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Home My WebLink About203-212Nolan 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: 12/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 05-04A 50029201520100 196089 10/30/2025 BAKER RPM PBU F-18B 50029206360200 225099 11/4/2025 BAKER MRPM END 1-39A 50029218270100 206187 11/20/2025 READ PressTempSurvey END 1-55 50029217880000 188021 11/26/2025 READ PressTempSurvey END 1-57 50029218730000 188114 11/18/2025 READ CaliperSurvey END 1-63 50029219050000 189006 11/23/2025 READ PressTempSurvey END 1-65A 50029226270100 203212 11/29/2025 READ PressTempSurvey END 2-18 50029220320000 190043 11/19/2025 READ PressTempSurvey END 2-20 50029220480000 190060 11/24/2025 READ PressTempSurvey END 2-32 50029220840000 190119 11/30/2025 READ PressTempSurvey END 2-46B 50029219210200 197137 11/21/2025 READ PressTempSurvey NCI A-13 50883200870000 192106 11/27/2025 READ Caliper Survey NS-33A 50029233250100 208189 5/22/2025 READ EVCamera Please include current contact information if different from above. T41175 T41176 T41177 T41178 T41179 T41180 T41181 T41182 T41183 T41184 T41185 T41186 T41187 END 1-65A 50029226270100 203212 11/29/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.05 11:03:29 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,379 feet NA feet true vertical 10,249 feet NA feet Effective Depth measured 15,341 feet 11,941, 12,517 feet true vertical 10,235 feet 9,774, 10,057 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# / 13Cr80 11,988' 9,801' Packers and SSSV (type, measured and true vertical depth) See Above 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 10,160psi 10,540psi 4-1/2" HES HXO SVLN 1,570 MD/ 1,525 TVD Production Liner 568'4-1/2"12,560' 10,067' 7-5/8" x 4-1/2" S-3 and 7-5/8" x 5-1/2" LTP TVD 4-1/2"10,087' NA 2,470psi 7,500psi 11,170psi 5,210psi 5,140psi 8,430psi 10,570psi 8,180psi 10,247' 12,990' 15,375' Intermediate 30" 7-5/8" 60' 5,212' 12,721' 12,721' 10,083' Casing 10-3/4" ENDICOTT / ENDICOTT OIL Conductor 5,212'Surface Burst NA Collapse Intermediate Plugs Junk measured measured NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047502 DUCK IS UNIT MPI 1-65A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-212 50-029-22627-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 119 Gas-Mcf 1900 6905 19002979 33 4394559 314 4273 N/A measured true vertical Packer MD 60' Size 60' 4,437' Length Production Liner 473' 2,815'4-1/2" Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Aras Worthington aras.worthington@hilcorp.com 907-564-4763 324-675 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.05.20 12:44:59 -08'00' Justus Hinks (3691) By Grace Christianson at 2:31 pm, May 20, 2025 JJL 6/13/25 RBDM JSB 052325 DSR-6/3/25 Well Name Rig API Number Well Permit Number Start Date End Date END 1-65A LRS CTU #1 / Slickline 50-029-22627-01-00 203-212 1/26/2025 4/20/2025 Hilcorp Alaska, LLC Weekly Operations Summary LRS CTU #1 1.5" Coil 0.134" WT, Job Scope = Drift/log and Adperf Continue in hole with HES TCP 2" perf gun. At the flag coorelate to bottom shot depth. RIH and tag PBTD. Shoot on bottom, 15307-15337 with 2" 60 degree ohase 6 SPF 30' perf gun. POOH. Freeze protect tubing. Verified shots fired. BD spent 2" HES perf guns. RDMO. ***Job Complete*** LRS CTU #1 1.5" Coil 0.134" WT, Job Scope = Drift/log and Adperf Continued to jet in hole, stopped at 13085 CTM. Chasing debris up and down the hole. POOH to swap tools. MU YJ milling assembly w/ 2.3 VBS. RIH Dry drifted down with multiple wiper trips to circulate slick 1% kcl w/ Safelube. Tag @ 15,348' CtM. Circulate slick 1% kcl w/ Safelube and Chase up hole. Make two passes from 12,400' to 13,200' CTM. POOH. BD YJ 2.3 VBS (recover 1/4 cup of rubber & couple small pieces of metal). MU YJ MHA and HES GR/CCL 2.2" Carrier w/ 2.25" DJN. RIH tag PBTD 15,350.79' CTM. Log up 50 fpm. Paint Flag @ 15,269.16 CTM. Log up 50 fpm. Stop at 11800 for top of log. POOH. Good data at surface, -13' correction. MU HES 2" x 30' perf gun. RIH. ***Job Continued 1/28/25*** 1/28/2025 - Tuesday 1/26/2025 - Sunday LRS CTU #1 1.5" Coil 0.134" WT, Job Scope = Drift/log and Adperf Mobilize CTU #1. NU BOPs. RU Planks top WH. Fnc Test BOPs. MU YJ internal ctc & MHA. MU HES Mem GR/CCL logging tools w/ 2.2" Carrier + LRS two 2" stingers + 2.25" DJN. Tag 12622 CTM. Jet down to 12904 CTM. ***Job Continued 1/27/25*** 1/27/2025 - Monday 3/31/2025 - Monday Slickline: ***WELL FLOWING ON ARRIVAL***(perforating) TAGGED TOP OF 4 1/2" BBE W/ 3.83" GAUGE RING @ 1,575' SLM EXTRACTED/PULLED 4 1/2" BBE (HBB-493) FROM HXO NIPPLE @ 1,570' MD (looks good) RAN 4 1/2" BRUSH, 3.80" GAUGE RING TO 7,750' SLM ***CONT WSR ON 4/1/25*** 4/1/2025 - Tuesday Slickline:***CONT WSR FROM 3/31/25*** (perforating) SET 4 1/2" SS CATCHER @ 7,700' SLM BAITED/PULLED BK-S/O FROM STA #5 @ 6,237' MD MADE 2 UNSUCCESSFUL ATTEMPTS TO SET BK-LGLV IN STA #5 WEATHER STANDBY ***CONT WSR ON 4/2/25*** Well Name Rig API Number Well Permit Number Start Date End Date END 1-65A LRS CTU #1 / Slickline 50-029-22627-01-00 203-212 1/26/2025 4/20/2025 Hilcorp Alaska, LLC Weekly Operations Summary 4/15/2025 - Tuesday LRS CTU #1- 1.50" Blue Coil Job Objective: AddPerf MIRU CTU. Perform weekly BOP test. M/U YJ MHA and HES GR/CCL. PT to 3500psi. Stab on lubricator and PT PCE 297/4060. Load well with 240bbls KCL w/SL cap with 5bbls 60/40 and 5bbls diesel. RIH dry tag at 13,418. Pick up and dry drift again making it further each time. No set downs after 13,600. Dry drift to PBTD. Log up to 11,900 with small weight bobbles at 13,474, 13,445, and 13,325. POOH, L/D HES GR/CCL ...Job in Progress... 4/2/2025 - Wednesday Slickline: ***CONT WSR FROM 4/1/25*** (perforating) ATTEMPTED TO SET BK-LGLV IN STA #5 @ 6,237' MD (brought back) RAN POCKET BRUSH TO STA #5 @ 6,237' MD (tt pin sheared) SET BK-LGLV(20/64", 2088#) IN ST#5 @ 6,237' MD. PULLED BK-LGLV FROM ST#6 @ 4,133' MD.(3rd attempt) SET BK-LGLV(16/64",1848#) IN ST#6 @ 4,133' MD. PULLED BK-DGLV FROM ST#4 @ 7,548' MD SET BK-SOGLV (28/64") IN ST#4 @ 7,548' MD PULLED 4-1/2" SS CATCHER @ 7,700' SLM DRAW DOWN IA 260psi (holding) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED ON WELL STATUS*** 4/16/2025 - Wednesday LRS CTU #1- 1.50" Blue Coil **Cont. from WSR 4-15-25*** Job Objective: AddPerf Make up 1.69" motor/fishing BHA with 1" MT pin facing down to engage threads on fish. RIH. Roll coil to KCl and spin into carrier at TD, 15310' CTMD. PUH with motor spinning at low rate to maintain engagement. Multiple heavy overpulls and MW at 13412, 13393, 13090'. Recover logging carrier and confirm good data, +2' correction. Make up 31' of 2" MaxForce perf guns, 6 spf and RIH. Correct to top shot at the flag. RIH past shot depth. PUH to top shot depth. Load & pump 1/2" firing ball. Perf interval 15,192' - 15,223'. (2" MaxForce, 60deg 6 spf). POOH. ~29 bbls FP in well. Break off firing head.Confirm shots fired. RD. Stand by for weather. ...Continued on WSR 4-17-25... 4/17/2025 - Thursday LRS CTU #1 - 1.50" Blue Coil ***Cont. from WSR 4-16-25*** Job Objective: AddPerf Continue weather standby due to high winds. ...In Progress.... Well Name Rig API Number Well Permit Number Start Date End Date END 1-65A LRS CTU #1 / Slickline 50-029-22627-01-00 203-212 1/26/2025 4/20/2025 Hilcorp Alaska, LLC Weekly Operations Summary LRS CTU #1 - 1.50" Blue Coil ***Cont. from WSR 4-17-25*** Job Objective: AddPerf Continue weather standby due to high winds. Side winds above 25 mph not allowing the unit to lower mast. ~04:00 winds below 25 mph. Lower Mast and pull unit out of the way. Snow removal in progress on 03-07. ***Job Complete*** Slickline: ***WELL S/I ON ARRIVAL*** (Perforating) RAN 4-1/2" BRUSH & 3.79" GAUGE RING TO 1,570' MD ATTEMPTED TO SET 4-1/2" BBE AT 1,570' MD (see log) ***CONTINUE ON 4/20/25 WSR*** 4/20/2025 - Sunday ***CONTINUED FROM 4/19/25 WSR*** (Perforating) SET 4-1/2" BBE (sn: HBB-423, 3 sets oversize pkg w/ swell fix o-rings) AT 1,570' MD RAN 4-1/2" CHECK SET TO 1,570' MD (sheared) ***WELL LEFT S/I ON DEPARTURE*** 4/18/2025 - Friday LRS CTU #1 - 1.50" Blue Coil ***Cont. from WSR 4-17-25*** Job Objective: AddPerf Continue weather standby due to high winds. ...In Progress.... 4/19/2025 - Saturday Hilcorp Alaska, LLC Perforated from 12,005' - 12,020' on 11/28/2021 12/22/21 DH Perforated (11/28/21) 2-1/2"6 12,005' - 12,020'O 11/28/2021 ~60 2"6 15,307' - 15,337'O 1/28/2025 Dome SO Gen 2 Mod 28 4/2/25 4/2/25 4/2/25 4/2/25 DH Deeper GL Design 2" 6 15,192' - 15,223' O 4/16/2025 5/20/25 DH Perforated (4/16/25) Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' 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? Yes No 9.Property Designation (Lease Number):10. Field: ENDICOTT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,379 NA Casing Collapse Conductor NA Surface 2,470psi Intermediate 8,180psi Intermediate 7,500psi Production Liner 10,540psi Production Liner 11,170psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng C.O. 462.007 7-5/8" x 4-1/2" S-3 & 7-5/8" x 5-1/2" LTP and 4-1/2" HES HXO SVLN 11,941MD/ 9,774TVD & 12,517MD/ 10,057TVD and 1,570MD/ 1,525TVD NA 12,560' 12,990' 568' 2-7/8" See Schematic 907-748-8581 brenden.swensen@hilcorp.com Operations Manager January 1, 2025 15,375'2,815' 4-1/2" 10,247' Perforation Depth MD (ft): See Schematic 10,067'3-1/2" 60' 30" 10-3/4" 7-5/8" 5,212' 4-1/2"473' 12,721' 5,210psi 5,140psi 4,437' 10,083' 10,087' 5,212' 12,721' 60' 60' 12.6# / 13Cr80 TVD Burst 11,988' 10,160psi MD NA 8,430psi Length Size Proposed Pools: 10,249 15,341 10,235 2,843 ENDICOTT OIL ENDICOTT OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047502 203-212 DUCK IS UNIT MPI 1-65A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22627-01-00 Hilcorp Alaska, LLC PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 10,570psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Brenden Swensen Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:45 am, Nov 27, 2024 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2024.11.26 16:27:40 -09'00' Justus Hinks (3691) 324-675 10-404 DSR-12/16/24JJL 12/03/24 SFD 12/2/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.16 15:57:38 -09'00'12/16/24 RBDMS JSB 121724 Page 1 of 5 Coil Add Perf Well: END 1-65A PTD: 203-212 Well Name: END 1-65A API Number: 50-029-22627-01 Current Status: Operable Producer PTD # 203-212 Estimated Start Date: 1/1/2025 Rig: Coil Reg.Approval Req’std? Yes Estimated Duration: 3 days Regulatory Contact: Darci Horner 907-777-8406 (O) First Call Engineer: Brenden Swensen 907-748-8581 (M) Second Call Engineer: Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure: 3843 psi @ 10,000’ TVD (SBHPS 6/26/2022) Maximum Expected BHP: 3843 psi @ 10,000’ TVD (est.) 7.4ppg EMW Max. Anticipated Surface Pressure: 2843 psi Gas Column Gradient (0.1 psi/ft) H2S Level: Current 340ppm 01/16/2024, Historical Max 475ppm 01/22/2021 Wellbore Condition History Well 1-65A is a coil sidetrack completed in 4/18/2004. The sidetrack wellbore was considered swept and not perforated. The parent wellbore was then perforated in the K2B from 12485 – 12505’ MD on 4/25/2004 post rig. In 2021, the well was perforated again in the parent bore in the S3A3 from 12005 – 12020’ MD on 11/28/2021. Eline was not able to get through the 3.5” x 2.865” cross over at 12,560’ MD with a tractor BHA. Based on observed wear spots along the body of the tool string, it is anticipated that dogleg severity may be the culprit for the tool string getting hung up. Based on follow up conversations with multiple PNL vendors, no vendor is comfortable with running their PNL logging tool strings through the severe dog legs in this well. Perfs will be shot based on original open hole logs from 2004. Objective Perforate the CTD liner. Locations based on 2004 open hole logs as well as updated reservoir data from offset producers. Page 2 of 5 Coil Add Perf Well: END 1-65A PTD: 203-212 Procedure Coil 1. MIRU, pressure test PCE 250psi low, 3,500psi high. 2. Drift to TD with ±2.30” jet nozzle. Take returns to surface. a. Record any sticking/drag points or set downs in well service report. b. Well completed in 2004, no prior entry into liner has been attempted/completed. 3. If not able to make it to TD without issues, be prepared to pick up venturi and/or motor and 2.30” mill. a. Discuss with OE on set down depths, and possible options. 4. Flag pipe ±100’ from PBTD tag. 5. Pick up GR/CCL/CBL logging tool string and perform tie in pass from PBTD to 11,900’. This will be the first cased hole log for the CTD liner. a. Send PDF and .las files to town OE’s and Geologist for depth tie into open hole logs. No cased hole logs available for this interval. i. Geo: Brock Rust – brust@hilcorp.com – 615-306-9509 ii. OE: Brenden Swensen - Brenden.swensen@hilcorp.com - 907-748-8581 6. Make up perf guns. Perforate based on the following perf schedule. a. Primary target perforations are 15,312 – 15,341’ MD (29’). i. If necessary, adjust overall gun lengths based on deepest depth achieved. b. Contingent secondary target perforations are 15,192 – 15,226’ MD (34’). i. These are fall back perforations if we cannot get to primary target. ii. If primary target perfs are achieved but not competitive, will set CIBP prior to shooting secondary target perforations. Slickline 7. MIRU, pressure test PCE 250psi low, 3,500psi high. 8. Set SSSV from 1570’ MD. Page 3 of 5 Coil Add Perf Well: END 1-65A PTD: 203-212 Dog Leg Severity Intervals With Greater Than 5deg/100ft MM D T VD In c l Az i m D o g L e g M D TVD In c l Az i m D o g L e g 11,534 9,507 35.9 139.38 10.0 13,815 10,082 90.7 127.34 16.9 11,565 9,532 38.1 136.25 9.7 13,841 10,082 90.6 129.98 10.1 11,597 9,557 39.7 134.4 6.0 13,870 10,082 89.7 127.17 10.2 11,629 9,581 42.0 133.44 7.6 13,899 10,082 90.3 122.81 14.8 11,660 9,604 45.0 132.46 9.7 13,930 10,081 92.5 120.24 11.0 11,691 9,625 46.8 130.69 7.3 13,961 10,080 92.6 117.22 9.9 11,724 9,647 49.2 129.6 7.6 13,990 10,079 90.6 112.69 16.8 11,755 9,667 51.4 128.11 8.0 14,020 10,078 90.4 109.07 12.1 11,822 9,707 54.8 128.37 6.1 14,058 10,078 90.1 102.88 16.6 12,265 9,959 61.1 125.47 8.5 14,089 10,078 89.6 100.07 9.1 12,297 9,974 62.3 127.47 6.8 14,122 10,078 90.8 97.17 9.7 12,327 9,987 63.4 129.37 6.7 14,153 10,077 94.0 95.5 11.5 12,390 10,014 66.3 130.87 6.7 14,184 10,075 92.9 99.83 14.2 12,421 10,026 68.2 129.81 6.6 14,216 10,074 92.1 103.79 12.6 12,452 10,037 69.9 130.12 5.6 14,249 10,073 91.9 107.66 12.0 12,488 10,049 71.7 129.31 5.5 14,290 10,071 91.4 111.95 10.5 12,520 10,058 74.3 128.68 8.7 14,321 10,071 90.6 113.82 6.6 12,549 10,065 77.6 128.18 11.3 14,351 10,071 88.7 110.92 11.5 12,581 10,071 80.7 127.27 10.1 14,382 10,072 89.5 106.94 13.1 12,612 10,076 82.7 124.63 10.7 14,412 10,072 89.8 103.22 12.4 12,641 10,079 84.5 123.68 6.7 14,443 10,072 89.5 98.71 14.6 12,675 10,082 86.2 123.98 5.1 14,470 10,072 89.1 96.07 10.0 12,767 10,085 89.8 119.46 6.4 14,491 10,072 90.2 93.67 12.6 12,958 10,087 89.3 123.8 7.9 14,520 10,072 90.6 90.63 10.4 13,020 10,088 90.3 126.8 13.7 14,551 10,072 91.1 87.71 9.6 13,051 10,087 93.6 129.8 14.7 14,580 10,071 90.0 84.1 12.8 13,080 10,084 94.9 133 11.7 14,611 10,072 88.8 81.43 9.5 13,110 10,083 91.7 135.75 14.3 14,641 10,072 88.5 78.51 10.0 13,125 10,083 89.5 138.53 23.5 14,734 10,076 84.8 85.52 26.2 13,161 10,082 93.4 149.13 31.2 14,767 10,079 84.8 87.77 6.8 13,238 10,079 89.5 143.28 20.1 14,802 10,082 84.9 90.9 9.0 13,264 10,080 86.8 139.08 19.6 14,835 10,085 84.9 95.28 13.0 13,294 10,081 86.7 135.83 10.8 14,871 10,088 84.3 100.21 13.9 13,329 10,083 89.5 130.97 15.8 14,902 10,091 84.2 103.46 10.6 13,359 10,082 91.5 129.69 8.0 14,932 10,095 81.2 102.8 10.3 13,387 10,082 91.5 125.24 15.5 14,967 10,102 77.3 99.64 14.2 13,427 10,082 87.8 117.98 20.7 14,997 10,109 75.0 98.13 8.9 13,462 10,083 88.6 113.97 11.7 15,031 10,119 71.1 91.75 21.8 13,496 10,083 90.7 109.28 15.0 15,059 10,128 70.2 88.42 11.3 13,531 10,082 93.6 105.92 12.8 15,098 10,142 68.7 74.85 33.4 13,561 10,080 92.8 101.88 13.5 15,130 10,154 66.0 71.98 11.6 13,593 10,079 91.3 99.58 8.7 15,169 10,169 67.4 65.08 16.7 13,623 10,079 89.9 103.27 13.2 15,202 10,182 67.1 60.99 11.4 13,653 10,079 88.1 105.86 10.4 15,232 10,194 67.6 53.65 23.1 13,683 10,081 85.9 110.23 16.2 15,260 10,204 67.8 51.25 7.9 13,716 10,083 87.2 114.26 12.8 15,292 10,217 67.5 44.18 20.3 13,749 10,084 90.7 117.57 14.4 15,319 10,227 68.7 41.46 10.2 13,781 10,083 92.0 121.71 13.9 15,350 10,238 68.8 36.12 16.4 Hilcorp Alaska, LLC Perforated from 12,005' - 12,020' on 11/28/2021 12/22/2021 DH Perforated (11/28/021) 2-1/2"6 12,005' - 12,020'O 11/28/2021 Perforated from 12,005' - 12,020' on 11/28/2021 ~60 Hilcorp Alaska, LLC Perforated from 12,005' - 12,020' on 11/28/2021 12/22/2021 DH Perforated (11/28/021) 2-1/2"6 12,005' - 12,020'O 11/28/2021 Perforated from 12,005' - 12,020' on 11/28/2021 ~60 PRIMARY 15,312 - 15,341' MD (29') CONTINGENT 15,192 - 15,226' MD (34') Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 1/12/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPI 1-65A (PTD 203-212) PERF 11/28/2021 Please include current contact information if different from above. 37' (6HW Received By: 01/12/2022 By Abby Bell at 10:57 am, Jan 12, 2022 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/28/2021 To: Department of Natural Resources Resource Evaluation 550 W 7th Ave, Suite 1100 Anchorage, AK 99501 DATA TRANSMITTAL MPI 1-6A (PTD 203-212) Perf Record 11/28/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/29/2021 By Abby Bell at 8:55 am, Dec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y Samantha Carlisle at 7:49 am, Dec 27, 2021 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU SFD 12/28/2021 DSR-1/3/22MGR18JAN2022 RBDMS HEW 12/29/2021 +LOFRUS$ODVND//& 3HUIRUDWHGIURP RQ '+3HUIRUDWHG 2 2 tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϭͲϲϱ Ͳ>ŝŶĞ ϱϬͲϬϮϵͲϮϮϲϮϳͲϬϭͲϬϬ ϮϬϯͲϮϭϮ ϭϭͬϮϴͬϮϬϮϭ ϭϭͬϮϴͬϮϬϮϭ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϭͬϮϳͬϮϬϮϭͲ^ĂƚƵƌĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϭͬϯϬͬϮϬϮϭͲdƵĞƐĚĂǇ ϭϭͬϮϴͬϮϬϮϭͲ^ƵŶĚĂǇ t>>^ͬ//EZZ/s>͘:K^KW;'ZͲ>dK^,KKd'hE/EdZs>ϭϮϬϬϱΖͲϭϮϬϮϬΖt/d,Ϯ͘ϱΖΖyϭϱΖ'hEͿWdWϮϱϬ>KtͲ ϯϬϬϬ,/',͕>K'KZZ>ddKƚůĂƐKƉĞŶŚŽůĞ>ŽŐ͕dϰͬϮϬϬϰ͕^,KKd'hE/EdZs>ϭϮϬϬϱΖͲϭϮϬϮϬΖ͕>dKdKW ^,KdсϭϮ͘ϲΖ͕>^dKWWd,сϭϭϵϵϮ͘ϰΖ͘t>>>&d^ͬ/KEWZdhZ͕WKWEKd/&/͘ ϭϭͬϮϵͬϮϬϮϭͲDŽŶĚĂǇ ϭϭͬϮϲͬϮϬϮϭͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϭͬϮϰͬϮϬϮϭͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϭͬϮϱͬϮϬϮϭͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ^,KKd'hE/EdZs>ϭϮϬϬϱΖͲϭϮϬϮϬΖ 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): 15,379'N/A Casing Collapse Structural N/A Conductor 2,470psi Surface 8,180psi Intermediate 7,500psi Production Liner 10,540psi Production Liner 11,170psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 473' 12,721' 12,560' Perforation Depth MD (ft): 12,990' 568' 2-7/8"15,375'2,815' 60'30" 10-3/4" 7-5/8" 5,212' 10,087' 5,212' 12,721' 10,067'3-1/2" 4-1/2" Length Size 60'60' 12.6# / 13Cr80 TVD Burst 11,988' 10,160psi MD N/A 8,430psi 5,210psi 5,140psi 4,437' 10,083' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047502 203-212 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22627-01-00 Hilcorp Alaska LLC ENDICOTT / ENDICOTT OIL C.O. 462.007 DUCK IS UNIT MPI 1-65A 10,570psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 7-5/8" x 4-1/2" S-3 & 7-5/8" x 5-1/2" LTP and 4-1/2" HES HXO SVLN 11,941MD/ 9,774TVD & 12,517MD/ 10,057TVD and 1,570MD/ 1,525TVD See Schematic See Schematic 11/25/2021 4-1/2" 10,247' 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Joleen Oshiro joleen.oshiro@hilcorp.com 907-777-8486 Operations Manager 10,249'15,341'10,235'2,080 15,341' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 11:18 am, Nov 09, 2021 321-574 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2021.11.09 11:00:03 -09'00' Torin Roschinger (4662) X 10-404 DLB 11/09/2021 MGR10NOV2021 DSR-11/10/21 X dts 11/12/2021 11/12/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.12 08:27:25 -10'00' RBDMS HEW 11/15/2021 S3A3 Perf Add Well: END 1-65A PTD: 203-212 API: 50-029-22627-01 Well Name:END 1-65A API Number:50-029-22627-01 Current Status:Operable Rig:SL, EL Estimated Start Date:11/25/2021 Estimated Duration:3 days Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner 777-8406 Permit to Drill Number:203-212 First Call Engineer:Joleen Oshiro (907)-777-8486 (O) (650)-483-4774 (M) Second Call Engineer: AFE Number: Well EZ Inputs Required:Yes Current Bottom Hole Pressure:4,000 psi @ 10,000’ TVD (SBHP offsets) Maximum Expected BHP: 4,000 psi @ 10,000’ TVD (SBHP offsets) MPSP:3,000 psi (0.1 psi/ft gas gradient) Max Deviation: 95° at 13,080’ md Minimum ID:2.813” X Nipple @ 12,002’ MD Reference Log:Atlas Openhole Log, 4/2004 Brief Well Summary: Well 1-65A is Operable and a cycle well due to high watercut; current perfs are in the K2A. Proposing to perforate 15' of uphole perfs. Uphole add perfs are in the S3A3 zone, which is the same zone that the majority of well 1- 29's oil is coming from. Endicott well 1-29 is currently producing at 265 bopd, 7000 bwpd, 19 mmscf/d fgas, 96.4% watercut, 75k gor. We anticipate that this intervention in 1-65A will yield similar results to 1-29's current production rate. 1-65A Most recent well test 10/1/21: 27 bopd, 0.4 mmscf/d, 5300 bwpd, 15k fgor, 99.5% watercut, 199 WOR Most recent tag 9/8/17: drift with 1.75’’ swedge to 12,349’ MD set down due to deviation. Objective: Shoot 15' of uphole perforations. Proposed gun run must be confirmed with town Gun Run # Perf Top Perf Bottom Perf Length 1 ±12,005’ MD ±12,020’ MD 15’ Total 15’ Table 1: END 1-65A Proposed Perf Gun Run -00 DLB -00 DLB S3A3 Perf Add Well: END 1-65A PTD: 203-212 API: 50-029-22627-01 Procedure: Slickline 1. RU SL unit and pressure test to 250psi low 3,500 psi high. 2. Pull SSSV at 1570’ MD. 3. Dummy gun drift with BHA that emulates 15’ x 2.5’’ perf guns to target depth of 12,050 ‘ MD. If cannot get down to target depth, shorten up dummy gun drift. If shorter dummy gun drift does not go down, downsize dummy gun drift OD to emulate 1.75’’ guns. Sundry Procedure (Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low 3,500 psi high. 2. RIH and obtain a GR/CCL correlation pass,Contact Joleen Oshiro at (650)-483-4774 to get final perf depths. 3. Perforate 15’ per final approved perf depths. Slickline 1. RU SL unit and pressure test to 250psi low 3,500 psi high. 2. Set SSSV at 1570’ MD. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic -00 DLB S3A3 Perf Add Well: END 1-65A PTD: 203-212 API: 50-029-22627-01 Current WBS -00 DLB -00 DLB S3A3 Perf Add Well: END 1-65A PTD: 203-212 API: 50-029-22627-01 Proposed WBS -00 DLB -00 DLB STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMISSION ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Acid Wash ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 203-212 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-50-029-22627-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047502 DUCK IS UNIT MPI 1-65A RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ENDICOTT OIL AUG 3 1 2016 11.Present Well Condition Summary: Total Depth measured 15,379 feet Plugs measured 15,341 feAOGC" true vertical 10,249 feet Junk measured N/A feet Effective Depth measured 15,341 feet Packer measured 11,941 &12517 feet true vertical 10,235 feet true vertical 9,774&10,058 feet Casing Length Size MD TVD Burst Collapse Conductor 60' 30" 60' 60' N/A N/A Surface 5,212' 10-3/4" 5,212' 4,437' 3,580psi 2,090psi Intermediate 12,721' 7-5/8" 12,721' 10,084' 8180 si 7,150psi Intermediate 473' 4-1/2" 12,990' 10,087' 8,430psi 7,500psi Production Liner 568' 3-1/2" 12,560' 10,067' 10,160psi 10,540psi Production Liner 2,815' 2-7/8" 15,375' 10,247' 10,570psi 11,170psi Perforation depth Measured depth See Attached Schematic True Vertical depth 10,048 to 10,054 SCANNED FEB 1 2017 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr80/NSCT 11,988' 9,802' 7-5/8"x4-1/2"S-3 1,570'(MD) Packers and SSSV(type,measured and true vertical depth) 7-5/8"x 5-1/2"LTP 4-1/2"HES HXO SVLN See Above 1,525'(TVD) 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 2,100 0 Subsequent to operation: 97 5,570 4,890 1,850 252 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ DevelopmentLi Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Li SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-327 Contact Taylor Wellman -i ) Email twellman@hilcorp.com Printed Name Mike Dunn ' Title Operations Manager Signature w f..- /(Irk Phone 777-8382 Date 8/31/2016 / > Form 10-404 Revised 5/2015 RBDMS t/L SEp - 1 2016 Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-65A Slickline 50-029-22627-01-00 203-212 7/5/2016 7/30/2016 ppiss, iU�( o K- m�,1�l ? a -9511'N °itt rations ,rcii l _ ,t,')1111 _ 1 II Aa iib)r ' 6/29/16 Wednesday No Operations to Report. 6/30/16-Thursday No Operations to Report. 7/1/16-Friday No Operations to Report. 7/2/16-Saturday No Operations to Report. 7/3/16-Sunday )� �A1l A15401101111011, No Operations to Report. 7/4/16-Monday No Operations to Report. 7/5/16-Tuesday ,111111111(1',,I, Initial T/I/0=950/2080/100psi.RU LRS pump truck to tbg.PT lines to 300psi/3500psi. Pump 5.5bbls 7.5%HCI down tubing.Follow w/3 bbls Meth.Wait 30 min,pump 30 bbls of diesel(clear of SSSV).RU SL,PT to 250psi/2000psi.RIH and latch SSSV at 1570'md.Jar for-1 hr,shear off and lay down for night. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-65A Slickline 50-029-22627-01-00 203-212 7/5/2016 7/30/2016 Daily Operations: Pm 7/6/2016-Wednesday WELL S/I ON ARRIVAL, PT 250 LOW/2050 HIGH (fish bbe). RAN A 3.5" GR PINNED STEEL...S/D ON CENTER SPEAR @ 1577' SLM,JAR UP FIVE TIMES AND SHEAR GR. RUN 3.5" DOGLESS GS (STEEL),JAR DOWN TEN TIMES AND ABLE TO SHEAR GS. BLED TUBING DOWN TO 1,000 PSI TO PUT DIFFERENTIAL ON VALVE, UNABLE TO EXTRACT VALVE. RAN 3/5" GS (STEEL) FOUR MORE TIMES AND UNABLE TO GET SSSV MOVING. 7/7/2016-Thursday (well s/I on arrrival, P/T TO 250 LOW, 2050 HIGH, (fish bbe). RAN A 3.5" GR (STEEL)AND LATCH UP TO SPEAR @ 1,579' SLM, JAR DOWN FOR 40 MINUTES. NO MOVEMENT. RAN A 3.5" S (STEEL)AND LATCHED UP TO SPEAR @ 1576' SLM,JAR UP FOR 1 HOUR, AFTER 30 MINUTES OF JARRING UP THE CONTROL LINE LOST INTEGRITY AND CAME DOWN TO TUBING PRESSURE (1,725 PSI). RAN A 3.5" GS(STEEL) 5 TIMES AND LATCHED UP TO SPEAR @ 1576' SLM,JAR UP 1 HOUR, NO MOVEMENT. RDMO TO WELL 2-26. 7/8/2016-Friday No activity to report. 7/9/2016-Saturday No activity to report. 7/10/2016-Sunday No activity to report. 7/11/2016- Monday No activity to report. 7/12/2016-Tuesday No activity to report. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-65A Slickline 50-029-22627-01-00 203-212 7/5/16 7/30/16 Daily Operations: 7/13/2016-Wednesday No activity to report. 7/14/2016-Thursday PT 200/2,000 PSI (GOOD TESTS). RUN A 3.5" GS THREE TIMES AND LATCH UP TO SPEAR PLANTED IN SSSV @ 1,574' SLM (1,570'MD),JAR UP FOR AN HOUR 1-1/2 TO 2 HOURS PER RUN AND NO MOVEMENT. 7/15/2016- Friday PT 200/2,200 PSI (GOOD TESTS). RAN 4.5" GS AND SIT DOWN ON SPEAR @ 1,577' BLM, UNABLE TO LATCH UP TO SPEAR. RAN 3.5" GS,TRIED TO BEAT THE 3.5" FISH NECK@ 1,577' BLM DOWN TO BE ABLE TO LATCH THE 4.5" FISH NECK TO PULL SPEAR. RAN 4.5" GS BUT STILL UNABLE TO LATCH UP TO THE SPEAR @ 1,577' BLM.;RAN 3.5" GS TWO MORE TIMES AND JARRED UP AT 2,500#OJ LICKS, NO MOVEMENT ON SPEAR AND SSSV. ON THE SECOND RUN AFTER JARRING FOR 20 MINUTES THE QUICK CONNECT TO THE BHA PULLED OUT AND ROLLED THE INTERNAL PROFILE. GS IS STILL IN THE WELL. 7/16/2016-Saturday PT 200/2,000 PSI (GOOD TESTS). PULLED 3.5" GS OUT OF SPEAR @ 1,574' BLM, QUICK CONNECT WAS BROKE. RAN 3.5" GS BUT COULD NOT LATCH UP TO SPEAR. RAN 4.5" GS AND COULD NOT LATCH UP TO SPEAR. RAN 3.5" GS (TWO TIMES)AND LATCHED UP TO SPEAR @ 1,574' BLM,JARRED UP FOR 70 MINUTES TOTAL BETWEEN THE TWO RUNS BUT WAS UNABLE TO MOVE THE SSSV. RDMO. 7/17/2016-Sunday No activity to report. 7/18/2016- Monday No activity to report. 7/19/2016-Tuesday No activity to report. 110 • • II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig _ API Number Well Permit Number Start Date End Date END 1-65A Slickline 50-029-22627-01-00 203-212 7/5/16 7/30/16 Daily Operations: 7/20/2016-Wednesday (well s/I on arrival) P/T TO 250 LOW, 2050 HIGH, (fish bbe sssv). MADE THREE MORE ATTEMPTS TO PULL SSSV W/ NO LUCK -ON LAST RUN DOGS ON GS ROLLED REALLY BAD &ALMOST STRIPPED OFF. MADE A RUN AND JARRED DOWN ON SPEAR TO TRY AND RELEASE. ATTEMPTED TO RECOVER SPEAR W/NO LUCK INDICATING THAT INNER CORE NOT PUSHED DOWN TO RELEASE SPEAR.;CURRENTLY SWAPPING BACK TO .125" SS WIRE TO GET BETTER ACTION TO JAR DOWN ON CORE OF SPEAR AND TRY TO RECOVER. 7/21/2016-Thursday (well s/I on arrival) P/T TO 250 LOW, 2050 HIGH, (fish bbe sssv). RAN 3.80" BARBELL W/3'x2-1/8" STEM TO TRY TO SHIFT CORE IN X-LOCK SPEAR DOWN TO RELEASE. UNABLE TO GET SPEAR TO RELEASE AND ALLOW US TO RECOVER SPEAR. ATTEMPTED TO USE DIFFERENTIAL PRESSURE TO EXTRACT BBE SSSV FISH FROM HXO @ 1570' MD. LAY DOWN FOR THE NIGHT- NOTIFIED PAD OP 7/22/2016- Friday (well s/I on arrival) P/T TO 250 LOW, 2050 HIGH, (fish bbe sssv). MADE SEVERAL ATTEMPTS TO LATCH X-LOCK SPEAR IN BBE SSSV 1570' MD. UNABLE TO RECOVER SPEAR, CONTROL AND BALANCE LINE ARE HOLDING, BUT SSSV WILL NOT OPEN ALLOWING FLOW TUBE TO MOVE DOWNWARDS. WELL LEFT SHUT IN - NOTIFIED PAD OP OF DEPATURE. 7/23/2016-Saturday No activity to report. 7/24/2016-Sunday No activity to report. 7/25/2016- Monday No activity to report. 7/26/2016-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-65A Slickline 50-029-22627-01-00 203-212 7/5/16 7/30/16 Daily Operations: 7/27/2016-Wednesday No activity to report. 7/28/2016-Thursday No activity to report. 7/29/2016- Friday No activity to report. 7/30/2016-Saturday (well s/I on arrival) PIT TO 250 LOW, 2050 HIGH, (fish bbe sssv). RIGGED UP EXTRA RISER AND ATTEMPTED TO JAR DOWN ON X-LOCK SPEAR W/540 LBS OF WEIGHT BAR. UNABLE TO SHIFT CORE IN SPEAR DOWN FAR ENOUGH TO LATCH 4-1/2 F/N & UNABLE TO SSSV TO MOVE DOWNHOLE. UPON ARRIVAL WAS ABLE GAIN CONTORL& BALANCE LINE INTEGRITY, AFTER JARRING DOWN WE LOST THE CONTROL LINE INTEGRITY BUT THE BALANCE STILL HAD GOOD INTEGRITY AND BLEEDS TO ZERO. WELL LEFT SHUT IN I- NOTIFIED PAD OP OF DEPARTURE. 7/31/2016-Sunday No activity to report. 8/1/2016- Monday No activity to report. 8/2/2016-Tuesday No activity to report. TREE= OW • SAFETY NOTES-WELL ANGLE>TO"@ 15059'.*** WELLHEAD= FMC N D 1 -6 5A H2S READINGS AVERAGE 230-260 PPM ON AA_ ACTUATOR= BAKER C GAS INJECTORS*** WELL REQURES A SSSV*** KB.ELE 56' BF.Et_EV= 15' I � CHROME TBG&CT LNR***INITIAL WELLBORE BF.EL KOP= 300' /-- NOT SHOWN BELOWWS*** Max Angle= 95"@ 13080' (Datum MD= 12511' 30"CONDUCTOR 1570' H4-1/2"HES MO SVLN,ID=3.813" Datum TVD= 10000'SS -----DUCT —� .,--- -90 f I GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PDRT DATE 10-3/4'CSG,45.5#,L-80 BTC,ID=9.950" — 5212' °6 4133 3587 40 KBMGM DONE BK 16 01/29/96 LI "5 6237 5246 38 KBMGM SO BK 20 01/29/96 4 7548 6283 38 KBMGM DMY BK 0 01/09/96 3 8462 6998 39 KBMGM DMY BK 0 01/09/96 Minimum ID = 2.377" 1256Q' 2 9337 7687 38 KBMGM DMY BK 0 01/09/96 1 10210 8379 33 KBMGM DMY BK 0 01/09/96 3-1/2" X 2-7/8" XO °STA 5 s 6==VALVES STUCK IN POCKET(AWGRS 12/04/03) ' 11930' --14-1/2"HES X NP,D=3.813" z . 11941' —{7-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" ' ' 11964' —14-1/2"FES X PD?D=3.813' ' 11975' H4-1/2"HES xN NIP,MILLED TO 3.80'(01/19/04) / \� 11988' -14-1/2"WLEG,D=3.958' 4-1/2"TBG,12.6#,13CR-80 NSCT, H 11988' .0152 bpf,D=3.958" 11992' H3.70"BTT DEPLOY Nati SLV,D=3.00" I I 12002' H 3-1/2"HOWCO X NP,D=2.813" I I 1251? H7-518"X 5.112'BKR SBP LTP.8)=4.992' f 12527' --I7-5/8'X5-1/2"E3KR HMC LNR HGR,D=4.75' 12535' —51/2'X 4-1/2'I.NR AD,1)=3.958' 3-1/2"LNR,8.814, 13CR-80 STL, H 12560' i---1 12560' H3-1/2'X 2-7/8")OD,D=2.377' .0087 bpf,ID=2.992' I7-5/8'CSG,29.7#1,USS95 BTC-M,ID=6.875' -[ 12721' J , , 4-1/2"MLLouT vurDDw(oi-ssA) 12990'-12999' 4-112"WMPSTOCK(03/15/04) '— 12990' 4-1/2' LNR, 12.64, L-80 NSCT, —12990 i 0152 bpf,ID=3.958* PERFORATION SUMMARY RID=LOG: MCNL ON 04/15/04 ANGLE AT TOP PERF: 72'@ 12485' N,te:Refer to Production DB for historical perf data SIZE SPF M(TERVAL Opn/Sqz SHOT SQZ A" 2-1/2" 6 12485-12505 0 04/25/04 "Rmink Nam- PBTD H 15341' ••• 2-7/8"LNR,6.54,13CR-80 Sit,.0058 bpf,ID=2.441' —I 15375' DATE REV BY COIMENTS DATE REV BY CON1iENTS ENDICOTT UNIT 01/26196 015 INITIAL COMPLETION 02/19/13 RKT/JMD SET PX PLUG(02/14/13) WELL: 1-65A/N-27 04/18/04 NORDIC2 CTD SIDETRACK(F31D1-65A) 04/23/13 CDJ/JMD PULLED PX PLUG(04/09/13) PERMT No: 2032120 04/04/11 ?/JND REFORMATTING API No: 50-029-22627-01 08/12/11 DW/JMD ADDED I-2S SAFETY NOTE SEC 36,T12N,R16E,2222'FM_&2218'Fa 06/20/12 AS/JMD PERF CORRECTION Hilcorp Alaska, LLC ti OF Tit • • *.e"I//j, 6. THE STATE Alaska OSI and Gas o f Li A S KA Conservati®n Commission 333 West Seventh Avenue x-- Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 Off" ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 N 0 9 , Anchorage, AK 99503N��1 `�� " Re: Endicott Field, Endicott Oil Pool, MPI 1-65A Permit to Drill Number: 203-212 Sundry Number: 316-327 Dear Mr. Dunn: 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, ,j-e-4/Ck Cathy P Foerster Chair DATED this / -day of June, 2016. RBDMS 1,, JUN 1 3 2016 r • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 0 9 2016 • APPLICATION FOR SUNDRY APPROVALS AQGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Acid Wash 2- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory 0 Development ❑✓ • 203-212 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage Alaska 99503 50-029-22627-01-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 Will planned perforations require a spacing exception? Yes 0 No 0 DUCK IS UNIT MPI 1-65A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047502 ' ENDICOTT/ENDICOTT OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15,379' . 10,249' ' 15,341' 10,235' 2,080 15,341' N/A Casing Length Size MD TVD Burst Collapse Structural 60' 30" 60' 60' N/A N/A Conductor 5,212' 10-3/4" 5,212' 4,437' 3,580psi 2,090psi Surface 12,721' 7-5/8" 12,721' 10,084' 8,180psi 7,150psi Intermediate 473' 4-1/2" 12,990' 10,087' 8,430psi 7,500psi Production Liner 568' 3-1/2" 12,560' 10,067' 10,160psi 10,540psi Production Liner 2,815' 2-7/8" 15,375' 10,247' 10,570psi 11170 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic 10,048 to 10,054 4-1/2" 12.6#/13Cr80/NSCT 11,988 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4-1/2"S-3&7-5/8"x 5-1/2"LTP and 4-1/2"HES HXO SVLN 11,941 MD/9,774TVD&12,517MD/10,058TVD and 1,570MD/1,525TVD 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/17/2016 Commencing Operations: OIL 0 - WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Wellman -Tit' Email twellmanCac hilcoro.com Printed Name e Dunn Title Operations Manager Signature Phone 777-8382 Date 6/8/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\LQ- 32/ Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No RBDMS ISA- JUN 1 3 2016 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0 ‘.f 0 C/ APPROVED BY Approved by: /2 COMMISSIONER THE COMMISSION Date: 6—/Q w Subs in Form and Form 10-403 R4..._ alettvised 1112 5 /,bRr`} I o alid for 12 months from the date of approval. �/ Attachments in Duplicate 6-.7_ �"7�� . ,.sz G, 9.' • • Tbg Soak/Pull SSSV Well: END 1-65A PTD: 203-212 Hawn,Alaska,LL API: 50-029-22627-01 Well Name: END 1-65A API Number: 50-029-22627-01 Current Status: SI—SSSV Closed Rig: Pumping+SL Estimated Start Date: June 15, 2016 Estimated Duration: 1 Reg.Approval Req'std? YES Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 203-212 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) Max. Proposed Surface Pressure: 2080psi (GL system Pressure—highest recorded for well) Brief Well Summary: The well is a gas lifted well that lost control line integrity during a temporary shut in. The valve can be functioned open but loses hydraulic pressure. During attempts to pull the SSSV,the expander mandrel and the lock were pulled off the SSSV. Samples of scale were recovered from the lock. The SSSV remained in place. See 05/11/16-05/13/16 WSR's for full description. t,,'' Current SSSV in well: 4-1/2" BBE (S/N= NBB-02, 3 sets of Oversize pkg w/0-rings, opening/closing pressures- 1700#/800#), set on 04/09/13 Objective: Acid wash tubing of scale buildup on SSSV, pull 4-1/2" BBE SSSV @ 1570' md, set new SSSV. Procedure: Note: Timing for pumping must be coordinated with slickline availability to reduce the time the acid is left in the tubing. Pumping ✓ 1. MI RU pump truck to tubing. PT hoses and hardline to 250psi low and 4000psi high. 2. Rig up pump truck to acid trailer. . 3. Pump 5 bbls 7.5% HCL DAD acid followed by —3 bbls of diesel. Come off pumps and close SSV to leave acid spot—teTol''top of SSSV. a. Max pump rate to be lbpm and 2000psi. 4. Monitor tubing pressure. a. If tubing pressure increases, this indicates the SSSV has come out of the landing nipple. Pump an additional "25bbls of diesel down the tubing. RD pump truck and move to Slickline Steps. b. If the tubing pressure remains below SITP, pump 16bbls of diesel into tubing to fluid pack the tubing from surface to SSSV. Continue to pump down tubing up to 3000psi to try and push SSSV down. If pressure drops off come off pump. Rig down pump truck and move to Operations Steps. Operations 5. Notify plant of possible acid returns. Open well and open SSSV with hydraulic control panel and flow well to production to flush acid from tubing. Slick Line 6. MIRU SL unit and pressure test to 250psi low and 2,000psi high. Tbg Soak/ PuII SSSV • Well: END 1-65A • ti PTD: 203-212 • IliIcor„Alaska,LL API: 50-029-22627-01 7. RU releasable spear toolstring and stab into SSSV @ 1570' md. Commence fishing operations to retrieve SSSV. 8. Flow well to allow well to warm. 9. Set 4-1/2 BBE SSSV @ 1570' md. a. Brush nipple profile as needed to prep for SSSV install. 10. RD slick line. Contingency—If unable to retrieve SSSV and unable to flow spent acid from tubing 11. RU pump truck and PT hoses and hardline to 250psi low and 4000psi high. 12. Displace tubing with 250 bbls of seawater. 13. RD. Pump truck. D• -65A Ilk NOTES WELL ANGLE>70°@ 15059'.*** WELLFEAD FMC At3INGS A1II=RAIGE 230-260 PPM ON ArL R ACTUATOR= BAKER C GAS INJECTORS WELL REQUIRES A SSSV URAL KB.ELE 56' BF.ELEV= 15' I I CHROME TBG&CT LNR***INITIAL WELLBORE KOP= 300' NOT SHOWN BELOW WS*** Max Angle= 95°@ 13080' Datum M)- 12511 30"CONDUCTOR — ,90 1570' -14-1/2"FES FFSVLN,ID=3.813" Datum TVD= 10000'SS GAS LF T F MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 10-3/4"CSG,45.5#,L-80 BTC,ID=9.950" — 5212' - . f *5 4133 3587 40 KBMGM DOME BK 16 01/29/96 1'"11 *5 6237 5246 38 KBMGM SO BK 20 01/29/96 4 7548 6283 38 KBMGM DMY BK 0 01/09/96 3 8462 6998 39 KBMGM DMY BK 0 01/09/96 2 337 7687 38 KBMGM BK 0 01/09196 Minimum ID = 2.377" @ 12560' 1 9210 8379 33 KBMGM DMY BK 0 01/09196 3-1/2" X 2-7/8" XQ STA 5&5=VALVES STUCK IN POCKET(AWGRS 12/04/03) ' , 11930' —14-1/2"HES X NP,D=3.813" p 11941' —17-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" I I 11964' —14-112"HES X NP,D=3.813' ' ' 11975• —4-1/2'HES XN NIP,MILLED TO 3.80'(01/19/04) 11988' --14-1/2"WLEG,D=3.958" 4-1/2"TBG,12.6#,13CR 80 NSCT, --J 11988' .0152 bpf,ID=3.958" 11992' —13.70^BTT DEPLOYMENT MB'4 Sly,D=3.00' I I 12002' —13-1/2"HOMO X NP,D=2.813" 1 12517' —7-5/8"X1ii-1/2"BKR SBP LTP,ID=4.992" -� 12527' --17-5/8"X 5-1/2'BKR HMC LNR HGR,ID=4.75" 12535' --I5-1/2"X4-1/2"LNR>I3,ID=3.958" 3-1/2"LNR,8.81#,13CR-80 STL, — 12560' 12560' 3-1/2"K2-7W XO,ID=2.377" .0087 bpf,ID=2.992" 7-5/8"CSG,29.7#,USS95 BTC-M,ID=6.875" — 12721' , 4-1/2"MLLOUT WINDOW(01-65A) 12990'-12999' 4-1/2"WHPSTOCK(03/15/04) —f 12990' 4-1/2" LNR, 12.6#,L-80 NSCT, —F:12990 0152 bpf,ID=3.958" PERFORATION SUNS RY REF LOG: MGA ON 04/15/04 ANGLE AT TOP PERF: 72°@ 12485' I'bte:Refer to Rod uction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ A" 2-1/2" 6 12485-12505 0 04/25/04 Nikaa� vv 1PBTD — 15341' • 2-7/8"LNR,6.5#,13CR-80 STL,.0058 bpf,D=2.441" H 15375' DATE REV BY COMMENTS DATE REV BY COMMENTS Ef 1 T I"IT 01/26/96 D15 INTIAL COMPLETION 02/19/13 RKT/JMD SET PX PLUG(02/14/13) WELL: 1-65A I N-27 04/18/04 NORDIC2 CTD SIDETRACK(EN)1-65A) 04/23/13 CDJ/JMD FULLED PX PLUG(04/09/13) PERMIT No: 2032120 04/04/11 ?/JMD REFORMATTING API No: 50-029-22627-01 08/12/11 OW/JIM ADDED H2S SAFETY NOTE SEC 36,T12N,1116E,2222'FNL&2218'FEL 06/20/12 AS/JIVD FERE CORRECTION BP Exploration(Alaska) • • RECEIVE !, Post Office Box 244027 JUL /� ryq Anchorage,AK 99524-4027 Hilcorp Alaska,LLC U 3 V 201 J 3800 Centerpoint Drive Suite 100 A ®�� Anchorage,AK 99503 �,1` Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 Commissioner Cathy Foerster 03_ cl !� Alaska Oil & Gas Conservation Commission a �c 333 West 7th Avenue, Suite 100 / & 571 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request SCANNED AUG 3 1201E 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 "/" 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, 77 Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig • New API_WeliNo PermitNumber WellName WellNumber WellNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/119 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/117 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 50029217220100 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/Q21 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 2-06/122 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 2-20/115 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J.. Q :3 - ~ j ;)... Well History File Identifier Organizing (done) o Two-sided ""1111111111 lUll o Rescan Needed II 1111111111 "" III RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No. I o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date (P 9: / () ~ 151 VI{ P III II 111111 III "III Project Proofing BY: ~ Date (p, '~ /0 b à x30= ~t1 Date (PI í? /0 b 151 YnP Scanning Preparation BY: C Maria J + a <6 = TOTAL PAGES ß <6 (Count does not include cover sheet) II\A P 151 , r t Production Scanning 11I1111111111111111 Stage 1 Page Count from Scanned File: «q (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: cM;ia) Date: to I f6 / 0 fp 151 NO MP Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: 151 11111111I1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 I1III BY: Maria Date: 151 Comments about this file: Quality Checked III 1111111111111111 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ti, e May 22, 2012 Mr. Jim Regg DP 3_ g'I I NI Alaska Oil and Gas Conservation Commission F `� 333 West 7 Avenue 1 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 altemate, Gerald Murphy, at 659 -5102. Sincerely, -12 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 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 / 0 -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 �jEND1 -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 • • ~.,Q-~-" ,,... MICROFILMED 03/01!2008 DO NOT PLACE ., w k _.. ANY NEW MATERIAL UNDER THIS PAGE F:~I.,aserFiche\CvrPgs_InsertsiMicrofilm_Marker.doc ¡x ,> f'Ik-, ?vk ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2032120 Well NamelNo. DUCK IS UNIT MPI1-65A1N27 Operator BP EXPLORATION (ALASKA) INC Sp~ J ì~ ~ c...¡ API No. 50-029-22627-01-00 MD 15379 /' TVD 10249 ./ Completion Date 4/25/2004 / Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD PRESSTEQ1, DIR I Multi / PROP I RES I GR, MEM I CCL I CN Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr Data Digital Dataset Log Log Run Interval OHI Y"Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 13110 15379 6/1/2004 Rpt Directional Survey 0 0 6/1/2004 PB1 included ~C TIF 12808 Induction/Resistivity 12990 15379 Open 1 0/29/2004 MWD/MPRlGRlDIR uZ 12808 Induction/Resistivity 25 Blu 12990 15379 Open 10/29/2004 MWD/MPRlGRI og 12808 InductionlResistivity 25 Blu 12990 15379 Open 1 0/29/2004 MWD/MPR/GRI Z 12808 Gamma Ray 25 Blu 12990 15379 Open 1 0/29/2004 MWD/MPRlGRI , pt 12808 LIS Verification 12990 15379 Open 10/29/2004 MWD/MPRlGRI ~..--e TIF 12934 Gamma Ray 12990 14597 1/15/2005 MWD-MPRlGRIDIR \Log 12934 Gamma Ray 25 Blu 12990 14597 1/15/2005 MWD-MPRlGRlDIR cJOg 12934 Induction/Resistivity 25 Blu 12990 14597 1/15/2005 MWD-MPR/GRlDIR t 12934 Induction/Resistivity 25 Blu 12990 14597 1/15/2005 MWD-MPRlGR/DIR pt 12934 LIS Verification 25 12990 14597 1/15/2005 MWD-MPRlGRlDIR Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . . ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~N & Chips Received? ~ ~. Y/N Formation Tops Analysis Received? Permit to Drill 2032120 MD 15379 TVD 10249 Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Well Name/No. DUCK IS UNIT MPI1-65A1N27 Operator BP EXPLORATION (ALASKA) INC Completion Date 4/25/2004 Completion Status 1-01L Current Status 1-01L i-o Date: API No. 50-029-22627-01-00 UIC N }.] N¡ ~ ~ . . . . Transmittal Form INTEQ ~ð3 - 2/z r'¡_ BAKER HUGHES .·'_+nhn_n...o'.. .. l_~ ..:~':;:;;;::____, ,.... , ¡ _... - 5.1. on _of ~ ::¡.: = . ... i :"'_..'.~,;;, I _... - ....., _.1 ';"'---".'-- ;;;;-;n;"i Anchorage GEOScience Center "'''''n~... ............ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 1-65AIPB1 ¡Contains the following: }.. q ') I...l Jl LDWG Compact Disc %' , (Includes Graphic Image files) j 1 LDWG lister summary )1 bluelines - GR/Directional Measured Depth Log .j 1 bluelines - MPR Measured Depth Log \/1 bluelines - MPR TVD Log LAC Job#: 649753 Sent BY~/;;' ItL Receive~ /!/ /ilt-t I fJM1ccU-- L---/ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Date: JanZ4, ~, 00$ /1.- Date: / J /{J.J ./ / Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 -"" -" ... ~_.~! -- ,- . _w.._ _~ ......~_¡ - ...' ~t·~.~ ~'~~I n._..____......__.____________..__...._._ ~!~,... r,:::',"::::", . . cXJt7 3 -ou;<. Transmittal Form r'¡_ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 1-65A/N-27 Contains the following: \ )vt \Jß t 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 bluelines - GR/Directional Measured Depth Log 1 blue lines - MPR Measured Depth Log 1 bluelines - MPR TVD Log LAC Job#: 649753 Sent By: Glen H el , I Î Date: Oct 22, 2004 Received y: 0/ j{J.{'UHrdA.-- Date: /1 ~¥' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 : 1'0()<"'" r-'~----~-----~ ---~--~-~ I:'I!>WI~" -"" -. ... "".-::.: '_'W__M____.~___.___ _______.,._._._.__._.."'.,_ .. . -- :::=:~ e STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION [';s WELL COMPLETION OR RECOMPLETION REPORT AND LOÓ"" J N O~, 7JJ04 (Of ~¡, }) &T Iv ~ IOl!-þ::/C? ~{:l.J 1:h¡¡~~)¡¡;Iå.sS:l "''.",,,,;'" "Ii" Developrt\~lJt,m¡¡;;¡!!J Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-212 304-100 13. API Number 50- 029-22627-01-00 14. Well Name and Number: ~7{b 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25,105 20AAC 25,110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a, Location of Well (Governmental Section): Surface: 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E, UM Top of Productive Horizon: 730' NSL, 3725' EWL, SEC. 31, T12N, R17E, UM Total Depth: 375' SNL, 1784' EWL, SEC. 05, T11 N, R17E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 258980 y- 5982195 Zone- ASP3 TPI: x- 264846 y- 5979679 Zone- ASP3 Total Depth: x- 267753 y- 5978484 Zone- ASP3 18. Directional Survey 181 Yes 0 No No. of Completions 21. Logs Run: MWD PRESSTEQ1, One Other 5. Date Comp., Susp., or Aband. 4/25/2004 6. Date Spudded 3/17/2004 7. Date TD. Reached 4/13/2004 8. KB Elevation (ft): KBE = 56 9. Plug Back Depth (MD+ TVD) 15343 + 10235 10. Total Depth (MD+TVD) 15379 + 10249 11. Depth where SSSV set (Nipple) 1570' MD 19. Water depth, if offshore 6' -12' MSL CASING SIZE 30" 10-3/4" 7-5/8" 4-1/2" 3-1/2" x 2-7/8" DIR I Multi I PROP I RES I GR, MEM I CCL / CNL I GR CASING, LINER AND CEMENTING RECORD SE;TTING DE;P1'fIMD SETT'ING DE;PTH 1VD Top BonOM Top BortoM Surface 60' Surface 60' 43' 5212' 43' 4437' 41' 12721' 41' 10084' 12517' 12990' 10058' 10087' 11992' 15375' 9803' 10247' 22. GRADE Drive L-80 USS-95 L-80 13Cr80 Structural 45.5# 29.7# 12.6# 9.3# I 6.5# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 6spf MD TVD MD TVD 12485' - 12505' 10048' -10054' 26. Date First Production: April 26, 2004 Date of Test Hours Tested PRODUCTION FOR 5/17/2004 4 TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED ........ Press. 700 1,900 24-HoUR RATE""" OIL-BsL 238 27. NIA 13-1/2" 9-718" 6-3/4" 3-3/4" 24. SIZE 4-1/2", 12.6#, 13Cr80 END 1-65A1N-27 15. Field I Pool(s): Endicott Field I Endicott Pool Ft Ft 16. Property Designation: ADL 047502 17. Land Use Permit: 20. Thickness of Permafrost 1465' (Approx.) AMOUNT PULLED Driven 845 sx PF 'E', 625 sx Class 'G' 630 sx Class 'G' 180 sx Class 'G' 145 sx Class 'G' RECORD DEPTH SET (MD) 11987' PACKER SET (MD) 11941' A¢IO, FAACTlJRE, CeMENT DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 34 Bbls of MeOH GAs-McF 1,197 GAs-McF 7,181 WATER-BsL 1,284 W A TER-BsL 7,705 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-BsL 40 CHOKE SIZE I GAS-OIL RATIO 104" 30,134 OIL GRAVITY-API (CORR) CORE DATA Brief ~escriptio~ of ~ithology, por~~ity, f~actures, apparent dips and presence of oil, gas 0, r water (atta~h, separate sheet, ~f ~ec:ssary). ,I Submit core chips; If none, state none. Noh.: "2~ $..w,f..u~,c..(,~.'ð 7J1't!:,-giÀ) Š-18.<..,.3L5 ~ None Form 10-407 Revised 12/2003 OR!G'~JAL CONTINUED ON REVERSE SIDE IfII.ISBFL. jU~ 1 0 n\1l~ G F e '3 G ç t-Ll '" ) . STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: r8I Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC25,105 20AAC25.110 One Other 5. Date Comp., Susp., or Aband. 4/25/2004 6. Date Spudded 3/1712004 21. Logs Run: MWD PRESSTEQ1, DIR I Multi I PROP I RES / GR, MEM I CCL I CNL I GR CASING, LINER AND CEMENTING RECORD SETTING DEPTI1MD SE'lYING DEPTH TVD lOP BO:rrOM top BOTTOM Surface 60' Surface 60' 43' 5212' 43' 4437' 41' 12721' 41' 10084' 12517' 12990' 10058' 10087' 11992' 15375' 9803' 10247' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-BBl 40 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Nbh¡, 1, '1 S..,.rs.-.~~ (..,.....o:\¡ I' 7 ..,-1 '-i )-8<2 I) ~ If l) '!. S"', 1 ~ 7;#~~ OR\G\NAL ~,', BF;. ¡ -~~¡ ~ Form 10-407 Revised 12/2003 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E, UM Top of Productive Horizon: 730' NSL, 3725' EWL, SEC. 31, T12N, R17E, UM Total Depth: 1186' SNL, 1678' EWL, SEC. 05, T11N, R17E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 258980 y- 5982195 Zone- ASP3 TPI: x- 264846 y- 5979679 Zone- ASP3 Total Depth: x- 267625 y- 5977676 Zone- ASP3 18. Directional Survey r8I Yes 0 No No. of Completions 22. CASING SIZE 30" 10-3/4" 7-5/8" 4-1/2" 3-1/2" x 2-7/8" WT. Structural 45.5# 29.7# 12.6# 9.3# I 6.5# GRADE Drive L-80 USS-95 L-80 13Cr80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 6spf MD TVD MD TVD 12485' - 12505' 10048' - 10054' 26. Date First Production: April 26, 2004 Date of Test Hours Tested 5/17/2004 4 Flow Tubing Casing Pressure Press, 700 1,900 PRODUCTION FOR TEST PERIOD .. CAlCULATEO -II.. 24-HoUR RATE""'" Oll-BBl 238 27. 7. Date T.D. Reached 4/13/2004 8. KB Elevation (ft): KBE = 56 RECEIVED MA Y2 0 2004 1 b~f~R Bi¿i:Gas Commission r8I Developm6ntharagÞ.J Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-212 304-100 13. API Number 50- 029-22627-01-00 14. Well Name and Number: END 1-65A1N-27 15. Field I Pool(s): Endicott Field I Endicott Pool 9. Plug Back Depth (MD+ TVD) 15343 + 10074 Ft 10. Total Depth (MD+TVD) ;0),'18 1+0 16. 15379 + ~ Ft 11. Depth where SSSV set (Nipple) 1570' MD 19. Water depth, if offshore 6' - 12' MSL Property Designation: ADL 047502 17. Land Use Permit: 20. Thickness of Permafrost 1465' (Approx.) N/A 13-1/2" 9-718" 6-3/4" 3-3/4" Driven 845 sx PF 'E', 625 sx Class 'G' 630 sx Class 'G' 180 sx Class 'G' 145 sx Class 'G' TUBING RECORD SIZE DEPTH SET (MD) 4-1/2",12.6#, 13Cr80 11987' PACKER SET (MD) 11941' AGID,F~CTURE,ÇEMENT SqQ$$IË, ErG. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 34 Bbls of MeOH GAs-McF 1,197 GAs-McF 7,181 CHOKE SIZE I GAS-Oil RATIO 104" 30,134 Oil GRAVITY-API (CORR) W A TER-BBl 1,284 WATER-BBl 7,705 ,1\"," 0 8 ?nn' CONTINUED ON REVERSE SIDE G~-l~ (OF ~ì:.( o ~ 28. e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". From Original Wellbore (1-65/N-25) None Kekiktuk 11855' 9726' K3A 11905' 9754' K2B 12179' 9913' Kekiktuk 12520' 10058' RECE/\IEn ~",,~~ "U MA Y2 0 2004 K3A 12593' 10073' K2B 12830' 10086' Alaska 1'.) ði From Sidetrack (1-65A1N-27) K2M 15000' 10110' K2A 15150' 10162' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well bore Schematic Diagram, Surveys 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie HUbble~~ ~~ END 1-65A1N-27 Well Number Title Technical Assistant Date ()5·~..OLf 203-212 304-100 Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Mark Johnson, 564-5666 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 e e BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 1 of 23 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 11112000 3/13/2004 18:30 - 18:00 - 20:15 0.00 MOB P 2.25 MOB P PRE PRE 20: 15 - 00:00 3.75 MOB P PRE 3114/2004 00:00 - 05:00 5.00 BOPSUF P PRE 05:00 - 12:00 7.00 BOPSUF P PRE 12:00 - 13:30 1.50 BOPSUF P PRE 13:30 - 15:00 1.50 BOPSUF P PRE 15:00 - 15:15 0.25 CLEAN P WEXIT 15:15 - 15:30 0.25 CLEAN P WEXIT 15:30 - 16:00 0.50 CLEAN P WEXIT 16:00 - 18:40 2.67 CLEAN P WEXIT 18:40 - 18:50 0.17 CLEAN P WEXIT 18:50 - 19:15 0.42 CLEAN P WEXIT 19:15 - 21:45 2.50 CLEAN P WEXIT 21 :45 - 22:00 0.25 CLEAN P WEXIT 22:00 - 00:00 2.00 RIGU P WEXIT 3115/2004 00:00 - 02:30 2.50 RIGU P WEXIT 02:30 - 04:15 1.75 RIGU P WEXIT 04:15 - 06:30 2.25 RIGU P WEXIT 06:30 - 07:30 1.00 RIGU P WEXIT 07:30 - 07:50 0.33 RIGU P WEXIT 07:50 - 09:30 1.67 RIGU P WEXIT 09:30 - 10:55 1.42 STWHIP P WEXIT 10:55 - 13:50 2.92 STWHIP P WEXIT 113:50 - 15:30 1.67 STWHIP P WEXIT Description of Operations Move from END 2-36 to END 1-65A Rig released from 3-17F at 1800 hrs Move rig off well and move to entrance of SOl PU matting boards and cellar liner Safety mtg re: next steps 1/2 of crew road to MPI and set matting boards and cellar liner on 1-65 while rig fin preps to move Safety mtg re: move to MPI Leave SDI at 2030 hrs and arrive MPI at 2230 hrs Back up and position rig on matting boards Safety mtg re: move over well Move rig over well and set down Accept rig at 0000 hrs 3/14/2004 Remove tree cap. NU BOPE Install sensors on lA, OA. Found IA ODS valve wouldn't seal (this was prior GLG side). Other side was double valved. Grease it, then add heat to warm up to get a seal Initial BOPE test. Witness waived by AOGCC WO DSM to pull TWC MIRU DSM. Pull TWC. RD DSM SIWHP 330, IA 470 Safety mtg re: kill well MU 3.80· 0331, motor, MHA for drift runlkill ops Attempt to bleed down pressure and declined to 80 psi. Monitor. Increased back to 300 psi and rising RIH wI BHA #1 wlo pump holding 300 psi BP and taking MeOH, crude and KCI retums to flowback tank. Tag CIBP at 13077' CTD (counter error after CCAT shutdown) SafetylTL mtg (crews late due to BOC evacuation drill) Nordic working wI one man short Start 9.5# used mud. Incr rate to 2.8/2300 holding 300 psi BP and fin CÎrc 9.5# brine out of CT POOH displacing wellbore to 9.5# mud Check returns after hole displaced and well bore stable. Fin POOH and displ CT to FW near surface LD drift assy while displ CT to MeOH Fin displ CT to MeOH. Cut off CTC. Install internal grapple and PT Safety mtg re: pull CT to reel Pull CT to reel and secure Safety mtg re: reel swap (2) Fin secure and load out e-free 2-318· Load in 2-3/8· E-CT Safety mtg: pull CT and stab Install grapple connector. Pull CT to floor and stab. Check fluid level and stable at surface. SI swab Fill CT w/12 bbls MeOH, 15 FW followed by mud at 1.3 bpm. PJSM. Stab onto well and pump slack back. Cut 60' coil. Pull test 35K. Rehead coil. Circulate to warm coil. PT coil and MU Whipstock BHA. RIH with whipstock to 12490, Tie - in log, Correction -16'. Intermittent data from MWD Bi Printed: 4/1912004 12:10:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Pagø2 of 23 BP EXPLORATION Operations Summary Report 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: Hours Task 3/15/2004 13:50 - 15:30 1.67 STWHIP P WEXIT 15:30 - 17:05 1.58 STWHIP N DFAL WEXIT 17:05 - 20:00 2.92 STWHIP N DFAL WEXIT 20:00 - 20:45 0.75 STWHIP N DFAL WEXIT 20:45 - 23: 15 2.50 STWHIP N DFAL WEXIT 23:15 - 00:00 0.75 STWHIP N DFAL WEXIT 3/16/2004 00:00 - 02:30 2.50 STWHIP N DFAL WEXIT 02:30 - 03:30 1.00 STWHIP N DFAL WEXIT 03:30 - 06:00 2.50 STWHIP N DFAL WEXIT 06:00 - 06:45 0.75 STWHIP N DFAL WEXIT 06:45 - 07:11 0.43 STWHIP N DFAL WEXIT 07:11 - 09:15 2.07 STWHIP P WEXIT 09:15 - 10:20 1.08 STWHIP P WEXIT 10:20 - 13:00 2.67 STWHIP P WEXIT 13:00 - 17:00 4.00 STWHIP P WEXIT 17:00 - 17:35 0.58 STWHIP P WEXIT 17:35 - 19:05 1.50 STWHIP P WEXIT 19:05 - 21 :50 2.75 STWHIP P WEXIT 21 :50 - 22:08 0.30 STWHIP P WEXIT 22:08 - 22:30 0.37 STWHIP P WEXIT 22:30 - 00:00 1.50 DRILL P PROD1 3/17/2004 00:00-01:10 1.17 DRILL P PROD1 01:10-01:35 0.42 DRILL P PROD1 01 :35 - 03:50 2.25 DRILL P PROD1 03:50 - 04:05 0.25 DRILL P PROD1 04:05 - 04:45 0.67 DRILL P PROD1 04:45 - 04:50 0,08 DRILL P PROD1 04:50 - 05:20 0.50 DRILL P PROD1 05:20 - 06:00 0.67 DRILL P PROD1 06:00 - 08:30 2.50 DRILL P PROD1 Directional Communiction Module. Tool cycling between operational to non operational. RIH tag 13020, PU to place top of WS at 12990'. Communication problem continue. Attempt to recover communication to orient. POH MWD failure, Tool restarted and worked for a while. Head back in hole, but quit again. Resume POOH Check WS, okay. Change power and comms sub on BHI BHA RIH wI BHA #3. Tool worked okay to 8000' then intermittent. RIH to 12500' and prepare to tie-in and tool comms not functioning (this also means BHA cannot be disconnected) POOH for MWD failure Stop at 8000' and continuity test at reel (1 hr) wI jumper. Tools powered up, but quit. Resume POOH Check WS, okay. Change power and comms sub for one with baud rate to short reel version and surface test, okay RIH wI BHA #4. Check tool every 2000' 12500' Begin tie-in. Correction -15'. Relog to confirm. OK. RIH. Tag at 13,021. UP WT 55k. On Wt 23K. PU place Top of WS at 12990'. Orient 92.1 R. Close EDC. Pressure to 4000 psi & hold. PU 45K & pressure to 4480 psi to shear. Set down 3K. to confirm set. O.K. POH. LD WS setting assy. MU milling assy RIH wI BHA #5 Start milling window f/12990' 2.65bpm 3650psi free-spin maintaining +1- 100 psi motor work 1-2k wob. Bottom of window appears to be 12999'. 'Fast window?' Drill formation f/12999' to 13009' Reaming window, Reamed 3 times, 3.78" string mill and dry tagged, clean. Pumped 20 bbl HVis sweep POOH with sweep gone. ( Painted Flag at 12800 ft ) PUH inspecting CT as per SLB SOPs dealing with Cr tubing Area is at 2.2' ovality LD window exit BHA in preparation of cutting of CT Window mill at 3.79 in, String 3.78in Cut 40 ft CT and rehead as per BHI SOP's. Pull Tested to 35k Ib Finish Re-head CTC, PT CTC to 3500 psi PU BHI BHA wI 1.5 AKO. Off set at 55.7 deg, tested tool at surface RIH. Seen the milled out 'XN' nipple at 11975 ft (+6ft) while RIH Tie-in from 12480 ft to 12521 ft (-18 ft correction) RIH, no tag at 13015.3 ft Vp = 414 bbl, Btm up = 142 bbl PUH to confirm Tie-in before preceeding deeper to 12470 ft Tie-in (+3 ft correction) RIH, motor work at 13017' PU, clean, RIH to 13021ft Drilling at 60 to 70 fph. PU 13025' TF at 90 R, Qp = 2.5/2,58 bpm, ROP at 40 fph Continue drilling ahead, Picked up RA's at 13002' 2.6 bpm ann= 5659psi 10.88 ecd 3550 free-spin 3-40Opsi mw 2-3k wob 70'/hr Drill to 13170' Printed: 4/1912004 12:10:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 311712004 08:30 - 09:45 1.25 DRILL P PROD1 Wiper trip to 11790'. Pumped hillow vis sweep while in the 7-5/8" csg. 09:45 - 12:00 2.25 DRILL P PROD1 Directionally drill ahead f/13170' 2.60bpm 3700psi fs 2-300psi mw. Ann/5594 bore/6144 10.75ecd 1-2k wob 70'/hr. Drill to 13320' 12:00 - 13:15 1.25 DRILL P PROD1 Wiper trip to 11788' pumping hillow vis sweep. Hole looks good. 13:15 - 17:15 4.00 DRILL P PROD1 Directionally drill ahead f/13320' 2.6/2.6 70'/hr to 13330' harder drilling since at 30'-40'/hr. Good solids returns over shaker, seeing small amount of thin coals <1/8" in size, Drilled to 13470'. Coals" Ordered Mud Swap at 0200 hrs 17:15 - 18:50 1,58 DRILL P PROD1 Wiper trip to 11700', pumped 10/10 H/L vis sweep in 7/5/8" casing Clean wiper trip 18:50 - 20:10 1.33 DRILL P PROD1 Drilling, TF @ 90L, ECD = 10.86, P = 5652/6200psi 20:10 - 20:20 0.17 DRILL P PROD1 Orient TF to 90, 20:20 - 21 :25 1.08 DRILL P PROD1 Drilling, TF @ 70 to 90 R, Qp = 2.56/2.56 bpm. Pp (btm)=5677/6234psi ECD = 10.89, Vp = 414bbl. 21 :25 - 21 :30 0.08 DRILL P PROD1 Orient TF, Having trouble orienting with bit on bottom, having to PU to orient TF 21 :30 - 22:27 0.95 DRILL P PROD1 Drilling, TF @ 90 L, Qp = 2.56/2.56 bpm. Pp (btm)=5595/6284psi ECD = 10.86. Vp = 414bbl. "Parted Coiled Tubing Drill" 22:27 - 00:00 1,55 DRILL P PROD1 Wiper trip after 150 ft drilled, PU wt = 49k. Pumped 10/10 H/L Vis pill Depth at 11800 ft 3/18/2004 00:00 - 00:30 0.50 DRILL P PROD1 Wiper trip 00:30 - 00:45 0.25 DRILL P PROD1 Tie-In at 13462' (+ 7 ft) 00:45 - 01 :00 0.25 DRILL P PROD1 RIH to WS at 12990 ft 01 :00 - 01 :17 0.28 DRILL P PROD1 Tie-in to RA Marker" Spill Drill before mud swap. RA Marker at 13002 ft TOW at 12993 ft BOW at 13002 ft 01:17 - 01:48 0.52 DRILL P PROD1 RIH 01:48 - 03:12 1.40 DRILL P PROD1 Drilling, TF 90L; Qp = 2.58/2.59bpm, Pp 5635/6379 psi, Vp = 410 bbl; WOB 2500#, ROP 70 fph, ECD = 10.81ppg 03:12 - 03:25 0.22 DRILL P PROD1 Drilling, TF 100-90L; Qp = 2.58/2.59bpm, Pp 5635/6379 psi, Vp = 410 bbl; WOB 2500#, ROP 70 fph, ECD = 10.81 ppg Started Mud swap at 0315 hrs. 03:25 - 03:40 0.25 DRILL P PROD1 Orient TF around 180 to 90R 03:40 - 04:00 0.33 DRILL P PROD1 Drilling, TF 80-90R; Qp = 2.5212.50bpm, Pp 5640 I 6057 psi; WOB 2.5k to 10k, ROP 70 to 80 fph, ECD = 10,90ppg Some bit stacking 04:00 - 04:45 0.75 DRILL P PROD1 Wiper trip during Mud swap. Started new mud down CT at 0415 hrs 04:45 - 06:00 1.25 DRILL P PROD1 Drilling, TF 80-90R; Qp = 2.5212.50bpm, Pp 5640 16057 psi: WOB 2.5k to 10k, ROP 70 to 80 fph, ECD = 10.90ppg. 06:00 - 10:45 4.75 DRILL P PROD1 Continue drilling ahead. Appear to be drilling at a fault line line starting at 13722'. Working through it stacking weight plowing ahead. 2.6/2.69.5/9.5 3800fs 2-300mw ecd 10.71 An 5561 Br6098 Small lithology change from sand to shale then back to sand between 13708'-13718'. ROP very erradic. Weight transfer a problem even with new mud. Samples are sand with some clays, At 13780' 2,6/2.6bpm 3550 free-spin 2-400psi mw Printed: 4/19/2004 12: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 311812004 06:00 - 10:45 4.75 DRILL P PROD1 Pumped a 10/10 lowlhi vis sweep while on bottom help while passing BHA. Continmue drilling with stacking every few feet. Drilled to 13818'. 10:45 - 13:35 2.83 DRILL P PROD1 TOH. Pumped low/hi vis sweep through 7 5/8" annulus. Checked last 150' coil for ovality. Okay but may need to cut next TOH 13:35 - 15:00 1.42 DRILL P PROD1 Change motor setting to 1.2* swap out lower quick connect (SOP every 2nd run) and orienter. P/U 3.75" DSX-49 bit. Surface test tools. Bit #1 missing 1 compact on nose gauge, 1 midway on body gauge. Heat checking on upper gauge compacts, Overall 50% of cutters were dull. 15:00 - 17:25 2.42 DRILL P PROD1 RIH "Fire Drill in the Generater Room" 17:25 - 17:50 0.42 DRILL P PROD1 Tie-in at RA marker. (-16ft correction) 17:50 - 18:15 0.42 DRILL P PROD1 RIH 18:15 - 20:10 1.92 DRILL P PROD1 Drilling at 100R TF Vp = 288 bbl, P= 5578/6286 psi, Qp = 2.57bpm Some stacking in 2nd shales 20: 10 - 20:25 0.25 DRILL P PROD1 Short Trip 100 ft 20:25 - 20:38 0.22 DRILL P PROD1 Drilling at 100R TF Vp = 282 bbl, P= 5638/6204 psi, Qp = 2,57bpm Stacking in 2nd shales and up hole. WOB @ 1.6k to 2,1k. 20:38 - 23:35 2.95 DRILL P PROD1 Wiper trip to tubing tail to cleanup upper hole section. Pit Volume totalizer not working, having driller strap pits on trips and drilling operations. Monitoring MM inlout for proper hole filling, Wiper trip from 13942 ft to 11730 ft (200 ft above TT) Pumped 10/10 bbl H/L Vis sweep while in the 7-5/8" casing Large amount of solids came up with HL vis sweep. Pumped another 10110 HL sweep while still in 7-5/8" casing. 23:35 - 23:51 0.27 DRILL P PROD1 Tagged at 13837 ft (Shale stringer) Orient TF to 90R, Worked through 23:51 - 00:00 0.15 DRILL P PROD1 RIH 3/19/2004 00:00 - 01 :30 1.50 DRILL P PROD1 Drilling TF@90L P=5636/6392psi, Qp = 2.57/2.55bpm, ECD 10.89ppg. Drilling through 2 nd shale section before S3A 1 shale section at 9954' TVD 01 :30 - 02:25 0.92 DRILL P PROD1 Drilling TF@90L P=5636 I 6392psi, Qp = 2.57/2.55bpm, ECD 10.81 ppg. Still stacking, shale. Coming up to the base of the S3A 1 shale 02:25 - 04:35 2.17 DRILL P PROD1 Wiper trip to 200' above TT at 11770 ft, Pumped 10/10 bbl HL Vis and circulated to surface. Qp = 3.00 bpm Pp = 4153 psi 04:35 - 04:45 0.17 DRILL P PROD1 Tie-in (going down) to RA Marker at 13002' (+ 5ft correction) 04:45 - 05:30 0,75 DRILL P PROD1 RIH. Seen tight spots at 13880' and 13820' while RIH 05:30 - 06:00 0.50 DRILL P PROD1 Drilling TF@90L P=5636 I 6392psi, Qp = 2.57/2.55bpm, ECD 10.81ppg. Still stacking while inverted at 96 degs No fluid lost in last 24 hrs. Lost communication with BHA, Tool shorted. 06:00 - 09:15 3.25 DRILL N DFAL PROD1 TOH Pulled heavy off bottom. Tight at 13950, 920, 880, 820' 09:15 - 10:10 0.92 DRILL N DFAL PROD1 Inspect last 150 coil for ovality. Looks and mic's same as last trip. Will not cut. Surface test BHi equipment. MEG tested disconnected e-line cable from flosub - good, Retest connected to flosub (within upper disconnect) - failed test. Install new probe, retest - good, P/U inspect bit and BHA looks good. Stab on to BHA and test - failed. 10:10 -11:30 1.33 DRILL N DFAL PROD1 UD BHA Orienter was bad, Chg out. Retest all tools okay. Stab Printed: 4/19/2004 12:10:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 311912004 10:10 - 11 :30 1.33 DRILL N DFAL PROD1 on injector. 11 :30 - 13:50 2,33 DRILL N DFAL PROD1 RIH w/ BHA #8 (64,92') 13:50 - 14:05 0.25 DRILL N DFAL PROD1 Starting at 13030' bit depth log RA tag at 13002' -17' correction. 14:05 - 14:35 0.50 DRILL N DFAL PROD1 RIH with TF's as drilled. Motorwork and taking weight at 13845' RIH at 14'/min to 13920' and stopped. Another shale at 13940' 14:35 - 17:00 2.42 DRILL N DPRB PROD1 Wash/ream back up and very tight. Working back above 13820' trying not to breakdown formation. Cleared up past 13820'. Pump lowlhi vis sweeps to clean-up solids in annulus. Pulling up into 41/2" and 7 5/8". Ordered out 10,Oppg (9.8ppg NaCI weighted to 1 O.Oppg with NaBr) System basicly made already at Deadhorse in anticipation of us needing it. 17:00 - 22:55 5,92 DRILL N DPRB PROD1 Circulate at min rate and wait on mud, 22:55 - 23:00 0.08 DRILL N DPRB PROD1 PJSM on Mud swap. Veco Dispatch unable to supply the required Vac trucks when called upon 23:00 - 23:57 0.95 DRILL N DPRB PROD1 Sucking mud out of pits, Pump 63 bbl10ppg mud down CT. 23:57 - 00:00 0.05 DRILL N DPRB PROD1 RIH and Tie-In at GR 12462 ft 3/20/2004 00:00 - 00:15 0.25 DRILL N DPRB PROD1 Tie-in (+2 ft) 00:15 - 02:16 2.02 DRILL N DPRB PROD1 RIH pumping 10ppg mud to 13210 ft PUH to try and get orienter to work, getting amp, but not turning. RIH at 10 to 15 fph, Qp 2.53bpm ECD 11.18ppg to 13375 ft and PUH to 13300 ft, RIH, Den = 9.9/9.9 ppg, Working way back inthe hole, orienter still not working. Motor work at 13548' TF change. Stopped Den = 10.0/9.95 ppg BHP increased from 4920 psi to 5218 psi 02:16 - 02:50 0.57 DRILL N DPRB PROD1 PUH to casing, and tried to get orienter to function 02:50 - 03:16 0.43 DRILL N DPRB PROD1 Working to function orienter. 03: 16 - 06:00 2,73 DRILL N DPRB PROD1 POOH to change out orienter, inspect IAT 150' of CT. Notified AOGCC on weekley BOP test Jeff Jones/AOGCC 06:00 - 06:15 0.25 DRILL P PROD1 Crew change and PJSM. 06:15 - 06:35 0.33 DRILL N DFAL PROD1 Continue inspection of last 150' of coil for wear. Need to cut. Regroup review plan forward. 06:35 - 07:05 0.50 DRILL N DFAL PROD1 UD BHA #8 remove checks in Flosub. 07:05 - 08:50 1.75 DRILL N DFAL PROD1 Reverse with 9.5ppg brine to clear coil of 10.0ppg mud. Blow back with air. Cut 200' of coil. 08:50 - 11 :00 2.17 DRILL N DFAL PROD1 Rehead CTC pull test and PT. Chnage out injector packing. Same time pressure test choke manifold 250psi/4000psi. 11 :00 - 13:00 2.00 BOPSUPP PROD1 Continue with weekly pressure test on BOPE. Stack 250psi low 4000psi high. Test accumulator function. 13:00 - 13:30 0.50 DRILL N DFAL PROD1 P/U BHA #9 (64.92') suface test - okay 13:30 - 16:00 2.50 DRILL N DFAL PROD1 RIH to 13025'. 16:00 - 16:20 0.33 DRILL N DFAL PROD1 Log tie-in at RA tags -17' correction 16:20 - 17:05 0.75 DRILL N DFAL PROD1 RIH 1.5bpm 2300psi At 13830 TF 90R 1.56bpm 2300 psi 17:05 - 17:45 0,67 DRILL N DPRB PROD1 Wash and back ream from 13830'-40' clean to 13838' work down to 13880 then ream back up to 13800'. Wash down to 14116'. P/U backream at 2.3bpm to 14116 ft 17:45 - 18:57 1.20 DRILL N DPRB PROD1 PUH and pulled 10k over at base of shale 13883 ft. pulled through OK, Pulled 8k over at 13922 ft to 13810 ft. No motor work, just bit and bend. PUH and clean above 13810' to 13500 ft. 18:57 - 19:22 0.42 DRILL N DPRB PROD1 RIH at 1,61 bprn, took some wt at 13823 ft, PUH 19:22 - 19:55 0,55 DRILL N DPRB PROD1 Working down in area 13823 ft to 13838 ft. Having trouble getting past 13838 ft using 0.75 bpm wI correct TF. Some Printed: 4/19/2004 12: 1 0:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 312012004 19:22 - 19:55 0.55 DRILL N DPRB PROD1 shale coming over shaker 19:55 - 00:00 4.08 DRILL N DPRB PROD1 POOH, pumped 10/10 sweep in 7-5/8". POOH to PU Bicenter bit 3/21/2004 00:00 - 00:35 0.58 DRILL N DPRB PROD1 Finish POOH, Inspect bottom 250 ft CT 00:35 - 01 :10 0.58 DRILL N DPRB PROD1 Changed out bit, Stab injector head 01:1 0 - 03:30 2.33 DRILL N DPRB PROD1 RIH 03:30 - 03:55 0.42 DRILL N DPRB PROD1 Tie-in at RA Marker @ 13002 ft (-14 ft) 03:55 - 04:25 0.50 DRILL N DPRB PROD1 RIH to 13803 ft 04:25 - 04:35 0.17 DRILL N DPRB PROD1 Orient TF away from stops. TF at 120 to 140 R 04:35 - 04:45 0.17 DRILL N DPRB PROD1 RIH to 13860ft at 60 fpm and backed reamed to 13810 ft 04:45 - 05:05 0.33 DRILL N DPRB PROD1 RIH, TF 120 R to 13901ft at 40 fpm and backed reamed to 13816 ft at 150 to 180TF 05:05 - 05:30 0.42 DRILL N DPRB PROD1 RIH and tagged bottom at 14,116 ft 05:30 - 08:30 3.00 DRILL N DPRB PROD1 Back reaming hole up at 12 fpm 3.5bpm looks clean. Continue PUH pump 10/10 low/hi vis sweep through 7 5/8" to above TT. RIH slight bobble at 13839'. Clean to 14040. Adjust TF to 80L from 90R sailed through. Go to bottom. 08:30 - 11 :45 3,25 DRILL P PROD1 Drilling ahead, 2,55bpm 3650psi fs 2-300psi mw 11.25ecd good wt transfer. Drilled a small sh 14210-14225 expecting main S3A1. Drilled to 14262'. 11 :45 - 14:25 2.67 DRILL P PROD1 Wiper trip overpull 13880,13817 RIH tag at 13832' plu work through first time, clear to bottom. 14:25 - 17:30 3.08 DRILL P PROD1 Drill ahead f/14262' 2.6bpm 3750psi fs 11.25 ecd. Have drilled to 14350' maintaining 99 deg without finding any major shale to indicate S3A 1. ROP varying between 20-70'/hr 17:30 - 19:45 2.25 DRILL P PROD1 Early wiper trip to TT. Pumped 10/10 LH Vis sweep once in 7-5/8" casing. Geo's need time to figure where the S2A 1 shale went to. Will be at 90 deg (tirn down) when 9926 ft TVD is reached, then drill 90 deg as per Geo 19:45 - 20:25 0.67 DRILL P PROD1 Tie-In at RA Marker at 13002 ft 1 st time to deep, relogged Corrected (+ 11 ft) 20:25-21:15 0.83 DRILL P PROD1 RIH Tagged at 13838 ft wI HS TF, PUH, Orient TF to 100R. RIH clean 21:15 - 23:10 1.92 DRILL P PROD1 Drilling, 90L TF, Qp = 2.54/2.54, ECD = 11.23ppg, Vp = 344 bbl/337bbl ROP slowed down to 15 fph at 14450 ft MD 9929 ft Turned down at 14453 ft to 135L. 23:10 - 23:32 0.37 DRILL P PROD1 Orient TF to 135L work CT to and get it to drill. Talked to Geo, could be at base of S3A 1 shale and we need to know if we build or drop hole angle. POOH to PU Res Tool 23:32 - 00:00 0.47 DRILL P PROD1 POOH 3/22/2004 00:00 - 03:30 3.50 DRILL P PROD1 POOH. Inspected btm 200 ft CT. 1 spot at 35 ft = 0.165" PJSM on BHA Handling while POOH 03:30 - 04:43 1.22 DRILL P PROD1 BHA change out. PU RB RWD ST BC bit, Motor, Orienter and Survey package w/ GR 04:43 - 06:00 1.28 DRILL P PROD1 RIH Vp = 236 bbl initially 06:00 - 07:15 1.25 DRILL P PROD1 Continue RIH to 13030'. 07:15 - 07:30 0.25 DRILL P PROD1 Log tie-in at RA's... -15' correction. 07:30 - 07:50 0.33 DRILL P PROD1 RIH to 13700'. 07:50 - 10:35 2,75 DRILL P PROD1 Log Madd pass starting at 13700' to TO. No major stops along the way, Printed: 4/19/2004 12: 1 0:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 3122/2004 10:35 - 11: 15 0.67 DRILL P PROD1 PUH slowly and WOO. Town confirmed it appears we are in the S3A2 sand. RIH to bottom. No hole problems 11 :15 - 13:40 2.42 DRILL P PROD1 Drill ahead f/14449' 2.6bpm 3700psi fs 2-300psi mw 11.44ppg ecd 2-3k wob 70'/hr 1: 1 returns 10.0ppg in 10.2ppg out. Start to turn over well to 90deg around 14500'. Hard drilling started at 14515', stacking wt. numerous short wiper trips without much help. Drilled to 14520'. 13:40 - 15:15 1.58 DRILL P PROD1 Wiper trip to window pump hi vis sweep. Hole in good shape both ways. 15:15 - 16:35 1.33 DRILL P PROD1 Drill ahead turning downward to 87 deg and hold f/14520' 2.5bpm 3550psi fs 3-400psi mw 2-3k wob 70'/hr drilled to 14599' started stacking wt. It's been 150' since coming into the TT so will make a wiper to the TT. 16:35 - 19:35 3.00 DRILL P PROD1 Wiper trip. pumped 10/10 bbl HL sweep in 7-5/8" casing. PUH to btm TT and RIH at 100 fp wI 3 bpm to improve cleaning of area below 4-1/2" TT, Open ECD and bring Qp up 3.5bpm out to assist in hole cleaning 19:35 - 19:55 0.33 DRILL P PROD1 SO Pumps, closed EDC at 12050 ft while RIH. 19:55 - 20:07 0.20 DRILL P PROD1 Tie-in at 13025' going down Corrected +5 ft) 20:07 - 21 :00 0,88 DRILL P PROD1 RIH (open hole) Monitoring TF Tagged at 14563, pulled tigh 21 :00 - 21 :18 0.30 DRILL P PROD1 Working area from 14558 ft to 14599 ft (41 ft) TF needs to be at 90L Wash to bottom at 14599 ft. 21:18 - 21:29 0.18 DRILL P PROD1 PUH and back ream 14599 ft to 14550 ft Vp=389 bbl. Motor work (+4000 psi) from 14563' to 14335 ft. Backed reamed to 14530 ft 21 :29 - 21 :40 0.18 DRILL N DPRB PROD1 Wash to btm from 14530 ft w/1 00 L TF Tagged at 14544' Pulled 70k, no motor work, Rest tool to big coming around corner 21 :40 - 21 :55 0.25 DRILL N DPRB PROD1 POOH to LD Res Tool. Pulled tight 14058 to 14033 ft, SO pump and came free, PUH, Shales packing off around Res Tool. Unable to come up or down, SO pumps open choke, came free, PUH wol pumps till free. 21:55 - 00:00 2.08 DRILL N DPRB PROD1 POOH, Pumped 10/10LH Vis sweep in the 7-5/8" casing 3/23/2004 00:00 - 02:50 2.83 DRILL N DPRB PROD1 POOH 02:50 - 03:45 0.92 DRILL N DPRB PROD1 LD Rest Tool and BHA, Checked bit 03:45 - 04:55 1.17 DRILL N DPRB PROD1 Cut 85 ft CT off, Install new CTC, pull test, Cir CT to warm up 04:55 - 06:40 1.75 DRILL N DPRB PROD1 3/23/2004 06:40 - 07:05 0.42 DRILL N DPRB PROD1 P/U BHA #12 (65.16') no resistivity tool onboard. 07:05 - 09:30 2.42 DRILL N DPRB PROD1 RIH to 13030', 09:30 - 09:45 0.25 DRILL N DPRB PROD1 Log tie-in at RA's... corrected -15' 09:45 - 10:40 0.92 DRILL N DPRB PROD1 RIH 1.0bpm 1800psi adjust to 90L TF at 14500' RIH to 14586'. 10:40 - 11 :00 0.33 DRILL N DPRB PROD1 W/R back up at 3'/min w/90L TF 2.0bpm overpulls all the way back to 14550'. RIH slow packing off work down to 14560' totally packed off, basically stuck. Put wt down and hold let hole relax. 11 :00 - 14:30 3.50 DRILL N DPRB PROD1 Working pipe at 14564', Opened EDC attempt to pump but packed off above. Let rest 20 min. PU 80k. Pump wo returns to warm coil -25F. Call for dead crude. Put coil in compression and wait 20 min pump a little mud. Wait. Pull 90k with pump on. Nothing.. cycle pump and dump pressure with surface choke. Leave coil in compression on pressure. Wait on crude, 14:30 - 14:45 0,25 FISH N DPRB PROD1 PJSM. Spot crude tanker. 14:45-18:00 I 3.25 FISH N DPRB PROD1 At 2bpm @ 3300psi load coil with 30 bbls crude followed by 31 Printed: 4/19/2004 12: 1 0:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 312312004 14:45 - 18:00 3.25 FISH N DPRB PROD1 bbls mud. Pump 5 bbls crude out bit, open EDC and pump through 5 bbls. Crude in place at 15:45 Wait Cavitate pump #2 and with max down force on coil -16k pump 5 bbls. Wait 18:00 - 20:00 2.00 FISH N DPRB PROD1 Wait on lignosulfinate product from town. Plan forward is to make up a pill of lignosulfinate in brine to soak BHA, and possiblty break down shales packing off around top of BHA. Continuing to pump every 25 minutes to bullhead fluid into the formation to prevent coil from freezing. 20:00 - 20:25 0.42 FISH N DPRB PROD1 Consult with town to discuss plan forward. Continue to wait on pill. Injecting fluid during freeze protect at 2.25 bpm and 3200 psi. Pumping 2 bbls at a time. No noticible change in injection pressure during freeze protect pumping. 20:25 - 20:50 0.42 FISH N DPRB PROD1 Filled hole accross the top to ensure that we can see if we get any returns during pumping. Took 10 bbls to fill hole. Begin pumping 37 bbllignosulfinate pill. Note, hole angle at BHA is 92 deg. Mix pill at 10.5 ppg to allow it to swap out around top of BHA. Initial pump rate 2.6 bpm, 4300 psi. Trying to turn the orienter and vibrate the BHA while circulated pill to bottom. Still able to rotate the orienter 360 deg. Pump sweep to bit. Had to slow rate to 1.7 bpm at 4200 psi as we got 25 bbls of fluid away. No returns at all during initial displacement to bit. 20:50 - 21 :00 0,17 FISH N DPRB PROD1 48 bbls away, started getting trickle of returns. Returns fluctuating, pump rate and ECD pressures fluctuating, Getting some fluid thru the packed off interval, but returns indicate that the packed off cuttings are still present. Bring pump rate up to 2.4 bpm, 4000 psi. Returns 1.5 bpm, Trying to clean up hole. Ligno still in coil. 21 :00 - 21 :30 0.50 FISH N DPRB PROD1 Ligno sweep to bit. 2.3/0.6 bpm, 4400 psi. Try to pick up. Pull to 52 klbs. Normal pickups yesterday were 50-52 klbs. No movement in BHA, returns dropping off slightly. Don't want to pull tight into cuttings bed again. No choice but to bring some ligno uphole. Stack weight, pump 17 bbls of sweep out coil. 2.2/0.45bpm returns low and variable. Got 2.1 bbls of returns during displacement of first 17 bbls of lignosulfinate out of bit. Shutdown and let it soak, 21 :30 - 21:40 0.17 FISH N DPRB PROD1 Bring pumps on to displace remaining 17 bbls of lignosulfinate pill. Pumping thru entire BHA to let motor bounce us around. Also turning orienter. Initial injectivity 2.2/0/4200 psi. No returns. 21 :40 - 22:05 0.42 FISH N DPRB PROD1 Pumped final 17 bbls of sweep out BHA. No returns during pumping. SO pumps, and let it sit for 25 minutes. 22:05 - 23:00 0.92 FISH N DPRB PROD1 Bring pumps back on. 2.48/010/4400 psi. No Returns. Begin pumping low vis/high vis sweeps, Pump 10 bbls brine, followed by 10 bbls of 150 klsrv mud. Repeat cycle with 4 sweeps of each, Get first sweep to bit. Work pipe from max compression to neutral weight. Continue to yo-yo pipe as we pump sweeps, Printed: 4/19/2004 12: 1 0:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 312312004 23:00 - 00:00 1.00 FISH N DPRB PROD1 No returns during displacement of sweeps out BHA. 100 bbls left in pits. Go too freeze protect mode while new mud and brine comes out from Deadhorse. Hold Spill drill while waiting on new mud. 3/24/2004 00:00 - 01 :45 1.75 FISH N DPRB PROD1 Continue to wait on mud. 01 :45 - 03:00 1.25 FISH N DPRB PROD1 Taking on usedlreconditioned mud system from MI. Resume trying to free BHA. Try surging the backside. Pump down backside and coil simultaniously then bleeding the backside quickly thru the choke. First attempt at 1000 psi. Next 4 attempts at 1500 psi. Check returns by liining up thru MM instead of choke. Bring on pumps. No returns. Try it again at 1500 psi for 4 more attempts. No returns. Try it again at 2000 psi for 4 attempts. No returns. 03:00 - 03:30 0.50 FISH N DPRB PROD1 Blow back mud from the standing iron to the pump. Bring on the pumps and try to rock the BHA. No luck. Pull to 60klbs, No movement up. Stack out weight. No movement down. 03:30 - 04:30 1,00 FISH N DPRB PROD1 Hook back up to crude transport. Pump 50 bbls of crude. Initial pump rate thru the EDC 2.64/0.0/4400 psi. Final pump rate 1.710.0/4500 psi. Displace 15 bbls out EDC. Shut EDC. Work pipe. Pull to max safe pull of 96 klbs several times. Work pipe vigorously in last attempt to get free, No movement of BHA up or down. 04:30 - 04:45 0.25 FISH N DPRB PROD1 Call town and discuss plan forward. Plan is to open disconnect and release from the BHA. 04:45 - 05: 10 0.42 FISH N DPRB PROD1 Gave it one last pull prior to opening EDC to release BHA, and at 96 klbs, BHA started moving up hole. Kick on pumps. Pumping 1.5/0.0/4200 psi. Still packing off. PUH slowly at 20 fpm, trying to clean up debris ahead of us. 05:10 - 06:00 0.83 FISH N DPRB PROD1 14110', Hung up again. Only pulled 10 klbs over. Circulate to see if it cleans up. 06:00 - 08:30 2.50 FISH N DPRB PROD1 Continue pumping 1.5 bpm 4100psi no returns. Shutdownpump bleed pressure thru Baker choke put coil in max compression -16k. Wait. Mix another 40bbl Ligno pill in tank #4. Fill backside. Pumping down coil .5bpm work pipe up to 65k the back to compression. Moved once 20' uphole. Continue working pipe. Moved again 2nd try. 08:30 - 09:30 1.00 FISH N DPRB PROD1 Line up to pump down backside thru kill line. Open choke line HCR. Shut-in downstream. Pump down BS to 1000 psi. Coordinate picking up while dumping downstream valve. Cycled this 6 times. Moved to 14063. Able to tag down at 14076', 13' of free movement. 09:30 - 10:20 0.83 FISH N DPRB PROD1 Pump down coil 1.25bpm 3800psi Breaking down to 3300psi. One very quick show of returns then packed off again. Increase to 1.5 3800psi. no returns. 10:20 - 11 :00 0,67 FISH N DPRB PROD1 Pump for freeze protect. Take on more whole mud, 11 :00 - 11 :20 0.33 FISH N DPRB PROD1 Line up on coil. Pump to 4000psi then block in at reel. Open Baker choke then dump block valve. Gave this 4 trys, Pick-up work up to 94K. No movement. No returns. 11 :20 - 12:15 0,92 FISH N DPRB PROD1 Load coil with 30bbl crude followed by 30 bbls. Mud. Spot 5 bbls out of bit. Open EDC and pump 5 more. Oil in place at 1215 Printed: 4/19/2004 12:10:34 PM e - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 3/24/2004 12:15 - 13:40 1.42 FISH N DPRB PROD1 Pump for freeze protect every 20min and move 5 bbls oil thru EDC. Maintain any residual pressures on the coil to slowly bleed down on it's own. 13:40 - 15:40 2.00 FISH N DPRB PROD1 Pump 30 bbllignosulfinite pill follow by 35 bbls mud at 2.40bpm 4400psi placing 5 bbls out of EDC, Cycle pipe 65k1-16k while pumping. No returns. Seem to have lost any free movement with BHA. Pill in place at 14:00 Coil pressure bleeds off to 11 OOpsi and stabilizes. 15:40 - 16:30 0.83 FISH N DPRB PROD1 Line up to fill backside. Pressure up to 1200psi and dump while PUH to 80k. RIH to -16k and repeat 3 times. Regained pipe movement of +1- 10', Line-up to pump down annulus and coil sametime. Dump annulus maintaining coil pressure. Not gaining but not loosing either. Shutdown pump maintaining coil pressure and work pipe within free zone. Mixing another ligno pill. 16:30 - 18:00 1.50 FISH N DPRB PROD1 Yo Y 0 pipe and maintain 11 00-1500psi on coil. 18:00 - 20:30 2.50 FISH N DPRB PROD1 Pump 25 bbls of lignosulfinate pill. Displace to bit. Open EDC, Yo-Yo pipe from stacked weight to 62 klbs (Last pickup weight) to attempt to string pill up thru stuck point. No apparent movement of BHA. Displace 12.5 bbls out coil. SI, and let it soak for 25 minutes. Pull on it to max pull of 95 kbls. No observed free travel up or down. Pull max overpull, and pump the remainder of the ligno. Perform stuck pipe calculations. Stuck pipe at 13700' based on calcs. Pretty close to bit depth of 14063'. 20:30 - 21 :00 0.50 FISH N DPRB PROD1 Check that the orienter will still turn. It does. IAP=396, OAP=O. Check coil limit yield curve for negative differential pressure and string weight. Pump 5 bbls to warm coil. Fill the well across the top. Took 0.6 bbls to fill well. Pressure up the backside to 2000 psi. No pressure on coil. Try to work pipe. Able to run down hole 30' to 14098', then tag up. PU and moving up at 64 klbs. Able to move up hole above last stuck point. Pulling up hole at 14068' until we hung up. RIH still holding 2000 psi whp, no coil pressure. Can't move down. Continue trying to work it down. No movement. Try picking up on it to max of 85 klbs (80% yeild point plus safety factor). No movement. 21 :00 - 21 :30 0.50 FISH N DPRB PROD1 Bleed off backside, warm coil. Pressure up backside to 2000 psi. Able to RIH 20'. PU unable to come up. Bleed off backside, this time able to move up. Made it up hole a few ft. Repeat the cycle, and able to RIH to 14087', PU, able to move up to 14068'. Bleed down the backside, line up down the coil. Pump down the coil. 1.4/0.0/4000 psi. Unable to move down, but did move up real draggy to 14043', then hung up, 21 :30 - 21 :45 0.25 FISH N DPRB PROD1 Depth at neutral weight = 14047'. Repeat backside pressuring cycles, No pipe movement. 21:45 - 22:10 0.42 FISH N DPRB PROD1 Bleed off backside. Pump down coil to warm it. 1.0 bpm, 3700 psi. Repeat backside pressuring cycles, Did not have any movement up or down. 22:10 - 22:40 0,50 FISH N DPRB PROD1 Pump down coil to warm pipe. Resume backside pressure cycle to 2000 psi while holding 90 klbs on coil. No movement Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 312412004 22:10 - 22:40 0.50 FISH N DPRB PROD1 of coil. 22:40 - 23:00 0.33 FISH N DPRB PROD1 Warm coil. Resume backside pressure cycle to 2000 psi while working pipe. No movement of coil. 23:00 - 23:30 0.50 FISH N DPRB PROD1 Begin pumping down coil and pressuring up backside, then dumping backside pressure. No movement in BHA. 23:30 - 00:00 0.50 FISH N DPRB PROD1 Pump crude down the coil at high rate. Initial injectivity 2.2/010/3900 psi going thru the bit. Pump crude to BHA, open EDC. 3/2512004 00:00 - 00:45 0.75 FISH N DPRB PROD1 Pump crude to BHA. Open EDC. Pump 10 bbls of crude. Work pipe. No pipe movement, no returns. 00:45 - 02:00 1.25 FISH N DPRB PROD1 Pull to 90 klbs. Hold string tension, 02:00 - 02:40 0.67 FISH N DPRB PROD1 Attempt to work pipe, Try while pumping and with pumps shutin. Can't move BHA in either direction. Call town. Discuss situation. No significant progress for last 5 hours. Time to disconnect. 02:40 - 06:00 3.33 FISH N DPRB PROD1 Warm pipe by pumping. Activate BHI EDC to disconnect from BHA. Disconnected at 02:45. Work pipe to attempt to get thru obstruction. Still stuck. Call E-line truck to spool up e-line in coil. Continue to work pipe. 06:00 - 06:01 0.02 FISH N PROD1 For anybody reading this the phone system is out. Winds howling. Comms people will be working on the probelm Currently waiting for SLB trucks. Pumping brine (bullheading) to keep coil warm. Can call OPS cab on their cell phone 907-448-1996 06:01 - 09:00 2.98 FISH N PROD1 Warm coil at 20 min intervals. Communications still exist with the BHi tools. EDC has not completely parted and severed the electrical connection. The EDC travel block was repositioned across the collets to reconnect. Take on more 10.0ppg brine. Transfer whole mud to vac truck. Empty full cuttings tank (all fluid). Discuss situation with town. 09:00 - 09:20 0.33 FISH N PROD1 PJSM with all hands incl SLB wireline. Review Plan Forward to work pipe to "free area" and obtain full disconnect there. SLB e-line truck released to Nabor 7ES. Replacement later this afternoon. 09:20 - 10:15 0.92 FISH N PROD1 Line up to pump down Kill line. Open Choke line HCR, block in at choke manifold, Work pipe with backside pressures to 2200psi max. Keeping pressure on coil for stiffness. Yo-yo pipe dumping pressures and recharging. No movement no returns. 10:15-10:20 0.08 FISH N PROD1 Send command to disconnect EDC. Regroup to work pipe with pressures. 10:20 - 11 :00 0.67 FISH N PROD1 Continue working pipe as above. Looking for comms loss with tools. Coil life at Gooseneck is over 50%. Stopping here before something else happens at surface. Call discuss with town. Plan forward is go into coil cutting mode. 11:00 -12:30 1.50 FISH N PROD1 Reorganize crews. Keep coil warm. 12:30 - 12:55 0.42 FISH N PROD1 PJSM with all hands incl SLB wireline. Review Guidelines and Procedures for cutting coil at surface and e-line removal. 12:55 - 13:50 0.92 FISH N PROD1 Prep tools. Pull 5k over original plu weight of 55k and set upper combi's. Pulllpush test. Release chain tension on injector and let bleed down, Coil slipped in combi's. reset chain tension. Unlock combi's. Pull to 40k. Open upper rams. Pull to 40k and close upperllower combi's and lock. Printed; 4/19/2004 12;10;34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 3/12/2004 4/18/2004 Spud Date: 12/13/1995 End: 312512004 13:50 - 15:00 1.17 FISH N PROD1 Pump last time to warm coil. Unstab from well plu injector. RU and hot tap coil to check for pressures and drain. Cut coil 7' above RT. P/U injector l' install e-line cable clamps. Cut 5/16" e-line. Move injector over bunghole and circ to warm. 15:00 - 18:00 3.00 FISH N PROD1 Erect Scaffolding. 18:00 - 18:30 0.50 FISH N DPRB PROD1 Scaffolding has been erected. Hold safety meeting discussing plan forward. One issue to discuss is that the coil is too egged to install the CTC. We will reswage it after the eline is recovered. 18:30 - 22:15 3.75 FISH N DPRB PROD1 Pull cable slack for rigup using rig blocks. Rig up to SWS eline unit with an empty drum, Pickup slack with eline unit. Install cable clamp. Pull weakpoint with rig blocks. Took 7 klbs at surface to pull weakpoint. Pull wire OOH with SWS unit. 22:15 - 22:25 0.17 FISH N DPRB PROD1 Safety meeting to discuss plan forward. 22:25 - 23:30 1.08 FISH N DPRB PROD1 Swage coil using SWS hydraulic swagger to remove egg in pipe. Pipe de-egged a bit, but need further improvement to properly install slip type CTC. Call for another swage from Deadhorse. 23:30 - 00:00 0.50 FISH N DPRB PROD1 Wait on new swage, and wireline crew from Deadhorse to continue with operations. 3/26/2004 00:00 - 01 :00 1.00 FISH N DPRB PROD1 Continue waiting on wireline crew and pipe swager. 01 :00 - 02:00 1.00 FISH N DPRB PROD1 Reswage pipe. Install CTC. Pull test, retighten, pulltest. Install valve, and pump in sub. 02:00 - 03:15 1.25 FISH N DPRB PROD1 Wait on SWS wireline crew. 03:15 - 03:35 0.33 FISH N DPRB PROD1 Meet with Schlumberger crew. Discuss the rig up, and job planning. 03:35 - 05:00 1.42 FISH N DPRB PROD1 RU Schlumberger eline unit, sheaves, grease head, etc. 05:00 - 05:30 0.50 FISH N DPRB PROD1 PJSM prior to arming chemical cutter. Note - Chemical cutter is a radio safe device. Hazards, mitigations and PPE discussed. 05:30 - 06:00 0.50 FISH N DPRB PROD1 RIH with dummy drift to 200'. 06:00 - 06:30 0.50 FISH N DPRB PROD1 RID dummy drift and arm chemical cutter. 06:30 - 06:45 0.25 FISH N DPRB PROD1 PJSM with new crews. Review procedures for handling chem cutter. POH with same slowly to avoid swabbing in well. Good communications with SLB/Nordic/SWS.. 06:45 - 07:15 0.50 FISH N DPRB PROD1 Insert chem cutter in coil. Connect grease tube. 07:15 - 09:30 2.25 FISH N DPRB PROD1 RI H wI cutter. Stopped at 12020' (20' below TT) P/U CC (1500Ibs) to 11950' RIH and bring on pump .5 bpm stopped again at 12020' 1750lb pick-up. Try several times at 1 bpm stopped same place 1850lb pick-up. Dont want to force this and get hung-up. Regroup. 09:30 - 10:15 0.75 FISH N DPRB PROD1 Look situation over. Since we are not currently on the coil with the blocks, will reposition SWS sheave to tugger & safety tag line and rig bales to latch coil to allow increasing tension in coil. It's possilbe coil could be slightly kinked just below the 4 1/2" TT due to excesive yo-yo work in just one spot yesterday or helical bending. 10:15 - 10:30 0.25 FISH N DPRB PROD1 PJSM with all hands and review procedures for plan forward, 10:30 - 11 :30 1.00 FISH N DPRB PROD1 Tighten SWS pack-off and back off tension. Reposition SWS sheave to "Blue" tugger line and secure with safety line to derrick gert. Install Bottleneck elevators on bales and add Green Sling thru bales for length. Reinspected sling's fiber optic cable prior to installation. Install YT elevators on sling and Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 3/12/2004 4/18/2004 Spud Date: 12/13/1995 End: 312612004 10:30 - 11 :30 1.00 FISH N DPRB PROD1 latch on coil beneath slip type coil connector. Insure YT's grip is below coil connector. Pull to 45k with blocks. Open lower combi's check for flow. Dead. Open upper combi rams, lost 5k on wt indicator. Remove dog collar safety clamp, let coil ride on slips, Pull to 45k. 11 :30 - 12:25 0.92 FISH N DPRB PROD1 RIH wI CC and stopped same place 12020'. Pull coil tension to 50k. RIH stopped at 12500' (74*). Bring on pump 1/2 bpm stopped at 12600', clean pick ups. Pump 3/4bpm RIH slowly increase pump to 1,25bpm stopped at 13320'. Now convenient! Only tie-in indicators were the X nipple at 11930' and the whipstock. Pull up to 13302'. Install dog collar. Close annular. Maintain 800 psi on coil. Fire CC fair indication at wt indicator, lost coil pressure, Try to pull out with CC but tool is hung up, Try pumping at 1000 psi. Pull to 53k and CC came free. Was aiming for 55k but coil appears to be cut. 12:25 - 14:45 2.33 FISH N DPRB PROD1 TOH to 200' with CC at 6000'/hr watch for swabbing. 14:45 - 15:00 0.25 FISH N DPRB PROD1 PJSM review procedures for lId of CC, 15:00 - 15:45 0.75 FISH N DPRB PROD1 Raise SWS sheave. Lower coil to working height. Install dog collar. Break side entry Y. Clear floor. P/U grease tube and CC. Layout CC and secure. 15:45 - 16:05 0.33 FISH N DPRB PROD1 Line up on backside and check that it's full. Pump down coil and fill. Both full and no circulation. P/U on coil confirm cut. 16:05 - 16:25 0.33 FISH N DPRB PROD1 RID SWS. 16:25 - 18:15 1.83 FISH N DPRB PROD1 Pick-up coil 15' close both Combi's, set slips and dog collar. Cut coil and dress end. Weld on coil splice device to stub of coil sticking up. 18:15 - 18:35 0.33 FISH N DPRB PROD1 Safety meeting re: Picking up Injector and stabbing coil onto splice device to weld coil up. 18:35 - 21 :20 2.75 FISH N DPRB PROD1 PU injector. Cut 60' of egged pipe to get to good coil. Stab coil into splice device, Weld coil. 21 :20 - 22:00 0.67 FISH N DPRB PROD1 Rig down scaffolding while waiting on weld to cool. 22:00 - 22:15 0.25 FISH N DPRB PROD1 Safety meeting prior to stabbing on to well with injector. 22:15 - 23:00 0.75 FISH N DPRB PROD1 Stab injector onto wellhead quick connect. 23:00 - 23:30 0.50 FISH N DPRB PROD1 PU off bottom. PU smooth at 54 klbs with no overpulls. Spool splice back onto reel ok, no mechanical deformation observed. Get 3 wraps on reel and PU speed. We are not pumping at this point. Note top of coil tubing fish is at 13302', with is 300' below the window. 23:30 - 00:00 0.50 FISH N DPRB PROD1 Stop at Tubing tail. Fill the backside with mud. Swap to pumping mud down the coil. Getting 1 for 1 returns. Swap to brine. Remain on bottom until brine to the end of coil. 3/27/2004 00:00 - 03:00 3,00 FISH N DPRB PROD1 Continue POOH with coil. Pumping 10 ppg brine. Swapped to methanol and freeze protected top 1500' of well. 03:00 - 04: 15 1.25 RIGD N DPRB PROD1 At surface with coil. PU injector. Catch the end of coil. Attached a CTC and nozzle. 04:15 - 04:30 0.25 RIGD N DPRB PROD1 Safety meeting prior to blowing down reel with nitrogen. 04:30 - 06:00 1,50 RIGD N DPRB PROD1 PT hard line to 3500 psi. Failed PT. Change out a chicksen. PT again. Passed ok, Line out N2 pumper to reel. On line with N2 to purge coil taking returns to tiger tank, 06:00 - 07:30 1,50 RIGD N DPRB PROD1 Blowdown coil with N2. Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 312712004 07:30 - 14:00 6.50 RIGD N DPRB PROD1 Secure coil to coil. Setback injector. Lower reel to Veco truck. Remove drive plates for coil reel. Currently plan to leave this reel on location until we swap out for one in Deadhorse. ATP meeting with Endicott personnel. Discussed 2-36 RWO Clean pits. 14:00-14:15 0,25 RIGD N DPRB PROD1 Set BPV. 14:15 -16:30 2.25 RIGD N DPRB PROD1 Remove 2 7/8" and 31/2" liner from pipe shed. Same time rebuild upper combi's on BOP's. 16:30 - 18:00 1,50 RIGD N DPRB PROD1 UD 1 1/4" hydril from derrick. 18:00 -18:15 0.25 RIGD N DPRB PROD1 Safety meeting prior to continuing to lay down CS hydril work string, 18:15 - 20:00 1,75 RIGD N DPRB PROD1 Continue laying out CS hydril work string. 20:00 - 23:00 3,00 RIGD N DPRB PROD1 Nipple down 7-1/16" stack. Nipple up tree cap. PT tree cap to 3500 psi with diesel. Rig release at 23:00 3-27-2004 Further telex entries carried on Endicott 2-36 reports. 23:00 - 23:30 0,50 RIGD N DPRB COMP 23:30 - 00:00 0,50 RIGD N DPRB POST 4/4/2004 18:30 - 00:00 5,50 MOB N DPRB PRE Rig released from 2-33F at 1830 hrs Move rig off well PU matting boards and cellar liner. Spot around 1-65 well head. Mats needed to provide enough height for rig over adjacent well houses, Safety mtg re: next steps Spot rig over well. Lower rig onto mats 4/5/2004 00:00 - 03:00 3,00 BOPSUP N DPRB PRE Rig over well. Accept at 0001 hrs on 4/5/04. NU coil BOPS, Take on water 03:00 - 06:00 3.00 RIGU N DPRB PRE Spot and pick up e-coil reel. Clean out remaining dirty fluid from pits. MU choke & kill lines, NU lubricator from BOPS to rotary table. 06:00 - 06:30 0.50 RIGU N DPRB PRE PJSM to plan work for day tour ahead. Discuss simultaneous operations involving rigging up reel and BOP testing. Hazard areas discussed and hazards mitigated. 06:30 - 11 :00 4.50 BOPSUPN DPRB PRE Perform initial BOP test. Witness waived by AOGCC. While driller is performing BOP test the other hands continue with rig up. SWS crews rig up hardline to reel, rig hands spot TLM, MI, and MWD shacks. Veco crew runs hardline to tiger tank. 11 :00 - 16:00 5.00 BOPSUP N RREP PRE Unable to get choke manifold to hold pressure. Grease tree. No improvement. Rebuild BOP test pump. Eventually determine leak is back through HCR valve to BOPS. Lesson learned for future testing. 16:00 - 18:30 2.50 BOPSUF N DPRB PRE Continue BOP test. Replace J box with jupitor connections for e-line inside reel. Continue to work on pipe shed door ram seal(s). 18:30 - 23:00 4,50 BOPSUF: N RREP PRE Blind shears not testing. Replace same. Blinds leaking. Rebuild rams again. Get good test. BOP test completed. Total test time: 14,5 hrs, Average trouble free BOP test time: 5.0 hrs. Total BOP trouble time: 9.5 hrs, 23:00 - 00:00 1,00 BOPSUPN DPRB PROD1 RU DSM lubricator, Pull BPV from well head. 4/6/2004 00:00 - 00:30 0,50 BOPSUF N DPRB PROD1 Complete BPV removal operations with DSM crew. No pressure on well, Printed: 4/19/2004 12: 1 0:34 PM « e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 416/2004 00:30 - 01 :00 0.50 STWHIP N DPRB PROD1 Hold PJSM with crews to discuss stabing coil operations. 01 :00 - 02:45 1.75 STWHIP N DPRB PROD1 Stab coil using tuggerlgrapple assembly. Pull across pipe shed roof and through injector. 02:45 - 04:00 1.25 STWHIP N DPRB PROD1 Get on well with injector. Circulate coil with meoh, water, followed with flo pro for 1.5 coil volumes. Reverse circulate with mud, followed by water to pump slack back into reel. 04:00 - 06:00 2,00 STWHIP N DPRB PROD1 Get off well. Cut coil back to e-line. MU Kendall connector and e-line flow sub. Test same. 06:00 - 06:30 0,50 STWHIP N DPRB PROD1 Make up cleanout BHA. DS49 bit, 1.2 deg motor, coiltrack MWD. 06:30 - 08: 15 1,75 STWHIP N DPRB PROD1 Stab on injector, RIH with BHA #13. Getting gas cut returns, take flow to the tiger tank. 08:15 - 08:40 0.42 STWHIP N DPRB PROD1 Stop coil. Pump accross the top with methanol taking returns to the tiger tank. Pump 20 bbls meth to freeze protect the TT line. (8 bbls rig vol). 08:40 - 09:35 0.92 STWHIP N DPRB PROD1 Continue RIH. 09:35 - 11 :15 1.67 STWHIP N DPRB PROD1 Cleanout 7-518" casing. Taking 100' slow bites, pumping high visllow vis sweeps, and chasing it to the TTail. 11 :15 - 11 :45 0.50 STWHIP N DPRB PROD1 Cleanout down to 12500. Tie into GR charecter at 12450', -12' correction. 11 :45 - 13:30 1.75 STWHIP N DPRB PROD1 Resume cleanout to window. Continue to take 100' bites. Circ hillo sweep with each bite. 46k# up, 16K# dn wt. 3800 psi@ 2.74 bpm. 13:30 - 14:30 1.00 STWHIP N DPRB PROD1 Enter open hole. Some motor work at 13030' - 60'. PU clean, Continue in hole to 13150'. Hole very smooth. Time hillo sweep to exit bit while POOH from 13150'. Continue to POOH at 30-40 fpm on final up pass. 14:30 - 16:45 2,25 STWHIP N DPRB PROD1 Circulate out of hole. RIH at surface to 500' to flush cuttings. Pull to surface. A lot of material over shaker, 16:45 - 17:00 0.25 STWHIP N DPRB PROD1 Hold PJSM to discuss handling BHA. 17:00 - 17:30 0.50 STWHIP N DPRB PROD1 At surface. Get off well. Unstab coil. LD MWD & motor. 17:30 - 18:00 0.50 STWHIP N DPRB PROD1 PU Weatherford billet & setting tool on mwd. 18:00 - 20:00 2.00 STKOH N DPRB PROD1 RIH wI BHA #14 20:00 - 20:20 0.33 STKOH N DPRB PROD1 Log tie-in down from 12470'. Corr -13' 20:20 - 20:40 0.33 STKOH N DPRB PROD1 RIH thru window, clean. RIH in OH to 13140', clean. 50.7k, 20.8k 20:40 - 20:50 0.17 STKOH N DPRB PROD1 Close EDC. Pressure setting tool to 2500 psi, then to 3500 psi and hold. Repressure twice after 200 psi bleed off thru weep hole. PUH and released from WS at 3k over. Top of OH WS at 13125' 20:50 - 23:00 2,17 STKOH N DPRB PROD1 POOH wI setting tool 1 .25/3000 23:00 - 23:20 0,33 STKOH N DPRB PROD1 LD WII setting tool and load out 23:20 - 00:00 0,67 STKOH N DPRB PROD1 MU sidetrack drilling BHA and surface test 4/7/2004 00:00 - 02:00 2,00 STKOH N DPRB PROD1 RIH wI BHA #15 (1.5 deg, DS111) 02:00 - 02:20 0,33 STKOH N DPRB PROD1 Log tie-in down from 12470'. Corr -17' 02:20 - 02:30 0.17 STKOH N DPRB PROD1 RIH and tag WS at min rate at 13128'. PUH 48k, start pump 2.5/3670 02:30 - 02:45 0.25 STKOH N DPRB PROD1 RIH and park at 13125.3' 2.5/3650. Swap to pump #2 2.5/3625 02:45 - 03:30 0.75 STKOH N DPRB PROD1 First motor work at 13125.3'. Begin drilling off WS face 2.5/3600/30-45R ECD 11.4 03:30 - 04:00 0,50 STKOH N DPRB PROD1 13127,0' and starting to stack. Pickup, clean. Better wt transfer as RIH, Appear to be off of WS so start control drilling at 20'/hr and get to 13128.2' wI 500# diff and then motor Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 41712004 03:30 - 04:00 0.50 STKOH N DPRB PROD1 stalled. PUH and found motor was still stalled and press bled off slowly. PUH thru window and surgelbleed off CT wI no help. Assume motor problem 04:00 - 06:15 2.25 STKOH N DPRB PROD1 Open EDC 2.5/3200. POOH for motor. Aluminum shavings over shaker 06:15 - 07:00 0.75 STKOH N DPRB PROD1 At surface. Get off well, Unstab coil. Check bit & motor. Found several 3/8" bullet or cone shaped pieces of aluminum inside nozzles. Motor feels ok. Somehow sucked or forced aluminum up inside bit, which plugged nozzles, 07:00 - 12:00 5.00 STKOH N SFAL PROD1 Found hairline crack in btm of powerpack hydraulic tank, Decide to repair same. Drain tank. Wipe down inside of tank. Inspect inside of tank. Purge with N2. Weld same. Crack was near end of baffle weld on inside of tank btm. Discussed event with H. Williams, Drillind HSE, and will classify as a mechanical repair. 12:00 - 12:45 0.75 STKOH N DPRB PROD1 Change out motor. MU and scribe same ( 1,5 deg wI DS-111 bit). Stab coil. Get on well. 12:45 - 15:00 2.25 STKOH N DPRB PROD1 RIH. Unload hydraulic tank repair equipment from pipe shed. 15:00 - 15:15 0.25 STKOH N DPRB PROD1 Log gr tie in from 12450'. Subtract 18' correction. 15:15 - 15:30 0.25 STKOH N DPRB PROD1 RIH, 15:30 - 18:00 2.50 STKOH N DPRB PROD1 RIH. 4100 psi@ 2.71 bpm fs. 46K# up, 16K# dn wt. TF:40R Tag at 1327'. Stall. PU and start again. Stall again. PU. Park bit at 13126'. Circulate for 5 minutes. Resume sidetracking off alum WS wI occasional stalls at 13127' 18:00 - 21 :20 3.33 STKOH N DPRB PROD1 13127.3' 2.6/3830 Have trouble getting by 13127.3' (stalls). Work slowly back down to this point, clean each try, but then motor stalls 21 :20 - 23:10 1.83 STKOH N DPRB PROD1 13127.6' 2.6/3920/40R Finally making cautious headway and appear to be off-no more stalls, but sli incr in FS 23: 10 - 00:00 0.83 STKOH N DPRB PROD1 13133.0' 2.6/3940/40R 20'/hr Drill to 13142' 4/8/2004 00:00 - 00:15 0.25 STKOH N DFAL PROD1 Slow backream clean thru billet area from 13142' after orientor was not responsive. Work to get orientor functioning-nope 00:15 - 02:10 1.92 STKOH N DFAL PROD1 POOH for orientor failure 02:10 - 03:15 1.08 STKOH N DFAL PROD1 Change complete MWD assy and add flex sub above motor. Adjust motor to 1.2 deg. Change bit (had 4 of 5 jets plugged with aluminum) Found out later that MWD problem was short in DPS sub 03:15 - 05:20 2.08 STKOH N DFAL PROD1 RIH wI BHA #17 (1.2 deg, DS49T) 05:20 - 05:40 0.33 STKOH N DFAL PROD1 Log tie-in down from 12470'. Corr -19' 05:40 - 06:00 0.33 STKOH N DFAL PROD1 RIH thru window, clean. Precautionary ream by OH WS at 2'/min 2.6/3800/40R and clean. Tag TO at 13144' 06:00 - 08:45 2.75 DRILL N DPRB PROD1 Drill from 13144' 2.6/3800/30R. ROP:70 fph. WOB: 1.5K# Drilling ahead smoothly. Good weight transfer. ECD: 11.4 ppg. 08:45 - 10:00 1.25 DRILL N DPRB PROD1 Short trip to tbg tail. Pump at min rate through window. RIH 100' before pulling into ttail with BHA. Pump 10 10/10 hi bbl vis pill while entering 7-5/8" csg section. 10:00 - 13:00 3.00 DRILL N DPRB PROD1 Drill ahead. 3865 psi @ 2.7 fs. 250 dpsi. 42k# up, 12k# dn wt, TF:110-70L WOB:1-2k#. ROP:70-80 fph. Drilling ahead smoothly. Holding back on ROP to maintain adequate hole cleaning. 13:00 -14:15 1.25 DRILL N DPRB PROD1 Short trip to tbg tail. Pump at min rate through window puuling slow (25 fpm). RIH 100' before pulling into ttail with BHA. Pump 1010/10 hi bbl vis pill while entering 7-5/8" csg section, Printed: 4/19/2004 12: 1 0:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 418/2004 14:15 - 16:30 2.25 DRILL N DPRB PROD1 Drill ahead to 13600' No change in drilling parameters, 16:30 - 18:40 2.17 DRILL N DPRB PROD1 Short trip to tbg tail. Pump at min rate through window puuling slow (25 fpm), RIH 100' before pulling into ttail with BHA. Pump 10 10/10 hi bbl vis pill while entering 7-5/8" csg section. RBIH and set down on OH WS wI TF at 120R. Go by at drilled TF, clean. Rest of hole clean. Tag at 13600' 18:40 - 18:50 0.17 DRILL N DPRB PROD1 Work wI orientor to get to 11 OR from 90L and seems slow to respond 18:50 - 00:00 5.17 DRILL N DPRB PROD1 Drill ahead 2.54/3630/90R ECD 11.44, but stacking due to TF change and shale interval shown later on GR. Several 50-100' wipers to remove dog leg. Continue drilling ahead at 87 deg and following plan. Cross a few minor shales 4/9/2004 00:00 - 00: 15 0.25 DRILL N DPRB PROD1 Drill to 13760' 00:15 - 01 :15 1.00 DRILL N DPRB PROD1 Wiper to EOT, clean, RBIH 01 :15 - 01 :30 0.25 DRILL N DPRB PROD1 Log tie-in down from 12470', Corr +8' 01 :30 - 02:05 0.58 DRILL N DPRB PROD1 Precautionary ream to TO, clean. Tag at 13763' 02:05 - 04:45 2.67 DRILL N DPRB PROD1 Drill ahead 2.55/3750/11 OR and penetration rate gradually slowing to 20'/hr while stacking 15k WOB. Assume bit is dull or motor is weak 04:45 - 05:25 0.67 DRILL N DPRB PROD1 Wiper to EOT 05:25 - 05:50 0.42 DRILL N DPRB PROD1 Pump 15 bbl ea lolhi vis pills while recip in 7-5/8" liner 05:50 - 07:30 1.67 DRILL N DPRB PROD1 POOH to check motor and bit. Open EDC. Able to get 3.0 bpm @ 3700 psi while POOH. 07:30 - 08: 15 0,75 DRILL N DPRB PROD1 At surface. RIH to 300' pumping. Shut dn pump. POOH to 150'. Get off well. Check coil while POOH slow. Slight flat spot 6' above connector. No action required. 08:15 - 09:15 1.00 DRILL N DPRB PROD1 LD BHA. Bit 0-1-1 09:15 -11:15 2.00 DRILL N DPRB PROD1 Stab coil. Get on well. RI H with new 1.2 deg mtr with new DSX49 bit. Repair pump#1 swab. 11:15-11:30 0.25 DRILL N DPRB PROD1 Log gr tie in from 12480'. Subtract 8' correction. 11 :30 - 12:00 0.50 DRILL N DPRB PROD1 RIH to TO. Hold 45 RTF past billet. 12:00 - 14:30 2.50 DRILL N DPRB PROD1 Drill ahead. 3900 psi@ 2.72 fs. 300 dpsi 48k# up, 14k# dn WI TF:85L WOB: 2.5-3.5k# ROP: 80 fph. ECD: 11,64 ppg. Tag btm at 13838'. Drill ahead smooth. Holding back on ROP to allow for hole cleaning. 14:30 - 16:30 2.00 DRILL N DPRB PROD1 Begin displacing to new mud system. Short trip to tbg tail. Pump at min rate through window puuling slow (25 fpm). RIH 100' before pulling into ttail with BHA. Pump 10 10/10 hi bbl vis pill while entering 7-5/8" csg section. RBIH and and clean to TO. Pump #2 liner leak. Swap to pump #1 16:30 - 18:00 1.50 DRILL N DPRB PROD1 Drill ahead. 3900 psi@ 2,62 fs. 300 dpsi 48k# up, 16k# dn WI TF:85L WOB: 2.5-3.5k# ROP: 80 fph. ECD: 11.46 ppg. Tag btm at 14050'. Drill ahead smooth. 18:00 - 19:40 1.67 DRILL N DPRB PROD1 Drill ahead 2.6/3830160L ECD 11.6 w/1 00-300 psi diff 3-5k WOB 19:40 - 21:15 1.58 DRILL N DPRB PROD1 Wiper to EOT was clean both ways. Tag at 14156' and orient to right 21:15 - 23:30 2.25 DRILL N DPRB PROD1 Drill ahead 2.56/3830175R ECD 11.5 100-400 psi diff, 1-4k WOB while building to 93 deg to hold at 10021' TVD. Getting steady sand returns over shaker wI sli incr in volume when RBIH thru 7-5/8" 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Wiper to EOT 4/10/2004 00:00 - 00:20 0.33 DRILL N DPRB PROD1 RBIH from EOT Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/1 2/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 4/10/2004 00:20 - 00:35 0.25 DRILL N DPRB PROD1 Log tie-in down from 12470'. Corr + 11' 00:35 - 01 :05 0.50 DRILL N DPRB PROD1 RIH to TO tagged at 14319' and orient to left. Wiper trip was clean both ways 01 :05 - 04:30 3.42 DRILL N DPRB PROD1 Drill ahead 2.56/3830/60-90R holding 91 deg w/1 00-300 psi diff, 2-5k WOB 04:30 - 05:20 0.83 DRILL N DPRB PROD1 Wiper to EOT 05:20 - 05:50 0.50 DRILL N DPRB PROD1 Recip in liner while displacing 10 bbl ea lolhi vis pills. No excess cuttings noted when sweep circ'd to surface. 05:50 - 06:30 0.67 DRILL N DPRB PROD1 Precautionary ream OH to TO tagged at 14459'. 06:30 - 09:45 3.25 DRILL P PROD1 Drill ahead. 3900 psi @ 2.59 bpm. 200-300 dpsi. TF:30-60L WOB: 2-3K# ROP: 70-90 fph, ECD: 11.41 ppg. Slowed down at 14580'. 10-20 FPH. Having to stack a lot of weight. 09:45 - 11:45 2.00 DRILL P PROD1 Wiper trip to 100' inside tbg tail. Hole smooth. 11 :45 - 15:00 3.25 DRILL P PROD1 Drill ahead. 3900 psi @ 2.59 bpm. 300-400 dpsi. TF:30-60L WOB: 3.5K# ROP: 70-90 fph. ECD: 11.63 ppg. 15:00 - 17:45 2.75 DRILL P PROD1 Wiper trip to 100' inside tbg tail. 17:45 - 22:35 4,83 DRILL P PROD1 Orient to right side. Drill ahead 2.55/3900/80-120R ECD 11.65 wI 100-300 psi diff, 5-15k WOB at 88 deg and starting slow drop to follow plan, Slow drilling due to wt transfer deterioration, GR showing sand 22:35 - 00:00 1.42 DRILL P PROD1 Wiper to EOT, clean 4/11/2004 00:00 - 00:35 0.58 DRILL P PROD1 Reciprocate in 7-5/8" liner while displace 2 15bbl ea lolhi vis pills. Sli incr in solids noted later over shaker 00:35 - 00:50 0.25 DRILL P PROD1 Log down from 12470'. Corr +9' 00:50 - 01 :50 1.00 DRILL P PROD1 RIH thru window, by OH WS and precautionary ream to TO, all clean. Tag at 14905' 01 :50 - 02:50 1.00 DRILL P PROD1 Orient to left. Resume drilling wI good wt transfer 2.56/3820/120L ECD 11.68 100-300 psi diff, 2-4k WOB while continuing slow drop-now at 80 deg. Drilled to 14946' and most of the good out of the wiper is gone-started stacking 02:50 - 05:35 2.75 DRILL P PROD1 Start new mud. Sliding better after new mud back to surface ECD 11.43 05:35 - 09:15 3.67 DRILL P PROD1 Wiper to EOT. Pump lolhi sweep while recip in 7-5/8". RIH to to continue drilling. Geo's noted a change in sample content when sweeps get to surface. Also noted increase in metal filings picked up by sweeps. Small increase in total cuttings volume at shaker with sweeps. 09:15 - 12:45 3.50 DRILL P PROD1 Drilling ahead. 3850 psi @2.65 bpm. 100-300 dpsi. 49k# up, 15k# dn wt. WOB:3-3.5k#. ROP: 1 0-20fph. ECD: 11.44 ppg. TF:85L Erratic drilling, may be in shale. Having to use all available coil down wt. Holding 71 deg inclination. Not seeing much motor work even with 3.5k# down hole WOB. 12:45 - 16:45 4.00 DRILL P PROD1 POOH to check motor & bit, and PU resistivity tool. Clean hole and 7-5/8" with lolhi sweep. Circ ooh at max rate through bit. RIH after tagging up to displace up well. 16:45 - 17:30 0.75 DRILL P PROD1 Get off well. Inspect 100' of coil for wear. Looked okay. 17:30 - 19:15 1.75 DRILL P PROD1 LD drilling assy. Bit 1-3-1, motor tite. Change bit, motor and resistivity Note: Nordic working one man short 19:15 - 21 :25 2.17 DRILL P PROD1 RIH wi BHA #19 (1.5 deg, DS49Xrr) Note: BOPE test frequency extended to 14 days for we1l1-65a Function tested pipeNBR rams on trip in hole. Check CT and no scars Printed: 4/19/2004 12: 1 0:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 411112004 21 :25 - 21 :45 0.33 DRILL P PROD1 Log tie-in down from 12485'. Corr-7' 21 :45 - 00:00 2.25 DRILL P PROD1 Log from 13200' at 600'/hr in OH while precautionary ream to 13815'2.1/3030 Relog from 13700' after MWD PC glitch 4/12/2004 00:00 - 03:00 3.00 DRILL P PROD1 Continue MAD pass and precautionary ream 2.05/2950 at 600'/hr to 14500', 300'/hr to TO tagged at 15090'. Res says wet 03:00 - 05:15 2.25 DRILL P PROD1 Drill from 15090' 2,54/3700/85L ECD 11.5, 100-500 psi diff, 2-4k wob and drill ahead wI neg wt holding 70 deg incl. Stalled at 15110' then took off driling wI pos string wt. Another drilling break at 15124' and got full string wt back. Pickups clean. Samples later showed coal 05:15 - 09:15 4.00 DRILL P PROD1 Wiper while circ up samples. Discuss plan forward with town team. RIH. Smooth all the way to TO. 09:15 - 11 :15 2.00 DRILL P PROD1 Drill ahead, 3700 psi @2.56 bpm, 50-150 dpsi. WOB: 3-3.5k#. TF:80L. Tag btm, Stack a lot of weight. Very slow drilling. Try to stall motor. Unable to stall. 11:15-15:00 3.75 DRILL P PROD1 POOH to change motor and bit. Get off well. Inspect coil (ok). 15:00 - 15:30 0.50 DRILL P PROD1 Un stab coil. Pull mwd. Break off mtr & bit. Motor feels tight, but cannot feel "lobes". Will send to shop for inspection. Bit 3-3-1. Several worn cutters on radius & nose. 15:30 - 16:00 0.50 DRILL P PROD1 MU 1.2 xtreme mtr wI new DS49 bit. Stab coil. Test tools, Get on well. 16:00 - 18:05 2,08 DRILL P PROD1 RIH wI BHA #20 Phz 1 GPB 18:05 - 18:20 0.25 DRILL P PROD1 Log tie-in down from 12470'. Corr -19' 18:20 -19:30 1.17 DRILL P PROD1 Precautionary ream 2.6/3900 to TO tagged at 15162' and hole is clean 19:30 - 21 :00 1.50 DRILL P PROD1 Drill ahead 2.55/3840/90L ECD 11.55 150-300 psi diff, 2-4k wob wI good pos str wt at 66 deg 30'/hr. Drill to 15180' and res tool quit (15126' last data). Geo says drill ahead wI GR while BHI trying a possible fix. GR showing 12 api sand again starting at 15154' 21 :00 - 21 :20 0.33 DRILL P PROD1 Wiper to 15000' to test the waters and attempt to fix res tool 2.53/3700 5k overpull wI MW at 15126', clean on RBIH. Got res tool working 21 :20 - 21 :30 0.17 DRILL N DFAL PROD1 Relog missed data from 15165' at 300'/hr 2.53/3680/80L and still wet 21:30 - 23:15 1.75 DRILL P PROD1 Resume drilling 2.53/3800/85L and make slow, but steady progress and getting close to a final TO Phz 1/2 GPB 23:15 - 00:00 0.75 DRILL P PROD1 Wiper to EOT was clean 4/13/2004 00:00 - 00:30 0.50 DRILL P PROD1 Fin wiper to EOT, clean 00:30 - 01 :30 1.00 DRILL P PROD1 Recip in 7-5/8" w/2 10 bbl ea lolhi vis sweeps. Had a little extra volume of mostly small coal chips circ'd over shaker 01 :30 - 01:45 0.25 DRILL P PROD1 Log tie-in down from 12470'. Corr +2' 01:45 - 03:15 1.50 DRILL P PROD1 Precautionary ream to TO 2.56/3700 and was clean all the way 103:15 - 04:50 to TO tagged at 15249' 1,58 DRILL P PROD1 Drill ahead 2.57/3710/90L ECD 11.54, 100-300 psi diff, 2-5k wob at 67 deg looking for a change in GR or penetration rate to signal TO, but all sand, Goo called TO at 15290' 04:50 - 07:15 2.42 DRILL P PROD1 Wiper to EOT, clean. Circ two lo/hi sweeps in 7-5/8" csg. Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 411312004 07:15 - 07:30 0.25 DRILL P PROD1 Log gr tie in. Add 3' correction, 07:30 - 10:15 2.75 DRILL P PROD1 Pull into tubing tail. CBU, Rest hole at min rate while slowly POOH. ECD: 10.71 ppg. 10:15 - 11:45 1.50 DRILL P PROD1 Orders from town to drill ahead to 15400' to expose more sand for injection. RIH to TO. Set down at 15123'. PU. Run through ok. 11 :45 - 14:30 2.75 DRILL P PROD1 Drill ahead. 3820 psi@ 2.6 bpm. 200-300 dpsi WOB:3-3.5k# TF:80L 48k# up, 16k# dn wt. ECD: 11.45 ROP:50-80 fph. Drilled to TO at 15380' 14:30 - 16:15 1.75 DRILL P PROD1 TOH to above tbg tail at 11988'. Pumped lowlhigh vis sweeps through 7 5/8" annulus. 16:15 - 18:15 2.00 DRILL P PROD1 Circulate at min rate moving pipe slowly above TT. 18:15 - 18:30 0,25 DRILL P PROD1 RIH to Tie-In 18:30 - 18:45 0.25 DRILL P PROD1 Tie-in at 12470' (corrected +6 ft) 18:45 - 20:25 1,67 DRILL P PROD1 RIH to confirm TO at 0,7 bpm and 25 fpm Tagged at 15379 ft 20:25 - 00:00 3.58 DRILL P PROD1 POOH to run liner (Open hole clean) 4/14/2004 00:00 - 00:30 0.50 DRILL P PROD1 POOH. Conducted PJSM while POOH on BHA handling and reel blow down 00:30 - 01:40 1.17 DRILL P PROD1 LD BHI's BHA, fill hole, stab on well to blow down 01 :40 - 03:00 1.33 DRILL P PROD1 Blow down CT 03:00 - 05:00 2.00 DEMOB P COMP Load out BHI tools, pull CT pack to reel and brought in BOT CTLRT's 05:00 - 05:30 0.50 DEMOB P COMP PJSM on Liner handling and running, Reel swap 05:30 - 06:00 0.50 CASE P COMP Running liner as per SOP's 06:00 - 06:20 0.33 CASE P COMP PJSM meeting with oncoming crew members, 06:20 - 11 :00 4.67 CASE P COMP Continue plu of 92jts 2 7/8" and 18jts 31/2" liner. Total length of liner 3383.06' 11 :00 - 11 :35 0,58 CASE P COMP MU CTLRT equipment. 11 :35 - 13:00 1.42 CASE P COMP P/U and position injector. Stab e-free coil to injector, 13:00 - 13:45 0.75 CASE P COMP Install BOT CTC pull test to 45K PT to 3500psi. 13:45 - 14:15 0.50 CASE P COMP Displace methanol from coil to cuttings tank. 14:15 - 15:15 1.00 CASE P COMP Load and pump coil dart 58.7 bbls. 15:15 - 15:40 0.42 CASE P COMP Stab on injector to CTLRTand liner. length = 3392.1' wt 20k with blocks (7k) 15:40 - 17:40 2.00 CASE P COMP RIH with liner. Check wt at 12950' 52k, RIH 16k dwn wt. Tagged bottom at 15398', (normal tie-in corrections have been minus 17'-19') 17:40-18:15 0.58 CASE P COMP Load and launch .625" ball. Displaced with 46.8 bbl, ball seated and released from liner at 4127 psi. PU and string wt = 38k152k 18:15 - 18:25 0.17 CASE P COMP Cir and make ready to swap well bore fluids to 10ppg brine 18:25 - 21 :15 2.83 CASE P COMP Displace well bore to 10ppg brine at 2.00 bpm and 1600 psi wlo LubeTex 21:15 - 21:35 0,33 CASE P COMP PJSM on cementing 21 :35 - 22:30 0,92 CASE P COMP Mixing 50 bbl bozan and batch mixing cement Cement at 15.8 ppg at 2230 hrs 22:30 - 00:00 1.50 CEMT P COMP Pumped 5 bbl 2% KCL, PT to 4500 psi Pumped 5 bbl2% KCL, 30 bbl15,8ppg cement. Cir @ 1:1ratio SO, cleaned lines, dropped dart, pressured up to 500 psi, lanched dart. Pumped 45 bbl Biozan, Caught fluid at 14 bbl pumped Landed dart using 57.9 bbl and sheared @ 3787 psi. Reduced reate with 15 bbl cement behine liner to 1 bpm. Circulate at 1: 1 ratio through entire job, Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 411412004 22:30 - 00:00 1.50 CEMT P COMP Landed dart with 77.1 bbl. Pressured up to 1900 psi, released pressure, floats held. PUH, 38k, POOH replacing CT displacment (0.00548 bpf) 4/15/2004 00:00 - 02:30 2.50 CEMT P COMP POOH 02:30 - 03:00 0.50 CEMT P COMP LD and load out BOT CTLRT 03:00 - 03:15 0.25 CEMT P COMP Safety Meeting on CDL 03:15 - 06:00 2.75 CEMT P COMP Cut + 180 ft drilling line 06:00 - 06:15 0.25 EV AL P COMP PJSM with oncoming crews, 06:15 - 06:55 0,67 EVAL P COMP M/U logging BHA 06:55 - 07:05 0.17 EVAL P COMP PJSM review precautions for handling logging source, 07:05 - 09:55 2.83 EV AL P COMP Load source. P/U 1 1/4" hydril pipe RIH BHA length = 3495.31' 09:55 - 10:10 0,25 EVAL P COMP Stab-on injector. 10:10 - 11 :35 1.42 EVAL P COMP Circulate ,5bpm to clear hydril pipe. Start RIH pumping .4bpm cement UCA >500psi at 1100hrs. RIH to 10000'. 11 :35 - 14:45 3,17 EVAL P COMP Start logging down f/10000' at 30'/min no problem entering liner top. Clean to 15300' slight motorwork to 15350' then setdown. 14:45 - 17:05 2.33 EVAL P COMP Start logging up spot perf pill f/13000'. Paint EOP flag at 11500'. Log to 10000' 17:05 - 18:10 1.08 EVAL P COMP TOH 18:10 -19:00 0.83 EVAL P COMP Stand back injector and make ready to stand back 1-1/4" CSH 19:00 - 21: 15 2.25 EVAL P COMP POOH and stand 1-1/4" CSH in derrick 21:15-22:53 1.63 EVAL P COMP SLB Logs data PBTD @ 15,342.5 ft Pipe Tally @ 15,344.64 ft 3-1/2" X 2-7/8" XO @ 12,561.0 ft Pipe Tally @ 12,563.70 ft TOL @ 11,992.0 ft Pipe Tally @ 11,995.94 ft Fill hole and pressure to test 2000 psi Cement Compressibility @ 2000 psi at 2000 hrs, (19 hrs) 2223 hrs 2067 psi, while shutting in valves, WHP dropped to 1800 psi 2225 hrs P= 1800 psi 2255 hrs (30 min) P = 1200 psi (pressure test failed) Alerted BOT on KB L T packer 22:53 - 23:15 0.37 PERF P COMP Perforating PJSM 23:15 - 00:00 0.75 PERF P COMP PU 2-1/2" Perf Guns and 1-1/4" CSH 4/16/2004 00:00 - 01 :00 1.00 PERF P COMP RIH with 20 jts 1-1/4" CSH, Stab Injector head on well 01 :00 - 03:20 2.33 PERF P COMP RIH and confirmed the well head is open to take returns. Corrected to flag -2.4 ft RIH. Wt check at 12,530 ft = 48k and 21k down. RIH, tagged 3-1/2" X 2-7/8" XO at 12,578.3' Corrected -17 ft to 12,561 ft 03:20 - 04:00 0.67 PERF P COMP PU, dropped 5/8" AI ball, lanched. Displace ball to firing head. Vct = 59.7 bbl Drive-by perforated using 3,325 psi and 56.5 bbls' from 12,487ft to 12,507ft, with 2-1/2" HMX 2506PJ 10.5 gm, 25.2" entry dis, 25.2" pentration 6 spf 04:00 - 04:20 0.33 PERF P COMP POOH, filling hole across top 04:20 - 05:20 1.00 FISH N STUC COMP Pulled tight with bottom of guns at 12,000 ft. Worked CT between 10k down and 68k Normal running wt is 21 k down and 48k up. Present CT has 650,000 running ft 05:20 - 05:36 0.27 FISH N STUC COMP Postion reel for ball drop, Drop 3/4" steel ball. 05:36 - 06:15 0.65 FISH N STUC COMP Displacing ball to disconnect. On seat after 51,5 bbls, Disconnect at 3100psi. P/U free of fish, 06:15 - 08:30 2,25 FISH N STUC COMP TOH paint EOP flag at 6950', Printed: 4/19/2004 12:10:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 411612004 08:30 - 10:00 1.50 FISH N STUC COMP Disconnect was not where we anticipated. Rather than the lower BOT disconnect (3/4" ball) parting it was the SLB upper disconnect (15/16" ball). The 3/4" ball was not on the SLB disconnect seat. Would have to believe it is still on top of the lower disconnect. Fish: see Perf BHA fllower half of SLB disconnect to bullnose 668.01 ' Mean while cutting 200' from end of this coil. Will rehead will BOT CTC and test coil and CTC to 4500psi. 10:00 - 10:20 0.33 FISH N STUC COMP Rehead with BOT CTC and test to 4500psi for 5 min. okay 10:20 - 10:45 0.42 FISH N STUC COMP P/U fishing BHA. 10:45-12:15 1.50 FISH N STUC COMP RIH start adding Lube-Tex to brine system. Investigate alternatives to present fishing assembly. Locate internal pack-off for SLB disconnect. Will change BHA configuration. Continue to add lube-tex while waiting on tools, 12:15-14:00 1,75 FISH N STUC COMP TOH circulating LubTex 14:00 - 14:20 0.33 FISH N STUC COMP Change out BHA's 14:20 - 16:20 2.00 FISH N STUC COMP RIH to 11200'. Check up wt 41000k. Following directions from town establish pressure at .50 bpm 100psi. RIH with charge pump only sting into fish with snorkel tagged at 11355' stack 5k. Bring up pump build pressure to 41 OOpsi releasing lower disconnect allow pressure to bleed to 0 maintaining 5k down weight. P/U no appreciable wt gain. Stab back in plu same wt. 16:20 - 18:10 1.83 FISH N STUC COMP TOH 18:10 -18:41 0.52 FISH N STUC COMP Unstab from well, check fish 18:41 - 19:25 0.73 FISH N STUC COMP Stand back 1-114" CSH and recovered all CSH top part BOT HOC 19:25 - 20:30 1.08 FISH N STUC COMP PU 3-1/8" Fishing BHA #24 20:30 - 22:47 2.28 FISH N STUC COMP RIH 22:47 - 23:45 0.97 FISH N STUC COMP Wt check at 11990 FT = 43k up and 22k. RIH and tagged top of fish at 11,975.8' (uncorrected). Working to get latch into FN wI 2-1/2" GS. Jetting up the top of fish to cleanup. Jars went off 3 times (down) while trying to get in fishing neck. Tried several things to get stabbed in, including PUH 200 ft to change orientation of GS. 3-1/8" X 3-5/8" BHA could be to stiff (00 of tools in 4-1/2" tubing) to stab into the "GS" and its hitting the edge of FN. 23:45 - 00:00 0.25 FISH N STUC COMP POOH 4/17/2004 00:00 - 02:10 2.17 FISH N STUC COMP POOH 02:10 - 03:00 0.83 FISH N STUC COMP LD BOT fishing tools. NOTE: The sleeve for the 2-1/2""GS" colletts was damaged due to tagging the FN. 03:00 - 04:10 1.17 FISH N STUC COMP Wait on new 2-1/2" Hydraulic GSO 04: 10 - 05:00 0.83 FISH N STUC COMP PU 2-1/8" Fishing BHA wol knuckle joint Note: 2-1/8" Knuckle Tensile strength rating of 29k, all other tools are rated to 50k of better 05:00 - 07:20 2.33 FISH N STUC COMP RIH with 2-1/8" Fishing BHA. Up wt wo/pump 41 kat 11850'. 07:20 - 08:00 0.67 FISH N STUC COMP RIH tagged fish wo/pump at 11976' (uncorrected depth) setdown w/3k. P/U no fish. 2nd try with pump 1 bpm setdown 3k shutdown pump p/u no fish, 3rd try again w/pump setdown 5k and jars went off pu no fish. 4th try wo/pump setdown 7k (no jarring action) p/u 47k and latched to fish. Jar down with 5k (under normal RIH wt) jar hit setdown still Printed: 4/19/2004 12: 1 0:34 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1-65/N-25 1-65/N-25 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 3/12/2004 Rig Release: 4/18/2004 Rig Number: Spud Date: 12/13/1995 End: 411712004 07:20 - 08:00 0.67 FISH N STUC CaMP stuck. PU cock jars hit again with 5k still stuck. Hit again w/10k came free. Move fish downhole 10'. P/U to stuck point jarred with 5k twice no movement. Hit w/10k and came free. No extra wt indication but not expecting any either. 08:00 - 10:00 2.00 FISH N STUC COMP TOH Setup trip tank. Filling hole from kill line side. 10:00 - 10:45 0.75 FISH N STUC COMP Recovered guns. But guns Low Order Fired..no perfs. Bottom gun swelled to 2,88" which caused the stuck pipe at the Howco XN nipple's 2,813" 10, Also the bullnose was blown off when guns missed fired staying in the liner, mostly likely coming to rest on the 31/2" x 2 7/8" XO at 12559.75' 10:45 - 12:00 1.25 FISH N STUC CaMP Dicuss options with town engineer. Plan forward: Turn well over to production for further fishinglcompletion operations. Copy of SLB bullnose taken to BOT Fishing. Should be recoverable with wireline using an Itco spear, Short catch grapple or magnet. All tools available from BOT. Basically fishing for 5" long, 2.50" 00 with an 10 of 1.00". The 10 is only +1-3" in depth from the top of bullnose. 12:00 - 13:00 1.00 FISH N STUC COMP Load out BOT fishing tools and KB packer assembly. 13:00 - 14:30 1.50 EVAL N DPRB CaMP Re-test liner lap. Attempted several times. Final test was with all surface valves insolated incl HCR's and inner mud cross valves, Final test pressures: 2000psi intial. 1230psi after 30/min. Bleed off all pressures re-open valves. IA stayed at 340 psi during all testing. Same time held PSJM with plan forward for RDMO to OS #14, 14:30 - 16:50 2.33 DEMOB P CaMP UD 114 jts 1,25" hydril 16:50 - 18:00 1.17 WHSUR P PROD1 M/U MHA stab-on injector RIH to 2200' and freeze protect well with 34 bbls 60/40 methanol 18:00 - 18:30 0.50 WHSUR P PROD1 POOH FP 2000 ft wI MEOH 18:30 - 20:30 2.00 WHSUR P PROD1 OOH, Closed SV (23-1/2 turns) and make ready to blow down CT with N2 & pig PT N2 to 4000 psi, Blowed down CT and N2 surface lines 20:30 - 21 :00 0.50 WHSUR P PROD1 Installed BPV and closed SV 21 :00 - 00:00 3.00 WHSUR P PROD1 NO BOP and remove 2-3/8" CT reel from rig 4/18/2004 00:00 - 02: 15 2.25 DEMOB POST ND BOP's 02: 15 - 03:00 0.75 DEMOB POST Pressure test Tree cap to 5000 psi. Rig Released at 0300 hrs 4/18/2004. Printed: 4/19/2004 12: 1 0:34 PM e e 1-65A/N-27 Endicott Field 50-029-22627 -01-00 203-212 Accept: Spud: Release: 03/14/04 03/17/04 03/27/04 Nordic #2, Accept: Spud: Release: POST RIG WORK 04/23/04 RUN 2.68 LIB SD @ 11983' SLM UNABLE TO WORK THROUGH RUN 2.25 LIB TO 12547' SLM, GET PICTURE OF PERF GUN SUB RUN 1.105 X 13" SPEAR TO 12547' SLM, RECOVER FISH DRIFT WI 2.69" BARBELL, 114" LONG TO 12,547" SLM. WELL S/I ON DEPARTURE. 04/25/04 PERFORATED 12485'-12505' WITH 2.5" 2506 POWERJET, 6 SPF, 25.2" PENE, 0.32" EH, 10.7 GMS. CORRELATED TO SWS MCNL DATED 15-APRIL-2004. 05/07/04 ATTEMPT TO SET 4.5 BBE SSSV (SER# NBB-33) WI OVERSIZE PACKING ON LOCK. 05/08/04 ATTEMPT TO SET 4.5 SSE SSSV. SET DSSSV W/3 SETS OF OVERSIZED PACKING (CONTROL & BALANCE HELD SOLID @ 5000#). 05/09/04 SET 4.5 BBE (W/3 SETS OF OVERSIZED PACKING) (SERIAL # NBB-35) @ 1576' SLM - PERFORMED CLOSURE TEST - GOOD TEST. '\ . BP-GDB Baker Hughes INTEQ Survey Report ~ ObP Company: Field: Site: Well: Wellpath: BP Amoco Endicott End MPI 1-65/N-25 1-65NN-27 Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: End MPI TR-12-16 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0,00 ft Ground Level: 0,00 ft 5979337.49 ft 256681,13 ft Well: 1-65/N-25 1-65/N-25 Well Position: +N/-S 2930.92 ft Northing: 5982195.19 ft +E/-W 2205.03 ft Easting: 258980,06 ft Position Uncertainty: 0.00 ft Wellpath: 1-65NN-27 500292262701 Current Datum: 91 : 65 5/30/1996 09:24 Magnetic Data: 4/1/2004 Field Strength: 57626 nT Vertical Section: Depth From (TVD) ft 41.50 Height 56.00 ft +N/-S ft 0.00 Survey Program for Definitive Wellpath Date: 5/19/2004 Validated: Yes Actual From To Survey ft ft 100.00 9800.00 9858,50 12989.30 12993.40 13110.07 13125,00 15379,00 . IC.. BAKIa Ir.1 U ~",..; L.I\iTEQ Date: 5/19/2004 Time: 10:51:37 Page: 1 Co-ordinate(NE) Reference: Well: 1-65/N-25. True North Vertical (TVD) Reference: 91 : 655/30/1996 09:24 56.0 Section (VS) Reference: Well (O,OON,O.00E,1 06.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 3 Well Centre bggm2003 Latitude: 70 20 Longitude: 147 58 North Reference: Grid Convergence: 38,358 N 30,505 W True -1,86 deg Slot Name: 65 Latitude: Longitude: 70 21 7.180 N 147 57 26.059 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1-65APB1/N-27 13125,00 ft Mean Sea Level 25.71 deg 80.98 deg Direction deg 106.00 Version: Toolcode 6 Tool Name 1 : Gyrodata gyrocompassing m/ (100,OO-900lY.Dgp(t>-MS 2: MWD - Standard (9858,50-13286,00) (1)MWD MWD (12993.40-14599,00) (3) MWD MWD (13125,00-15379,00) MWD Annotation MD ft 13110,07 13125,00 15379,00 TVD ft 10082.67 10082,51 10248,51 TIP KOP TO Survey: MWD Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Gyrodata gyrocompassing m/s MWD - Standard MWD - Standard MWD - Standard Start Date: 4/13/2004 Engineer: Tied-to: From: Definitive Path R,· E.,... Î' ,~ , ...,. \,~ f JUN 0 1 2004 A¡e~:,:a ;t éJ '3 - .:¿ J J... ObP . BP-GDB . II.. BAKM HUGIll. Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 5/19/2004 Time: 10:51:37 Page: 2 Field: Endicott Co-ordinate(NE) Reference: Well: 1-65/N-25. True North Site: End MPI Vertical (fVD) Reference: 91 : 65 5/30/1996 09:24 56.0 Well: 1-65/N-25 Section (VS) Reference: Well (0.00N,O.00E,106.00Azi) Wellpath: 1-65A1N-27 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10Oft 13110,07 91,68 135.75 10082,67 10026.67 -2993,77 6888,28 5978981.50 265768,24 7446,63 0.00 13125,00 89,54 138,53 10082,51 10026,51 -3004,72 6898.43 5978970,24 265778,04 7459.41 23.50 13161,14 93,37 149,13 10081,59 10025,59 -3033.83 6919.72 5978940.45 265798,38 7487,90 31,17 13201,72 92.42 150,01 10079.54 10023.54 -3068,78 6940.25 5978904,86 265817,77 7517,26 3,19 13238,19 89,51 143,28 10078,92 10022.92 -3099,21 6960,28 5978873,80 265836.82 7544,91 20,10 13263,83 86,77 139,08 10079,76 10023.76 -3119,17 6976,34 5978853,33 265852,22 7565,85 19,55 13293,85 86,72 135,83 10081.46 10025.46 -3141,25 6996,60 5978830,62 265871.77 7591.41 10,81 13329,10 89.45 130,97 10082.64 10026,64 -3165.45 7022,19 5978805,61 265896.56 7622,68 15,81 13358,63 91.45 129,69 10082.41 10026.41 -3184,56 7044,70 5978785,79 265918.44 7649,59 8.04 13387.41 91.47 125,24 10081,67 10025.67 -3202,05 7067,53 5978767,57 265940.70 7676.35 15.46 13426,78 87.76 117,98 10081,94 10025.94 -3222,67 7101,03 5978745,88 265973.52 7714.24 20.71 13461,65 88.56 113,97 10083,06 10027,06 -3237,93 7132,36 5978729,62 266004,33 7748.56 11.72 13495,94 90.68 1 09.28 10083.29 10027,29 -3250,57 7164,22 5978715.97 266035,77 7782.67 15.01 13530.74 93.62 105,92 10081,98 10025,98 -3261,08 7197,36 5978704.40 266068,56 7817.42 12.82 13561.36 92.76 101,88 10080,28 10024,28 -3268.42 7227,03 5978696.11 266097,98 7847.97 13.47 13592.78 91.26 99,58 10079,17 10023,17 -3274.27 7257,88 5978689.27 266128,62 7879,23 8.74 13622.60 89,91 103,27 10078,87 10022,87 -3280,17 7287,10 5978682.43 266157,63 7908,95 13,18 13652.97 88.13 105,86 10079,39 10023,39 -3287.81 7316.49 5978673.85 266186,76 7939.30 10.35 13683.05 85.94 110,23 10080.95 10024,95 -3297,11 7345,04 5978663.64 266215,00 7969.31 16.23 13716.19 87,24 114.26 10082,92 10026,92 -3309,63 7375,65 5978650,14 266245,19 8002,19 12,76 13749.15 90.65 117,57 10083,52 10027,52 -3324,03 7405,29 5978634.80 266274.34 8034.64 14.42 13780.53 91.99 121.71 10082,80 10026,80 -3339.54 7432,55 5978618.42 266301,09 8065.12 13.86 13814,62 90.71 127,34 10082,00 10026,00 -3358.85 7460,61 5978598.22 266328,52 8097.42 16.93 13840.90 90.55 129,98 10081,71 10025,71 -3375.26 7481,13 5978581.15 266348,50 8121.67 10.06 13869.67 89.69 127,17 10081,65 10025,65 -3393.20 7503,62 5978562.50 266370.40 8148.24 10.21 13899.42 90,25 122,81 10081,66 10025,66 -3410.25 7527,99 5978544.67 266394.20 8176.36 14,78 13930,24 92.48 120,24 10080.93 10024.93 -3426.36 7554.25 5978527.73 266419,93 8206.04 11.04 13960.84 92.62 117 ,22 10079,57 10023,57 -3441,05 7581,05 5978512.18 266446.25 8235,86 9.87 13990.41 90.61 112,69 10078,73 10022,73 -3453.52 7607,84 5978498.86 266472.62 8265.05 16.75 14020.29 90.40 109,07 10078.47 10022.47 -3464,17 7635,75 5978487,32 266500,17 8294.81 12.14 14057.65 90.12 102,88 10078,30 10022,30 -3474.45 7671,65 5978475,89 266535.72 8332.15 16.59 14089,13 89.60 100,07 10078,38 10022.38 -3480,71 7702,50 5978468,64 266566,35 8363.53 9.08 14121.55 90.80 97,17 10078,26 10022,26 -3485,57 7734,55 5978462,76 266598.23 8395.68 9.68 14152.73 93.97 95,50 10076.97 10020,97 -3489,00 7765,51 5978458.32 266629,06 8426,38 11.49 14184.23 92.88 99,83 10075,08 10019,08 -3493,20 7796,66 5978453,13 266660.06 8457.49 14.15 14216,24 92.06 103,79 10073.70 10017.70 -3499,74 7827.96 5978445,58 266691.13 8489,38 12.62 14248,60 91,90 107,66 10072,59 10016.59 -3508,50 7859.08 5978435,82 266721.95 8521,71 11,96 14289.97 91,35 111,95 10071.41 10015.41 -3522,51 7897.98 5978420,57 266760,38 8562,96 10.45 14320,77 90,58 113,82 10070.89 10014,89 -3534.49 7926,35 5978407,69 266788,35 8593,53 6,57 14350,72 88,74 110,92 10071.07 10015.07 -3545,89 7954.04 5978395.41 266815,66 8623.29 11.47 14381,82 89,54 106.94 10071.54 10015.54 -3555,97 7983.45 5978384,38 266844,73 8654,34 13,05 14411,89 89,82 103,22 10071,71 10015.71 -3563,79 8012.48 5978375,63 266873.49 8684.40 12.41 14442,99 89.45 98.71 10071.90 10015,90 -3569,71 8043.00 5978368,74 266903,81 8715,38 14,55 14469,69 89,11 96,07 10072,24 10016.24 -3573,14 8069.48 5978364.46 266930,15 8741,77 9,97 14490,71 90,21 93,67 10072,36 10016,36 -3574,92 8090.42 5978362,00 266951,03 8762,39 12,56 14520,27 90,64 90.63 10072,15 10016,15 -3576,03 8119,95 5978359.94 266980,51 8791.09 10.39 14550,93 91,08 87,71 10071,69 10015,69 -3575.59 8150,60 5978359.40 267011,16 8820.43 9.63 14580.41 90,03 84.10 10071.40 10015.40 -3573.48 8180,00 5978360,56 267040,61 8848.11 12,75 14611.46 88,77 81.43 10071,72 10015,72 -3569.57 8210,80 5978363.47 267071,51 8876,64 9,51 14640,88 88,53 78.51 10072.42 10016.42 -3564.45 8239,76 5978367,66 267100,62 8903,06 9,96 14672,21 89,14 78.16 10073,05 10017,05 -3558,12 8270.44 5978373,00 267131.48 8930,80 2.24 14702,58 88,18 77.89 10073,77 10017,77 -3551,82 8300,14 5978378.34 267161,37 8957.62 3.28 14734,29 84,84 85,52 10075,70 10019,70 -3547.25 8331 .43 5978381.90 267192,79 8986.44 26,22 ObP . BP-GDB . _íí. IIAICDt IUGIIIS Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 5/19/2004 Time: 10:51:37 Page: 3 Field: Endicott Co-ordinate(NE) Reference: Well: 1-65/N-25, True North Site: End MPI Vertical (TVD) Reference: 91 : 65 5/30/1996 09:24 56.0 Well: 1-65/N-25 Section (VS) Reference: Well (0.ooN,O.00E,106.00Azi) Wellpath: 1-65A1N-27 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 14767,30 84,75 87,77 10078,69 10022,69 -3545.33 8364,24 5978382.77 267225,65 9017.45 6.79 14802,00 84,90 90.90 10081.82 10025,82 -3544.93 8398,79 5978382,06 267260,20 9050,55 8,99 14835.48 84,90 95,28 10084,80 10028.80 -3546,73 8432.09 5978379,19 267293.41 9083,05 13.03 14871,14 84,26 100,21 10088,17 10032,17 -3551,51 8467,25 5978373.28 267328.40 9118.17 13.88 14901,79 84.21 103,46 10091,25 10035.25 -3557,76 8497.09 5978366.07 267358,03 9148,58 10.55 14932,03 81,17 102.80 10095,10 10039,10 -3564.58 8526,30 5978358.32 267387,00 9178,54 10,28 14967.25 77.27 99.64 10101.69 10045,69 -3571.31 8560,23 5978350,50 267420.69 9213,00 14,15 14997,22 75,04 98,13 10108.86 10052.86 -3575,81 8588.97 5978345.08 267449,28 9241.88 8.90 15030,52 71,08 91,75 10118,57 10062.57 -3578,57 8620,68 5978341.30 267480,88 9273.12 21.84 15059.42 70.22 88.42 10128,15 10072.15 -3578,61 8647.94 5978340,38 267508,13 9299,34 11.27 15097,75 68.65 74.85 10141,66 10085,66 -3573.43 8683,35 5978344.42 267543.68 9331,94 33,39 15130.03 65.99 71.98 10154.11 10098,11 -3564.93 8711,89 5978351,99 267572.48 9357,03 11,63 15168,85 67,36 65.08 10169.50 10113.50 -3551,89 8745.03 5978363,97 267606.02 9385.30 16.70 15202,09 67,11 60,99 10182,37 10126.37 -3537.99 8772,34 5978376.98 267633,76 9407.72 11.37 15231,55 67,61 53,65 10193,72 10137,72 -3523,32 8795.21 5978390.90 267657,09 9425.65 23,06 15259,70 67.79 51,25 10204.40 10148.40 -3507.45 8815,85 5978406.10 267678.23 9441,13 7,91 15291,93 67.48 44.18 10216,68 10160,68 -3487.41 8837,89 5978425.42 267700.90 9456,78 20,31 15319.26 68.67 41.46 10226.89 10170,89 -3468,82 8855,12 5978443.45 267718,71 9468,22 10.21 15349,58 68,83 36.12 10237.88 10181.88 -3446,80 8872.81 5978464.88 267737,11 9479.16 16.42 15379,00 68,83 36.12 10248,51 10192.51 -3424,64 8888.98 5978486.51 267753,98 9488.60 0,00 BP Amoco WELLPATH DETAILS 1-65A1N·27 500292262701 Parent WeUpath: 1-65APB1IN·27 Tie on MD: 13125,00 Rig: Nordic 2 Ref. Datum: 91 : 65 513011996 09:24 56,OOft V.Section Origin Onglo Starting Angle +NI-S +E/·W From ND 106.00" 0,00 0,00 41,50 REFERENCE INFORMATION Co·ordinate tN/Ej Reference Well Centre' 1-65/N·25, True North Vertical ( VD Reference: System: Mean Sea Level Section (VS) Reference: Slot· 65 (O,OON,O.OOE) Measured Depth Reference: 91 : 65 5/30/1996 09:24 56,00 Calculation Method: Minimum Curvature At .TJO TARG!i.TO€TAILS ·NI-$ Sl>ap~ ND MD Azimuths to True North Survey: MWD (1-65/N-25/1-65NN-27) Magnetic North: 25,71" Created By: Digital Business Client UserDate: 5/19/2004 Magnetic Field Strength: 57626nT Dip Angie: 80,98° Date: 4/1/2004 Model: bggm2003 T 1-65fN-25 (1-65/N-2:;) 1-$5/N-25 (1~65/N-2 ~PH) 1-65/N;25 (1-65APB 1/N-27) 1-65A1N-27 MWO 1 0 ;5.Q...AM.- ¡ IJ 1: ~ 41 i! I- ~" ObP . BP-GDB Baker Hughes INTEQ Survey Report \ Company: Field: Site: Well: Wellpath: BP Amoco Endicott End MPI 1-65/N-25 1-65APB1/N-27 Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: End MPI TR-12-16 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0,00 ft Ground Level: 0.00 ft 5979337.49 ft 256681,13 ft Well: 1-65/N-25 1-65/N-25 Well Position: +N/-S 2930,92 ft Northing: 5982195,19 ft +E/-W 2205,03 ft Easting: 258980,06 ft Position Uncertainty: 0,00 ft Wellpath: 1-65APB1/N-27 500292262770 Current Datum: 91 : 65 5/30/1996 09:24 Magnetic Data: 4/1/2004 Field Strength: 57626 nT Vertical Section: Depth From (TVD) ft 41,50 Height 56,00 ft +N/-S ft 0,00 Survey Program for Definitive Wellpath Date: 4/1/2004 Validated: Yes Actual From To Survey ft ft 100.00 9800,00 9858.50 12989,30 12993.40 14599.00 . B.. BAKD IIUGIIIS IN'TEQ Date: 5/19/2004 Time: 10:52:51 Page: 1 Co-ordinate(NE) Reference: Well: 1-65/N-25, True North Vertical (TVD) Reference: 91 : 65 5/30/1996 09:24 56.0 Section (VS) Reference: Well (O.OON,O.OOE, 113. 76Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 3 Well Centre bggm2003 Latitude: 70 20 Longitude: 147 58 North Reference: Grid Convergence: 38,358 N 30,505 W True -1,86 deg Slot Name: 65 70 21 7,180 N 147 57 26,059 W Latitude: Longitude: Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0,00 1-65/N-25 12993.40 ft Mean Sea Level 25,71 deg 80,98 deg Direction deg 113,76 Version: Toolcode 5 Tool Name 1 : Gyrodata gyrocompassing m/ (100.00-99GIY.fXXþ(D-MS 2: MWD - Standard (9858.50-13286.00) (1)MWD MWD (12993.40-14599.00) MWD Annotation MD ft 12989,30 12993.40 14597.00 TVI> ft 10087.42 10087.48 9982,04 TIP KOP TO Survey: MWD CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Gyrodata gyrocompassing m/s MWD - Standard MWD - Standard Start Date: 3/22/2004 Engineer: Tied-to: From: Definitive Path ;(tJ1- ~/;t ObP . BP-GDB . B¡¡. ... BAKØ HUGHH Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 5/19/2004 Time: 10:52:51 Page: 2 Field: Endicott Co-ørdinate(NE) Reference: Well: 1-65/N-25. True North Site: End MPI Verôcal (TVD) Reference: 91 : 655/30/199609:2456.0 Well: 1-65/N-25 Secôon (VS) Reference: Well (0.00N,O,OOE,113. 76Azi) Wellpath: 1-65APB1/N-27 Survey Calculaôon Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 12989.30 89,20 123.20 10087.42 10031.42 -2916,96 6795.62 5979061.25 265678,10 7394,89 0,00 12993.40 89,21 123.28 10087.48 10031,48 -2919,20 6799,04 5979058,90 265681.46 7398.94 1,97 13020,17 90,25 126.80 10087,61 10031.61 -2934,57 6820,96 5979042,83 265702,86 7425.18 13,71 13050,70 93,60 129,80 10086,58 10030.58 -2953.48 6844,90 5979023,17 265726,18 7454.71 14.72 13080,32 94,92 133,00 10084,38 10028.38 -2973,01 6867,05 5979002,94 265747,70 7482,86 11.66 13110,07 91,68 135,75 10082,67 10026,67 -2993.77 6888,28 5978981.50 265768,24 7510,65 14.27 13140.14 87.37 141,36 10082,92 10026,92 -3016.30 6908,17 5978958,35 265787.40 7537,93 23,52 13177.47 89.10 150.24 10084,07 10028,07 -3047,13 6929,12 5978926,86 265807.34 7569,52 24,22 13205.63 90.88 152.18 10084,07 10028,07 -3071,80 6942,68 5978901,76 265820.10 7591.87 9,35 13235.46 87,28 155.04 10084.55 10028,55 -3098,52 6955,93 5978874,64 265832.49 7614.76 15.41 13271,89 85,20 147,63 10086,94 10030.94 -3130,39 6973,35 5978842,22 265848,88 7643,55 21.08 13305,94 86,79 143,74 10089,32 10033,32 -3158.44 6992,50 5978813.57 265867,11 7672,37 12.32 13339,06 88,18 140,66 10090,78 10034,78 -3184.58 7012.78 5978786.80 265886,53 7701.46 10,19 13371.45 88,08 132,55 10091,84 10035,84 -3208,08 7035.00 5978762,59 265907,99 7731,27 25,03 13399,60 89.33 130,16 10092.47 10036.47 -3226,67 7056,12 5978743.33 265928.50 7758,09 9,58 13426.69 91,71 126.10 10092.23 10036.23 -3243.40 7077.42 5978725,93 265949,25 7784,32 17,37 13460.84 92,74 118.09 10090,90 10034.90 -3261,51 7106,31 5978706,89 265977,54 7818,06 23.63 13494,26 92.98 110.04 10089,23 10033.23 -3275,11 7136,76 5978692,32 266007,54 7851.41 24.07 13523,24 93,16 104.55 10087,67 10031.67 -3283,71 7164,38 5978682,84 266034,86 7880,15 18,93 13548,33 95,75 103.14 10085,73 10029.73 -3289,70 7188.66 5978676.08 266058,94 7904,79 11.75 13577.41 96,65 105,00 10082,59 10026,59 -3296,72 7216.70 5978668.15 266086,74 7933.29 7,07 13603.49 94.52 100,58 10080,05 10024,05 -3302.4 7 7242.01 5978661.60 266111.85 7958.76 18,74 13633,91 93.75 99.08 10077,85 10021,85 -3307,65 7271,90 5978655.46 266141.56 7988,21 5,53 13671.49 94.66 90,18 10075.09 10019,09 -3310.67 7309,22 5978651,24 266178.76 8023.58 23,74 13707.44 99.05 95.29 10070.80 10014.80 -3312,37 7344,85 5978648.40 266214,32 8056,88 18.66 13737,95 98,39 1 02.46 10066,17 10010.17 -3317,02 7374,63 5978642,79 266243,93 8086,01 23.33 13766.41 94,71 108,70 10062.92 10006.92 -3324,61 7401,84 5978634,32 266270,88 8113,97 25,33 13798,54 96,10 115.52 10059,89 10003,89 -3336.64 7431.46 5978621.35 266300,10 8145,93 21.57 13835,13 97,66 117,62 10055,50 9999,50 -3352.89 7463.95 5978604,07 266332,04 8182.21 7.12 13876,44 97,99 126,82 10049,87 9993,87 -3374.68 7498,53 5978581,17 266365,91 8222,64 22,08 13905.00 97.05 132.40 10046,13 9990,13 -3392.73 7520,34 5978562.43 266387.12 8249,87 19,65 13934.84 96.40 135,35 10042,63 9986,63 -3413.26 7541.70 5978541,22 266407.81 8277.69 10,06 13967.51 95.17 130.90 10039,34 9983,34 -3435.48 7565.41 5978518,26 266430,80 8308,35 14,06 13998.15 95,23 125.18 10036,56 9980.56 -3454,27 7589,44 5978498,70 266454,20 8337.91 18.59 14036,87 96,09 115.65 10032,73 9976.73 -3473,76 7622,62 5978478,16 266486.74 8376.13 24.59 14065,79 95,19 112.23 10029,89 9973.89 -3485.43 7648,92 5978465,64 266512,65 8404.91 12.17 14094,05 94,44 105,92 10027,51 9971.51 -3494,63 7675,53 5978455,59 266538,94 8432,96 22.41 14125,51 94,72 10Q.48 10025.00 9969,00 -3501.79 7706,04 5978447.46 266569,22 8463,77 17,26 14159,72 94,99 95,87 10022,10 9966,10 -3506.64 7739.78 5978441.53 266602,77 8496,60 13,45 14193,62 95,67 89,54 10018,95 9962,95 -3508.23 7773.47 5978438.85 266636.40 8528,09 18,70 14221.82 97.99 90,52 10015,60 9959,60 -3508,24 7801.47 5978437,94 266664,38 8553,72 8,92 14250.94 98,66 95.26 10011,38 9955,38 -3509,69 7830.24 5978435.56 266693,09 8580,63 16.27 14282.58 98,77 102,38 10006,58 9950,58 -3514.49 7861.12 5978429,78 266723.80 8610.83 22,25 14319,51 100,18 109,54 10000.49 9944.49 -3524.49 7896,12 5978418,66 266758.46 8646.89 19,50 14357,11 98.46 115.88 9994.40 9938.40 -3538,81 7930,33 5978403,24 266792.19 8683,97 17,26 14388,80 96,18 114.24 9990.36 9934.36 -3552,12 7958,80 5978389,02 266820,21 8715.39 8.84 14415,93 94,05 109,67 9987,94 9931.94 -3562.22 7983,85 5978378,12 266844,93 8742,39 18.52 14445,70 92,44 103,56 9986,25 9930,25 -3570,71 8012,32 5978368.72 266873,11 8771,87 21,19 14476,27 92.76 99,63 9984,87 9928,87 -3576.85 8042,23 5978361.62 266902,80 8801,71 12,89 14513.12 92.45 98,81 9983,19 9927,19 -3582.75 8078.57 5978354,56 266938,93 8837,35 2.38 14544,84 90.40 96.50 9982.40 9926.40 -3586,97 8109.99 5978349,33 266970,20 8867,81 9,73 14597,00 90.40 96.50 9982,04 9926.04 -3592,88 8161,81 5978341,76 267021.80 8917.62 0,00 14599,00 90.40 96,50 9982,02 9926.02 -3593,10 8163,80 5978341.47 267023.78 8919.53 0,00 . . . RT, ELEV = 56,00' BF, ELEV = 15,00' MAX DEV = 90 DEG. (12770-13285) HORIZONTAL COMPLETION END 1..65AfN"27 TREE: COOPER 4-1/16" 5000 psi INELlJ-ŒAD:FMC SSH 13 5/8" 5000 psi 10 3/4" 45,5#1ft l:80 BTC CSG I 5212' I 0.... H ES 'HXO' SVLN 3,813" MIN, ID 1569 .....~ ì. '. 4112 "12,6 #/FT NSC T 13 CRBO GLM'sHES MBX9CR1"BK lJI.TCH NO Tv'DSS MD #6 3563 4133 #5 5197 6237 #4 6236 7547 :fIB 6956 8462 #2 7639 93:35 L I ......- ______4112" 'X' NIP P LE :3,813" ID 11930 #1 8323 10209 2S t2h ........7·518" BAKER S·3 PACKER 11941 P .. .." 4112" 'X'NIP..P ,LE:3. ..8,,1,3 ID ~ . .4112". 'XN' NIPPLE, . . ~ ' . MILLED aUHO"," -....;,.~ ",..41I2"WLEG 11965 11975 11988 o HO\ßJCO XN NIPPLE 2,8131D -12002 Z.... BAKE R "SBP" LINE R TOP PKR -12517 DEV= 74 deg. -.¡-31I2X27I8X-OVER 12500 1 t8: 75.B" 29 #ltt NT95H S N SCC 4112" 12,6# L-80 N SCT 12721 - _ - 2718 5,5# 1:3Cr STL LINER 2.372 ID CTD SIDETRACK INFO BAKER WHIPSTOCK 12990 MD'TOW 89 DE G. "RA" PIP @ 13000' MD 2718" 5.5# 1:3 Cr STL FROM 12551 . 15341 ~ ~, PERFORATION SUMMARY REF LO G: ATLA.S SBT/GR 1/18/96 CO SIZE SPF IN TERVAL STATUS 5 12488.12508 SOZD 6 12504-12524 SOZD 6 12730-13100 SOZD SWS 2,5 6 12485-12fo$ OPEN K-1 CEMENT RETAINER "----7 @13010 TD @MD 15375 41/2" 12,6#1ft L·80 NSCT 63/4" BIT SIZE 13285 DATE COMMENTS ENDICOTT WELL 1-65A/N-25 API NO: 50-029-22627-00 COMPLETION DIAGRAM BP EXPLORATION 1130/95 TLR COMPLETION 12/15/99 4/20/01 TP MAS Add Perfs CEMENT RETAINER 4/18/04 WRR NORDIC 2 CTD SIDETRACK · STATE OF ALASKA . ALASKA O~AND GAS CONSERVATION COM . SION , APPLICATION FOR SUNDRY APPROVAL~61\-~{Z-Iz.ott)ý- 20 MC 25.280 ~ ì~ r/ z /1- 1. Type of Request: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P,O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): o Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate o Plug Perforations 0 Stimulate o Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: r8I Development 0 Exploratory o Stratigraphic Test 0 Service o Waiver o Time Extension o Annular Disposal 5. Permit T,9'Drill Number 203-212/304-098 6. API Number: ,/ 50-029-22627-01-00 IS! Other Re-Enter Ops Shutdown /' 99519-6612 KBE = 56 9. Well Name and Number: END 1-65A1N-27 /' 8. Property Designation: 10. Field I Pool(s): ADL 047502 Endicott Field I Endicott Pool PRESENTWELLCoNOtnoN SOMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): I Effective Depth TVD (ft): 14599 9927 13302' 10089 Plugs (measured): None Junk (measured): 13302' Structural Conductor 60' 30" 60' 60' Surface 5169' 10-3/4" 5212' 4437' 5210 2480 Intermediate 12680' 7-5/8" 12721' 10084' 8180 5120 Production Liner 768' 4-1/2" 12517' - 12990' 10058' - 10087' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 12488' - 13010' 10049' - 10088' Packers and SSSV Type: 7-5/8" Baker 'S-3' packer 4-1/2" HES 'HXO' SSSV Landing Nipple Tubing Size: 4-1/2" Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 11941' 1570' Tubing MD (ft): 11987 12. Attachments: r8I Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title CT Drilling Engineer 13. Well Class after proposed work: o Exploratory r8I Development 0 Service April 4, 2004 /' Date: 15. Well Status after proposed work: r8I Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Ted Stagg, 564-4694 Phone 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness ¿ o Plug Integrity ŒI BOP Test 0 Mechanical Integrity Test 0 Location Clearance rest BorE to '\<;"00 'PSI: . Other:' ''t r.. ,") r D z.. O!- "2- t '- J St'c' f u./Ci..- Þ 'cï~ r; Sundry Number: ..3 C' '!- / /?1 REfEIVED '1' fp R'1..: 1 2004 Alaska Oil & :~~;:~~mmiSSio~n BY ORDER OF 1ì!J // COMMISSIONER THE COMMISSION te ~ tJ y- n Q , G 1 t\! A L bmit n Duplicate ßgØZS.6Þ¿ L/-tJ~ x:?ý . . Endicott 1-65A Re-entry Summary /' On March 27, 2004, Nordic 2 released from Endicott 1-65A sidetrack due to a stuck drilling assembly. An Operation Shutdown, Form 10-403, was filed on March 29,2004:"" Plans are now in place to resume the 1-65A sidetracking operation upon completion of the Endicott 2-36 workover currently in progress. Summary of 1-65A Re-entry plan: , 1. MIRV Nordic 2 and test BOPE. /' 2. Rill with motor and mill to clean out to approx. 200 ft beyond the window and displace to 10.0 ppg PIo-Pro. /' 3. Set an open hole aluminum billet at approx. 13,125' MD (10,025ss). 4. Kick off billet and drill per re-drill directional plan (attached). 5. Complete with cemented and perforated liner per original plan. / Note: All previous wellbore below the aluminum billet will be re-named 1-65PB1. The re-entry drilling operation will proceed under the original Permit to Drill, 203-212. r~ Please direct any questions to Ted Stagg, 564-4694 ObP I BP-GDB . Ba er Hughes INTEQ Planning Re rt ... BAKIII IllIG". INTEQ \. ~~:~~~Y~-~~d~~ -------' -- I Site: End MPI I Well: 1-65/N-25 ! ~e~~a~~.!la~!1~_~-65~=~7 _ ______ _u__. ~ ---~._..~ -..- '~-~~--~--' ____.~._._....._...-~--.-~_._.____.__~~_._-~____-m.-'-_._-,___~__----c_._..........,.____ '---..,------,---" ,..-....-- '..-'-.-'- Date: 4/1/2004 Time: 12:29:33 Page: Co-ordinate(NE) Reference: Well: 1-65/N-25. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E.106.00Azi) ,__ _s.1l.':"!y_Calc.!~at.ï.~n~_~tb_ocJ.~___ _~~r1i.":l~rT1_CI.I.r\fa_tlJr'E___ Db: Or.a:c~e_._.J - -- Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 3 Well Centre bggm2003 __ - ._..__....__....._._._____..._n__n____ Site: End MPI TR-12-16 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground 0.00 ft 5979337.49 ft Latitude: 70 20 38.358 N 256681.13 ft Longitude: 147 58 30.505 W Nortb Reference: True Grid Convergence: -1.86 deg "_. ------_._.~.._.._---_._-----_.. --- - - ---- - ----_._._-~ . -----------------------, Slot Name: 65 5982195.19 ft Latitude: 70 21 7.180 N 258980.06 ft Longitude: 147 57 26.059 W ____n·_____ __,..._______ ,-._------------------ 1-65/N-25 1-65/N-25 Well Position: +N/-S 2930.92 ft Nortbing: +E/-W 2205.03 ft Easting: Position Uncertainty: 0.00 ft - - ---------.'-"-- --..-------------- Wellpatb: Plan#10 1-65A1N-27 500292262701 Current Datum: 91 : 655/30/199609:24 Magnetic Data: 4/1/2004 Field Strengtb: 57626 nT Vertical Section: Deptb From (TVD) ft 41.50 Height 56.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 1-65APB 1/N-27 13110.07 ft Mean Sea Level 25.71 deg 80.98 deg Direction deg ----------~----------,_._-,- 106.00 --------.--",-.----- +N/-S ft - ---~-_._-~-_.__._-------- 0.00 Targets 1-65A1N-27 Polygon7.1 0.00 -3058.86 7058.20 5978910.98 265935.98 70 20 37.064 N 147 53 59.852 W -Polygon 1 0.00 -3058.86 7058.20 5978910.98 265935.98 70 20 37.064 N 147 53 59.852 W -Polygon 2 0.00 -3193.30 6953.47 5978779.98 265826.98 70 20 35.743 N 147 54 2.916 W -Polygon 3 0.00 -3680.52 7887.66 5978262.98 266744.98 70 20 30.942 N 147 53 35.639 W -Polygon 4 0.00 -3623.79 9059.48 5978281.98 267917.98 70 20 31.487 N 147 53 1.405 W -Polygon 5 0.00 -3365.82 8961.13 5978542.98 267827.98 70 20 34.025 N 147 53 4.269 W -Polygon 6 0.00 -3358.93 7776.25 5978587.98 266643.98 70 2034.106 N 147 53 38.884 W -Polygon 7 0.00 -3167.33 7231.79 5978796.98 266105.98 70 20 35.996 N 147 53 54.784 W 1-65A1N-27 Fault 1 0.00 -3056.84 6810.00 5978920.98 265687.98 70 20 37.086 N 147 54 7.104 W -Polygon 1 0.00 -3056.84 6810.00 5978920.98 265687.98 70 20 37.086 N 147 54 7.104 W -Polygon 2 0.00 -3247.91 7681.63 5978701.98 266552.98 70 2035.199 N 147 5341.645 W 1-65A1N-27 Fault 2 0.00 -3345.88 7031.42 5978624.98 265899.98 70 20 34.242 N 147 54 0.643 W -Polygon 1 0.00 -3345.88 7031.42 5978624.98 265899.98 70 20 34.242 N 147 54 0.643 W -Polygon 2 0.00 -3298.54 7880.37 5978644.98 266749.98 70 20 34.699 N 147 53 35.840 W 1-65A1N-27 T10.4 10015.00 -3542.91 7873.22 5978400.98 266734.98 70 20 32.296 N 147 53 36.056 W 1-65A1N-27 T10.5 10015.00 -3509.56 8163.31 5978424.98 267025.98 70 20 32.620 N 147 53 27.581 W 1-65A1N-27 T10.6 10025.00 -3493.23 8359.89 5978434.98 267222.98 70 20 32.779 N 147 5321.838 W 1-65A1N-27 T10.1 10028.00 -3044.98 6927.88 5978929.04 265806.17 70 20 37.202 N 147 54 3.660 W 1-65A1N-27 T10.3 10034.00 -3353.03 7430.87 5978604.98 266298.98 70 2034.167 N 147 53 48.973 W 1-65A1N-27 T10.2 10047.00 -3257.67 7098.62 5978710.98 265969.98 70 2035.108 N 147 53 58.677 W 1-65A1N-27 T10.7 10048.00 -3559.47 8540.12 5978362.98 267400.98 70 2032.125 N 147 53 16.575 W 1-65A1N-27 T10.8 10150.00 -3517.41 8789.91 5978396.98 267651.98 70 20 32.536 N 147 53 9.276 W ObP Company: Field: Site: Well: Wellpath: Targets Annotation MD ft 13110.07 13125.00 13150.00 13175.00 13200.00 13285.00 13408.00 13628.00 13898.00 14200.00 14300.00 14550.00 14800.00 14875.00 15265.00 I BP-GDB . Ba er Hughes INTEQ Planning R~rt ... 8AICa IIIUG... INTEQ BP Amoco Endicott End MPI 1-65/N-25 Plan#10 1~65A1N;'27 Date: 4/1/2004 Time: 12:29:33 Page: Co-ordinate(NE) Reference: Well: 1-65/N-25, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N.0.OQE.106.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 2 - --~.-.".'...-.-..-.-'.-.-.-.". ~_._._--- - "-"..- . -. --.......-.- ,...,...... ....-... --~-_._- Name TVD ft 10026.67 10026.51 10026.00 10024.48 10023.49 10032.80 10046.81 10041.26 10027.41 10016.64 10015.54 10014.89 10024.60 10030.44 10151.19 .- -'--'----'--'---'--- ~_. ~~... .. "'M~p"" ·'-M~p--_..·~~n~ L~tit;de"=:";'''Z:'' L~~g¡~d;~~;'l +E/-W Northing Easting Deg Min Sec Deg Min Sec I' ft ft ft Description TVD +N/-S Dip. Dir. ft ft ~ -- ._--_.~ .---.-.' ._"-~----_.,.-.- .'" ",,',.. _.._._--"----~.,_._------"-'-._-----~---"-~~ . .__._----_.~--~.._-~---"_..."~-,_._--_.- TIP KOP 3 4 5 6 7 8 9 10 11 12 13 14 TO ------- ------------------- Plan #10 AI billet OH sidetrack Yes Date Composed: Version: Tied-to: 4/1/2004 2 From: Definitive Path - - - - - ---- -- _' ________n__ Plan Section Information ----.-.'---.--.-..------ ____._'"··,·_._....______.___~-_.__.__.."'M.--..---.--~----c---....-'--------..._...__.._._~__...~_._ -- --- _.~----------_.-~ -~~~---~~·----l MD Inel Mm TVD +N/.s +E/-W DLS Build Turn TFO Target I I ft deg deg ft ft ft deg/100ft deg/10Oftdeg/100ft deg - -. ~---,- . .. -.-.'- '.M .._._____'--___c-._.." .-___00· _ _. _ '~--'-----'.'..~ ...~ ._--,.~--_._---_._----.._--.._---..""._----._. . ...·'·0." ·,.,___·~_~.,,_._,,·o _._._,----"-~.~.---=---~_.._.- _.;--------"-...--~~""--~-"--'-------' 13110.07 91.68 135.75 1 0026.67 -2993.77 6888.28 0.00 0.00 0.00 0.00 13125.00 89.54 138.53 10026.51 -3004.72 6898.43 23.50 -14.33 18.62 127.57 13150.00 92.79 141.26 10026.00 -3023.83 6914.53 17.00 13.02 10.93 40.00 13175.00 94.16 145.03 10024.48 -3043.79 6929.49 16.00 5.44 15.07 70.00 13200.00 90.40 146.40 10023.49 -3064.43 6943.56 16.00 -15.04 5.47 160.00 13285.00 77.01 144.00 10032.80 -3133.65 6991.65 16.00 -15.75 -2.83 -170.00 13408.00 89.96 129.05 10046.81 -3221.74 7075.46 16.00 10.53 -12.15 -50.00 13628.00 92.84 93.95 10041.26 -3301.12 7276.87 16.00 1.31 -15.95 -85.00 13898.00 92.76 137.21 10027.41 -3414.80 7514.35 16.00 -0.03 16.02 89.00 14200.00 91.09 88.88 10016.64 -3529.41 7783.93 16.00 -0.55 -16.00 -91.00 14300.00 90.16 104.86 10015.54 -3541.33 7882.88 16.00 -0.92 15.97 93.20 14550.00 90.12 64.86 10014.89 -3519.38 8126.85 16.00 -0.02 -16.00 -90.00 14800.00 85.60 104.64 10024.60 -3496.85 8370.57 16.00 -1.81 15.91 97.00 14875.00 85.49 116.68 10030.44 -3523.18 8440.41 16.00 -0.15 16.05 91.00 15265.00 61.44 55.77 10151.19 -3513.10 8791.07 16.00 -6.17 -15.62 -120.00 Survey MD VS ft ft ft 13110.07 91.68 135.75 10026.67 -2993.77 6888.28 5978981.50 265768.24 7446.63 0.00 13125.00 89.54 138.53 10026.51 -3004.72 6898.43 5978970.24 265778.04 7459.41 23.50 13150.00 92.79 141.26 10026.00 -3023.83 6914.53 5978950.61 265793.51 7480.15 17.00 13175.00 94.16 145.03 10024.48 -3043.79 6929.49 5978930.18 265807.82 7500.04 16.00 13200.00 90.40 146.40 10023.49 -3064.43 6943.56 5978909.10 265821.22 7519.25 16.00 13225.00 86.46 145.70 10024.18 -3085.16 6957.51 5978887.94 265834.50 7538.37 16.00 190.00 MWD 13250.00 82.52 145.00 10026.58 -3105.62 6971.66 5978867.03 265847.98 7557.61 16.00 190.02 MWD 13259.90 80.96 144.72 10028.00 -3113.64 6977.30 5978858.84 265853.36 7565.24 16.00 190.09 13275.00 78.58 144.29 10030.68 -3125.73 6985.92 5978846.47 265861.59 7576.87 16.00 190.13 MWD 13285.00 77.01 144.00 10032.80 -3133.65 6991.65 5978838.37 265867.06 7584.55 16.00 190.20 6 13290.48 77.57 143.31 10034.00 -3137.96 6994.81 5978833.97 265870.08 7588.78 16.00 310.00 ObP . BP-GDB . B er Hughes INTEQ Planning R rt . .";,,,,.,,,,,,,,,.,..,,,,.,,-.-----.--- INTEQ --- ---- ---_.__..-.._._----~---_._--~_._------- _.__._______ __._m_______ Ul Company: BP Amoco Date: 4/1/2004 " . Time:." '12:29:33 .', rage: 3 ! Field: Endicott Co-ordinate(NE) Referelce: Well:1-65/N-25, True North i Site: End MPI Vertical CTVD) Reference: System: Mean Sea Level Well: 1-65/N-25 Section (VS)Rêference: Well,(O.OON,O.OOE, 106.00~i) Wellpath: Plan#10 1-65NN-27 surveY CakulationMétho.d: Minimum Curvature Db: Oracle - -- - '_._-_..._._._-_.,,~ " -~'-"-"-'-~-"..._- "' __ ___ -','______.___m ._·"u _',,_ _"___ - ~..'"'____"__._~_"~_____~____~..___.___""'_,_.__~.,._ "_______" ______ ___._m -_'_'~~----------'---'_'--- - ---'-~.'-"- ~ ------ --~-" Survey .___.____m__.___,,__ --- --- ._------,-..-,--_. --------------,-------,,- ----~-------- ----------_.._----,--- ---,-----------------------..--'--,-----.---.-.--'-- -_._...,-----,- -~'---'- ---1 MD lncl Azim SysTVD N/S EIW M:apN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg --'. .'. --. '_.~,-~,+~ .-- -"'- n___'___<_,,____..'___,_._.,__~'.._.. 13300.00 78.56 142.12 10035.97 -3145.37 7000.46 5978826.38 265875.48 7596.25 16.00 310.15 MWD 13325.00 81.16 139.04 10040.37 -3164.38 7016.08 5978806.88 265890.49 7616.51 16.00 310.40 MWD 13350,00 83.80 136.00 10043.64 -3182.65 7032.82 5978788.08 265906.63 7637.64 16.00 310.94 MWD 13375.00 86.44 132.99 10045.77 -3200.10 7050.58 5978770.06 265923.82 7659.52 16.00 311.34 MWD 13400.00 89.10 130.00 10046.74 -3216.65 7069.29 5978752.92 265941.99 7682.07 16.00 311.59 MWD 13408.00 89.96 129.05 10046.81 -3221.74 7075.46 5978747.63 265947.99 7689.40 16.00 311.71 7 13425.00 90.19 126.34 10046.79 -3232.14 7088.91 5978736.81 265961.10 7705.20 16.00 275.00 MWD 13450.00 90.54 122.35 10046.63 -3246.24 7109.55 5978722.06 265981.27 7728.92 16.00 275.00 MWD 13475.00 90.89 118.37 10046.32 -3258.87 7131.11 5978708.74 266002.42 7753.13 16.00 274.97 MWD 13500.00 91.23 114.38 10045.86 -3269.97 7153.50 5978696.92 266024.44 7777.71 16.00 274.92 MWD 13525.00 91.56 110.39 10045.25 -3279.49 7176.61 5978686.67 266047.22 7802.55 16.00 274.85 MWD 13550.00 91.89 106.41 10044.49 -3287.37 7200.31 5978678.02 266070.66 7827.51 16,00 274.75 MWD 13575.00 92.21 102.42 10043.60 -3293.59 7224.51 5978671.03 266094.64 7852.48 16.00 274.63 MWD 13600.00 92.51 98.42 10042.57 -3298.11 7249,07 5978665.73 266119.04 7877.33 16.00 274.49 MWD 13625.00 92.81 94.43 10041.41 -3300.90 7273.88 5978662.13 266143.75 7901.95 16.00 274.32 MWD 13628.00 92.84 93.95 10041.26 -3301.12 7276.87 5978661.82 266146.73 7904.89 16.00 274.14 8 13650.00 92.90 97.48 10040.16 -3303.31 7298.73 5978658.93 266168.51 7926.50 16.00 89.00 MWD 13675.00 92.95 101.48 10038.88 -3307.42 7323.35 5978654.03 266192.99 7951.30 16.00 89.18 MWD 13700.00 92.99 105.49 10037.59 -3313.24 7347.62 5978647.43 266217.06 7976.24 16.00 89.38 MWD 13725.00 93.01 109.49 10036.28 -3320.74 7371.43 5978639.17 266240.61 8001.19 16.00 89.59 MWD 13750.00 93.01 113.50 10034.97 -3329.89 7394.65 5978629.28 266263.53 8026.04 16.00 89.80 MWD 13775.00 93.01 117.50 10033.66 -3340.63 7417.18 5978617.82 266285.70 8050.66 16.00 90.01 MWD 13800.00 92.98 121.51 10032.35 -3352.92 7438.91 5978604.83 266307.02 8074.93 16.00 90.22 MWD 13825.00 92.95 125.51 10031.06 -3366.70 7459.72 5978590.39 266327.37 8098.73 16.00 90.43 MWD 13850.00 92.89 129.52 10029.78 -3381.91 7479.52 5978574.56 266346.67 8121.96 16.00 90.64 MWD 13875.00 92.83 133.52 10028.53 -3398.45 7498.21 5978557.42 266364.82 8144.48 16.00 90.84 MWD 13898.00 92.76 137.21 10027.41 -3414.80 7514.35 5978540.57 266380.42 8164.50 16.00 91.04 9 13900.00 92.75 136.89 10027.32 -3416.26 7515.71 5978539.06 266381.74 8166.21 16.00 269.00 MWD 13925.00 92.67 132.88 10026.13 -3433.88 7533.40 5978520.88 266398.85 8188.07 16.00 268.98 MWD 13950.00 92.58 128.88 10024.98 -3450.22 7552.28 5978503.94 266417.19 8210.73 16.00 268.80 MWD 13975.00 92.48 124.88 10023.88 -3465.20 7572.25 5978488.33 266436.68 8234.06 16.00 268.61 MWD 14000.00 92.36 120.87 10022.82 -3478.76 7593.23 5978474.10 266457.20 8257.95 16.00 268.43 MWD 14025.00 92.24 116.87 10021.82 -3490.82 7615.10 5978461.35 266478.67 8282.30 16.00 268.27 MWD 14050.00 92.10 112.87 10020.87 -3501.32 7637.76 5978450.12 266500.98 8306.98 16.00 268.10 MWD 14075.00 91.95 108.87 10019.99 -3510.22 7661.10 5978440.47 266524.02 8331.87 16.00 267.95 MWD 14100.00 91.79 104.87 10019.17 -3517.48 7685.00 5978432.46 266547.68 8356.85 16.00 267.81 MWD 14125.00 91.63 100.87 10018.42 -3523.04 7709.36 5978426.11 266571.85 8381.79 16.00 267.68 MWD 14150.00 91.45 96.88 10017.75 -3526.90 7734.05 5978421.46 266596.39 8406.59 16.00 267.56 MWD 14175.00 91.27 92.88 10017.16 -3529.02 7758.94 5978418.54 266621.21 8431.10 16,00 267.45 MWD 14200.00 91.09 88.88 10016.64 -3529.41 7783.93 5978417.35 266646.17 8455.23 16.00 267.36 10 14225.00 90.86 92.88 10016.22 -3529.79 7808.92 5978416.16 266671.13 8479.36 16.00 93.20 MWD 14250.00 90.63 96.87 10015.89 -3531.91 7833.82 5978413.24 266695.95 8503.88 16.00 93.27 MWD 14275.00 90.40 100.87 10015.67 -3535.77 7858.52 5978408.59 266720.51 8528.68 16.00 93.32 MWD 14300.00 90.16 104.86 10015.54 -3541.33 7882.88 5978402.25 266744.69 8553.64 16.00 93.36 11 14325.00 90.16 100.86 10015.47 -3546.89 7907.25 5978395.91 266768.86 8578.59 16.00 270.00 MWD 14350.00 90.16 96.86 10015.40 -3550.74 7931.95 5978391.26 266793,42 8603.39 16.00 269.99 MWD 14375.00 90.16 92.86 10015.33 -3552.86 7956.85 5978388.35 266818.24 8627.92 16.00 269.98 MWD 14400.00 90.16 88.86 10015.26 -3553.23 7981.84 5978387.17 266843.21 8652.05 16.00 269.97 MWD 14425.00 90.15 84.86 10015.20 -3551.86 8006.80 5978387.74 266868.20 8675.66 16.00 269.96 MWD 14450.00 90.15 80.86 10015.13 -3548.76 8031.60 5978390.04 266893.08 8698.64 16.00 269.94 MWD 14475.00 90.14 76.86 10015.07 -3543.93 8056.13 5978394.08 266917.75 8720.88 16.00 269.93 MWD 14500.00 90.14 72.86 10015.00 -3537.40 8080.25 5978399.83 266942.07 8742.28 16.00 269.92 MWD 14525.00 90.13 68.86 10014.95 -3529.20 8103.87 5978407.26 266965.94 8762.72 16.00 269.91 MWD ObP . BP-GDB . BiI. IIAICD ...... B er Hughes INTEQ Planning R rt ".~C",·"·",.__,.,"··· INTEQ Company: BP Amoco Date: 4/112004 Time: 12:29:33 Page: 4 Field: Endicott Co-ordinate(NE) Reference: Well: 1-65/N-25, True North Site: End MPI Vertical (TVD) Reference: System: Mean Sea Level Well: 1-65/N-25 Section (VS) Reference: Well (0.00N,0:OOE,106.00Azi) Wellpath: Plan#10 1-65A1N-27 Survey CalculatiouMethod: Minimum Curvature Db: Oracle -- . . - -. -,-~.- Survey ... .~ - ~~.._--~..~ ___ __ _____·__···_.__"_o ..-.....-...--......- . .-. - -----·-------------------·----··-----l MD Iud Azim SysTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 14550.00 90.12 64.86 10014.89 -3519.38 8126.85 5978416.34 266989.22 8782.10 16.00 269.90 12 14575.00 89.64 68.83 10014.94 -3509.55 8149.83 5978425.43 267012.51 8801.48 16.00 97.00 MWD 14600.00 89.15 72.80 10015.21 -3501.34 8173.44 5978432.88 267036.37 8821.91 16.00 96.99 MWD 14625.00 88.67 76.77 10015.68 -3494.78 8197.55 5978438.66 267060.68 8843.28 16.00 96.95 MWD 14650.00 88.19 80.74 10016.36 -3489.91 8222.06 5978442.74 267085.33 8865.50 16.00 96.87 MWD 14675.00 87.73 84.72 10017.25 -3486.74 8246.84 5978445.10 267110.19 8888.44 16.00 96.77 MWD 14700.00 87.27 88.70 10018.35 -3485.31 8271.77 5978445.73 267135.16 8912.01 16.00 96.62 MWD 14725.00 86.83 92.68 10019.63 -3485.61 8296.73 5978444.63 267160.09 8936.09 16.00 96.45 MWD 14750.00 86.40 96.66 10021.11 -3487.64 8321.59 5978441.80 267184.88 8960.55 16.00 96.25 MWD 14775.00 85.99 100.65 10022.77 -3491.39 8346.25 5978437.25 267209.40 8985.29 16.00 96.01 MWD 14800.00 85.60 104.64 10024.60 -3496.85 8370.57 5978431.02 267233.54 9010.17 16.00 95.75 13 14825.00 85.54 108.65 10026.53 -3503.99 8394.45 5978423.12 267257.17 9035.09 16.00 91.00 MWD 14850.00 85.51 112.66 10028.48 -3512.78 8417.76 5978413.58 267280.19 9059.93 16.00 90.69 MWD 14875.00 85.49 116.68 10030.44 -3523.18 8440.41 5978402.46 267302.49 9084.56 16.00 90.38 14 14900.00 83.50 113.19 10032.84 -3533.67 8462.97 5978391.25 267324.70 9109.14 16.00 240.00 MWD 14925.00 81.53 109.68 10036.10 -3542.73 8486.04 5978381.45 267347.46 9133.81 16.00 240.33 MWD 14950.00 79.60 106.13 10040.20 -3550.31 8509.50 5978373.12 267370.67 9158.45 16.00 240.79 MWD 14975.00 77.70 102.54 10045.12 -3556.38 8533.24 5978366.29 267394.20 9182.95 16.00 241.37 MWD 14983.62 77.06 101.28 10047.00 -3558.12 8541.47 5978364.29 267402.37 9191.34 16.00 242.08 1-65A1N-1 14988.03 76.73 100.64 10048.00 -3558.93 8545.69 5978363.34 267406.56 9195.62 16.00 242.35 1-65A1N-l 15000.00 75.86 98.89 10050.84 -3560.91 8557.15 5978361.00 267417.95 9207.18 16.00 242.50 MWD 15025.00 74.06 95.19 10057.32 -3563.87 8581.10 5978357.27 267441.80 9231.02 16.00 242.92 MWD 15050.00 72.34 91.42 10064.55 -3565.25 8604.99 5978355.12 267465.63 9254.36 16.00 243.88 MWD 15075.00 70.68 87.58 10072.48 -3565.05 8628.69 5978354.56 267489.32 9277.09 16.00 244.97 MWD 15100.00 69.11 83.66 10081.08 -3563.26 8652.09 5978355.59 267512.77 9299.09 16.00 246.18 MWD 15125.00 67.63 79.67 10090.30 -3559.89 8675.08 5978358.21 267535.85 9320.26 16.00 247.53 MWD 15150.00 66.25 75.58 10100.09 -3554.97 8697.54 5978362.41 267558.46 9340.50 16.00 249.01 MWD 15175.00 64.97 71.42 10110.42 -3548.51 8719.37 5978368.17 267580.48 9359.70 16.00 250.60 MWD 15200.00 63.82 67.17 10121.23 -3540.55 8740.45 5978375.45 267601.81 9377.77 16.00 252.33 MWD 15225.00 62.79 62.85 10132.46 -3531.12 8760.69 5978384.22 267622.34 9394.63 16.00 254.16 MWD 15250.00 61.90 58.44 10144.07 -3520.27 8779.99 5978394.44 267641.97 9410.18 16.00 256.11 MWD 15262.51 61.51 56.21 10150.00 -3514.32 8789.26 5978400.09 267651.43 9417.46 16.00 258.15 1-65A1N-, 15265.00 61.44 55.77 10151.19 -3513.10 8791.07 5978401.25 267653.28 9418.86 16.00 259.21 TO WEUPATH DETAILS Plal\#10 14:HJAlN·;tl 500292262101 Paflfflt ~I~th; 1>65APB11N~21 Tie Oft 1\110: 13114.07 Rig; Non:Uc 2: Ref, Datum: 91: 65 513011996 09:24 56.0Oft V,SettlOI'} Origin Origin ~;:::~Ð Awgfe 'toW-$; +E¡·W 106,0(r (U)4 .... 41.50 REFERENCE INFORMATION Plan: Plan #10 (H35JN"2SIPlan#10 1~65A/N-27 Created By: Srij Patnis Dale: 4/1/2004 T LEGEND . 9000 9100 9200 9300 9400 10400 -2500 ·2600 -2700 ·2800 -2900 -3000 3600 3700 3800 ·3900 -4200 6600 6700 B800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 T-arg..t va., DL.. $ECTI<m tlETAfI;.S HIli.) TV/) TVÐAlinotn-tii:II" Az¡ , ~ ¡ , : " " " " .. " 6600 6700 6900 7000 7100 7200 7300 7700 9900 1-.A/N-27 Proposed . TREE: COOPER 4-1/16" 5000 psi WELLHEAD: FMC SSH 13-5/8" 5000 psi KB. ELEV = 56.00' BF ELEV = 15.00' MAX DEV = 90° (12770' -13285') HORIZONTAL COMPLETION SSSV LANDING NIPPLE I 1569 HES "HXO" (3.813" LD.) 0< KOP = 300' 10-3/4", 45.5#/ft, L-80, BTC I 5212' I > A GLM's, HES MBX 9CR , 1" BK NO. TVDSS MD-BKB 6 3538 4133 5 5197 6237 4 6236 7547 3 6956 8462 2 7639 9336 1 8323 10209 0p of CTD liner ~ ~900' md, 3.70" ~ 513' of} 7 5/8" 2. ... 4-1/2", 12.6#/ft, NSCT 13CR80 J 11930' 11941' 11965' 11975' 11988' I 12004' I [g . -{=l / BAKER "SSP"1 Liner Top Pkr 12517' DEV = 74° 7-5/8", 29.7#/ft, NT95HS, NSCC 112721' I >J. ~ 1-65A1N-27 CTD Sidetrack 3 1/2" 9.3# 13Cr80 liner 41/2" 12.6# L-80 NSCT .-----Þ 12730' ; o o o Perforation summary Ref Log: 1/18/96 Atlas SBT/GR o o Status Open Open Open Date 9/00 11/99 1196 SPF 6 6 6 Interval 12488-12508 12504-12524 12730-13100 o o Whipstock at 12990' md, 89° inclination K-1 Cement retainer @ 13010' 0 0 13100' 4-1/2", 12.6#/ft 113285' I L-BO NSCT > Date By Comments 1/30/96 TLR COMPLETION 12/15/99 TP Add-perfs 9130100 MAS Add-perfs & corrections 4/20/01 MAS Cement retainer 11/11/03 MOJ CTD ST Proposed 63/4" bit size ENDICOTT WELL: 1-65/N-25 API NO. 50-029-22627-00 COMPLETION DIAGRAM BP EXPLORATION (ALASKA), INC ... VJ 61t-" '5 í? '/l-lk;)'f p JB 3/31 / 'I--- . STATE OF ALASKA . ALASKA oYAND GAS CONSERVATION COM ðSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: D Abandon D Alter Casing D Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): D Suspend D Repair Well D Pull Tubing IS! Operation Shutdown D Perforate D Plug Perforations D Stimulate D Perforate New Pool D Re-Enter Suspended Well 4. Current Well Class: !HI Development 0 Exploratory o Stratigraphic Test 0 Service 99519-6612 KBE = 56 8. Property Designation: ADL 047502 D Waiver D Time Extension D Annular Disposal 5. Permit To Drill Number 203-212 /" 6. API Number: /' 50- 029-22627-01-00 D Other 9. Well Name and Number: END 1-65A1N-27/" 10. Field I Pool(s): Endicott Field I Endicott Pool f>RSSSN"FWEI.,.LCONDITlON SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 14599 9927 13302' 10089 None Junk (measured): 13302' Structural Conductor 60' 30" 60' 60' Surface 5169' 10-3/4" 5212' 4437' 5210 2480 Intermediate 12680' 7-5/8" 12721' 10084' 8180 5120 Production Liner 768' 4-1/2" 12517' - 12990' 10058' - 10087' 8430 7500 12. Attachments: !HI Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: March 27, 2004 16. Verbal Approval: Date: 3/26/2004 Commission Representative: Winton Aubert 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title CT Drilling Engineer Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 12488' - 13010' 10049' - 10088' Packers and SSSV Type: 7-5/8" Baker 'S-3' packer 4-1/2" HES 'HXO' SSSV Landing Nipple Signature Sundry Number: loW - 001 g Tubing Size: 4-1/2" Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 11941' 1570' Tubing MD (ft): 11987 13. Well Class after proposed work: o Exploratory !HI Development 0 Service 15. Well Status after proposed work: !HI Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Ted Stagg, 564-4694 Phone 564-4694 o Plug Integrity o Mechanical Integrity Test Conditions of approval: Notify Commission so that a representative may witness o Location Clearance RECEIVED o BOP Test Other: MArt 3 0 2004 +0 re S tt\,v t- ~4 <"'-' 4:t. £Y\. <;. , A!F1~il Œ1 & Gas Cans. Commøn t},~Gh~ BY ORDER OF COMMISSIONER THE COMMISSION Date 3-3/~ðf Submit In Duplicate l~W~ APR 0'1 .26M . . Re: Summary of events leading to Operations Shutdown on Endicott 1-65A CTD sidetrack. 1-65A was drilled to a depth of 14,599 MD (9927ss) when the drilling assembly became stuck at a bit depth of 14,560' ón 3/23/04. Eff0sts to move the fish were partially successful as the fish was moved to a bit depth of 14,047' MD (9975ss). Further efforts to free the fish were unsuccessful. On 3/26/04 the coil tubing was chemically cut at a depth of 13,302' MD (1O,028ss) leaving both coiled tubing and the drilling BHA in the hole. """ Final depths are as follows: Top of 2 3/8" coil tubing @ 13,302' MD (10,028'ss) 1 Top of drilling assembly @ 13,982' MD (9981 'ss) Bottom of drilling assembly @ 14,047' MD (9975'ss) The fluids left in the well provide approx. 670 psi overbalance to formation pressure. / 10.0 ppg brine from surface to 11,970' MD (tubing tail) , 10.0 ppg drilling fluid from 11,970' MD to drilled TD of 14,599' MD /' / Nordic 2 secured Endicott 1-65A on March 27 and have now moved onto Endicott 2-36 for a workover. Plans are being reviewed in order to decide whether to move back onto 1-65A following the 2-36 workover to continue the 1-65A sidetrack or to complete the abandonment of 1-65A and return the well to production from the 1-65 parent well. The fate of 1-65A will be decided within the next week and notification will be sent to the __ AOGCC at that time. Ted Stagg 564-4694 1-6SAlNeStatus at Ops Shutdown M.29, 2004 /~ KB. ELEV = 56.00' BF ELEV = 15.00' TREE: COOPER 4-1/16" 5000 psi MAX DEV = 90° (12770' -13285') WELLHEAD: FMC SSH 13-5/8" 5000 psi HORIZONTAL COMPLETION KOP = 300' 10-3/4", 45.5#/ft, L-80, BTC 1 5212' I > A GLM's, HES MBX 9CR, 1" BK NO. TVDSS MD-BKB 6 3538 4133 5 5197 6237 4 6236 7547 3 6956 8462 2 7639 9336 1':7' 1 8323 1 0209 ~ . 10.0 ppg Flo-Pro below tubing tail and 10.0 ppg brine above / tubing tail. Primary producing perfs ~ ~ 'V' from parent well ð 7-5/8", 29.7#1ft, NT95HS, NSCC __ ~ 112721' I 41/2" 12.6# L-80 NSCT ~ 12730' -; o o o Perforation summary Ref Log: 1/18/96 Atlas SBT/GR Interval Status 12488-12508 Open 12504-12524 Open 12730-13100 Open Date SPF 9/00 6 11/99 6 1/96 6 Whipstock at 12990' md, 89° inclination K-1 Cement retainer @ 13010' 0-< SSSV LANDING NIPPLE I 1569 HES "HXO" (3.813" I.D,) ~ 4-1/2", 12.6#/ft, NSCT 13CR80 J 11930' 11941' 11965' 11975' 11988' I 12004' I ~ BAKER "SBP"I Liner Top Pkr 12517' DEV = 74° ~ Top of 2 3/8" Coil at 13,302' MD (chern. cut) o o TD@ 14,599' MD o o :~ '- :. Inteq Drlg.BHA approx. 13,982 - 14,047' MD o o 13100' 4-1/2", 12.6#/ft 113285' I 6 3/4" bit size L-80 NSCT > Date By Comments 1/30/96 TLR COMPLETION ENDICOTT WELL: 1-65/N-25 12/15/99 TP Add-perfs API NO. 50-029-22627-00 9/30100 MAS Add-perfs & corrections COMPLETION DIAGRAM 4/20101 MAS Cement retainer 11/11/03 MOJ CTD ST Proposed BP EXPLORATION (ALASKA), INC . =~ (ill} !Æ~!Æ~~~!Æ . / í FRANK H. MURKOWSKI, GOVERNOR I AI,ASIiA OIL AM) GAS / CONSERVATION COMMISSION / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Endicott DIU 1-65A1N-27 BP Exploration (Alaska), Inc. Permit No: 203-212 Surface Location: 3058' NSL, 2218' WEL, Sec. 36, T12N, R16E, UM Bottomhole Location: 411' SNL, 1874' EWL, Sec. 05, T11N, R17E, UM Dear Mr. Johnson Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations unt il all 0 ther required permits a nd approvals ha ve been is sued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may resµ1t in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sinc~ /~".,/ I ./' ~ -'" BY ORDER OF THE COMMISSION DATED this~ day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. VJ6 Æ- t LI%l2..ct) '3 o Drill B Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3058' NSL, 2218' WEL, SEC. 36, T12N, R16E, UM Top of Productive Horizon: 331' NSL, 4260' EWL, SEC. 31, T12N, R17E, UM Total Depth: 411' SNL, 1874' EWL, SEC. 05, T11 N, R17E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-258980 Y-5982195 Zone-ASP3 16. Deviated Wells: Kickoff Depth ~ø..·· Cªsil'1€1f'r<>9ram Size Hole CasinQ Weight 3-3/4" 3-1/2" x 2-7/8" 9.3# /6,16# . STATE OF ALASKA .. ALASKA _ AND GAS CONSERVATION CO_SSION PERMIT TO DRILL 20 AAC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: IBI Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 15430 /' TVD 10132 7. Property Designation: ADL 047502 II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: ./ D I4 ~1-65A1N-27 12. Field / Pool(s): Endicott Field I Endicott Pool 9. Acres in Property: 2560 13. Approximate Spud Date: January 15, 2004 14. Distance to Nearest Property: 4909' 8. Land Use Permit: 12990 ft Maximum Hole Angle 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): KBE = 56 feet 1-29/M-25 is 494' away at 13125' MD 17. Anticipated pressure (see 20 AAC 25.035) /' Max. Downhole Pressure: 4719 psig. Max. Surface Pressure: 3722 psig 97° Grade 13Cr Coupling LenQth STL 3460 MD 11970' TVD 9735 MD TVD (includinQ stage data) 15430' 10132 147 sx Class 'G' Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): 13286 10088 13010 13198 10089 None Structural Conductor 60' 30" Driven 60' 60' Surface 5169' 10-3/4" 845 sx PF 'E', 625 sx Class 'G' 5212' 4437' Intermediate 12680' 7-5/8" 630 sx Class 'G' 12721' 10084' Production Liner 768' 4-1/2" 180 sx Class 'G' 12517' - 13285' 10058' - 10088' 20. Attachments IBI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 10049' - 10089' IBI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements Perforation Depth MD (ft): 12488' - 13100' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoi '5 true and correct to the best of my knowledge. Printed Name Mark Johnson Title CT Drilling Engineer SiQnature 7~ Új Phone 564-5666 Date: Contact Mark Johnson, 564-5666 Prepared By Name/Number: Date /~ 'f, 0'3 Terrie Hubble, 564-4628 Permit To Drill Number: I Permit APproval See cover letter for Number: 203 - .2../.2... 50-029-22627-01-00 Date: other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required k E (~\A+lU Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required ~e·s "'-¡jÑo Other:'Tts.t- 'ßl?P~ to 'fOOD pS.I. DEC - 5 2003 Alaska Oil & Gas Cons. Commission p ~~r@}lþ~~\ ~~~~g~~~ION A~:t:orr!.:id¡[:;:. e e BP 1-65A/N-27 Sidetrack Summary of Operations: Endicott welll-65/N-25 is scheduled for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on 1/15/04. The sidetrack, 1-65A/N-2L will exit.Q\tt efthe existing 4 W' liner from a whipstock at 12990' md. The existing perforations in 1-65/N-25 will be abandoned by liner cement from the 1-65A/N-21 liner (P&A sundry fOI111 already submitted). The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (phase 1) I) Slickline -Drift tubing. Dummy GL Vs, Pressure test IA to 3000 psi. 2) CT - FCO, log memory caliper in horizontal 4 W' liner, bullhead CaC03 to reduce pel111eability of existing perforations, mill XN nipple to 3.80" ID, cleanout liner, drift for whipstock. CTD Sidetrack Summary (phase 2) 1) MIRU CTO rig. . 2) Set 4 W' LSX whipstock at 12990' md. ~ 3) Mill window with 3.80" OD diamond speed mill. / 4) Drill 3.75" openhole sidetrack to -15430' TO with MWDæg /' y/resistivity. 5) Run 3 1/2" x 27/8" solid liner completion and cement wi 'B of 15.8 ppg class G cement. Bottom ofliner at TO, top ofliner at -11970' md. WO . sure test liner and lap to 2000 psi. ./ Run liner top packer if needed. P&A of 1-65/N-25 is complete. 6) Perforate 1-65A/N-21 liner. 7) RDMO. Mud Program: · Phase 1: 9.3 ppg brine · Phase 2: 9.3 ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. / Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / · 3 1/2" x 27/8" 13Cr solid cemented liner completion from 11970' to TD at 15430'. The 3 1/2" will . run from 11970' to 13050' and the 27/8" will run from 13050' to TD at 15430'. The liner cement volume is planned to be -30 bb1s of 15.8 ppg class G. ./' Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. .-/ · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 97 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD directional and Gamma Ray will be run over all of the open hole section. · MWD Resistivity is planned. e e Hazards ~ . Endicott row 1 has illS readings over 100 ppm and is designated as an H2S pad. Maximum recorded illS on the pad was 1800 ppm from 1-37/P-24. The last 1-65/N-25 illS level was 110 ppm on ,..- 9/312003. All illS monitoring equipment will be operational. · Two small fault crossings are anticipated. Lost circulation risk is considered "low", but LCM material will be on location as a contingency. Reservoir Pressure · Res. press. is estimated to be 4719 psi at 9970'ss (9.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft:) to surface is 3722 psi. ~/ Distance to Endicott Unit boundary line · 1-65A/N-27 is 4909' from the Endicott unit boundary line at TO of 15430' md. Distance to nearest well within pool . 1-29/M-25 is 494'md away at 13125' in the 1-65A/N-27 directional plan. The 1-65A/N-27 wellbore will also come close (within 8'md) of the 1-65/N-25 pilot hole at 13270'md, but this is a nonf issue since the pilot hole was plugged back to 9900' md with cement on 1/3/96. Casin2lLiner Information 10 3/4", L-80, 45.5#, Burst 3580 psi; collapse 2090 psi 75/8", NT95HS, 29.7#, Burst 8180 psi; collapse 5120 psi 4 Yz" BCr-80 NSCT, 12.6#, Burst 8440 psi; collapse 7500 psi 3 1/2" BCr-80 STL, 9.3#, Burst 10180 psi; collapse 10540 psi (connection same as body rating) 27/8" BCr-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (connection same as body rating) MOJ 12/4/03 ,KB. ELEV = 56.00' BF ElEV = 15,00' MAX DEV . 90· (12770' - 13285') HORIZONTAL COMPLETION -- TREE: COOPER 4-1116" 5000 PS.¡ WELLHEAD: FMC SSH 13-5/8" ¡ KOP = 300' 10-314", 45.5#lft, L-80, BTC o~ SSSV LANDING NIPPLE I 1669 HES "HXO" (3.813"I.D.) I 6212' I ~A ( 4-1/2", 12.6#Ift. NSCT 13CR80 tbg ~ GLM's, HES MBX 9CR , 1" BK NO. TVDSS MD-BKB 6 3638 4133 5 6197 6237 4 6236 7647 3 6966 8462 2 7639 9336 I 83~~ 10~09 START BUILDING ANGLE . -11600' (34-) ~ 4-112-'X' NIPPLE (3.813-I.D.) 7-518" BAKER "8-3" 4-112" 'X' NIPPLE 4-112- 'XN' NIPPLE (3.725"I.D.) ~4-112" WLEG ELMD: Ref 1/18/96 SBT BAKER "SBP" Uner Top Pkr DEV·74° g j 8 7-~".,~.711ft. NT95HS, NSCC 112721' I ~A 4112" 12.6# L-80 NSCT :> ~ 12730' Perforation summary Ref Log: 1/18196 Atlas SBT/GR Interval 12730-13100 12504-12524 12488-12508 Status Open Open Open Date SPF 1/96 6 11199 6 9/00 6 DPC 6 SPF e-< 111930' I 11941' 11965' 11976' 111988' I 112004' I I 12517' I K-1 Cement retainer I 13010' I 4-112", 12.6flft 113286' I > f 13100' L-80 NSCT Date By Comments ENDICOTT WELL: 1-66/N"26 1130196 TLR COMPLETION API NO. 60.029-22627.00 12/15199 TP AdcI-perfs COMPlETION DIAGRAM ti3OIOO MAS AdcI-perfs & correc:llona 4I2M1 MAS Cement retainer BP EXPLORATION (AlASKA), tNC ~ ''¡~ ~ KB. ELEV = 56.00' BF ELEV = 15.00' MAX DEV = 90° (12770' -13285') 1-.A/N-27 Proposed TREE: COOPER 4-1/16" 5000 psi WELLHEAD: FMC SSH 13-5/8" 5000 psi e HORIZONTAL COMPLETION PfO pot~d KOP = 300' 10-3/4", 45.5#Ift, L-80, BTC 0-< SSSV LANDING NIPPLE I J HES "HXO" (3.813"I.D.) 1569 I 5212' I GLM's, HES MBX 9CR , 1" BK NO. TVOSS MD-BKB 6 3538 4133 5 5197 6237 4 6236 7547 3 6956 8462 2 7639 9336 1 8323 10209 >A ~ 4-1/2", 12.6#1ft, NSCT 13CR80 J (Top of CTD liner ~ 11970' md, 3.70" O~ .I 513' Of~ 0 :Iiii 7 5/8" r: W%,t~ ~:::: 7-5/8", 29.7#/ft, NT95HS, NSCC . "]1 /12721' I ¿.!1r > ~jll 41/2" 12.6# L-80 NSCT ~:!I 12730' 0 =;:::: Perforation summary 0 H:~ 0:::::: Ref Log: 1/18/96 Atlas SBTlGR o~~::~: Interval Status Date SPF 12488-12508 Open 9/00 6 12504-12524 Open 11/99 6 12730-13100 Open 1/96 6 K-1 Cement retainer XO at 13Cr80 liner TD":"@ @ 13010' 0 13050' 15430 MD 4-1/2" 'X' NIPPLE ~ (3.813"1.0.) ~7~8"BAKER"S~" ~ 4-112" 'X' NIPPLE ~ 4-112" 'XN' NIPPLE (milled to 3.80" I.D.) 4-112" WLEG I ELMO: Ref 1/18/96 SB II 11930' 11941' 11965' 11975' 11988' I 12004' I :~:~:~:: BAKER "SBP" I I ~ 1 ~~:_~:17' ~3 112" 9::~c~~dl:~~Ck 0 0 4-112", 12.6#Ift ~<' 13100' 113285' I > 63/4" bit size L-80 NSCT ? Date By Comments 1/30/96 TLR COMPLETION ENDICOTT WELL: 1-65/N-25 1211 5199 TP Add-peñs API NO. 50-029-22627-00 9130100 MAS Add-perfs & corrections COMPLETION DIAGRAM 4/20101 MAS Cement retainer .... 11/11/03 MOJ CTD ST Proposed BP EXPLORATION (ALASKA), INC 8~':;j OOOO'::j 9100'::] _ 9200-::1 I: 'j. . ~O- 9300-::f·..·;,~'...·,............ 9400-':¡ t:, :t·, ..t: 9500", " t :,1 .! 9600':;]" 1 9700'::1 i! 9800)" : 9900-:.1 ! 100r0·¡Þl......: 10100':¡ :-1-" 10200,:1 ',1 10300':;]' . "1,1 1.-25 (I -eMI-26PHl' ¡ 10400-:_1-.,·;·i'~~·~·~·"~_: .-'1-",-,.'" '-1'~-r-'-i:'"'' ¡~'.~~-~ '!:T' ¡·--:·":"-:"¡·-·r·-:"1·:·:,:~::·--r··.:~·:·--;·~":·:~·-:·'¡'-'~'-'-'''¡-~-i-1-¡-''1':';''-1-:':''!'¡'~ ' , , ' ,:,";i-¡' -:'¡':"1T~"-¡ r (i':';,: r-'·1·:.....¡·:·,·1·:·;·:~1..i·:T:; : :1T'--'¡':T'Í'n "1T'-''':'~' "¡'::'·~"~::':~"-1+"1-:+:'¡'~''- ~Ti-"1':-:"1-:-r-"1':':''-¡'¡''';-:':+¡-~ '-1-:'" 7000 7100 7200 7300 7400 7500 7600 7700 7000 7900 sOoo 8,()() 8200 8300 8400 8500 8600 8700 8600 8000 9000 91'00 9200 9300 9400 9500 9600 9700 9600 9900 100001010010200103001040010&)(1106001070010800 Vertical Section at 106.00· [100ft/ln] BP Amoco ~~ï:; .,.DIa~ v._ - Wl!l.UATN DftAILA -.-. ............ ..-.. ........ e1 I . 1aIf't_...... IL_ 0: '= ~ t...... .... .... 41'" REFERENCE INFORMATION Cc>-anI.- ~¡ RIfenfnœ, We! CentnJ, 1.æ1N-25, True NO<1I1 v:::"(VS! ==: ~~~~~o:ï~ M_ Depth RIfenfnœ, 91 ,65 ~'996 09:24 56.00 CoIcuI81Ion Me1hod: Mirinun Curvl1Ure -- .. 1M ... ... ..... - - TP_ T..... ..... .- ....~.. 0- .... .... ...... ..... .- ........ .-... L" .... ....... ..... ...... .aauo ....." '.ao ..... ,an.o. 0 ..... ...... -H1'a.7. .....1. 11.DD ..... ....... ..... ..... ........ nn.17 1a.1O .- 71U.11 0 .-... ..... ...... ........ ;m:= ..-11::: ..... ....... . 1....... ".ia .... ........ - .,...... 0 ......... .,..., ....,... ........ ,.,..11 .... ..... U.I.'" 0 ._... M.a ...... ...... ........ _"0 ,.... ,ao.eo ....... 1.'...... ..... oo.a ....... ........ ....... ..... ..... =-= 11 14ÐC1.01 a.oo ,-.a4 ,-..0 4I12.Q -... 1L... 'OIUII ,.,...... n.aI ...., ,...." ........ ....... ,a.oo .,OLIO =:: 11'...... ...,. ..... '11.... ........ ....... ,LIO ,..... -"'-1 TVD M.......... '1M3.... 111II.. .,. tlU1A tBN." KOP ."".11 tll...... I tlUS.,. 112...... . 11U1.12....... . 1111............. . ............... , .....,......... . Nn.JI.......... . ..,.....,........ 'I' t""'" ........ 'It 'IIU.n'...... 'II ...."..,...... TD ......ŒTM.S M> ..... Dill -3OM.1Ið TOM.20 - - "'~ '~PoIyvon7' 0::":'::.1')1'" ..,,:.:. 1.,,1 Rill 8fAft4.a Ccn1acIlnIoonation: ~=¡:<:,¡n 26?~~qcom Baker Hugho. INTEQ: (9'6~7.æoo LEGEND T 1_~_'2S) .0- 1_ 1.86h-2iPH) 1';\ M _1 ·21 't. Plan 11 i / tb ,¡:J ~Ien: Plan IrI (1-65/N-251P11n1J11-65A1N-21) CI88ted By: Or! ~.... 0"0' 11/6/2003 AzImuths to True North Magnetic North: 25.89' Magnetic Field Strength: 57615nT Dip Angle: 80.97' Data: 111612003 Model: bggm2OO3 ,"", ~: , ,. L;,.: ....' ';"';;"~:/ .................................... INTF..Q -2500 ,;.. -2600 ----0 .....__n.___. -2700 -2800 . ....... ...,.. ë' -3000':(" ~ -3100 " o t:,-3200 - ;t.-3300 @ -3400 o !-35OQ ";' - '-3800 ! -3700:1.. e -3800 -4000",' ' -4100':':';" .. , .. , .. , . .................... ,. -4200''1;'' . ': : . .. ' . , õ-· r""': ','" ;-r.,· ¡Of ·.T· . + ~.~ .,.~+ ~-;-¡-; +~.:' ~ ':':'~ -,-~. ~T!-¡-;·,·+ ~·r ,(¡·r .,. i·:·~ + ~-;-rH'r '.- ¡.; + i·; -'--'-1' ~·!",·:·r .;-¡: ·r+~·; -,-i· ¡ ,. i' :-H·¡-; -,--;-¡ ,H-¡; -r-'- :-~ -, i-~-!- i· ¡- ¡ ,- ¡ - ¡ -, .;. ¡-; -, ¡.: -, ',-¡ - :-:·i-: -, -,' ¡-:', y ¡ -; -,' ¡ 6600 6700 61ioo 6000 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 soOo 8100 8200 8300 8400 8500 86()Q 8700 8800 8900 ~O 9100 9200 West(-)lEast(+) [100ft/In] e !" , , ..".' .........,................. ................'. . ' . ..' '. " ,. .. . ' , .'.·.·¡.·¡.\,.·,·.i~.,ß 11/ç:I./')",,'). ').',)/1 D"~ O~}n "," ~.~, BP-GDB .r Hughes INTEQ Planning R~rt lIid BADa ......s ......'...................... INTEQ Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: End MPI TR-12-16 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 3 Well Centre bggm2003 5979337.49 ft 256681.13 ft Latitude: 70 20 Longitude: 147 58 North Reference: Grid Convergence: 38.358 N 30.505 W True -1.86 deg WeD: 1-65/N-25 Slot Name: 65 1-65/N-25 Well Position: +N/-S 2930.92 ft Northing: 5982195.19 ft Latitude: 70 21 7.180 N +EI-W 2205.03 ft Easting: 258980.06 ft Longitude: 147 57 26.059 W Position Uncertainty: 0.00 ft Wellpath: Plan#? 1-65A1N-27 500292262701 Current Datum: 91 : 65 5130/1996 09:24 Magnetic Data: 11/612003 Field Strength: 57615 nY Vertical Seetion: Depth From (TVD) ft 41.50 Targets Drilled From: Tie-on Depth: Above System Datum: DecUoation: Mag Dip Angle: +EI-W ft 0.00 1-65/N-25 12989.30 ft Mean Sea Level 25.89 deg 80.97 deg Direction deg 106.00 Height 56.00 ft +N/-S ft 0.00 1-65A1N-27 PoIygon7.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 Annotation 0.00 -3058.86 7058.20 5978910.98 265935.98 70 20 37.064 N 147 53 59.852 W 0.00 -3058.86 7058.20 5978910.98 265935.98 70 20 37.064 N 147 53 59.852 W 0.00 -3193.30 6953.47 5978779.98 265826.98 70 20 35.743 N 147 54 2.916 W 0.00 -3680.52 7887.66 5978262.98 266744.98 70 20 30.942 N 147 53 35.639 W 0.00 -3623.79 9059.48 5978281.98 267917.98 70 20 31,487 N 147 53 1.405 W 0.00 -3365.82 8961.13 5978542.98 267827.98 70 20 34.025 N 147 53 4.269 W 0.00 -3358.93 7776.25 5978587.98 266643.98 70 2034.106 N 147 53 38.884 W 0.00 -3167.33 7231.79 5978796.98 266105.98 70 20 35,996 N 147 53 54.784 W 12989.30 12990.00 13010.00 13210.00 13570.00 13680.00 13845.00 13990.00 14080.00 14580.00 14930.00 15280.00 15430.00 10031,42 10031,43 10031.71 10033.70 10022.02 10014.45 9998.30 9980.19 9973.32 9974.01 10005.22 10083.17 10131.55 TIP KOP 3 4 5 6 7 8 9 10 11 12 TO 14LfO ~J bp BP-GDB .r Hughes INTEQ Planning R_rt Company: BPAmoco Date: 111612003 ...hne:..·...·.15;26;36 Page: 2 Field: Endicott CO-OJ'1liliBte(NE).RefetelÜ:e: \Nefl:..1-¢;t1'.~25..·TrI.Ie.North Site: EndMPI Veffieai('J'VÐ).iteference: ~Y$teri'l:.·MC;¡I:JI1§AA·l.eyet Well: 1-651N-25 Stdio"(VS).Rerer/,\n~e: We1I.(O.OON,O.OOE,.106.00Azj) Wellpath: Plãri#7..1-65A1N-27 SlII"Vefealclllation.Meth04: Mil1JmurnCurvatUre Db: Oracle Plan: Plan #7 Date Composed: 11/6/2003 KO above cement retainer Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 12989.30 89.20 123.20 10031.42 -2916.96 6795.62 0.00 0.00 0.00 0.00 12990.00 89.20 123.20 10031.43 -2917.34 6796.20 0.00 0.00 0.00 0.00 13010.00 89.20 125.00 10031.71 -2928.55 6812.76 9.00 0.00 9.00 90.00 13210.00 89.68 149.00 10033.70 -3073.74 6948.16 12.00 0.24 12.00 89.00 13570.00 93.87 105.97 10022.02 -3287.67 7226.87 12.00 1.16 -11.95 -84.00 13680.00 93.99 119.20 10014.45 -3329.72 7327.96 12.00 0.11 12.03 89.00 13845.00 97.13 99.55 9998.30 -3384.00 7482.07 12.00 1.90 -11.91 -80.00 13990.00 97.10 117.09 9980.19 -3429.05 7618.11 12.00 -0.02 12.09 89.00 14080.00 91.63 126.43 9973.32 -3476.24 7694.28 12.00 -6.08 10.38 120.00 14580.00 88.22 66.52 9974.01 -3530.11 8168.69 12.00 -0.68 -11.98 -93.00 14930.00 82.00 108.24 10005.22 -3513.93 8509.10 12.00 -1.78 11.92 100.00 15280.00 73.38 66.07 10083.17 -3499.51 8842.01 12.00 -2.46 -12.05 -106.00 15430.00 69.29 84.59 10131.55 -3463.45 8978.66 12.00 -2.73 12.34 106.00 Survey 12989.~ 89.20 123.20 10031.42 -2916.96 6795.62 5979061.25 265678.10 7336.39 0.00 0.00 TIP (12990.00 89.20 123.20 10031.43 -2917.34 6796.20 5979060.85 265678.68 7337.06 0.00 0.00 KOP 13000.00 89.20 124.10 10031.57 -2922.88 6804.53 5979055.05 265686.82 7346.58 9.00 90.00 MWD 13010.00 89.20 125.00 10031.71 -2928.55 6812.76 5979049.11 265694.86 7356.06 9.00 89.99 3 13025.00 89.23 126.80 10031.92 -2937.35 6824.91 5979039.93 265706.72 7370.17 12.00 89.00 MWD 13050.00 89.29 129.80 10032.24 -2952.84 6844.53 5979023.82 265725.83 7393.29 12.00 88.98 MWD 13075.00 89.34 132.80 10032.54 -2969.33 6863.30 5979006.73 265744.07 7415.89 12.00 88.94 MWD 13100.00 89.40 135.80 10032.81 -2986.79 6881.19 5978988.71 265761.39 7437.90 12.00 88.90 MWD 13125.00 89.46 138.80 10033.06 -3005.16 6898.14 5978969.80 265777.74 7459.26 12.00 88.87 MWD 13150.00 89.52 141.80 10033.28 -3024.39 6914.11 5978950.07 265793.08 7479.91 12.00 88.84 MWD 13175.00 89.59 144.80 10033.48 -3044.43 6929.05 5978929.56 265807.36 7499.79 12.00 88.81 MWD 13200.00 89.65 147.80 10033.64 -3065.23 6942.92 5978908.33 265820.56 7518.86 12.00 88.79 MWD 13210.00 89.68 149.00 10033.70 -3073.74 6948,16 5978899.65 265825.52 7526.24 12.00 88.77 4 13225.00 89.86 147.21 10033.76 -3086.48 6956.09 5978886.66 265833.03 7537.37 12.00 276.00 MWD 13250.00 90.18 144.22 10033.75 -3107.13 6970.17 5978865.57 265846.44 7556.60 12.00 276.01 MWD 13275.00 90.49 141.24 10033.61 -3127.02 6985.31 5978845.20 265860.93 7576.63 12.00 276.01 MWD 13300.00 90.80 138.26 10033.32 -3146.10 7001.46 5978825.61 265876.46 7597.41 12.00 275.99 MWD 13325.00 91.11 135.27 10032.90 -3164.31 7018.58 5978806,86 265892.98 7618.89 12.00 275.95 MWD 13350,00 91.42 132.29 10032.35 -3181.60 7036.62 5978789.00 265910.46 7641.00 12.00 275.90 MWD 13375.00 91.72 129.30 10031.67 -3197.93 7055.54 5978772.08 265928.84 7663.69 12.00 275.84 MWD 13400.00 92.02 126.31 10030.85 -3213.24 7075.28 5978756.14 265948.08 7686.88 12.00 275.76 MWD 13425.00 92.32 123.33 10029.90 -3227.50 7095.78 5978741.22 265968.12 7710.53 12.00 275.66 MWD 13450.00 92.60 120.34 10028.83 -3240.68 7117.00 5978727.37 265988.90 7734.55 12.00 275.55 MWD 13475.00 92.88 117.35 10027.63 -3252.72 7138.87 5978714.63 266010.37 7758.90 12.00 275.42 MWD 13500.00 93.15 114.35 10026.32 -3263.61 7161.34 5978703.03 266032,47 7783.49 12.00 275.27 MWD 13525.00 93.42 111.36 10024.88 -3273.30 7184.33 5978692.60 266055.14 7808.27 12.00 275.12 MWD 13550.00 93.67 108.37 10023.34 -3281.78 7207.80 5978683.38 266078.32 7833.16 12.00 274.95 MWD 13570.00 93.87 105.97 10022.02 -3287.67 7226.87 5978676.88 266097.19 7853.11 12.00 274.76 5 13575,00 93.88 106.57 10021.68 -3289.06 7231.65 5978675.32 266101.93 7858.10 12.00 89.00 MWD 13600.00 93.92 109.58 10019.98 -3296,80 7255.36 5978666.83 266125.38 7883.02 12.00 89.04 MWD 13625.00 93.96 112.58 10018.27 -3305.77 7278.63 5978657.12 266148.35 7907.86 12.00 89.25 MWD 13650.00 93.98 115.59 10016.54 -3315.95 7301.40 5978646.21 266170.77 7932.55 12.00 89.45 MWD 13675.00 93.99 118.60 10014.80 -3327.31 7323.60 5978634.15 266192.59 7957.02 12.00 89.66 MWD 13680.00 93.99 119.20 10014.45 -3329.72 7327.96 5978631.60 266196.88 7961.89 12.00 89.87 6 13700.00 94.41 116.83 10012.99 -3339.09 7345.57 5978621.67 266214.18 7981.39 12.00 280.00 MWD O· ", '''' . '> '",}: hr., ~ ......... ~ BP-GDB .r Hughes INTEQ Planning .rt ........................... INTEQ Company: Field: Site: Well: Wellpath: Survey BP Amoco Endicott End MPI 1-651N-25 Plan#7 1-65A1N-27 Date: 111612003 Time: 15:26:36 Page: 3 CfH)rdinate(NE) Reference: Welt 1-651N-25, True North Vertical (TVD) Reference: System: Mean Sea LeVel Section (VS) Referem:e: Well (0.ooN,O.ooE,106.ooAzi) Sarvey Calcnlation Method: Minimum Curvature Db: Oracle 13725.00 94.91 113.86 10010.95 -3349.75 7368.09 5978610.28 266236.34 8005.98 12.00 279.83 MWD 13750,00 95.40 110.89 10008.71 -3359.23 7391.11 5978600.07 266259.04 8030.72 12.00 279.59 MWD 13775.00 95.88 107.92 10006.25 -3367.49 7414.57 5978591.06 266282.23 8055,55 12.00 279.32 MWD 13800.00 96.35 104.93 10003.58 -3374.52 7438.41 5978583.26 266305.83 8080.41 12.00 279.03 MWD 13825.00 96.79 101.95 10000.72 -3380.29 7462.57 5978576.72 266329.78 8105.21 12.00 278.71 MWD 13845.00 97.13 99.55 9998.30 -3384.00 7482.07 5978572.39 266349.15 8124.98 12.00 278.37 7 13850.00 97.14 100.16 9997.68 -3384.85 7486.96 5978571.38 266354.01 8129.91 12.00 89.00 MWD 13875.00 97.18 103.18 9994.56 -3389.86 7511.25 5978565.59 266378.13 8154.65 12.00 89.08 MWD 13900.00 97.20 106.21 9991.43 -3396.15 7535.23 5978558.53 266401.90 8179.44 12.00 89.45 MWD 13925.00 97.20 109.23 9988.29 -3403.70 7558.86 5978550.23 266425.27 8204.23 12.00 89.83 MWD 13950.00 97.18 112.25 9985.16 -3412.49 7582.05 5978540.70 266448.16 8228.94 12.00 90.21 MWD 13975.00 97.14 115.28 9982.05 -3422.48 7604.75 5978529.98 266470.53 8253.52 12.00 90.59 MWD 13990.00 97.10 117.09 9980.19 -3429.05 7618.11 5978522.99 266483.67 8268.17 12.00 90.97 8 14000.00 96.50 118.14 9979.00 -3433.65 7626.90 5978518.10 266492.31 8277.89 12.00 120.00 MWD 14025.00 94.99 120.74 9976.50 -3445.88 7648.56 5978505.19 266513.57 8302.08 12.00 120.12 MWD 14050.00 93.4 7 123.33 9974.65 -3459.10 7669.70 5978491.29 266534.26 8326.04 12.00 120.38 MWD 14075.00 91.94 125.92 9973.4 7 -3473.29 7690.24 5978476.45 266554.34 8349.70 12.00 120.58 MWD 14080.00 91.63 126.43 9973.32 -3476.24 7694.28 5978473.37 266558.28 8354.39 12.00 120.70 9 14100.00 91.51 124.04 9972.77 -3487.77 7710.61 5978461.32 266574.23 8373.27 12.00 267.00 MWD 14125.00 91.35 121.04 9972.15 -3501.21 7731.67 5978447.21 266594.85 8397.23 12.00 266.93 MWD 14150.00 91.18 118.04 9971.60 -3513.53 7753.41 5978434.20 266616.18 8421.52 12.00 266.86 MWD 14175.00 91.01 115.05 9971.12 -3524.70 7775.77 5978422.31 266638.17 8446.09 12.00 266.79 MWD 14200.00 90.84 112.05 9970.72 -3534.69 7798.68 5978411.60 266660.75 8470.87 12.00 266.74 MWD 14225.00 90.66 109.06 9970.39 -3543.47 7822.09 5978402.07 266683.86 8495.79 12.00 266.69 MWD 14250.00 90.49 106.06 9970.14 -3551.01 7845.92 5978393.77 266707.43 8520.77 12.00 266.65 MWD 14275.00 90.31 103.07 9969.96 -3557.29 7870.11 5978386.71 266731.41 8545.76 12.00 266.62 MWD 14300.00 90.13 100.07 9969.87 -3562.31 7894.60 5978380.91 266755.72 8570.68 12.00 266.60 MWD 14325.00 89.95 97.08 9969.85 -3566.03 7919.32 5978376.39 266780.31 8595.4 7 12.00 266.59 MWD 14350.00 89.77 94.08 9969,91 -3568.46 7944.20 5978373.16 266805.09 8620.06 12.00 266.58 MWD 14375.00 89.60 91.09 9970.05 -3569.59 7969.17 5978371.23 266830.02 8644.37 12.00 266.59 MWD 14400.00 89.42 88.09 9970.26 -3569.41 7994.17 5978370.60 266855.00 8668.35 12.00 266.61 MWD 14425.00 89.24 85.10 9970.55 -3567.93 8019.12 5978371.28 266879.99 8691.92 12.00 266.63 MWD 14450.00 89.07 82.10 9970.92 -3565.14 8043.96 5978373.27 266904.90 8715.03 12.00 266.67 MWD 14475.00 88.90 79.11 9971.36 -3561.06 8068.61 5978376.55 266929.68 8737.61 12.00 266.71 MWD 14500.00 88.73 76.11 9971.88 -3555.70 8093.02 5978381.13 266954.25 8759.60 12.00 266.77 MWD 14525.00 88.57 73.12 9972.47 -3549.07 8117.12 5978386.98 266978.54 8780.93 12.00 266.83 MWD 14550.00 88.41 70.12 9973.13 -3541.19 8140.83 5978394.09 267002.50 8801.55 12.00 266.90 MWD 14575.00 88.25 67.12 9973.86 -3532.08 8164.10 5978402.45 267026.04 8821.41 12.00 266.98 MWD 14580.00 88.22 66.52 9974.01 -3530.11 8168.69 5978404.27 267030.70 8825.28 12.00 267.06 10 14600.00 87.81 68.89 9974.71 -3522.53 8187.18 5978411.25 267049.42 8840.97 12.00 100.00 MWD 14625.00 87.29 71.85 9975.7$ -3514.14 8210.71 5978418.88 267073.20 8861.27 12.00 99.92 MWD 14650.00 86.79 74.81 9977.0t -3506.98 8234.62 5978425.27 267097.33 8882.28 12.00 99.79 MWD 14675.00 86.29 77.77 9978.58 -3501.06 8258.86 5978430.40 267121.75 8903.95 12.00 99.64 MWD 14700.00 85.80 80.74 9980.3~ -3496.41 8283.36 5978434.26 267146.39 8926.22 12.00 99.46 MWD 14725.00 85.32 83.71 9982.2 ' -3493.04 8308.05 5978436.84 267171.18 8949.03 12.00 99.25 MWD 14750.00 84.86 86.68 9984.38 -3490.95 8332.87 5978438.12 267196.05 8972.31 12.00 99.02 MWD 14775.00 84.41 89.66 9986.7~ -3490.16 8357.75 5978438.12 267220.93 8996.00 12.00 98.77 MWD 14800.00 83.97 92.65 9989.25 -3490.66 8382.61 5978436.82 267245,77 9020.04 12.00 98.49 MWD 14825.00 83.56 95.63 9991.96 -3492.45 8407.39 5978434,23 267270.48 9044.36 12.00 98.19 MWD 14850,00 83.15 98.63 9994.86 -3495.54 8432.03 5978430.36 267295.00 9068.89 12.00 97.86 MWD 14875.00 82.77 101.63 9997.92 -3499.90 8456.45 5978425.21 267319.27 9093.57 12.00 97.52 MWD 14900.00 82.41 104.63 10001.15 -3505.53 8480.59 5978418.81 267343.22 9118.32 12.00 97.15 MWD o¡,-w> . ,"... .'. t..1f:'~" BP-GDB .r Hughes INTEQ Planning "'rt ~""tiIIIII IIV..... BAlœR IØ.IOIaS .....--................. INTt:~Q Company: Field: Site: Well: Wellpath: Survey BP Amoco Endicott End MPI 1-65/N·25 Plan#71-65A1N·27 Date: 111612003 Time: 15:26:36 Page: 4 Co-ordinate(NE) Reference: Well: 1-65/N-25, True North Vertical (TVD)R.eference: System: Mean Sea level Section (VS) Refereøce: Well (0.00N.0.OOE.1 06.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle 14925.00 82.06 107.64 10004.52 -3512.41 8504.39 5978411.16 267366.78 9143.09 12.00 96.76 MWD 14930.00 82.00 108.24 10005.22 -3513.93 8509.10 5978409.49 267371.44 9148.04 12.00 96.36 11 14950.00 81.34 105.90 10008.11 -3519.74 8528.01 5978403.07 267390,16 9167.83 12.00 254.00 MWD 14975.00 80.54 102.98 10012.05 -3525.90 8551.92 5978396.15 267413.85 9192,50 12.00 254.34 MWD 15000.00 79.77 100.03 10016.32 -3530.81 8576.05 5978390.47 267437.81 9217.06 12.00 254.80 MWD 15025.00 79.02 97.08 10020.93 -3534.47 8600.35 5978386.03 267461.98 9241.42 12.00 255.30 MWD 15050.00 78.30 94.11 10025.84 -3536.86 8624.74 5978382.86 267486.28 9265.52 12.00 255.85 MWD 15075.00 77.62 91.12 10031.06 -3537.98 8649.16 5978380.96 267510.65 9289.31 12.00 256.43 MWD 15100.00 76.96 88.12 10036.56 -3537.81 8673.55 5978380.33 267535.03 9312,70 12.00 257.05 MWD 15125.00 76.34 85.10 10042.33 -3536.38 8697.83 5978380.99 267559.34 9335.64 12.00 257.71 MWD 15150.00 75.76 82.07 10048.36 -3533.67 8721.93 5978382.92 267583.52 9358.07 12.00 258.41 MWD 15175.00 75.21 79.03 10054.63 -3529.70 8745.80 5978386.12 267607.50 9379.92 12.00 259.14 MWD 15200.00 74.70 75.96 10061.12 -3524.47 8769.37 5978390.58 267631.23 9401.14 12.00 259.91 MWD 15225.00 74.24 72.89 10067.81 -3518.01 8792.57 5978396.30 267654.62 9421.66 12.00 260.70 MWD 15250.00 73.82 69.80 10074.69 -3510.32 8815.34 5978403.25 267677.63 9441.42 12.00 261.52 MWD 15275.00 73.45 66.70 10081.74 -3501.43 8837.62 5978411.42 267700.18 9460.39 12.00 262.37 MWD 15280.00 73.38 66.07 10083.17 -3499.51 8842.01 5978413.20 267704.63 9464.08 12.00 263.25 12 15300.00 72.73 68.49 10089.00 -3492.12 8859.65 5978420.01 267722.50 9479.00 12.00 106.00 MWD 15325.00 71.96 71.53 10096.58 -3483.98 8882.03 5978427.43 267745.13 9498.27 12.00 105.30 MWD 15350.00 71.24 74.60 10104.47 -3477.07 8904.72 5978433.61 267768.03 9518.18 12.00 104.37 MWD 15375.00 70.57 77.70 10112.65 -3471.41 8927.66 5978438.52 267791.13 9538.67 12.00 103.40 MWD 15400.00 69.95 80.82 10121.10 -3467.03 8950.77 5978442.16 267814.38 9559.68 12.00 102.39 MWD 15425.00 69.39 83.96 10129.79 -3463.92 8974.01 5978444.52 267837.70 9581.15 12.00 101.34 MWD 15430.00 69.29 84.59 10131.55 -3463.45 8978.66 5978444.84 267842.36 9585.50 12,00 100.25 TD 0:·:::::':", '.::' ":". ~ "). .:: ..: hr.' " e BP-GDB Anticollision Report e IIi. BAU. NUONI:S IN'I'EQ GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference - There ar~_ells In thBlllfDFlan #7 & NOT PLANNED PROGRA iii Interpolation Method: MD + Stations Interval: 10.00 ft Error Model: ISCWSA Ellipse Depth Range: 12989.30 to 15430.00 ft Scan Method: Trav Cylinder North Muimnm Radius: 1738.85 ft Error Snñace: Ellipse + Casing Casing Points 5212.00 4436.84 12721.00 10084.27 12990.00 10087.43 15430.00 10187.55 10.750 7.625 4.500 2.875 12.250 8.500 6.000 3.750 10 314" 7 5/8" 4112" 27/8" Plan: Plan #7 KO above cement retainer Principal: Yes Date Composed: Version: Tied-to: 11/6/2003 2 From: Definitive Path Snmmary End MPI 1-21/K-25 Plan 1-21a1N-24 High K 13025.00 14870.00 930.71 333.30 597.40 Pass: Major Risk End MPI 1-29/M-25 1-29/M-25 V1 13125.00 13620.00 494.41 343.82 150.59 Pass: Major Risk End MPI 1-33A1PB 1 1-33AIPB 1 V3 Out of range End MPI 1-35/0-25 1-35/0-25 V1 Out of range End MPI 1-431P-26 1-431P-26 V1 13434.33 13320.00 1139.68 379.31 760.37 Pass: Major Risk End MPI 1-651N-25 1-651N-25 V1 12990.00 12990.00 0.00 0.00 0.00 FAIL: NOERRORS /' End MPI 1-651N-25 1-651N-25PH V1 13270.26 13010.00 8.00 No Reference Casings End SOl 3-01/N-29 3-01lN-29 V1 Out of range End SDI 3-07/N-28 3-07/N-28 V1 15250.00 13500.00 912.78 328.58 584.20 Pass: Major Risk End 501 3-07A1L-29 3-07 NL-29 V5 15250.00 13200.00 1075.09 308.73 766.37 Pass: Major Risk End SDI 3-091L-28 3-091L-28 V1 Out of range End SDI 3-25/M-27 3-25/M-27 V1 14925.00 13410.00 499.72 368.73 130.99 Pass: Major Risk End SOl 3-25/M-27 3-25NPB1 Vi 14925.00 13410.00 499.72 368.84 130.88 Pass: Major Risk End SDI 3-25/M-27 3-25BIL-27 V10 15375.00 13720.00 874.54 323.67 550.87 Pass: Major Risk End SOl 4-08/P-27 4-08/P-27 V1 14375.00 13850.00 1005.25 327.28 677.96 Pass: Major Risk End SDI 4-10/M-28 4-10/M-28 V1 Out of range End SDI 4-10/M-28 4-10AIL-28 V16 Out of range Site: End MPI Well: 1-21/K-25 Rnle Assigned: Major Risk Wellpath: Plan 1-21a1N-24 High KOP VO Plan: 1-21a1N-24 wp01 Inter-Site Error: 0.00 ft 12989.85 10087.43 14700.00 10159.03 49.26 52.83 29.12 265.92 8.500 1018.74 337.01 681.74 Pass 12990.00 10087.43 14710.00 10164.32 49.26 52.87 28.80 265.60 8.500 1013.06 336,94 676.12 Pass 12994.56 10087.50 14720.00 10169.63 49.27 52.90 28.88 265.27 8.500 1007.41 336.82 670.59 Pass 12996.90 10087.53 14730.00 10174.95 49.28 52.93 28.76 264.94 8.500 1001.84 336.71 665.13 Pass 13000.00 10087.57 14740.00 10180.28 49.29 52.96 28.71 264.61 8.500 996.32 336.58 659.74 Pass 13000.00 10087.57 14750.00 10185.63 49.29 53.00 28.37 264.27 8.500 990.87 336.37 654.50 Pass 13003.99 10087.63 14760,00 10190.98 49.30 53.03 28.39 263.93 8.500 985.48 336,20 649.28 Pass 13006.39 10087.66 14770.00 10196.34 49.30 53.07 28.25 263.58 8.500 980.15 336.03 644.12 Pass 13010.00 10087.71 14780,00 10201.72 49.31 53.10 28.23 263.23 8.500 974.89 335.83 639.06 Pass 13010.00 10087.71 14790.00 10207.11 49,31 53.14 27.88 262.88 8.500 969.70 335.67 634.03 Pass 13010.00 10087.71 14800.00 10212.50 49,31 53.18 27.52 262.52 8.500 964.58 335.49 629.10 Pass 13015.10 10087.78 14810.00 10217.91 49.30 53.21 27.76 262.15 8.500 959.51 335.12 624.39 Pass 13017.16 10087.81 14820.00 10223.33 49.29 53.24 27,64 261.78 8.500 954.52 334.84 619.68 Pass 13019.24 10087.84 14830.00 10228.76 49.28 53.28 27.52 261.41 8.500 949.61 334.55 615.06 Pass 13025.00 10087.92 14840,00 10234.20 49,27 53.30 27.83 261.03 8.500 944.79 334,10 610.69 Pass 13025.00 10087.92 14850.00 10239.66 49.27 53.34 27.45 260.65 8.500 940.01 333.85 606.16 Pass 13025.00 10087.92 14860.00 10245.12 49.27 53.39 27.07 260.27 8.500 935.31 333.58 601.73 Pass I,;'..~ c.~"-"" j,.'sð/N-21 (n~()) ( 'L ) /JoSt> 3,75 -2,a7~ -== 107--? l"t ) f 7 ( 3.1$'8 t.... 3.) 'L) /t.>'t, / ('I,'67$'t.- -J,r.....) lOt., /8,2 !~ / 3,'IIYIH~ - 1$'0/30 - /3o)() ól1 J.Â~ " 31$ ,. ,,:t I II. o I o z Iii w :J: U) e 7,7 - - -/11'0 ~$1 3'f-t y 7~¿Af o 0 z z w W II. ..I ~ it !iJ g ;:) II) ~ 0· 5~~ I \~~1\6 1°0 fY)öe 2-'/, G:, 15M ~t., ']0 /!>þ( ~ ].7) . .-----...."...-""-..- ~ iT t' \ \ \ -;. \ ' I 'T"\," I \~~-\". ~~:-L..-1---!-!--~--l-L..:.~, ii-I", , ~b ,1b '307 t 'I 7:~ì1~_", ~ ;-¡¡-c w ~ Q ..I > Q. ø. c( Ii: w Q = :! c:J z - a: III III Z - c:J Z III ~ ~ '" ~ « Mo:f /11/03 I- Z II: o 0 w W Q W "') W 3: II) U) CJ ;:) c( Z U) II) W c. .c o e Nordic 2 CTD BOP Detail . \... I I, t===C f=C= HCR I m@W I 7-1/16" ID, 5000 psi working pressure / I-¡- Ram Type Dual Gate BOPE I TOT ~ Manual over Hydraulic I xo Spool as necessary \ / I I ® I ® I I 'IL T~ ì~ ì ~ ¿YUI I ~ Methanol Injection ð.H.ð Otis 7" WLA Quick I' Connect - I 7-1/16"ID, 5000 psi working pressure ;-- Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Full production christmas tree MOJ 9/15/02 Tubing r Spool I I 0'\l \ ~CTlnjeclorHead -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ 7" Riser I I " Annular BOP (Hydril),7-1I16"ID 5000 psi working pressure /' ./ I I Blind/Shear I / /' 12 318 " Combi PipelSIi~ I Kill line check valve or HCR )l®nffill -wQ-: l Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on OS Hardline to StandpipE manifold / 1/ 1/ I I 2 3/8" Combi Pipe/Slip 23/8" x 3 1/2" VBRs 2 flanged gate valves Inner Annulus Outer Annulus p055169 DATE 1 0/6/2003 I I CHECK NO. 055169 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 10/6/2003 INV# PR1001031 PERMIT TO DRILL -=EE H \-(psPrJN'~7 RECEIVED DEC - 5 2003 Alaska Oil & Gas Cons. Commission Anchorage e THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BPEXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAG!;, AK995J9-6612 NATIONAL CITY BANK Ashland, Ohio 56-?89 412 No. p 055169 CONSOLIDATED COMMERCIAL ACCOUNT PAY: AMOUNT ***(f77$1öç.00*******1 e TO THE ORDER OF: 1110 5 5 ¡. b g III I: 0... ¡. 20 j 8 g 5 I: 0 ¡. 2 78 g b liD e . TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number, stated above. BOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/]0/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Field & Pool ENDICOTT - 220000 Well Name: DUCK IS UNIT MPI1-65A1N27 Program Well bore seg PTD#: 2032120 Company BP EXPLORATION (ALASKA) INC Initial ClasslType 11-01L GeoArea 890 Unit 10450 OnlOff Shore Off Annular Disposal 1 PermiUee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2Lease_nIJmb~r_appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 .U_n[qIJe weltname_aod oumb.er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ . . . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ 4 WeUJQcated In_a_d_efine~pool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 W~JIJQcated pr_op~rdistance from driJling unitb_oundary_ _ _ _ _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 W~JIJQcated prop~r _d[stance_ from Qthe.r wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _SutficienLacreag.e_aYailable [n_driUiog uniL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Kdeviated, js_ weJlbQre platincJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 Operator only: affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ 10 .Operator bas_appropr[ateJ).ond [nJQrce. _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ . _Ye~ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . . _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ . _ _ . _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ _ _ _ 11 Pe(l1)it cao be [s~ued withQut co_nserva_tion ord~r _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 12 Permit cao be [s~ued withQut admini$tratÍ\le_approvaJ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . .' ,12/5/2003 13 Can permit be approved before 15-day wait Yes 14 W~JIJQcated w[thin area and strata _authQr[zed byJojectioo Order # (putlO# in_commeots).{FQr_ NA_ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 15 .AJlwelJs_witÞtn.1l4_l'lJile_are.a_ofreyiewideotlfied(For$ervjcewell only:). _ _ _ _ _ _ _ _ _ _.. _ _ _NA _ _. _. _ _ _ _ _ _ _. _ _ _ _ _ _ _ _. _. _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _.. _ _ _ _ _ _.. _ _ _ _ _._ 16 Pre.-produ_cecl iojeçtor; ~uratiQn_of pre-pro~uçtion le~s_ than. 3 months (For_service well QnJy) _ _ _NA _ _ _ _ _ _ _ . _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ _ . 17 AÇMPJ=indingof CQn_si$teocy.h_as beeRis_sIJed.forJhis pr_oject_ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ NA . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ 18 _Coodu_ctor stringprQv[ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_urfaœcasing_ pJQtects all known_ USDWs _ _ _ _ _ _ _ _ . . _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ 20 _CMTvoladequ_ateJo circulate on_cond_uctor.&suJtCSg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .NA _ _ _ _ _ _ _. _ _ _ _ _ _. _ _ _ _ _ _. . _ _ _ _ _ _ _. _ _ _ _ _. 21 _CMT vol adequateJo ti~-inJQngstring to_SIJrf csg. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 22 _CMT will coyer_a]! koownpro_dlJctiye bQrizons _ _ _ _ . . _ _ _ _ _ _ _ . _ Yes _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 23 _C_asiog de.signs ad_eQuaJ~ for C,T" B_&_perl'lJafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 24 A~equateJan_kage_oJ re_serve pit _ _ _ _ _ . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Ye~ _ CTDU. _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ 25 Ka.re-~rilt bas a_ to,40;3 for abandonment beeo apPJQved _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ . . _ _ _ 26 A~equatewellQofe.$epªratio_npropO$e~.. _ _ _ _ _ _ _ . . . _ . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . . . Yes _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . . . . _ _ _ _ . . _ . _ . _ _ _ _ . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ . 27 Kdiver:t~r Jequire.d, dQes it meet reguJations. _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ Sidetrack, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _. _ _ . _ _ _ _ Date 28 .DJiUiog fluid.prQgram sc.hematic.& eCl-uipJistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Max MW9~3. ppg, _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ 121812003 29 .BOPEs,_d_o _they meet reguJation _ _ _ _ . . _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ Yes _ . . _ _ . . _ . _ _ _. _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ . _ _ . _ _ _ . . _ _ _ . . _ _ _ _ _ _ . _ _ _ _ . _ 30 .BOPE_pr~ss ratil1g appropriate; _t~stto(put psig in .comments)_ _ _ _ _ _ _ _ . Yes _ _ . _ _ _ T~st to AOOO psi. _MSF> 3722 p~i._ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ 31 .C_hoke_l'lJanifold cQmpJies_ w/API R,F>-53. (May 84). _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ . _ _ Yes. _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ . _ _ _ _ _ . . _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . _ . _ _ _ . 32 Work will occ_ur withoutoperation .sbutdown_ . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ 33 Js presence. Qf H2S gas. prob_able . _ _ _ _ _ _ _ _. .. _ _ _ _ _ _ _ . . . _ _ _ . _ _ _ _ Yes _ _ aO_ppm< _ _ . _ _ . _. _ _ _ _ _ _ _ _ _ _ . _ . _ _ . _ _ _ _ _ _ . _ _ _ . _ _ _ . _ _ _ . . _ _ _ _ 34 MechanicaLcoodjt[ol1ofwe.llswithin'/\Oßyerifiecl<For_servjcewelJ0 nJy)_ _ _ _ _ _ _. _ _ _ _ _ _NA _ . _ _ _ _ _ _ _ _ _ _ _.. _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Administration Appr Date Engineering Appr "A Geology Appr Date RPC 12/5/2003 Geologic Commissioner: (Jr;-S D D ~ - - - - - - - ~ - - - - - - - -- 35 Permit c.ao be [s~ued w/oJlydrogen_ sulfide meaSjJres _ . _ _ _ _ _ _ _ _ _ . . _ _ _ No. _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ 36 .D.ata_preseoted Qn. pote.ntial overpressure _Zone$ _ _ _ _ _ _ _ _ . _ . . _ _ _ _NA . _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 37 _Seismicanalysjs_ of $haJlow gaszoo~s_ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ NA _ _ _ _ . _ _ _. _. _ _ _ . _ 38SeaQed _conditioo survey.(if off-shore) _ _ _ _ _ . . . _ _ _ _ _ _ _. NA _ . _ _ _ . 39 _Conta_ctnam.elp/loneJorweeklyprogressreport~[e)(ploratory_ooly). _ _ _ _ _ _ _ _ _ _.. _ _ _ NA_. _. _ _ _ _ _ _ _ _.. _ _ _ _ _ _.. _ _ _ _ _ _ _.. _ _ _ _ _ _ _._ Engineering Public ...fl ~ / )ay , J;~ì 3 Commi",i"e< D,te Commi"'iooe'{r ''1 lilt Il3 - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - - - ~ - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - e e 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 infoffilation. 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. e e ~o3 -;;Z/;2 0],". " **** REEL HEADER **** MWD 05/01/14 /213t{ BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/01/14 649753 01 3.125" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! Remark File Version 1.000 Extract File: ldwg.las -Version Information VERSo 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame -Well Information Block #MNEM.UNIT Data Type Information #--------- ------------- ------------------------------- STRT.FT 12977.5.0000: Starting Depth STOP.FT 14597.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMPo COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 1-65A/PB1 FLD . FIELD: Endicott LOC. LOCATION: 70 deg 21' 7.180" N 147 deg 57' 26.059"W CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3.125" CoilTrak - GR/USMPR DATE. LOG DATE: 25-Mar-04 API . API NYUMBER: 500292262770 -Parameter Information Block #MNEM.UNIT Value Description #--------- ------------------------- ------------------------------- SECT. 36 Section TOWN. N 12 Township RANG. 16 Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . RKB Log Measured from FAPD.F 56 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 56 Elevation of Kelly Bushing EDF . F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE. F 13002 Casing Depth OSl . DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray and Resistivity data are realtime data unless otherwise noted. (4) The USR (Ultra Slim Resistivity) data from 13400 ft. to 13651 ft. MD (10036.5 ft. to 10022 ft - e (5) pass data. ( 6) (7) Circulating TVD) is merged wiper trip data. The USR data from 13651 ft. to 14402 ft. MD (10022 ft. to 9333 ft. TVD) is merged MAD Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system. Tools run in the string included Casing Coil Locator, Electrical Disconnect and Sub, a Drilling Performance Sub, (inner and outer downhole pressure, downhole weight on bit, downhole temperature), Ultra Slim Resistivity Sub, a Gamma and Directional Sub, And a Hydraulic Orienting with near bit Inclination sensor. (8) Data presented here is final and has been depth shifted to a PDC ( Primary Depth Control) recorded by SWS on April 14, 2004. (9) The sidetrack was drilled from milled window in 4 1/2" tubing. Top of window. 12993.4 ft. MD ( 10031.4 ft. TVD ) Bottom of window. 13002.4 ft. MD ( 10031.5 ft. TVD ) (10) The interval from 14563 ft. to 14597 ft. MD (9926 ft. to 9926 ft. TVD ) was not logged due to bit to sensor offset. (11) Tied in to 1-65/N-25 at 12462 ft. MD. (12) An open hole sidetrack was made at 13125 ft. MD (10026.5 ft. TVD) for 1-65A/N-27. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour RACLX -> Attenuation Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RACHX -> Attenuation Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm RPCLX -> Phase Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RPCHX -> Phase Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm CURVE SHIFT DATA BASELINE, MEASURED, 13003.5, 13001.2, DISPLACEMENT -2.28613 Tape Subfile: 1 71 recûrds... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1-65apbl.xtf 150 BP Exploration (Alaska) Inc. 1-65APBl/N-27 Endicott North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 14-Apr-04 *** INFORMATION TABLE: CIFO CHAN DIMT CNAM ODEP MNEM e e ---------------------------------------------------- GR GR GRAXOl 0.0 ROP ROP ROPAOl 0.0 RACL RACL RACLXOl 0.0 RACH RACH RACHXOl 0.0 RPCL RPCL RPCLXOl 0.0 RPCH RPCH RPCHXOl 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 90 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 12977.500000 14597.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 103 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN raw.xtf e e LCC CN WN FN COUN STAT 150 BP Exploration (Alaska) 1-65APB1/N-27 Endicott North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROPA ROPA ROPA 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPA MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 180 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 12980.000000 14597.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 193 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/01/14 649753 01 **** REEL TRAILER **** MWD 05/01/14 BHI 01 Tape Sub file: 4 Minimum record length: Maximum record length: e e 2 records... 132 bytes 132 bytes e e Tape Subtile 2 is type: LIS DEPTH GR ROP RACL RACH RPCL RPCH 12977.5000 121.0700 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12978.0000 113.3633 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13000.0000 255.5800 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 11.4600 81.1400 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 11.3100 60.7800 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 12.1000 79.0700 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 14.5000 24.6300 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 13.8500 44.3400 -999.2500 -999.2500 -999.2500 -999.2500 13600.0000 13.2200 51.2900 -999.2500 -999.2500 -999.2500 -999.2500 13700.0000 16.6533 48.7500 14.8850 13.3900 10.3450 9.1750 13800.0000 21. 7600 16.2600 20.4760 9.1920 8.7020 8.0380 13900.0000 21.3800 83.6400 32.6180 26.7840 18.8420 17.3280 14000.0000 15.4100 89.8300 3.8000 3.3400 3.2900 3.2100 14100.0000 17.6600 89.7800 8.0000 12.0775 9.3075 9.4900 14200.0000 15.6900 55.3300 7.1900 6.5967 4.9067 4.2667 14300.0000 14.1800 71.6700 123.5950 21. 0450 14.5350 10.3125 14400.0000 11.1500 68.9300 2179.3999 6064.5400 656.7133 1336.0750 14500.0000 117.9100 46.8000 2179.3999 6064.5400 171.4400 141.9200 14597.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 12977.500000 Tape File End Depth 14597.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet \ '" e e Tape Sub file 3 is type: LIS DEPTH GRAX ROPA RACL RACH RPCL RPCH 12980.0000 121.0700 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12980.2500 117.2167 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13000.0000 44.8500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 10.3900 78.8600 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 10.9900 63.7700 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 12.1600 77.6800 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 14.9100 44.2900 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 12.4900 45.8700 -999.2500 -999.2500 -999.2500 -999.2500 13600.0000 20.2300 74.3800 -999.2500 -999.2500 -999.2500 -999.2500 13700.0000 27.9400 49.7600 14.1680 12.3320 10.9020 10.6080 13800.0000 17.5400 111.4400 20.1225 9.0325 9.1525 8.0075 13900.0000 20.7600 82.9200 27.3300 20.2900 14.9100 12.5400 14000.0000 14.6800 100.3700 3.5933 2.9000 2. 6767 2.3267 14100.0000 12.2900 94.4800 7.4900 8.7680 6.5660 5.7620 14200.0000 14.3400 55.0700 6.6767 5.9400 5.2300 4.7733 14300.0000 11.9000 121.0850 268.1100 22.4600 12.3020 8.4800 14400.0000 11.1900 33.9100 2179.3999 6064.5400 601.7700 592.9500 14500.0000 141. 7300 53.3100 2179.3999 6064.5400 138.1800 114.3200 14597.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 12980.000000 Tape File End Depth 14597.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet e - **** REEL HEADER **** MWD 04/10/27 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/04/13 649753 01 3.125" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 12976.0000: STOP.FT 15379.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 36 TOWN.N 12 RANG. 16 PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 56 DMF KB EKB .F 56 EDF .F N/A EGL .F 0 CASE.F 13002 OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. Remark File Version 1.000 Extract File: Idwg.las 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 1-65A/N-27 Endicott 70 deg 21' 7.180"N 147 deg 57' 26.059"W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - GR/USMPR 13-Apr-04 500292262701 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 vo?t>3-ZIZ- I ;<. 8t~ e e (2) (3) (4 ) (5) Circulating All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is real time data. Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system. Tools run in the string included Casing Coil Locator, Electrical Disconnect and Sub, a Drilling Performance Sub, (inner and outer downhole pressure, downhole weight on bit, downhole temperature), Ultra Slim Resistivity Sub, a Gamma and Directional Sub, And a Hydraulic Orienting with near bit Inclination sensor. (6) Data presented here is final and has been depth shifted to a PDC ( Primary Depth Control) recordeded by SWS on April 14,2004. (7) The sidetrack was drilled from milled window in 4 1/2" tubing. Top of window. 12993.4 ft. MD ( 10031.4 ft. SSTVD ) Bottom of window. 13002.4 ft. MD ( 10031.5 ft. SSTVD ) (8) The interval from 15352 ft. to 15379 ft. MD ( 10182.8 ft. to 10192.5 ft. SSTVD ) was not logged due to bit to sensor offset. (9) Tied in to 1-65/N-25 at 12462 ft. MD. (10) The USR and Gamma Ray data from 13125 ft. to 15050 ft. MD (10026.5 ft. to 10069.0 ft. SSTVD) is merged MAD pass data. (11) The open hole sidetrack was made at 13125 ft. MD (10026.5 ft. SSTVD) from 1-65APB1/N- 27. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPA -> Rate of Penetration, feet/hour RACLM -> Attenuation Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RACHM -> Attenuation Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm RPCLM -> Phase Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RPCHM -> Phase Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm CURVE SHIFT DATA BASELINE, MEASURED, 13003.5, 13001.2, 13041.3, 13038.6, 13060.7, 13055.5, 13203.8, 13199.3, 13229.6, 13223.6, 13281.5, 13277.5, 13293.4, 13288.4, 13306.3, 13301.5, 13310.4, 13304.8, 13333.8,13331.1, 13343.8, 13339.6, 13378.6, 13374.2, 13381. 7, 13376.5, 13404, 13399.2, 13479, 13475.7, 13490.2, 13485.6, 13544,13540.3, 13548.8, 13543.2, 13581.1, 13574.7, 13586.9, 13581. 3, 13602.2, 13599.3, 13614.8, 13610.9, 13711.1, 13709.3, 13719.9, 13715.9, 13744,13740.3, 13761.1, 13758.9, 13775.3, 13772.4, 13780.9, 13777.4, 13823.4, 13819.9, 13830.7, 13827.2, 13847.6, 13846.6, 13918.4, 13915.7, 13943.2, 13939.9, 13962.2,13959.9, 13971.1,13966.9, 13991.3, 13989, DISPLACEMENT -2.28613 -2.70215 -5.19531 -4.57129 -6.02734 -3.94824 -4.9873 -4.78027 -5.61133 -2.70117 -4.15625 -4.36426 -5.19531 -4.7793 -3.3252 -4.57227 -3.74121 -5.61035 -6.44238 -5.61035 -2.91016 -3.94824 -1.87109 -3.94824 -3.74023 -2.28613 -2.91016 -3.53223 -3.53223 -3.53223 -1.03906 -2.70117 -3.3252 -2.28613 -4.15625 -2.28516 e e -3.74121 -3.53223 -4.57129 0.415039 -1.66211 -4.36426 -4.57227 -4.57129 -3.3252 -0.832031 -3.11719 -1.24707 -1.66309 -3.5332 -1. 45508 -1.87012 -0.623047 -2.07812 -1.87012 -1.66309 -1.66211 -2.07812 -3.74121 -3.11719 -1.45508 -3.11719 -1.66211 -2.70215 -2.98047 -10.2168 -9.57812 -6.81055 -6.17285 -1.70312 -1.70312 -1.06445 -0.425781 4.68262 -6.02637 -6.23438 -4.9873 -4.9873 14004.6, 14000.9, 14041.8, 14038.3, 14062.4, 14057.8, 14283.5, 14283.9, 14298,14296.4, 14321.1, 14316.7, 14336.6, 14332, 14342.2, 14337.6, 14415.7, 14412.4, 14432.9, 14432.1, 14453, 14449.9, 14495.9, 14494.7, 14507.4, 14505.7, 14518.8,14515.3, 14539, 14537.6, 14547.8,14545.9, 14661.1,14660.5, 14669,14666.9, 14673.6, 14671.7, 14725.6,14723.9, 14875.6,14873.9, 14937.7, 14935.6, 14943.7, 14940, 14961.7, 14958.5, 14998.6, 14997.2, 15010, 15006.9, 15017.1, 15015.5, 15021.9, 15019.2, 15050.4,15047.5, 15074.1, 15063.9, 15079.4, 15069.8, 15088.3, 15081.5, 15094.5, 15088.3, 15101.3, 15099.6, 15106.6, 15104.9, 15113.9, 15112.8, 15117.5, 15117.1, 15125.1,15129.8, 15149.5, 15143.5, 15200.8, 15194.6, 15233.1, 15228.1, 15256.2, 15251.2, EOZ END BASE CURVE: GRCH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU 150 records... 10 bytes 132 bytes e e WDFN LCC CN WN FN COUN STAT 1-65a.xtf 150 BP Exploration (Alaska) Inc. 1-65A/N-27 Endicott North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 14-Apr-04 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX01 0.0 ROP ROP ROPA01 0.0 RAD RAD RACLX01 0.0 RAS RAS RACHX01 0.0 RPD RPD RPCLX01 0.0 RPS RPS RPCHX01 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (va1ue= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 134 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 12976.000000 15379.000000 0.500000 feet **** FILE TRAILER **** e e Tape Sub file : 2 147 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 BP Exploration (Alaska) 1-65A/N-27 Endicott North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROPA ROPA ROPA 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length e e 1 GRAX MWD 68 1 AAPI 4 4 2 ROPA MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 267 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 12979.000000 15379.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 280 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/04/13 649753 01 **** REEL TRAILER **** MWD 04/10/27 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subfile 1 is type: LIS e e e e Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 12976.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12976.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13000.0000 279.1333 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13050.0000 12.3367 70.6933 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 9.9813 79.0018 -999.2500 -999.2500 -999.2500 -999.2500 13150.0000 12.8369 43.9040 6.2841 4.5641 4.0927 3.4899 13200.0000 14.7424 62.8304 11. 8047 14.1132 12.4800 12.3290 13250.0000 13.1604 63.8149 6.8001 5.3872 4.4073 3.2783 13300.0000 23.4273 79.2687 10.9941 9.4456 8.8752 7.2431 13350.0000 14.0479 63.5459 8.8542 7.8969 6.5706 6.9874 13400.0000 86.6148 81.2837 16.2013 21.0495 15.7011 17.5300 13450.0000 16.0754 86.1334 6.5943 5.0657 4.3546 3.4189 13500.0000 11.0446 65.7929 11.0161 11. 9646 8.3563 10.4384 13550.0000 22.0113 88.6773 14.0391 15.2557 11.8416 9.6502 13600.0000 66.9559 82.4947 18.3017 27.5023 22.7525 32.3993 13650.0000 10.5431 143.2679 5.9649 4.3849 3.7249 3.0674 13700.0000 32.8906 47.2897 11. 6227 15.9250 13.2091 15.5680 13750.0000 77.9013 48.9179 14.8594 21. 0392 19.6348 27.4591 13800.0000 11.8000 90.1300 8.4740 6.1280 5.3880 4.5220 13850.0000 9.0564 79.9243 12.0859 6.1492 5.4073 4.1480 13900.0000 11.3496 76.4109 30.3755 28.8173 e e 14.0367 11.1014 13950.0000 19.0035 25.7481 27.1839 15.6666 11.2729 8.6198 14000.0000 72.0145 75.2683 11. 6163 19.7846 15.3543 37.2259 14050.0000 75.1294 52.4079 1618.9238 6064.5400 29740.2734 53821.6797 14100.0000 9.3588 101.4602 8.7620 15.4665 10.7213 13.6256 14150.0000 17.8176 61.1265 7.6677 9.8274 9.1286 11. 8143 14200.0000 17.1250 77.4900 9.9160 6.8227 7.7686 7.6120 14250.0000 13.6125 79.4819 11.4115 9.2806 7.1720 6.4884 14300.0000 9.5925 74.4659 20.3374 11.0453 7.3986 5.0529 14350.0000 14.8343 60.8548 15.7619 1063.4253 15.1781 12.8105 14400.0000 11.2348 48.0725 14.9588 17.0030 10.6958 9.1184 14450.0000 14.1951 94.7563 24.5521 16.3122 10.9390 9.0137 14500.0000 9.3013 70.1507 12.0093 6.4411 5.5299 4.4680 14550.0000 15.1834 31. 0794 18.7292 21.8464 17.7874 25.2221 14600.0000 14.4998 27.9030 30.4267 7.8030 9.1059 7.7360 14650.0000 10.4390 114.6586 10.2500 6.7975 6.1538 5.2288 14700.0000 12.1995 35.4184 13.9689 33.7525 22.1820 37.7618 14750.0000 10.7328 44.4747 3.8380 3.0859 2.9326 2.8298 14800.0000 11.4616 74.3858 4.2904 3.8288 3.7498 3.7493 14850.0000 12.2328 47.7339 5.6941 5.0501 4.8381 4.7759 14900.0000 10.5121 81. 9508 5.1048 4.3273 4.0952 4.1699 14950.0000 7.9239 71. 2936 4.2432 3.8028 3.5588 3.3564 15000.0000 174.3605 133.0765 17.8653 44.6250 31.2909 50.7257 e e 15050.0000 10.1690 120.9536 22.5310 92.8405 38.6149 66.7233 15100.0000 55.0079 69.7776 147.4813 25.7763 23.3515 22.2042 15150.0000 9.9868 114.7096 8.3878 12.3938 9.5417 13.1058 15200.0000 32.6938 13.8055 14.6437 10.5504 8.2852 6.5587 15250.0000 14.6600 31.2600 7.3300 7.5100 8.3000 10.5900 15300.0000 14.4900 53.0900 6.4400 6.3500 5.9900 6.1000 15350.0000 -999.2500 58.6400 -999.2500 -999.2500 -999.2500 -999.2500 15379.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 12976.000000 Tape File End Depth 15379.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet e e Tape Subfile 3 is type: LIS DEPTH GRAX ROPA RACL RACH RPCL RPCH 12979.0000 120.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12979.2500 118.4100 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13000.0000 44.4400 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13050.0000 9.4800 72.0000 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 10.4700 78.8600 -999.2500 -999.2500 -999.2500 -999.2500 13150.0000 14.6967 32.0200 6.1120 4.1550 3.8800 3.4800 13200.0000 9.7500 63.0600 14.0433 18.4100 14.3267 14.2667 13250.0000 13.3010 59.6100 6.5350 5.9850 4.9233 5.0250 13300.0000 17.6514 67.0400 9.8350 8.1550 7.8850 6.5550 13350.0000 16.1329 73.8700 11.8083 7.9817 6.8500 4.9083 13400.0000 44.1220 76.9600 16.4017 20.7000 17.2117 21.2583 13450.0000 13.0880 67.5500 5.8000 3.9700 3.9100 3.5000 13500.0000 13.0250 66.7200 11. 9957 16.0971 13.6271 16.6886 13550.0000 19.9567 78.8800 13.6900 14.7550 9.1100 6.5450 13600.0000 42.5620 109.1600 20.9930 26.5470 24.0530 27.0190 13650.0000 10.0800 12.5800 6.0386 4.5271 3.8186 3.2200 13700.0000 28.6167 43.7900 11. 0536 16.1882 12.8009 16.4455 13750.0000 83.0214 49.5900 14.4350 21. 9580 19.6390 28.1220 13800.0000 11.1671 136.3150 7.6780 5.5520 4.8330 4.3210 13850.0000 10.0100 73.5000 12.5150 6.4700 5.4550 4.1350 13900.0000 13.7000 73.3500 27.2780 23.3280 e e 12.8720 10.5140 13950.0000 35.6833 90.2300 21. 8900 10.9160 9.2120 9.5140 14000.0000 102.2133 64.0300 14.0800 6064.5400 80.4300 53821.6797 14050.0000 68.8100 48.6200 52.9410 6064.5400 39270.0000 53821.6797 14100.0000 10.4200 101.6600 8.4300 12.9033 7.8067 7.6133 14150.0000 15.2582 64.6600 6.8000 7.0000 6.2100 5.7600 14200.0000 15.3050 75.6600 10.0218 6.4364 5.4400 4.2991 14250.0000 13.9200 79.2400 11.3591 9.2227 7.1064 6.3764 14300.0000 10.2557 75.0900 17.4700 10.4500 7.0800 5.1200 14350.0000 13.3960 63.2100 12.4886 103.5214 22.3629 33.2671 14400.0000 13.6757 36.5600 14.5314 15.9257 11.0286 9.2600 14450.0000 17.3020 74.7200 22.0620 21.1960 20.0460 25.8060 14500.0000 9.6300 66.6300 10.9400 5.4100 4.6300 3.3400 14550.0000 13.4800 36.3800 18.2400 19.1467 12.8967 13.9500 14600.0000 10.3100 50.1150 20.2700 6.3520 5.8660 4.5680 14650.0000 10.1860 145.2900 10.3160 6.7880 6.2000 5.3680 14700.0000 12.4533 77.6700 14.8660 4873.0596 49.0460 551. 0800 14750.0000 9.6175 65.1400 3.7700 2.9000 2.7700 2.6600 14800.0000 9.7060 19.4500 4.0875 3.5825 3.5075 3.5125 14850.0000 11. 9100 56.6000 5.9120 5.3360 5.0680 4.8860 14900.0000 10.3100 131. 0400 5.0800 4.4100 4.2200 4.3700 14950.0000 9.5100 68.8900 4.7800 3.9550 3.5625 3.1000 15000.0000 110.8150 115.9200 12.2160 17.5240 23.2040 42.2780 e e 15050.0000 67.3133 98.9000 22.4750 86.8175 39.0700 69.7900 15100.0000 120.3200 50.7900 197.0100 28.3200 26.3500 25.9300 15150.0000 56.4700 52.7900 22.0300 44.9000 47.4000 78.3400 15200.0000 63.3100 32.3800 37.2200 23.6400 20.1400 18.6500 15250.0000 12.0200 34.2300 5.0500 3.7600 3.3000 2.8200 15300.0000 19.4800 80.7200 6.9200 7.9300 8.6400 11.0200 15350.0000 42.5200 57.7400 -999.2500 -999.2500 -999.2500 -999.2500 15379.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 12979.000000 Tape File End Depth 15379.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ~ rape Subfile 4 is type: LIS e e