ COMP RIH WITH ESP COMPLETION TO PUMP SETTING DEPTH RUNCO' @ 7725' 21:00 - 23:00 2.00 ,l~e-' COMP MAKE ESP CABLE CONNECTOR TO HANGER & LAND ~ .00IP SAME & RILDS. 23:00 - 00:00 I 1 BOPSU COMP SET TWC & TEST & NIPPLE DOWN BOP. 4/29/2002 00:00 - 00:30I 0.50 BOPSUF~P COMP NIPPLE DN BOP 00:30 - 02:30 2.00 WHSURIP COMP NIPPLE UP TREE & TEST TO 5000 PSI. 02:30 - 04:00 1.50 WHSUR!P COMP RIG LUB & PULL TVVC & SET BPV & SECURE TREE AREA. (RIG RELEASED @ 0400 HRS. 4/29/2002 I Printed: 4~30~2002 3:14:50 PM oN OR C:LOKtXlviF~M-DOC PERMIT DATA 97-037 PERF 97-037 GR/CCL 97-037 7687 97-037 DGR/CNP/SLD-MD 97-037 DGR/EWR4/ROP-MD 97-037 DGR/EWR4-TVD 97-037 DGR/CNP/SLD-TVD AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~7660-7950 ~887-8149 d~ScH~,u~ PDC/GR/CC~, ~/3970-8280 ~70-8280 ~603-7336 603-7336 Page: 1 Date: 05/24/99 RUN RECVD FINAL 04/25/97 FINAL 05/16/97 i 05116197 FINAL 07/02/97 FINAL 07/02/97 FINAL 07/02/97 FINAL 07/02/97 97-037 8020 ~I~-SPERRY GR/ROP 10-407 ~OMPLETION DATE @ ~ w~ o~ ~ ~3/!//~/ TO A~e dr~ ditch samples ~e~ui~ed? yes no ~d ~eceived? 2-3 07/02/97 yes no Was the well cored? yes no Analysis & description received? yes no Are well tests required? i~es no Received? Well is in compliance ~ ~ Initial COMMENTS C yes no T D BOX -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 3711' NSL, 1812' WEL, SEC. 25, T13N, R10E At top of productive interval 687' NSL, 4283' WEL, SEC. 24, T13N, R10E At effective depth 812' NSL, 4403' WEL, SEC. 24, T13N, R10E At total depth 844' NSL, 4434' WEL, SEC. 24, T13N, R10E 6. Datum Elevation (DF or KB) RTE = 58.5' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-19 9. Permit Number / Approval No. 97-37 10. APl Number 50- 029-22746 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 90' Surface Intermediate 3930' Production Liner 8222' 8249 feet 7309 feet 8164 feet 7237 feet Size 20" 9 5/8" 7" Plugs (measured) Junk (measured) Cemented M D TVD 250 sx Arcticset 1 (Approx) 115' 115' 1195 sx PF 'E', 725 sx Class 'G' 3955' 3532' 334 sx Class 'G' 8247' 7249' Perforation depth: measured true vertical 7837' - 7860', 7872' - 7902' (Subsea) 6900' - 6920', 6930' - 6956' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 EUE to 7666' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL Alaska 0il & Gas Cons. O0m~issiort Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run ~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ J-/~--~¢-~ Title Staff Technical Assistant Prepared By Name/Number: Date Jeanne L. ~aa~, 564-5225 Progress Report Facility M Pt E Pad Well MPE-19 Page 1 Rig Nabors 5S Date 11 May 98 Date/Time 05 May 98 06 May 98 07 May 98 06:00-12:00 12:00-18:00 18:00-21:00 21:00-00:00 00:00-01:30 01:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-11:30 11:30-14:00 14:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 18:00-22:30 22:30-00:00 00:00-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-12:30 12:30-13:00 13:00-15:00 15:00-15:30 15:30-17:30 17:30-18:00 18:00-19:00 19:00-20:30 20:30-22:30 22:30-06:00 Duration 6hr 6hr 3hr 3hr 1-1/2 hr 4-1/2 hr lhr lhr lhr 2-1/2 hr 2-1/2 hr 2hr 1/2 hr lhr 1/2 hr 4-1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1-1/2 hr lhr 6-1/2 hr 1/2 hr 2hr 1/2 hr 2hr 1/2 hr lhr 1-1/2 hr 2hr 7-1/2 hr Activity Rig moved 0.00 % Rig moved 100.00 % Rigged up Draw works Rigged up Draw works Retrieved Hanger plug Circulated at 7666.0 ft Circulated at 7648.0 ft Installed Hanger plug Rigged down Xmas tree Rigged up All rams Tested All rams Removed Hanger plug Removed Tubing hanger Pulled Tubing in stands to 0.0 ft Pulled Tubing in stands to 250.0 ft Pulled Tubing in stands to 7648.0 ft Laid down 0.0 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 291.0 ft (2-7/8in OD) Ran Tubing to 338.0 ft (2-7/8in OD) Ran Tubing to 510.0 ft (2-7/8in OD) Ran Tubing in stands to 7663.0 ft Ran Tubing in stands to 7663.0 ft Ran Tubing in stands to 7663.0 ft Installed Tubing hanger Removed BOP stack Installed Xmas tree Tested All tree valves Retrieved Hanger plug Freeze protect well - 7.000 bbl of Diesel Rig moved 25.00 % STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil [~ Gas [] Suspended [~] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-37 APl Number 3. Address 8. 50-029~-22746OO P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ,~-I'Ii;;:IIF~: 9. Unlt or Lease Name 3711' NSL, 1812' WEL, SEC. 25, T13N, R10E F'%.~:'---.~'-::%'~ ~ Milne Point Unit At top of productive interval I ~.'~.,~,J~..': ..... ". i ~I~ ',~.__. "10. Well NUmber 687' NSL, 4283' WEL, SEC. 24, T13N, R10E ~.~/ , ~ At total depth i~ ~_,/~_ ~,~_' ~.~ !~, I~L ~ MPE-19 ~, - ": - - i 1. Field and Pool 844' NSL, 4434' WEL, SEC. 24, T13N, R10E i-/~,f'~_--_.1~ Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Le~'se~ t~esign-ati~Sn and Serial No. Sands RTE = 58.5'I ADL 047437 12. Date Spudded3/13/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 16' N°' °f C°mpleti°ns3/19/97 5/4/97 MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8249 7309' FTI 8164 7237 FT []Yes [] NOI MD 1800' (Approx.) 22. Type Electric or Other Logs Run GR/CDR 23. CASlNG~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO~I-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1Cf H-40 Surface 115' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 24.5' 3955' 12-1/4" 1195sx PF 'E', 725 sx Class 'G' i ,, 7" 26Cf L-80 24.5' 8247' 8-1/2" 334 sx Class 'G' ..... 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) ........ 4.5" at 5 spf 2 7/8" 6.5 L-80 EUE " 7666' MD TVD MD TVD 7837'-7860' 6958'-6978 ..... 7872'-7902 6988'-7014' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,,, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 5/17/97I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-DEL OIL GRAvITY'API (CORR) Press. 24-HOUR RATE 28. L;ORE L)AT ~ -.; ¢... ~. i: '-'. /:' ',-.. Brief description of lithology, porosity, fractures, apparent dips and prCs'bd~e'"'~ bll/g~S 6r,v~ater. Submit core chips. None Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TKUP 7645' 6795' KC1 7832' 6954' TKB7 7866' 6983' , , 21. Li~i'"~f Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip AIvord _~,.-- '~ ~. Title Senior Drilling Engineer Date MPE-19 97-37 Prepared By Name/Number: Jeanne Haas, 564-5225 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 00:57, 28 Aug 97 Page 1 The analysis is from ~ 09:30, 17 Mar 97 - to - 09:30, 17 Mar 97 Programs in Result Table: MPE-19 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPE-19 Event 09:30, 17 Mar 97 09:30, 17 Mar 97 0 hr 0 min Obtained leak off 15.100 Hole Size MDR 8-1/2 Facility Date/Time 11 Mar 97 12 Mar 97 13 Mar 97 14 Mar 97 15 Mar 97 16 Mar 97 M Pt E Pad Progress Report Well MPE- 19 Rig Nabors 27E Page Date 11:00-15:30 15:30-16:00 16:00-06:00 06:00-06:30 06:30-18:00 18:00-23:00 23:00-05:00 05:00-06:00 06:00-06:30 06:30-13:30 13:30-18:30 18:30-19:30 19:30-20:30 20:30-21:00 21:00-22:30 22:30-00:30 00:30-06:00 06:00-06:30 06:30-20:00 20:00-20:45 20:45-21:30 21:30-22:00 22:00-02:00 02:00-02:30 02:30-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-11:00 11:00-11:30 11:30-12:30 12:30-15:00 15:00-16:30 16:30-18:00 18:00-19:30 19:30-23:30 23:30-01:00 01:00-03:00 03:00-06:00 06:00-07:00 07:00-07:30 07:30-09:00 09:00-10:00 10:00-12:00 12:00-14:00 14:00-17:30 17:30-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-21:30 21:30-00:30 Duration 4-1/2 hr 1/2 hr 14hr 1/2 hr 11-1/2 hr 5hr 6hr lhr 1/2 hr 7hr 5hr lhr lhr 1/2 hr 1-1/2 hr 2hr 5-1/2 hr 1/2 hr 13-1/2 hr 3/4 hr 3/4 hr 1/2hr 4hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2hr lhr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 4hr 1-1/2 hr 2hr 3hr lhr 1/2 hr 1-1/2 hr lhr 2hr 2hr 3-1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 3hr Activity Rigged down High pressure lines Held safety meeting Rig moved 50.00 % Held safety meeting Rig moved 100.00 % Rigged up Fluid system Rigged up Divertor Serviced Additional services Held safety meeting Rigged up Divertor Ran Drillpipe to 2800.00 ft (5in OD) Held safety meeting Made up BHA no. 1 Tested Divertor Drilled to 206.00 ft Made up BHA no. 1 Drilled to 713.00 ft Held safety meeting Drilled to 2014.00 ft Circulated at 2014.00 ft Pulled out of hole to 600.00 ft R.I.H. to 2014.00 ft Drilled to 3036.00 ft Circulated at 3036.00 ft Pulled out of hole to 2000.00 ft R.I.H. to 3036.00 ft Drilled to 3720.00 ft Held safety meeting Drilled to 3970.00 ft Circulated at 3970.00 ft Pulled out of hole to 980.00 ft Serviced Top drive R.I.H. to 3970.00 ft Circulated at 3970.00 ft Pumped out of hole to 260.00 ft Downloaded MWD tool Rigged up Casing handling equipment Ran Casing to 3955.00 ft (9-5/8in OD) Circulated at 3955.00 ft Mixed and pumped slurry - 265.000 bbl Circulated at 1300.00 ft Mixed and pumped slurry - 345.000 bbl Held safety meeting Serviced Casing handling equipment Serviced Top drive Rigged up Divertor Installed Casing head Rigged up BOP stack Installed BOP test plug assembly Held safety meeting Tested BOP stack Removed BOP test plug assembly Serviced Choke manifold Made up BHA no. 2 1 27 August 97 Facility Date/Time 17 Mar 97 18 Mar 97 19 Mar 97 20 Mar 97 21 Mar 97 M Pt E Pad Progress Report Well MPE- 19 Page 2 Rig Nabors 27E Date 27 August 97 00:30-01:00 01:00-02:30 02:30-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:00 09:00-09:30 09:30-11:30 11:30-12:30 12:30-14:30 14:30-16:00 16:00-17:30 17:30-18:00 18:00-18:30 18:30-20:30 20:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-09:30 09:30-10:00 10:00-11:00 11:00-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-06:00 06:00-15:30 15:30-17:00 17:00-18:30 18:30-20:00 20:00-21:30 21:30-22:30 22:30-01:00 01:00-05:30 05:30-06:00 06:00-08:30 08:30-09:30 09:30-11:00 11:00-20:00 20:00-20:30 20:30-00:30 00:30-02:00 02:00-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-11:00 11:00-14:00 Duration 1/2 hr 1-1/2 hr 3-1/2 hr 1/2hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2hr lhr 2hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2hr 9-1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 1/2 hr lhr 7hr 1/2 hr 5-1/2 hr 1/2 hr lhr 1/2 hr 4hr 9-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 2-1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr lhr 1-1/2 hr 9hr 1/2 hr 4hr 1-1/2 hr 1/2 hr 2hr lhr 1/2 hr 1/2 hr 2-1/2 hr 2hr 3hr Activity R.I.H. to 1296.00 ft Drilled installed equipment - Cementing packer R.I.H. to 3867.00 ft Held safety meeting Tested Casing Drilled installed equipment - Landing collar Circulated at 3990.00 ft Performed formation integrity test Downloaded MWD tool Circulated at 4294.00 ft Pulled out of hole to 112.00 ft Downloaded MWD tool Made up BHA no. 3 Serviced Top drive Held safety meeting R.I.H. to 4294.00 ft Drilled to 5420.00 ft Held safety meeting Drilled to 5797.00 fl Circulated at 5797.00 ft Pulled out of hole to 4293.00 ft Serviced Top drive R.I.H. to 5797.00 ft Drilled to 6640.00 fl Held safety meeting Drilled to 7290.00 fl Circulated at 7290.00 ft Pulled out of hole to 5790.00 ft R.I.H. to 7290.00 ft Drilled to 7667.00 ft Drilled to 8280.00 ft Circulated at 8280.00 ft Pulled out of hole to 3955.00 ft Serviced Top drive Serviced Block line R.I.H. to 8280.00 ft Circulated at 8280.00 ft Pulled out of hole to 215.00 ft Pulled BHA Pulled BHA Worked on BOP - Pipe ram g~,;, Rigged up Casing handling equipment Ran Casing to 8249.00 ft (7in OD) Rigged up Cement head Circulated at 8249.00 ft '~" Mixed and pumped slurry- 122.000 bb~$b~ Tested Casing Serviced Fluid system Installed Wellhead integral components Serviced Pipe ram Serviced Pipe ram Rigged down BOP stack Installed Wellhead integral components Installed Xmas tree Facility Date/Time M Pt E Pad Progress Report Well MPE- 19 Rig Nabors 27E Page Date 14:00-06:00 Duration 16hr Activity Rig moved 70.00 % 3 27 August 97 , 'rD '- .-_rHdhnP. R;av 1'3rJlllnn .... [ Contractor; NABORS 4ES ' JlPl~one: 4164 P";~ $27.855 'lc"mm comp '~2~.ess ~ cum~ I ln~rm~iat~ (Pr~U~) ~ratlon at.~: TEST BOP ~../n~h 7"2e~oB~ ~8247' ~l'fl/mn~hPmdu~i~ Uner: ' ~A. IPed~'a~d in~l: 7~7-7~2, ~u~ Ceg. psi: . NIA I~l-~n~hJ~ C~ T~ · 4-1,~.~97 ~" ~lg A~pl (hr/date): 22~-5-2-g7 IRIg Release (hCdat~): ~A Data No. 2 Llner'S~e: N/A PM: N/A PM:. ~A psi: ~A ~1~ Pump Ra~: N/A ~low P~p p~: N/A ~.. · .. , ..~ , , BHA D~rl~: - , ., , ,= , ..... ;. · , = . ¥~o~ ~ ' I~.~. . [~ "~' '.- '1~-'*~'~'~: 'u~ I .o~,.., ~., ~ . ' Bit& ~tNum: ~A ' Size: ~A Make: N/A- It~: N/A INn' ' ...... . · .. !MIr ' ~pth " Fig; Hrm' InoP: IRPM: . "": "'* "": ! P."Y: 0~; . ,, ...... I~gclion O~ .to Ram: Pressure; 8~r~: .. Volume:. - Ty~ Fl~d: . InJe~on CC-2A [- N/A ! N/A Well: ,== ... · ~._ ,., . . ~ummula~e : ~ly Velum: N/A . .. - ' .. - Freeze' ~ol~ Fluid; N/A ' . '' VolUme; NiA '" Ue~: ... gnll~ur~:. - : Re~d; g~Ju~e~; paLl~uroo: , Cu~JBos D~ I ~ ., W~nl~r '~f~Op m~. . .. "' ~,, Spill D,II, m/97 /s~'' <Y/N)? N ' ~?lyme'(.a',,.):.-" N/A Fy~ Spill: N/A .o~A ~lled? N/A ~..~{.w~ N In"mo: -~a-- ... ,l.g~w--_- I II I I TI~ OpomUon Pr~ C~e -'Hrs. -: -: ' -Ope~fione From 0600 to 0~ . NO 8Pt~LS NO'AcCIDENTS *,~5 DSLTA '-g7 DSL~ - . [... . ~34~- NU-ND ;1,5.' TAKE ON'9.4 BRINE,ffiU B'~RM ~.N:D FIRAC TREE . . - , , ~2~. NU.ND .2.S NU'7"X I~8.ADPT F~G, BOP,PULL BPV, SET TEGT PLUO ~~ ~'- ' -0.5 TEST BOP260~/6~' · '" ' - '=. ' ~== ....... . .. .., , . : . .. . . . . ,. .... , , . . . . . · ~.,.. . . . . . , . . . . . . ..... .~. ,. ., . .... . . .... , . ', . l . , , ,,~ . . . ... _ -.~ ~. , 9:5;4 No.O0.~ P.01 Report ..1AN .... )1 10:1~ PrlJcihnA RAy l-3rillinn ! ] ·.c.tllrll~tfnnlt/V_n_r14c~V_~ ' F°: .,~n~a~°n' ' ,.~'*~RS 4 ES . LP~e:' '-- ~154 JOally~,a, ~9-6~2 ', .:Jwu' ~061~Ps: . $67 ' 5~7"' J ~wa,, ~n.t~' ' ra~ at ~. - · In~r~late (P~duotion) c~g: ~ - ' ~ ' RIH W/2 7/8 T~G/ESP AS~YL J~l~/nnnth 7 26ffLBO B~8247 ~g ~&pt (hr/date):" 23~ HRS 5-2-97 JRig ~eiea~ (hr/date): ~ , [Fluid Fluid Bdne ~Over NIA' D.iIV' NlA' d T;., N/A J.elly lCum . ~, , - . ,. , . , .... . . . Mill Out:D~ 'Ftg: Hr,: N~ !_ ' N/A iRPM: N/A IWU ~AI ....... -N/A B[~ & ~lt Num: ~A Size~ N/A Make: N/A . ~: NIA~N~:I~""'~.. N/A ~'~ff~ . JOnah i~:' N/A ~u;~: Volume: r~e ~m[d:.. lnJ~°n C~2A Ja~: NIA {~reeau~e= ~A ~ _ Weli~ - I _ . ~1 psi : Daily Volume: N/A ~ummula~v° ' ' ' ..... ' . ~lV~[~me; ~ N/A BaL Fre~ ~rote~-Fluid; N/A . Volume; - .. ~' [: .. N/A Fa~ Fuel & Waler .. N JNa~; ~A JEmPl~er: N/A JRpt Filed? W~) N/A Time ~era~on Pm~ C~e Hre. ' Operations Fmm 0S00 to ~ ' ' ..... ' NO SPILLS NO ACCIDENTS '~e'DSLTA ~sao N~ND ' ' .5 IN~TALLW~R RING ' ' ' ~3~ K~ 2.5 LOAD PiP~ SIDED W/2 7/8 TBG;SLM'DRFT .... ~11~ KILL 2 RIH W/2 W8 TBG~TO 21~0~ W/RaP ~!~ K~ .5 DISPL FREEZE 'PROTECT.WIg.4 BRINE 11~t~ KILL - 4.5 ~'NT RIH ~'~'7/8 TBGRBT TOOL TO 77~' .. "" ~1~1~ KILL ' - 2 DI'SPL WELL W~.4 BRINE,4 BPM ~500~- ~1~o -~LL - - .5 TAG ~Bp ~ 7765',~ET' DWN~ 5K OVER,MoNT ,REL~E, PULL 5 K OVER, ~ .. . ,, ' RIH TO ~80' ' .... 1~21~ Kl~ a CBU 3.5 BPM :~ 11~ ~,FLUID LO~SES 12 BPH,4 BBL GAiN IN PIT,~HUT IN, - . OlRC THRU ~oKE, p~CING-REtURNS IN '1 i ,(R~I URN TOTAL 73 BB~ ORUDE · , . MONT WELL,6 Bp'H sTATIG LOSS ' 213~ KILb '- '~ ~D ~. JTS 2 7)~TaG.TOH.LD RaP TOOL · ~-~3H~ ' ~UN ~MP - .1 RIG UP TO RUN ESP · ot~30. RUN C~P 2 MU 8ERVlCE ,ESP - - . -~o5~ PROB ' - ' ~.5" REPAIR STRIPPED THREADS ON ESP' POT HEAD:: ....... o~s~ RUN ~Mp .... '~ ~ : TIH ~ 2 7~8 COMP W/ESP . , , No.O02 P.01 'Hop0~ ; IPPI3'' 8154 Contractor: NABORS 4ES Fh°ne: 41.64 IDaily ~6'~,1g0 ICumm ~,omp ~'IP~ 7-'~?' I Gumnl Jlntormediate (Production) Gag: 7~6#L80 BTTO8247 Dperatl0n at 08o0: RELEASE RIG 1800 H RS I~i.A/l:3Anfh · ~;l~'AIDpnlh IRig Release (hr/date): 1~00 HRS S-4-97 Rig Ac~-,~pt (hr/date): 2300 HRS 5-2-97 ~ula Brine I~"r N/A Dally 'N/A a T~ N/A IDal'y Icum Fluid T~e: i balance; ~ss~ BB LOSS;. Cost: ICost: , . ~, , BNA . I q' ,, Bit &. Sit Num; N/A S~e: N/A Make: N/A .'~Y~:- N/A ' IseHm'' N/A ~FA: " JDepU~ Im N/A ,,, I , I~, l,--, . . , W~lh , . ~ - ~mul~ve · . , . , . gal ' 'FUel ~ Water D~t~ ..... . Fuel ' "lFUel ' IFuel IO~. Water - IDU. Water Us~: , ~1 J 8our~: BPX : Lake JRe~'d:_. gal lU~ed: . BBLISource: . O~ll~ N/A' C~umulmlvo: N/A / a~Age O~ ~lfm. , , Tim~ ' Operation Pr~ ~e Hre, Operations Fr~% 06~ to 06~ . . . NO SPILLS NO AGOlDENTS "e37 D'SLTA' "~ ~0690 RIG SERV ' .5 LUB RIG .... ~~ RUN ~MP ' ~.S RIH W/2 718 ESP ASSY~,MU HNGR LD~'~ J~'(U~ED 126 ~SALLE CLMPS)" 1~12~ RUN'~MP 2 MU PIG'I All. SPLICE FO~ HNGR . - ' . ' 1~1~ RuN OOMp I ~D T~G.RILDS.LO LNDNG JT ,S~*TWC ~~ ND NU 2 ' ND RISER. FLoW LINE.BO~.N0 TREE 1~10~ TEST= I ' 'T~'H~GR,TREE TO 50~,PULL ~C,S~ BPV --. 2 FREEZE PROT,BU~EAD 10 BBLS DIESEL DW~ ~G,BULLHEAD ~ BBLS DWN ANNULI,BLOW DWN LINES,aEGURE WE~EAD,MAKE FINAL- .... SEP OK, ' - . . . : - .... RELEASE RIG 18~ HRS '5~97''" .; . . , ,.....,.. . . , . ...... ~._ ,.- . .. _ . . . ' ..., , · ' . SPEZ -SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 031597 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70070 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. .00 .00 -57.50 341.50 341.46 283.96 432.50 432.42 374.92 523.50 523.34 465.84 614.50 614.20 556.70 0 0 1 18 2 0 2 42 3 26 N .00 E .00 .00N .00E .00 N 54.62 W .38 2.27N 3.19W 3.88 N 52.09 W .77 3.85N 5.30W 6.50 N 63.12 W .91 5.80N 8.47W 10.14 N 68.35 W .87 7.78N 12.92W 14.73 705.50 704.98 647.48 796.50 795.61 738.11 887.50 885.96 828.46 978.50 975.92 918.42 1072.10 1067.99 1010.49 4 31 5 47 7 44 9 29 11 10 N 70.39 W 1.21 9.99N 18.84W 20.55 N 78.18 W 1.58 12.14N 26.72W 27.74 N 78.88 W 2.15 14.26N 37.23W 36.84 N 72.48 W 2.19 17.70N 50.41W 48.77 N 66.92 W 2.08 23.58N 66.11W 64.21 1166.60 1160.08 1102.58 1261.50 1251.37 1193.87 1355.50 1341.34 1283.84 1449.40 1430.55 1373.05 1542.90 1518.33 1460.83 14 44 16 53 16 47 19 33 20 44 N 59.93 W 4.13 33.20N 84.95W 84.50 N 55.81 W 2.54 47.00N 106.80W 109.85 N 55.67 W .12 62.32N 129.30W 136.73 N 50.68 W 3.38 79.93N 152.66W 165.80 N 49.37 W 1.35 100.63N 177.33W 197.94 1637.30 1605.75 1548.25 1731.70 1691.84 1634.34 1826.10 1777.68 1720.18 1920.00 1862.23 1804.73 2013.90 1944.97 1887.47 23 24 24 27 29 33 52 19 13 10 N 51.23 W 3.08 123.33N 204.73W 233.45 N 50.51 W 1.43 147.77N 234.75W 272.05 N 49.59 W .71 173.00N 264.87W 311.26 N 48.88 W 3.11 199.66N 295.78W 352.04 N 48.52 W 2.08 228.95N 329.11W 396.38 2107.70 2026.22 1968.72 2201.00 2106.33 2048.83 2295.00 2186.86 2129.36 2388.60 2266.89 2209.39 2482.90 2347.36 2289.86 3O 45 3O 54 31 12 31 15 31 34 N 46.89 W 1.91 260.48N 363.75W 443.21 N 45.87 W .58 293.47N 398.37W 491.04 N 45.39 W .41 327.38N 433.04W 539.52 N 44.76 W .35 361.66N 467.40W 588.04 N 44.85 W .34 396.54N 502.04W 637.18 2574.00 2424.70 2367.20 2665.10 2501.64 2444.14 2757.70 2579.50 2522.00 2851.10 2657.81 2600.31 2942.20 2734.32 2676.82 32 32 33 33 32 13 31 1 2 40 N 49.47 W 2.77 429.23N 537.32W 685.28 N 48.77 W .53 461.15N 574.20W 734.00 N 47.86 W .75 494.49N 611.64W 784.10 N 46.58 W .75 529.07N 649.01W 835.01 N 45.73 W .65 563.31N 684.66W 884.44 3036.50 2813.60 2756.10 3131.60 2893.30 2835.80 3226.60 2972.63 2915.13 3320.00 3050.68 2993.18 3413.20 3129.09 3071.59 32 54 33 13 33 31 33 5 32 21 N 45.40 W .30 599.06N N 44.56 W .59 635.76N N 44.43 W .33 673.04N N 44.21 W .49 709.73N N 45.60 W 1.12 745.42N 721.13W 935.51 757 . 80W 987 . 37 794 . 43W 1039 . 60 830 . 27W 1090 . 85 865 . 83W 1141 . 22 SPEt -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLOITATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 031597 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70070 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 3505.90 3207.19 3149.69 32 49 N 45.24 W .53 780.48N 901.39W 3546.90 3241.64 3184.14 32 49 N 45.50 W .34 796.09N 917.21W 3599.80 3286.05 3228.55 33 2 N 45.35 W .43 816.27N 937.69W 3693.60 3364.90 3307.40 32 32 N 44.68 W .65 852.17N 973.62W 3788.50 3445.72 3388.22 30 40 N 44.89 W 1.97 887.46N 1008.65W 1191.14 1213.35 1242.10 1292.88 1342.58 3830.00 3481.38 3423.88 30 50 N 45.10 W .48 902.47N 1023.65W 3873.50 3518.76 3461.26 30 41 N 44.29 W 1.02 918.29N 1039.30W 3970.00 3601.74 3544.24 30 41 N 44.29 W .00 953.54N 1073.69W 1363.80 1386.04 1435.25 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1435.99 FEET AT NORTH 48 DEG. 23 MIN. WEST AT MD = 3970 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 313.45 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 3,873.50' MD PROJECTED SURVEY AT 3,970.00' MD SPE7 ' SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 031597 JOB NUMBER: AK-EI-70070 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -57.50 .00 N .00 E .00 1000.00 997.12 939.62 18.77 N 53.79 W 2.88 2.88 2000.00 1932.83 1875.33 224.46 N 324.03 W 67.17 64.29 3000.00 2782.95 2725.45 585.14 N 707.01 W 217.05 149.88 3970.00 3601.74 3544.24 953.54 N 1073.69 W 368.26 151.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEY -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 031597 JOB NUMBER: AK-EI-70070 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -57.50 57.50 57.50 .00 157.50 157.50 100.00 257.52 257.50 200.00 357.55 357.50 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 1.15 N 1.62 W .02 .02 2.48 N 3.49 W .05 .03 457.60 457.50 400.00 557.70 557.50 500.00 657.87 657.50 600.00 758.20 757.50 700.00 858.78 857.50 800.00 4.39 N 5.99 W 6.53 N 9.91 W 8.74 N 15.34 W 11.34 N 22.96 W 13.51 N 33.44 W .10 .05 .20 .10 .37 .17 .70 .33 1.28 .58 959.82 1061.41 1163.94 1267.91 1372.41 957.50 1057.50 1157 50 1257.50 1357 50 900.00 1000.00 1100.00 1200.00 1300.00 16.77 N 47.47 W 22.77 N 64.21 W 32.87 N 84.37 W 48.04 N 108.34 W 65.17 N 133.37 W 2.32 1.04 3.91 1.58 6.44 2.53 10.41 3.97 14.91 4.50 1478.00 1584.97 1693.86 1803.96 1914.70 1457 50 1557.50 1657 50 1757.50 1857 50 1400 1500 1600 1700 1800 .00 .00 .00 .00 .00 86.00 N 160.07 W 110.53 N 189.06 W 137.67 N 222.49 W 167.08 N 257.93 W 198.09 N 293.97 W 20 27 36 46 57 .50 5.59 .47 6.98 .36 8.89 .46 10.10 .20 10.74 2028.25 2144.10 2260.68 2377.61 2494.80 1957 50 2057.50 2157.50 2257.50 2357.50 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 233.58 N 334.35 W 273.21 N 377.34 W 314.90 N 420.38 W 357.61 N 463.39 W 400.96 N 506.44 W 70 86 103 120 137 .75 13.55 .60 15.85 .18 16.58 .11 16.94 .30 17.19 2612.77 2731.46 2850.74 2969.74 3088.81 2457.50 2557.50 2657.50 2757.50 2857.50 2400 2500 2600 2700 2800 .00 .00 .00 .00 .00 442.67 N 553.03 W 484.89 N 601.03 W 528.93 N 648.86 W 573.69 N 695.31 W 619.08 N 741.34 W 155 173 193 212 231 .27 17.97 .96 18.69 .24 19.28 .24 19.00 .31 19.08 3208.45 3328.14 3446.84 3565.77 3684.82 2957.50 3057.50 3157.50 3257.50 3357.50 2900.00 3000.00 3100.00 3200.00 3300.00 665.88 N 787.41 W 712.92 N 833.36 W 758.03 N 878.70 W 803.26 N 924.50 W 848.81 N 970.29 W 250.95 270.64 289.34 308.27 327.32 19.63 19.69 18.71 18. 93 19.05 SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/18/97 DATE OF SURVEY: 031597 JOB NUMBER: AK-EI-70070 KELLY BUSHING ELEV. = 57.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3802.20 3918.55 3970.00 3457.50 3400.00 3557.50 3500.00 3601.74 3544.24 892.42 N 1013.59 W 344.70 17.39 934.75 N 1055.36 W 361.05 16.35 953.54 N 1073.69 W 368.26 7.21 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS sPER -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031997 MWD SURVEY JOB NUMBER: AK-MM-70067 KELLY BUSHING ELEV. = 58.55 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDI DEGREES DG/100 NORTH/SOUTH EAST/ NATES WEST VERT. SECT· .00 .00 -58.55 209.66 209.66 151.11 299.75 299.75 241.20 389.39 389.37 330.82 480.29 480.21 421.66 0 0 N .00 E .00 .00N 0 11 N 88.98 E .09 .01N 0 44 N 37.63 W .96 .47N 1 28 N 61.49 W .96 1.48N 2 21 N 58.74 W .97 3.01N .00E .35E · 14E .23W .86W .00 - .25 .22 1.91 4·87 567.35 567.18 508.63 657·55 657.22 598.67 746.58 746.00 687.45 838.37 837.33 778.78 926.91 925.10 866.55 2 55 N 69.35 W .86 4.73N 3 44 N 86.98 W 1.44 5.69N 4 51 N 79.40 W 1.41 6.54N 6 31 N 76.88 W 1.84 8.44N 8 26 N 73.80 W 2.21 ll.40N 7 12 19 28 39 .47W .57W · 18W · 08W .23W 8.68 13.04 18.42 26.19 36.32 1018.60 1015.59 957.04 1111.39 1106.60 1048.05 1206.00 1198.18 1139.63 1301.64 1289.80 1231.25 1395.81 1379.68 1321.13 10 0 N 69.51 W 1.86 16.07N 12 22 N 64.48 W 2.75 23.17N 16 40 N 55.88 W 5.07 35.16N 16 40 N 57.31 W .43 50.26N 18 1 N 53.75 W 1.82 66.17N 53 69 9O 112 136 · 17W .69W .08W .98W .09W 49.65 66.53 89·57 116.59 144.31 1489.77 1468.54 1409.99 1584.05 1556.41 1497.86 1676.00 1640.61 1582.06 1771.60 1727.69 1669.14 1866.32 1813.44 1754.89 19 55 N 48.27 W 2.77 85.42N 22 32 N 50.63 W 2.93 107.58N 24 47 N 51.61 W 2.47 130.74N 23 57 N 50.55 W .98 155.52N 26 15 N 48.45 W 2.60 181.64N 159.76W 185.73W 214.47W 245.17W 275.70W 174.73 208.82 245.61 284.94 325.07 1958.01 1894.88 1836.33 2051.92 1976.69 1918.14 2146.59 2058.22 1999.67 2240.48 2138.82 2080.27 2332.61 2217.76 2159.21 28 24 N 49.36 W 2.39 209.30N 30 22 N 47.50 W 2.30 239.88N 30 42 N 46.32 W .73 272.75N 31 1 N 45.86 W .42 306.15N 31 2 N 45.12 W .41 339.45N 307 341 377 411 445 .43W .89W · 01W .71W .58W 367.13 413.18 461.28 509.44 556.93 2426·97 2298·53 2239·98 2522.15 2379.69 2321.14 2612.79 2456.53 2397.98 2704.90 2534.30 2475.75 2796.52 2611.31 2552.76 31 13 N 44.81 W .26 373.97N 31 47 N 49.77 W 2.79 407.67N 32 15 N 49.42 W .56 438.83N 32 32 N 48.38 W .68 471.27N 33 3 N 46.78 W 1.10 504.76N 480 516 553 590 627 .06W .60W .20W .39W .03W 605.70 655.40 703.40 752.71 802.34 2890.68 2690.51 2631.96 2981.39 2766.96 2708.41 3074.92 2845.57 2787.02 3169.89 2925.15 2866.60 3265.35 3004.91 2946.36 32 25 N 45.94 W .83 539.90N 32 42 N 45.62 W .37 573.95N 32 54 N 44.82 W .51 609.65N 33 13 N 44.87 W .34 646.39N 33 25 N 44.52 W .28 683.67N 663.88W 698.87W 734.84W 771.39W 808.27W 853.26 902.08 952·75 1004.54 1056.96 ORIGINAL SPE5, -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031997 MWD SURVEY JOB NUMBER: AK-MM-70067 KELLY BUSHING ELEV. = 58.55 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3361.64 3085.84 3027.29 32 12 3453.61 3163.54 3104.99 32 28 3546.94 3242.20 3183.65 32 39 3641.26 3321.50 3262.95 32 53 3736.05 3402.01 3343.46 30 47 N 45.70 W 1.43 720.50N 845.23W N 45.72 W .30 754.85N 880.44W N 45.83 W .20 789.89N 916.45W N 46.03 W .27 825.41N 953.13W N 44.99 W 2.29 860.43N 988.81W 1109.11 1158.31 1208.54 1259.60 1309.59 3830.93 3483.50 3424.95 30 3914.68 3555.41 3496.86 30 4057.78 3679.04 3620.49 29 4151.28 3760.89 3702.34 28 4242.71 3841.51 3782.96 28 50 49 38 8 10 N 45.24 W .14 894.73N 1023.25W N 45.06 W .11 925.01N 1053.68W N 44.18 W .89 976.29N 1104.30W N 45.15 W 1.68 1008.42N 1136.04W N 47.64 W 1.29 1038.16N 1167.27W 1358.18 1401.09 1473.10 1518.25 1561.38 4335.42 3923.21 3864.66 4430.83 4007.30 3948.75 4524.62 4090.04 4031.49 4617.52 4171.85 4113.30 4711.96 4255.07 4196.52 28 28 28 28 27 13 8 2 31 53 N 47.88 W .14 1067.61N 1199.71W N 47.74 W .11 1097.88N 1233.10W N 47.90 W .13 1127.55N 1265.84W N 48.48 W .59 1156.89N 1298.65W N 48.33 W .67 1186.52N 1332.03W 1605.18 1650.24 1694.40 1738.41 1783.02 4804.46 4337.17 4278.62 26 58 4899.01 4421.32 4362.77 27 15 4993.05 4504.81 4446.26 27 32 5087.13 4588.59 4530.04 26 32 5181.17 4671.98 4613.43 28 29 N 48.75 W 1.01 1214.74N 1363.97W N 47.86 W .52 1243.41N 1396.15W N 48.09 W .33 1272.39N 1428.30W N 48.90 W 1.13 1300.74N 1460.34W N 48.01 W 2.11 1329.56N 1492.85W 1825.61 1868.69 1911.96 1954.72 1998.14 5275.36 4754.91 4696.36 28 6 5368.05 4836.24 4777.69 29 14 5463.39 4919.76 4861.21 28 25 5556.93 5001.59 4943.04 29 30 5653.32 5085.81 5027.26 28 42 N 49.22 W .74 1359.08N 1526.34W N 47.10 W 1.65 1388.75N 1559.45W N 48.47 W 1.10 1419.64N 1593.49W N 47.20 W 1.34 1450.05N 1627.06W N 47.32 W .83 1481.88N 1661.50W 2042.75 2087.19 2133.15 2178.44 2225.32 5746.83 5167.18 5108.63 30 5837.83 5245.79 5187.24 30 5932.98 5328.10 5269.55 30 6027.82 5410.30 5351.75 29 6121.76 5491.83 5433.28 29 17 12 0 5O 44 N 44.96 W 2.11 1513.79N 1694.68W N 45.00 W .10 1546.23N 1727.09W N 46.18 W .66 1579.62N 1761.18W N 47.11 W .52 1612.10N 1795.57W N 47.27 W .13 1643.81N 1829.81W 2271.36 2317.20 2364.91 2412.22 2458.88 6215.57 5573.41 5514.86 6309.96 5655.12 5596.57 6403.95 5736.18 5677.63 6497.90 5817.46 5758.91 6591.11 5897.85 5839.30 29 3O 30 30 30 25 38 10 1 46 N 48.21 W .59 1674.96N 1864.09W N 47.57 W 1.33 1706.64N 1899.13W N 48.37 W .65 1738.50N 1934.47W N 49.11 W .43 1769.57N 1969.89W N 46.98 W 1.41 1801.10N 2004.94W 2505.19 2552.42 2599.98 2647.06 2694.19 SPE} -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031997 MWD SURVEY JOB NUMBER: AK-MM-70067 KELLY BUSHING ELEV. = 58.55 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6682.65 5976.33 5917. 6774.88 6055.05 5996. 6864.11 6131.06 6072. 6958.18 6211.15 6152. 7051.91 6290.92 6232. 78 31 12 N 47.90 W .71 1832.98N 2039.66W 50 31 34 N 47.00 W .65 1865.47N 2075.05W 51 31 36 N 46.23 W .45 1897.58N 2109.03W 60 31 38 N 46.36 W .08 1931.66N 2144.69W 37 31 42 N 46.49 W .10 1965.59N 2180.35W 2741.32 2789.36 2836.10 2885.44 2934.66 7144.07 6369.44 6310. 7234.96 6446.83 6388. 7331.62 6528.92 6470. 7426.89 6609.72 6551. 7522.83 6691.11 6632. 89 31 24 N 45.68 W .56 1999.05N 2215.10W 28 31 51 N 45.58 W .49 2032.38N 2249.17W 37 31 53 N 45.60 W .04 2068.09N 2285.63W 17 32 5 N 45.10 W .35 2103.56N 2321.54W 56 31 51 N 43.93 W .69 2139.78N 2357.15W 2982.89 3030.55 3081.58 3132.04 3182.81 7616.13 6770.47 6711. 7708.88 6849.43 6790. 7803.11 6929.63 6871. 7898.42 7010.90 6952. 7993.18 7091.72 7033. 92 31 36 N 43.91 W .26 2175.13N 2391.19W 88 31 40 N 44.79 W .50 2209.92N 2425.20W 08 31 38 N 44.72 W .06 2245.05N 2460.02W 35 31 21 N 44.09 W .46 2280.62N 2494.86W 17 31 35 N 43.99 W .26 2316.18N 2529.25W 3231.82 3280.45 3329.88 3379.64 3429.06 8085.23 7170.16 7111. 8180.74 7251.44 7192. 8230.46 7293.71 7235. 8280.00 7335.84 7277. 61 31 31 N 43.43 W .33 2351.00N 2562.54W 90 31 49 N 43.92 W .42 2387.27N 2597.17W 16 31 44 N 43.68 W .31 2406.17N 2615.30W 29 31 44 N 43.68 W .00 2425.02N 2633.30W 3477.17 3527.26 3553.42 3579.45 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3579.80 FEET AT NORTH 47 DEG. 21 MIN. WEST AT MD = 8280 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 313.45 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 8,280.00' MD SPE} -SUN DRILLING SERVICES · ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031997 JOB NUMBER: AK-MM-70067 KELLY BUSHING ELEV. = 58.55 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.55 .00 N .00 E 1000.00 997.28 938.73 14.94 N 50.14 W 2000.00 1931.81 1873.26 222.31 N 322.59 W 3000.00 2782.62 2724.07 580.98 N 706.06 W 4000.00 3628.82 3570.27 955.79 N 1084.38 W .00 2.72 2.72 68.19 65.47 217.38 149.19 371.18 153.80 5000.00 4510.97 4452.42 1274.53 N 1430.69 W 489.03 6000.00 5386.17 5327.62 1602.68 N 1785.43 W 613.83 7000.00 6246.75 6188.20 1946.81 N 2160.57 W 753.25 8000.00 7097.53 7038.98 2318.75 N 2531.74 W 902.47 8280.00 7335.84 7277.29 2425.02 N 2633.30 W 944.16 117.85 124.80 139.42 149.22 41.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE! -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031997 JOB NUMBER: AK-MM-70067 KELLY BUSHING ELEV. = 58.55 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .0 58.55 58.5 158.55 158.5 258.55 258.5 358.56 358.5 -58. 100. 200. 300. 55 00 00 00 00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .18 E .00 .00 .06 N .45 E .00 .00 1.10 N .53 W .01 .01 458.61 458.5 558.71 558.5 658.88 658.5 759.18 758.5 859.73 858.5 400. 500. 600. 700. 800. 00 00 00 00 00 2.55 N 3.10 W .06 .05 4.57 N 7.06 W .16 .10 5.70 N 12.66 W .33 .17 6.74 N 20.23 W .63 .30 8.99 N 30.45 W 1.18 .56 960.73 958.5 1062.23 1058.5 1164.84 1158.5 1269.02 1258.5 1373.59 1358.5 900. 1000. 1100. 1200. 1300. O0 O0 O0 O0 O0 12.79 N 44.01 W 18.78 N 60.32 W 29.17 N 80.71 W 45.21 N 105.11 W 62.10 N 130.55 W 2.18 1.00 3.68 1.51 6.29 2.61 10.47 4.18 15.04 4.57 1479.15 1458.5 1586.37 1558.5 1695.76 1658.5 1805.38 1758.5 1916.75 1858.5 1400. 1500. 1600. 1700. 1800. O0 O0 O0 O0 O0 83.04 N 157.07 W 108.15 N 186.42 W 135.88 N 220.96 W 164.24 N 255.77 W 196.54 N 292.60 W 20.60 5.56 27.82 7.21 37.21 9.39 46.83 9.62 58.20 11.37 2030.90 1958.5 2146.97 2058.5 2263.51 2158.5 2380.22 2258.5 2497.30 2358.5 1900. 2000. 2100. 2200. 2300. O0 O0 O0 O0 O0 232.70 N 334.05 W 272.88 N 377.15 W 314.42 N 420.23 W 356.77 N 462.97 W 399.12 N 506.73 W 72.35 14.15 88.42 16.07 104.96 16.54 121.67 16.71 138.75 17.09 2615.17 2458.5 2733.67 2558.5 2852.81 2658.5 2971.40 2758.5 3090.39 2858.5 2400. 2500. 2600. 2700. 2800. O0 O0 O0 O0 O0 439.65 N 554.16 W 481.56 N 601.96 W 525.78 N 649.28 W 570.17 N 695.01 W 615.61 N 740.77 W 156.62 17.87 175.12 18.49 194.26 19.14 212.85 18.59 231.84 18.99 3209.82 2958.5 3329.39 3058.5 3447.69 3158.5 3566.37 3258.5 3685.31 3358.5 2900. 3000. 3100. 3200. 3300. O0 O0 O0 O0 O0 661.90 N 786.82 W 708.49 N 832.93 W 752.63 N 878.17 W 797.20 N 923.97 W 841.97 N 970.26 W 251.27 19.43 270.84 19.57 289.14 18.30 307.82 18.68 326.76 18.95 SPEF -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031997 JOB NUMBER: AK-MM-70067 KELLY BUSHING ELEV. = 58.55 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3801.87 3458.55 3400.00 3918.34 3558.55 3500.00 4034.21 3658.55 3600.00 4148.62 3758.55 3700.00 4262.05 3858.55 3800.00 884.24 N 1012.67 W 926.33 N 1055.01 W 967.93 N 1096.17 W 1007.53 N 1135.15 W 1044.31 N 1174.02 W 343.32 16.56 359.79 16.46 375.66 15.87 390.07 14.41 403.50 13.42 4375.53 3958.55 3900.00 4488.94 4058.55 4000.00 4602.39 4158.55 4100.00 4715.90 4258.55 4200.00 4828.46 4358.55 4300.00 1080.34 N 1213.78 W 1116.30 N 1253.39 W 1152.10 N 1293.24 W 1187.75 N 1333.41 W 1221.92 N 1372.15 W 416.98 13.48 430.39 13.41 443.84 13.45 457.35 13.51 469.91 12.56 4940.89 4458.55 4400.00 5053.55 4558.55 4500.00 5165.89 4658.55 4600.00 5279.48 4758.55 4700.00 5393.62 4858.55 4800.00 1256.28 N 1410.38 W 1290.87 N 1449.03 W 1324.69 N 1487.43 W 1360.35 N 1527.81 W 1397.25 N 1568.60 W 482.34 12.44 495.00 12.65 507.34 12.34 520.93 13.59 535.07 14 . 14 5507.54 4958.55 4900.00 5622.24 5058.55 5000.00 5736.83 5158.55 5100.00 5852.60 5258.55 5200.00 5968.14 5358.55 5300.00 1433.64 N 1609.24 W 1471.76 N 1650.52 W 1510.22 N 1691.12 W 1551.48 N 1732.34 W 1591.80 N 1773.86 W 548.99 13.92 563.69 14.71 578.28 14.59 594.05 15.77 609.59 15.54 6083.44 5458.55 5400.00 6198.51 5558.55 5500.00 6313.95 5658.55 5600.00 6429.83 5758.55 5700.00 6545.39 5858.55 5800.00 1630.91 N 1815.85 W 1669.38 N 1857.84 W 1708.02 N 1900.63 W 1747.14 N 1944.19 W 1785.21 N 1987.83 W 624.89 15.29 639.96 15.08 655.40 15.44 671.28 15.88 686.84 15.56 6661.86 5958.55 5900.00 6778.98 6058.55 6000.00 6896.39 6158.55 6100.00 7013.87 6258.55 6200.00 7131.30 6358.55 6300.00 1825.75 N 2031.67 W 1866.93 N 2076.63 W 1909.28 N 2121.25 W 1951.83 N 2165.85 W 1994.40 N 2210.34 W 703.31 16.47 720.43 17.12 737.84 17.41 755.32 17.47 772.75 17.44 7248.75 6458.55 6400.00 7366.52 6558.55 6500.00 7484.50 6658.55 6600.00 7602.14 6758.55 6700.00 7719.60 6858.55 6800.00 2037.47 N 2254.37 W 2080.99 N 2298.80 W 2125.22 N 2343.12 W 2169.84 N 2386.10 W 2213.92 N 2429.17 W 790.20 17.45 807.97 17.76 825.95 17.98 843.59 17.64 861.05 17.46 SPE~, -SUN DRILLING SERVICES ANCHOR3~GE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-19 500292274600 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 031997 JOB NUMBER: AK-MM-70067 KELLY BUSHING ELEV. = 58.55 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7837.08 6958.55 6900.00 2257.71 N 2472.56 W 878.53 17.47 7954.24 7058.55 7000.00 2301.51 N 2515.09 W 895.69 17.16 8071.61 7158.55 7100.00 2345.83 N 2557.64 W 913.06 17.37 8189.10 7258.55 7200.00 2390.45 N 2600.23 W 930.55 17.50 8280.00 7335.84 7277.29 2425.02 N 2633.30 W 944.16 13.61 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS O I:i I /1__ I IM Oi S =: !::1 L/I WELL LOG TRANSMITTAL To: State of Alaska July 2, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPE-19, AK-MM-70067 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jhm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPE-19: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22746-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22746-00 2"x 5" MD Neutron and Density Logs: 50-029-22746-00 2"x 5" TVD Neutron and Densi~ Logs: 50-029-22746-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company _ 01:! I Lt-I N G S ~:: I:! ~/I r' ~:: S To: WELL LOG TRANSMITTAL -- State of Alaska Alaska Oil and Gas Conservation Cormn. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - JULY 2, 1997 MPE-19 AK-MM-70067 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Yah Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22746-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, inc. Company _ Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) May 12, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. ,/'1 Anchorage, Alaska 99519-6612 ~_~ The following data of the PDC GR for wells MPU E-14 & MPU E-19, Job # 9'7182 & 97181, was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3o3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 CH LIS Tape each 1 Film each 3 Bluelines each State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 300t Porcupine 'Drive Anchorage, AK 99501 1 CH LIS Tape each 1 Blueiine each 1 RFolded Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 CH LIS Tape each 1 Blueline each 1 RFolded Sepia each Sent Certified Mail Z 777 937 571 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 995i'9~66t-2' ~.-~'-:-~.:~ ~ ~ Date Delivered' Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by; ~ ~/ 4/24/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10967 Company: Field: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPU E-14 PERFORATION RECORD 9 7041 6 1 1 M PU E-18 PERFORATION RECORD 970415 I 1 MPU E-19 PERFORATION RECORD 970414 I 1 MPU F-701 L.i,.~ (.L_ CHEMICAL CUTTER 970320 I 1 MPU F-73 GR/CCL 97031 3 I 1 MPU F-73 PERFORATING RECORD 97031 3 I 1 MPU J-09 ~,.,~ ~ CHEMICAL CUTTER RECORD 97041 7 1 1 MPU J-09 . J. CBL 97041 8 I 1 MPU J-09~ PERFRECORD 97041 8 I 1 K-21 PERF RECORD W/GR 97031 6 1 1 MPK-21 CBL 97031 6 I 1 MPK-43A H.P.G. GUNS SHOOTING RECORD 97031 9 1 1 I M P K-43A STATIC PRESSURE SURVEY W/CPLT 97031 9 I 1 MPK-43A CBL 97031 9 I 1 M P K-43A H.P.G. GUNS PERFORATION RECORD 970321 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 / Received b ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 12, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPE-19 BP Exploration (Alaska), Inc. Permit No. 97-037 Sur Loc 371 lq'qSL, 1812'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc 7642qSL, 4367'WEL, Sec. 24, T13N, R10E, UM Dear Mr. Schofietd: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated March 5, 1997, are in effect for this revision. . v Chairman'~ IO BY ORDE~ THE MMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl BP EXPLORATION March 11, 1997 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ORiGiNAL Subject: Before Spud Changes to Approved Application for Permit to Drill #97-037 Dear Mr. Johnston, In order to improve the positioning of the bottom hole location away from faults in the Kuparuk it is necessary to modify the well profile from the one submitted and approved in the Permit to Drill #97-037 on March 5, 1997. This correspondence is submitted in order to be in compliance with AOGCC Regulation 20 ACC 25.015, Changes to Drilling Permit, (a) For a proposed change in a drilling permit. ..... before the start of actual drilling operations. It has been proposed by the BPX Milne Point Geoscienes Group that a more optimal wellbore trajectory for stimulation and well productivity will be achieved if the well profile is changed through the Kuparuk interval in the well MP E-19 as proposed in the request. The revised well profile for MP E-19, incorporating this modification to the well trajectory is included in this request for change. As a result of the proposed wellbore trajectory modification the following changes are requested: 1. The well profile be modified. 2. The location At top of productive interval be changed to: 631' NSL, 4227' WEL, Sec. 04, T12N, RllE, UM. 3. The location At Total Depth be changed to: 764' NSL, 4367' WEL, Sec. 04, T12N, RllE, UM. Thank-you for your consideration in this mater and if you have any questions or need additional information concerning this request for Before Spud Changes to Approved Application for Permit to Drill #97-037 please contact me in Anchorage at 564-5042. Respectfully Lance J. Spencer Drilling Operations Engineer Shared Services Drilling BPX Gas Cons, ~mmi~i0n STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL REVISED 03/11/97 20 AAC 25.005 [] Drill [] Redrill ]lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE -- 57.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3711' NSL, 1812' WEL, SEC. 25, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 631' NSL, 4227' WEL, SEC. 24, T13N, R10E MPE-19 At total depth 9. Approximate spud date Amount $200,000.00 764' NSL, 4367' WEL, SEC. 24, T13N, R10E 03/13/97 12. Distance to nearest property line113. DistanCe to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 764'I No Close Approach 2560 8072' MD / 7183' TVD 16. To be completed for deviated wells i17. Anticipated pressure {see 20 AAC 25.035 (el (2)} Kick Off Depth 300' Maximum Hole Angle 29.90° Maximum surface 2885 psig, At total depth (TVD) 7044' / 3589 psig 18. Casing Program I Setting Depth Size Specifications~ Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) ....... 12-1/4" 9-5/8" 40# L-80 Btm 3859' 31' 31' 3890' 3558' 9885x PF 'E', 724 sx Class 'G' 8-1/2" 7" 26# L-80 Btm 8042' 30' 30' 8072' 7183' 242 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs(measured)ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor ~ ~ t~' ~,, ~ V ~. ~ Surface ' ' Intermediate Productioni 2 1997 Liner ~,.i~.~ Oii& Gas Cons. Commission Anchorage Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Narne/Nurnber: Kathy Carnnpoarnor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si.g_. ned --%---~*~-- Tim Schofield / ~ Title Senior Drilling Engineer Date z,./t ~ £ ~ ? Commission Use Only P e r m it ~t,~,~b e,~ ) APl Number Approval Date I See cover letter - 7 50-~_?!~- ~ 2.. ~ ,~L//~' for other requirements Conditions of Approval: Samples ReqUired [] Yes ~' No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures []Yes ,~ No Directional Survey Required '~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; J~ SM; [] 1OM; [] 15M Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: Lance Spencer I Well Name: IMP E-19 Well Plan Summary I Type of Well (producer or injector)' I Kuparuk Producer 564-5042 Surface Location: 3711 NSL 1812 WEL Sec 25 T13N R10E UM.,AK Kuparuk Target Location: 631 NSL 4227 WEL Sec 24 T13N R101E UM., AK Bottom Hole Location' 764 NSL 4367 WEL Sec 24 T13N R10E UM., AK IAFE Number: 1337064 I I Ri!]: I Nabors 27-E IMD' 18,072 I I TVD: 17,183' Kkb I IKBE' 157.5 IWell Design (conventional, slimhole, I Milne Point Ultra Slimh,,ole Longstring 9- etc.)' I 5/8", 40# Surface X 7, 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Base Permafrost 1 9 2 9 1 8 5 8 8.3 ppg, 802 psi NA 4726 4283 8.3 ppg, 1849 psi CA 48 8 2 4 41 8 8.3 ppg, 1907 psi CB 4957 4483 8.3 ppg, 1935 psi Base OB 4 998 451 8 8.3 ppg, 1950 psi Top HRZ 6 97 0 6 22 8 8.6 ppg, 2785 psi BaseHRZ 7218 6443 8.6 ppg, 2881 psi TKLB 7334 6543 9.8 ppg, 3334 psi TKUP/UD 7483 6673 9.8 ppg, 3401 psi TKUC/TARGET 7 6 85 6 845 9.8 ppg, 3488 psi TKC1 7 685 6 848 9.8 ppg, 3490 psi TKUB/B8 7703 6863 9.8 ppg, 3497 psi TKB7 7 71 4 6 87 3 9.8 ppg, 3502 psi TKUA 7922 7053 9.8 ppg, 3594 psi ExpectedOWC 7978 7102 9.8 ppg, 3619 psi Total Depth +_8072 71 84 9.8 ppg, 3661 psi ~-~C~'t*~Y~ ¥ Casincj/Tubin~I Pro!lram. I,/~kR, '~ ~- '[997 Hol~ (~sg/ 'Wt/Ft Grade Conn Length Top Btm Size Tb!] O.D. M D/TVD~c.~,~;;_~Cf/~:/~i~ 24" 20" 91 . 1 # H-40 Weld 80 32/32 1 1 12 1/4" 9-5/8" 40# L-80 btrc 3859 31/31 3890/3558 8-1/2" 7" 26# L-80 btrc 8042 30/30 8072/7183 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKC1 at + 7044 TVDSS In this instance, this worst case surface pressure would occur with afull column of gas from the reservoir from a depth of +7044 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3589 psi is 2885 psi, well below the internal yield pressure rating of the 7" casing. MP E-19 (N) Drilling Permit 1 3/11/97 Logging Program: Open Hole Logs: Surface MWD Directional from surface to TD. Intermediate N/A Final Cased Hole Logs: Mud Logging MWD Directional from 9-5/8 shoe and LWD (GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time N/A Mud Loggers and samples are NOT required. MWD Directional: GR: EWR4: CNP: SLD: ROP: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mud Program: Special design considerations Special attention should be given to gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on E-Pad. Prior to spudding a complete review of the E-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate problems and lost time in the surface hole. HYDRATES Hydrates are present on E-Pad and must be managed safely. It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will be encountered while drilling on E-Pad. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 10.2 50 35 15 30 1 0 15 Production Mud Properties: I LSNDfreshwatermud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 10 3 7 8.5 6 - 8 to to to to to to to 10.2 50 15 10 20 9.5 4-5 MP E-19 (N) Drilling Permit 2 3/11/97 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP:300' Maximum Hole Angle: 29.9° Close Approach Well: (No Shut In Wells) Disposal: No "Drilling Wastes" will be injected or disposed into E-19 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with Pertinent rules and regulations GENERAL DISCUSSION Well Objective: MP E-19 will be drilled to aTD of 8072' md with a horizontal displacement of 3,460'. The surface casing will be shallow set above the Schrader Bluff at 3,890'md (3558' bkb) . This well is planned to intersect three targets in the Kuparuk: the C1, B7 and the A sands. MP E-19 will be completed as Kuparuk River Ct,B7, and A Sand producer. Geology The anticipated reservoir pressure for the MPE-N fault block is 3600 psi, based on the initial reservoir pressure enoourntered in MPE-13. Pressures surrounding the fault are substantially lower. Asttuctural trap exists in the MPE-N area. Faults separate the MPE-N structure from the B-6/B- 9/B-22 and A-01/A-03 areas. The OWC in the MPE-N fault block is expected at 7044' TVDss which is the same depth encounted in well MPE-13. All three Kuparuk sands should be 100% hydrocarbon bearing. DRILLING HAZARDS AND RISKS: GAS HYDRATES Hydrate sections may be encountered on E-Pad while drilling the surface hole. Mud treatments with Lecithin have minimized the adverse effects of hydrates but it's use is still not proven so its use should be carefully monitored. In spite of the apparent success's of the Lecithin treatments extreme caution is still advised. Severely gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on E-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to minimize them. Plans should be made in advance prior to spudding the surface hole to mitigate to potential risks and minimize the nonproductive time involved in managing hydrates. Some measures which are necessary to lessen to effects of gas hydrates include: 1. Increased mud weights; 2. Low drilling fluid temperatures; 3. Reduced ROP's for control drill rates; 4. Controlled circulating and drilling fluid rates; 5. Utilization of Lecithin Close Approaches There are no close approaches associated with the drilling of MP E-19, however, tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized. MP E-19 (N) Drilling Permit 3 3/1 1/97 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP:900' Maximum Hole Angle: 29.9° Close Approach Well: (No Shut In Wells) Disposal: No "Drilling Wastes" will be injected or disposed into E-19 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with Pertinent rules and regulations GENERAL DISCUSSION Well Objective: MP E-19 will be drilled to a TD of 8072' md with a horizontal displacement of 3,460' The surface casing will be shallow set above the Schrader Bluff at 3,890'md (3558' bkb) . This well is planned to intersect three targets in the Kuparuk: the C1, B7 and the A sands. MP E-19 will be completed as Kuparuk River C1,B7, and A Sand producer. Geology The anticipated reservoir pressure for the MPE-N fault block is 3600 psi, based on the initial reservoir pressure encourntered in MPE-13. Pressures surrounding the fault are substantially lower. Asttuctural trap exists in the MPE-N area. Faults separate the MPE-N structure from the B-6/B- 9/B-22 and A-01/A-03 areas. The OWC in the MPE-N fault block is expected at 7044' TVDss which is the same depth encounted in well MPE-13. All three Kuparuk sands should be 100% hydrocarbon bearing. DRILLING HAZARDS AND RISKS: GAS HYDRATES Hydrate sections may be encountered on E-Pad while drilling the surface hole. Mud treatments with Lecithin have minimized the adverse effects of hydrates but it's use is still not proven so its use should be carefully monitored. In spite of the apparent success's of the Lecithin treatments extreme caution is still advised. Severely gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on E-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to minimize them. Plans should be made in advance prior to spudding the surface hole to mitigate to potential risks and minimize the nonproductive time involved in managing hydrates. Some measures which are necessary to lessen to effects of gas hydrates include: 1. Increased mud weights; 2. Low drilling fluid temperatures; 3. Reduced ROP's for control drill rates; 4. Controlled circulating and drilling fluid rates; 5. Utilization of Lecithin Close Approaches There are no close approaches associated with the drilling of MP E-19, however, tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized. MP E-19 (N) Drilling Permit 3 3/1 1/97 Water Injection The water injection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazard or risk. Annular Injection Currently annular injection is not permitted on E-Pad. Gas Injection No gas injection wells are present on E-Pad. The gasinjection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazzard or risk. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occured while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. The losses normally occur in the Ugnu and Schrader Bluff with the shallow set surface casing design especially while cementing the 7" csg. Stuck Pipe Potential: Running gravels, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occured while drilling the 12 1-4" surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9- 5/$" casing has been stuck. While drilling the surface hole additional time has beeen spent reaming and conditioning the hole prior to cementing because of tight hole. These problems in some instances were greatly exaggerated because of measures taken to manage the gas hydrate problems. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurance has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher muds weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK SAND 7044' TVDss 3600 PSI 9.8 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKB7 at + 7044 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7044 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3589 psi is 2885 psi. The maximum expected pore pressure for this well is 9.8 ppg EMW (3,600 psi @ 7,044' TVDss). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point E-Pad Data Sheet prepared by Pete Van Dusen for information on E pad and review recent wells drilled on E Pad. MP E-19 (N) Drilling Permit 4 3/11/97 MP E-19 Kuparuk Producer Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. . Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. . Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 1300'. . Perform Two Stage cement. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP . MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/EWR4/CNP/SDL). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Revised Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 150' of production rat hole between the base of the Kuparuk B sand and PBTD before running the 7" casing. 11. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk. Displace cement with 8.4 ppg source waterand enough diesel to cover from the base of permafrost to surface (+-21 00' MD). 1 2. Test casing to 3500 psig. 13. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 1 4. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP E-19 (N) Drilling Permit 5 3/1 1/97 MP E-19 Kuparuk Producer 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON Casing Size: 9-5/8" 40# L-80 Circ. Temp 60 deg F at 2840' TVDSS. TWO STAGE CEMENT PROGRAM: Refer to the Two Stage Cementing Procedure The objective of the Surface Cement is to insure that cement is circulated to surface. Second stage lead cement shall be pumped until such time as cement is circulated to surface before switching to displacement. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface. This volume may exceed the annular capacity and the 250% estimated excess. Note: 1. The ES Cementer is located at 1300' md. 2. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. 3. Lead and Tail slurries are pumped in the first stage. 4. Only a Lead slurry is pumped in the second stage. 5. Dye shall be introduced into the fisrt few bbl. of cement of the first stage and into the water before the second stage in order to obtain an estimate of annular capacity, so that, if required additional cement can supplied and adequate excess can be pumped. 6. Once an adequate volume of cement has been circulated to surface immediately begin displacement. 7. The WELLHEAD STABILITY CEMENT will be pumped only if the cement top falls below surface after the pumps are shut down. 8. Utilize a large flow area float shoe. 9. Use weighted spacer before first stage lead slurry:(1 ppg higher than current mud weight). 1 0. Add dye in the water spacer before the second stage to assist in determining the annular volume. 1 1. Incorporate "Celloflakes" into ONLY the First Stage cement LEAD and TAIL slurries. Caution: 1. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPINGDISPLACEMENT. 2. Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurries. 3. Make preparations to handle cement to surface on the first stage circulation. 4. Make preparations to handle cement to surface on the second stage circulation. MP E-19 (N) Drilling Permit 6 3/1 1/97 First Stage: SPACER: 70 bbls NSCI weight 1 ppg higher than current mud weight. 1st LEAD CEMENT TYPE: Permafrost E ADDITIVES: 0.15#/sk Flocele WEIGHT: 12.0 ppg APPROX NO SACKS: 331 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 1st TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCI2 +.15#/sk Floceles WEIGHT: APPROX NO. SACKS: 724 FLUID LOSS: 15.8 ppg YIELD'1.15 ft3/sx MIX WATER: 4.9 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 Second Stage- SPACER; 75 bbls Water 2nd LEAD CEMENT TYPE:: Permafrost E ADDITIVES: None WEIGHT: APPROX NO SACKS: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk 6 5 7 THICKENING TIME' Greater than 4 hrs at 50° F. Wellhead Stability Cement CEMENT TYPE: Permafrost E ADDITIVES: None WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER' 11.63 gal/sk Centralizer Placement: . Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on bottom 10 joints of casing (required). 2. Install one(l) Straight Blade TURBULATOR Centralizers per joint on the 9-5/8" casing on from 2200-2700 feet to cover the top hydrate intervals (required). Place all centralizers in middle of joints using stop collars. MP E-19 (N) Drilling Permit 7 3/1 1/97 Surface Cement Volumes: , First Stage LEAD Cement Volume = Interval from1300-1929' md The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer at 1300' md to the Base of the Permafrost at 1929' md (1858 TVDbkb) + 250% EXCESS. 2~ First StageTAIL Cement Volume = Interval from 1929-3890' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the Base of the Permafrost at t929' md to surface TD at 3890' md (3558' TVDbkb) plus 30% Excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. , Second Stage LEAD Cement Volume = Interval from 0-1300 md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 1300' MD (1300' TVDbkb) to surface plus 250% excess. , The estimated Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Other Considerations: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 1 2 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. . After MPK-25 was suspended following problems with the surface casing job. The importance of getting a sucessful cement job on the suface job cannot be stressed enough. There are changes to the spacer, cement volumes and centralizer program on this well to improve the chances of getting cement to the surface. If the cement falls back, do a wellhead stability cement job. MP E-19 (N) Drilling Permit 8 3/1 1/97 MP E-19 Kuparuk Producer 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON This cement program is proposed only if the Schrader Bluff formations are NOT hydrocarbon bearing. In the event the Schrader Bluff formations proves to be hydrocarbon bearing a revised cement program will be submitted. Casing Size: 7" 26# L-80 CIRC. TEMP' 140°F BHST 170° F at 7040' TVDSS. SINGLE STAGE CEMENT JOB' Cement from TD to 1000' above KUPARUK TKUP/UD. SPACERs: 20 bbls fresh water and 70 bbls NSCI mixed per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER' 5.0 gal/sk 242 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. CEMENT VOLUME' Interval 6483-8072' md . Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: . Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, MP E-19 (N) Drilling Permit 9 3/11/97 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-1622 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPE-19 (Pll) Field ........ : Milne Point E-Pad Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.45475155 N Surface Long.: 149.43420964 W Legal Description Surface ...... : 3711 FSL 1812 FEL S25 T13N R10E UM Target ....... : 631 FSL 4227 FEL S24 T13N R10k UM BHL .......... : 764 FSL 4367 FEL S24 T13N R10E UM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 569332.77 6016250.39 566897.00 6018428.00 566755.93 6018559.19 STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPTH ANGLE AZIMUTH KB 0.00 0.00 0.00 KOP / 2/100 CURVE 300.00 0.00 265.00 400.00 2.00 265.00 500.00 4.00 265.00 CURVE 2/100 600.00 6.00 265.00 PROPOSED WELL PROFILE VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART Prepared ..... : 11 Mar 1997 Vert sect az.: 313.45 KB elevation.: 57.50 ft Magnetic Dcln: +28.178 (E) Scale Factor.: 0.99990546 Convergence..: +0.53319010 , ,ONLY 0.00 -57.50 0.00 300.00 242.50 0.00 399.98 342.48 1.16 499.84 442.34 4.63 599.45 541.95 10.41 0.00 N 0.00 E 0.00 N 0.00 E 0.15 S 1.74 W 0.61 S 6.95 W 1.37 S 15.63 W DL/ 100 700.00 7.27 278.44 800.00 8.82 287.55 900.00 10.52 293.86 1000.00 12.31 298.39 1100.00 14.15 301.77 698.79 641.29 19.06 0.89 S 27.10 W 797.80 740.30 31.14 2.35 N 40.68 W 896.38 838.88 46.64 8.35 N 56.34 W 994.40 936.90 65.53 17.11 N 74.06 W 1091.74 1034.24 87.80 28.61 N 93.84 W 569332.77 6016250.39 95L 0.00 569332.77 6016250.39 95L 0.00 569331.03 6016250.22 95L 2.00 569325.82 6016249.72 95L 2.00 569317.15 6016248.88 57R 2.00 1200.00 16.03 1300.00 17.94 304.38 1188.29 1130.79 113.41 306.45 1283.92 1226.42 142.34 569305.68 6016249.24 44R 2.00 569292.08 6016252.36 35R 2.00 569276.36 6016258.21 29R 2.00 569258.56 6016266.81 24R 2.00 569238.68 6016278.13 21R 2.00 42.85 N 115.63 W 569216.76 6016292.16 19R 2.00 59.80 N 139.42 W 569192.81 6016308.89 17R 2.00 (Anadrill (c)97 MPE19Pll 3.0C 6:51 PM P) MPE- 19 (Pll STATION IDENTIFICATION ========= ........... MEASURED INCLN DEPTH ANGLE 1400.00 19.87 1500.00 21.80 1600.00 23.75 1700.00 25.71 1800.00 27.67 END 2/100 CURVE 1894.70 29.53 BASE PERMAFROST 1929.18 29.53 CURVE 2/100 1963.66 29.53 END 2/100 CURVE 1982.64 29.90 9-5/8" CASING POINT 3890.08 29.90 NA 4726.41 29.90 OA 4882.14 29.90 OB 4957.12 29.90 BASE OB 4997.50 29.90 TOP HRZ 6970.09 29.90 BASE HRZ 7218.11 29.90 TKLB (MARKER 19) 7333.46 29.90 TKUP/(D SHALE) 7483.43 29.90 *** TARGET *** 7685.30 29.90 TKC1 7685.30 29.90 PROPOSED WELL PROFILE TKUB/B8 7702.60 29.90 TKB7 7714.14 29.90 TKB6 7742.98 29.90 TKB5 7771.82 29.90 TKB4 7812.19 29.90 DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 1378.53 1321.03 1471.98 1414.48 1564.18 1506.68 1655.01 1597.51 1744.35 1686.85 TKB3 7846.80 29.90 TKB2 7875.64 29.90 TKB1 7898.71 29.90 308.13 309.53 310.71 311.71 312.59 SECTION DEPART 11 Mar 1997 Page 2 COORDINATES-FROM WELLHEAD 174.55 79.45 N 165.18 W 209.99 101.76 N 192.87 W 248.64 126.72 N 222.46 W 290.44 154.28 N 253.92 W 335.33 184.43 N 287.20 W 313.32 1827.50 1770.00 380.66 313.32 1857.50 1800.00 397.65 313.32 1887.50 1830.00 414.64 313.45 1903.99 1846.49 424.05 313.45 3557.50 3500.00 1374.95 215.32 N 320.37 W 226.98 N 332.74 W 238.64 N 345.10 W 245.10 N 351.94 W 899.11 N 1042.20 W 313.45 4282.50 4225.00 1791.87 1185.87 N 313.45 4417.50 4360.00 1869.51 1239.26 N 313.45 4482.50 4425.00 1906.89 1264.97 N 313.45 4517.50 4460.00 1927.02 1278.82 N 313.45 6227.50 6170.00 2910.39 1955.17 N 3034.03 3091.54 3166.30 3266.94 3266.94 313.45 6442.50 6385.00 313'.45 6542.50 6485.00 313~45 6672.50 6615.00 313.45 6847.50 6790.00 313.45 6847.50 6790.00 3275.56 3281.31 3295.69 3310.07 3330.19 (Anadrill (c) 97 MPE19Pll 3.0C 6:51 PM P) 313.45 6862.50 6805.00 313.45 6872.50 6815.00 313.45 6897.50 6840.00 313.45 6922.50 6865.00 313.45 6957.50 6900.00 3347.45 3361.82 3373.32 ALASKA Zone 4 TOOL DL/ X Y FACE 100 313.45 6987.50 6930.00 313.45 7012.50 6955.00 313.45 7032.50 6975.00 2040.20 N 2079.76 N 2131.17 N 2200.39 N 2200.39 N 2206.32 N 2210.28 N 2220.17 N 2230.06 N 2243.90 N 2255.76 N 2265.65 N 2273.56 569166.88 6016328.29 15R 2.00 569138.98 6016350.34 14R 2.00 569109.16 6016375.02 13R 2.00 569077.45 6016402.29 12R 2.00 569043.89 6016432.12 llR 2.00 569010.44 6016462.70 HS 2.00 568997.97 6016474.24 HS 0.00 568985.50 6016485.79 10R 0.00 568978.60 6016492.18 HS 2.00 568282.34 6017139.68 HS 0.00 1344.86 W 567977.06 6017423.58 HS 0.00 1401.21 W 567920.22 6017476.44 HS 0.00 1428.35 W 567892.85 6017501.90 HS 0.00 1442.96 W 567878.11 6017515.60 HS 0.00 2156.81 W 567158.07 6018185.22 HS 0.00 2246.56 W 567067.54 6018269.41 HS 0.00 2288.31 W 567025.43 6018308.57 HS 0.00 2342.57 W 566970.69 6018359.47 HS 0.00 2415.63 W 566897.00 6018428.00 HS 0.00 2415.63 W 566897.00 6018428.00 HS 0.00 2421.89 W 566890.68 '6018433.87· HS 0.00 2426.06 W 566886.47 6018437.79 HS 0.00 2436.50 W 566875.95 6018447.58 HS 0.00 2446.94 W 566865.42 6018457.37 HS 0.00 2461.55 W 566850.68 6018471.07 HS 0.00 2474.07 W 566838.05 6018482.82 HS 0.00 2484.51 W 566827.52 6018492.61 HS 0.00 ANADRILL AKA-DPC- APPROVED FOP, PERMITTING ONLY 0O "?E-19 (Pll) 11 N~ar 1997 Page 3 STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE --. ,======= .............. TKUA 7921.78 29.90 TMLV 7950.62 29.90 EXPECTED OWC 7978.31 29.90 TD 8071.78 29.90 PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 313.45 7052.50 6995.00 313.45 7077.50 7020.00 313.45 7101.50 7044.00 313.45 7182.53 7125.03 SECTION DEPART ........ 3384.83 3399.20 3413.00 3459.60 COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 2281.47 N 2501.21 W 566810.68 6018508.28 HS 0.00 2291.36 N 2511.64 W 566800.15 6018518.07 HS 0.00 2300.85 N 2521.66 W 566790.05 6018527.46 HS 0.00 2332.91 N 2555.49 W 566755.93 6018559.19 0.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN (Anadrill (c)97 MPE19Pll 3.0C 6:51 PM P) SHARED SERVTCES DRTLL~N6 -, MPE-t9 (PlI) ^NADmU. ^r~-~,CVEflTIC~L SECTION VIE~ APPROVED FOR PERMITTING ~t~o~ ~: ~.4~ ,FVD Scale.' ~ inch = ]000 feet '<KB> o, ONLIt Dep Scale.' :~ inch = lO00 feet I P'.AN'#. l( i Deawn'il Nan ~997 500-- c-- ! " j ,4nadnJ]] $ch]umbengen lO00 ~ j Marker Identification ND BKB SECTN INCLN j A) KB 0 0 0 0.00 ' B) KOP / 2/100 CURVE 300 300 0 0.00 C) CURVE 2/100 600 599 lO 6.00 1500F- D) END 2/100 CURVE ~895 1827 38i 29.53 E) CURVE 2/100 ~964 1887 415 29.53 .... ~_- F] END 2/100 CURVE ~983 1904 424 29.90 2000 ......... ~'Lc'p~A~ST - i'8~ G} 9-5/8" CASING POINT 3890 3558 1375 29.90 H) ~ TARGET ~ 7685 6848 3267 29.90 I) TD 8072 7~83 3460 29.90 T 2500 I , D 3000 ~~,~[ 3500 i 4500 -U~.s~- ~'~- - _ _ i 5000 ,, ' ' \ 5500 ', ~'~. ! JJ ., 'T~:]'-HI~'Z - ~B'"' - - - ! ............................ .... ! ------ ,, .oo '~*'~*"~"'--*: :::::::::::i::::: ::::: : : ,, ...... _.........; .... · . .... · ..... . ......... ,,~ J . -:31~=~$~ ___- ___- __-_ __-_ __-_ ~__-_ [_=_=~=__--~:::= ...... = --=_~_==-,=:=-=-_~: '~ I 0 500 i000 ir - 2000 2500 3000 3500 4000 ..... ,500 5000 5500 6000 6500 ~, Section 0epan~ure ., SHARED SERVICES DRILLING i' VERTICAL SECTION VIEW Section at' 313.45 . TVD Scale.' 1 inch = 100 feet ! Bep Scale · 1 inch = 100 feet I Drawn · lJ Msr 1997 L_J~54 ..... i ..... I~ ] /~nadr3 ]] $£h]umberger I I ' Marker Identification MD BKB SECTN INCLN j ' A) *~* TARGET *~ 7685 6848 3267 29.90 I B) TD 8072 7183 3460 29.90 i . . I · I ~-~; ........... ~ .......... l- ~ % 4 _I_ ' 'T~U~/~- -m~- - _ _ ~ ] - _ Z - Z ~ Z-~ ........... Z Z - _- _l. _- _-. J t .......... r ''iiiiiiil -,~,_~ ~ .., .......... ~_ -. AIqADRIL~ , /~[q-uvc ~ APPROVi~D ~ !~1 Alii · _ 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 Sect ion Departure [~nadrill fclg7 HPEigP~ 3.0C 6:53 PN P) SHARED SERVICES DRILLIN8 I · KOP / 2/~00 CURVE 300 0 N 0 E ~ o~,v~/,oo ~oo ,~ ,~ PLAN VlE~ D) END 2/100 CURVE 1895 2~5 N 320 E) CURVE 2/100 1964 239 N 345 W CLOSURE ' 3460 feet at Azimu(h 3~2.39 F) END 2/100 CURVE 1983 245 N 352 W G) 9-5/8" CASING POINT 3890 899 N 1042 W ~DECLINATION.' +28. 178 (E) H) ~ TARGET ~ 7685 2200 N 24~6 W ,SCALE · 1 inch = 500 feet I) ID 8072 2333 N 2555 DRAWN · 11 Mar 1997 F ANADRILL A~-DPC /naCi]] Schlumberger : APPROVED FOR PERMITTING ONLY : PLAN ~ i j 2750 2250 , ~ I J ~500 , . 1250 I ' ~ ~ J 750 I i i soo I _ 250 250 6 3~50 3000 2750 ~500 2250 ~000 ~750 ~500 1250 ~000 750 500 ~50 0 ~50 <- ~EST · EAST -> (Anadri]] (c)g7 NPE~gP]! 3.0C 6:52 Pl~ P) TONY KNOWLE$, GOVERNOR ~KA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 5, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPE-19 BP Exploration (Alaska) Inc. Permit No 97-037 Sur. Loc.: 371 lqqSL, 1812'WEL, Sec. 25, T13N, R10E, UM Btmhole Loc: 578q'qSL, 4062'WEL, Sec. 24, T13N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice ma.y_?e~g_i~ven~..jzy_~acting the Commission petroleum field inspector on the North David W. Jo~-g~n ' Chairman ~ BY ORDER OF THE COMMISSION dlf/enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Envinomment Conservation w/o encl. STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type°fw°rk I-IRe-Entry []Deepen~ []Service I-I Development Gas I-ISingle Zone I-] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 57.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437~' 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3711' NSL, 1812' WEL, SEC. 25, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 449' NSL, 3931' WEL, SEC. 24, T13N, R10E MPE-19 At total depth 9. Approximate spud date Amount $200,000.00 578' NSL, 4062' WEL, SEC. 24, T13N, R10E 03/05/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 578'I No Close Approach 2560 7942' MD / 7184' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 900' Maximum Hole Angle 28.45 o Maximum surface 2885 psig, At total depth (TVD) 7044' / 3589 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btm 3786' 31' 31' 3817' 3558' 956 sx PF 'E', 712 sx Class 'G' 8-1/2" 7" 26# L-80 Btm 7912' 30' 30' 7942' 7184' 242 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary .? Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ~irn°edructi°n RECEIVED FEB 2_7 1997 Perforation depth: measured true vertical Alaska 0il & Gas Cons. Commission Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is tru~ and c~r~ect to the best of my knowledge Signed ~ d'''~ ' ,~' ' /~7/~ TimSchofie,d /~ ~r"~'~¢"f~, Title Senior Drilling Engineer Date ~__/~. ..... // Commission Use Only Permit Number I APl Numbu~ I Apg, rova~ Date I See cover letter (~ '7' 0 ~ ~ I 50- 0~- ~ ?~ '" O(~) I ~1~1 C~ ~'~I for other requirements Conditions of Approval: Samples Required [] Yes J~ No Mud Log Required [] Yes I~No Hydrogen Sulfide Measures ~,Yes .?No Directional Survey Required ]~ Yes [] No Required Working Pressure for DOPE [] 2M; []3M; ~ EM; [] 10M; [] 15M Other: 0i'Jgirla[ Signecl By by order of Approved By n,-,,;~ '~f~i lnhnefnn Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit plicate Shared Services I Type of Well Drilling Contact: Lance Spencer Well Name: IMP E-19 Well Plan Summary I Kuparuk Producer (producer or injector)' 564-5042 Surface Location' 3711 NSL 1812 WEL Sec 25 T13N R10E UM., AK Kuparuk Target Location: Bottom Hole Location' 449 NSL 3931 WEL Sec 24 T13N R101E UM., AK 578 NSL 4062 WEL Sec 24 T13N R10E UM., AK I AFE Number: J 33706~1, I J Rig: INab°rs 27-E IreD' 17,942' II TVD: 17,184' Kkb I IKBE' 153 IWell Design (conventional, slimhole, I Milne Point Ultra Slimh,,ole Longstring 9- etc.)' I 5/8", 40# Surface X 7, 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Base Permafrost 1 892 1 858 8.3 ppg, 802 psi NA 4 6 41 4 2 8 3 8.3 ppg, 1849 psi CA 4 7 9 5 4 41 8 8.3 ppg, 1907 psi CB 4 8 6 9 4 4 8 3 8.3 ppg, 1935 psi Base OB 4 9 0 9 4 51 8 8.3 ppg, 1950 psi Top HRZ 6854 6228 8.6 ppg, 2785 psi BaseHRZ 7098 6443 8.6 ppg, 2881 psi TKLB 7 21 2 6 5 4 3 9.8 ppg, 3334 psi J~' TKUP/UD 7360 6673 9.8 ppg, 3401 psi TKUC/TARGET 7555 6845 9.8 ppg, 3488 psi TKC1 7559 6848 9.8 ppg, 3490 psi;~,., TKU B/B8 7 5 7 6 6 8 6 3 9.8 ppg, 3497 psi' TKB7 7 5 8 7 6 8 7 3 9.8 ppg, 3502 psi A~.~,~.'°~s. C,~,,.. TKUA 7 7 9 2 7 0 5 3 9.8 ppg, 3594 psi ExpectedOWC 7848 7102 9.8 ppg, 3619 psi Total Depth _+7942 7184 9.8 ppg, 3661 psi Casinq/Tubing Pro!lram· Hol~ (~sg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 3786 31/31 3817/3558 8-1/2" 7" 26# L-80 btrc 7912 30/30 7942/7184 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKC1 at _+ 7044 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7044 TVDSS. The maximum anticipated surface pressure in this case assuming a MP E-19 (N) Drilling Permit 1 2/26/97 reservoir pressure of 3589 psi is 2885 psi, well below the internal yield pressure rating of the 7" casing. MP E-19 (N) Drilling Permit 2 2/26/97 Logging Program: Open Hole Logs: Surface MWD Directionalfrom sudace to TD. Intermediate N/A Final Cased Hole Logs: Mud Logging MWD Directional from 9-5/8 shoe and LWD (GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time N/A Mud Loggers and samples are NOT required. MWD Directional: GR: EWR4: CNP: SLD: ROP: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mud Program: Special design considerations Special attention should be given to gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas ~ mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on E-Pad. Prior to spudding, a complete review of the E-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate ~roblems and lost time in the surface hole. HYDRATES Hydrates are present on E-Pad and must be managed safely. It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will be encountered while drilling on E-Pad. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 10.2 50 35 15 30 10 15 Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 10 3 7 8.5 6 - 8 to to to to to to to 10.2 50 15 10 20 9.5 4-5 MP E-19 (N) Drilling Permit 3 2/26/97 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP:900' Maximum Hole Angle: 28.45° Close Approach Well: (No Shut In Wells) Disposal: No "Drilling Wastes" will be injected or disposed into E-19 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with Pertinent rules and regulations GENERAL DISCUSSION Well Objective: MP E-19 will be drilled to a TD of 7942' md with a horizontal displacement of 3,1 10'. The surface casing will be shallow set above the Schrader Bluff at 3,817'md (3558' bkb) . This well is planned to intersect three targets in the Kuparuk: the C1, B7 and the A sands. MP E-19 will be completed as Kuparuk River C1 and B7 Sand producer. Geology The anticipated reservoir pressure for the MPE-N fault block is 3600 psi, based on the initial reservoir pressure encourntered in MPE-13. Pressures surrounding the fault are substantially lower. A sttuctural trap exists in the MPE-N area. Faults separate the MPE-N structure from the B-6/B- 9/B-22 and A-01/A-03 areas. The OWC in the MPE-N fault block is expected at 7044' TVDss which is the same depth encounted in well MPE-13. All three Kuparuk sands should be 100% hydrocarbon bearing. DRILLING HAZARDS AND RISKS: GAS HYDRATES Hydrate sections may be encountered on E-Pad while drilling the surface hole. Mud treatments with Lecithin have minimized the adverse effects of hydrates but it's use is still not proven so its use should be carefully monitored. In spite of the apparent success's of the Lecithin treatments extreme caution is still advised. Severely gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on E-Pad and are directly attr.[buted to gas h~drates. In addition problems can develop as a result of measures designed to lessen ~(~effects~g-a-s.-~t~-important to recognize what problems might develop while fighting gas hydrates and have plans in place to minimize them. Plans should be made in advance prior to spudding the surface hole to mitigate~'{~ potential risks and minimize the r}~nproductive time involved in managing hydrates. Some measures which are necessary to lessen to-effects of gas hydrates include: 1. Increased mud weights; 2. Low drilling fluid temperatures; 3. Reduced ROP's for control drill rates; 4. Controlled circulating and drilling fluid rates; 5. Utilization of Lecithin Close Approaches There are no close approaches associated with the drilling of MP E-19, however, tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized. MP E-19 (N) Drilling Permit 4 2/26/97 Water Injection The water injection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazard or risk. Annular Injection Currently annular injection is not permitted on E-Pad. Gas Injection No gas injection wells are present on E-Pad. The gasinjection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazzard or risk. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occured while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. The losses normally occur in the Ugnu and Schrader Bluff with the shallow set surface casing design especially while cementing the 7" csg. Stuck Pipe Potential: Running gravels, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occured while drilling the 12 1-4" surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9- 5/8" casing has been stuck. While drilling the surface hole additional time has beeen spent reaming and conditioning the hole prior to cementing because of tight hole. These problems in some instances were greatly exaggerated because of measures taken to manage the gas hydrate problems. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurance has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher muds weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK SAND 7044' TVDss 3600 PSI 9.8 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKB7 at _+ 7044 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7044 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3589 psi is 2885 psi. The maximum expected pore pressure for this well is 9.8 ppg EMW (3,600 psi @ 7,044' TVDss). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point E-Pad Data Sheet prepared by Pete Van Dusen for information on E pad and review recent wells drilled on E Pad. MP E-19 (N) Drilling Permit 2/26/97 MP E-19 Kuparuk Producer Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. , Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. . Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 1300'. . Perform Two Stage cement. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP . MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/EWR4/CNP/SDL). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Revised Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 150' of production rat hole between the base of the Kuparuk B sand and PBTD before running the 7" casing. 11. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk. Displace cement with 8.4 ppg source waterand enough diesel to cover from the base of permafrost to surface (+ - 2 1 0 0' MD). 1 2. Test casing to 3500 psig. 13. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 1 4. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP E-19 (N) Drilling Permit 6 2/26/97 MP E-19 Kuparuk Producer 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON Casing Size: 9-5/8" 40# L-80 Circ. Temp 60 deg F at 2840'TVDSS. TWO STAGE CEMENT PROGRAM: Refer to the Two Stage Cementing Procedure The objective of the Surface Cement is to insure that cement is circulated to surface. Second stage lead cement shall be pumped until such time as cement is circulated to surface before switching to displacement. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface. This volume may exceed the annular capacity and the 250% estimated excess. Note: 1. The ES Cementer is located at 1300' md. 2. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. 3. Lead and Tail slurries are pumped in the first stage. 4. Only a Lead slurry is pumped in the second stage. 5. Dye shall be introduced into the weighted spacer before the first stage and into the water before the second stage in order to obtain an estimate of annular capacity so that if required additional cement can supplied and adequate excess can bepumped. 6. Once an adequate volume of cement has been circulated to surface immediately begin displacement. 7. The WELLHEAD STABILITY CEMENT will be pumped only if the cement top falls below surface after the pumps are shut down. 8. Utilize a large flow area float shoe, 9. Use weighted spacer before first stage lead slurry:(1 ppg higher than current mud weight). 1 0. Add dye in the water spacer before the second stage to assist in determining the annular volume. 1 1. Incorporate "Celloflakes" into ONLY the First Stage cement LEAD and TAIL slurries. Caution: 1. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPINGDISPLACEMENT. 2. Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurries. 3. Make preparations to handle cement to surface on the first stage circulation. 4. Make preparations to handle cement to surface on the second stage circulation. MP E-19 (N) Drilling Permit 7 2/26/97 First Stage: SPACER: 70 bbls NSCI weight 1 ppg higher than current mud weight. 1st LEAD CEMENT TYPE: Permafrost E ADDITIVES: 0.15#/sk Flocele WEIGHT: 12.0 ppg APPROX NO SACKS: 299 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 1st TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCl2 +.15#/sk Flocele 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 4.9 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREEWATER: 0 WEIGHT: APPROX NO. SACKS: 712 FLUID LOSS: Permafrost E Second Stage. SPACER: 75 bbls Water 2nd LEAD CEMENT TYPE" 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk 6 5 7 THICKENING TIME: Greater than 4 hrs at 50° F. ADDITIVES: None WEIGHT: APPROX NO SACKS: Wellhead Stability Cement CEMENT TYPE: Permafrost E YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk ADDITIVES: None WEIGHT: 12.0 ppg APPROX NO SACKS: 150 Centralizer Placement: . Install one(l) Straight Blade TURBULATOR Centralizers per joint of 9-5/8" casing on bottom 10 joints of casing (required). . Install one(l) Straight Blade TURBULATOR Centralizers per joint on the 9- 5/8" casing on from 2200-2700 feet to cover the top hydrate intervals (required). Place all centralizers in middle of joints using stop collars. MP E-19 (N) Drilling Permit 8 2/26/97 Surface Cement Volumes: , First Stage LEAD Cement Volume = Interval from1300-1892' md The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer at 1300' md to the Base of the Permafrost at 1892' md (1858 TVDbkb) + 250% EXCESS. . First StageTAIL Cement Volume = Interval from 1892-3817' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the Base of the Permafrost at 1803' md to surface TD at 3817' md (3558' TVDbkb) plus 30% Excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 3~ Second Stage LEAD Cement Volume = Interval from 0-1300 md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 1300' MD (1300' TVDbkb) to surface plus 250% excess. . The estimated Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Other Considerations: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 1 2 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary, 2. After MPK-25 was suspended following problems with the surface casing job. The importance of getting a sucessful cement job on the suface job cannot be stressed enough. There are changes to the spacer, cement volumes and centralizer program on this well to improve the chances of getting cement to the surface. If the cement falls back, do a wellhead stability cement job. MP E-19 (N) Drilling Permit 9 2/26/97 MP E-19 Kuparuk Producer 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON This cement program is proposed only if the Schrader Bluff formations are NOT hydrocarbon bearing. In the event the Schrader Bluff formations proves to be hydrocarbon bearing a revised cement program will be submitted. Casing Size- 7" 26# L-80 CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. SINGLE STAGE CEMENT JOB: Cement from TD to 1000' above KUPARUK TKUP/UD. SPACERs: 20 bbls fresh water and 70 bbls NSCI mixed per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 242 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. CEMENT VOLUME: Interval 6360-7942' md . Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: , Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary, MP E-19 (N) Drilling Permit 10 2/26/97 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPE-19 (Pg) Fie] ! ........ : Milne Point E-Pad Computation..: Minimum Curvature Unitg ........ : FEET Surface hat..: 70.45475155 N Surface Long.: 149.43420964 W Legal Description Surface ...... : 3711 FSL 1812 FEL S25 T13N R10E UM Tie-in survey: 3711 FSL 1812 FEL S25 T13N R10E UM TARGET ....... : 449 FSL 3931 FEL S24 T13N R10E UM BHL .......... : 578 FSL 4062 FEL S24 T13N R10E UM LOCATIONS - ALASKA Zone: X-Co0rd 569332.77 569332.77 567195.00 567063.21 4 ¥-Coord 6016250.39 6016250.39 6018248.00 6018376.65 PROPOSED WELL PROFILE Prepared ..... : 19 Feb 1997 Vert sect az.: 314,84 KB elevation.: 57.50 ft Magnetic Dcln: +28.180 (E) Scale Factor.: 0.9999h~46 Convergence..: +o.s3]z,OI~ADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN STATION MEASURED INCLN DIRECTION IDENTIFICATION DEPT~ ANGLE AZIMUTH Tie-in KOP BUILD 2/100 600.00 0.00 265.00 900.00 2.00 265.00 800.~0 4.00 265.00 START 2/100 CURVE 900.00 6,00 265,00 1000.00 7.22 278,86 ll0O.00 8,73 288.35 1200.00 10.41 294.93 1300.00 12.18 299.67 1400,00 14.02 303.20 1500.00 15.89 305.92 VERTICAL-DEPTMS SECTION COORDINATES-FROM ALASKA Zone 4 TOOL Db/ T~D SUB-SEA DEPART WELLHEAD X Y FACE 100 33.00 -24.50 0.00 0.00 N 0,00 E 569332.7~ 6016250.39 95L <TIE 600.0D 542.50 0,00 0,00 N Q.00 E 569]32.77 6016250.39 95L 0.00 699.98 642.48 1.13 0,15 S 1,74 W 569331,03 6016250.22 95L 2.00 799,8~ 742.34 4,50 0.61 S 6.95 W 569325,82 6016249.72 95L 2.00 899.45 841.95 10.12 1.37 S 15.63 W 569317,15 6016248.88 60R 2'.00 998.79 941.29 18.58 0.86 S 27.05 W 569305.73 60162~9.28 46R 2.00 1097.83 1040.33 30.46 2.50 N 40.47 W 569292.29 6016252.51 36R 2.00 1196.43 1138,93 45.74 8.70 N 55.86 W 569276.83 6016258.57 30R 2.00 1294.49 1236,99 64.42 17.73 N 73.23 W 569259.39 6016267,44 25R 2,00 1391.89 1334.39 86.47 29.59 N 92,53 W 569239,98 6016279.11 22R 2.00 1488.50 1431.00 111.86 44,25 N 113.75 W 569218.62 6016293.57 ~gR 2.00 (Anadrill (c)97 MP£19P9 3.0C i:20 AM P) STATION MEASURED INCLN IDENTIFICATION DEPTN ANGLE 1600.00 17.79 1700.00 19.71 1800.00 21,64 END 2/100 CURVE 1859.46 22.80 BASE PERMAFROST 1892.01 22.80 START 2/100 CURVE 1924.55 22.80 2000.00 24.27 2100.00 26.22 2200.00 28.18 END 2/100 CURVE 2213,80 28.45 2213.81 28.45 SURFACE CASING 3816.74 28.45 NA 4541.36 28.45 OA 4794.91 28.45 OB 4868.84 28,45 PROPOSED WELL PROFILE DIKECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 308.07 1584.21 1526.71 309.82 1678.90 1621.40 311.27 1772,45 1714.95 312.02 1827.50 1770.00 312,02 1857.50 1800.00 SECTION DEPART 140.55 172,52 207.73 230,18 242.78 312.02 1887.50 1830.00 255.37 312,88 1956.68 1899.18 285.47 313,87 2047.12 1989.62 328,10 314.73 2136.06 2078.56 373.81 314.84 2148.20 2090.70 380.36 314.84 2148.21 314.84 3557.50 314,84 4282.50 314.84 4417.50 314.84 4482.50 2090,71 380.36 3500.00 1144.09 4225.00 1536.99 4360.00 1610.15 4425,00 1645.38 BASE OB 4908.65 28.45 314.84 4517.50 4460.00 1664.35 TOP HRZ 6853.61 28.45 314,84 6227.50 6170.00 2591.04 BASE HRZ 7095.15 28,45 314.84 6442,50 6385.00 2707.56 7155.38 28,45 314,84 6492.82 6435.32 2734.8'3 TKLB (MARKER 19} 7211.89 28,45 314.84 6542.50 6485.00 2761.75 TKUP/(D SHALE) 7359.75 28.45 *** TARGET 0'* 7555.38 28.45 TKC1 7558.80 28.45 TKUB/B8 7575,86 28,45 TKB7 7587.23 28.45 TKB6 7615.67 28,45 TKB5 7644.10 28.45 TKB4 7683,91 29,45 [k~adrtll (¢)97 MPE19P9 3.0C 8:20 AM P) 314.84 6672.50 314.84 6844.50 314.84 6847.50 314.84 6862.50 314.84 6872.50 314.84 6897.50 314.84 6922.50 314.84 6957,50 6615.00 2832.20 6787,00 2925.41 6790.00 2927.04 6805,00 2935.17 6815.00 2940.59 6840.00 2954.14 6865.00 2967.68 6900,00 2986.65 COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 61.70 N 136.87 W 569195~35 6~16310.81 81.92 N 161.85 W 569170.18 6016330.80 104.89 N 188.66 W 569143.16 6016353.51 119.83 N 205,46 W 569126,22 6016368.30 128.28 N 214.83 W 569116.78 6016376.65 TOOL DL/ FACE 100 17R 2.00 16R 2.00 14R 2.00 HS 2.00 HS 0.00 136.72 N 224.19 W 569107.33 6016385.00 13R 0.00 157.05 N 246.42 W 569084.92 6016405,13 13R 2.00 186.35 N 277.41 W 569053.67 6016434.13 12R 2.00 218.28 N 310.12 W 569020.67 6016465.76 11R 2.00 222,90 N 314.76 W 569015.98 6016470,33 HS 2.00 222.90 N 314.76 W 569015.98 6016470.33 HS 2.00 761,47 N 856.28 W 568469.53 6017003.78 HS 1038.53N 1134.85 W 568188.41 6017278.22 HS 0.00 1090.12 N 1186.73 W 568136.06 6017329.~2 HS . 0.00 1114.96 N 1211.70 W 568110.86 6017353.92 HS 0.00 1128.33 N 1225.15 W 568097,29 6017367.17 HS 0.00 1781.82 N 1882,21 W 567434.24 6018014.45 BS 0.00 1863.98 N 1964.82 W 567350,87 6018095.83 HS 0.00 1883.21 N 1984.16 W 567331,36 6018114,8~ HS 1902.20 N 2003.25 W 567312.10 6018133.69 HS 0.00 1951.88 N 2053.20 W 567261:69 6018182.89 HS 0.00 2017.61 N 2119.29 W 567195.00 6018248.~0 HS 0.00 2018.76 N 2120.44 W 567193.84 6018249.14 HS 0.00 2024.49 N 2126.'20 W 2028.31 N 2130.05 W 2037.86 N 2139.6~ 2047,42 N 2149.2( 2060.79 N 2162.7] 567188.02 6018254.81 HS 0.00 567184.14 601825~,~Q, HS ~_~0 ..... ANADRILL AKA-DPC 567174.4 W O E D o.oo 567164 76 H 0.00 PLAN 9 .. ',,I O C~ II ',,I 0 STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE TKB3 7718.03 28.45 TKB2 7746.47 28.45 TK81 7769.21 28.45 TK/3A 7791.96 28.45 TMLV 7820.40 28.45 EXFP iTED OWC 7847.70 28.45 TD 7941.96 28.45 PROPOSED WELL DIRECTION VERTiCAL-DEPTHS AZIMUTH T%;D SUB-SEA ]14.84 6987.50 6930.00 ~1~.84 7012.50 6955.00 ~14.84 7032.50 6975.00 ~14.84 7052.50 6995.00 ~14.84 7077.50 7020.00 ~14.84 7101.50 7044.00 314.84 7184.38 7126.88 SECTION COORDINATES-FROM Ai~KA Zone 4 TOOL DL/ DEPART WELLHEAD X Y FACE 3002.91 2072.26 N 2174.24 W 567139.55 6018302.13 ~S 0.00 3016.46 2081.81 N 2183.84 W 567129.86 6018311.59 ~S 0.00 3027.30 2089.45 N 2191.53 W 567122.10 6018319.16 HS 0.00 3038.13 2097.10 N 2199.21 W 567114.35 6018326.73 ~S 3051.68 2106.65 N 2208.82 W 567104.65 6018336.20 HS 0.00 3064.69 2115.82 N 2218.04 W 567095.35 6018345.28 ~S 0.00 3109.60 2147.50 N 2249.89 W 567063.21 6018376.65 0.00 O ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # 9 {Anadrlll (c)97 MPE19P9 3.0C 8:20 AM P) Feb-19-97 08:38A Anadrill DPC 907 344 2160 P.O5 MPE-19 (Pg) VERTICAL SECTION VIE~ iSection at: 314.84 TVD Sca]e.' ! inch = ~000 feet Dep Scale · I inch = ~000 feet : ~' i A-- ' : ' Dr~wn ..... : lg Feb 1997 t ..... }¢" ' ....... ~ ' ~ ~ ~ ' i ~'- " I ~l Anao/r~]] Scl~]umDerger ,, . i i I ~anl(er' Iclent~ficatio~ MD BKB ~CTN INCLN ~ C~- : :[ I ~ C) START 2/100 CURVE 900 899 ~0 6.00 . I : D] END 2/~00 CURVE t859 t827 230 22.80 t-~q ....... [ E) START 2/100 CURVE ~925 1BB7 255 22.80 ...... i ~ ' F) E~ 2/100 CURVE 2214 2148 3BO 28.45 ' ~ '.','" i ~~'~r'~ .... G) SURFACE CASING 3817 3558 t144 28.45 ~ : : ~ I I H) ~ TARGET ~ 7555 6844 2925 28.45 ' F ~ j [} TO 7942 7184 3~t0 28.45 i , ~ .............. ~ ~ ..................... ~ ~ ~ j J , ~ j ' j ~ ' ' ~ .......... I ~KA-D~C ; ~ ~' i j ~ ANABRILL , ,' ' .......... ',,-~:¢---1 ..,...¢ ........... L ' , ~.,~...,. ,0, ,,,,,,,,,,,,,,,, ~,,,,, ~,,--.,...,,~,,, ~,,,,,. ....... ... ,,,, _..,,,,.,.,,, . . ~ ..... ~ ...................... , ............. ~ - -looo -500 0 500 ~000 moo 2000 2500 3000 3500 4000 4500 5000 5500 6000 _ ___ Secti°n Departure __ Feb-19-97 08:38A Anad~ill DPC 907 344 2160 P.06 mm I I'' S~)kRED SERVICES DRILLING i m ii m I i m j mm II Im I I I mi ...... ~rker Identkficatkon ~0 ,~. ~,,. ,~, MPE-19 (P9) A) )** TARGET **. 75~ 6844 ~. 28.45 ,~ ~o ~,~ 7~, ~o ~..,s VERTICAL SECTION VIEW ill i i i Sect ion at: TVD Scale.' I ~nch = 200 feet Dep Scale.' ~ ~ncb = 200 ~eet ~ooo............ ) i I Drawn ' 19 Feb ~997 6100 ..... [ ............... ~ ...... , .... 6200 ' I .... ~'~ ......... F'" ; , · .......... i , ~ ........... ~ ....... ~ .... .... , . ~ ........... ~ ...~ '~ )- '~73 - -.~ , - ....................... 6800'6700 ......... "~ [~21~~., ,~~~ -~ ' ~ .......... ~ ti ........... I ~ i,~~'~- 7000 '~ ' ~ wm-~r ..... ' .......... ~ ~ , . i. ,~r - ~ ..... ~::]:: ---.... ~ :::::~::: , :'-:--- ..., ............ · ,~ - ~ ....... ::::: ~ ....... , ..... _ . __~ 7~00 ...... ~ [ .... ~ _ 7400 , .~ I I r 7500 ........... ~ ..... ] ......................... ~_.. 2200 2300 2400 ~500 ~600 2700 ~800 ~900 3000 3100 3200 3300 3400 3500 3600 , Section Oepactur~, SHARED SERVT.CES DR,.ILLING ........ I._ AnadrJ ]1 Sch]umberger , [ ! . _ ]1 [ i MPE- 9(P9) PLAN VIEW · , ii CLOSURE ' 3110 feet at Azimuth 313.67 , .................. ! .... i~ARGET (R,tdius 10( feet ) ' , I DECLINATION.: +28.180 (E) ' i~-~ ISCALE ....... : 1 inch : 400 feet I ... ~ , . . IDRAWN ....... : 19 Feb 1997 ~-- ¢ 1, i . - [ -- Marker ¢If~e-in KOP BUILD Identif2/t00 icat~an 600 MD 33 N/S ON ON E/~ O E O E J C) START 2/,00 CURVE 900 I ~ ~ .... ~ D) ENO 2/100 CURVE 1859 120 N 205 N ~ ~ ... ' E) START 2/100 CURVE 1925 137 N 224 ' I ~ F) END 2/100 CURVE 2214 223 N 315 W ; G) SURFACE CASING 3B~7 761 N 856 W ~ ~ ~ j ~ I ~ ~ J , i I. i i ._.i ~ j 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 <- NES7 · EAST -> II I _ Il I II II Il (Anadri]] {cig7 NPE$gP9 3.0C 8:~ ~H PI WELL PERMIT CHECKLISTco. Y ~.~,o ~ ~ooL °LASS D~. 1-o,7 ~.o~. ~A PROGRAM: exp[] dev ~redrlD serv[] wellbore segD ann disp para req~ ADMINISTRATION REMARKS 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. · 6. Well located proper distance from other wells ...... DATE 7. 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval. . 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR DATE Sufficient acreage available in drilling unit ...... · Conductor string provided 14 ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf cng. CMT vol adequate to tie-in long string to surf cng . . 17. 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~ 31. Data presented on potential overpressure zones ..... ~~' Seismic analysis of shallow gas zones ......... ~ ~ 32.33. Seabed condition survey (if off-shore) ...... /- ~ ~ 34. Contact name/phone for weekly progress reports · ./~ · . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: JDH ~'~-- mcm~~~ Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01/97 WELL PERMIT CHECKLISToo~Y ~.~,D ~ Poo~. S-2 ~ d ~N~ CLASS WELL NAME ~~ ~F/p__/~_ /~ PROGRAM: expo dev [] redrlD servO wellbore segO ann disp para reqO c) ~ G~.oL A~A ~ 0 ~N~# I' t 3 o%~° ON~O~'~ S~O~ ~ ADMINISTRATION ENGINEERING GEOLOGY DATE 1. Permit fee attached ................... ~ N 2. Lease number appropriate ................ ~ N 3. Unique well name and number ............... ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary. . ~ N 6. Well located proper distance from other wells ...... ~ N 7. Sufficient acreage available in drilling unit ...... ~ N 8. If deviated, is wellbore plat included ......... ~ N 9. Operator only affected party .............. .~ N 10. Operator has appropriate bond in force ......... ~' N 11. Permit can be issued without conservation order ..... ~ N 12. Permit can be issued without administrative approval. . ~ N 13. Can permit be approved before 15-day wait ........ ~ N BOPE press rating adequate; test to ~~ psig Choke manifold complies w/API RP-53 (May 84) ...... Work will occur without operation shutdown ....... Is presence of ~2S gas probable ............ 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. ~ N 17. CMT vol adequate to tie-in long string to surf csg .~''. Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ .~ N __ ^_ 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed ......... · 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. 27. 28. 29. N 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential over~ ~. '~.. y !~[ 32. Seismic analysis of ~ones. ......... Y 33. Seabed co~y (if off-shore) ......... Y 34. Co ame/phone for weekly progress reports ..... Y N [exploratory only] REMARKS GEO___LO~: ENGINEERING: COMMISSION: ~ JD_H~' mcm Comments/Instructions: HOW/dlf - A:\FORMS\cheklist rev 01/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : MPU E- 19 FIELD NAME : MILNE POINT BOROUGH '. NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22746-00 REFERENCE NO : 97181 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 15:29 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC REEL NAME : 97181 CONTINUATION # : PREVIOUS REEL : COI~4~2~f : B.P. EXPLORATION, MPU E-19, MILNE POINT, API #50-029-22746-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC TAPE NAME : 97181 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~NT : B.P. EXPLORATION, MPU E-19, MILNE POINT, API #50-029-22746-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NA~iE: MPU E-19 API 1VUM~ER: 500292274600 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 7-MAY-97 JOB NUMBER: 97181 LOGGING ENGINEER: JOHN MAJCHER OPERATOR WITNESS: MARK OMALLEY SURFACE LOCATION SECTION: 25 TOWNSHIP: 13N ~GE: 10E FNL: FSL : FEL : FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 58.50 GROUND LEVEL: 24.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 7. 000 8247.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 15:29 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: NONE LDWG CURVE CODE: NONE RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ RE~gRKS : THIS IS THE PDC LOG FOR THIS WELL, FROM A GR/CCL LOGGED BY SCHLUMBERGER ON 14-APR-97. NO DEPTH CORRECTIONS WERE MADE. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE · 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]MBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS1W3MBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~zARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8154.0 3888.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RE~ARKS: THIS IS THE CLIPPED DATA FROM THE PDC GR (GR/CCL) LOGGED 14-APR-97 BY SCHLUMBERGER. LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 15:29 PAGE: 3 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 557834 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 557834 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 557834 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 557834 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8154.000 GRCH. GR -999.250 TENS.GR 2498.000 CCL.GR DEPT. 3888.000 GRCH. GR 25.873 TENS.GR 1389.000 CCL.GR -999.250 -0.042 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 15:29 PAGE **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE - 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS ~ER : 1 DEPTH INCRt~4ENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8170.0 3887.0 GRCH $ LOG HEADER DATA DATE LOGGED: 14-APR-97 SOFTWARE VERSION: 8C0 - 609 TIME LOGGER ON BOTTOM: 1013 14-APR-97 TD DRILLER (FT) : 8164.0 TD LOGGER (FT) : 8154.0 TOP LOG INTERVAL (FT) : 3887.0 BOTTOM LOG INTERVAL (FT) : 8149.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): TOOL NUMBER ........... SGTL 8.500 8247.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 15:29 PAGE: LOGGERS CASING DEPTH (FT) '. BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER/DIESEL NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE .COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS) : NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG ~SURED FROM DFE 58.55 FT. PRIMARY DEPTH CONTROL IS MAGNETICALY MARKED LINE. LIS FORMAT DATA R.BATES, D. BLODGETT. * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 15:29 PAGE '. 6 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 557834 O0 000 O0 0 2 1 1 4 68 0000000000 GR GR GAPI 557834 O0 000 O0 0 2 1 1 4 68 0000000000 TENS GR LB 557834 O0 000 O0 0 2 1 1 4 68 0000000000 CCL GR V 557834 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8170.000 GR.GR 21.286 TENS.GR 2116.000 CCL.GR DEPT. 3887.000 GR.GR 27.062 TENS.GR 1365.000 CCL.GR O. 001 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE - FLIC VERSION ' O01CO1 DATE · 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 15:29 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC TAPE NAME : 97181 CONTINUATION # : 1 PREVIOUS TAPE : COF~IENT : B.P. EXPLORATION, MPU E-19, MILNE POINT, API #50-029-22746-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE ' 97/05/ 7 ORIGIN : FLIC REEL NAM~ : 97181 CONTINUATION # : PREVIOUS REEL : COF~FJVT : B.P. EXPLORATION, MPU E-19, MILNE POINT, API #50-029-22746-00 · Sperry-Sun Drilling Services LIS Scan Utility Mon Jun 30 12:48:10 1997 Reel Header Service name ............. LISTPE Date ..................... 97/06/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97,/06/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-H~-70067 A. PIEPER J. PYRON 1ST STRING Date MPE-19 500292274600 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 30-JUN-97 MWD RUN 3 AK-MM-70067 M. HALL J. PYRON 25 13N 10E 3711 1812 .00 58.50 24.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) JUL 0 2 Oil & Gas Cons. Commission 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 20.000 112.0 12.250 9.625 3955.0 8.500 8280.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8280'MD, 7336'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 800 PPM. MUD WEIGHT = 8.6 - 10.2 PPG. FORMATION WATER SALINITY = 14545 PPM. FLUID DENSITY = 1.0 G/CC. MATRIX DENSITY = 2.65 G/CC. LITHOLOGY = SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEFTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE DRHO RHOB FCNT NCNT NPHI FET RPD RPM RPS RPX GR PEF ROP $ START DEPTH 3951.5 3951.5 3951.5 3951.5 3951 5 3951 5 3951 5 3951 5 3951 5 3951 5 3951 5 3952 0 3965 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 3951 5 3957 5 3965 5 3972 5 3974 0 3978 0 3982 0 3983 5 3985 0 3986 5 3988 0 3990 5 3992 5 3998 5 4003 0 4006 5 4008 5 4013 0 4015 5 4017 5 4018 5 4020 5 4022 0 4024 5 4027.5 4037.5 4040.5 4043.5 4051.0 4056.0 4068 5 4072 5 4078 5 4081 5 4100 5 4102 0 4105 5 4107 0 4110.5 4114.0 4116.5 4119.0 4133.5 4141.0 GR 3955 0 3961 0 3970 5 3977 0 3979 0 3983 0 3988 0 3989 5 3991 0 3993 0 3994 0 3996 0 3998 0 4005 0 4007 0 4011 0 4014 5 4019 0 4021 5 4023 5 4024 5 4026 5 4027 5 4030 0 4033 5 4044 5 4048 0 4051 0 4057.0 4062 5 4073 0 4077 0 4083 5 4086 0 4104 5 4106 5 4110 0 4112 0 4114 5 4119 0 4121 5 4123 5 4138 5 4145 0 STOP DEPTH 8215.5 8215.5 8180.5 8180 5 8180 5 8206 5 8206 5 8206 5 8206 5 8206 5 8226 5 8215 5 8284 5 EQUIVALENT UNSHIFTED DEPTH -- 4147 0 4149 5 4152 0 4155 0 4176 0 4182 5 4186 0 4192 5 4195 0 4197 5 4199.5 4202.5 4207.0 4220.0 4224.5 4226.5 4232.0 4233.5 4246.5 4249.0 4250.5 4287.5 4289.0 4324.5 4326.5 4331.0 4343.0 4344.5 4361 0 4362 5 4380 0 4388 5 4391 0 4394 5 4400 5 4402 5 4404 5 4411.5 4419.5 4429.0 4431.0 4436.0 4442 0 4490 5 4503 0 4546 0 4550 5 4556 5 4560 5 4567 0 4572 0 4579 5 4596.0 4615.5 4618.0 4630.0 4633.0 4655.0 4660.5 4666.5 4668.0 4670.5 4673.0 4675.5 4152.0 4154.5 4156.5 4158.5 4179.5 4185.0 4188.0 4196.0 4199.0 4201.0 4202.5 4205.5 4210.5 4222.0 4227.5 4231.0 4235.0 4236.5 4251.0 4253.5 4254.5 4291.0 4292.5 4329.0 4330.0 4335.0 4348.5 4350.5 4363.5 4365.0 4384.0 4393.0 4396 0 4398 0 4404 0 4406 0 4408 0 4413 5 4422 5 4432 5 4434 5 4439 0 4445 0 4493 5 4505 0 4551 5 4556 5 4561 0 4564 0 4570 5 4576 5 4584 0 4602 0 4619 0 4621 5 4633 0 4636 0 4658 5 4663 0 4669 5 4671 0 4673 0 4675 5 4678 5 4686.5 4687.5 4692 5 4694 5 4695 5 4697 0 4699 0 4701 0 4706 0 4708 0 4718.0 4720 0 4730 0 4736 5 4740 0 4776 0 4792 5 4798 0 4801 5 4825 0 4828 0 4831 0 4842 5 4846 5 4850 0 4852 5 4856 0 4894 5 4905.5 4937.5 4941.0 4946.0 4949.0 4960.0 4962.0 4964.0 4973.0 4975.0 4995. 0 5008.5 5011.0 5013.0 5016.5 5019.0 5022.5 5034.5 5118.5 5166.5 5174.0 5177.5 5184.0 5187.0 5192.5 5221.0 5336 5 5342 5 5344 0 5348 0 5367 5 5370 0 5373 5 5375 0 5390 0 5416 0 4689.5 4690.0 4696.5 4698.0 4699.0 4700.0 4701.5 4703.5 4707 0 4710 0 4718 5 4720 5 4732 5 4738 5 4743 5 4778 0 4793.0 4799 5 4802 5 4826 0 4830 0 4832 5 4843 0 4848 0 4852 0 4854 0 4856 5 4896 5 4907 0 4939 5 4943 5 4948 0 4951 5 4961 5 4963 5 4965 5 4975 0 4977 0 4995 5 5010 5 5012 0 5015 5 5019 0 5021 5 5024 5 5036 5 5121 0 5169 5 5178 0 5179 0 5185 5 5189 5 5193 0 5223 0 5338.0 5347 5 5350 0 5351 0 5371 0 5373 0 5374 5 5376 0 5389 5 5416 5 5419.5 5606.5 5608.5 5610.5 5670. 0 5672.0 5674.5 6332.0 6334.5 6335.5 6337. 0 6338. 0 6374.5 6375.5 6623.5 6624.5 6673.0 6677 5 6696 5 6698 5 6810 5 6813 0 6814 5 6819.5 6823.5 6827.0 6828.0 6830.0 6832.0 6833.5 6835.5 6837.0 6840.0 6841.5 6848.5 6850.5 6895.5 6911. 0 6938.5 6947.0 7031 5 7033 5 7035 5 7164 5 7166 0 7167 5 7172 0 7174 0 7175 5 7177 0 7179 5 7236 5 7238 5 7241 5 7244 0 7245 0 7247 0 7249 0 7259 5 7266 0 7269.0 7271.0 7274. 0 7275.5 5419 0 5610 0 5612 0 5613 5 5669 0 5671 5 5673 0 6334 0 6336.0 6337.5 6339.0 6340.0 6376.5 6377.5 6627.0 6628.0 6673.5 6677.0 6694.5 6696.5 6809.0 6813.0 6814.5 6817.5 6820.5 6823.5 6826.5 6828.0 6829.5 6831.0 6834.5 6836.0 6838.0 6839.0 6850.5 6852.5 6897.5 6913.0 6936.5 6944.5 7030.0 7031.0 7033 5 7160 5 7162 5 7164 0 7169 0 7170 0 7171 5 7173 5 7176 0 7231 0 7232 0 7235 0 7239 0 7240 0 7242 5 7244 0 7253 5 7259 5 7263 0 7265 5 7267 0 7269 5 7278 5 7280 5 7284 0 7288 0 7290 5 7291 5 7294 5 7298 0 7316 0 7317 5 7320 5 7322 5 7323 5 7324.5 7327.0 7329.5 7332.5 7334.0 7338.0 7340.0 7341.0 7343 5 7344 5 7347 0 7351 0 7352 5 7355 0 7358.5 7359.5 7360.5 7362.0 7366 5 7369 0 7371 0 7373 0 7374 5 7380 0 7382 0 7386 0 7390 0 7391 5 7394 5 7395 5 7396 5 7399 0 7400 5 7427 5 7429 0 7492.0 7494.5 7496.0 7497.0 7502.0 7504 0 7506 5 7512 5 7514 0 7520 0 7528 5 7531 5 7533.0 7534.5 7541.0 7544.5 7271.5 7273.5 7277.0 7281.5 7283 5 7284 5 7287 5 7290 5 7312 0 7313 5 7316.0 7317.0 7318 5 7320 0 7322 0 7325 5 7328 0 7329 5 7333.5 7335.5 7336.5 7338.5 7340.0 7342.5 7346.5 7348.0 7350.0 7352.5 7354.5 7356.0 7358.5 7362.0 7364 0 7366 5 7367 5 7370 0 7376 0 7378 5 7382.5 7386.0 7387.5 7389.5 7390.5 7391 5 7393 0 7395 0 7423 5 7424 5 7487 5 7489 5 7491 0 7492 5 7497 0 7498 5 7501 0 7509 5 7511 5 7516 0 7525 0 7527 0 7528 5 7529 5 7536 5 7540 0 7546.0 7547.0 7548.5 7554.0 7558.0 7569.5 7571 0 7573 5 7575 5 7576 5 7577 5 7587 0 7589.0 7592 0 7594 5 7596 5 7597 5 7600 0 7604 0 7605 5 7606.5 7608 0 7644 5 7646 5 7647 5 7649 5 7650 5 7655 0 7671 5 7673.5 7719.5 7722.5 7732.0 7733.5 7749.0 7750.0 7751.5 7769.5 7771.0 7780.0 7781.5 7783.0 7787 5 7789 5 7801 5 7804 5 7807 5 7812 0 7814 0 7817 0 7835 5 7837.0 7838 5 7840 5 7857 5 7858 5 7859 5 7870 5 7873 0 7873.5 7884.0 7886.0 7887.5 7991.5 7541.5 7542.5 7544.0 7549.5 7553.0 7565.0 7567.0 7568.5 7570.5 7572.0 7573.0 7583.0 7586.0 7587.5 7589 5 7593 5 7595 0 7597 0 7599 5 7601 0 7602.0 7603.5 7639.5 7642.0 7642.5 7645.0 7646.0 7651.0 7667.0 7668.5 7717.0 7718.0 7727.5 7729.0 7744.5 7745.0 7746.5 7765.0 7766.5 7775.5 7777.0 7778.5 7782.5 7784 0 7798 5 7799 5 7801 0 7807 0 7809 5 7812 0 7831 5 7832 5 7834 0 7836 5 7853 5 7854 5 7856 0 7865 0 7868 0 7868 5 7879 5 7881 5 7883 5 7988 5 7995.0 7992.0 7999.0 7995.5 8001.5 7997.5 8085.0 8081.0 8086.5 8082.0 8100.5 8096.5 8130.0 8127.5 8133.5 8130.0 8135.0 8131.0 8138.5 8134.5 8141.0 8136.5 8142.0 8138.5 8144.0 8139.5 8145.5 8141.0 8284.5 8280.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 3970.0 4295.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 4295.0 8280.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHM~ 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHM~ 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 3951.5 8284.5 6118 ROP 9.3811 2270.77 229.205 GR 11.6437 313.184 89.4783 RPX 0.246 319.813 3.99715 RPS 0.5205 108.743 3.66112 RPM 0.5045 81.3881 3.50734 Nsam 8667 8640 8551 8511 8511 8511 First Reading 3951.5 3965 3951.5 3951.5 3951.5 3951.5 Last Reading 8284.5 8284.5 8226.5 8206.5 8206.5 8206.5 RPD 0.5124 2000 3.7521 8511 NPHI 15.8607 81.7622 45.2351 8459 NCNT 2146.24 3919.8 2614.23 8459 FCNT 409 947 611.755 8459 RHOB 1.3816 3.1359 2.30459 8529 DRHO -0.193 0.8253 0.0392967 8529 PEF 1.7323 17.4803 2.65005 8528 FET 0.1102 9.474 0.977536 8511 3951.5 3951.5 3951.5 3951.5 3951.5 3951.5 3952 3951.5 8206 5 8180 5 8180 5 8180 5 8215 5 8215 5 8215 5 8206 5 First Reading For Entire File .......... 3951.5 Last Reading For Entire File ........... 8284.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE DRHO RHOB FCNT NCNT NPHI FET RPD RPM RPS RPX GR PEF ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2 .5000 START DEPTH 3955.0 3955 0 3955 0 3955 0 3955 0 3955 0 3955 0 3955 0 3955 0 3955 0 3955 0 3955 5 3970 0 STOP DEPTH 4225 5 4225 5 4191 0 4191 0 4191 0 4217 0 4217 0 4217 0 4217 0 4217 0 4156 5 4226 0 4295 0 17-MAR-97 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.96 CIM 5.46 MEMORY 4295.0 3970.0 4295.0 28.1 29.6 TOOL NUMBER P0686CRDGP6 P0686CRDGP6 P0686CRDGP6 P0686CRDGP6 8.500 8.5 PAC GEL 8.40 52.0 9.6 50O .0 3.500 3.500 2. 625 5.250 20.8 Name Service Order Units Size Nsam Rep Code Offset Channel DEP? FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RP S MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 NPHI MWD 2 P.U. 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 FCNT MWD 2 CNTS 4 1 68 NCNT MWD 2 CNTS 4 1 68 RHOB MWD 2 G/CC 4 1 68 DRHO MWD 2 G/CC 4 1 68 PEF MWD 2 BARN 4 1 68 16 20 24 28 32 36 40 44 48 52 5 6 7 8 9 10 11 12 13 14 Name Min Max Mean DEPT 3955 4295 4125 GR 27.6999 96.3436 67.0814 RPX 0.246 21.5923 4.7419 RPS 0.6445 22.5237 4.82231 RPM 2.1132 20.715 4.7706 RPD 2.2548 2000 9.50088 NPHI 37.0261 70.3625 49.2236 ROP 24.726 912.536 287.668 FET 0.3298 1.3986 0.683627 FCNT 409 731 545.233 NCNT 2146.24 2736 2486.38 RHOB 1.3816 3.1307 2.08147 DRHO -0.078 0.8253 0.100805 PEF 1.7323 3.0709 2.36218 Nsam 681 4O4 525 525 525 525 473 651 525 473 473 542 542 542 First Reading 3955 3955 3955 3955 3955 3955 3955 3970 3955 3955 3955 3955 3955 3955.5 Last Reading 4295 4156.5 4217 4217 4217 4217 4191 4295 4217 4191 4191 4225.5 4225.5 4226 First Reading For Entire File .......... 3955 Last Reading For Entire File ........... 4295 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 4100.5 NCNT 4100.5 NPHI 4100.5 FET 4124.0 RPX 4124.0 RPD 4124.5 RPM 4124.5 RPS 4124.5 PEF 4136.0 DRHO 4136.0 RHOB 4136.0 GR 4146.5 ROP 4202.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): STOP DEPTH 8176.0 8176.0 8176.0 8202.0 8202.0 8202.0 8202 0 8202 0 8211 0 8211 0 8211 0 8222 0 8280 0 19-MAR-97 4.96 CIM 5.46 MEMORY 8280.0 4295.0 8280.0 26.6 32.1 TOOL NUMBER P0687CRDGP6 P0687CRDGP6 P0687CRDGP6 P0687CRDGP6 8.500 8.5 PAC GEL 10.20 55.0 9.5 7OO 4.8 3.500 2.120 2.625 5.250 57.8 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 3 AAPI 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMM 4 1 68 NPHI MWD 3 P.U. 4 1 68 ROP MWD 3 FT/H 4 1 68 FET MWD 3 HOUR 4 1 68 FCNT MWD 3 CNTS 4 1 68 NCNT MWD 3 CNTS 4 1 68 RHOB MWD 3 G/CC 4 1 68 DRHO MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 4100.5 8280 6190.25 8360 GR 11.6437 313.184 90.5167 8152 RPX 0.4519 319.813 4.04257 8157 RPS 0.4401 108.743 3.67345 8156 RPM 0.4636 81.3881 3.50223 8156 RPD 0.5058 57.0705 3.44914 8156 NPHI 15.8607 81.7622 45.1571 8152 ROP 9.3811 2270.77 226.339 8157 FET 0.1102 9.7327 1.19519 8157 FCNT 412 947 613.581 8152 NCNT 2168 3919.8 2616.95 8152 RHOB 1.6115 3.1359 2.31251 8151 DRHO -0.193 0.3146 0.0371904 8151 PEF 1.811 17.4803 2.66473 8151 First Reading 4100.5 4146.5 4124 4124.5 4124.5 4124.5 4100.5 4202 4124 4100.5 4100.5 4136 4136 4136 Last Reading 8280 8222 8202 8202 8202 8202 8176 8280 8202 8176 8176 8211 8211 8211 First Reading For Entire File .......... 4100.5 Last Reading For Entire File ........... 8280 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/06/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/06/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File