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HomeMy WebLinkAbout197-075Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 T41311END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 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: 7/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250723 Well API #PTD #Log Date Log Company AOGCC ESet # END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON T40691 KU 41-08 50133207170000 224005 6/30/2025 AK E-LINE T40692 MPU F-05 50029227620000 197074 7/1/2025 READ T40693 MPU J-02 50029220710000 190096 5/21/2025 YELLOWJACKET T40694 MPU R-106 50029238160000 225033 6/8/2025 HALLIBURTON T40695 MPU R-107 50029238190000 225049 7/11/2025 YELLOWJACKET T40696 ODSK-41 50703205850000 208147 6/13/2025 HALLIBURTON T40697 ODSN-02 50703206710000 213046 6/13/2025 HALLIBURTON T40698 ODSN-16 50703206200000 210053 6/14/2025 HALLIBURTON T40699 ODSN-17 50703206220000 210093 6/14/2025 HALLIBURTON T40700 ODSN-24 50703206620000 212178 6/15/2025 HALLIBURTON T40701 ODSN-28 50703206760000 213148 6/17/2025 HALLIBURTON T40702 ODSN-36 50703205610000 207182 6/12/2025 HALLIBURTON T40703 PBU 07-23C 50029216350300 225043 7/4/2025 HALLIBURTON T40704 PBU 14-18C 50029205510300 225040 6/25/2025 HALLIBURTON T40705 PBU 15-33C 50029224480300 216075 7/3/2025 HALLIBURTON T40706 PBU C-30A 50029217770100 208169 7/1/2025 HALLIBURTON T40707 PBU E-09C 50029204660300 209095 6/30/2025 HALLIBURTON T40708 PBU F-38B 50029220930300 225029 6/12/2025 HALLIBURTON T40709 PBU GNI-02A 50029228510100 206119 7/4/2025 HALLIBURTON T40710 PBU GNI-02A 50029228510100 206119 7/3/2025 HALLIBURTON T40710 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU GNI-04 50029233670000 207117 6/27/2025 HALLIBURTON T40711 PBU J-07C 50029202410300 225026 5/30/2025 HALLIBURTON T40712 PBU L-105 50029230750000 202058 6/24/2025 YELLOWJACKET T40713 PBU L-108 50029230900000 202109 6/23/2025 YELLOWJACKET T40714 PBU NK-25 50029227600000 197068 6/5/2025 YELLOWJACKET T40715 PBU P2-06 50029223880000 193103 6/19/2025 HALLIBURTON T40716 PBU S-104 50029229880000 200196 6/21/2025 YELLOWJACKET T40717 END 1-25A 50029217220100 197075 6/19/2025 HALLIBURTON Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:54:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU-05 50283202030000 225037 7/3/2025 YELLOWJACKET T40718 TBU D-08RD 50733201070100 174003 6/4/2025 READ T40719 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.28 09:53:40 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/03/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL END MPI 1-25A (PTD 197-075) PERFORATING RECORD 06/17/2020 Please include current contact information if different from above. Received by the AOGCC 11/03/2020 Abby Bell 11/03/2020 PTD: 1970750 E-Set: 34173 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 9/11/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPI 1-25A (197-075) Gas Saturation Analysis using TMD3D ANALYSIS GASSAT FIELD DATA Please include current contact information if different from above. PTD: 1970750 E-Set: 33833 Received by the AOGCC 09/14/2020 Abby Bell 09/14/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Hilcorp Alaska 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 14,660 feet N/A feet true vertical 10,122 feet 14,607 feet Effective Depth measured 10,560 feet N/A feet true vertical 9,186 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)4-1/2" 12.6# / L-80 / IBM 9,544' 8,871' 1,509' MD Packers and SSSV (type, measured and true vertical depth)N/A N/A 4-1/2" BBE SSV 1,509 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 5,393 Water-Bbl MD 131' 2,483' 8,919' 14,652' TVD 131' 47 Oil-Bbl measured true vertical Packer 7" 4-1/2" 9,257' 13,938' Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 109 Representative Daily Average Production or Injection Data 314161 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-075 50-029-21722-01-00 Plugs ADL0034633 & ADL0312828 5. Permit to Drill Number: ENDICOTT / ENDICOTT OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-251 1,701 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com Size 1,900 DUCK IS UNIT MPI 1-25A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 539 Gas-Mcf 700 Casing Pressure Tubing Pressure 28,219 measured 348' 4,841' Production Liner Casing Conductor Liner 813' Length 90' 2,442' 8,880' Surface Production 30" 13-3/8" 9-5/8" 9-5/8" 8,160psi 2,482' 8,426' 8,679' 10,125' 4,760psi 5,090psi Burst N/A 5,020psi 6,870psi 8,150psi 7,500psi 7,020psi 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,430psi Collapse N/A 2,260psi 10,065' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:35 am, Jul 16, 2020 Chad A Helgeson 2020.07.15 21:38:21 -08'00' DSR-7/16/2020 RBDMS HEW 7/16/2020 MGR21JUL2020 SFD 7/16/2020 3-3/8" 6 13,484 - 13,489 o 6/17/2020 6/17/2020 TDF Perf Add 3-3/8" 6 13,484 -13,489 33/8 6 13,484 13,489 oo 6/17/20206/17/2020 Well Name Rig API Number Well Permit Number Start Date End Date END 1-25A Eline 50-029-21722-01-00 197-075 6/17/2020 6/17/2020 No operations to report No operations to report 6/20/2020 - Saturday No operations to report 6/23/2020 - Tuesday 6/21/2020 - Sunday No operations to report 6/22/2020 - Monday 6/19/2020 - Friday No operations to report 6/17/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MIRU ELINE, PT 250 psi low / 3,500 psi High. COULDN'T GET ANY DEEPER THAN 11,510 md. LRS ASSISTED PUMPING E LINE DOWN HOLE, DISPLACED TBG DOWN WITH 1% KCL, AND THEN CONTINUE PUMPING TO HELP E LINE GET TO ZONE TO PERF. PERFORATED FROM 13,484' TO 13,489' ELMD. AFTER E LINE PERFED, WE PUMPED AWAY REMAINING FLUID (62 BBLS), PUMPED 5 BBLS 60/40 TO FREEZE PROTECT SURFACE EQUIPMENT. RIGGED DOWN. 6/18/2020 - Thursday No operations to report 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: ___________________ 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/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,660'14,607' Casing Collapse Conductor N/A Surface 2,260psi Production 4,760psi Production 5,090psi Liner 7,020psi Liner 7,500psi 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: 6/11/2020 Conditions of approval: Notify Commission 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 COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng DUCK IS UNIT MPI 1-25A ENDICOTT / ENDICOTT OIL C.O. 462.007 4,841'7"13,938'10,065'8,160psi 348'9-5/8" N/A and 4-1/2" BBE SSV N/A and 1,509MD / 1,509TVD Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 14,652' Authorized Signature: 6/15/2020 4-1/2" Perforation Depth MD (ft): See Schematic See Schematic 90' 30" 13-3/8" 9-5/8" 2,442' 4-1/2"813' 8,880' Perforation Depth TVD (ft): 5,020psi 6,870psi 2,482' 8,426' 10,125' 2,483' 8,919' 9,257'8,679'8,150psi N/A 131'131' 12.6# / L-80 / IBM TVD Burst 9,544' MD N/A 8,430psi Length Size 10,122'10,560'9,186'2,556 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0034633 & ADL0312828 197-075 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21722-01-00 Hilcorp Alaska LLC Tubing Grade: Tubing MD (ft): dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.06.11 10:13:49 -08'00' By Samantha Carlisle at 12:55 pm, Jun 11, 2020 320-251 SFD 6/11/2020 6/11/2020 10-404 Perforate gls 6/12/20 Comm q 6/16/2020 dts 6/15/2020 JLC 6/15/2020 RBDMS HEW 6/18/2020 Perf Add Well: END 1-25A PTD: 197-075 API: 50-029-21722-01 Well Name:END 1-25A API Number: 50-029-21722-01 Current Status:Online Rig:EL Estimated Start Date:June 15th, 2020 Estimated Duration:1 day Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:197-0275 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer: AFE Number: Well EZ Inputs Required:Yes Current Bottom Hole Pressure:3,556 psi @ 10,000’ ss TVD Maximum Expected BHP:3,556 psi @ 10,000’ ss TVD Max. Anticipated Surface Pressure:2,556 psi (Based on 0.1 psi/ft. gas gradient) WHP:2,111 psi Min ID:3.725” ID 4-1/2” XN Nipple at 9,531’ MD Reference Log:CBL March 13th 2011 Brief Well Summary: END 1-25A well is a K1 producer. Objective: Using Eline, perforate the following K2A interval for increased oil production. Proposed gun run must be confirmed with respect to signed Final Approved Perforation Request Form provided by Reservoir Engineer: Gun Run # Perf Top Perf Bottom Perf Length 1 ±13,484’ ±13,489’ 5 Total 5 Table 1: END 1-25A Proposed Perf Gun Runs Sundry Procedure (Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low 3,500 psi high. 2. MU perforating tool string with 3-3/8”, 6spf, 60 deg phasing guns. 3. RIH and correlate gun run to reference log Perforation Depth Control Log dated 3/13/2011. Contact OE David Gorm at 1(505) 215-2819 prior to perforating for final approval of tie in. 4. Perforate gun run as per Table 1: END 1-25A Proposed Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. 5. RD Eline. Attachments: As-built / Well Schematic Using Eline, perforate the following K2A interval for increased oil production. Proposed gun run must be confirmed with respect to signed Final Approved Perforation Request Form provided by Reservoir 3-3/8" 6 13,484 - 13489 new perfs 13484-13489 ft • a t Post Office Box 244027 0 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 2015 3800 Centerpoint Drive Suite 100 AOGCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 icANNED MU Li 2 9 2016 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission / ` D 76 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 / _ a 57'9 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I"followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig New API_WeliNo PermitNumber WellName WeIlNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/I17 1-17A 50029225690000 1950930 ;DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 0029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, May 26, 2015 8:39 AM To: Alaska NS - Endicott - Field Foreman;Alaska NS - Endicott - Operations Leads; Loepp, Victoria T (DOA) Cc: Wallace, Chris D (DOA); Regg, James B (DOA); Taylor Wellman Subject: RE: END1-25 (PTD # 1970750) TIFL Passed Attachments: image001jpg; image004.jpg All, Producer END1-25 (PTD# 1970750) passed a TIFL on 5-24-15.There has been no further IA pressurization.The passing TIFL confirms tubing integrity.The well was returned to production. Please call with any questions. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ilil "„I' 11a.1..i i 1 t SCANNED MAY 2 7 2U1F From: Wyatt Rivard Sent: Friday, May 22, 2015 5:00 PM To: Alaska NS - Endicott - Field Foreman; Alaska NS - Endicott - Operations Leads; Loepp, Victoria T(DOA) Cc: 'Wallace, Chris D (DOA)'; Regg, James B (DOA); Taylor Wellman Subject: END1-25 (PTD # 1970750) Sustained Casing Pressure All, Gas lifted producer END1-25 (PTD# 1970750)was found to have sustained Inner Annulus casing pressure on 5/20/2015 with T/I/O =51/2550/50 following the shut-in of the Endicott Pipeline for Sag River flooding. IA has been bled to 2350 psi and well remains SI. Plan forward—Operations: 1) Return well to production when possible 2) Obtain TIFL survey Pending TIFL results, well will be evaluated for additional wellhead diagnostics or GLV change out. Please call with any questions or concerns. Thank You, 1 Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 liil.Y,rr Illa.i►w.1.1.i: 2 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning pr.oject. They are available in the original file and viewable by direct inspection. / ~' 7-' ~ '~-~ File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: [3 GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type 'OVERSIZED ,Logs of vadous kinds Other Complete COMMENTS: Scanned by: Bever~j Mitdmd-D'amtha ~owell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /s/ PV on , �w�"\\I%%,sv THE STATE Alaska Oil and Gas ' 4� == �,,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue r,M 0o, Q+ Anchorage, Alaska 99501-3572 ALAS Y' Main: 907.279.1433 tti LA)i,,, Fax 907.276.7542 go Josiah Igwe Petroleum Engineer y:_P_L__57 BP Exploration(Alaska), Inc. ("7 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, EPA 1-25A/K-22 Sundry Number: 313-544 Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat y P oerster Chair, Commissioner St- DATED this J day of October, 2013. 1 Encl. 4 y STATE OF ALASKA ,47,-k 3 OCT?S 1 4) 201 ALASKA OIL AND GAS CONSERVATION COMMISSION !0` 3 APPLICATION FOR SUNDRY APPROVALS ., 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other:Convert to Injector Si ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development is , 197-075-0 '' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21722-01-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? EPA 1-25A/K-22 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 " ENDICOTT, ENDICOTT OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 14660 • 10128 , 10560 9186 None 14425 Casing Length Size MD ND Burst Collapse Structural Conductor 90 30"Conductor 40.6-131 40.6-131 Surface 2442 13-3/8"68#L-80 41.02-2483.15 41.02-2482.21 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 37-9544 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(it): See Attachment for Packer Depths 4-1/2"BBE SSV 1509',1508.65' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program © BOP Sketch ❑ Exploratory ❑ Development ❑ Service © - 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ Q - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Email Josiah.lgwe @BP.Com Printed Name Josiah lgwe Title Petroleum Engineer Signature Phone 907-564-4753 Date Prepared by Garry Catron 564-4424 IG — ID —2,b13 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1.3 S-6-k' , Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test n Location Clearance ❑ Other: 44 17-- IA 1.--.e.‘1 i cd aFt-cr' ,5i-Gtbj , i,? Zd 'iv" aiterfiow 10 r-� v1rccl u ft-i!r 5rabis1i 5raw 1`x11 C /t c =� r t� © vet/ /s `� r r7 te-d to q !/aw for - tYrc curr2 hoc l z• c! �� 9egg ` �vtb rah i5 4l9-6'e4D a-190 v---e. ft-7c f-010 perf0 ' fi i Spacing Exception Required? Yes ❑ No Q Subsequent Form Required: /U — ¢6 4- APPROVED BY ` Approved by: _7 ( COMMISSIONER THE COMMISSION Date: /O _ 51._ /z Form 10-403 Revised 10/2012 A to eRpIIi aGol%I 72 months from the date of approval. ( / �( iq Z� r) � p pproval. _Submi rm and Attachments in Duplicate; ,�' II RBDMS NOV 6 2Ui3' / ki Casing Summary ADL0312828 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade_ -CONDUCTOR 90 30" Conductor 41 131 41 131 LINER 4841 7"29#L-80 9097 13938 8559 10065 8160 7020 L-80 LINER 813 4-1/2" 12.6# L-80 13839 14652 10057 10125 8430 7500 L-80 PRODUCTION 348 9-5/8"47# NT95HS 8909 9257 8419 8679 8150 5080 NT95HS PRODUCTION 8880 9-5/8"47# L-80 39 8919 39 8426 6870 4760 L-80 SURFACE 2442 13-3/8"68# L-80 41 2483 41 2482 5020 2260 L-80 TUBING 9507 4-1/2" 12.6# L-80 37 9544 37 8869 8430 7500 L-80 Ill 0 , • • Perforation Attachment ADL0312828 Well Date Perf Code MD Top MD Base TVD Top TVD Base 1-25A/K-22 8/30/08 APF 13590 13608 10037 10039 1-25A/K-22 8/30/08 PER 13608 13610 10039 10039 1-25A/K-22 8/30/08 PER 13610 13620 10039 10041 1-25A/K-22 8/29/08 PER 13850 13870 10058 10060 1-25A/K-22 5/29/97 PER 14080 14170 10077 10085 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Ills • Packers and SSV's Attachment ADL0312828 Well Facility Type MD Top Description TVD Top 1-25A/K-22 SSSV 1509 4-1/2" BBE SSV 1509 1-25A/K-22 PACKER 9097 7" Baker ZXP Top Packer 8559 1-25A/K-22 PACKER 9444 4-1/2" BAKER S-3 PERM PACKER 8811 1-25A/K-22 PACKER 13849 4-1/2"TIW Packer 10058 • • Area of Review - Endicott DIU 1-25A/K-22 (1970750) Subsequent to the conversion of well 1-25A/K-22 from producer to water injector an Area of Review(AOR) is obligatory. This AOR will discuss the wells within 1/4 mile of said well's entry point into the Kekiktuk Formation to the bottom of well bore completion. Five individual well bores enter the AOR of 1-25A/K-22 at the top of the Kekiktuk to bottom of wellbore completion. The following table illustrates the five wells within the AOR, their respective distances from 1-25A, and any annulus integrity comments based on an in depth review of each well. Well Name PTD Distance, Ft. Annulus Integrity 1-25A/K-22 197075o No known integrity issue. 1-25/N-22 1870420 978' Side tracked 1-o9A/L-21 1970290 932' MIT-IA passed to 3000 psi on 08/06/2013 1-47A/M-20 1972030 1123' Packer cement squeezed,MIT IA Passes to 3000 2-06/J-22 1870180 55o' MIT-IA passed to 4033 psi 5-o1/SD-07 1801200 23o' AA for slow TxIA,MIT-IA tested every 2 yrs. 1-21/K-25 1900020 2951' MTT-T xIA passed to 3000 psi Figure 1: Wells within AOR Well Name Casing Size Hole Size Vol Cement Kekiktuk Depth 7" 8-1/2" 82 bbls, 579' 1-25A/K-22 4-1/2" 6" 23 bbls 12 1-25/N-22 5-1/2" 8-1/2" 254 bbls 10756' 1-o9A/L-21 7" , 8-1/2" 56 bbls, 11257' 4-1/2 6" Un-cemented SL 7" 8-1/2" 63 bbls 1-47A/M-20 4-1/2" 6" 7o bbls 11492' 2-7/8" 4-1/2" 36 bbls 2-o6/J-22 7" 8-1/2" 64 bbls 12702' 5-o1/SD-07 7" 8-1/2" 111 bbls 11789' 1-21/K-25 7" 8-1/2" 59 bbls 12578' Figure 2: Completion Detail Cdnc✓t. Piodevc/01 a, J''ye k e1/ �1Gf Grefe./ /Pi/ ryas Jr0 P. Cos✓car 1'i y 7-4,c U,eil 7 0 col ,'h✓C ?d/ florid Q/ld ,c / e..'d fe co ver ,ffoot re'0 fOrrt OA- Tie pool. 4 q/9(1/1 • 4 t /1 Well 1-25A/K-22 (PTD 1970750)was sidetracked fronyparent well 1-25/N-22 in May 1997. The completion crossed the Kekiktuk formation at 12,579' MD.A 7" liner was run to 1 38'MD, hung off at 9097' MD ar(d cemented with 82 bbls of class G cement.�A SCMT cement bond log of the "liner run 3/13/2011 indicates good bond from 12400-11 o'MD . (Roughly 300'of Fair to good cement bond above the top oft e reservoir). A 4-1/2"liner run to 14652'MD and hung off at 13839'MD. The 4-1/2"liner was cemented with 23 bbls of class G cement. In well 1-25/N-22 (PTD 1870420) a 5-1/2"liner was run to 13504' MD and hung off at 10431' MD. The completion crossed the Kekiktuk formation at 10756' MD. The 5-1/2"liner was cemented with 254 bbls of class G cement. The top of cement is calculated to be above the top of the reservoir at 7278'MD.A cement bond log run 6/20/1987 indicated poor cement bond, probably due to f microannulus interfering with the CBL attenuation reading. The well was plugged and abandoned in April 1997 with 43 bbls of class G cement placed from TD to 1o871'MD and sidetracked at 9257'MD. In End1-21/K-25 (PTD 1900020),the well was completed in 1990 and had a RWO in 2008 to set and cement scab liner. The completion crossed the Kekiktuk formation at 12,578'. The 7" Liner was hung up in the 9-5/8"casing at 13089'. 59 bbls of class G cement was pumped to cement the liner in 1990. Analysis of CBT suggest good cement from 13660'43480', Gas behind casing. Liner lap poorly cemented 13480' — 13320'with no gas present. Liner lap was moderately cemented from 13300' to 13215'. Well 1-o9A/L-21 (PTD 1970290)was sidetracked from parent well 1-o9/J-18 in March 1997. The completion crossed the Kekiktuk formation at 11,257'MD.A 7" 2 intermediate casing was run to 11920'MD and hung at 7892'MD. The 7"casing was cemented with 56 bbls of class G cement. The top of cement is calculated to be above the reservoir at 9442'MD. A 4-1/2" slotted liner was run to 12585' MD and hung off at 1187o'MD. The 4-1/2" slotted liner was not cemented. Well 1-47A/M-20 (PTD 1972030)was sidetracked from parent well 1-47/Q-21 in December 1997 and completed in January 1998. The completion crossed the Kekiktuk formation at 11,492' MD. The 7"liner was unable to be pushed to the planned TD of 13,085' MD due to tight hole conditions, and was instead landed at 12582'MD and the liner top packer set at 7758'MD leaving it 666'MD inside the window. The casing passed a pressure test to 350opsi for 30 minutes meaning cement circulation was not possible, and instead the well was cemented by placing a cement retainer at 12574' and pumping 10 bbls of Class G cement to 1600psi through the float equipment then perforating the wellbore from 12534- 12530 and 12114-1211o'MD and squeezing 18bbls of class G to 2900psi through a cement retainer at 12378'to circulate between the two sets of perforations.A SBL • • of the 7"casing run 12/22/1997 shows poor bond in general with good isolation between 12500-12450 ft . A cementing variance from section 20.d.3.0 AAC was approved and the well was then perforated at 11400-11404'MD to down squeeze an additional35bbls of Class G cement to 25oopsi to fill the annulus above the hydrocarbon bearing zones. Another SBL of the 7"casing was run 12/26/1997 indicating good isolation between 11650 and 11920ft with an isolated liquid ,ill' pocket in between .The 4-1/2"liner was run to 14070'MD and hung off at 11329'MD. The 4-1/2"liner was cemented with 70 bbls of class G cement.A SBL run 1/12/1998 indicated areas of good bond between 12700 -12575 ft MD. In June 2001 a 2-7/8"scab liner was run inside of the 4-1/2"finer to 13909'MD and cemented in place with 30 bbls of class G cement to shut off gas production from the K2B. The liner top packer was cut and pulled from the 2-7/8"liner 10/04/2004 at 9646'MD in preparation to squeeze the leaking 4-1/2"x 7"tubing packer. In well 2-o6/J-22 (PTD 1870180) a 7"liner was run to 13,247' MD and hung off at 12,403'MD. The completion crossed the Kekiktuk formation at 12,701' MD. The 7"liner was cemented with 64 bbls of class G cement. The top of cement in the 7"liner is calculated to be 10433' MD.A bond log was run 3/29/87 and showed good cement bond 12710-12685 ft above the interval and adequate cement intervals below that top The well has been worked over twice since drilled. The tubing was changed out during a RWO in Oct1991. Another RWO in 2001 was needed due to tubing leaks, a restriction in the tubing and casing leaks. The tubing was changed out and a 7-5/8" scab liner was run from 5492' MD to 12,378' MD to repair the casing damage. This liner was cemented with 116 bbls of class G cement. In well 5-o1/SD-o7(PTD 1801200) a 7"liner was run to 12,522' MD and hung off at 11,020' MD. The 7"liner was cemented with 111 bbls of class G cement. The completion entered the Kekiktuk formation at 11,789' MD. The top of cement in the 7" casing is calculated to be above the reservoir at 7610' MD.After a production test, the well was suspended 3/31/81 and in 1987 it was reentered to complete the well as a gas injector. The open perforations were cement squeezed at that time and a cement bond log was run 3/18/87. This log shows >50' of good cement above the injection interval,before the dual casing anulates the cbl reading . The well is currently a gas injector operating under an AA for slow TxIA. 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II \ riit--111--. ;TREE= 4-1/16"CM/(5000 PSI) NOTES: •, ; AV; •GE 230-280 WELLHEAD= 13-518"CAN(5000 PSI) ACTUATOR= E N D 1 -25A PPM ON A/L&GAS INJ ©i ""'''WELL REQUIRES A SSSV"" ELEV= 55.3• BF,B_EV= - 15.4' ii ii KOP Angle= 89 14452 4110 = _ I 1509' H4-112"OTIS HXO SLVN,ID=3813" I Vex el Datum = 13832 Datum TVD= 10300'SS 113-3/8 CSG, ,L-80 ID=12,415" 1---I 2483' GAS LIFT MANDRELS ST NO TVD TYPE VLV LATCH PORT DATE " ' 6 3571 -;%.: 3 KGB-2 DONE BTM 16 05/29/97 MIN ID = 3.725 @ 9531 5 5 • 5282 3 KGB-2 DMY BTM 0 05/29/97 4-1/2" XN NIPPLE 4 6355 ; • 12 KGB-2 CONE BTM 16 0. • •7 3 7094 7030 31 KGB-2 DIMY BTM 0 05/29/97 2 ; 1 7744 42 KGB-2 COME BTM 16 L. • :7 [9-5/8"CSG,470,L-80 X0 TO NT95HS H 8919 I-->< 1 8946 8447 41 KGB-2 SO BTM 24 04/1 [TOP OF 7"LNR H 9097' 1-1. 9-5/8"MILLOLJTWNDOW(13101-25A) 9257'-9307 19-5/8"CSG,470,NT95HS, =8.881" H 9257' I • • I 9434' H41/7'HES X NP,ID=3.813" I Z X — I 9444' H X 4-1/T BKR S-3 F'(R ID=3.875" I )1\44 4 • • 9509' 4-1r2"HES X NIP,ID=3.813" *\'\41 0311 Iv r- • • I 9531' H41/2"HES XN NIP, Cr 3.725" I , , 4-1/2"TBG,12.8%, L-80 BM,.0152 bpf,Cr 3.958" —I 9544' 1 1q3--c* r--9544' H4-1/2"WLEG,10=3 12 IND H ELMD TT NOT LOGGED I /3,-90 TOP OF 4-1/2"LNR 1383W LNR,290, L-80,.0371 bpf,ID=8.276" 13938' PERFORATION SUMMARY REF LOG: MD GR/R ON 05121/97 ANGLE AT TOP FERF: 81'6)13590' Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 13590-13610 0 04130X)4 2-7/80 6 1 ; -13633 0 08/30/08 —2-7/8" 6 1 ;- -13870 0 08/25108 3-318" 6 1. -14170 0 05129197 Ps-ro 14807' I 44 4• 444* 4444 14-1/7 osR, 1290,L-80 IBT-M.0152 bpi,ID=3.!-;" H 14852' DATE REV BY COMMENTS DATE REV BY COMMENTS •COTT UNIT 07/02/57 (315 INITIAL COMPLETION 08/12/11 DAVJAA) I-QS SAFETY NOTE WELL 1-25A/K-22 06/28/97 D15 SIDETRACK(BN01-25A) 02/05/12 PJC CONVERSION CORRECTIONS •-". No:'970750 03/18/10 JLW/SV CSG CORRECTION API No: 50-029-21722-01 06/02/10 JEN/PJC DRAWING CORRECTIONS SEC 36,T12N,R16E,3251'NSL& • 'WEL 02/16/11 MB/JNO SSSV SAFETY NOTE 07/11/11 AW/JMD_CSG COFiRECTION/FERF DATE BP Exploration(Alaska) prd /97-0 75 • • Ferguson, Victoria L (DOA) From: Igwe,Josiah <Josiah.Igwe @BP.com> Sent: Friday, October 25, 2013 3:08 PM To: Ferguson,Victoria L(DOA) Cc: Bill, Michael L(ASRC) Subject: RE: EPA 1-25A/K-22 (PTD 197-075, Sundry 313-544) Attachments: 1-25A.JPG;4314_009.pdfi 4314_001.pdf;4315_001.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Enclosed is a scanned copy of a section of the 1-25A SCMT Cement Bond Log dated 3/12/11. A calculation of the cement top assuming good displacement with no allowance for losses or out of gauge hole indicates the top of cement to be about 10256' MD. The top of the Kekiktuk is 12579' MD (9675'TVD). Based on the bond log and the cement top calculations there is isolation to above the Kekiktuk, but not to the packer. Enclosed also is a log section. The packer is placed near the top of a thick shale section with no permeable intervals between the top of the Kekiktuk and the packer. We request approval to inject water into this well with the packer located at 9444' MD (8797'TVD). Please call me if you have any other questions. Thank you, Josiah From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson @alaska.govJ Sent: Thursday, October 24, 2013 3:41 PM To: Igwe, Josiah Subject: EPA 1-25A/K-22 (PTD 197-075, Sundry 313-544) Josiah, Do you have a copy of the SCMT CBL run 3/13/2011 which indicates good bond from 12400-11550' MD? Please refer to 20 AAC 25.412(b);The packer must be placed within 200 feet MD above the top of the perforations, unless different placement is approved. According to the well schematic,the packer is 4146' MD above the top perforation. Please estimate the TOC. Please summarize the cement job. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonalaska.gov 1 . - 7L.JV - ~ 0 414- • ti :rr' API 15U 8700 - Packer - 9500 - 8800 r , _ _' - 9750 8900 ti . 10000 - . = ... 9000 - I a. 10250 i j z 4 9100 - — - 10500 _ J y - 10750 z 1 ti 9200 - --'! = 11000 =- a "` 4 r j m X11250 = 9300 - —44 - 115() ,... ,.._ _..,- a �A TT 9400 ,! = 11750 r ] 12000 - 9500 ? <O C1 ,... - 12250 — j tIP— c..31.-) \3e..3/ 9600 �/ - 12500 } y P LCU truncation -':'.E 1 of Kekituk �- 9700 -' - 12750 �. ..- y - 13000 --;_3808- 11111 I 1` - -a. '1 - Proposed c.-- 13250 -- J IIIII pert interval - n-- 9900 -2, IIIIIIIIIIII E 13500 A,. Top pee f- i- 1 ?75f14- .... " • • Schiumberger 1 `r Company: BP Exploration (Alaska), Inc. 1. FINAL of i. -. Well 1-25A/K-22 Field: Endicott y State: Alaska s Borough: North Slope , .. 7 ��� Cement Bond Log r'@ re, U CCL / GR / SCMT .' : it 13-March-2011 �" Elev.: K.B. 56.00 ft o� 0 2028.73'FNL&2092'FEL o z c, '1 z at Surface. G.L. o '' N o O D.F. cn S ti Y Q ccD ti-1 U Permanent Datum: MSL Elev.: 0.00 ft N z w ° — m -I Log Measured From: KB_ 56,00 ft above Perm. Datum t c c Drilling Measured From KB o) 0 1 o "a m — E API Serial No. Section Township 1 Range a� 12N coo ii: U 50-029-21722-01 36 16E Logging Date 13-Mar-2011 Run Number 1 � ,. ' Depth Driller 14607 ft _ ' � ' � Schlumberger Depth 13646 ft Bottom Log Interval 13636 ft _ 7910 ft , Top Log interval .- -" Casing Fluid Type 1 %KCL . —...____—._ * Salinit 1''"� Density 8.34 Ibm/gal - Fluid Level _._ BIT/CASING/TUBING STRING Bit Size From _ To Casing/Tubing Size 7.000 in ' Weight 29Ibm/ft Grade L-80 From 9097 ft To 13938 ft Maximum Recorded Temperatures 174 degF � -------1 J Logger On Bottom i Time 13-Mar-2011 16:01 Unit N umber l Location 2266 Prudhoe Bay _____L____ - Recorded By N, LaCroix/W. Rivard/E.Kroh Witnessed By R.Doshier(T.Wellman _ v 7. i} tr .. ,.'► 7W I/ ' Gj I " ///C� /M//i i/as A//i/ ', amonsramaimmirm we lulu=f.:,mr 1A _ / i %_ __MIPmmwmi mvRl:mmm MMMM mm/iWaMMIUMMMOw]rmmmm mmmm1mrmOm mmmw, IMMMr ////M iw/MMrIMMIA=i0MNAMM mimmemommomm mmmmwmmm mmmommumimmm ommommm mmmmmmnimmmmmummrmmmm mmmmir/mmmwm mmmmx.mmmm wmmmM .MMmmmmmummmmmmm miimMm1mwm mmmaimr/iii Mimi•I/rmo/rmmmm rm@mw t Ir .) 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"'.yC Izato___ 1 i IE1_ _ _I._►1_11_____ai!NIMIM.7_ • _1._•I•..a_NI_____%I9LI_M_ NIIIIIIIIIIIMMUUMIEMIIIMIMPSUIREIMMEI 1•1•1■_J.__1•11•11•111.4•=1 1•1111•1111111111 111111=•11111111M NOM `>•_'tilL1___ . f.__I._1•_a___w. _�JEI__ mum=L_:11_i____p m____ ( � MI IIIMMIIMMINIEN MOM fa__i._A7_a___'Ill•_____ 1.j 111110111•1••=1=11•1 M___0:c I_E_!w_ _-_I._la___MMMMa*I•JF7••• __late_i._NI___ ;AWEi 1i___EI _MINI■_r.___-__1111.7:.d➢ie.Z'frt _WI_I._U_NI_!1•1•1•1•111_11 _!•_1•_I_____1•___'aw►/WE ___U_nM_______.,'i.l4.1_7 1•\\_I■_a_a__1•1•_DIia/6_!I_ 1..-,1 L1 •_•1•_11 IM71a711__ __w11._YI/_-__1•_(4.;11.____ . 1•_./1._MIN NI____0_l.Ili___ _M MOM_1._____.L_7t:s1____ ___I■_J._MEI 1•_L I5 •_1• _•_IF •d._i__<11C-t.•••_ MEMO"►7A'J__EMI 1_iJ•1._• •_ ` ___r:_la_a__ICale�lvlr1•__ t __a:._OM____a_S.Y A7____ t`` ___I.1_M._S___fl !U____ 1•__1N_I1.1•____M i.1•___ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519-6612 May 22, 2012 75 Mr. Jim Regg S. Alaska Oil and Gas Conservation Commission O 9 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 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) Endicott Row 1 Date: 09/24/2010 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 END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0-20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 �7 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / Q -26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1-47A / M-20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / Q -20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / Q-20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 04/28(11 Schiumberger ND 5729 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer i ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE / 93 a i 1 4 03/14/11 1 0`7VP 1 17 -06 BBKA -00094 INJECTION PROFILE . • _ 03/10/11 1 ,t/•,,f 1 C -128 BAUJ -00064 MEM PRODUCTION PROFILE ' 03/08/11 1 A ' `— 1 , G -238 BLPO -00079 MEM PRODUCTION PROFILE , AA.— /Lie( 03/09/11 1 , 1 16 -08A BJGT -00022 GLS ^ 03/07/11 1• - ' 1 02 -18B BLPO -00087 I'JgdtNaweZ.Z i ' :_T 1 J -22A BJGT -00023 = •y4. ' ' ._ — 1 L -210 BLPO -00086 MEM INJECTION PROFILE ' • 03/23/11 1 1WaMPI,, 1 V -105 BLP0.00091 MEM INJECTION PROFILE _ ♦ _,• 03/29/11 1 IN±..r 1 V -220 BBSK -00065 INJECTION PROFILE/WFL iTiaa� ' F:i .'tL�4 V • -212 8088.00096 MEM INJECTION PROFILE _ f � . J 04/03/11 1 r 1 1 U L -214A BCRJ -00073 INJECTION PROFILE I 03/18/11 1 Y 1 V -223 BAUJ -00071 MEM INJECTION PROFILE ,.'/ • _, 03/19/11 1 th(/ j 1 V -217 BAUJ -00077 wgaIP61oic. tic /rt�dla '� it t " - 'rlir a :_rji/I.:� 1 3-05/0-29 BG 00043 Zf'ri ' ' �r TAri 1 1- 47A/M -20 BLPO -00092 MEM PRODUCTION PROFILE "' i 'y g ' ' I5!T�L^ , 1 1-25A/K-22 BBSK -00057 COMMIIIMUMII . 03/13/11 r.Zkl 1 S-01C BCUE -00113 MEM CBL C) _,- 11.1 t 03117/11 Alt # ' 1 1 , 11 -30 BD88 -00097 MEM INJECTION PROFILE '' '"" 04/18/11 1 • • 1 04.11A AWJI -00134 INJECTION PROFILE UZ� D 41 t • ' --11 03/24/11 1 1 , P2 -41 BG4H -00044 PRODUCTION PROFILE i 4".. -[3 °" Wirt A. 03/22/11 1 ?ppp 1 0 -26B BMSA -00009 SCMT , • ^— 03/24/11 8 • " MEM 1 02 -18B BLP0.00087 MEM PRODUCTION PROFILE A L 1112ZEMINIIIIIIIIRTZTAR — 1 Z -20 BP5G -00010 Ir 03/29/11 1 ,r.it � • 1 1 Y -29A BCUE -00122 MEM LDL C ei(0 .— ( / 03/20/11 1 9D." 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd, Anchorage, AK 99503 -2838 10/19 /00 NO. 5423 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ANN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 14- 23APB1 09AKA0035 ON MWD/LWD EDIT 111 04/29109 1 1 1 14- 23APB2 09AKA0035 OHMWD /LWDEDIT 1 05/07/09 1 1 E -12 AZCM -00041 RST — 09/07/09 1 1 15-428 B2WY -00028 MCNL 08/29/09 1 1 B -14A AXED -00043 MCNL 09/01/09 1 1 1- 251K•22 112086685 RST 09/21/08 1 1 12.05 11676951 CH EDIT PDC JUS 06/24/07 1 07 -21 AYS4.00098 RST — 09/18/09 1 1 S -134 AWLS -00039 CH EDI PDC USIT 09/28/09 1 1 H -148 B2WY -00026 MCNL 08/27/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETU ING ONE COPY EACH TO: SP Exploration (Alaska) 1M. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503.2838 • �c STATE OF ALASKA 1'~~'~~' ALA OIL AND GAS CONSERVATION COMf~iION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ "Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension "" "' ?~~' Change Approved Program ~ Operat. Shutdown Perforate Q- Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' - Exploratory ~' 197-0750 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21722-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56 KB 1-25A/K-22 ' 8. Property Designation: 10. Field/Pool(s): , ADLO-312828 ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 14660 - feet Plugs (measured) None true vertical 10128.11 feet Junk (measured) 14425 Effective Depth measured 14560 feet~~R~p~~r~^ s~~ ~ ~ ZQaU t'i IY i.~ true vertical 14105 feet Casing Length Size MD TVD Burst Collapse Conductor 91 30" 40 - 131 40 - 131 Surface 2444 13-3/8"68# L-80 39 - 2483 39 - 2482 4930 2270 Production 1015 9-5/8" 47# NT95HS 8919 - 9934 8427 - 9023 8150 5080 Production 8881 9-5/8"47# L-80 38 - 8919 38 - 8427 6870 4760 Liner 799 4-1/2" 12.6# L-80 13581 - 14650 10058 - 10125 8430 7500 Liner 4834 7" 29# L-80 9104 - 13938 8565 - 10065 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 36 - 9543 0 0 - Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 9444 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: 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: 35 35 3 273 Subsequent to operation: 45 46 12 274 14. Attachments: 15. Well Class after proposed work' copies of Logs and surveys Run Exploratory f Development ~- Service ' Daily Report of Well Operations X 16. Well Status after proposed work: 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: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~ Phone 564-4944 Date 9/8/2008 Form 10-404 Remised 04/2006 1 ...t ~ ~;~ / 1 1 ~ S~~ ~ c~ ~~0~ .,Y„ 444. '~1 iii...,~~~ ~, ~ Submit Original Only `'Cc~ 1-25A/K-22 197-0750 PFRF ~TT~f'.HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 1-25A/K-22 5/29/97 P_ER 14,080. 14,170. 10,076.94 10,085.44 1-25A/K-22 4/30/04 APF 13,590. 13,610. 10,036.5 10,039.38 1-25A/K-22 8/29/08 PER 13,850. 13,870. 10,057.63 10,059.5 1-25A/K-22 8/30/08 PER 13,608. 13,620. 10,039.11 10,040.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED _ SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • C~ 1-25A/K-22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ACTIVITYDATE SUMMARY -~ __ 8/27/2008 CTU #6 1.75" CT Drift &Mem Log for Ad Perf <InterACT is not publishing> ', MIRU CTU waiting on support equipment to get started. Bleed trailer showed ', up so we can PT. PT stack and open up to well. Start killing well and RIH. At 2000' we are loosing generator power. Problem getting worse, POOH and call out mechanics. OOH and well is starting to pressure up, shut down pump with ', :,287 bbls away to keep from locking up perfs. Wait for mechanics to show up. *"*Job continued on WSR 8/28/08*** 8/28/20083CTU #6 1.75" CT Diesel/Xylene Wash, Drift &Mem Log for Ad Perf <InterACT is not publishing> Job continued from WSR 8/27/08. OOH mechanics on =location checking Genset problem. Fuel pump seemed to be the culprit and was swapped out. Now w are having problems getting the Deck Engine to run '':,and CCAT to see all of the parameters. Mechanic found a loose wire on the ';Gen Set that supplies the 12v power to the OPS CAB. RIH to resume ''Diesel/Xylene wash. Wash Perf intervals 13590' to 13610' and 14080' to ;14170' with 80/20 diesel/xylene. Overdisplace diesel xylene with 2% KCL 3 POOH. OOH, swab and master leaking, call grease crew. Chains were slipping :off bottom for awhile, inspect chains and found 2 bad bearings, R&R bearings. -Swab and master greased and holding pressure. *'`"Job continued on WSR 8/29/08'`*'` 8/29/2008 CTU #6 1.75" CT Mem Log & Ad Perf <InterACT is not publishing> Job 'continued from WSR 8/28/08. OOH changing out 2 bad bearings, R&R bearings. MU Logging BHA and RIH. RIH to 14125' and PU to 14100' to start logging. Stop and paint flag at 13800' (mech reads 13826') continue POOH "logging to 13200'. POOH. OOH. Rig back to check for data. Confirm good '-.data. MU and RIH with 20' 2 7/8" perf gun. Correct at coil flag to top shot. RIH '??to perf interval. Tag and work through liner top at 13839'. Drop 1/2" aluminum 'ball to fire guns. Perforate 13850' to 13870'. Good indication of guns firing. 'POOH. OOH guns fired, LD spent guns. Hold PJSM to MU Logging Tools, MU ''tools. RIH ''*""Job continued on WSR 8/30/08*** __ 8/30/2008' CTU #6 1.75" CT Mem Log & Ad Perf <InterACT is not publishing> Job continued from WSR 8/29/08. POOH from Mem log run. While POOH the reel ;stopped moving because the spool wraps are to high for the depth of the reel sump (bed wrap is messed up), RIH to inspect pipe and pipe is flat and needs °"to be cut off and we will have to relog for perf run. Cut off 433' of CT, rehead 'and MU logging BHA. RIH w/SWS logging BHA. Log from 14100' ctmd to ':13200' ctmd. Flag painted at 13550' ctmd. POOH. OOH. Confirm good :.data(+16' correction). MU and RIH with 20' 2 7/8" 6spf PJ2906 perforating gun. Correct to top shot at coil flag. Bring well online with choke at 25 beans. After ;confirmation of well flowing, drop 1/2" aluminum ball and position top shot at 'atop of interval. Perforate 13608' to 13620'. Good indication of guns firing, ;POOH. OOH, guns ire spent guns. DMO to END4-06. Well left flowing. ;Operator to put in test at 24 and 72 hours. CTU RD but on weather STBY wind I'at 27mph constant Gusting to 32mph ''*'`Job in complete*'`'` FLUIDS PUMPED BBLS 387 2% KCL 13 50/50 METH 30 DIESE; 430 TOTAL ( STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator SuspendD Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate ŒI WaiverD Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 197-0750 Stratigraphic D 9. Well Name and Number: 1-25A1K-22 10. Field/Pool(s): Endicott Field / Endicott Oil Pool, Duck Island Unit Name: BP Exploration (Alaska), Inc. Development Œ) Exploratory 0 ServiceO 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 8. Property Designation: ADL-312828 11. Present Well Condition Summary: Total Depth measured 10660 feet true vertical 9209.5 feet Plugs (measured) Effective Depth measured 10560 feet true vertical 9185.5 feet Junk (measured) Casing Length Size MD TVD Conductor 91 30" Conductor 40 - 131 40.0 - 131.0 Liner 4834 7" 29# L-80 9104 - 13938 8564.7 - 10065.3 Liner 799 4-1/2" 12.6# L-80 13851 - 14650 10057.7 - 10124.9 Production 8881 9-5/8" 47# L-80 38 - 8919 38.0 - 8426.5 Production 1015 9-5/8" 47# NT95HS 8919 - 9934 8426.5 - 9023.4 Surface 2444 13-3/8" 68# L-80 39 - 2483 39.0 - 2482.1 Perforation decth: Measured depth: 13590 -13610,14080 -14170 True vertical depth: 10036.5 -10039.38, 10076.94 -10085.44 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 @ 36 9543 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: @ 9444 13 OtherD 6. API Number 50-029-21722-01-00 None 14425 Burst Collapse 8160 7020 8430 7500 6870 4760 8150 5080 4930 2270 Prior to well operation: Subsequent to operation: Oil-Bbl 174 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 6 839 Tubing Pressure 278 280 169 6 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Copies of Logs and Surveys run - 1085 Development Œ] Service D 16. Well Status after proposed work: Operational Shutdown 0 OilŒ) GasO WAG 0 GINJO WINJD WDSPLO Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Æd~~ Phone 564-4657 Production Technical Assistant 6/16/04 Title Signature Form 10-404 Revised 12/2003 OR\G\NAl 'S l Date 1M 1< "I - ( ( 1-25A1K-22 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/29/04 MIRU FOR PERF JOB. MU/RIH WI 20' X 2 7/8" DUMMY GUN DRIFT. DRIFT TO 144251, NO TAG. POOH. CONTINUED ON 04/30104 WSR. 04/30104 CONTINUED FROM 04/29/04 WSR. OUT OF HOLE WI 201 DUMMY GUN. MUIRIH WI PDS MEM GRICCL IN CARRIER. TAG LINER TOP @ 138261 (UP WT), CANNOT GET INTO LINER. LOG FROM 13,8261-132001 WI FLAGS @ 135401 & 138001. POOH. MU/RIH W/2- 7/81\ GUN #1. CANNOT PASS THROUGH 4-1/211 LINER. SHOOT 135901-136101. POOH. RDMO. WELL READY TO POP. FLUIDS PUMPED BBLS 111 145 256 50/50 Methanal Sea Water TOTAL Page 1 ( R.T. ELEV = B.F. ELEV = MAX DEV = 55.3' 15.4' 88.55' @14452.04' 13-3/8"CSG SHOE I 2483' I >.4 TOP OF T' LINER 1 9104' > - 9-5/8" SIDETRAC~ WIN9°W "PERFORATING SUMMARY Ref Log: MD GR/R 5/21/97 Si7e SPF Interval 3-3/8" 6 14080' - 14170' TOP OF 4-1/2" LINER -113851' ~J ~TM OF SHOE -113938' L. 7' , 29#1ft, L-80, 4.5", 12.6#/ft, L-80, 1ST mod -. PBTD 1 14650' I > XX Date By Comments 5/28/97 RAC SIDE-TRACK ( III TREE: 4-1/16"/5000psi/CIW WELLHEAD: 13-518" / 5000 psi / CIW 8~ 1509' I OTIS HXO SVLN (3.813" 1.0.) . ~ 4-1/2", 12.6#1ft, L-80, IBM -< CAMCO (KGB-2-LS) GLM (BTM INTERGAL LATCHES) 1-1/4" .In(; PIJIIINr,TOOI ~ No. MD-BKB TVD-SS #6 3571' 3513' #5 5286' 5226' #4 6354' 6290' #3 7093' 6974' #2 8001' 7680' #1 8a46' 8301' .~ 4-1/2" 'X' NIPPLE I 9433' (3.813" 1.0.) Z ~ 9-5/8" PACKER I 9444' 1 (BAKER S-3) ". D r 4-1/2"'X'NIPPLE SWS (3.813" 1.0.) 4-1/2" 'XN' NIPPLE ~ SWN (3.725" 1.0.) 4-1/2" WLEG I 9509' I I 9531' I I 9543' I ELMO I I 9-5/8", 47#/fl NT95HS, NSCC 110717' I .". ~ '" ENDICOTT WELL: 1-25A1 K-22 API NO. 50-029-21722-01 COMPLETION DIAGRAM .. . B.P. EXPLORATION (ALASKA) INC. . ON OR BEFORE ANUARY 03 2001 c:LOt~VfflLl'a-DOC MEMORANDUM TO: THRU:- State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser,~[~-)~\~ Commissioner Tom Maunder, P. I. Supervisor~'~'-- ~-~.-~-.--0 ~( FROM: John Crisp, SUBJECT: Petroleum Inspector. DATE: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MPI I & 2 May 20,2001: I traveled to BP's Duck Island Unit Endicott Field to witness Safety Valve System tests. Mark Souve was BP's Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner, i witnessed one failure, the SSSV on well 1-19 failed to pass the DP test. The AOGCC test report is attached for reference. i inspected 25 well houses on MPi Row I & 2 w/no problems witnessed. SUMMARY: I witnessed SVS testing in BP's Endicott Field. 17 wells, 51 components tested. 1 failure witnessed. 1.96% failure rate. 25 well houses inspected. Attachmen..ts: SVS DIU 5-20-01jc cc: ..NgN-C .O. NFIDENT,I .AL SVS DIU 5-20-01jc Alaska Oil and Gas Conservation Commi~.on Safety Valve System Test Report Operator: BPX Operator Rep: Mark Souve AOGCC Rep: John Crisp. .... Submitted By: John Crisp, Date: Field/UniffPad: Endicott DIU MPI Pad Separator psi: LPS 235 HPS 5/20/01 Well Pemit Separ Set L~ Test T~t Test Date oil WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed G~ or ~CLE 1-01/Jl~ 1880370 235 150 125 P P P OIL 1-03~16 1951500 235 150 135 P P P OIL 1-o~/O2o ~61o~o 1-o~~ ~7o~o ~ ~o ~o e ' ~ '~ ' 'o~ 1-15~25 1930560 1-1~1 1961990 ~-~1~ ~000~0 1-~~' ~9707~0 ~ ~0 l~o e' ~ e om 1-~7~o' ~7oo~o, ~ ~o ~ e e' " e ' o~ i-~~l ~o7~o ~ 1~o l:~ e e e" om 1~/o~ ~8~'4o: '~3 1~o ~ e e ~ o~ 1-39~ 17 1880630 1-47~ 1972030 1-49~21 1880780 23~ 150~ 130 'P "P P OIL 1-55~5 1880210 235 "150 145~ P P P OIL 1_~7~ ~8s~40 ~ ~0 ~no e"' e ~ ' 0~ ~:~/Q:o ~4~4~0 ~ ~0 ~ e ~ e 0~ 2-0n~l~ lS~OS2O :-o~/J:: ~s70~so :-os~ ~sSo04o 2,12/Q~6 ~21170 ~-~/0~ ~6~0 ~-~6 1~004~0 2-20~15 1900600 2-28~19 1880860 "' ~ , , , , 2-30~1 1981880 2-32/SN3 1901190 ...... , , 2-36/O14 1900240 2-38/SN1 1901290 ...... , , 2-fi~¢~ m ~ 1941520 I I I I I Il II I [ I ~V-';:' .'S,~o~ .'... .' R~t)!~'- '~?!~ Well/Type' Well Pemit Separ Set ~ Test Test Test Date ~ WAG, Gm J, Number Number PS! PSI ,Trip Code C0,de ,,~Code Passed G~,?,r c~c[~ 2-42m~3 ~as~4so 2-~Q~, ~9505~0" ~ .,. '.' ..... , , " 2-46B/S1 1971370] ' ' 2,4~/0~3 . '~95'!660 .... , , .., , , . . ,, , . , , . ,. 2-50~08 193~70 235 150 145 P P P OIL , , ,, . . 2-52/S14 1870920 2-56~I 1980580 ~ , , ,. . . .. . , , 2-ss/s09 ~9~520 2-60~3 ~930~36'~ 23s iso ~30 'P P" 'P ........ , , ,., .I , . .,.., 2-62/Q17 1861580 2-68/s~7~8~0970 ..... S..o~/s~7 .... ~801200 .......... , , , ,, .. . ..... , ,, , , ,. . ., Wells: 17 Components: 51 Failures: 1 Failure Rate: 1.96% r-! ~o Day Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD 97-075 97-075 97-075 97-075 97-075 97-075 CHEM CTTR 8079 D~/EW~4-TVD ~8682-10122 DGR/CNP/SLD-TVD ~/8682-10122 ./ DGR/CNP/SLD-MD .~/9267-14660 DGR/EWR4-TVD ~/9267-14660 ~/~963-4 - 9921 FINAL 07/18/97 ~.PERRY MPT/GR/EWR4/CNP/SLD/ROP 5-12 08/20/97 FINAL 08/27/97 FINAL 08/27/97 FINAL 08/27/97 FINAL 08/27/97 97-075 MWD SRVY ~ 9226.1-14660 10-407 ~C0NP~ETION D~TE @ i'll-Vigil ~in¥ wz~ o~s ~ ~ ¥/2t If?~ ?o ~-~"1~1 dry ditch samples required? yes ~And Are received? Was the well cored? yes ~ Analysis & description received? Are well tests required? yes ~o~_Received? ~e~- no Well is in compliance ~, Initial COMMENTS SPERR 09~27/97 ye~ ..... ~o_. T D BOX -- 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. 97-75 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ..... 50-029-21722-01 I I 4. Location of well at surface [~0~,¢TE~-I'0~-~'~ j ~ 9. Unit or Lease Name 3251' NSL, 2092' WEL, SEC. 36, T12N, R16E ! _ ,~^TE ~ ! ' 1, ~1~..," - -' Duck Island Unit/Endicott At top of productive interval !~,~~~~ 10. Well Number 4104' NSL, 1095' WEL, SEC. 31, T12N, R17E ! ~.lJ:l~--~ 1-25A/K-22 At tota, depth ~~~,~~ ~ ] ~ 11. Field and Pool 4558' NSL, 207' WEL, SEC. 31 T12N, R17E ~ ' - .................. ' .... Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56I ADL 31828 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 4-18-97 5-20-97 5-24-97 N/A MSLI One )~o a~pth (MD+TVD)10122 F,1118' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set121' Thickness °f Permafr°st10560 10105 FTI I~Yes I--1No 1509 MD 1465' (Approx.) 22. Type Electric or Other Logs Run MWD-GR, MWD-RES 23. CASING~ LINER AND CEMENTING RECORD CASING SEq-I-ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" . Structural casin9 driven 13-3/8" 68# L-80 0 2483 17" 3488 cuft permafroat 9-5/8" 47 L-80 0 8919 12.25 9-5/8" 47# NT95HT 8919 10717 12.25 575 cuft class G 7" 29 L-80 9104 13938 8.5 460 cuft Class G 4.5 12.6 L-80 13851 14650 6 129 cu ft 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) 3-3/8" Gun Diameter, 6 spf 4.5" 12.6# 9543 9444 MD TVD MD TVD 14080 - 14170 10076 - 10085 26. AmD, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9258 - 9307 55 bbl cement kickoff plug across section ;27. PRODUCTION TEST ...... Date First Production I Method of Operation (Flowing, gas lift, etc.) 6/1/97 J Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing ,Casing Pressure CALCULATED OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AU6 £ ? 1997 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. Top HRZ 11500 9376 LCU 12580 9650 Top Kekiktuk 12580 9650 31. List of Attachments Summary of Daily Drilling Reports, Surveys Signed ~- SteveShu~t~ Title Senior Drilling Engineer Date 1-25A/K-22 97-75 Prepared By Name/Number: Chris West, 564-5089 Well Number Permit No. / Approval No. ~NSTRUCTIONS 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 2?.' 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 Facility Date/Time 21 Apr 97 22 Apr 97 End MPI Progress Report Well 1-25A/K-22 Page 1 Rig Doyon 15 Date 25 August 97 08:30-13:00 08:30-09:00 09:00 09:00-13:00 13:00 13:00-17:30 13:00-17:30 17:30 17:30-18:30 17:30-18:00 18:00 18:00-18:30 18:30 18:30-19:00 18:30-19:00 19:00 19:00-22:00 19:00-20:00 20:00 20:00-22:00 22:00 22:00-00:00 22:00-22:30 22:30 22:30-23:30 23:30 23:30-00:00 00:00 00:00-06:00 00:00-03:30 03:30 03:30-06:00 06:00 06:00-13:00 06:00-06:30 06:30 06:30-13:00 13:00 13:00-15:00 13:00-15:00 15:00 15:00-16:00 15:00-16:00 16:00 16:00-18:00 16:00-16:30 16:30 16:30-17:00 17:00 17:00-18:00 18:00 18:00-22:00 18:00-18:30 18:30 Duration 4-1/2 hr 1/2 hr 4hr 4-1/2 hr 4-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr lhr 2hr 2hr 1/2 hr lhr 1/2 hr 6hr 3-1/2 hr 2-1/2 hr 7hr 1/2 hr 6-1/2 hr 2hr 2hr lhr lhr 2hr 1/2 hr 1/2 hr lhr 4hr 1/2hr Activity Move rig Held safety meeting Completed operations Rig moved 100.00 % At well location - Cellar Fluid system Fill pits with Seawater Completed operations Wellhead work Retrieved Hanger plug Equipment work completed Held safety meeting Completed operations Well control Bleed down well Completed operations Fluid system Reverse circulated at 250.00 ft Obtained clean returns - 10.00 % hole volume Circulated at 9924.00 ft Obtained clean returns - 100.00 % hole volume Wellhead work Installed Hanger plug Equipment work completed Removed Xmas tree Equipment work completed Removed Adapter spool Equipment work completed Nipple up All functions Rigged up All functions Equipment work completed Tested All functions Pressure test completed successfully - 5000.000 psi Nipple up All functions (cont...) Held safety meeting Completed operations Tested All functions Suspended test, surface equipment leaked Repair Repaired Choke manifold Equipment work completed Perform integrity test Tested Choke manifold Pressure test completed successfully - 5000.000 psi Wellhead work Rigged up Lubricator Equipment work completed Removed Hanger plug Equipment work completed Retrieved Tubing hanger Equipment work completed Pull Single completion, 4-1/2in O.D. Held safety meeting Completed operations Facility End MPI Progress Report Well 1-25A/K-22 Page 2 Rig Doyon 15 Date 25 August 97 Date/Time 23 Apr 97 24 Apr 97 18:30-19:30 19:30 19:30-20:30 20:30 20:30-21:00 21:00 21:00-22:00 22:00 22:00-23:00 22:00-22:30 22:30 22:30-23:00 23:00 23:00-06:00 23:00-01:30 01:30 01:30-06:00 06:00 06:00-08:30 06:00-06:30 06:30 06:30-08:00 08:00 08:00-08:30 08:30 08:30-09:00 08:30-09:00 09:00 09:00-14:30 09:00-09:30 09:30 09:30-11:00 11:00 11:00-14:00 14:00 14:00-14:30 14:30 14:30-15:30 14:30-15:30 15:30 15:30-06:00 15:30-18:00 18:00 18:00-18:30 18:30 18:30-20:00 20:00 20:00-20:30 20:30 20:30-04:30 04:30 04:30-06:00 Duration lhr lhr 1/2 hr lhr lhr 1/2 hr 1/2 hr 7hr 2-1/2 hr 4-1/2 hr 2-1/2 hr 1/2hr 1-1/2 hr 1/2 hr 1/2hr 1/2 hr 5-1/2 hr 1/2hr 1-1/2 hr 3hr 1/2 hr lhr lhr 14-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 8hr 1-1/2 hr Activity Rigged up Completion string handling equipment Equipment work completed Laid down 240.00 ft of Tubing Stopped: To flowcheck well Flow check Observed 0.500 bbl gain in annulus in 0.50 hr Circulated at 9684.00 ft In 0.08 hr had 10.000 bbl Gain - closed in well Bottom up gas Well control Circulated closed in well at 9684.00 ft Gas at surface Flow check Observed well static Pull Single completion, 4-1/2in O.D. Laid down 8293.00 ft of Tubing SCSSSV nipple assembly laid out Laid down 8000.00 ft of Tubing Stopped: To hold safety meeting Pull Single completion, 4-1/2in O.D. (cont...) Held safety meeting Completed operations Laid down 1900.00 ft of Tubing Completed operations Rigged down Tubing handling equipment Equipment work completed Wellhead work Installed Wear bushing Eqpt. work completed, running tool retrieved Electric wireline work Rigged up Logging/braided cable equipment Equipment work completed Conducted electric cable operations Completed logging run with Junk basket/gauge ring from 9927.00 ft Installed Bridge plug Equipment work completed Rigged down Logging/braided cable equipment Equipment work completed Perform integrity test Tested Casing Pressure test completed successfully - 3500.000 psi BHA run no. 1 Made up BHA no. 1 BHA no. 1 made up Held safety meeting Completed operations Singled in drill pipe to 1626.00 ft Stopped: To test equipment Functioned M.W.D. tool Equipment work completed Singled in drill pipe to 9885.00 ft At Setting depth: 9885.00 ft Set tool face 0.00 ft Facility End MPI Progress Report Well 1-25A/K-22 Page 3 Rig Doyon 15 Date 25 August 97 Date/Time 25 Apr 97 26 Apr 97 06:00 06:00-06:30 06:00-06:30 06:30 06:30-09:00 06:30-09:00 09:00 09:00-02:00 09:00-23:00 23:00 23:00-01:00 01:00 01:00-01:30 01:30 01:30-02:00 02:00 02:00-03:00 02:00-03:00 03:00 03:00-06:00 03:00-05:00 05:00 05:00-06:00 06:00 06:00-07:30 06:00-06:30 06:30 06:30-07:30 07:30 07:30-08:00 07:30-08:00 08:00 08:00-11:00 08:00-11:00 11:00 11:00-12:00 11:00-12:00 12:00 12:00-06:00 12:00-12:30 12:30 12:30-15:00 15:00 15:00-15:30 15:30 15:30-16:30 16:30 16:30-01:30 01:30 01:30-02:00 02:00 02:00-04:30 04:30 04:30-06:00 Duration 1/2 hr 1/2hr 2-1/2 hr 2-1/2 hr 17 hr 14hr 2hr 1/2 hr 1/2 hr lhr lhr 3hr 2hr lhr 1-1/2 hr 1/2hr lhr 1/2 hr 1/2hr 3hr 3hr lhr lhr 18hr 1/2 hr 2-1/2 hr 1/2 hr lhr 9hr 1/2 hr 2-1/2 hr 1-1/2 hr Activity Completed operations BHA run no. 1 (cont...) Held safety meeting Completed operations Fluid system Circulated at 9855.00 ft Hole displaced with Water based mud - 100.00 % displaced BHA run no. 1 '"-. Milled Casing at 9855.00 ft "M At Kick off depth · 9893.00 ft Circulated at 9893.00 ft Hole swept with slug - 200.00 % hole volume Flow check Observed well static Pulled out of hole to 8626.00 ft Stopped: To service drilling equipment Planned maintenance Serviced Block line Line slipped and cut BHA run no. 1 Pulled out of hole to 1326.00 ft At BHA Pulled BHA BHA Laid out BHA run no. 1 (cont...) Held safety meeting Completed operations Pulled BHA BHA Laid out Planned maintenance Serviced BOP stack Equipment work completed BHA run no. 2 Made up BHA no. 2 BHA no. 2 made up Planned maintenance Serviced Block line Line slipped and cut BHA run no. 2 Functioned M.W.D. tool Equipment work completed R.I.H. to 9760.00 ft Began precautionary measures Set tool face Completed operations Washed to 9893.00 ft Got stuck whilst pipe stationary Worked stuck pipe at 9893.00 ft Pipe came free Circulated at 9855.00 ft Heavy slug spotted downhole Pulled out of hole to 2502.00 ft At BHA Pulled BHA Facility Date/Time 27 Apr 97 End MPI Progress Report Well 1-25A/K-22 Page 4 Rig Doyon 15 Date 25 August 97 06:00 06:00-07:00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-08:30 07:00-08:00 08:00 08:00-08:30 08:30 08:30-10:00 08:30-09:30 09:30 09:30-10:00 10:00 10:00-16:30 10:00-12:00 12:00 12:00-12:30 12:30 12:30-14:00 14:00 14:00-16:30 16:30 16:30-17:00 16:30-17:00 17:00 17:00-19:00 17:00-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-04:30 19:00-20:30 20:30 20:30-22:30 22:30 22:30-01:30 01:30 01:30-02:00 02:00 02:00-04:30 04:30 04:30-05:30 04:30-05:30 05:30 05:30-06:00 05:30-06:00 06:00 06:00-06:30 06:00-06:30 Duration lhr 1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 1-1/2 hr lhr 1/2 hr 6-1/2 hr 2hr 1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 2hr lhr 1/2 hr 1/2 hr 9-1/2 hr 1-1/2 hr 2hr 3hr 1/2 hr 2-1/2 hr lhr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr Activity Stopped: To hold safety meeting BHA run no. 2 (cont...) Held safety meeting Completed operations Pulled BHA BHA Laid out BHA run no. 3 Made up BHA no. 3 BHA no. 3 made up R.I.H. to 3310.00 ft Stopped: To service drilling equipment Planned maintenance Serviced Block line Line slipped and cut Serviced Top drive Equipment work completed BHA run no. 3 R.I.H. to 9855.00 ft At Window: 9855.00 ft Reamed to 9855.00 ft Stopped: To circulate Circulated at 9855.00 ft Hole swept with slug - 100.00 % hole volume Pulled out of hole to 7000.00 ft Draw works failed - Abort operation Repair Repaired Draw works Equipment work completed BHA run no. 3 Pulled out of hole to 1400.00 ft AtBHA Held safety meeting Completed operations Pulled BHA BHA Stood back BHA run no. 4 Made up BHA no. 4 BHA no. 4 made up R.I.H. to 9855.00 ft At 9-5/8in casing shoe Milled Other sub-surface equipment at 9855.00 ft Completed operations Flow check Observed well static Pulled out of hole to 1520.00 ft At BHA Repair Repaired Top drive Equipment work completed BHA run no. 4 Pulled BHA Stopped: To hold safety meeting BHA run no. 4 (cont...) Held safety meeting Facility Date/Time 28 Apr 97 End MPI Progress Report Well 1-25A/K-22 Page 5 Rig Doyon 15 Date 25 August 97 06:30 06:30-09:30 06:30-09:30 09:30 09:30-10:30 09:30-10:30 10:30 10:30-22:00 10:30-12:30 12:30 12:30-13:30 13:30 13:30-17:00 17:00 17:00-17:30 17:30 17:30-20:30 20:30 20:30-22:00 22:00 22:00-06:00 22:00-01:00 01:00 01:00-03:00 03:00 03:00-04:30 04:30 04:30-06:00 06:00 06:00-17:30 06:00-06:30 06:30 06:30-08:30 08:30 08:30-09:00 09:00 09:00-11:00 11:00 11:00-11:30 11:30 11:30-13:00 13:00 13:00-16:00 16:00 16:00-17:00 17:00 17:00-17:30 17:30 17:30-22:00 17:30-20:00 20:00 20:00-22:00 22:00 22:00-23:30 Duration 3hr 3hr Ilar lhr 11-1/2 hr 2hr lhr 3-1/2 hr 1/2 hr 3hr 1-1/2 hr 8hr 3hr 2hr 1-1/2 hr 1-1/2 hr 11-1/2 hr 1/2 hr 2hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 3hr lhr 1/2 hr 4-1/2 hr 2-1/2 hr 2hr 1-1/2 hr Activity Completed operations 5in. Drillpipe workstring run Ran HWDP in stands to 1418.00 ft Stopped: To service drilling equipment Planned maintenance Serviced Block line Line slipped and cut 5in. Drillpipe workstring run Ran Drillpipe in stands to 9855.00 ft At Window: 9855.00 ft Washed to 9893.00 ft On bottom Circulated at 9893.00 ft Obtained req. fluid properties - 300.00 %, hole vol. Worked toolstring at 9893.00 ft Completed operations Pulled out of hole to 0.00 ft AtBHA Pulled out of hole to 0.00 ft At Wellhead: 0.00 ft BHA run no. 5 Made up BHA no. 5 BHA no. 5 made up R.I.H. to 9850.00 ft At Top of new hole section: 9850.00 ft Washed to 9893.00 ft On bottom Drilled to 9940.00 ft Stopped: To hold safety meeting BHA run no. 5 (cont...) Held safety meeting Completed operations Drilled to 9968.00 ft Began precautionary measures Pulled out of hole to 9768.00 ft At 9~5/8in casing shoe Circulated at 9768.00 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 9271.00 ft Began precautionary measures Circulated at 9271.00 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 2499.00 ft At BHA Pulled BHA BHA Stood back Held safety meeting Completed operations Electric wireline work Conducted electric cable operations Began precautionary measures Conducted electric cable operations Completed run with Downhole tools from 0.00 ft to 9700.00 ft 5in. Drillpipe workstring run Facility Date/Time 29 Apr 97 30 Apr 97 End MPI Progress Report Well 1-25A/K-22 Page 6 Rig Doyon 15 Date 25 August 97 22:00-23:30 23:30 23:30-00:30 23:30-00:30 00:30 00:30-06:00 00:30-03:30 03:30 03:30-06:00 06:00 06:00-06:30 06:00-06:30 06:30 06:30-10:30 06:30-07:00 07:00 07:00-10:30 10:30 10:30-11:00 10:30-11:00 11:00 11:00-06:00 11:00-12:00 12:00 12:00-16:00 16:00 16:00-17:00 17:00 17:00-18:00 18:00 18:00-18:30 18:30 18:30-06:00 06:00 06:00-19:30 06:00-06:30 06:30 06:30-12:30 12:30 12:30-15:00 15:00 15:00-17:30 17:30 17:30-18:30 18:30 18:30-19:00 19:00 19:00-19:30 19:30 19:30-00:30 19:30-22:30 22:30 22:30-00:30 Duration 1-1/2 hr lhr lhr 5-1/2 hr 3hr 2-1/2 hr 1/2 hr 1/2 hr 4hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 19 hr lhr 4hr lhr lhr 1/2 hr 11-1/2 hr 13-1/2 hr 1/2 hr 6hr 2-1/2 hr 2-1/2 hr lhr 1/2 hr 1/2 hr 5hr 3hr 2hr Activity Ran Drillpipe in stands to 2847.00 ft Stopped: To service drilling equipment Planned maintenance Serviced Block line Line slipped and cut 5in. Drillpipe workstring mn Ran Drillpipe in stands to 9418.00 ft Completed run with Bridge plug to 9418.00 ft Pulled out of hole to 0.00 ft Stopped' To hold safety meeting 5in. Drillpipe workstring run (cont...) Held safety meeting Completed operations Test well control equipment Retrieved Wear bushing Equipment work completed Tested BOP stack Pressure test completed successfully - 5000.000 psi Planned maintenance Serviced Top drive Equipment work completed BI-IA run no. 7 Made up BHA no. 7 BHA no. 7 made up R.I.H. to 9413.00 ft On bottom Circulated at 9413.00 ft Heavy slug spotted downhole Milled Casing at 9258.00 ft Began precautionary measures Held safety meeting Completed operations Milled Casing at 9292.00 ft Began precautionary measures Stopped for safety meeting. BI-IA run no. 7 (cont...) Held safety meeting Completed operations Milled Casing at 9307.00 ft Completed operations Circulated at 9307.00 ft Obtained clean returns - 200.00 % hole volume Pulled out of hole to 678.00 ft At BI-IA Pulled BI-IA BHA Stood back Held safety meeting 77i Completed operations Circulated at 0.00 ft Obtained clean returns - 100.00 % hole volume,(. 5in. Dfillpipe workstring run Ran Drillpipe in stands to 9413.00 ft ~ ~ .... ..... On bottom Circulated at 9413.00 ft Progress Report Facility End MPI Well 1-25A/K-22 Rig Doyon 15 Page 7 Date 25 August 97 Date/Time 01 May 97 02 May 97 00:30 00:30-01:00 00:30-01:00 01:00 01:00-02:30 01:00-01:30 01:30 01:30-02:30 02:30 02:30-03:30 02:30-03:30 03:30 03:30-06:00 03:30-06:00 06:00 06:00-06:30 06:00-06:30 06:30 06:30-10:00 06:30-08:00 08:00 08:00-10:00 10:00 10:00-13:30 10:00-13:30 13:30 13:30-23:00 13:30-15:30 15:30 15:30-18:00 18:00 18:00-18:30 18:30 18:30-19:30 19:30 19:30-21:30 21:30 21:30-23:00 23:00 23:00-01:00 23:00-01:00 01:00 01:00--02:00 01:00-02:00 02:00 02:00-06:00 02:00-03:30 03:30 03:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-18:00 Duration 1/2 hr 1/2 hr 1-1/2 hr 1/2hr lhr lhr lhr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 2hr 3-1/2 hr 3-1/2 hr 9-1/2 hr 2hr 2-1/2 hr 1/2 hr lhr 2hr 1-1/2 hr 2hr 2hr lhr lhr 4hr 1-1/2 hr 2-1/2 hr 24 hr 1/2 hr 11-1/2 hr Activity Obtained clean returns - 200.00 % hole volume Cement: Kickoff plug Mixed and pumped slurry - 55.000 bbl Cement pumped 5in. Drillpipe workstring run Pulled Drillpipe in stands to 8269.00 ft Stopped: To circulate Reverse circulated at 8269.00 ft Obtained clean returns - 100.00 % hole volume Cement: Kickoff plug Held 2000.0 psi pressure on 1.500 bbl squeezed cement Completed operations 5in. Drillpipe workstring run Pulled Drillpipe in stands to 0.00 ft Completed operations 5in. Drillpipe workstring run (cont...) Held safety meeting Completed operations BI-IA run no. 7 Made up BI-IA no. 7 BI-IA no. 7 made up R.I.H. to 8000.00 ft Began precautionary measures Cement: Kickoff plug Wait on cement Resumed operations BHA run no. 7 Washed to 9128.00 ft At Top of cement: 9128.00 ft Drilled cement to 9262.00 ft At Kick off depth: 9262.00 ft Held safety meeting Completed operations Circulated at 9262.00 ft M.W.D. tool failed - Abort operation Pulled out of hole to 2500.00 ft AtBHA Pulled BHA BI-IA Stood back BHA run no. 8 Made up BHA no. 8 BHA no. 8 made up Planned maintenance Serviced Block line Line slipped and cUt BI-IA run no. 8 R.I.H. to 9262.00 ft On bottom Drilled to 9275.00 ft Stopped: To hold safety meeting BHA run no. 8 (cont...) Held safety meeting Completed operations Circulated at 9439.00 ft Facility Date/Time 03 May 97 04 May 97 05 May 97 End MPI Progress Report Well 1-25A/K-22 Page 8 Rig Doyon 15 Date 25 August 97 18:00 18:00-18:30 18:30 18:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-10:00 10:00 10:00-10:30 10:30 10:30-11:00 11:00 11:00-18:00 18:00 18:00-18:30 18:30 18:30-03:30 03:30 03:30-04:30 04:30 04:30-05:00 05:00 05:00-05:30 05:30 05:30-06:00 06:00 06:00-10:00 06:00-06:30 06:30 06:30-09:00 09:00 09:00-10:00 10:00 10:00-06:00 10:00-11:00 11:00 11:00-14:00 14:00 14:00-15:00 15:00 15:00-18:00 18:00 18:00-18:30 18:30 18:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-15:30 15:30 15:30-16:30 Duration 1/2 hr 11-1/2 hr 24 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2hr 7hr 1/2 hr 9hr lhr 1/2 hr 1/2 hr 1/2 hr 4hr 1/2 hr 2-1/2 hr lhr 20 hr lhr 3hr lhr 3hr 1/2 hr 11-1/2 hr 24 hr 1/2hr 9hr lhr Activity Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 9716.00 ft Stopped: To hold safety meeting BHA run no. 8 (cont...) Held safety meeting Completed operations Drilled to 9782.00 ft Began precautionary measures Pulled out of hole to 9250.00 ft At top of check trip interval R.I.H. to 9782.00 ft On bottom Drilled to 10037.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 10164.00 ft ROP dropped from 25.0 ft/hr to 9.0 fl/hr - Bit quit Circulated at 10164.00 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 9204.00 ft Stopped: To circulate Circulated at 9204.00 ft Heavy slug spotted downhole Pulled out of hole to 7300.00 ft Stopped: To hold safety meeting BHA run no. 8 (cont...) Held safety meeting Completed operations Pulled out of hole to 3459.00 ft At BHA Pulled BHA BHA Stood back BHA run no. 9 Made up BHA no. 9 BHA no. 9 made up R.I.H. to 9182.00 ft Began precautionary measures Washed to 10164.00 ft On bottom Drilled to 10225.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 10470.00 ft Stopped: To hold safety meeting BHA run no. 9 (cont...) Held safety meeting Completed operations Drilled to 10725.00 ft Began precautionary measures Pulled out of hole to 9185.00 ft Facility End MPI Progress Report Well 1-25A/K-22 Page 9 Rig Doyon 15 Date 25 August 97 Date/Time 06 May 97 07 May 97 08 May 97 16:30 16:30-17:00 17:00 17:00-18:00 18:00 18:00-18:30 18:30 18:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-18:00 18:00 18:00-18:30 18:30 18:30-06:00 06:00 06:00-16:00 06:00-06:30 06:30 06:30-08:00 08:00 08:00-09:30 09:30 09:30-14:30 14:30 14:30-16:00 16:00 16:00-20:30 16:00-16:30 16:30 16:30-18:00 18:00 18:00-18:30 18:30 18:30-20:30 20:30 20:30-00:30 20:30-00:30 00:30 00:30-01:30 00:30-01:30 01:30 01:30-06:00 01:30-03:30 03:30 03:30-06:00 06:00 06:00-02:00 06:00-06:30 06:30 06:30-10:30 10:30 Duration 1/2 hr lhr 1/2 hr 11-1/2 hr 24 hr 1/2hr 11-1/2 hr 1/2 hr 11-1/2 hr 10hr 1/2 hr 1-1/2 hr 1-1/2 hr 5hr 1-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 4hr 4hr lhr lhr 4-1/2 hr 2hr 2-1/2 hr 20 hr 1/2 hr 4hr Activity At top of check trip interval R.I.H. to 10725.00 ft On bottom Drilled to 10765.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 11148.00 ft Stopped: To hold safety meeting BHA run no. 9 (cont...) Held safety meeting Completed operations Drilled to 11470.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 11800.00 ft Stopped: To hold safety meeting BHA run no. 9 (cont...) Held safety meeting Completed operations Drilled to 11865.00 ft Reached planned end of run - Maximum hours on bit Circulated at 11865.00 ft Obtained clean returns - 100.00 % hole volume Pulled out of hole to 3459.00 ft AtBHA Pulled BHA BHA Stood back Test well control equipment Retrieved Wear bushing Equipment work completed Tested BOP stack Began precautionary measures Held safety meeting Completed operations Tested BOP stack Pressure test completed successfully - 5000.000 psi BHA run no. 10 Made up BHA no. 10 B HA no. 10 made up Planned maintenance Serviced Block line Line slipped and cut BHA run no. 10 R.I.H. to 11320.00 ft Began precautionary measures Reamed to 11765.00 ft Stopped: To hold safety meeting BHA run no. 10 (cont...) Held safety meeting Completed operations Reamed to 11865.00 ft On bottom Ar~ci:ora~j~ Facility Date/Time 09 May 97 10 May 97 11 May 97 End MPI Progress Report Well 1-25A/K-22 Page Rig Doyon 15 Date 10 25 August 97 10:30-18:00 18:00 18:00-18:30 18:30 18:30-20:00 20:00 20:00-23:00 23:00 23:00-02:00 02:00 02:00-06:00 02:00-05:30 05:30 05:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-08:30 08:30 08:30-18:00 18:00 18:00-18:30 18:30 18:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-11:30 11:30 11:30-12:30 12:30 12:30-13:30 13:30 13:30-14:00 14:00 14:00-18:00 18:00 18:00-18:30 18:30 18:30-04:30 04:30 04:30-06:00 06:00 06:00-13:00 06:00-06:30 06:30 06:30-10:30 10:30 10:30-13:00 13:00 13:00-16:00 13:00-16:00 Duration 7-1/2 hr 1/2 hr 1-1/2 hr 3hr 3hr 4hr 3-1/2 hr 1/2 hr 24 hr 1/2 hr 2hr 9-1/2 hr 1/2hr 11-1/2 hr 24 hr 1/2 hr 5hr lhr lhr 1/2 hr 4hr 1/2 hr 10hr 1-1/2 hr 7hr 1/2 hr 4hr 2-1/2 hr 3hr 3hr Activity Drilled to 12120.00 ft LWD tool failed - Abort operation Held safety meeting Completed operations Circulated at 12120.00 ft Obtained clean returns - 100.00 % hole volume Pulled out of hole to 5403.00 ft At BHA Pulled BHA BHA Stood back BHA run no. 11 Made up BHA no. 11 BHA no. 11 made up R.I.H. to 7000.00 ft Stopped: To hold safety meeting BHA run no. 11 (cont...) Held safety meeting Completed operations R.I.H. to 12120.00 ft On bottom Drilled to 12340.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 12590.00 ft Stopped: To hold safety meeting BHA run no. 11 (cont...) Held safety meeting Completed operations Drilled to 12710.00 ft Began precautionary measures Circulated at 12710.00 ft Obtained clean returns - 100.00 % hole volume Pulled out of hole to 11223.00 ft At top of check trip interval R.I.H. to 12710.00 ft On bottom Drilled to 12790.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 13013.00 ft ROP dropped from 30.0 ft/hr to 12.0 ft/hr - Bit quit Circulated at 13013.00 ft Obtained clean returns - 100.00 % hole volume BHA run no. 11 (cont...) Held safety meeting Completed operations Pulled out of hole to 6359.00 ft At BHA Pulled BHA BHA Stood back BHA run no. 12 Made up BHA no. 12 Facility Date/Time 12 May 97 13 May 97 End MPI Progress Report Well 1-25A/K-22 Rig Doyon 15 16:00 16:00-17:00 16:00-17:00 17:00 17:00-06:00 Duration lhr lhr 13hr Activity BHA no. 12 made up Planned maintenance Serviced Block line Line slipped and cut BHA run no. 12 17:00-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-23:30 23:30 23:30-00:00 00:00 00:00-01:00 01:00 01:00-06:00 06:00 lhr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr lhr 5hr R.I.H. to 10559.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations R.I.H. to 12116.00 ft Began precautionary measures Reamed to 12371.00 ft Completed precautionary measures R.I.H. to 12850.00 ft Began precautionary measures Reamed to 13013.00 ft On bottom Drilled to 13138.00 ft Stopped: To hold safety meeting 06:00-10:30 06:00-06:30 06:30 06:30-10:30 10:30 10:30-11:00 10:30-11:00 11:00 11:00-06:00 11:00-18:00 18:00 18:00-18:30 18:30 18:30-03:30 03:30 03:30-05:00 05:00 05:00-06:00 06:00 06:00-13:30 06:00-06:30 06:30 06:30-11:00 11:00 11:00-13:30 13:30 13:30-06:00 13:30-17:00 17:00 17:00-18:00 18:00 18:00-18:30 18:30 18:30-20:30 20:30 4-1/2 hr 1/2 hr 4hr 1/2 hr 1/2 hr 19hr 7hr 1/2 hr 9hr 1-1/2 hr lhr 7-1/2 hr 1/2 hr 4-1/2 hr 2-1/2 hr 16-1/2 hr 3-1/2 hr lhr 1/2 hr 2hr Page Date BHA run no. 12 (cont...) Held safety meeting Completed operations Drilled to 13233.00 ft Stopped: To service drilling equipment Planned maintenance Serviced Brake Equipment work completed BHA run no. 12 Drilled to 13360.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 13488.00 ft Stopped: To circulate Circulated at 13488.00 ft Obtained clean returns - 100.00 % hole volume Pulled out of hole to 12538.00 ft Stopped: To hold safety meeting BHA run no. 12 (cont...) Held safety meeting Completed operations Pulled out of hole to 6358.00 ft At BHA Pulled BHA BHA Stood back BHA run no. 13 Made up BHA no. 13 BHA no. 13 made up Pumped out of hole to 9200.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations R.I.H. to 13228.00 ft Began precautionary measures 11 25 August 97 Facility Date/Time 14 May 97 15 May 97 16 May 97 Progress Report End MPI Well 1-25A/K-22 Page 12 Rig Doyon 15 Date 25 August 97 20:30-22:00 22:00 22:00-06:00 06:00 06:00-03:30 06:00-06:30 06:30 06:30-18:00 18:00 18:00-18:30 18:30 18:30-23:30 23:30 23:30-01:30 01:30 01:30-03:30 03:30 03:30-04:30 03:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00 06:00-20:00 06:00-06:30 06:30 06:30-11:30 11:30 11:30-12:00 12:00 12:00-12:30 12:30 12:30-15:00 15:00 15:00-18:00 18:00 18:00-18:30 18:30 18:30-19:30 19:30 19:30-20:00 20:00 20:00-06:00 20:00-21:00 21:00 21:00-21:30 21:30 21:30-03:30 03:30 03:30-04:00 04:00 04:00-05:00 05:00 05:00-06:00 Duration 1-1/2 hr 8hr 21-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 5hr 2hr 2hr lhr lhr 1-1/2 hr 1-1/2 hr 14hr 1/2hr 5hr 1/2 hr 1/2 hr 2-1/2 hr 3hr 1/2 hr lhr 1/2 hr 10hr lhr 1/2 hr 6hr 1/2 hr lhr lhr Activity Reamed to 13488.00 ft On bottom Drilled to 13610.00 ft Stopped: To hold safety meeting BHA run no. 13 (cont...) Held safety meeting Completed operations Drilled to 13870.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Drilled to 13948.00 ft Reached planned end of run - Section / well T.D. Circulated at 13948.00 ft Hole swept with slug - 100.00 % hole volume Pulled out of hole to 9200.00 ft At 9-5/8in casing shoe Planned maintenance Serviced Block line Line slipped and cut BHA run no. 13 R.I.H. to 13948.00 ft On bottom BHA run no. 13 (cont...) Held safety meeting Completed operations Circulated at 13948.00 ft Hole swept with slug - 150.00 % hole volume Pulled out of hole to 13100.00 ft Stopped: To flowcheck well Flow check Observed well static Pulled out of hole to 6351.00 ft AtBHA Pulled BHA Stopped: To hold safety meeting Held safety meeting Completed operations Downloaded MWD tool Completed operations Pulled BHA BHA Laid out Run Liner, 7in O.D. Rigged up Casing handling equipment Equipment work completed Held safety meeting Completed operations Ran Liner to 4815.00 ft (7in OD) Stopped: At sub-assembly Rigged down sub-surface equipment - Liner hanger Equipment work completed Circulated at 4850.00 ft String displaced with Water based mud - 100.00 % displaced Ran Liner on landing string to 6000.00 ft Facility Date/Time 17 May 97 End MPI Progress Report Well 1-25A/K-22 Page 13 Rig Doyon 15 Date 25 August 97 06:00 06:00-17:00 06:00-06:30 06:30 06:30-07:30 07:30 07:30-08:30 08:30 08:30-10:30 10:30 10:30-11:30 11:30 11:30-12:00 12:00 12:00-14:30 14:30 14:30-17:00 17:00 17:00-21:00 17:00-17:30 17:30 17:30-18:00 18:00 18:00-18:30 18:30 18:30-19:30 19:30 19:30-19:45 19:45 19:45-20:15 20:15 20:15-21:00 21:00 21:00-00:30 21:00-21:30 21:30 21:30-22:00 22:00 22:00-23:00 23:00 23:00-23:30 23:30 23:30-00:30 00:30 00:30-04:30 00:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00 06:00-08:30 06:00-06:30 06:30 06:30-08:00 Duration llhr 1/2 hr 1hr 2hr 1/2 hr 2-1/2 hr 2-1/2 hr 4hr 1/2 hr 1/2hr 1/2 hr 1hr 1/4 hr 1/2 hr 3/4 hr 3-1/2 hr 1/2 hr 1/2 hr 1hr 1/2 hr lhr 4hr 4hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2hr 1-1/2 hr Activity Stopped: To hold safety meeting Run Liner, 7in O.D. (cont...) Held safety meeting Completed operations Ran Liner on landing string to 9235.00 ft At 7in casing shoe Circulated at 9235.00 ft String displaced with Water based mud - 100.00 % displaced Ran Liner on landing string to 12305.00 ft Stopped: To circulate Circulated at 12305.00 ft Broke circulation Ran Liner on landing string to 13725.00 ft Observed 100000.00 lbf resistance Washed to 13948.00 ft On bottom Circulated at 13948.00 ft Obtained bottoms up (100% annulus volume) Cement: Liner cement Tested High pressure lines Pressure test completed successfully - 5000.000 psi Pumped Water spacers - volume 70.000 bbl Required volume of spacer pumped Held safety meeting Completed operations Circulated at 13948.00 ft Obtained bottoms up (100% annulus volume) Pumped Lo/Hi vis combination spacers - volume 70.000 bbl Required volume of spacer pumped Mixed and pumped slurry - 82.000 bbl Cement pumped Displaced slurry - 341.000 bbl Plug bumped Run Liner, 7in O.D. Set Tie back packer at 9107.00 ft with 4500.0 psi Packer set at 9107.00 ft Reverse circulated at 9107.00 ft String displaced with Water based mud - 110.00 % displaced Pulled Drillpipe in stands to 8157.00 ft Completed operations Rigged down High pressure lines Equipment work completed Laid down 7680.00 ft of 5in OD drill pipe Drillstring handling equipment failed - Change operation Repair Repaired Drillstring handling equipment Equipment work completed Run Liner, 7in O.D. Laid down 1500.00 ft of 5in OD drill pipe Stopped: To hold safety meeting Run Liner, 7in O.D. (cont...) Held safety meeting Completed operations Pulled Drillpipe in stands to 0.00 ft Facility Date/Time 18 May 97 ! End MPI Progress Report Well 1-25A/K-22 Page 14 Rig Doyon 15 Date 25 August 97 08:00 08:00-08:30 08:30 08:30-09:00 08:30-09:00 09:00 09:00-12:00 09:00-12:00 12:00 12:00-12:30 12:00-12:30 12:30 12:30-16:30 12:30-14:00 14:00 14:00-16:30 16:30 16:30 16:30-17:00 16:30-17:00 17:00 17:00-00:00 Duration 1/2 hr 1/2 hr 1/2hr 3hr 3hr 1/2 hr 1/2 hr 4hr 1-1/2 hr 2-1/2 hr 1/2hr 1/2 hr 7hr Activity Completed operations Retrieved Liner landing string Retrieved 0.00 ft from Setting tools Wellhead work Removed Wear bushing Equipment work completed Test well control equipment Tested All functions Pressure test completed successfully - 5000.000 psi Wellhead work Installed Wear bushing Eqpt. work completed, running tool retrieved BHA run no. 14 Made up BHA no. 14 BHA no. 14 made up Singled in drill pipe to 2500.00 ft 192 joints picked up Stopped: To service drilling equipment Planned maintenance Serviced Draw works Equipment work completed BHA run no. 14 17:00-18:00 18:00 18:00-18:30 18:30 18:30-21:00 21:00 21:00-21:30 21:30 21:30-00:00 00:00 lhr 1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr Singled in drill pipe to 4800.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Singled in drill pipe to 6300.04 ft 192 joints picked up Rigged up Drillstring handling equipment Equipment work completed R.I.H. to 8100.00 ft Stopped: To service drilling equipment 00:00-01:00 00:00-01:00 01:00 01:00-06:00 01:00-01:30 01:30 01:30-02:00 02:00 02:00-04:30 04:30 04:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-07:30 07:30 07:30-18:00 lhr lhr 5hr 1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 24 hr 1/2 hr lhr 10-1/2 hr Planned maintenance Serviced Block line Line slipped and cut BHA run no. 14 R.I.H. to 13849.00 ft At Float collar: 13849.00 ft Tested Liner - Via annulus and string Pressure test completed successfully - 3500.000 Drilled installed equipment - Float shoe Completed operations Circulated at 13936.00 ft Stopped: To hold safety meeting BHA run no. 14 (cont...) Held safety meeting Completed operations Circulated at 13938.00 ft Obtained req. fluid properties - 150.00 %, l~e ~[~. ,~ Drilled to 14185.00 fl .h~ ? 18:00 18:00-18:30 18:30 18:30-06:00 1/2 hr 11-1/2 hr Stopped · To hold safety meeting Held safety meeting Completed operations Drilled to 14500.00 ft Facility Date/Time 19 May 97 20 May 97 21 May 97 End MPI Progress Report Well 1-25A/K-22 Page Rig Doyon 15 Date 06:00 06:00-20:00 06:00-06:30 06:30 06:30-11:00 11:00 11:00-12:00 12:00 12:00-18:00 18:00 18:00-18:30 18:30 18:30-19:30 19:30 19:30-20:00 20:00 20:00-20:30 20:00-20:30 20:30 20:30-06:00 20:30-21:30 21:30 21:30-23:00 23:00 23:00-23:30 23:30 23:30-02:30 02:30 02:30-06:00 06:00 06:00-06:00 06:00-06:30 06:30 06:30-18:00 18:00 18:00-18:30 18:30 18:30-20:00 20:00 20:00-20:30 20:30 20:30-21:00 21:00 21:00-00:30 00:30 00:30-01:00 01:00 01:00-01:30 01:30 01:30-04:30 04:30 04:30-05:00 05:00 05:00-06:00 Duration 14hr 1/2 hr 4-1/2 hr 6hr 1/2hr lhr 1/2 hr 1/2 hr 1/2 hr 9-1/2 hr lhr 1-1/2 hr 1/2 hr 3hr 3-1/2 hr 24 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr lhr Activity Stopped: To hold safety meeting BHA run no. 14 (cont...) Held safety meeting Completed operations Drilled to 14533.00 ft Walk & build rate unacceptable - BHA Circulated at 14533.00 ft Obtained bottoms up (100% annulus volume) Pulled out of hole to 186.30 ft At BHA Held safety meeting Completed operations Downloaded MWD tool Completed operations Pulled BHA BHA Stood back Planned maintenance Serviced Top drive Equipment work completed BHA run no. 15 Made up BHA no. 15 BHA no. 15 made up R.I.H. to 6300.00 ft At 9-5/8in casing shoe Serviced Drillstring handling equipment Equipment work completed R.I.H. to 14533.00 ft On bottom Drilled to 14560.00 ft Stopped: To hold safety meeting BHA run no. 15 (cont...) Held safety meeting Completed operations Drilled to 14660.00 ft Reached planned end of run - Section / well T.D. Held safety meeting Completed operations Circulated at 14660.00 ft Hole swept with slug - 100.00 % hole volume Pulled out of hole to 13930.00 ft At 7in casing shoe R.I.H. to 14660.00 ft On bottom Circulated at 14660.00 ft Hole swept with slug - 200.00 % hole volume Pulled out of hole to 13900.00 ft At 7in casing shoe Flow check Observed well static Pulled out of hole to 6300.00 ft Stopped: To change handling equipment Rigged up Drillstring handling equipment Equipment work completed Pulled out of hole to 3000.00 ft 15 25 August 97 Facility Date/Time 22 May 97 Progress Report End MPI Well 1-25A/K-22 Page 16 Rig Doyon 15 Date 25 August 97 06:00 06:00-09:00 06:00-06:30 06:30 06:30-07:30 07:30 07:30-08:00 08:00 08:00-09:00 09:00 09:00-23:00 09:00-09:30 09:30 09:30-10:00 10:00 10:00-11:00 11:00 11:00-11:30 11:30 11:30-12:00 12:00 12:00-18:00 18:00 18:00-18:30 18:30 18:30-21:00 21:00 21:00-21:30 21:30 21:30-22:00 22:00 22:00-23:00 23:00 23:00-00:30 23:00-23:30 23:30 23:30-23:45 23:45 23:45-00:00 00:00 00:00-00:30 00:30 00:30-02:30 00:30-00:45 00:45 00:45-01:00 01:00 01:00-01:30 01:30 01:30-02:00 02:00 02:00-02:30 02:30 02:30-03:30 Duration 3hr 1/2 hr lhr 1/2 hr lhr 14hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2hr 6hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr lhr 1-1/2 hr 1/2hr 1/4 hr 1/4 hr 1/2hr 2hr 1/4 hr 1/4hr 1/2hr 1/2 hr 1/2 hr lhr Activity Stopped: To hold safety meeting BHA run no. 15 (cont...) Held safety meeting Completed operations Pulled out of hole to 186.00 ft AtBHA Downloaded MWD tool Completed operations Pulled BHA BHA Laid out Run Liner, 4-1/2in O.D. Rigged up Casing handling equipment Equipment work completed Held safety meeting Completed operations Ran Liner to 813.00 ft (4-1/2in OD) Hanger assembly installed Rigged up Drillstring handling equipment Equipment work completed Circulated at 813.00 ft Broke circulation Ran Liner on landing string to 9702.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Ran Liner on landing string to 13938.00 ft At 7in casing shoe Circulated at 13938.00 ft Broke circulation Ran Liner on landing string to 14660.00 ft On bottom Circulated at 14660.00 ft Obtained bottoms up (100% annulus volume) Cement: Liner cement Tested High pressure lines Pressure test completed successfully - 4000.000 psi Pumped Lo/Hi vis combination spacers - volume 70.000 bbl Required volume of spacer pumped Mixed and pumped slurry - 23.000 bbl Cement pumped Displaced slurry - 188.000 bbl Plug bumped Run Liner, 4-1/2in O.D. Set Liner hanger at 13850.00 ft with 3500.0 psi Equipment work completed Set Tie back packer at 13848.00 ft with 0.0 psi Packer set at 13848.00 ft Reverse circulated at 13839.00 ft String displaced with Water based mud - 200.00 % displaced Pulled Drillpipe in stands to 12896.00 ft Stopped: To circulate Rigged down High pressure lines Equipment work completed Planned maintenance Facility Date/Time 23 May 97 End MPI Progress Report Well 1-25A/K-22 Page 17 Rig Doyonl5 Date 25August97 02:30-03:30 03:30 03:30-06:00 03:30-06:00 06:00 06:00-08:30 06:00-06:30 06:30 06:30-08:00 08:00 08:00-08:30 08:30 08:30-21:00 08:30-09:30 09:30 09:30-11:30 11:30 11:30-12:00 12:00 12:00-13:30 13:30 13:30-14:00 14:00 14:00-16:00 16:00 16:00-18:00 18:00 18:00-18:30 18:30 18:30-21:00 21:00 21:00-06:00 21:00-00:30 00:30 00:30-01:30 01:30 01:30-05:30 05:30 05:30-06:00 06:00 06:00-09:00 06:00-06:30 06:30 06:30-08:00 08:00 08:00-09:00 09:00 09:00-13:00 09:00-13:00 13:00 13:00-19:30 13:00-18:00 18:00 Duration lhr 2-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 12-1/2 hr lhr 2hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 2hr 1/2 hr 2-1/2 hr 9hr 3-1/2 hr lhr 4hr 3hr 1/2 hr 1-1/2 hr lhr 4hr 4hr 6-1/2 hr 5hr Activity Serviced Block line Line slipped and cut Run Liner, 4-1/2in O.D. Pulled Drillpipe in stands to 6300.00 ft Stopped: To hold safety meeting Run Liner, 4-1/2in O.D. (cont...) Held safety meeting Completed operations Pulled Drillpipe in stands to 0.00 ft Completed operations Removed Casing handling equipment Equipment work completed 2-7/8in. Drillpipe workstring run Rigged up Drillstring handling equipment Equipment work completed Ran Drillpipe to 1117.00 ft (2-7/8in OD) Stopped: To circulate Circulated at 1117.00 ft Broke circulation Ran Drillpipe in stands to 6945.00 ft Stopped: To change handling equipment Rigged up Drillstring handling equipment Equipment work completed Ran Drillpipe in stands to 14480.00 ft At Top of cement: 14480.00 ft Circulated at 14480.00 ft Stopped: To hold safety meeting Held safety meeting Completed operations Reverse circulated at 14480.00 ft Obtained clean returns - 50.00 % hole volume BHA run no. 16 Drilled cement to 14560.00 ft Completed operations Tested Casing - Via annulus and string Pressure test completed successfully - 3500.000 psi Circulated at 14560.00 ft Hole displaced with Brine - 100.00 % displaced 9.6 ppg brine Cleared Flowline Equipment work completed BHA run no. 16 (cont...) Held safety meeting Completed operations Cleared Mud shakers Equipment work completed Tested Tubular strings - Via annulus and string Pressure test completed successfully - 3250.000 p.~' ,~,? ~ ~, i ~# il Fluid system Filter Brine Obtained req. fluid properties- 100.00 %, hole vol./~ [}C) ~ 5in. Drillpipe workstring run Laid down 5980.00 fl of Drillpipe Stopped' To hold safety meeting "' Facility Date/Time 24 May 97 End MPI Progress Report Well 1-25A/K-22 Page 18 Rig Doyonl5 Date 25August97 18:00-18:30 18:30 18:30-19:30 19:30 19:30-23:00 19:30-23:00 23:00 23:00-01:00 23:00-01:00 01:00 01:00-01:30 01:00-01:30 01:30 01:30-06:00 01:30-02:00 02:00 02:00-06:00 06:00 06:00-14:00 06:00-06:30 06:30 06:30-11:00 11:00 11:00-11:30 11:30 11:30-14:00 14:00 14:00-14:30 14:00-14:30 14:30 14:30-15:00 14:30-15:00 15:00 15:00-17:30 15:00-17:30 17:30 17:30-01:30 17:30-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-19:30 19:30 19:30-20:00 20:00 20:00-23:00 23:00 23:00-23:30 Duration 1/2 hr lhr 3-1/2 hr 3-1/2 hr 2hr 2hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 4hr 8hr 1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 8hr 1/2 hr 1/2 hr 1/2 hr Activity Held safety meeting Completed operations Laid down 7260.00 ft of Drillpipe Completed operations 3-1/2in. Drillpipe workstring run Laid down 5500.00 ft of Drillpipe Completed operations 2-7/8in. Drillpipe workstring run Laid down 800.00 ft of Drillpipe Completed operations Wellhead work Removed Wear bushing Equipment work completed Run Single completion, 4-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed Ran Tubing to 9544.00 ft (4-1/2in OD) Stopped: To hold safety meeting Run Single completion, 4-1/2in O.D. (cont...) Held safety meeting PJSM on running completion Completed operations Ran Tubing to 8000.00 ft (4-1/2in OD) SCSSSV nipple assembly installed Tested Dual control line Pressure test completed successfully - 5000.000 psi Ran Tubing to 9543.00 ft (4-1/2in OD) At Setting depth: 9543.00 ft Wellhead work Installed Tubing hanger Equipment work completed Run Single completion, 4-1/2in O.D. Tested Dual control line Pressure test completed successfully - 5000.000 psi Fluid system Reverse circulated at 9543.00 ft Hole displaced with Inhibited brine - 100.00 % displaced Run Single completion, 4-1/2in O.D. Installed Tubing hanger Landed hanger Tie-down bolts energised Held safety meeting PJSM on Nippling down BOPE & installing tree Completed operations Set Permanent packer at 9444.00 ft with 4000.0 psi Held 30 min for tbg test. Packer set at 9444.00 ft Tested Casing Pressure test completed successfully - 3500.000 psi Installed Hanger plug Equipment work completed Removed BOP stack Equipment work completed Installed Adapter spool Facility Date/Time 25 May 97 End MPI Progress Report Well 1-25A/K-22 Page Rig Doyon 15 Date 19 25 August 97 23:30 23:30-00:00 00:00 00:00-00:30 00:30 00:30-01:30 01:30 01:30-03:00 01:30-03:00 03:00 03:00-06:00 03:00-03:30 03:30 03:30-04:30 04:30 Duration 1/2 hr 1/2 hr lhr 1-1/2 hr 1-1/2 hr 3hr 1/2hr 1hr Activity Equipment work completed Installed Surface tree Equipment work completed Tested Xmas tree equipment Pressure test completed successfully - 5000.000 psi Retrieved Hanger plug Equipment work completed Fluid system Freeze protect well - 35.000 bbl of Diesel Completed operations Run Single completion, 4-1/2in O.D. Installed Hanger plug Eqpt. work completed, running tool retrieved Rigged down ESD system Equipment work completed SP: IY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 1-25A/K-22 500292172201 NORTH SLOPE BOROUGH COMPUTATION DATE: 6 / 4 / 97 DATE OF SURVEY: 052097 MWD SURVEY JOB NUMBER: AK-MM-70112 KELLY BUSHING ELEV. = 56.00 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. 9226.10 8655.23 8599.23 41 25 9268.00 8686.67 8630.67 41 20 9328.63 8731.68 8675.68 42 46 9361.01 8754.85 8698.85 45 50 9391.59 8775.71 8719.71 48 7 S 86.06 E .00 86.52S 1876.66E S 86.15 E .24 88.40S 1904.30E S 89.36 E 4.25 89.98S 1944.87E N 89.08 E 10.06 89.91S 1967.49E N 87.69 E 8.19 89.28S 1989.83E 1779.06 1805.10 1843.64 1865.39 1887.03 9423.19 8796.37 8740.37 50 13 9455.71 8816.75 8760.75 52 7 9487.52 8836.00 8780.00 53 25 9518.84 8854.34 8798.34 54 52 9551.48 8872.77 8816.77 56 20 N 87.10 E 6.76 88.19S 2013.71E N 85.65 E 6.80 86.58S 2038.99E N 84.42 E 5.14 84.39S 2064.22E N 83.97 E 4.74 81.82S 2089.48E N 81.53 E 7.66 78.42S 2116.19E 1910.28 1935.01 1959.86 1984.83 2011.44 9583.22 8889.97 8833.97 58 1 9614.64 8906.17 8850.17 59 52 9646.95 8921.98 8865.98 61 31 9678.85 8936.78 8880.78 63 10 9709.65 8950.25 8894.25 64 57 N 79.91 E 6.81 74.11S 2142.51E N 80.04 E 5.90 69.43S 2169.01E N 78.46 E 6.65 64.17S 2196.69E N 76.66 E 7.19 58.08S 2224.28E N 74.25 E 9.11 51.12S 2251.08E 2037.92 2064.69 2092.74 2120.93 2148.62 9745.23 8964.75 8908.75 66 55 9775.12 8976.07 8920.07 68 34 9809.95 8988.15 8932.15 70 49 9841.90 8997.99 8941.99 73 16 9904.40 9014.95 8958.95 75 14 N 74.69 E 5.65 42.42S 2282.38E N 77.55 E 10.42 35.79S 2309.24E N 78.16 E 6.69 28.92S 2341.17E N 79.17 E 8.24 22.95S 2370.97E N 79.34 E 3.15 11.74S 2430.06E 2181.10 2208.74 2241.32 2271.61 2331.50 10001.02 9040.76 8984.76 10095.00 9067.21 9011.21 10196.29 9093.72 9037.72 10290.76 9116.66 9060.66 10386.91 9140.87 9084.87 73 73 76 75 75 46 33 5 47 3 N 77.16 E 2.65 7.21N 2521.21E N 74.18 E 3.05 29.53N 2608.58E N 76.00 E 3.06 54.67N 2703.03E N 75.72 E .44 77.06N 2791.90E N 75.10 E .99 100.50N 2881.95E 2424.33 2514.45 2612.18 2703.77 2796.78 10482.76 9165.45 9109.45 75 13 10578.66 9189.30 9133.30 75 57 10673.29 9211.77 9155.77 76 34 10768.33 9234.10 9178.10 76 15 10866.36 9258.22 9202.22 75 15 N 74.79 E .36 124.56N 2971.41E N 75.46 E 1.02 148.40N 3061.18E N 76.02 E .86 171.05N 3150.27E N 75.57 E .57 193.72N 3239.82E N 75.21 E 1.07 217.68N 3331.76E 2889.41 2982.27 3074.15 3166.48 3261.45 10963.35 9283.69 9227.69 11059.03 9310.71 9254.71 11154.44 9338.50 9282.50 11250.63 9365.99 9309.99 11344.99 9391.96 9335.96 74 18 72 53 73 14 73 33 74 30 N 74.89 E 1.04 241.82N 3422.18E N 73.95 E 1.75 266.47N 3510.58E N 74.75 E .88 291.09N 3598.47E N 75.28 E .62 314.92N 3687.51E N 77.08 E 2.09 336.59N 3775.59E 3355.02 3446.79 3538.06 3630.22 3720.85 ORIgINaL SF~RY-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE 2 SHARED SERVICES DRILLING ENDICOTT / 1-25A/K-22 500292172201 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 4/97 DATE OF SURVEY: 052097 MWD SURVEY JOB NUMBER: AK-MM-70112 KELLY BUSHING ELEV. = 56.00 FT. OPERJ~TOR: 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. 11440.01 9416.70 9360.70 11535.61 9439.80 9383.80 11633.79 9462.65 9406.65 11730.30 9485.25 9429.25 11828.21 9506.65 9450.65 75 19 N 79.63 E 2.73 355.10N 3865.44E 76 42 N 80.45 E 1.68 371.14N 3956.80E 76 22 N 80.20 E .43 387.19N 4050.92E 76 33 N 80.35 E .24 403.04N 4143.40E 78 11 N 83.30 E 3.39 416.61N 4237.96E 3812.30 3904.53 3999.41 4092.66 4187.27 11909.90 9523.68 9467.68 12005.92 9544.89 9488.89 12101.40 9567.45 9511.45 12198.22 9591.78 9535.78 12291.14 9616.90 9560.90 77 43 N 83.31 E .58 425.93N 4317.31E 76 45 N 84.10 E 1.30 436.19N 4410.39E 75 54 N 84.04 E .88 445.78N 4502.66E 74 59 N 81.57 E 2.65 457.51N 4595.61E 73 37 N 80.74 E 1.70 471.26N 4684.00E 4266.09 4358.37 4449.69 4542.24 4630.98 12387.45 9644.92 9588.92 12484.53 9674.63 9618.63 12580.10 9704.90 9648.90 12675.06 9735.66 9679.66 12770.68 9767.15 9711.15 72 33 N 79.28 E 1.83 487.24N 4774.74E 71 48 N 76.88 E 2.47 506.32N 4865.15E 71 16 N 73.28 E 3.62 529.65N 4952.73E 70 55 N 71.49 E 1.82 556.83N 5038.34E 70 37 N 69.76 E 1.73 586.78N 5123.51E 4722.59 4814.74 4905.36 4995.15 5085.28 12867.52 9800.06 9744.06 12964.01 9833.55 9777.55 13058.16 9866.56 9810.56 13154.57 9901.09 9845.09 13249.43 9936.19 9880.19 69 38 N 66.28 E 3.53 620.86N 5207.95E 69 45 N 65.47 E .80 657.84N 5290.54E 69 11 N 67.37 E 1.98 693.11N 5371.33E 68 50 N 67.04 E .48 727.99N 5454.32E 67 43 N 66.09 E 1.50 763.03N 5535.17E 5175.86 5265.47 5352.88 5442.28 5529.67 13344.68 9972.68 9916.68 13379.23 9985.34 9929.34 13409.69 9995.25 9939.25 13442.26 10004.59 9948.59 13476.80 10013.09 9957.09 67 13 N 65.16 E 1.04 799.34N 5615.31E 69 46 N 64.40 E 7.63 813.04N 5644.38E 72 16 N 63.54 E 8.63 825.68N 5670.26E 74 22 N 63.78 E 6.52 839.52N 5698.22E 77 9 N 64.18 E 8.10 854.20N 5728.30E 5616.74 5648.47 5676.84 5707.54 5740.52 13509.11 10020.22 9964.22 13538.36 10026.35 9970.35 13572.04 10032.71 9976.71 13602.95 10037.61 9981.61 13634.24 10041.52 9985.52 77 20 N 64.39 E .86 867.87N 5756.70E 78 26 N 65.33 E 4.93 880.02N 5782.58E 79 48 N 66.31 E 4.92 893.57N 5812.75E 81 56 N 65.90 E 7.08 905.93N 5840.65E 83 41 N 67.29 E 7.10 918.26N 5869.14E 5771.59 5799.83 5832.57 5862.80 5893.59 13667.32 10044.45 9988.45 13699.21 10046.32 9990.32 13731.47 10048.00 9992.00 13763.54 10049.89 9993.89 13795.56 10052.15 9996.15 86 9 N 68.92 E 8.91 930.54N 5899.71E 87 7 N 68.48 E 3.37 942.11N 5929.37E 86 53 N 68.21 E 1.12 953.99N 5959.31E 86 21 N 68.24 E 1.66 965.87N 5989.04E 85 31 N 68.89 E 3.31 977.54N 6018.77E 5926.37 5958.07 5990.14 6021.99 6053.79 SD .... ~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING ENDICOTT / 1-25A/K-22 500292172201 NORTH SLOPE BOROUGH COMPUTATION DATE: 6 / 4 / 97 DATE OF SURVEY: 052097 MWD SURVEY JOB NUMBER: AK-MM-70112 KELLY BUSHING ELEV. = 56.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 13826.00 10054.67 9998.67 85 0 13858.79 10057.64 10001.64 84 35 13939.61 10064.61 10008.61 85 31 13974.34 10067.33 10011.33 85 28 14007.57 10069.93 10013.93 85 33 N 68.72 E 1.80 988.51N 6047.05E 6084.01 N 69.07 E 1.64 1000.27N 6077.51E 6116.54 N 63.30 E 7.21 1032.77N 6151.14E 6196.29 N 60.83 E 7.09 1048.99N 6181.73E 6230.17 N 58.47 E 7.09 1065.72N 6210.31E 6262.27 14033.9 14132.5 14227.0 14323.3 14418.5 1 10072.06 10016.06 85 9 0 10081.20 10025.20 84 11 7 10088.43 10032.43 87 2 2 10094.22 10038.22 86 3 9 10098.78 10042.78 88 26 N 58.16 E 1.92 1079.51N 6232.65E 6287.56 N 57.97 E .99 1131.43N 6315.95E 6382.00 N 55.75 E 3.81 1182.98N 6394.89E 6472.14 N 55.13 E 1.20 1237.48N 6474.01E 6563.27 N 53.86 E 2.84 1292.74N 6551.47E 6653.01 14452.0 14481.9 14512.9 14547.7 14579.8 4 10099.66 10043.66 88 33 2 10100.53 10044.53 88 7 1 10101.58 10045.58 87 58 9 10103.72 10047.72 85 0 5 10107.58 10051.58 81 10 N 55.04 E 3.54 1312.18N 6578.68E 6684.54 N 55.29 E 1.66 1329.24N 6603.19E 6712.82 N 55.11 E .76 1346.91N 6628.62E 6742.16 N 55.09 E 8.49 1366.83N 6657.17E 6775.11 N 57.80 E 14.62 1384.42N 6683.69E 6805.47 14596.60 10110.47 10054.47 78 53 N 58.23 E 13.84 14660.00 10127.29 10071.29 70 18 N 58.23 E 13.53 1393.16N 6697.68E 6821.33 1425.31N 6749.59E 6880.13 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6898.44 FEET AT NORTH 78 DEG. 4 MIN. EAST AT MD = 14660 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 73.90 DEG. TIE-IN SURVEY AT 9,226.10' MD WINDOW POINT AT 9,268.00' MD PROJECTED SURVEY AT 14,660.00' MD S¥~---~RY-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 1-25A/K-22 500292172201 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 4/97 DATE OF SURVEY: 052097 JOB NUMBER: AK-MM-70112 KELLY BUSHING ELEV. = 56.00 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 9226.10 8655.23 8599.23 86.52 S 1876.66 E 10226.10 9100.88 9044.88 61.67 N 2731.11 E 11226.10 9359.04 9303.04 308.94 N 3664.76 E 12226.10 9599.00 9543.00 461.46 N 4622.25 E 13226.10 9927.35 9871.35 754.28 N 5515.43 E 570.87 1125.22 554.35 1867.06 741.84 2627.10 760.04 3298.75 671.65 14226.10 10088.38 10032.38 1182.43 N 6394.09 E 14660.00 10127.29 10071.29 1425.31 N 6749.59 E 4137.72 838.97 4532.71 394.98 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP~ RY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 1-25A/K-22 500292172201 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 4/97 DATE OF SURVEY: 052097 JOB AKIMBER: AK-MM-70112 KELLY BUSHING ELEV. = 56.00 OPER3~TOR: 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 9226.10 8655.23 8599.23 86.52 S 1876.66 E 570.87 9227.15 8656.00 8600.00 86.59 S 1877.37 E 571.15 .28 9362.69 8756.00 8700.00 89.88 S 1968.71 E 606.69 35.54 9521.73 8856.00 8800.00 81.57 S 2091.82 E 665.73 59.04 9723.24 8956.00 8900.00 47.78 S 2262.94 E 767.24 101.52 10055.32 9056.00 9000.00 19.58 N 2571.84 E 999.32 232.08 10445.71 9156.00 9100.00 115.16 N 2936.84 E 1289.71 290.38 10857.62 9256.00 9200.00 215.52 N 3323.59 E 1601.62 311.91 11215.37 9356.00 9300.00 306.33 N 3654.80 E 1859.37 257.75 11605.57 9456.00 9400.00 382.52 N 4023.90 E 2149.57 290.21 12054.09 9556.00 9500.00 441.02 N 4457.00 E 2498.09 348.51 12424.41 9656.00 9600.00 493.80 N 4809.38 E 2768.41 270.33 12737.07 9756.00 9700.00 575.81 N 5093.75 E 2981.07 212.66 13028.42 9856.00 9800.00 682.42 N 5345.68 E 3172.42 191.36 13301.53 9956.00 9900.00 782.65 N 5579.17 E 3345.53 173.10 13841.01 10056.00 10000.00 993.92 N 6060.99 E 3785.01 439.49 14660.00 10127.29 10071.29 1425.31 N 6749.59 E 4532.71 747.70 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Operator: BPX Well Name: 1-25A / K-22 Casing Size: 9 5/8" Set @ Test: Initial Weekly Rig No. '~'~'-") PTD # Co. Rep.: Rig Rep.: 9,262' md Location: Sec. X Other DATE: 5/7/97 97-25 Rig Ph.# 659-6510 Eddie Vaughn Allen Sinclair 36 T. 12N R. 16E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Well Sign Housekeeping: ok (Gen) Drl. Rig PTD On Location ok Hazard Sec. Standing Order Posted ok , BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve ok ok ok Quan. Test Press. I 300/3,000 I 500/5,000 I 500/5,000 I 500/5,000 I 500/5,000 2 500/5,000 I 500/5,000 NA P/F MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 500/5,000 P I 500/5,000 P I 500/5,000 P 1 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 18 Test Pressure P/F 500/5,000 P 46 500/5,000 P 2 P Func~oned Func~oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2700 avg. 3,050 I P 1,400 p minutes 45 sec. minutes 43 sec. Yes Remote: Yes Psig. TEST RESULTS Number of Failures: 0 ,test time: ¢4.5,,)Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Excellent Test Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AKHLEGEF,XLS MEMORANDUM TO: THRU: David Johns ~,~'~~ Chairma~ Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: Mzy 7, 1997 FILE NO: akhlegef, doc FROM: ;John Spaulding, ,¢¢'~ SUBJECT: Petroleum Insp.~ BOPE Test Doyon 15 BPX / MPI / 1-25A/K-22 PTD 97-25 Wednesday May 7, 1997: I traveled to BPX's Endicott Field to witness the BOPE Test on Doyon rig 15. The AOGCC BOPE Test Report is attached for reference. As noted in the test report no failures were observed. The area around the rig was quite clean with very good access. The rig crew performed an excellent test. Summary: I witnessed the BOPE test on - Doyon 15, 5/7/97, test time 4.5 hours, 0 failures Attachments: akhlegef, xls X Unclassified Confidential (Unclassified if document removed) Confidential WELL LOG TRANSMITTAL To: State of Alaska August 27, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1-25A/K-22, AK-MM-70171 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Ym~ Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1-25A/K-22: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21722-01 1 Blueline 1 Rev Folded Sepia 2"x 5" TVD Resistivity & CJamma Ray Logs: 50-029-21722-01 1 Blueline 1 Rev Folded Sepia 2"x 5"MD Neutron & Density Logs: 50-029-21722-01 1 Blueline 1 Rev Folded Sepia 2"x 5" TVD Neutron & Density Logs: 50-029-21722-01 1 Blueline 1 Rev Folded Sepia AUG 2 ? 1997 Oil & Gas ~n~, ~c~or'~ja 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company n FI I I_1_ I I~1 G SEFI~/ICE S WELI~ LOG TRANSMITTAL To: State of Alaska /- August 20, 1997 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 1-25A/K-22, AK-MM-70112 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.' Yum Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21722-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 - A Dresser Industries, Inc. Company 7/18/97 GeoQuest 500 W. International Airport Road Anchorage, Al( 99518-1199 ATTN: Sherrie NO. 11163 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 3 - 49 A / M - 40 RETAINER SET RECORD 970402 I 1 3-49A/M-40 STATIC PRESSURE SURVEY 970424 I I -- 3-49A/M-40 PERFORATION RECORD 970425 I 1 3- 49 A / M - 40 PERFORATION RECORD 970426 I 1 4-44/M-44 ~ I (~ TUBING PUNCHER RECORD 970313 I 1 2-24/M-12 {~ I ~ INJECTION PROFILE 970326 I 1 2-46A/R-10 PRODUCTION LOG 970416 I 1 2 - 26/N - 14 PRODUCTION PROFILE 970402 1 1 2-08/K-16 :GAS LIFT SURVEY 970308 1 1 2 - 08 / K - 16 PRODUCTION PROFILE 970308 I 1 1-25A/K-22 CHEMICAL CUT RECORD 970419 I 1 1 - 25 A/K- 22 PLUG SET RECORD 970423 I 1 3- 29/J - 32 PRODUCTION PROFILE W/DEFT 970329 I 1 1-09A/L-21 GAMMA RAY/CCL 970301 I 1 1-17A/1-1 7 COMPLETION RECORD 970306 I 1 4- 50 / K- 41 CHEMICAL CUTTER 970321 I I 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: J U l... i 8 'i9 !t Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 21; 1997 Steve Shultz Senior Drilling Enoineer=. BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island I-,,A/K-2,. BP Exploration (Alaska) Inc. Permit No' 97-75 Sur. Loc.: 325 i'NSL. 2092'WEL, Sec. 36, TI2N, R16E, UM Btmhole Loc: 4558'NSL, 207'WEL, Sec. 31. T12N, R17E, UM Dear Shultz: Enclosed is the approved application for permit to drill the above referenced ~vell. 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 xvith 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 may be given by contacting the Commission petroleum field inspector on the North BY ORDER OF THE MISS ON dltS;en¢losures Department of Fish & Game. Habitat Section ~v/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA _ ALASK' )IL AND GAS CONSERVATION Cf.' PERMIT TO DRILL 20 AAC 25.005 MISSION la. Typeofwork I~Drill I--IRedrill Ilb. Typeofwell E] Exploratory I-']StratigraphicTest [~ Development Oil ' [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone i2. Name of Operator !5. Datum Elevation (DF or KB) 10. Field and Pooi BP Exploration (Alaska) Inc. Plan RTE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 31828 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3251' NSL, 2092' WEL, SEC. 36, T12N, R16E Duck Island At top of productive interval - 8. Well Number Number 2S100302630-277 4104' NSL, 1095' WEL, SEC. 31, T12N, R17E 1-25A/K-22 At total depth 9. Approximate spud date Amount $200,000.00 4558' NSL, 207' WEL, SEC. 31, T12N, R17E 04/18/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047502, 4558'I No Close Approach 2560 15042' M D / 10090' 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9934' Maximum Hole Anqle 89 o Maximum surface 3372 psig, At total depth ('R/D) 10030' / 4375 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 511 4059' 9750' 9000' 13809' 10051' 360 sx Class 'G' 6" 4-1/2" 13# L-80 IBM 1233' 13809' 10051' 15042' 10146' Uncemented Slotted Slotted 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate -'~ ~'" ~.~ ~ ~ V ~ P Production LinerAPR £ 1 1997 .4I~ ¢.J! & Uas Cons, Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/N/~mber: Chris W/~st, 564-5089 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that thC/~oC~gcr~'~, trt&e~a'fld correct to the best of my knowledge .~,¢_,f"' St~v~$huItz ~- ~! \" Title Senior Drilling Engineer Date Commission Use Only Permit Number_ I APl Number I ¢/~1o~,,~ I See cover letter ~,,~- ~.,~" 50- 02.¢-- ~-- '/ 7 ~ ~-- -' 4:~ ! for other requirements Conditions of Approval: Samples Required [] ..Yes-'~ No Mud Log Rfequire~l [] Ye¢~8~' No Hydrogen Sulfide Measures /[~es [] No Directional Survey Required /~ Ye._.___..s [] No [] [] [] [] [] Required Working Pressure for DOPE 2M; 3M; ;~ 5M; by olro~;of 15M ~,pproved By Other: Original Si.gned. ,~'Y Commissioner the commission Date'"¢"¢,~ Form 10-401 Rev. 12-01-85 David W, J0hnstu~ Submit In Triplicate I Well Name: 11-25A/K-22 Well Plan Summary Type of Well (Producer or injector): Producer Well Design (Conventional, slimhole, etc.): SIDETRACK FSL FEL SEC TWP RNG Surface Location: 3251 2092 36 12N 16E Tie in survey Location' 3129 4615 31 12N 17E Target 1 Location' 4104 1095 31 12N 17E Target 2 Location' 4558 207 31 12N 17E I AFE Number: 1727011 IEstimated Start Date: 4/28/97 I Rig: I DOYON 15 I I Operating days to drill and complete' 27+6 Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =4055 psi TOP WEST SAK 6810 TOP SEABEE/AYLYAK 7750 TOP SHALE WALL/TUFFS 8875 KOP 9,934 MD / 9,100 TVDSS TOP HRZ 11243 9480 BASE HRZ 12141 9665 TOP PUT RIVER LCU 12141 9665 ITKILYARIAK KEKIKTUK - Top Flow 3A 12141 9665 9.2 4690 - 4190 psi @ 9,640 TVDSS Top Flow 2B 12165 9670 9.2 4650- 4350 psi @ 9,710 TVDSS Top Flow 2M 12505 9740 4650 - 4350 psi @ 9,710 TVDSS Top Flow 2A 12626 9765 4375 - 4350 psi @ 9,840 TVDSS Top Flow lC 13691 9975 Top FIowlB 13926 9995 Top Flow lA 14460 10060 3000 - 4375 psi @ 10,030 TVDSS Top Zone 3A3(P3) TD 15042 10090 Logging Program' Logs: 8.5" Hole Tangent and Curve 6" Hole from LCU to TD MWD GR/Directional/Resistivity Density & Neutron Porosity MWD G R/Directional/Resistivly Cased Hole: Optional SBT 24 hours after CIP - Possible CNL post rig Casing/Tubinc Pro ram' Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 8.5 7" 29 L-80 511 4059 9750/9000 13809/10051 6 4.5" Sltd 13 L-80 IBM 1233 13809/10051 15042/10146 TBG 4.5" 12.6 L-80 IBM 9962 38 10000/9196 1-25A/K-22 Drilling Permit 4/19/97 Cementing Program: Hole Section Liner Size Depth Volume Cement Intermediate 7" Liner from 9,750Cement from +_ 360 Sxs Class 'G' to 13,809 with 7" x13,809 to 0.5% CFR 2 9-5/8" liner hanger11,141 0.7% Halad 344 0.1% HR-5 2 pps Super CBL Production 4.5" Slotted Liner Not Cemented Slotted liner from 13,650 to 15,042 with 4.5" x 7" TIW SSH hanger Mud Program' Production Mud Properties: 18.5" and 6" hole section' LSND Depth Density Marsh Yield 10 sec LSR YP pH Fluid Flow (PPG) Viscosity Point 10 Min Loss Rate Gel Milling 10.0- 70-100 25-35 8-16 8.5- <6 600 10.2 11 - 24 9.5 Reservoir 10.2 - 45 - 60 18 - 25 7 - 11 8.5 - <4 250 10.4 9.5 Hazards/Concerns Pore pressure (__.8.6 - 9.4 ppg EMW) based on offset SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. Excessive Torque to be combated with lubricant additions after testing. WELLHEAD EQUIPMENT Casing Head: Casing Hanger: Tubinghead: X-mas Tree: Cameron 13 3/8" X 13 5/8", 5M Flange Cameron Mandrel Hanger Cameron 13 5/8",5M X 13 5/8", 5M Cameron 4",5M DIRECTIONAL STATS FOR 9 5/8" CASING ON 2.44/R-12 Average Angle: Maximum Angle Maximum Dogleg (above KOP) Centralizers Top of Cement 45° 89° 51" @ 12,200' 3.63°/100@ 8200' 10 Turbo Clamps from 10,727 to 10,327 9,394 (Calc. assuming 30% washout) Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS There are no drilling close approach wells after the sidetrack of the original 1-25/N-22 wellbore. PORE PRESSURE / LOST CIRCULATION Production Interval (8.5"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset pore pressure (based on nearby 3B BHP of 3000 to 4350 psi at +_ 10,000' TVDss) should range from _+ 5.7 to 9.3 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. 1-25A/K-22 Drilling Permit 4/19/97 NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal Cuttings Handling: Fluid Handling' CC2A Annular injection is not available at Endicott for this well. Contacts Office Home Pager Drilling Superintendent Adrian Clark 564-4720 345-9066 Sr Drilling Engineer Steve Shultz 564-5405 373-1657 Operations Drilling Engineer: Chris West 564-5089 345-4699 Production Engineer Bob Metzger 564-4613 Geologist: Doug Dickey 564-5474 348-0208 Geophysicist: Evvy Goebel 564-5367 Sperry Sun Directional Gordon Hecht 563-3256 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Dave Higbie 248-3511 345-0398 275-1779 275-1789 275-7530 275-1337 1-25A/K-22 Drilling Permit 4/19/97 Drilling Discussion General The 1-25A/K-22 well on MPI at Endicott will target the Kekiktuk in the Zone 1 in accordance with the 1997 development plan. We will have to abandon the existing perforation in the 1- 25/N-22 well by pumping cement down tubing, cut production tubing, circulate KWM, pull tubing with the rig, set a whipstock, cut a window, and kick off through the 9-5/8" casing to the new K-22 BHL utilizing the 7" cemented and 4.5" slotted liner design. We will not pull the existing production packer or tailpipe in this well. The liner lengths will be _. 3929 feet for 7" and 1180 for the 4.5" slotted, with the top of the liner hanger back into the 9-5/8" casing. A standard 6 valve slimhole (4.5" x 1" for 7" casing) GLM design will be run for the completion on a 4.5" L-80 tubing design with a X/X/XN nipple profile. Directional Plan: The directional plan for the 1-25A/K-22 well consists of kicking off with a whipstock and conventional BHA's for the Kekiktuk Flow sands. Current plans call for 8°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, and steering directionally back into the Sands with 85° of inclination, the well will be drilled to _+15,042 MD (10,146' TVD). THE DIRECTIONAL TARGET CAN BE INTERSECTED ANYWHERE WITHIN THE TARGET BOUNDRY. THUS UNNECESSARY AND VERY EXPENSIVE SLIDING SHOULD BE AVOIDED TO KEEP THE WELL EXACTLY ON THE WELLPATH. THERE IS NOT ANY GEOSTEERING APPLICATION FOR THIS WELL. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized in the 8.5" hole sections to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits IF run. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD/LWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily wellsite meeting. Directional Survey Program The survey program for 1-25A/K-22 calls for use of Sperry's DWD MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to J©RPS is required, with the use of checkshots and survey data validation. Bit Program We will kick off the in the Tuffs with a conventional directional BHA and roller cone bit, which should make it to the Kekiktuk. After milling the window, a 8.5" tangent section is planned to the Kekiktuk. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication 1-25A/K-22 Drilling Permit 4/19/97 of bit failure such as torque spikes, the bit should be pulled at th~ descretion of the rigsite team. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSl Casing Section Standard Window Mills 500 - 550 gpm 8.5"KOP Tangent GTPS 09D 550 - 600 gpm 3 x 15 2.9 - 4.8 8.5" Final Build ATJPS11HD 550 - 600 gpm 6" Section BBL 880 250 - 300 gpm NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. PDC bits will be run only if Sperry 6-3/4" performance motors are available. Mud Program: We will use LSND on this well. The problems of lubricant additions in a (high weight - high calcium carbonate - high chloride) system severely hampered the drilling process on the both SDI wells Sheardrill was used on. There should not be any additions of any lubricants in this well without extensive testing of the actual fluid on location. A new Gel/Biozan polymer will be used for milling the window. Ditch Magnets should be used and WEIGHED to ensure metal cuttings removal. Most of this well will be drilled at angles of greater than 60°, therefore frequent lo/hi vis sweeps should be implemented to ensure hole cleaning. In addition rotary speeds of 100 rpm should be used during the sweeps to aid in cutting bed removal. Rheology control can be maintained using Gel and Biozan polymer. At this time raise the LSR YP to the recommended range using Biozan. Biozan sweeps should be pumped to assist in hole cleaning and to prevent the build up of cuttings beds. Additions of 3#/BBL each of Baranex and Barotrol should be maintained throughout this well. This treatment should result in an HPHT of <14 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. To prevent torque problems from developing, the standard ERD lubricant mix should be started after the window is cut. The lubricants should be added gradually to prevent foaming and shaker blinding. The LSND mud will be taken to TD on this well. Maintain the weight at the density required in the intermediate section. The Barotrol and Baranex treatments should be maintained at 3#/bbl. The APl filtrate should be reduced to the 4 cc range with PAC and starch. This will reduce the chances of differential sticking and reduce filtration invasion. Tripping Practices / Stuck Pipe / Hole Cleaning Tripping in the 8.5" hole interval should be undertaken with caution due to swabbing possibilities with high viscosity fluids. The bottom hole pressure varies from 3000 psi to 4690 psi (5.7 to 9.2 ppg ). It is recommended that mud weights be maintained in the 10.2 to 10.4 ppg range to control the hydrocarbon intervals, maintain shale stability and minimize the possibility of differential sticking. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. No potential hazardous levels of H2S are anticipated in the 1-25A/K-22 well. There have been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. 1-25A/K-22 Drilling Permit 4/19/97 Logging Program: ILogs: 8.5" Hole Tangent and Curve 6" Hole from to TD Cased Hole: MWD GR/Directional/Resistivity Density & Neutron Porosity MWD G R/Directional/Resistivly Optional SBT 24 hours after CIP - Possible CNL post rig Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This sidetrack well will require a 7" 29# L-80 liner to be run down to the tope of the Kekiktuk 1C, and then a 4.5" slotted liner will be run across the Flow 1. This will be hung off in the 9- 5/8" casing at 10,450 feet. Make sure we have 5000 feet of 5" "S" drill pipe to allow for the maximum overpull. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned with several lo/hi vis sweeps with high rotary RPM to ensure hole cleaning for the casing. Before POH to run liner spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. This liner will use Hydrill 511 connections to allow rotation at much higher torque and reciprocation than any other connections. Special equipment will be required for this including XO for safety valve and having the liner hanger cut with a 511 connection on bottom. (Do not crossover from buttress as this would be a weak link in the string). The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges in the Tuffs, will require special care while running casing through. The liner will require 2 straight blade centralizers on every joint to the 200 feet above the top of the Kekituk at _+ 13,147', and then one straight blade centralizer on every other joint to the window. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull casing and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. The cementing program for the 7" casing is designed to place cement 1000 feet above the top of the Kekiktuk formation. The approximate volume will be 360 sacks of Class 'G' with additives as speficied in the casing detail section. Cementing operations at Endicott continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. After drilled the Kekiktuk Flow 1, we will run a 4.5 slotted liner. Perforating This sidetrack well will not require a perforating as it will be completed with a slotted liner across the Kekiltuk. 1-25A/K-22 Drilling Permit 4/19/97 SUMMARY PROCEDURE COMMENTS 1. The 9-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The packer will not be recovered. 2. This well will be sidetracked at app. 9934 feet. PRE-RIG OPERATIONS 1. RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 2. Establish bullhead rate down 4.5" tubing and into perforations. 3. Pump 100 sx of class G cement and circulate down the tubing. Displace to at least 10,000 MD. Squeeze cement into perforations up to 1500 psi. 4. RU wireline and cut tubing with chemical cutter just above 4.5" x 9-5/8" packer at 9,973' MD. 5. Circulate the 4.5" tubing with 1.5 volumes of 9.5 ppg brine or milling fluid. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. Note: Maintain contact with Drilling. If rig move is delayed to more than four days after the well kill, a deeper freeze protect will need to be done by the PE's. 6. Dig out the cellar and level the pad. Inspect the wellhead and tree. Replace the 9-5/8" packoff and function test the LDS's. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. If not circ well w/brine or milling fluid until dead. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) Screw into the landing joint. Pull and LD the tubing. (1 day) Run and set 9-5/8" wireline bridge plug at +_ 9,940 MD with CCL to set BP 3 feet below collar. (1/2 day). P/U 9-5/8" whipstock and milling BHA and TIH to cut window from 9,934 - 9,950 MD. (2 days) POOH w/mills. (1/2 day) Pick up Sperry 6.75" directional BHA to turn and build @ 10°/100 feet to 77° at app 10,205' MD, hold to 13,570 then build and turn to 84° at 62.8 azimuth. Drill ahead as specified by the rig supervisor to ICP at 13,679. POOH. (12 days) Run a 7" solid liner from 9,750 to 13,679' MD, cement as per plan. (2 days). Pick up Sperry 6." bit and directional BHA to TD at appx 14,680 MD. POOH. (3 days) If there are hole problems, run a HO over whole interval and spot lubricant in OH section. POOH. Run a 4.5" slotted liner from 13,500' to 14,680' MD. (2 days). Make a clean out trip with bit and scraper and displace with KW Brine. RIH w/7" x 4-1/2" packer, 4-1/2" L-80 tubing, and 6 GLM to expected setting depth at 10,800 MD. Drift packer, tubing and all jewlery before running. (1 day) Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. Turn the well over to Production. 1-25A/K-22 Drilling Permit 4/19/97 1-25a/K-22 Wp4 ertical Section 71.22° KB 56.00' MD Inc. Azi. 9934.00 47.94 10000.00 52.17 10100.00 58.80 10200.00 65.63 10300.00 72.60 10378.30 78.11 10400.00 78.11 10500.00 78.11 10600.00 78.11 10700.00 78.11 10800.00 78.11 10900.00 78.11 '11000.00 78.11 11100.00 78.11 11200.00 78.11 11243.07 78.11 ! 1300.00 78.11 !1400.00 78.11 i 1500.00 78.11 11600.00 78.11 11700.00 78.11 11800.00 78.11 !1900.00 78.11 12000.00 78.11 12100.00 78.11 12140.71 78.11 12164.97 78.11 12200.00 78.11 12300.00 78.11 12400.00 78.11 12500.00 78.11 12504.62 78.11 12600.00 78.11 12625.92 78.11 12700.00 78.11 12800.00 78.11 12900.00 78.11 13000.00 78.11 13057.76 78.11 95.14 91.00 85.57 80.86 76.64 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 73.56 TVDss 9100.69 9143.06 9199.73 9246.33 9281.97 9301.77 9306.25 9326.86 9347.46 9368.07 9388.68 94O9,29 9429,90 9450.51 9471.12 948O.OO 9491.73 9512.34 9532.95 9553.56 9574.17 9594,78 9615.39 9636.O0 9656.61 9665.00 9670.00 9677.22 9697.83 9718.44 9739.O5 974O.OO 9759.66 9765.00 9780.27 9800.88 9821.49 9842.10 9854.00 TVDrkb 9156.69 9199.06 9255.73 9302.33 9337.97 9357.77 9362.25 9382.86 94O3.46 9424.07 9444.68 9465.29 9485.90 9506.51 9527.12 9536.OO 9547.73 9568.34 9588.95 9609.56 9630.17 9650.78 9671.39 9692.00 9712.61 9721.00 9726.00 9733.22 9753.83 9774.44 9795.05 9796.00 9815.66 9821.00 9836.27 9856.88 9877.49 9898.10 9910.00 Rect. Coordinates No~hing 123.34S 125.99S 123.37S 112.82S 94.53S 75.03S 69.02S 41.33S 13.63S 14.06n 41.76n 69.45n 97.15n 124.84n 152.53n 164.46n 180.23n 207.92n 235.62n 263.31n 291.01n 318.70n 346.40n 374.09n 401.79n 413.06n 419.78n 429.48n 457.18n 484.87n 512.57n 513.84n 540.26n 547.44n 567.96n 595.65n 623.34n 651.04n 667.03n Easting 2372.83e 2423.33e 2505.59e 2593.34e 2684.88e 2758.04e 2778.40e 2872.26e 2966.11e 3059.96e 3153.82e 3247.67e 3341.52e 3435.37e 3529.23e 3569.65e 3623.08e 3716.93e 3810.79e 3904.64e 3998.49e 4092.35e 4186.20e 4280.05e 4373.90e 4412.11e 4434.88e 4467.76e 4561.61e 4655.46e 4749.32e 4753.65e 4843.17e 4867.49e 4937.02e 5030.88e 5124.73e 5218.58e 5272.79e Grid Coordinates DLS Easting No~hing de~100ff 261479.42 5982183.79 0.00 261529.80 5982179.50 8.00 261612.10 5982179.45 8.00 261700.14 5982187.15 8.00 261792.22 5982202.46 8.00 261865.97 5982219.57 8.00 261886.52 5982224.91 0.00 261981.22 5982249.55 0.00 262075.92 5982274.18 0.00 262170.62 5982298.81 0.00 262265.32 5982323.44 0.00 262360.02 5982348.08 0.00 262454.72 5982372.71 0.00 262549.42 5982397.34 0.00 262644.12 5982421.98 0.00 262684.91 5982432.59 0.00 262738.82 5982446.61 0.00 262833.52 5982471.24 0.00 262928.22 5982495.87 0.00 263022.91 5982520.51 0.00 263117.61 5982545.14 0.00 263212.31 5982569.77 0.00 263307.01 5982594.41 0.00 263401.71 5982619.04 0.00 263496.41 5982643.67 0.00 263534.96 5982653.70 0.00 263557.94 5982659.67 0.00 263591.11 5982668.30 0.00 263685.81 5982692.94 0.00 263780.51 5982717.57 0.00 263875.21 5982742.20 0.00 263879.58 5982743.34 0.00 283969.91 5982766.83 0.00 263994.45 5982773.22 0.00 264064.61 5982791.47 0.00 264159.30 5982816.10 0.00 264254.00 5982840.73 0.00 264348.70 5982865.37 0.00 264403.40 5982879.59 0.00 Vedical Section 2206.80 2253.75 2332.48 2418.95 2511.50 2587.05 2608.26 2706.04 2803.81 2901.58 2999.35 3097.13 3194.90 3292.67 3390.44 3432.56 3488.22 3585.99 3683.76 3781.53 3879.30 3977.08 4074.85 4172.62 4270.39 4310.20 4333.92 4368.17 4465.94 4563.71 4661.48 4666.00 4759.25 4784.60 4857.03 4954.8O 5052.57 5150.34 5206.81 Comment KOP/Begin Dir @ 8/100 · 9934 MD End Dir- 10378 MD Top HRZ' 11243 MD BHRZ/LCU/Top Kekiktuk 3A · 12141 MD Top Kekiktuk 2B · 12165 MD Top Kekiktuk 2M · 12505 MD Top Kekituk 2A · 12626 MD GOC -13058MD 4/15/97 6:26 PM Page 1 of 2 1-25a/K-22 Wp4 ~ertical Section 71.22° IKB 56.0O' MD Inc. Azi. 13100.00 78.11 73.56 13200.00 78.11 73.56 13300.00 78.11 73.56 13400.00 78.11 73.56 13500.00 78.11 73.56 13532.34 78.11 73.56 13600.00 81.06 68.95 13690.98 85.12 62.86 13700.00 85.12 62.86 13800.00 85.12 62.86 13808.52 85.12 62.86 13900.00 85.12 62.86 13926.07 85.12 62.86 14000.00 85.12 62.86 14100.00 85.12 62.86 14200.00 85.12 62.86 14300.00 85.12 62.86 14400.00 85.12 62.86 14500.00 85.12 62.86 14600.00 85.12 62.86 14689.93 85.12 62.86 14700.00 85.12 62.86 14800.00 85.12 62.86 14900.00 85.12 62.86 15000.00 85.12 62.86 15042.43 85.12 62.86 TVDss TVDrkb Rect. Coordinates Grid Coordinates No~hing Easting Easting No~hing 9862.71 9918.71 678.73n 5312.43e 264443.40 5982890.00 9883.32 9939.32 706.43n 5406.29e 264538.10 5982914.63 9903.93 9959.93 734.12n 5500.14e 264632.80 5982939.26 9924.54 9980.54 761.82n 5593.99e 264727.50 5982963.90 9945.15 10001.15 789.51n 5687.85e 264822.20 5982988.53 9951.81 10007.81 798.47n 5718.20e 264852.82 5982996.50 9964.05 10020.05 819.86n 5781.18e 264916.47 5983015.83 9975.00 10031.00 856.72n 5863.56e 265000.00 5983050.00 9975.77 10031.77 860.83n 5871.57e 265008.13 5983053.84 9984.27 10040.27 906.27n 5960.23e 265098.22 5983096.39 9985.00 10041.00 910.15n 5967.79e 265105.90 5983100.01 9992.78 10048.78 951.72n 6048.90e 265188.32 5983138.93 9995.00 10051.00 963.57n 6072.01e 265211.80 5983150.02 10001.29 10057.29 997.17n 6137.57e 265278.41 5983181.48 10009.80 10065.80 1042.62n 6226.24e 265368.50 5983224.02 10018.31 10074.31 1088.07n 6314.91e 265458.60 5983266.57 10026.82 10082.82 1133.52n 6403.57e 265548.69 5983309.11 10035.33 10091.33 1178.96n 6492.24e 265638.79 5983351.65 10043.84 10099.84 1224.41n 6580.91e 265728.88 5983394.20 10052.35 10108.35 1269.86n 6669.58e 265818.97 5983436.74 10060.00 10116.00 1310.73n 6749.32e 265900.00 5983475.00 10060.86 10116.86 1315.30n 6758.25e 265909.07 5983479.28 10069.37 10125.37 1360.75n 6846.92e 265999.16 5983521.82 10077.88 10133.88 1406.20n 6935.59e 266089.26 5983564.37 10086.39 10142.39 1451.64n 7024.26e 266179.35 5983606.91 10090.00 10146.00 1470.92n 7061.88e 266217.58 5983624.96 DLS deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 8.00 8.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Ve~ical Section 5248.12 5345.89 5443.66 5541.43 5639.21 5670.83 5737.34 5827.21 5836.10 5934.68 5943.08 6033.26 6058.96 6131.84 6230.42 6329.00 6427.58 6526.16 6624.74 6723.31 6811.97 6821.89 6920.47 7019.05 7117.63 7159.46 Comment Begin Dir @ 8/100: 13532 MD End Dir/Target 1/TKekiktuk 1C: 13691 MD 7" Casing: 13809 MD Top Kekiktuk lB: 13926 MD Target 2/Top Kekiktuk lA: 14690 MD TD/4 1/2" Slotted Liner: 15042 MD 4/15/97 6:26 PM Page 2 of 2 tS~ hared Services Drilling ruc}ure: End MPI . Well: 1-25A/K-22 Field: EndicoH Location: Alaska $c01e 1 ' 400.00 East -> 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 2400 2000 - 1600 - 1200 - A _ II ~oo - -- _C 400 - ; L - 0 0 - g _ -400 - o -800 - 0 c5 _ · . -1200- .,--- _ -- ~ -1600 11-25A/K-22 Wp4I TARGET DATA MD Inc Dir 'DVD North East -- Name .... Position -- 14690 85.12 62.86 10116 1311 6749 Target 2 265900, 5983475 13691 85.12 62.86 10031 857 5864 Target 1 265000,5983050 4 1/'2' SlottedLin~r ~1"~ arget 2 7' C '~g Targ~ 2400 -- - 2000 -- 1600 - 1200 - A - soo II -- - 4O0 Z - 0 - 0 I _ ::D'- - -400 -- - -800 ¢ -- -- --1200 .- - O ' b -1600 o 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 Sc01e 1 ' 400.00 East -> Shared Services Drilling Structure - End MPI Well: 1-25A/K-22 Field - Endicott Location: Alaska 6800 "m 7200 . . 7600 C) . f-. 8000 (:D 8400 t3 8800 L 9200 (D 9600 10000 II V 10400 10800 11200 11600 1 -~K-22 Wp4 1 .... Po[hr KOP End of Build End of Hold forget target WELL PROFILE DATA 9934 10378 13532 13691 14690 Inc Dir TVD NoAh East DL$(deg/100ft) 47.94 95,14 9157 -123 2373 0.00 78.11 73.56 9358 -75 2758 8.00 78.11 75,56 1000B 79B 5718 0.00 85.12 62.88 10031 857 5864 B.OO 85,12 62.88 10116 1311 6749 0.00 0.00 End of Hold 15042 85,12 62.86 10146 1471 7062 1200 16O0 2000 Sccle 1 ' 400.00 2400 2800 3200 .3600 4-000 4400 4800 5200 5600 6000 6400 Vertical Section on 71.22 <~zimuth wHh reference 0.00 S, 0.00 E from 1-25A/K-22 6800 7200 7600 8000 MPI WELL 1-25A/K-22(WP3) SURFACE & DOWNHOLE LOCATIONS 3/17/97 ITEM NAME COMMENTS ALASKA STATE PLANE ZONE 3 (NAD 27) DECIMAL DEGREES (NAD 27) S & E SEC LINE OFFSETS SECTION, TOWN., NEAREST SECTION LINE OFFSETS NO. V X LATITUDE (N°) LONGITUDE (W°) FSL FEE RANGE, UMIAT, AK DIST. LINE DIST. LINE 1 MPI 1-25A/K22 Surface Surface Location 5,982,384.08' 259,111.92' 70.3525220° 147.9562178° 3251 2092 SEC 36 T12N R16E 2029 N 2092 E 2 MPI 1-25A/K22:9900 MD 5,982,186.87' 261,454.45' 70.3521882° 147.9371573° 3129 4615 SEC 31 T12N R17E 2151 N 255 W 3 MPI 1-25A/K22:12136.39 MD Base HRZ/LCU 5,982,674.50' 263,542.51' 70.3537006° 147.9203377° 3682 2541 SEC 31 T12N R17E 1597 N 2327 W 4 MPI 1-25A/K22:13679.24 MD T1 3/14 5,983,050.00' 265,000.00' 70.3548512° 147.9086050° 4104 1095 SEC 31 T12N R17E 1176 N 1095 E 5 MPI 1-25A/K22:14680.52 MD TD 7" Liner 5,983,476.00' 265,900.00' 70.3560915° 147.9014086° 4558 207 SEC 31 T12N R17E 722 N 207 E Notes: Coordinates shown are North American Datum 1927 (NAD 27). F. Robert Bell & Assoc. Jeff Col-ton 564-4969 File Name: Mpibhl .xls 3/17/97 WELL PERMIT CHEC F~.~,D ~ Poo~, 2--q-~> /~ ADMINISTRATION 1. Permit 2. Lease 3. Unique 4. Well 1 5. Well 1 6. Well 1 7. Suffic 8. If der 9. Operat 10. Operat 11. Permit 12. Permit 13. Can ps ENGINEERING 14. Conduc] 15. Surfac 16. CMT vo 17. CMT vO 18. CMT wi 19. Casin¢ 20. Adequa 21. If a r 22. Adequa 23. If div 24 Drilli 25 BOPEs 26 BOPE p 27 Choke 28 Is pr~, Work ~ 29 GEOLOGY ,, 30. Permi~ 31. Data ~ 32. Seism~ 33. Seabe~ 34. Conta~ GEOLOGY: MPI Well 1-25/K22 (Wp3) Surface and Downhole Locations Section Line Ties 3/17/97 NW Sec 36 T12N R16E Umiat X=255990.65 Y=5984514.54 SW Sec 36 T12N R16E Umiat X=255822.36 Y=5979237.41 5280 91o50'48,, 1-25/K-22 Surface Location X=259111.92 Y=5982384.08 2092 5280 91 °50'47" NW Sec 31 T12N R17E Umiat NE Sec 36 T12N R16E Umiat X=261267.72 Y=5984344.40 --_ 255 SW Sec 31 T12N R17E Umiat SE Sec 36 T12N R16E Umiat X=261099.45 Y=5979067.29 2327 1 -25/K-22 MD: 9900 X=261454.45 Y=5982186.87 NE Sec 31 T12N R17E Umiat 4862 X=266126.82 91048,28" Y=5984191.03 1 -25/K-22 T1 3/14:13679.24 X:265000.00 '-I Y = 5983050.00 -"t..~ _.! ~U/I-~ ~7~,/K-22 -. ~ Liner :14680.52 1095 1-25/K-22 BHRZ/LCU :12136.39 X=263542.51 Y=5982674.50 X=265900.00 Y=5983476.00 4884 91 °48'28" SE Sec31 T12N R17E Umiat X=265980.58 Y=5978913.24 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. Sperry-Sun Drilling Services LIS Scan Utility Thu Aug 14 14:55:06 1997 o'-"1% Reel Header Service name ............. LISTPE Date ..................... 97/08/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNF_NOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/14 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 DUCK ISLAND UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MM-70112 M. WORDEN E. VAUGHN Date 1-25A / K-22 500292172201 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 14-AUG-97 MWD RUN 6 AK-MM-70112 M. WORDEN E. VAUGHN MWD RUN 7 AK-MM-70112 M. WORDEN E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WI~qESS: SURFACE LOCATION MWD RUN 8 AK-MM-70112 M. WORDEN E. VAUGHN MWD RUN 11 AK-MM-70112 M. WORDEN J. CARLILE MWD RUN 9 AK-MM-70112 M. WORDEN E. VAUGHN MWD RUN 12 AK-~-70112 M. WORDEN J. CARLILE MWD RUN 10 AK-MM-70112 M. WORDEN E. VAUGHN AUG 20 1997 Ata~,~a Oil & 6.as Cons. Mchora[ae SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 36 12N 16E 3251 2092 .00 56.00 14.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH <FT) 9.625 9268.0 8.500 7.000 13938.0 6.000 14460.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 4 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 3. MWD RUNS 5 AND 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR). 4. MWD RUNS 7 THROUGH 10 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND SLABILIZED LITHO DENSITY (SLD) . 5. MWD RUNS 11 AND 12 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) . 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR BOB METZGER OF BP EXPLORATION (ALASKA), INC. ON 12 JUNE, 1997. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14660'MD, 10127'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 - COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FO~ATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ 800-1100 PPM. 10.2 - 10.7 PPG. 16000 PPM. 1.0 G/CC. 2.65 G/CC. SANDSTONE File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE ~JMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH GR 9243 0 ROP 9267 0 PEF 11841 0 DRHO 11841 0 RHOB 11841 0 FCNT 11841 0 NCNT 11841 NPHI 11841 FET 11841 RPD 11841 RPM 11841 RPS 11841 RPX 11841 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASEL INE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD 5 MWD 6 MWD 7 MWD 8 MWD 9 Mk~JD 10 MWD 11 STOP DEPTH 14611 0 14659 5 13911 0 13910 5 13901 5 13901 5 13901 5 13901 5 14618 0 14618 0 14618 0 14618.0 14618.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP 9267 0 10164 0 11866 0 12121 0 13013 0 13488 0 13948 0 MERGE BASE 10164 0 11866 0 12121 0 13013 0 13488 0 13948 0 14532 0 MWD 12 14532.0 $ REMARKS: MERGED MAIN PASS. $ 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 14660.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM ~A~D OHMM 4 1 68 RPD MWD OHMM 4 1 68 NPHI MWD P.U. 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 FET MWD HOUR 4 1 68 PEF MWD BARN 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 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 DEPT 9243 GR 10.9045 ROP 2.1652 RPX 0.1014 RPS 0.1144 RPM 0.1999 RPD 0.212 NPHI 7.7426 RHOB 1.1072 DRHO -0.472 FET 0.6129 PEF 1.376 NCNT 2083.61 FCNT 402 Max Mean Nsam 14659.5 11951.2 10834 367.27 127.39 10737 1350.68 36.3342 10786 2000 107.723 5555 2000 254.742 5555 2000 275.12 5555 2000 304.803 5555 81.7622 33.8122 4089 2.9812 2.19081 4140 0.2605 -0.00812437 4140 84.0484 5.94252 5554 17.4203 2.45442 4141 4413.85 3070.87 4122 1756.8 910.96 4089 First Reading 9243 9243 9267 11841 11841 11841 11841 11841 11841 11841 11841 11841 11841 11841 Last Reading 14659.5 14611 14659.5 14618 14618 14618 14618 13901.5 13910.5 13910 . 5 14618 13911 13901.5 13901.5 First Reading For Entire File .......... 9243 Last Reading For Entire File ........... 14659.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 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 ....... 97/08/14 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: 5 DEPTH INCREMENT: .5000 FILE SUMPLARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9243.0 10140.5 ROP 9267.0 10163.5 $ LOG HEADER DATA DATE LOGGED: 04-MAY-97 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: 40.7 MAXIMUM ANGLE: 75.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0730CG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 10164.0 9267.0 10164.0 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHFIM) 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 70.0 9.9 1200 3.5 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 65.6 First Name Min Max Mean Nsam Reading DEPT 9243 10163.5 9703.25 1842 9243 GR 32.4832 237.445 132.445 1796 9243 ROP 4.3001 608.203 34.8787 1794 9267 Last Reading 10163.5 10140.5 10163.5 First Reading For Entire File .......... 9243 Last Reading For Entire File ........... 10163.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 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 ....... 97/08/14 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10140.0 ROP 10144.0 $ 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: STOP DEPTH 11840.5 11866.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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: 07-MAY-97 ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 11866.0 10164.0 11866.0 73.2 78.2 TOOL NUMBER P0730CG6 8.500 8.5 LSND 10.20 61.0 8.6 1100 3.2 .000 .000 67.8 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 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10140 11866 11003 3453 10140 GR 73.8482 303.79 159.793 3402 10140 ROP 8.0357 414.151 35.0255 3445 10144 Last Reading 11866 11840.5 11866 First Reading For Entire File .......... 10140 Last Reading For Entire File ........... 11866 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMI~ARY VENDOR TOOL CODE START DEPTH GR 11840 0 PEF 11841 0 DRHO 11841 0 RHOB 11841 0 FCNT 11841 0 NCNT 11841 0 NPHI 11841 0 FET 11841 0 RPD 11841 0 RPM 11841 0 RPS 11841 0 RPX 11841 0 ROP 11860 5 $ 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: M3tXIMUMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): STOP DEPTH 12088 0 12077 5 12077 0 12077 0 12068 5 12068 5 12068 5 12061 0 12061 0 12061 0 12061.0 12061.0 12120.5 08-MAY-97 ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 12121.0 11866.0 12121.0 76.8 77.7 TOOL NUMBER P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 8.500 8.5 LSND 10.30 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 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 7 AAPI 4 1 68 RPX MWD 7 OHMM 4 1 68 RPS MWD 7 OHMM 4 1 68 RPM MWD 7 OHMM 4 1 68 RPD MWD 7 OHMM 4 1 68 FET MWD 7 HOUR 4 1 68 NPHI MWD 7 P.U. 4 1 68 FCNT MWD 7 CNTS 4 1 68 NCNT MWD 7 CNTS 4 1 68 RHOB MWD 7 G/CC 4 1 68 DRHO MWD 7 G/CC 4 1 68 PEF MWD 7 BARN 4 1 68 ROP MWD 7 FT/H 4 1 68 80.0 9.5 1100 3.0 1.100 .538 1.000 1.600 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 63 .3 Name Min Max Mean DEPT 11840 12120.5 11980.2 GR 149.228 347.941 223.468 RPX 6.7393 12.7313 9.11101 RPS 6.9899 24.9176 12.4813 RPM 9.8721 213.483 24.4225 RPD 10.2854 123.933 26.9204 FET 0.7763 29.4447 4.77487 First Last Nsam Reading Reading 562 11840 12120.5 497 11840 12088 441 11841 12061 441 11841 12061 441 11841 12061 441 11841 12061 441 11841 12061 NPHI 51.2057 81.7622 77.0698 456 FCNT 657.059 871.663 752.173 456 NCNT 2121.46 2724.39 2396.62 456 RHOB 1.9312 2.5537 2.348 473 DRHO -0.039 0.1557 0.0124666 473 PEF 2.0948 7.6508 3.03406 474 ROP 4.2453 3733.59 85.1245 521 11841 11841 11841 11841 11841 11841 11860.5 12068.5 12068.5 12068.5 12077 12077 12077.5 12120.5 First Reading For Entire File .......... 11840 Last Reading For Entire File ........... 12120.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX FCNT NCNT NPHI PEF DRHO RHOB GR ROP $ 8 .5000 START DEPTH 12060.0 12060 0 12060 0 12060 0 12060 0 12067 5 12067 5 12067 5 12076 5 12076 5 12076 5 12087 0 12121 5 STOP DEPTH 12952 5 12952 5 12952 5 12952 5 12952 5 12960 0 12960 0 12960 0 12969 0 12968 5 12968 5 12979 5 13012 5 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 MINIMIZM 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 STABILIZED LITHO DEN $ 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 T3~e .................. 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 ....................... Il-MAY-97 ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 13013.0 12121.0 13013.0 75.0 69.6 TOOL NUMBER P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 8.500 8.5 LSND 10.40 52.0 8.9 9OO 3.6 1.300 .518 1.200 1.700 74.4 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 68 GR MWD 8 AAPI 4 1 68 RPX MWD 8 OHI~I~ 4 1 68 RPS MWD 8 OHMt4 4 1 68 RPM MWD 8 OHMM 4 1 68 RPD MWD 8 OHMM 4 1 68 NPHI MWD 8 P.U. 4 1 68 ROP MWD 8 FT/H 4 1 68 FET MWD 8 HOUR 4 1 68 FCNT MWD 8 CNTS 4 1 68 NCNT MWD 8 CNTS 4 1 68 RHOB MWD 8 G/CC 4 1 68 DRHO MWD 8 G/CC 4 1 68 PEF MWD 8 BARN 4 1 68 Rep 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 12060 13012.5 12536.2 1906 GR 10.9045 367.27 124.042 1786 RPX 1.0595 2000 192.174 1786 RPS 0.4725 2000 515.89 1786 RPM 0.1999 2000 535.962 1786 RPD 0.212 2000 546.171 1786 NPHI 7.7426 81.7622 27.4169 1786 ROP 4.9066 367.734 31.2085 1783 FET 1.6136 17.0175 3.87336 1786 FCNT 570.706 1756.8 1034.49 1786 NCNT 2199.26 4413.85 3114.87 1786 RHOB 1.9158 2.9193 2.28305 1785 DRHO -0.27 0.2605 0.00199821 1785 PEF 1.6765 17.4203 2.82869 1786 First Reading 12060 12087 12060 12060 12060 12060 12067.5 12121.5 12060 12067.5 12067.5 12076.5 12076.5 12076.5 Last Reading 13012 5 12979 5 12952 5 12952 5 12952 5 12952 5 12960 13012.5 12952.5 12960 12960 12968.5 12968.5 12969 First Reading For Entire File .......... 12060 Last Reading For Entire File ........... 13012.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 BIT RUN NIIMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE PEF DRHO RHOB FET RPD RPM RPS RPX FCNT NCNT NPHI GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. 9 .5000 START DEPTH 12931.0 12931 0 12931 0 12948 0 12948 0 12948 0 12948 0 12951 0 12956 0 12956 0 12956 0 12978 0 13010 5 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: 13428 13435 13435 13435 13455 13488 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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: STOP DEPTH 13444.5 13444.0 13444.0 13428.0 13428.0 13428.0 13428 0 0 5 5 5 0 0 13 -MAY- 97 ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 13488.0 13013.0 13488.0 67.2 72.3 TOOL NUMBER P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 8.500 8.5 LSND 10.60 62.0 8.9 MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHNIM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: I~[ATRIX 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 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 9 AAPI 4 1 68 RPX MWD 9 OHNIM 4 1 68 RPS MWD 9 OHMM 4 1 68 RPM MWD 9 OHMM 4 1 68 RPD MWD 9 OHIO4 4 1 68 NPHI MWD 9 P.U. 4 1 68 ROP MWD 9 FT/H 4 1 68 FET MWD 9 HOUR 4 1 68 FCNT MWD 9 CNTS 4 1 68 NCNT MWD 9 CNTS 4 1 68 RHOB MWD 9 G/CC 4 1 68 DRHO MWD 9 G/CC 4 1 68 PEF MWD 9 BARN 4 1 68 8OO 3.1 1.400 .500 1.000 1.600 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 79.4 Narne Min Max Mean DEPT 12931 13488 13209.5 GR 11.6521 161.316 33.6226 RPX 2.743 780.638 174.691 RPS 3.0493 2000 406.041 RPM 4.0372 2000 377.583 RPD 6.8543 2000 431.178 NPHI 9.2153 81.7622 18.839 ROP 3.2804 451.529 31.7813 FET 1.8969 24.2196 5.98226 First Last Nsam Reading Reading 1115 12931 13488 955 12978 13455 955 12951 13428 961 12948 13428 961 12948 13428 961 12948 13428 960 12956 13435.5 956 13010.5 13488 961 12948 13428 FCNT 424.587 1567.24 1049.06 960 NCNT 2102.93 4216.04 3614.63 960 RHOB 1.1072 2.6133 2.13814 1027 DRHO -0.472 0.2153 -0.0235793 1027 PEF 1.6839 10.5279 1.96403 1028 12956 12956 12931 12931 12931 13435.5 13435.5 13444 13444 13444.5 First Reading For Entire File .......... 12931 Last Reading For Entire File ........... 13488 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date o~ Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE PEF DRHO RHOB RPD RPM RPS RPX FET FCNT NCNT NPHI GR ROP $ LOG HEADER DATA DATE LOGGED: 10 .5000 START DEPTH 13381 0 13387 5 13387 5 13424 0 13424 0 13424 0 13426 0 13428 5 13431 0 13431 0 13431.0 13453.0 13485.5 STOP DEPTH 13911 0 13910 5 13910 5 13894 0 13894 0 13894 0 13894 0 13893 5 13901 5 13901 5 13901 5 13921 5 13947 5 14-MAY-97 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 D~NGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 ~sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 13948.0 13488.0 13948.0 77.1 87.1 TOOL NUMBER P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 P0736CRNDG6 8.500 8.5 LSND 10.60 58.0 9.5 9OO 2.6 .85O .367 .800 1.300 73 .3 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 10 AAP I 4 1 68 RPX MWD 10 OHMM 4 1 68 RPS MWD 10 OHMM 4 1 68 RPM MWD 10 O HlVIM 4 1 68 RPD MWD 10 OHMM 4 1 68 NPHI MWD 10 P.U. 4 1 68 ROP MWD 10 FT/H 4 1 68 FCNT MWD 10 CNTS 4 1 68 NCNT MWD 10 CNTS 4 1 68 RHOB MWD 10 G/CC 4 1 68 DRHO MWD 10 G/CC 4 1 68 PEF MWD 10 BARN 4 1 68 FET MWD 10 HOUR 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 13381 13947.5 13664.2 1134 GR 12.2906 189.332 68.0057 938 RPX 6.8128 2000 49.0256 937 RPS 8.3798 2000 65.0085 941 RPM 10.2163 2000 92.1474 941 RPD 14.059 2000 127.399 941 NPHI 16.6003 74.3041 40.3102 909 ROP 4.9066 1082.81 39.667 925 FCNT 402 914.599 603.254 909 NCNT 2083.61 3887.16 2768.92 942 RHOB 1.1794 2.9812 2.01185 1047 DRHO -0.442 0.2474 -0.018688 1047 PEF 1.376 8.4293 1.95993 1061 FET 1.6353 24.4275 5.4295 931 First Reading 13381 13453 13426 13424 13424 13424 13431 13485.5 13431 13431 13387.5 13387.5 13381 13428.5 Last Reading 13947.5 13921.5 13894 13894 13894 13894 13901 5 13947 5 13901 5 13901 5 13910 5 13910 5 13911 13893.5 First Reading For Entire File .......... 13381 Last Reading For Entire File ........... 13947.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 13890.0 14490 0 RPD 13890.0 14490 0 RPM 13890.0 14490 0 RPS 13890.0 14490 0 RPX 13891.0 14490 0 GR 13920.0 14483 0 ROP 13945.5 14531 5 $ LOG HEADER DATA DATE LOGGED: 19-MAY-97 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: 84.2 MAXIMUM ANGLE: 88.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PO669SP4 EWR4 ELECTROMAG. RESIS. 4 PO669SP4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.000 DRILLER'S CASING DEPTH (FT): 6.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : 57.0 MUD PH: 9.3 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : 3.4 RESISTIVITY (OHlVIM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .850 I~3D AT MAX CIRCULATING TERMPERATURE: .316 -17.7 MUD FILTRATE AT MT: .750 MTJD CAKE AT MT: 2.500 NEUTRON TOOL MATRIX: ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 14532.0 13948.0 14532.0 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 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 11 AAPI 4 1 68 RPX MWD 11 OHMM 4 1 68 RPS MWD 11 OHlViM 4 1 68 RPM MWD 11 OHMM 4 1 68 RPD MWD 11 OHMM 4 1 68 ROP MWD 11 FT/H 4 1 68 FET MWD 11 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 13890 14531.5 14210.8 1284 GR 13.6469 195.672 111.489 1127 RPX 0.1014 100.096 27.6452 1199 RPS 0.1144 90.0127 26.9699 1201 RPM 0.4027 2000 82.0933 1201 RPD 1.1495 2000 139.239 1201 ROP 2.1652 181.406 49.6156 1173 FET 0.6129 84.0484 9.60239 1201 First Reading 13890 13920 13891 13890 13890 13890 13945.5 13890 Last Reading 14531.5 14483 14490 14490 14490 14490 14531.5 14490 First Reading For Entire File .......... 13890 Last Reading For Entire File ........... 14531.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14484.0 RPD 14490.5 FET 14491.0 RPM 14491.0 RPS 14491.0 RPX 14491.0 ROP 14533.5 $ 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 $ 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): 14618 14618 146S9 STOP DEPTH 14611 0 14618 0 14618 0 14618 0 0 0 5 20-MAY- 97 ISC 4.96 CIM 5.30/DEP 2.17 MEMORY 14660.0 14532.0 14660.0 78.9 87.9 TOOL NtrMBER PO669SP4 PO669SP4 6.000 6.0 LSND 10.20 57.0 9.3 7OO FLUID LOSS (C3) : RESISTIVITY (OHM14) 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 3.4 .88O .340 .700 2.520 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 RPX MWD 12 OH14M 4 1 68 8 3 RPS MWD 12 OHM~ 4 1 68 12 4 RPM MWD 12 OHMM 4 1 68 16 5 RPD MWD 12 OHMM 4 1 68 20 6 ROP MK~ 12 FT/H 4 1 68 24 7 FET MWD 12 HOUR 4 1 68 28 8 91.6 Name Min Max DEPT 14484 14659.5 GR 102.016 214.646 RPX 6.1756 59.1695 RPS 15.0306 91.5021 RPM 15.1425 2000 RPD 17.0331 2000 ROP 3.3484 65.9474 FET 3.0294 24.0413 Mean Nsam 14571.8 136.309 24 5414 32 9914 69 1904 69 6124 22 9214 10 1351 First Last Reading Reading 352 14484 14659.5 255 14484 14611 255 14491 14618 255 14491 14618 255 14491 14618 256 14490.5 14618 253 14533.5 14659.5 255 14491 14618 First Reading For Entire File .......... 14484 Last Reading For Entire File ........... 14659.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/08/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File