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Home My WebLink About203-0211. 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 14,350 feet N/A feet true vertical 10,359 feet N/A feet Effective Depth measured 14,221 feet 11,109 feet true vertical 10,244 feet 8,165 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 11,167' 8,204' 11,109' MD 1,515' MD Packers and SSSV (type, measured and true vertical depth) 9-5/8" Baker S3 8,165' TVD 4-1/2" HES HXO SVLN 1,511' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: N/A Sr Pet Eng: 7,500psi Sr Pet Geo: Sr Res Eng: WINJ WAG 14,904 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 Gas-Mcf 1,902 1,7001,086 318 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 267 1,800 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 172 2,000356 N/A Length 131' 2,448' 131'Conductor Surface Intermediate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-021 50-029-22125-02-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: DUCK IS UNIT SDI 3-25B MD Burst Collapse 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047502, ADL0312828 ENDICOTT / ENDICOTT OIL Hilcorp Alaska LLC measured TVD Plugs Junk measured 8,430psi 9-5/8"4,760psi N/A 5,020psi 6,870psi N/A 2,260psi 131' Production Liner 11,320' 3,183' Casing Structural 8,305' 4-1/2" 11,320' 14,350' 10,360' 2,448' 2,383' 30" 13-3/8" Size PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:15 pm, Oct 30, 2024 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.10.28 12:52:48 - 08'00' Sara Hannegan (2519) DSR-11/6/24 RBDMS JSB 103124 WCB 2-7-2025 Well Name Rig API Number Well Permit Number Start Date End Date END 3-25B Slickline 50-029-22125-02-00 203-021 10/15/2024 10/19/2024 10/19/2024 - Saturday ***WELL S/I ON ARRIVAL*** TAG HXO SVLN @1,515' MD W/ 3.84 CENT BRUSH HXO SVLN W/ 4 1/2" BLB, 3.80 G-RING SET 4-1/2" BBE-SSSV IN HXO-SVLN @ 1,515' MD (sn: HNBB-22, OS-sandwhich single layer pkg W/ OS O-ring, all 3 stacks, 2nd lockdown, 60" oal) SUCCESSFUL DRAWN DOWN TEST W/ PAD-OP ***PAD-OP BROUGHT WELL ONLINE ON DEPARTURE*** ***WELL FLOWING ON ARRIVAL*** (Patch tubing/ liner) RAN 3.85" GAUGE RING TO 4-1/2" BBE AT 1,515' MD (all clear) PULLED 4-1/2" BBE (ser# H4) AT 1,515' MD RAN 2.90" PATCH DRIFT TO 14,100' SLM (no issues - see log) ***WELL S/I ON DEPARTURE*** 10/15/2024 - Tuesday 10/18/2024 - Friday ***JOB CONTINUED FROM 17-OCT-2024*** (HEX PATCH) GET SWAB AND SSV GREASED. PT. 300 LOW AND 2800PSI HIGH RIH WITH HEX PATCH. SET ELEMENT TO ELEMENT: 14070-14085'. CCL TO ME=20.0', CCL STOP AT 14050.0 TOP OF PATCH AT 14067', BOTTOM OF PATCH AT 14087' WELL SECURED. TURNED OVER TO PAD OP TO POP. ***JOB COMPLETED*** Hilcorp Alaska, LLC Weekly Operations Summary 10/17/2024 - Thursday ***WELL FLOWING ON ARRIVAL*** (HEX PATCH) SI WELL TO RUN PATCH. PT TO 200 LOW 3000PSI HIGH, FUNCTION TEST WLVS UNABLE TO GET TOOL WORKING WITH GUN GAMMA ON LINE. DOES WORK WITH JUST CCL. RUN GUN GAMMA/CCL TO 14200-13750 FOR CORRELATION. LOG CORRELATED TO HALLIBURTON PERF LOG DATED 28-JAN-2021 ***JOB CONTINUED ON 18-OCT-2024*** RIH WITH HEX PATCH. SET ELEMENT TO ELEMENT: 14070-14085'. CCL TO ME=20.0', CCL STOP AT 14050.0 TOP OF PATCH AT 14067', BOTTOM OF PATCH AT 14087' _____________________________________________________________________________________ Revised By: DH 10/25/24 SCHEMATIC ENDICOTT Well: END 3-25B Last Completed: 4/25/2003 PTD: 203-021 TD =14,350’ (MD) / TD = 10,359’(TVD) 30” Marker Jts @ 13,881’ & 13,901’ KBE = 55.1’/ BF Elev = ? 9-5/8” 17 3 9 6 4 8 10 5 14 12 13 1 2 11 159-5/8” Whipstock (4/11/2003) @ 11,320’ Tag 14,190’ SLM (14,221’ MD) on 4/14/2018 MIN Lower ID = 1.00”@ 14,067’ PBTD =14,258’ELM(MD) / PBTD =10,276’(TVD) 7 13-3/8” 4-1/2” 9-5/8” EZSV (4/11/2003 MIN Upper ID = 3.725”@ 11,155’ 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 30" Conductor N/A N/A Surface 131’ 13-3/8" Surface 68 / NT-80 / BTC 12.4515 Surface 2,448’ 9-5/8”" Production 47 / NT80 HS / NSCC 8.681 Surface 11,320’ 4-1/2” Liner 12.6 / 13Cr80 / Hydril 563 3.958 11,167’ 14,350’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr80 / VAM-ACE 3.958 Surface 11,167’ JEWELRY DETAIL No Depth Item 1 1,515’ 4-1/2” HES HXO SVLN – ID= 3.813 GLM Detail: MMGM / RK Latch / 1-1/2” GLV 2 3,837’ST 6:Port= 16, Dev= 48, Vlv= Dome, TVD= 3,505’, Date= 5/04/18 3 5,711’ST 5:Port= 20, Dev= 49, Vlv= Dome, TVD= 4,725’, Date= 5/04/18 4 7,262’ST 4:Port= 0, Dev= 49, Vlv= Dome, TVD= 5,753’, Date= 5/04/18 5 8,475’ST 3:Port= 0, Dev= 55, Vlv= Dmy, TVD= 6,503’, Date= 4/27/03 6 9,688’ST 2:Port= 0, Dev= 52, Vlv= Dome, TVD= 7,239’, Date= 5/04/18 7 10,850’ST 1:Port= 0, Dev= 49, Vlv= S/O, TVD= 7,995’, Date= 5/04/18 8 11,088’ HES X Nipple 9Cr – ID=3.813” (ELMD @ 11,095’ on 04/29/03) 9 11,109’ 9-5/8” Baker S-3 Production Packer 10 11,134’ HES X Nipple 9Cr – ID=3.813” 11 11,145’ Baker Liner Tie Back Sleeve 12 11,155’ HES XN Nipple 9Cr – ID= 3.725” 13 11,166’ 4-1/2” WLEG Fluted 9Cr – Bottom @ 11,167’ 14 11,167’ Baker 9-5/8” x 7” Flex Lock Liner Hanger 15 11,176’ Cross Over 7” x 4-1/2” Hydril 563 – ID=3.90” 16 13,825’ Owen X-Span Perm. Patch, ID=2.992” 04/20/18, Bottom @ 13,840’ 17 14,067’ Interwell HEX Patch,ID= 1.00”, set 10/18/24, Bottom @ 14,087’ PERFORATION DETAIL Sands Top (MD)Btm (MD) Top (TVD) Btm (TVD)FT Date Status S3A3 13,749’ 13,769’ 9,823’ 9,841’ 20 3/1/2022 Open S3A2 13,828’ 13,838’ 9,892’ 9,901’ 10 04/20/17 Isolated on 4/20/18 K2A 14,075’ 14,080’ 10,114’ 10,118’ 5 1/28/2021 Isolated on 10/18/24 K2A 14,153’ 14,163’ 10,182’ 10,191’ 10 04/12/17 Open K2A 14,182’ 14,196’ 10,208’ 10,220’ 14 04/29/03 Open Ref Log: SLB PDC GR/CCL 04/29/2003 – Angle at Top Perf= 27 Deg. @ 14,182’ OPEN HOLE / CEMENT DETAIL 30" Driven 13-3/8" 2629 cu ft Permafrost in 17-1/2” Hole 9-5/8” 3448 cu ft Class “G” in 12-1/4” Hole 4-1/2” 8943 cu ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 11,320’ Max Hole Angle = 59 deg. @ 11,707’ TREE & WELLHEAD Tree 4-1/16” Cameron Wellhead 13-5/8” 5K McEvoy GENERAL WELL INFO API: 50-029-22125-02-00 Original Completion by Doyon 15 – 03/28/1991 Sidetracked and Completed by Doyon 15 – 10/29/1993 Sidetracked and Completed by Doyon 15 – 04/21/2003 Perf Add – 4/20/2017 Install Perm Patch Across S3A2 Perfs – 4/20/2018 Install HEX Patch Across K2A Perfs – 10/18/2024 9-5/8” WINDOW DETAIL 11,320’ TOP / 11,336’ Bottom SAFETY NOTE: H2S Reading Average 230 – 260 PPM on A/L & Gas Injectors. Well Requires a SSSV. Chrome Tbg/ Liner & Jewelry 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: 10/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241030 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-26 50283202010000 224098 10/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/14/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/12/2024 AK E-LINE Perf GP-ST-18742-33 50733203060000 177032 10/9/2024 AK E-LINE LeakDetect/Packer IRU 11-06 50283201300000 208184 10/4/2024 AK E-LINE Plug/Perf MPU B-28 50029235660000 216027 10/4/2024 READ CaliperSurvey MPU F-13 50029225490000 195027 10/15/2024 READ CaliperSurvey MPU L-36 50029227940000 197148 10/17/2024 READ CaliperSurvey MRU G-01RD 50733200370100 191139 10/10/2024 AK E-LINE Hoist NCIU A-21 50883201990000 224086 10/8/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/1/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/11/2024 AK E-LINE Perf PBU 06-18B 50029207670200 223071 10/2/2024 HALLIBURTON RBT PBU 14-32B 50029209990200 224073 10/13/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON WSTT PBU NK-26A 50029224400100 218009 10/14/2024 HALLIBURTON PPROF PCU 02A 50283200220100 224110 9/30/2024 AK E-LINE CBL PCU 02A 50283200220100 224110 10/4/2024 AK E-LINE Perf SDI 3-25B 50029221250200 203021 10/17/2024 AK E-LINE Patch Please include current contact information if different from above. T39726 T39727 T39728 T39732 T39733 T39734 T39735 T39736 T39737 T39738 T39739 T39739 T39740 T39741 T39742 T39742 T39743 T39744 T39744 T39745SDI 3-25B 50029221250200 203021 10/17/2024 AK E-LINE Patch Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.01 13:27:33 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240509 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 4/17/2024 HALLIBURTON MFC END 3-25B 50029221250200 203021 3/31/2024 HALLIBURTON PPROF MPU J-16 50029226150000 195169 3/28/2024 HALLIBURTON WFL-TMD3D NCIU A-18 50883201890000 223033 5/1/2024 READ Multiple Array PProf PBU B-05D 50029202760400 213069 4/24/2024 HALLIBURTON RBT PBU C-16C 50029204380300 213191 4/26/2024 HALLIBURTON RBT PBU D-18B 50029206940200 215001 4/21/2024 HALLIBURTON RBT TBF A-07 50733200360000 167046 4/17/2024 HALLIBURTON RBT TBF A-18 50733201430000 168076 4/16/2024 HALLIBURTON RBT Please include current contact information if different from above. T38771 T38772 T38773 T38774 T38775 T38776 T38777 T38778 T38779 END 3-25B 50029221250200 203021 3/31/2024 HALLIBURTON PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 12:46:46 -08'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221202 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-34 50283201860000 222039 11/22/2022 AK E-Line Perf BRU 233-23 50283201360100 222050 11/3/2022 AK E-Line GPT BRU 244-27 50283201850000 222038 11/23/2022 AK E-Line Perf GPT CLU 05RD2 50133204740200 222092 11/17/2022 AK E-Line Perf MPU K-34 50029227120000 196169 11/10/2022 AK E-Line Punch CLU 13 50133206460000 214171 11/12/2022 Halliburton SBHP END 3-25B 50029221250200 203021 11/24/2022 Halliburton PPROF PBU S-15 50029211130000 184071 11/24/2022 Halliburton RBT PBU Z-221 50029237040000 221095 11/17/2022 Halliburton IPROF PBU Z-221 50029237040000 221095 11/19/2022 Halliburton IPROF Please include current contact information if different from above. T37345 T37346 T37347 T37348 T37349 T37350 T37351 T37352 T37353 T37353 By Meredith Guhl at 12:25 pm, Dec 02, 2022 END 3-25B 50029221250200 203021 11/24/2022 Halliburton PPROF Meredith Guhl Digitally signed by Meredith Guhl Date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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer END 3-25B (PTD# 203-0210) IA Exceeded MOASP Date:Friday, September 9, 2022 1:33:00 PM Attachments:image003.png image004.png image005.png image006.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, September 9, 2022 1:22 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Producer END 3-25B (PTD# 203-0210) IA Exceeded MOASP Mr. Regg, Producer END 3-25B (PTD# 203-021) was recently shut in as a result of a facility shutdown. After being shut in, the inner annulus pressure climbed and exceeded MOASP to 2800 psi. Currently the well is shut in and will remain shut in until the facility is online. The well is now classified as UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. Set TTP and DGLVs 2. CMIT-TxIA and MIT-T 3. PPPOT-T/IC 4. Set LGLVs and Pull Plug 5. Additional Diagnostics as required Please respond if there any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Thursday, July 14, 2022 9:58 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Producer END 3-25B (PTD# 203-0210) IA Exceeded MOASP Mr. Regg, END 3-25B (PTD# 203-021) was recently shut in for TAR activities at the facility and subsequently exceeded MOASP to 2750 psi. The OGLV was changed out and the well was brought online for a passing warm TIFL. This passing TIFL demonstrates barrier competency. The well is now reclassified as OPERABLE. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, June 28, 2022 1:11 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Producer END 3-25B (PTD# 203-0210) IA Exceeded MOASP Mr. Regg, Producer END 3-25B (PTD# 203-0210) was recently shut in for the facility TAR. After being shut in, the inner annulus pressure began to climb and exceeded MOASP to 2750 psi. Currently the well is and will remained shut in until TAR activities are completed. The well is now classified as UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. C/O OGLV 2. TIFL 3. Engineer to evaluate additional diagnostics as required Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that anydissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is acceptedby the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer END 3-25B (PTD# 203-0210) IA Exceeded MOASP Date:Thursday, July 14, 2022 10:57:50 AM Attachments:image001.png image002.png PTD 2030210 Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, July 14, 2022 9:58 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Producer END 3-25B (PTD# 203-0210) IA Exceeded MOASP Mr. Regg, END 3-25B (PTD# 203-021) was recently shut in for TAR activities at the facility and subsequently exceeded MOASP to 2750 psi. The OGLV was changed out and the well was brought online for a passing warm TIFL. This passing TIFL demonstrates barrier competency. The well is now reclassified as OPERABLE. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, June 28, 2022 1:11 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Producer END 3-25B (PTD# 203-0210) IA Exceeded MOASP Mr. Regg, Producer END 3-25B (PTD# 203-0210) was recently shut in for the facility TAR. After being shut in, the inner annulus pressure began to climb and exceeded MOASP to 2750 psi. Currently the well is and will remained shut in until TAR activities are completed. The well is now classified as UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. C/O OGLV 2. TIFL 3. Engineer to evaluate additional diagnostics as required Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Sundry 321-039: Endicott Well 3-25B (PTD 203-021) Date:Sunday, February 20, 2022 4:46:35 PM From: Rixse, Melvin G (OGC) Sent: Sunday, February 20, 2022 4:45 PM To: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Subject: RE: Sundry 321-039: Endicott Well 3-25B (PTD 203-021) Joleen, As discussed on the telephone, Hilcorp is approved to utilize perforating guns as described below. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Joleen Oshiro <Joleen.Oshiro@hilcorp.com> Sent: Friday, February 18, 2022 3:39 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Sundry 321-039: Endicott Well 3-25B (PTD 203-021) Hi Mel, Hilcorp would like to propose using 2.875’’ perforation guns to shoot gun run #2 (13,749’ – 13,769’ MD) instead of the 3.125’’ guns noted in the approved sundry (attached). Please let me know if you have any qualms with this proposal. Cheers, Joleen Oshiro Alaska Islands Team Ops Engineer 650-483-4774 joleen.oshiro@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 02/12/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL END 3-25B (PTD 203-021) PERF 01/28/2021 Please include current contact information if different from above. PTD: 2030210 E-set: 34891 Received by the AOGCC 02/12/2021 04/06/2021 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: Perf Add 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14,350'N/A Casing Collapse Conductor N/A Surface 2,260psi Production 4,760psi Liner 6,350psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: David Gorm Operations Manager Contact Email: Contact Phone: 777-8333 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 2/2/2021 4-1/2" Perforation Depth MD (ft): See Schematic ENDICOTT / ENDICOTT OIL DUCK IS UNIT SDI 3-25B 9-5/8" S-3 packer and 4-1/2"HXO SVLN SSSV 11,109' (MD) & 8,164' (TVD) and 1,515' (MD) & 1,511' (TVD) 14,350' See Schematic 131'30" 13-3/8" 9-5/8" 2,448' 4-1/2"3,183' N/A 7,780psi 11,320' 5,020psi 6,870psi 2,383' 8,304' 10,359' 2,448' 11,320' 10,276'2,051 N/A 131'131' 12.6 / 13Cr80 / VAM-ACE TVD Burst 11,167' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047502 & ADL312828 203-021 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22125-02-00 Hilcorp Alaska LLC C.O. 462.007 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size 10,359'14,258' dgorm@hilcorp.com COMMISSION USE ONLY Authorized Name: Authorized Signature: Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:50 pm, Jan 19, 2021 321-039 Chad Helgeson (1517) 2021.01.19 12:32:44 - 09'00' 10-404 DSR-1/19/21MGR19JAN21 X DLB 01/20/2021 Com m. 1/21/21 dts 1/20/2021 X JLC 1/21/2021 RBDMS HEW 1/27/2020 Perf Add Well: END 3-25B PTD: 203-021 API: 50-029-22125-02 Well Name:END 3-25B API Number:50-029-22125-02 Current Status:Online Rig:EL Estimated Start Date:February 2nd, 2021 Estimated Duration:1 day Reg.Approval Req’std? Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:203-021 First Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Second Call Engineer: AFE Number: Well EZ Inputs Required:Yes Current Bottom Hole Pressure:~4,042 psi @ 10,000’ ss TVD Maximum Expected BHP:~4,042 psi @ 10,000’ ss TVD Max. Anticipated Surface Pressure:2,051 psi (Based on 0.1 psi/ft. gas gradient) WHP:1,950 psi Min ID:2.992” ID 4-1/2” Patch at 13,825’ MD Reference Log:Primary Depth Control Press/Temp/GR/CCL, 4-29-2003 Brief Well Summary: 3-25B is a production well from the K2A sands. Objective: Using Eline, perforate the following K2A and S3A3 intervals for increased oil production. Proposed gun run must be confirmed with respect to signed Final Approved Perforation Request Form provided by Reservoir Engineer: Gun Run # Perf Top Perf Bottom Perf Length 1 ±14,075’ ±14,080’ 5 2 ±13,749’ ±13,769’ 20 Total 25 Table 1: END 3-25B Proposed Perf Gun Runs Sundry Procedure (Approval Required to Proceed): Eline 1. RU EL unit and pressure test to 250psi low 3,500 psi high. 2. MU perforating tool string with 2.5”, 6spf, 60 deg phasing guns. 3. RIH and correlate gun run to reference log Perforation Depth Control Log dated 4/29/2003. Contact OE David Gorm at 1(505) 215-2819 prior to perforating for final approval of tie in. 4. Perforate gun run as per Table 1: END 3-25B Proposed Perf Gun Runs. (5’ gun run) POOH. a. Note any tubing pressure change in WSR. 5. MU perforating tool string with 3.125”, 6spf, 60 deg phasing guns. 6. RIH and correlate gun run to reference log Perforation Depth Control Log dated 4/29/2003. Contact OE David Gorm at 1(505) 215-2819 prior to perforating for final approval of tie in. 7. Perforate gun run as per Table 1: END 3-25B Proposed Perf Gun Runs. (20’ Gun Run) POOH. a. Note any tubing pressure change in WSR. 8. RD Eline. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic _____________________________________________________________________________________ Revised By: TDF 6/14/18 SCHEMATIC ENDICOTT Well: END 3-25B Last Completed: 4/25/2003 PTD: 203-021 TD = 14,350’(MD) / TD = 10,359’(TVD) 30” Marker J ts @ 13,881’ & 13,901’ KBE = 55.1’/ BF Elev = ? 9-5/8” 3 9 6 4 8 10 5 14 12 13 1 2 11 15 Tag 14,190’ SLM (14,221’ MD) on 4/14/2018 PBTD =14,258’ELM (MD) / PBTD =10,276’(TVD) 7 13-3/8” 4-1/2” MIN ID = 3.725”@ 11,155’ 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 30" Conductor N/A N/A Surface 131’ 13-3/8" Surface 68 / NT-80 / BTC 12.4515 Surface 2,448’ 9-5/8”" Production 47 / NT80 HS / NSCC 8.681 Surface 11,320’ 4-1/2” Liner 12.6 / 13Cr80 / Hydril 563 3.958 11,167’ 14,350’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr80 / VAM-ACE 3.958 Surface 11,167’ JEWELRY DETAIL No Depth Item 1 1,515’ 4-1/2” HES HXO SVLN – ID= 3.813 GLM Detail: MMGM / RK Latch / 1-1/2” GLV 23,837’ST 6:Port= 16, Dev= 48, Vlv= Dome, TVD= 3,505’, Date= 5/04/18 35,711’ST 5:Port= 20, Dev= 49, Vlv= Dome, TVD= 4,725’, Date= 5/04/18 47,262’ST 4:Port= 0, Dev= 49, Vlv= Dome, TVD= 5,753’, Date= 5/04/18 58,475’ST 3:Port= 0, Dev= 55, Vlv= Dmy, TVD= 6,503’, Date= 4/27/03 69,688’ST 2:Port= 0, Dev= 52, Vlv= Dome, TVD= 7,239’, Date= 5/04/18 7 10,850’ST 1:Port= 0, Dev= 49, Vlv= S/O, TVD= 7,995’, Date= 5/04/18 8 11,088’ HES X Nipple 9Cr – ID=3.813” (ELMD @ 11,095’ on 04/29/03) 9 11,109’ 9-5/8” Baker S-3 ProductionPacker 10 11,134’ HES X Nipple 9Cr – ID=3.813” 11 11,145’ Baker Liner Tie Back Sleeve 12 11,155’ HES XN Nipple 9Cr – ID= 3.725” 13 11,166’ 4-1/2” WLEG Fluted 9Cr – Bottom @ 11,167’ 14 11,167’ Baker 9-5/8” x 7” Flex Lock Liner Hanger 15 11,176’ Cross Over 7” x 4-1/2” Hydril 563 – ID=3.90” 16 13,825’ Owen X-Span Perm. Patch, ID=2.992” 04/20/18 –Btm @ 13,840’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status S3A2 13,828’ 13,838’ 9,892’ 9,901’ 10 04/20/17 Isolated K2A 14,153’ 14,163’ 10,182’ 10,191’ 10 04/12/17 Open K2A 14,182’ 14,196’ 10,208’ 10,220’ 14 04/29/03 Open Ref Log: SLB PDC GR/CCL 04/29/2003 – Angle at Top Perf= 27 Deg. @ 14,182’ OPEN HOLE / CEMENT DETAIL 30" Driven 13-3/8" 2629 cu ft Permafrost in 17-1/2” Hole 9-5/8” 3448 cu ft Class “G” in 12-1/4” Hole 4-1/2” 8943 cu ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 11,320’ Max Hole Angle = 59 deg. @ 11,707’ TREE & WELLHEAD Tree 4-1/16” Cameron Wellhead 13-5/8” 5K McEvoy GENERAL WELL INFO API: 50-029-22125-02-00 Original Completion by Doyon 15 – 03/28/1991 Sidetracked and Completed by Doyon 15 – 10/29/1993 Sidetracked and Completed by Doyon 15 – 04/21/2003 Perf Add – 4/20/2017 Install Perm Patch Across S3A2 Perfs – 4/20/2018 9-5/8” WINDOW DETAIL 11,320’ TOP / 11,336’ Bottom SAFETY NOTE: H2S Reading Average 230 – 260 PPM on A/L & Gas Injectors. Well Requires a SSSV. Chrome Tbg/ Liner & Jewelry _____________________________________________________________________________________ Revised By: TDF 1/19/2021 PROPOSED ENDICOTT Well: END 3-25B Last Completed: 4/25/2003 PTD: 203-021 TD =14,350’ (MD) / TD = 10,359’(TVD) 30” Marker Jts @ 13,881’ & 13,901’ KBE = 55.1’/ BF Elev = ? 9-5/8” 3 9 6 4 8 10 5 14 12 13 1 2 11 15 Tag 14,190’ SLM (14,221’ MD) on 4/14/2018 PBTD =14,258’ELM (MD) / PBTD =10,276’(TVD) 7 13-3/8” 4-1/2 ” MIN ID = 3.725”@ 11,155’ 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 30" Conductor N/A N/A Surface 131’ 13-3/8" Surface 68 / NT-80 / BTC 12.4515 Surface 2,448’ 9-5/8”" Production 47 / NT80 HS / NSCC 8.681 Surface 11,320’ 4-1/2” Liner 12.6 / 13Cr80 / Hydril 563 3.958 11,167’ 14,350’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr80 / VAM-ACE 3.958 Surface 11,167’ JEWELRY DETAIL No Depth Item 1 1,515’ 4-1/2” HES HXO SVLN – ID= 3.813 GLM Detail: MMGM / RK Latch / 1-1/2” GLV 23,837’ST 6:Port= 16, Dev= 48, Vlv= Dome, TVD= 3,505’, Date= 5/04/18 35,711’ST 5:Port= 20, Dev= 49, Vlv= Dome, TVD= 4,725’, Date= 5/04/18 47,262’ST 4:Port= 0, Dev= 49, Vlv= Dome, TVD= 5,753’, Date= 5/04/18 58,475’ST 3:Port= 0, Dev= 55, Vlv= Dmy, TVD= 6,503’, Date= 4/27/03 69,688’ST 2:Port= 0, Dev= 52, Vlv= Dome, TVD= 7,239’, Date= 5/04/18 7 10,850’ST 1:Port= 0, Dev= 49, Vlv= S/O, TVD= 7,995’, Date= 5/04/18 8 11,088’ HES X Nipple 9Cr – ID=3.813” (ELMD @ 11,095’ on 04/29/03) 9 11,109’ 9-5/8” Baker S-3 ProductionPacker 10 11,134’ HES X Nipple 9Cr – ID=3.813” 11 11,145’ Baker Liner Tie Back Sleeve 12 11,155’ HES XN Nipple 9Cr – ID= 3.725” 13 11,166’ 4-1/2” WLEG Fluted 9Cr – Bottom @ 11,167’ 14 11,167’ Baker 9-5/8” x 7” Flex Lock Liner Hanger 15 11,176’ Cross Over 7” x 4-1/2” Hydril 563 – ID=3.90” 16 13,825’ Owen X-Span Perm. Patch, ID=2.992” 04/20/18 –Btm @ 13,840’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status S3A2 ±13,749’ ±13,769’ ±9,823’ ±9,841’ 20 Future Future S3A2 13,828’ 13,838’ 9,892’ 9,901’ 10 04/20/17 Isolated K2A ±14,075’ ±14,080’ ±10,114’ ±10,118’ 5 Future Future K2A 14,153’ 14,163’ 10,182’ 10,191’ 10 04/12/17 Open K2A 14,182’ 14,196’ 10,208’ 10,220’ 14 04/29/03 Open Ref Log: SLB PDC GR/CCL 04/29/2003 – Angle at Top Perf= 27 Deg. @ 14,182’ OPEN HOLE / CEMENT DETAIL 30" Driven 13-3/8" 2629 cu ft Permafrost in 17-1/2” Hole 9-5/8” 3448 cu ft Class “G” in 12-1/4” Hole 4-1/2” 8943 cu ft Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 11,320’ Max Hole Angle = 59 deg. @ 11,707’ TREE & WELLHEAD Tree 4-1/16” Cameron Wellhead 13-5/8” 5K McEvoy GENERAL WELL INFO API: 50-029-22125-02-00 Original Completion by Doyon 15 – 03/28/1991 Sidetracked and Completed by Doyon 15 – 10/29/1993 Sidetracked and Completed by Doyon 15 – 04/21/2003 Perf Add – 4/20/2017 Install Perm Patch Across S3A2 Perfs – 4/20/2018 9-5/8” WINDOW DETAIL 11,320’ TOP / 11,336’ Bottom SAFETY NOTE: H2S Reading Average 230 – 260 PPM on A/L & Gas Injectors. Well Requires a SSSV. Chrome Tbg/ Liner & Jewelry Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL END 3-25B (PTD 203-021) GASSAT AND TMD3D 09/21/2020 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 2030210 E-Set: 34356 Abby Bell 12/09/2020 Hilcorp Alaska, LLC August 26, 2019 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8547 11, /B,2 C F t ~3 Ls ty�7 L—L U, — a_P AUG 2 9 410119 Re: Endicott Conductor Annulus Cement and Corrosion Inhibitor Treatments 8/6/19-8/18/19 Dear Mr. Schwartz, Enclosed please find multiple copies of a spreadsheet with a list of Endicott wells that were treated with cement and corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than water "grease -like" filler displaces water to prevent external casing corrosion that could result in a surface casing leak. The attached spreadsheets include the well names, field, API and PTD numbers, treatment dates and volumes. If you have any additional questions, please contact me at 777-8547 or wrivard@hilcorp.com. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC Endicott Surface Casing by Conductor Annulus Cement Top lob and Fill Coat Corrosion Inhibitor (CI) Applications Well Field API PTD Initial Top of Cement (ft.) Volume of Cement bbls Pumped P ( ) Final Top of Cement (ft.) Cement Pump Date Corrosion Inhibitor Fill Final Cl Top (ft.) Volume (gal) Corrosion Inhibitor Treatment Date 1-61 DIU 50029225200000 1941420 6.5 3.86 1 8/6/2019 23 Flush w/top of conductor 8/18/2019 2-12 DIU 50029223020000 1921170 15 10.18 0.5 8/6/2019 18 Flush w/top of conductor 8/18/2019 3-11 DIU 50029218480000 1880870 9.2 6.11 0.5 8/9/2019 7 Flush w/top of flutes 8/18/2019 3-25B DIU 50029221250200 2030210 12.2 7.87 1 8/9/2019 3 Flush w/top of flutes 8/18/2019 3-41 DIU 50029218780000 1881260 6.4 3.79 1 8/10/2019 5 Flush w/top of flutes 8/18/2019 3-45 DIU 50029218110000 1880510 5.2 2.95 1 8/9/2019 5 Flush w/top of flutes 8/18/2019 3-47 DIU 50029215690000 1860640 2.9 1.33 1 8/9/2019 3 Flush w/tap of flutes 8/18/2019 THE STATE 01ALASKA GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU SDI 3-25B Permit to Drill Number: 203-021 Sundry Number: 318-056 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276 7542 www.aogcc.olasko.gov 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. 4, DATED this 1 S day of February, 2018. Sincerely, Hollis S. French Chair RBDMS L` h_ [ 6 2618 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 0 9 90+13 oU5�15�1$ A0 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: Liner Patch ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑� . Stratigraphic ❑ Service ❑ 203-021 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22125-02-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? Yes ❑ No ❑+ DUCK IS UNIT SDI 3-25B ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADI -004750i & ADL312828 ENDICOTT / ENDICOTT OIL it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,350' - 10,359' 14,258' 10,276' 3,042 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,448' 13-3/8" 2,448' 2,383' 5,020psi 2,260psi Production 11,320' 9-5/8" 11,320' 8,304' 6,870psi 4,760psi Liner 3,183' 4-1/2" 14,350' 10,359' 7,780psi 6,350psi Perforation Depth MO (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6 / 13Cr80 / VAM-ACE 11,167' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (fly 9-5/8" S-3 packer and 4-1/2"HXO SVLN SSSV 11,109' (MD) & 8,164' (TVD) and 1,515' (MD) & 1,511' (TVD) 12. Attachments: Proposal Summary Wellbore schematic L4J 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: 2/28/2018 OIL ❑� - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG p 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman^ Authorized Title: O ons Manager Contact Email: iWellmaD hiIcor .com Contact Phone: 777-8449 Authorized Signature: Date: 2/9/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ A Spacing Exception Required? Yes ❑ No Subsequent Form Required: 18 — "-[VY RBDMS C� f"_:i i (liU APPROVED BY �-_� Z,� 11\0, Approved by: COMMISSIONER THE COMMISSION Date: S ,110Z./s ORIGINAL Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. IV Submit Form and �/� Attachme s in Duplicate Patch S3A2 Well: END 3-25B PTD: 203-021 API: 50-029-22125-02 Well Name: END 3-25B API Number: 50-029-22125-02 Current Status: Online Rig: SL/EL Estimated Start Date: Feb 28, 2018 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Darci Horner 777-8406 Permit to Drill Number: 203-021 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE: WeIIEZ Entry Required: Yes Maximum Expected BHP:—4042psi @ 10,000' TVD (Based on SBHPS on 08/16/16) Max. Anticipated Surface Pressure: 3,042psi (0.1 psi/ft gradient) Min ID: 3.725"4-1/2" XN Nipple @ 11,155' and Brief Well Summary: 3-25B is a production well from the K2A sands. Over the past 7 years, the well's production trend has shown a decrease in gas production. Over this same duration the well's total fluid production has increased. These are possible indications of moving fluid contacts in the reservoir. A RMT -31) log was run on 08/22/17 to check the contacts in the well. Analysis of the log indicated potential re -saturation of the K2A and an additional target in the S3A2 sands uphole. The S3A2 perforations were shot and an immediate but short term oil buzz was produced. The gas rates have climbed to—41mmscfpd since this time. Objective: Set patch across the S3A2 perforations from 13,828'— 13,838' md. Non Sundried Operations Slickline 1. RU SL unit and pressure test to 250psi low/2,000psi.� 2. RIH and pull the 4-1/2" BBE SSSV from 1,515' md. a. Description of the last SSSV installed on 07/22/17: 4.5" BBE SER#HBB-428, SIT DOWN IN SSSV NIPPLE @ 1,484' SLM (1,515' MD), HAND SPANG FOR 10 MINUTES, GET INTEGRITY ON BOTH e�J BALANCE AND CONTROL LINES, SHEAR OFF, LOSE 100#, STILL HAVE CONTROL LINE INTEGRITY, S POOH 3. Drift w/ 3.70" dummy whipstock drift. a. Target depth to achieve is 13,900' md. b. See 4/10/17 -4/11/17 WSR's for reference on previous patch drifts. 4. RD SL unit. Sundried Operations (Approved Sundry required prior to proceeding) E -Line 5. RU EL unit and pressure test to 250psi low 2,500psi high. 6. MU 4-1/2" special clearance_X-Span casing patch toolstring and RIH. a. OD=3.6", Length= 15' element to element. S I'`-41 b. Follow E -Line company's running procedure to minimize chances for premature set. 7. Set patch from +/-13,825'-13,840' md. hw( ro 3 a Z �' l 311 3x Pc. Correlation Log: Pollard Perforation Record dated 20Apri12017. d. Final depths to be adjusted to cover perforation interval previously shot. e. The closest casing collars are located at 13,801' and 13,843' md. Patch S3A2 Well: END 3-256 PTD: 203-021 ua.o alt,, u, API: 50-029-22125-02 f. Slack off weight on patch post setting. 8. POOH and RD E -Line unit. Slickline 9. RU SL unit and pressure test to 250psi low/2,OOOpsi. 10. RIH and set 4-1/2" BBE SSSV at 1,515' md. Description of the last SSSV installed on 07/22/17: 4.5" BBE SER#HBB-428, SIT DOWN IN SSSV NIPPLE @ 1,484' SLM (1,515' MD), HAND SPANG FOR 10 MINUTES, GET INTEGRITY ON BOTH BALANCE AND CONTROL LINES, SHEAR OFF, LOSE 100#, STILL HAVE CONTROL LINE INTEGRITY, POOH 11. RD SL unit. n Rilourp At lla. Lt.0 KBE =55.1'/ BF Elev=? TD=14,350' (MD) / TI) =10,359'(TVD) PBTD=14,258'ELM (MD) / PBTD = 10,276'(TVD) SCHEMATIC ENDICOTT Well: END 3-25B Last Completed: 4/25/2003 PTD: 203-021 SAFETY NOTE: TREE & WELLHEAD H25 Reading Average 230- 260 PPM on A/L & Gas Injectors. Tree 4-1/16" Cameron Well Requiresa555V. Chrome Tbg/ Liner&Jewelry I Wellhead 1 13-5/8"5K McEvoy OPEN HOLE / CEMENT DETAIL 30" Driven 13-3/8" 2629 Cu ftPermafrost in 17-1/2" Hole 9-5/8" 3448 cult Class "G" in 12-1/4" Hole 4-1/2" 8943 cu ft Class "G" in 8-1/2" Hole WELL INCLINATION DETAIL KOP @ 11,320' Max Hole An = 59 deg. @ 11,707' CASING DETAIL Size Type Wt/ Grade/ Conn ID I Top Btm 30" Conductor N/A N/A Surface 131' 13-3/8" Surface 68/NT-80/BTC 12.4515 Surface 2,44F- 9-5/8"" Production 47/NT80 HS/NSCC 8.681 Surface 11,320' 4-1/2" Liner 12.6/13Cr80/Hydril 563 3.958 11,167' 14,350' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 1 3.958 1 Surface 1 11,167' JEWELRY DETAIL No Depth Item 1 1,515' 4-1/2"HESHXOSVLN-10=3.813 Date GLM Detail: MMGM / RK Latch/ 1-1/2" GLV 2 3,837' ST 6: Port= 16, Dev= 48, VIv= Dome, TVD= 3,505', Date= 10/23/10 3 5,711' ST 5: Port= 20, Dev= 49, VIv= Dmy, TVD=4,725', Date= 10/23/10 4 7,262' ST 4: Port= O,Dev= 49, VIv=Dmy, TVD=5,753', Date=4/27/03 5 8,475' ST 3: Port= 0, Dev= 55, VIv= Dory, TVD=6,503', Date=4/27/03 6 9,688' ST 2: Port= 0, Dev= 52, VIv=Dmy, TVD=7,239', Date=4/27/03 7 10,850' ST 1: Port= 0, Dev= 49, VIv=Dmy, TVD=7,995', Date= 4/27/03 8 11,088' HESX Nipple 9Cr - I D=3.813" (ELM D@ 11,095' on 04/29/03) 9 11,109' 9-5/8" Baker S-3 Prod uctionPacker 30 11,134' HESX Nipple 9Cr-ID=3.813" at Top Perf= 27 Deg. @ 14,182' LinerTie Back Sleeve HES XN Nipple 9Cr-ID=3.725" F1111,145'Baker 4-1/2" WLEG Fluted 9Cr- Bottom @ 11,167' Baker 9-5/8"x7" Flex Lock Liner Hanger Cross Over 7" x 4-1/2" Hydril 563 - ID=3.90" PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 53A2 13,828' 13,838' 9,892' 9,901' 10 04/20/17 Open K2A 14,153' 14,163' 10,182' 10,191' 10 04/12/17 Open K2A 14,182' 14,196' 10,208' 10,220' 14 04/29/03 Open Ref Log: SLB PDC GR/CCL04/29/2003-Angle at Top Perf= 27 Deg. @ 14,182' 9-5/8" WINDOW DETAIL 11,320' TOP / 11,336' Bottom GENERAL WELL INFO API: 50-029-22125-02-00 Original Completion by Doyon 25 - 03/28/1991 Sidetracked and Completed by Doyon 15 -10/29/1993 Sidetracked and Completed by Doyon 15 -04/21/2003 Perf Add -4/20/2017 Revised By: TDF 4/26/2017 TD=14,359 (MD) / TO = 10,35YMO) PBTD=14,259 ELM (MD) / PBTD=10,276'(TVD) OPEN HOLE/ CEMENT DETAIL 30" 1 Driven 13-3/8" ENDICOTT 9-5/8" 3448 cu ft Class "G" in 12-1/4" Hole 4-1/2" 8943 cu ft Class "G" in 8-1/2" Hole Well: END 3-258 N/A Surface PROPOSED Last Completed: 4/25/2003 Surface 68 / NT -80 / BTC PTD: 203-021 Surface SAFETY NOTE: TREE & WELLHEAD KBE=55.1'/BFElev=? 47/NT80 HS/NSCC H25 Reading Average 230-260 PPM on A/L&Gas injectors. 1 Tree 4-1/16" Cameron 4-1/2" Liner 12.6/13Cr80/Hydril563 3.958 11,167' 14,350' Well Requires a SSSV. Chrome Tbg/ Liner & Jewelry I Wellhead 13-5/8" 5K McEvoy TD=14,359 (MD) / TO = 10,35YMO) PBTD=14,259 ELM (MD) / PBTD=10,276'(TVD) OPEN HOLE/ CEMENT DETAIL 30" 1 Driven 13-3/8" 2629 cu ft Permafrost in 17-1/2" Hole 9-5/8" 3448 cu ft Class "G" in 12-1/4" Hole 4-1/2" 8943 cu ft Class "G" in 8-1/2" Hole WELL INCLINATION DETAIL KOP @ 11,320' Max Hole Angle = 59 deg. @ 11,707' CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 30" Conductor N/A N/A Surface 131' 13-3/8" Surface 68 / NT -80 / BTC 12.4515 Surface 2,448' 9-5/8"" Production 47/NT80 HS/NSCC 8.681 Surface 11,320, 4-1/2" Liner 12.6/13Cr80/Hydril563 3.958 11,167' 14,350' TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 1 3.958 Surface 11,167' JEWELRY DETAIL No Depth Item 1 1,515' 4-1/2- HES HXO SVLN-ID=3.813 Date GLM Detail: MMGM / RK Latch / 1-1/2" GLV 2 3,837' ST 6: Port= 16, Dev= 48, VIv= Dome, TVD= 3,505', Date= 10/23/10 3 5,711' ST 5: Port= 20, Dev= 49, VIv= Dmy, ND= 4,725', Date= 10/23/10 4 7,262' ST 4: Port= 0, Dev= 49, VIv= Dmy, TVD= 5,753', Date= 4/27/03 5 8,475' ST 3: Port= 0, Dev= 55, VIv= Dmy, TVD= 6,503', Date= 4/27/03 6 9,688' ST 2: Port= 0, Dev= 52, VIv= Dmy, TVD= 7,239', Date= 4/27/03 7 10,850' ST 1: Port= 0, Dev= 49, VIv= Dmy, TVD= 7,995', Date= 4/27/03 8 11,088' HES X Nipple 9Cr- ID=3.813" (ELMD @ 11,095' on 04/29/03) 9 11,109' 9-5/8" Baker S-3 Production Packer 10 11,134' HESX Nipple 9Cr - ID=3.813" 11 11,145' Baker Liner Tie Back Sleeve 12 11,155' HES XN Nipple 9Cr-ID=3.725" 13 11,166' 4-1/2" WLEG Fluted 9Cr- Bottom @ 11,167' 14 11,167' Baker 9-5/8" x 7" Flex Lock Liner Hanger 15 11,176' Cross Over 7" x 4-1/2" Hydril 563 - ID=3.90" 16 ±13,825' X -Span Patch (±13,825'-±13,840' md), ID=2.992" PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status S3A2 13,828' 13,838' 9,892' 9,901' 10 04/20/17 Open K2A 14,153' 14,163' 10,182' 10,191' 10 04/12/17 Open K2A 14,182' 14,196' 10,208' 10,220' 14 04/29/03 Open Ref Log: SLB POC GR/CCL 04/29/2003 -Angle at Top Pert= 27 Deg. @ 14,182' 9-5/8" WINDOW DETAIL 11,320' TOP / 11,336' Bottom GENERAL WELL INFO API: 50-029-22125-02-00 Original Completion by Doyon 15-03/28/1991 Sidetracked and Completed by Doyon 15 -10/29/1993 Sidetracked and Completed by Doyon 15 -04/21/2003 Perf Add - 4/20/2017 Revised By: TDF 2/9/2017 HILCORP ALASKA LLC, DUCK IS UNIT SDI 3-25B (203-021) ENDICOTT, ENDICOTT OIL Monthly Production Rates 10,000,000 s V 0 1,000,000 d fl_ 100,000 0 10,000 m DO s 1,000 0 c0 C 0 100 0 0 CID 10 rG 10,000,000 1,000,000 0 O c CIO 100,000 a n c c n T 10,000 0 0 1,000 3 n T 100 �c 0 S 10 1 i 1 ISIIf bods ry8y tio~o tio~y otio ti 41 1a 41� me ,ac 1 ® Produced Oil (BOPM) • GOR a Produced Gas (MCFM) o Produced Water (SOPM) 10,000,000 1,000,000 0 O c CIO 100,000 a n c c n T 10,000 0 0 1,000 3 n T 100 �c 0 S 10 1 1 bods ry8y tio~o tio~y otio ti 41 1a 41� me ,ac 1 ® Produced Oil (BOPM) • GOR a Produced Gas (MCFM) o Produced Water (SOPM) SPR EADSH EET_Production_Cu Ne—Wel I_VO97_2030210_DI U_SDI_03-25 B_20180213.xlsx 2/13/2018 `2- o3 -02,1 • • -3_,`/C13'& Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 RECEIVED Tele: 907 777-8337 nv-�� Hile .=Vs�rka.l.t.{: Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED OCT 2 4 2017 ,o iSt/201E .1 K. BENDER DATE 10/23/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SDI 3-2513 203-021 Prints: PERFORATION RECORD GR/CCL 2.88 Power Onega HSD CD's 1_ PERFORATION RECORD 4202017 10/23/2017 3:04 PM File folder Please include current contact information if different from above. SCANNED FEB 2 8 20 t3 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 <../7Received 8m 6..."Atee4Date: • • 293- OZ� 213 `) Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Hilcnrp al;erka,t.i.t: RECEIVED Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED OCT 24 2017 `O /It/201'"1 ;vi K. BENDER DATE 10/23/2017 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SDI 3-256 203-021 Prints: THERMAL MULTIGATE DECAY 3 DECECTOR 02222017 TMD3D SIGMA LOG 02192017 CD's I TMD3D_19FEB17 4/11/2017 1:29 PM File folder i TMD3D_22FEB17 4/11/2017 1:29 PM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By:/ ✓d� 1/7 Date: STATE OF ALASKA RECEIVED AIL OIL AND GAS CONSERVATION COASION REPORT OF SUNDRY WELL OPERATIONS APR 2 7 2011 1.Operations Abandon LI Plug Perforations U Fracture Stimulate U Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑., Other Stimulate ❑ Alter Casing ❑ Cha o ram ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 203-021 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 50-029-22125-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047502&ADL312828 DUCK IS UNIT SDI 3-25B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 14,350 feet Plugs measured N/A feet true vertical 10,359 feet Junk measured N/A feet Effective Depth measured 14,258 feet Packer measured 11,109 feet true vertical 10,276 feet true vertical 8,164 feet Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,448' 13-3/8" 2,448' 2,383' 5,020psi 2,260psi Production 11,320' 9-5/8" 11,320' 8,304' 6,870psi 4,760psi Liner 3,183' 4-1/2" 14350 10359 7,780psi 6,350psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet I$ED MAY 1 7202 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/13Cr80/VAM-ACE 11,167' 8,202' 1,515'MD Packers and SSSV(type,measured and true vertical depth) 9-5/8"S-3 4-1/2"HXO SVLN SSSV See Above 1,511'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: 571 6,831 2,603 2,000 326 Subsequent to operation: 922 11,260 4,202 1,700 391 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 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❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: .34-7=0-1-6 '3 12-1000 Authorized Name: Bo York Contact Name: Taylor Wellman Authorized Title: Operations Manager / Contact Email: twellman@hilcorp.cot71 Authorized Signature: ' -2241 17- Dat 4/26/2017 Contact Phone: 777-8449 /771 1 - zo,7 ORIGINAL Form 10-404 Revised 4/2017 RBDMS �/� h1MY 3 O j4 b Suumit Original Only II • ENDICOTT • Well: END 3-25B SCHEMATIC Last Completed: 4/25/2003 e;l1��t„ Ia.- .1�.c PTD: 203-021 SAFETY NOTE: TREE&WELLHEAD KBE=55.1'/BF Elev=? H2S Reading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/16"Cameron Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K McEvoy 'i 3a I, OPEN HOLE/CEMENT DETAIL . 1 30" Driven ', 13-3/8" 2629 cu ft Permafrost in 17-1/2"Hole 9-5/8" 3448 Cu ft Class"G"in 12-1/4"Hole 4-1/2" 8943 Cu ft Class"G"in 8-1/2"Hole 2; WELL INCLINATION DETAIL 73-3/8"4I IL KOP @ 11,320' Max Hole Angle=59 deg.@ 11,707 CASING DETAIL 3 Size Type Wt/Grade/Conn ID Top Btm I 30" Conductor N/A N/A Surface 131' 13-3/8" Surface 68/NT-80/BTC 12.4515 Surface 2,448' 4 9-5/8"" Production 47/NT80 HS/NSCC 8.681 Surface 11,320' 4-1/2" Liner 12.6/13Cr80/Hydril 563 3.958 11,167' 14,350' I TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,167' 5 JEWELRY DETAIL No Depth Item 6 1 1,515' 4-1/2"HES HXO SVLN-ID=3.813 GLM Detail:MMGM/RK Latch/1-1/2"GLV 2 3,837' ST 6:Port=16,Dev=48,VIv=Dome,TVD=3,505',Date=10/23/10 3 5,711' ST 5:Port=20,Dev=49,VIv=Dmy,TVD=4,725',Date=10/23/10 7 4 7,262' ST 4:Port=0,Dev=49,VIv=Dmy,TVD=5,753',Date=4/27/03 5 8,475' ST 3:Port=0,Dev=55,VIv=Dmy,TVD=6,503',Date=4/27/03 6 9,688' ST 2:Port=0,Dev=52,VIv=Dmy,TVD=7,239',Date=4/27/03 7 10,850' ST 1:Port=0,Dev=49,VIv=Dmy,TVD=7,995',Date=4/27/03 8 11,088' HES X Nipple 9Cr-ID=3.813"(ELMD @ 11,095'on 04/29/03) 9 11,109' 9-5/8"BakerS-3 ProductionPacker 10 11,134' HES X Nipple 9Cr-ID=3.813" 11 11,145' Baker Liner Tie Back Sleeve 8 12 11,155' HES XN Nipple 9Cr-10=3.725" 9 13 11,166' 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,167' 14 11,167' Baker 9-5/8"x 7"Flex Lock Liner Hanger 10 15 11,176' Cross Over 7"x 4-1/2"Hydril 563-ID=3.90" MINID=3.725"@ Y 11,155' 11 PERFORATION DETAIL 12 Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status ii ••E 13 14 S3A2 13,828' 13,838' 9,892' 9,901' 10 04/20/17 Open 11 -' 15 K2A 14,153' 14,163' 10,182' 10,191' 10 04/12/17 Open K2A 14,182' 14,196' 10,208' 10,220' 14 04/29/03 Open 17 Ref Log:SIB PDC GR/CCL 04/29/2003-Angle at Top Perf=27 Deg.@ 14,182' 9-5/8" 9-5/8"WINDOW DETAIL 11,320'TOP/11,336'Bottom GENERAL WELL INFO __ API:50-029-22125-02-00 ,861' _ Original Completion by Doyon 15-03/28/1991 Marker.11s21313,901' Sidetracked and Completed by Doyon 15-10/29/1993 -- Sidetracked and Completed by Doyon 15-04/21/2003 Perf Add-4/20/2017 4-1/7' ' AL TD=14,350'(MD)/TD=10,359'(TVD) PBTD=14,258'ELM(MD)/PBTD=10,276'(TVD) Revised By:TDF 4/26/2017 . . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-25B Slickline 50-029-22125-00-00 203-021 4/10/17 4/25/17 Daily Operations: 4/5/2017 -Wednesday No activity to report. 4/6/2017-Thursday No activity to report. 4/7/2017- Friday No activity to report. 4/8/2017 -Saturday No activity to report. 4/9/2017 -Sunday No activity to report. 4/10/2017- Monday WELL FLOWING ON ARRIVAL, (DRIFT 20'x 3.70 DMY WHIP STOCK), PT 250/2,000 PSI. PULLED 4.5" BBE SER#HBB-423 @ 1,483' SLM (1,515' MD). RAN 20'x 3.70" WHIP STOCK DRIFT, UNABLE TO MAKE IT PAST 11,787' SLM, SAT DOWN IN MULTIPLE SPOTS (SEE JOB LOG). RAN BRUSH, 3.70" G-RING SAT DOWN @ 11,470' SLM, UNABLE TO MAKE IT PAST. RAN 5' 3" DRIVE DOWN BAILER AND TAG BOTTOM @ 14,189'SLM. NO RESTRICTIONS, NO SOLIDS IN BAILER. 4/11/2017-Tuesday WELL S/I ON ARRIVAL(DRIFT FOR ELINE), PT 250/2,000 PSI). RAN 3.67" CENT, 5' 2-1/8" STEM, 3.67" DRIVE DOWN BAILER, SAT DOWN IN MULTIPLE SPOTS (SEE JOB LOG),TAG BOTTOM @ 14,193'SLM. RECOVERED A LARGE CHUNK OF CEMENT LODGED IN BOTTOM OF BAILER. RAN 4.5" GR, 10' 3.70" DUMMY WHIP STOCK AND TAG BOTTOM @ 14,193' SLM, NO RESTRICTIONS. RAN 4.5" GR, 20' 3.70" DUMMY WHIP STOCK AND SIT DOWN @ 11,783' SLM, UNABLE TO WORK PAST. RDMO. I Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-25B Slickline 50-029-22125-00-00 203-021 4/10/17 4/25/17 Daily Operations: 4/12/2017-Wednesday ***WELL SHUT IN UPON ARRIVAL*** (ELINE ADPERF). PT 250# LOW/2000# HI. RAN 10' X 2.875" PERF GUN AND PERFORATED INTERVAL FROM 14,153' - 14,163' (NO PRESSURE CHANGE) (6 SPF/60 DEG PHASING). TIED INTO SLB PRIMARY DEPTH CONTROL LOG DATED 4/29/2003. ***WELL TURNED OVER TO OPS TO POP- NOTIFIED PAD OP OF DEPATURE***. 4/13/2017-Thursday No activity to report. 4/14/2017- Friday No activity to report. 4/15/2017-Saturday No activity to report. 4/16/2017-Sunday No activity to report. 4/17/2017- Monday No activity to report. 4/18/2017-Tuesday No activity to report. • 410 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 3-25B Slickline 50-029-22125-00-00 203-021 4/10/17 4/25/17 Daily Operations: 4/19/2017 Wednesday No activity to report. 4/20/2017 -Thursday Pressure test= LPT 350 PSI. HPT 2,200 PSI. RIH W/ 10' x 2.88" PJO. PERFORATE INTERVAL 13,8281-13,838'. L OG CORRELATED TO SLB PDC DATED 29-APR-2003. RELEASED WELL TO OPS TO POP- NOTIFIED PAD OP AND ISLAND OF DEPARTURE. ***JOB COMPLETE*** 4/21/2017 - Friday No activity to report. 4/22/2017 -Saturday No activity to report. 4/23/2017-Sunday No activity to report. 4/24/2017- Monday No activity to report. 4/25/2017 -Tuesday ***WELL FLOWING ON ARRIVAL*** (set sssv). PT PCE 250#-LOW/2,300#-HIGH. RAN 3.805" G. RING &4-1/2" BRUSH TO BRUSH HXO NIPPLE AT 1,515' MD. SET 4-1/2" BBE SSSV(HNBB-11) IN HXO NIP AT 1,515' MD ***3 sets standard pkg w/o- rings***. PERFORMED PASSING DRAWDOWN TEST ON BBE. ***WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED***. • • \Al//7 ,v THE STATE Alaska Oil and Gas 14 of LAS KA Conservation Commission 333 West Seventh Avenue 141t GOVERNOR BILL WALKER �\nh Anchorage, Alaska 99501-3572 g Main: 907.279.1433 F ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov 171 Bo York i. 0 4 L., Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU SDI 3-25B Permit to Drill Number: 203-021 Sundry Number: 317-106 Dear Mr. York: 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, Cathy P Foerster Chair DATED this I day of March, 2017. RDD S MAR 2 3 2E7 • al RECEIVED STATE OF ALASKA MAR 0 7 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION pc7T 3/ 15-j/7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate Q. Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing0 0 Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory 0 Development Q 203-021 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service 0 6.API Number: Anchorage Alaska 99503 50-029-22125-02-00 • 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 SDI 3-25B • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047502 i A'L 3(Z.�y ENDICOTT/ENDICOTT OIL - 11. Att PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,350' ' 10,359' ' 14,258' 10,276' 2,050psi 'f N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,448' 13-3/8" 2,448' 2,383' 5,020psi 2,260psi Production 11,320' 9-5/8" 11,320' 8,304' 6,870psi 4,760psi Liner 3,183' 4-1/2" 14,350' 10,359' 7,780psi 6,350psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/13Cr80/VAM-ACE 11,167' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"S-3 packer and 4-1/2"HXO SVLN SSSV 11,109'(MD)&8,164'(TVD)and 1,515'(MD)&1,511'(TVD) 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development❑✓ Service 0 14.Estimated Date for 15.Well Status after proposed work: - 1-Apr-17 Commencing Operations: OIL O WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 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'?°J Email twellman©hilcorp.com Printed Name Bo York Title Operations Manager Signat ^R YW IL Phone 777-8345 Date 3/7 II COMMISSION USE ONLY Conditions of appro : Notify Commission so that a representative may witness Sundry Number: 3'-7- I O(4 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ ' -!-r, ''j(% 5111- Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No d Subsequent Form Required: / 0 "' c/G 1 R q� 2017 S D ' ISS f I 14,:\R L L 3 01-4/ 9Approved � TPROVED BY by: COMMISSIONER THE COMMISSION mont ( Date: 3 s—(7 Form 10-403 Revised 11/2015 Oialailitin for 1 hs from the date of approval. ' Submit Form and Attachment in Duplicate • • Perf K2A&S3A2 Well: END 3-25B PTD:203-021 ILileorp Alaska,LL API:50-029-22125-02 Well Name: END 3-25B API Number: 50-029-22125-02 Current Status: Online Rig: SL/EL Estimated Start Date: April 1, 2017 Estimated Duration: 3 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Darci Horner 777-8406 Permit to Drill Number: 203-021 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907)777-8547 (0) (509) 670-8001 (M) AFE: WeIIEZ Entry Required: Yes Maximum Expected BHP: -4042psi @ 10,000' TVD (Based on SBHPS on 08/16/16) Max.Anticipated Surface Pressure: -2050psi - (Gas lift system pressure) Last SI WHP: 1950psi Stacked out to GL sys. press. 08/16/16 Min ID: 3.725"4-1/2"XN Nipple @ 11,155' and Brief Well Summary: 3-25B is a production well from the K2A sands. Over the past 7 years,the well's production trend has shown a decrease in gas production. Over this same duration the well's total fluid production has increased. These are possible indications of moving fluid contacts in the reservoir. A RMT-3D log was run on 08/22/17 to check the contacts in the well. Analysis of the log indicated potential re-saturation of the K2A and an additional target in . the S3A2 sands uphole. Objective:Add perforations to the following zones as prescribed in the table below. Well will be flow tested and evaluated after each interval. Gun Run# Perf Top Perf Bottom Perf Length Formation 1 +/-14,153' +/-14,163' 10' K2A 2 +/-13,828' +/-13,838' 10' _ S3A2 Total 20' - Table 1: END 3-25B Proposed Perf Gun Runs "1/' f Note: Final depths to be confirmed in "Final Approved Perf Sheet" Qtr ontingency liner patches will be run across each new perf interval in case of detrimental production (high WC 1:/or high gas rates). Proposed patch depths are:+/-14,150'-14,165' and &+/-13,825'-13,840' md. Non Sundried Operations Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and at least 2,000psi high. 3. RIH & pull 4-1/2" BBE SSSV from 1515' and (set on 03/25/17). 4. Drift well w/15'x3.60" dummy gun and tag. a. Target depth to reach is 14,180' md. b. Last tag was on 02/20/17 w/3.0" pump bailer at 14,190' slmd. 5. RDMO SL unit. Sundried Operations(Approved Sundry required prior to proceeding) E-Line 6. RU EL unit and pressure test to 250psi low 2,000psi high. • Perf K2A&S3A2 Well: END 3-25B • PTD:203-021 Haeorp Alaska,Lb 15 4- 2...01- API:50-029-22125-02 7. MU perforating tool string with 10' of 2-7/8", 6spf,guns. 8. RIH and correlate 1st gun run to Tie-In Loi,_Contact OE Taylor Wellman or OE Wyatt Rivard (contact info above) prior to perforating for final approval of tie in. 9. Perforate as per Table 1: END 3-25B Proposed Perf Gun Runs. POOH. a. Correlation Log: SLB PDC Log dated 29-Apr-2003 S b. Note any tubing pressure change in WSR. c. Ensure Correlation Pass and Shooting Passes have CCL displayed for contingency future patch setting correlation. 10. RD Eline. Slickline 11. RU SL unit and pressure test to 250psi low/2,000psi. 12. RIH and set 4-1/2" BBE SSSV at 1515' md. a. Description of last SSSV set on 02/23/17:4.5" BBE SER#HBB4-93. See WSR for full details. 13. RD SL unit. Operations 14. Bring well online and flow test for 4-8 weeks. 15. Evaluate if a patch will be required to isolate the new K2A perforations. If so, see Contingency Section below. Slickline 16. MIRU SL unit. 17. Pressure test to 300psi low and at least 2,000psi high. 18. RIH & pull 4-1/2" BBE SSSV from 1515' and (set on 03/25/17). 19. RDMO SL unit. E-Line 20. RU EL unit and pressure test to 250psi low 2,000psi high. ,� 21. MU perforating tool string with 10' of 2-7/8", 6spf,guns. ,5`5� 22. RIH and correlate 2nd gun run to Tie-In Log, Contact OE Taylor Wellman or OE Wyatt Rivard (contact ra info above) prior to perforating for final approval of tie in. e,Gr 23. Perforate as per Table 1: END 3-25B Proposed Perf Gun Runs. POOH. d. Correlation Log: SLB PDC Log dated 29-Apr-2003 e. Note any tubing pressure change in WSR. f. Ensure Correlation Pass and Shooting Passes have CCL displayed for contingency future patch setting correlation. 24. RD Eline. Slickline 25. RU SL unit and pressure test to 250psi low/2,000psi. 26. RIH and set 4-1/2" BBE SSSV at 1515' md. b. Description of last SSSV set on 02/23/17:4.5" BBE SER#HBB4-93. See WSR for full details. 27. RD SL unit. Operations 28. Bring well online and flow test for 4-8 weeks. • Perf K2A&S3A2 Well: END 3-25B PTD: 203-021 Hilcorp Alaska,LLD API: 50-029-22125-02 29. Evaluate if a patch will be required to isolate the new S3A2 perforations. If so, see Contingency Section below. Contingency: If the K2A or the S3A2 perforations negatively impacts oil production from the existing K2A Slickline 30. RU SL unit and pressure test to 250psi low/2,000psi. 31. RIH and pull the 4-1/2" BBE SSSV from 1,515' md. 32. RD SL unit. E-Line 33. RU EL unit and pressure test to 250psi low 2,500psi high. 34. MU 4-1/2" special clearance X-Span casing patch toolstring and RIH. O'La. OD=3.6", Length = 15' element to element. t. b. Follow E-Line company's running procedure to minimize chances for premature set. 35. Set patch from +/-14,150'—14,165' and and/or from +/-13,825'—13,840' md. c. Final depths to be adjusted to cover perforation interval previously shot. d. The closest casing collars are located at 14,136' and 13,843' md. e. Slack off weight on patch post setting. 36. POOH and RD E-Line unit. Slickline 37. RU SL unit and pressure test to 250psi low/2,000psi. 38. RIH and set 4-1/2" BBE SSSV at 1515' md. c. Description of last SSSV set on 02/23/17:4.5" BBE SER#HBB4-93. See WSR for full details. 39. RD SL unit. • . ENDell:ICOTT • WEND 3H -25B • SCHEMATIC Last Completed: 4/25/2003 hilcorp Alaska,LLC PTD: 203-021 SAFETY NOTE: TREE&WELLHEAD KBE=55.1'/BF Elev=? H2S Reading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/16"Cameron 30.,I L Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K McEvoy OPEN HOLE/CEMENT DETAIL 30" Driven WELL INCLINATION DETAIL �s 1 13-3/8" 2629 Cu ft Permafrost in 17-1/2"Hole KOP @ 11,320' f 9-5/8" 3448 cu ft Class"G"in 12-1/4"Hole Max Hole Angle=59 deg.@ 11,707' 4-1/2" 8943 cu ft Class"G"in 8-1/2"Hole CASING DETAIL 2 i Size Type Wt/Grade/Conn ID Top Btm 13-301 I 30" Conductor N/A N/A Surface 131' ' 13-3/8" Surface 68/NT-80/BTC 12.4515 Surface 2,448' 9-5/8"" Production 47/NT80 HS/NSCC 8.681 Surface 11,320' 4-1/2" Liner 12.6/13Cr80/Hydril 563 3.958 11,167' 14,350' 3 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,167' JEWELRY DETAIL 4 No Depth Item 1 1,515' 4-1/2"HES HXO SVLN-ID=3.813 GLM Detail: MMGM/RK Latch/1-1/2"GLV , 5 2 3,837' ST 6:Port=16,Dev=48,VIv=Dome,TVD=3,505',Date=10/23/10 3 5,711' ST 5:Port=20,Dev=49,VIv=Dmy,TVD=4,725',Date=10/23/10 4 7,262' ST 4:Port=0,Dev=49,VIv=Dmy,TVD=5,753',Date=4/27/03 5 8,475' ST 3:Port=0,Dev=55,VIv=Dmy,TVD=6,503',Date=4/27/03 6 6 9,688' ST 2:Port=0,Dev=52,VIv=Dmy,TVD=7,239',Date=4/27/03 7 10,850' ST 1:Port=0,Dev=49,VIv=Dmy,TVD=7,995',Date=4/27/03 8 11,088' HES X Nipple 9Cr-I0=3.813"(ELMD @ 11,095'on 04/29/03) 7 9 11,109' 9-5/8"Baker S-3 ProductionPacker 10 11,134' HES X Nipple 9Cr-ID=3.813" 11 11,145' Baker Liner Tie Back Sleeve 12 11,155' HES XN Nipple 9Cr-I0=3.725" 13 11,166' 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,167' 14 11,167' Baker 9-5/8"x 7"Flex Lock Liner Hanger 15 11,176' Cross Over 7"x 4-1/2"Hydril 563-10=3.90" 8 4 9 10 MNID"3.725"@ 11,155' 11 12 X14 1 13 14 r 15 PERFORATION DETAIL 17 9-5/8" Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status K2A 14,182' 14,196' 10,208' 10,220' 14 04/29/03 Open Ref Log:SLB PDC GR/CCL 04/29/2003-Angle at Top Perf=27 Deg.@ 14,182' Marker Jts @ 13,881' 13,901' 9-5/8"WINDOW DETAIL GENERAL WELL INFO 11,320'TOP/11,336'Bottom API:50-029-22125-02-00 Original Completion by Doyon 15-03/28/1991 4-1/2" Ail Sidetracked and Completed by Doyon 15-10/29/1993 1D=14,350 (MD)/TD=10,359(TVD) Sidetracked and Completed by Doyon 15-04/21/2003 PBTD=14,258'ELM(MD)/PBTD=10,276'(TVD) Revised By:TTW 03/06/2017 II 4110 ENDICOTT • • Well: END 3-25B PROPOSED SCHEMATIC Last Completed: 4/25/2003 Hilcorp Alaska,LLC PTD: 203-021 SAFETY NOTE: TREE&WELLHEAD KBE=55.17 BFElev=? H2SReading Average 230-260 PPM on A/L&Gas Injectors. Tree 4-1/16"Cameron I Well Requires a SSSV.Chrome Tbg/Liner&Jewelry Wellhead 13-5/8" 5K McEvoy 30"41 OPEN HOLE/CEMENT DETAIL 30" Driven WELL INCLINATION DETAIL 0. 1 13-3/8" 2629 cu ft Permafrost in 17-1/2"Hole KOP @ 11,320' 9-5/8" 3448 cu ft Class"G"in 12-1/4"Hole Max Hole Angle=59 deg.@ 11,707' 4-1/2" 8943 cu ft Class"G"in 8-1/2"Hole CASING DETAIL 2; Size Type Wt/Grade/Conn ID Top Btm 13-3/8"I I1 30" Conductor N/A N/A Surface 131' 13-3/8" Surface 68/NT-80/BTC 12.4515 Surface 2,448' 9-5/8"" Production 47/NT80 HS/NSCC 8.681 Surface 11,320' 4-1/2" Liner 12.6/13Cr80/Hydril 563 3.958 11,167' 14,350' 3 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/VAM-ACE 3.958 Surface 11,167' JEWELRY DETAIL 4 No Depth Item 1 1,515' 4-1/2"HES HXO SVLN-ID=3.813 GLM Detail:MMGM/RK Latch/1-1/2"GLV 5 2 3,837' ST 6:Port=16,Dev=48,VIv=Dome,TVD=3,505',Date=10/23/10 3 5,711' ST 5:Port=20,Dev=49,VIv=Dmy,TVD=4,725',Date=10/23/10 4 7,262' ST 4:Port=0,Dev=49,VIv=Dmy,TVD=5,753',Date=4/27/03 5 8,475' ST 3:Port=0,Dev=55,VIv=Dmy,TVD=6,503',Date=4/27/03 6I 6 9,688' ST 2:Port=0,Dev=52,VIv=Dmy,TVD=7,239',Date=4/27/03 7 10,850' ST 1:Port=0,Dev=49,VIv=Dmy,TVD=7,995',Date=4/27/03 8 11,088' HES X Nipple 9Cr-ID=3.813"(ELMD @ 11,095'on 04/29/03) 7 9 11,109' 9-5/8"Baker 5-3 ProductionPacker 10 11,134' HES X Nipple 9Cr-ID=3.813" 11 11,145' Baker Liner Tie Back Sleeve 12 11,155' HES XN Nipple 9Cr-ID=3.725" 13 11,166' 4-1/2"WLEG Fluted 9Cr-Bottom @ 11,167' 14 11,167' Baker 9-5/8"x 7"Flex Lock Liner Hanger 15 11,176' Cross Over 7"x 4-1/2"Hydril 563-ID=3.90" 8 0,-"-.4 i 9 10 MN ID=3.725"@ 11,155' 11 1, 12 i ,t 13 14 .� r 15 PERFORATION DETAIL 1-7 9-5/8' Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status S3A2 13,828' 13,838' 9,892' 9,901' 10 Future Proposed - K2A 14,153' 14,163' 10,182' 10,191' 10 Future Proposed _ K2A 14,182' 14,196' 10,208' 10,220' 14 04/29/03 Open IV' Ref Log:SLB PDC GR/CCL 04/29/2003-Angle at Top Pelf=27 Deg.@ 14,182' Marker Jts @ 13,881' 13,901' V---7-' 9-5/8"WINDOW DETAIL GENERAL WELL INFO 11,320'TOP/11,336'Bottom API:50-029-22125-02-00 Original Completion by Doyon 15-03/28/1991 4-1/2" Sidetracked and Completed by Doyon 15-10/29/1993 TD=14,350 (MD)/TD=10,359(TVD) Sidetracked and Completed by Doyon 15-04/21/2003 PBTD=14,258'ELM(MD)/PBTD=10,276'(TVD) Revised By:TTW 03/06/2017 • • Davies, Stephen F (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday, March 9, 2017 7:45 AM To: Davies, Stephen F (DOA) Subject: RE: DIU SDI 3-25B (PTD#203-021) Attachments: END 3-25B AOR Map 3-6-2017.pdf Steve, In short,the planned perforations do conform to these requirements. See below for a full explanation for this. The proposed perfs in DUI SDI 3-25B are in the K2A and S3A2. The 1-65A well was a coil tubing sidetrack in 2004, drilled in the K2B.This section remains unperforated within the 1,000' radius of the 3-25B K2B perfs.The perfs displayed on the mother wellbore remain open in the K2B, but fall outside the 1,000' radius. The S3A2 exists only in the mother wellbore (1-65) and is unperforated outside of the 1,000' radius as shown by the well symbol 1-65. The 4-10A well is currently open in both the K2B, and recently perforated (November 2016) in the S3A2, but fall outside the 1,000' radius as displayed by the Active/Open perforations on the map. All other wells are outside the 1,000' radius. If you have any other questions feel free to reach out. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, March 08, 2017 4:37 PM To: Taylor Wellman Subject: DIU SDI 3-25B (PTD #203-021) Taylor, I'm reviewing Hilcorp's Application for Sundry Approvals to add perforations to DIU SDI 3-25B. Rule 3 of CO 462 states: CO 462, Rule 3: Nominal 40-acre drilling units are established for the pool...Each drilling unit shall conform to quarter- quarter governmental sections...No more than one well may be drilled into and produced from each drilling unit. The pool may not be opened in a well closer than a 1000 feet to any well opened to the pool. The pool shall not be opened in any well closer than 500 feet to the exterior boundary of the affected area. 1 • • . Will the planned perforations conform to these requirements? Thank you. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 -25A • \IIIIIHILCORP ALASKA LLC 5/1�a7 1 ♦..,uc /2/19974-- , . ALASKA NORTH SLOPE:ENDICOTT 3-25B AOR MAP-K2A&S3A2 1-21 POSTED WELL DATA –_ 1/1 011 990 - - - - - - - - I- - - - - Well Number -- --_- WELL-SPUD_DATE – • 1127138 9 WELL SYMBOLS • Active Oil D&A Shut In Oil W ! P&A Oil Abandoned Injector 1• ,'( •3 5 INJ Well(Water Flood) • Shut in Injector Water gg 1 7/ • •8 • INJ Well(Gas Injector) tN _..-. .-_.. j Shut in Injector Gas GP i REMARKS 3-5ogle �� Well symbol at top of S3A2 Sand � Active/Open parts in Black 1-65 ` Proposed perfs in red Inactive/Abandoned perfs in pink 12/13/ 995 1 '29 _./ 0501 –♦ - - Red Dashed Circle=1,000'radius Blue Dashed Circle=1,320'(1/4 mile)radius 11/11/1986 / ' 3-25B V- 0 411)•/1312003 994 0 X00 2.000 1-35 3-25_ 3 I FEET 12/30/1986 1�/6/ 9' 1/17 - /� March 6,2017 •h004 x/ 0033-07A , 8/29/1998___\_s. L . , — �_. Illr Nol 3-31 1-43 11 ' 8/7/3-11 988 2 3-09A 9995 1117119! 4/24 1993 ' 16/1988 ! 4-08 c 07 ./6 4�> 1/26 1987 2/'/ 98! -01 ‘14,- 12/,8/ 98• 381-3 DC 9x'75581,9998 3-29 1-45 �� 4; 12/12/1990 12/13/1989 Ael 3 A )///7 315 7/9. 986 ill Kr ) 3- 7 6/4/1586 4-02 4/ 6/1988 PETRA&6201711:27:20 AM • • ,,‘ < et) x IN41 c , „ a ---------------2 -CD E c Cbsl cr' u rz; 14111 iZ 01) CD C° CD a) III cv _gr. grin • - i%no • _virmAsfa 4-- tv) ft""ft g N CNI cv) flit 1114 im" 00) T"' NH. 0 4-1i‹ / / • 4k4 % 3 g 4-3 yf'') CL CO0 I CO To.03 c w jfj 1111 114. • • Kx Post Office Box 244027 Anchorage,AK 99524-4027 JUL 3 !n� Hilcorp Alaska,LLC 0 201,) 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 AOGCC Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster O 3 - 0D- 1 r O� Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 C'D Anchorage, AK 99501 `� Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig New API_WellNo I PermitNumberl WellName I WellNumber I I WellNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/135 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/I37 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/J40 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/Q28 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/Q32 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/Q30 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/S30 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/M35 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 /Image . ~bject Well History File C~ )er 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. ~O ð - £J:LJ Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: {p 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: HelenA Date: 0 .Ja Stage 1 If NO in stage 1 page(s) discrepancies were found: YES I Organizing (done) D Two-sided 1111111111111111111 R~CAN \IIf' Color Items: D Greyscale Items: DI~LDATA ~Diskettes No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: BY: Helen~ Project Proofing BY: Hele~ Scanning Preparation BY: Hele~~ ~ x 30 = pO BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~escan Needed 1 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: I 1 Date: C' 10 651s1 YJ1..!.'J 1111- -III DateO it? ~. óS: Isl \fl.10 + (p ~ T'::>TAL ?AGES 0 (p .n (Count doe. not inc ude cover sheetì A A J Date: 0 to á~1 VV~ 1 NO e::s: /5/ NO YJ1-' Date: 151 III "IIIHIIII lUll 11I1111111111111111 1 Date: 151 Quality Checked 1111111111111111111 - . STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well] Plug Perforations ❑ Stimulate Other Q FURMANITE WRAP Performed: Alter Casing ❑ Pull Tubino Perforate New Pool ❑ Waiver[] Time Extension ❑ Change Approved Program ❑ Operat. Shutdowr❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 203 -0210 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 22125 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 312828 3- 25B/L -27 10. Field /Pool(s): ENDICOTT FIELD / ENDICOTT OIL POOL 11. Present Well Condition Summary: Total Depth measured 14350 feet Plugs (measured) None feet true vertical 10358.63 feet Junk (measured) None feet Effective Depth measured 14258 feet Packer (measured) 11109 feet true vertical 10275.59 feet (true vertical) 8164 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 131' 30" SURFACE - 131 SURFACE -131 Surface 2448' 13 -3/8" 68# N -80 SURFACE - 2448 SURFACE - 2383 5020 2260 Intermediate 11320' 9- 5 /8 "47 #NT- 80 /NT95HSSURFACE - 11320 SURFACE - 8304 6870/8150 4760/5080 Production Liner 3205' 4 -1/2" 12.6# 13CR80 11145 - 14350 8188 - 10359 8430 7500 Liner Perforation depth: Measured depth: O 14182 - 14196 I True Vertical depth: 0 10208 - 10220 Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR80 SURFACE - 11167 SURFACE - 8202 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" X 4 -1/2" BAKER S -3 PKR 11109 8164 N t s. . , 12. Stimulation of cement squeeze summary:�,,1 t Intervals treated (measured): 1 L t 41 Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 696 21,280 1165 1140 Subsequent to operation: 880 13,391 1388 896 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development' 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas LJ WDSPL GSTOR ❑ WINJ ❑ WAG[] GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam J Last Title Data Manager Signature Phone 564 -4091 Date 11/22/2010 Form 10 -404 Revised 10/2010 RBDMS N OV 26 M' sue. � (LL -� Submit Original Only 3- 25B/L -27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/24/2010 T /I /O = 270/1000/140. Temp = 96 *. Bleed OAP to 0 psi (Furmanite prep). No AL. OA FL near surface. IA FL @ 5220' (above sta #5)(280 bbls). Bled OAP to 0+ psi in i j 12 hrs (gas/ < 1 bbl fluid). SI, monitored for 30 min during rig down. No change in I OAP. Job incomplete.* *Will need 37" sombraro for containment. ** Final WHPs = 270/1000/0 +. SSV =C. WV, SSV, MV =O. IA, OA =OTG. NOVP. 3 } 10/24/20101 * * *CONT FROM 10/23/10 WSR * ** (Pre -WH repair) SET 4 -1/2" BBE (SR# BB45 -01) IN SVLN @ 1487' SLM / 1515' MD GOOD CLOSURE CLOSURE TEST (300psi Drawdown) 1 ** *WELL LEFT S /I, WELL TENDER NOTIFIED * ** 10/25/2010 710/950/10. Temp= 112 Bleed IAP to CLP (Furmanite Prep). IAP decreased 50 psi, OAP increased 10 psi overnight. IA FL @ 5165'(276 bbls). Bled I IAP to production from 950 psi to 780 psi in 1.5 hrs. IA FL inflowed 100'. SI, monitored for 30 min. No change in WHPs or IA FL. Job complete. Final WHPs= 1710/780/10. 1 SV= C. WV, SSV, MV= O. IA, OA= OTG. NOVP. i 3 G 10/30/2010 T /I /O= 950/800/45. Temp =110 *. OART (eval BUR) with well online ( Furmiate IfPrep). No AL. OA FL near surface. Bled OAP from 45 psi to 0 psi in 15 mins (fluid 1 !to surface), hold open bleed for 1 hr. SI OA bleed, monitor OA BUR for 4 hrs (see € log for details). Job Complete. Final WHPs 950/800/2. SV =C WV,SSV,MV =O IA,OA =OTG NOVP i I i i 10/31/2010T/I/0= 970/20/7. Temp= 113 °. WHPs (post IA bleed) & OA BUR - pre Furmanite. No AL. TP increased 20 psi, IAP & OAP unchanged since last night. SV =C. WV, SSV & MV =O. IA & OA =OTG. NOVP. j i [ i i I j I 10/31/2010,T/1/0= 950 /800 /7.�Temp =110 °. Bleed IA & AL to 0 psi. (Furmanite prep). AL 'disconnected. OA increased 5 psi since day shift. IA FL @ 4480' (240 bbl). Bled IAP to 20 psi in 6 hr. Monitor 30 min, IAP unchanged. Final WHPs= 950/20/7. I Job complete. I =SV =C. WV, SSV, MV =O. IA &OA =OTG. NOVP. � , s i l _. 11/3/20103T/I/O= 990/24/21. Temp= Hot. IA & OA FL (pre - Furmanite wrap). No AL. IA FL @ 14494' (between sta # 5 & 6). OA FL near surface. Well cellar measures 53" below I !floor grating, cellar culvert measures Tx 7'. 3 SV= closed. WV,SSV,MV =open. IA,OA =open to gauge. NOVP. j i � I i i 3 f { j t 11/5/2010T/1/O= 950/24/22. Temp= Hot, Bleed OAP to 0 psi, install N2 cap on OA — 50' -W I (Furmanite wrap). No AL. OA FL near surface. Bled OAP from 22 psi to 0 psi in 30 j minutes (all gas). Rigged up N2 to OA, increased OAP from 0 psi to 50 psi in 5 !minutes. Monitored for 30 minutes. OAP unchanged, OA FL push to 50'. Removed floor grating, installed heater trunk into cellar then covered cellar w/ visqueen. Final 1 WHPs= 950/24/50. Job completed. !SV= closed. WV,SSV,MV =open. IA,OA =open to gauge. NOVP. LL 11/6/2010 T /1 /0= 980/24/55. Temp= Hot. Assist w/ Furmanite Wrap (SH repair). No AL. O P & OA FL unchanged. CCI sandblasted surface casing. Furmanite applied a -glass to surface casing. See log for details. r i f i 11/7/2010 1000/0/0. Temp= Hot Assist w/ Furmanite Wrap (SH repair). Monitor open bleed on OA during Furmanite wrap. Furmanite applied first layer of carbon fiber wrap. See log for details. l � fi ( � 1 i s 3 I 11/8 /2010'"Continue WSR from 11/07/10. ** ;Assist w /Furmanite wrap. (SH repair). Maintain open bleed on OA during furmanite 1wrap. Furmanite wrap completed @ 1300 hrs, begin 7 day cure. See log for details. * * *DHD: Performed Well Control Safety Drill * ** E � I i 11/9/2010; * *Continue WSR from 11/08/10. ** Assist w /Furmanite wrap. (SH repair). Maintain open bleed on OA during furmanite 'wrap. See log for details. s j E 11/10/2010"Continue WSR from 11/09/10. ** IAssist w /Furmanite wrap. (SH repair). Maintain open bleed on OA during furmanite 1 !wrap. See log for details. I 1 11 /11 /2010 1 *Continue WSR from 11 /10/10. ** Assist w /Furmanite wrap. (SH repair). Maintain open bleed on OA during furmanite -wrap. See log for details. I i i i 3 11/12/2010 T /I /O = 1000/0/4. Temp = 90 °. * **Continued from previous day's AWGRS. Assist I �w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for j F sdetails. [ i i ` I 1 I l i 3 11/13/2010'T/1/0=1000/0/4. Tem 90 °. ** *Continued from p revious day's AWGRS. Assist P= P Y `w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for details. j � I i i F 11/14/2010 TWO - 1000 /3/2. Temp = 90 ** *Continued from previous day's AWGRS. Assist 1 w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for details. G 4 j 1 i I i 11/15/2010�T/I/0 = 1000/8/4. Temp = 90 ** *Continued from previous day's AWGRS. Assist j I jw /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for I 'details. € t € I 3 11/16/2010 TWO = 1000/26/4. Temp = 90 ** *Continued from previous day's AWGRS. Assist �w /Furmanite wrap. (SH repair). Monitor well during Furmanite curing. * *See log for details. Final WHPs= 1000/27/0. 3 SV= closed. WV,SSV,MV =open. IA,OA =open to gauge. NOW. I ` s 3 11/20/2010 T /1 /O= 1000/27/12. Temp =120 *. MIT OA to 1200 psi PASSED, (SH repair) Well on injection. OA FL near surface. Pressured OA to 1200 psi with 3.25 bbls diesel in 15 min. OAP lost 30 psi in 1st 15 min. and 0 psi in the 2nd 15 min. for a total loss of 30 psi in 30 min. TP and IAP were unchanged during MIT. Bled OAP from 1170 psi to E 10 psi in 4 minutes (2 bbls returns). During bleed TP and IAP remained unchanged. (Monitored for 30 min., OAP increased 20 psi. Job Complete. Final WHPs= 1000/27/30. j ASV =C. WV, SSV, MV =O. IA, OA =OTG. NOVP. a I ° ' . RT ELEV = 551' TREE: 4-1/16 psi Chrome CIW BF. ELEV = 15.28' END3-25B WELLHEAD: 135(8"5,000 psi McEvoy 6 3887 36W DOW RK 16 1012311 MMGM 1-1/2 valve RXF LATCH 4-11r x 1-1/r MMGM GAS LIFT MANDRELS V GA Be NO, MD TVD #6 3,887 3500 —4-112"X NIPPLE #5 5,711 4750 3.$IrID Eil #4 7.262 5750 x 4-1r2 BAKER S-3 PACKER 11,109 #3 8,475 6600 1#2 1 9,M 1 7250 3.813'ID EM Note: Tailpipe stung into finer top +/- 25* 4-1/2'x 4-1/2'WLEG ELMD MARKER JOINT 1300-13900' 9-5/8'Ellne set Bridge Plug Q 11 344' x PERFORATION SUMMARY 6' Hole drill to 14,429 In 2001 REF LOG: Sjxrry-Sun MWD Left BHA fish 13,491-13,623' CO. SIZE I SPF INTERVAL Suspended 2001 x x 2003 SIDETRACK INFO 8.5" HOLE X 4-1 IT LINER 13 CR HYDRIL 563 LINER PBTD TD 13,8" MD, 10,357'TVD r - , 29#/ft, Iq I I DATE REV BY OCMVIENTS DATE REV BY CONWENTS ENDKX)TT UNIT 04/25103 RLW SIDEIRCK-COWLEtION WELL: 3-25811-27 04129M RLW PERFORATE PEFMTNo: 1 2030210 BPExpbration (Alaska) • ~.... ,k-~. --- MICROFILMED 03/01/2008 DO NOT PLACE ~` ~~`~ ~_ ~..- ~` ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc Schlumberger NO. 4459 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~GANNED OCT 3 1 2007 Company: State of Alaska Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milnl! Pt.,lisburnE D B C CD Well Job# lo!! Description ate l olor F-48 11846815 USIT IV} (..- (' lL> 10/12/07 1 G-19A 11890315 USIT 1'1'1 - t 'd 09/30/07 1 NGI-13 11890313 US IT 1 )"Lt' l- "'), -rAt 09/30/07 1 MPE-30A 11855817 USIT ~Ol -On 10/01/07 1 F-11 B 11649954 MCNl ;:)cf-I- 10,'-( -# ,5.s-:t~ 03/22/07 1 1 W-12A 11418301 MCNl } 'ì1f -/?f 'd "I~ç-:¡q 09/10/06 1 1 11·27 11637127 RST i~lL, - 147í ¢ I....."\"'":}(., 06/05/07 1 1 02-22A 11216214 MCNl (){\{) - h~O¡ 1t IS-~ .¡..'+ 10/02/06 1 1 01-16 11630486 RST ,":;L<Jr-(JIYx --''''<'-+1r 06/28/07 1 1 01-14 11801086 RST I/. ~'1-- ()+"':} tt. ¡ f\"5 +"i 07/07/07 1 1 l5-05 11767129 MCNl / ... '"'::} -/)("q * , .c::-;c:.-'? 0 06/17/07 1 1 D·21 11626119 RST 1 "x;) - I....~.=> ... , ~~¡,- I 09/12/07 1 1 14-15 11221550 RST 111'1 - ó"lJl...( "JI '~~"Xi } 03/07/06 1 1 D-18A 11695074 RST 0n/-lf'>~'" ,~:.... "75 08/28/07 1 1 14·05A 11813055 RST I CI¡;) -(10 I .. 1 ~-:S-1f 0 06/11/07 1 1-23/0-15 11846802 RST lJ~.(\_ iOtt..('-¡::I* 'It ,< "'5155 08/11/07 1 S-03 11223120 RST ¡Lxi - ,CI,,\ 'It IfÇ,,~~1 06/13/06 1 1-09A1l-21 11849930 RST I C\ -:} - (),9q 11: I ~S- -+ 5"" 08/04/07 1 1 P2-19A 11649963 MCNl ..J,'j''+- Aid .... 1~5":}d 04/22/07 1 1 OWDW-NW 11211370 RST 1)"']:1' I~" -V/~ $:I. 1'559-/ 02/28/06 1 1 K-01 11695073 RST I ~3 - If) I ... /5S1-ö 08/27/07 1 1 11-32 11630498 RST D,L-f- I~ I *" I ~5 G.,CJ 09/03/07 1 1 3-25B/l-27 11630490 RST rC)(~~ - A:;:} ... . ~<:7_sr 07/26/07 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 A~h~"". AK "S03""'L ATTN: Beth £ Received by: C1 "" Date Delivered: 1 0/23/07 . . 07/27/07 Scblullbel'g8P R.E,CErVE[) Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth NO. 4346 JUL 3 0 ZOOl 2.0G1 Company: Alaska Oil & Gas Cons. commsgANMED f1.U G 0 1 Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 (903 -Od I Field: Prudhoe Bay Endicott Well Job# Log Description Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received by: 'df..2 · .'->~' j ~,'''' :_', ):\J~:~~:: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: 02-28B 0-19, 03-17E K-30,03-25B L-27. - - - The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 02-28B 0-19: g03-QOk, -P-14490 Digital Log Images: 50-029- 2184 7 -02 1 CD Rom 03-17E_K-30: QOd -;)«7- 1:t (¿"¡Lf":f;). Digital Log Images: 50-029-21946-05 1 CD Rom 03-25B_L-27: d03 -Oé) / 11: /4l..f7f Digital Log Images: 50-029-22125-02 1 CD Rom scANNI:'D FES 0 12007 1 e e /3515 WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 16, 2003 RE: MWD Formation Evaluation Logs: 3-25BIL-27, AK-MW-2377690 3-25B/L-27: Digital Log Images 50-029-22125-02 :)03- D>I 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ? Date~ SignJ~. . J~Jl/( h ~ 8) «"-:-(.-':,;(,;;;,_ \>z', r'-\.,.: ~.q \"L~ ~) DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030210 Well Name/No. DUCK IS UNIT SDI 3-25B/L27 Operator BP EXPLORATION (ALASKA) INC AP!t: ~=-22(!~ttO ,{ 60 ) MD 14350 ./ TVD 10359 .."" Completion Date 4/29/2003./ Completion Status 1-01l Current Status 1-01l UIC N ---"~-_.._-_._-- ---- -----"'.. ---_.._-------,-- ..__._-~_.,._-_._-,-----------"- REQUIRED INFORMATION Mud log Yes Samples No Directional Surve" Yes ') 4' ----.-.------ -------_..~---_.._..- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES PWD, NEU, DEN, lWD Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from logs Portion of Master Well Data Maint) ) Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments A Directional Survey log is required to be su . ed. This record matically creat om Permit to Drill ule on: 2/6/2003. ~D 11801 LIS Verification 3 11292 14322 Open 6/12/2003 ,~D Directional Survey 11318 14350 Open 4/29/2003 Rpt Directional Survey 11318 14350 Open 4/29/2003 ~ Induction/Resistivity 11292 14322 Open 12/8/2003 This data replaces any previous data received. :~ ~D C Asc 12021 LIS Verification 10501 14251 Case 6/10/2003 Primary Depth Control log J. with Pressure, Temp, GR, CCl /D C Pds 12021 Pressure 5 10501 14251 Case 6/10/2003 Primary Depth Control log with Pressure, Temp, GR, CCl ED C Pds 12021 Temperature 5 10501 14251 Case 6/10/2003 Primary Depth Control log with Pressure, Temp, GR, I CCl ¡ reO C Pds 12021 Casing collar locator 5 10501 14251 Case 6/10/2003 Primary Depth Control log I with Pressure, Temp, GR, i CCl ..(Rpt Pressure 5 Blu 10501 14251 Case 6/10/2003 Primary Depth Control log l with Pressure, Temp, GR, CCl -- ~ ---. ---'-.' ".' --,-- -~, ,-~~------,.,-,-,-_.-.._--------'--'-------'- ---------- --- DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030210 Well Name/No. DUCK IS UNIT SDI 3-25B/L27 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22125-02-00 MD 14350 TVD 10359 Completion Date 4/29/2003 Completion Status 1-01L Current Status 1-01L UIC N 'ED ~---------_.-- 0 Las 12262 Production 14109 14254 Case 11/17/2003 ED 0 Las 12262 Production 14048 14241 Case 11/17/2003 /:~ 0 Las 12262 Production 14071 14263 Case 11/17/2003 0 Las 12262 Production 14037 14230 Case 11/17/2003 ED 0 Las 12262 Production 14080 14275 Case 11/17/2003 ED 0 Las 12262 Production 14027 14221 Case 11/17/2003 ) ED 0 Las 12262 Production 14059 14253 Case 11/17/2003 ~ ED 0 Las 12262 Production 13688 14227 Case 11/17/2003 ]Ïo: Production 5 BM 13688 14236 Case 11/17/2003 Production Log og Casing collar locator 5 BM 13688 14236 Case 11/17/2003 Production Log Log Spinner 5 BM 13688 14236 Case 11/17/2003 Production Log -log Pressure 5 BM 13688 14236 Case 11/17/2003 Production Log ~D Las 11801 Induction/Resistivity 11292 14322 Open 12/8/2003 This data replaces any previous data received. ~D Las 11801 Neutron 11292 14322 Open 12/8/2003 This data replaces any previous data received. ~ Neutron 11292 14322 Open 12/8/2003 This data replaces any previous data received. ~ 0 Las 11801 Density 11292 14322 Open 12/8/2003 This data replaces any previous data received. ~ Density 11292 14322 Open 12/8/2003 This data replaces any previous data received. EYD Las 11801 Rate of Penetration 11292 14322 Open 12/8/2003 This data replaces any previous data received. RPt.- Rate of Penetration 11292 14322 Open 12/8/2003 This data replaces any previous data received. ¡tOg Pressure Blu 13750 14209 Case 3/12/2004 Static Bottom Hole Pressure Survey with I PressurefTemp/GRlCCL JOg Temperature Blu 13750 14209 Case 3/12/2004 Static Bottom Hole Pressure Survey with I PressurefT emp/GRlCCL 1 Log Casing collar locator Blu 13750 14209 Case 3/12/2004 Static Bottom Hole l_______ Pressure Survey with PressurefTemp/GRlCCL ~~,- ~-' - --_._--~, --..----.- .--..,-------.-.- Permit to Drill 2030210 MD 14350 TVD 10359 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y @) Chips Received? v I N Analysis Received? Y~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Well Name/No. DUCK IS UNIT SDI 3-25B/L27 Operator BP EXPLORATION (ALASKA) INC Completion Date 4/29/2003 Completion Status 1-01L Current Status 1-01L Interval Start Stop Sample Set Number Comments Sent Received Daily History Received? (J / N Formation Tops êJ N ~------ I Date: API No. 50-029-22125-02-00 UIC N ) Æ (~ ~- 12/18/03 Schlumberger NO. 3079 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Midnight Sun Prudhoe Bay Endicott Well Job# Log Description Date BL Sepia CD 3-25B/L-27 ~-('~ \ 10563054 SBHP SURVEY 04/30/03 1 A-23 JJf -o~ 10687642 RST/GRA VEL PACK 09/07/03 1 E-102'" \ -- 1 ~ LP 10708040 SBHP SURVEY 12/10/03 1 F-15 . )3 - ) - ., 10684302 DDL 08/29/03 1 D-30A ~C'9-021- 0 10563448 MCNLlSIGMA OS/20/03 1 1 )0 Lft5¿¿; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: Î'.;l ;,~.f) 1 d7\ ?004 ¡ " .l , o......u Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth ç~~ .. "'---. Received by:~("') \ \.~j"",, ~',_Q_~_.>.....~ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 R· ECEIV·· ···E· D 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ;JJ~$!<a Ot~ &. GasCous. Comln~~~ Anmorage '<;--~ ~ '- f\.r c::" ~. D.\~\ \\. "-b -..--....-........ ~03 ~é) \ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska November 25,2003 RE: MWD Formation Evaluation Logs - 3-25B / L-27, AK-MW-2377690 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of Rob Kalish, ~peny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~\.,.l.-^,,~' ~'-..~/~ 1 LDWG formatted Disc with verification listing. API#: 50-029-22125-02 1 \'60 \ Note: This Data Replaces Any Previous Data For Well 3-25B / L-27. RECEIVED DEC 08 2003 Alasf(8 011 & Gas Cons.. (.;OfTlfIliafJion AnchOf'!Qe 1..)6 ~ II' .~--. (j05 ~L> 0- t WLt-L LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE : Distribution - Final Print[ s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. o. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petro-Technical Data Center LB2-1 900 East Benson Blvd. Anchorage, AK 99501 WELL DATE loG TyPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S] REPORT OR BLUELINE Open Hole 1 3-258 10-22-03 Res. Eva!. CH 1 /&éJ 19 ë;ì. 1 1 Mech. CH 1 Caliper Survey Signed: ""'-. ~~)\Jv-.¡ý\'~,-<=-- ~~t)- ~ RECEIVED Date : Print Name: NOV 1 7 2003 AJaska Oil & Gas Cons. ~n Anchomge PRoACTivE DiAGNOSTic SERvicES, INC., PO Box 1 }69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~Dr\"~ .-, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil a.tld Gas Conservation Comm. Attn.: Howard Okland 33 3 West jh Avenue, Suite 100 Anchorage, Alaska June 09, 2003 RE: MWD Fonnation Evaluation Logs - 3-25B / L-27, AK-MW-2377690 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this tratlsmittalletter to the attention of: Rob Kalish, Sperry-Sun Drilling SeIVÍces, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22125-02 r, ~ -\ N ~~f~ ~(}l"- . (\Jf\.JJ ~V r~\J/ ;05 \ .. ,-(). .. \;1)9 o-Ø 7~xo~ \ . )9;-0 c~ ~ ao3-o).-f RECEf\WfO JUN 1 2 2003 A1asK!! 0;-: &Ga~ C.·'~_(~~n ~Cfr.;~" ð ' ¥ Schlumbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well 2-288/0-19 ~ð3-G:'Jl 0 2-288/0-19 ~03 -COl~ 3-17E/K-30~~ "aYr- 3-258/L-27v 03 ~ 4-10A/L-28 (')';;}.... é) ~ * Job# 23205 23204 23292 23256 23321 Log Description PDC GRlCCL RST SIGMA PDC GRlCCL PDC GRlCCL PDC GRlCCL PLEASE ACKNOWLEDGE RECEIPT 8Y SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~'\'{\~ G /' (d - 03 06/03/03 NO. 2872 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott Color Date Blueline Prints CD 04/12/03 1 1 J!JrJ {'?{ 04/12/03 1 1 fi1 02/25/03 1 1 04/29/03 1 1 02/28/03 1 1 ) ç () Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth .-.~'".'':';.>'' 1..... :'pao' ¡"\ ¡ â- ,'1. Received by: r< t:,~ \,,} t:'~ :; r:.!-.; ~//' JI 1:\1 1 ""' f'_in03 . ,_,i'J U ~, .C<2a~~::. "' :;~'~ ':~~ ~:,::: ~l~~ '~~{jf";S- :~Cfnfnt55tOn .~\nchor~e Seblumbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well ,o.'iI (:J:'J:, 2-28B/0-19-...) 2-28B/0-1~ ~ ~ ïj '7 3-17E/K-~~ C}3 .- 0.;1./ 3-25B/L-21J 9 '/-' Q.9.J 4-10A/L-23-...j Color Date Blueline Prints CD 04/12/03 1 04/12/03 1 02/25/03 1 04/29/03 1 02/28/03 1 Job# Log Description 23205 PDC GRlCCL 23204 RST SIGMA 23292 PDC GRlCCL 23256 PDC GRlCCL 23321 PDC GRlCCL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 0/IO--0? 06/03/03 NO. 2872 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott ) ) Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Receiv~~l(/1ðl/ g:¿~J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ') ) 1. Status of Well ŒI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2519' SNL, 759' WEL, SEC. 08, T11N, R17E, UM At top of productive interval 564' NSL, 3493' WEL, SEC. 32, T12N, R17E, UM X = 267782, Y = 5979422 At total depth ;!"of/J.G.. !J?SJ(J&fJQ.1 10. Well Number 651' NSL, 3489' WEL, SEC. 32, T12N, R17E, UM X = 267788, Y = 5979509 3-25B/L-27 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Endicott Field I Endicott Pool KBE = 54.07' ADL 312828 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4-13-2003 4-18-2003 4-29-2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14350 10359 FT 14258 10276 FT ŒI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES,PWD,NEU,DEN,LWD Classification of Service Well 7. Permit Number 203-021 8. API Number 50- 029-22125-02 7 fo ') r~ J. "ì rf 7 (1V '1(},t( 9. Unit or Lease Name X = 270283, Y = 5970978 Duck Island Unit/Endicott 15. Water depth, if offshore 16. No. of Completions 6' - 12' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost 1515' (Nipple) MD 1465' (Approx.) 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Surface 131' Driven 13-3/8" 68# NT -80 Surface 2448' 17-1/2" 2629 cu ft Permafrost 9-518" 47# NT-BO I NT95HS Surface 11320' 12-1/4" 3448 cu ft Class 'G' 4-112" 12.6# 13Cr80 11145' 14350' 8-1/2" 8983 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 SPF MD TVD MD TVD 25. SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 11167' PACKER SET (MD) 111 09' 14182' -14196' 10208' -10220' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 105 Bbls of Diesel. 27. Date First Production May 2, 2003 Date of Test Hours Tested 5-9-2003 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL GAs-MCF TEST PERIOD 1718 2011 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL 416 W ATER-BBL CHOKE SIZE GAS-OIL RATIO 45 IN 1171 OIL GRAVITY-API (CORR) 22.2 CORE DATA Brief description of lithology, p:-o_~~.~~~,fra~ures, apparent dips and presence of oil, gas or water. Submit cOR~C E I \l E IJ' No core samples were taken. '- 28. ; :1 J~c~µ:.. ; ·--.'~-ik~-- ,I: .,' .-. .:....". ~ ,"";,:",.",,-.,,..:" RBDMS BfL ~r- JUN (~ j'.- ,,'[ , t~ ¡ I~~ JUN 0 2. 2003 Alaska O¡i & Gas Cons. CmnmÎ::;sion Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth K3A 13733' 9801' S3A3 13733' 9807' S3A2 13771' 9841' S3A1 13841' 9904' K2B 13849' 9911' K2M 13981' 10029' K2A 14020' 10064' S2A3 14020' 10064' S2A2 14147' 10176' S2A1 14152' 10181' K1 14203' 10226' 31. List of Attachments: ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECE'w ~\.f[·'" ',~ J,~ ~"'~liV.1 ~~ ' ,~' K'::"':I JUN 0 2 7003 Alaska Oil & Gas Gums" Commission Anchorage Summary of Daily Drilling Reports, Surveys, Post Rig Work Summary and a Leak-Off Integrity Test Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed sondr~~-L.t.S:L.-_ Title Technical Assistant 3-25B/L-27 Well Number 203-021 Permit No. I Approval No. INSTRUCTIONS Date 0 Cj - ~ - 0 ~ Prepared By Name/Number: Drilling Engineer: Sandra Stewman, 564-4750 Fred Johnson, 564-5427 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). I;EM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, ~ater Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 OR\G\NAL ) ) BÞEXPLORATION .Operations summary .Report Page 1 of15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-258/L-27 3-258/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From- To Hours Task Code NPT Phase Description of Operätions 4/6/2003 10:00 - 12:00 2.00 MOB P PRE Hold Pre-Job Safety Meeting - Rig Down Lines Between Complexes - Blow Down Rig And Skid Rig Floor - Raise Legs In Cellar Area 12:00 - 14:00 2.00 MOB P PRE Held PJSM - Move Pit And Pump Complex Away From Sub Base And Spot On Location - Move Sub Base Off Well - Load Out Matting Boards And Clean Up Location 14:00 - 16:30 2.50 MOB P PRE Held PJSM - Move Mud Pit Complex From MPI To SDI And Stage On Location 16:30 -19:00 2.50 MOB P PRE Held PJSM - Move Sub Base Complex From MPI TO SDI 19:00 - 20:30 1.50 RIGU P PRE Held PJSM - Move Sub Base Complex Over Well No. 3-15 B / L-27 - Lower Legs And Pre Load - Close Cellar Doors 20:30 - 22:00 1.50 RIGU P PRE Held PJSM - Move Pit Complex And Spot With Sub Base 22:00 - 23:00 1.00 RIGU P PRE Held PJSM - Skid Rig Floor 23:00 - 00:00 1.00 RIGU P PRE Held PJSM - Spot Rock Washer - Rig Up Cellar Area 4/7/2003 00:00 - 06:30 6.50 RIGU P PRE Held PJSM - Berm Up Around Rig - Hook Up Utilities - Hook Up Flare And Gas Buster Lines - Switch Boiler And Turbines Over To Natural Gas - Rig Up Mud Lines, Cellar Pump, And Fill Up Lines - Hook Up Lines Under Rig Floor - Hook Up Auger To Rock Washer *Note* Doyon Rig 15 Accepted For Well Work On 3-25B / L-27 At 06:30 Hours On 04/07/2003 06:30 - 07:00 0.50 WHSUR P DECOMP Held PJSM - Rig Up DSM Lubricator And Pull BPV - Rig Down Lubricator And Clear Rig Floor 07:00 - 08:30 1.50 WHSUR P DECOMP Held PJSM - Dry Rod In TWC Valve - Install Secondary Valve On Tubing Spool - Test TWC Valve From Below To 1,000 Psi. For 10 Minutes (Test Good) 08:30 - 09:00 0.50 WHSUR P DECOMP Held PJSM - Blow Down And Rig Down All Test Lines 09:00 - 10:00 1.00 WHSUR P DECOMP Held PJSM - Bleed Down Pressure On Cameron Adapter Flange And Nipple Down Tree 10:00 - 17:30 7.50 BOPSUR P DECOMP Held PJSM - Nipple Up Mud Cross And Riser Spool - Pick Up BOP Stack And Install On Riser Spool - Nipple Up 13 5/8" 5M BOP Stack And Related Equipment - Install Bell Nipple, Flow Line, And Fill Up Lines - Pick Up Tools And Equipment 17:30 - 18:30 1.00 BOPSURP DECOMP Held PJSM - Fill BOP Stack With Water - Close Blind Rams- Test From Blind Rams To Tubing Hanger At 250 Psi. Low And 4,500 Psi. High (Test Good) - Drain BOP Stack 18:30 - 20:00 1.50 PULL P DECOMP Held PJSM - Pick Up And Make Up Landing Joint To Tubing Hanger - Verify That No Pressure Under Tubing Hanger - Back Out Lock Down Studs - Pull Hanger To Rig Floor - Break Out Landing Joint And Hanger Remove TWC - Lay Down 2 Joints 4 1/2" Tubing With Mule Shoe 20:00 - 21 :30 1.50 BOPSUR P DECOMP Held PJSM - Install Cameron Test Plug - Rig Up Testing Equipment - Flush Lines With Water - Make Up Safety Valve And IBOP Valve 21 :30 - 00:00 2.50 BOPSUR P DECOMP Hold Pre-Job Safety Meeting - Witness Of BOP Test Waived By AOGCC Inspector Chuck Sheave - Test Annular At 250 Psi. Low And 3,500 Psi. High - Test Upper And Lower Pipe Rams, Blind Rams Choke Manifold At 250 Psi. Low And 4,500 Psi. High 4/8/2003 00:00 - 02:00 2.00 BOPSURP DECOMP Hold Pre-Job Safety Meeting - Continue To Test Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves, Manual And HCR Valves On The Choke Printed: 4/28/2003 9:14:27 AM ) ) sF> EXPLORATION Operations· Summary·.Repørt Page 2 of15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-258/L-27 3-258/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From - To Hours Task Code NPT Phase Descrí ptionof Operations . 4/8/2003 00:00 - 02:00 2.00 BOPSUR P DECaMP And Kill Lines At 250 Psi. Low And 4,500 Psi. High - Perform Accumulator Test 02:00 - 02:30 0.50 BOPSUR P DECaMP Hold Pre-Job Safety Meeting - Rig Down Testing Equipment - Remove Test Plug - Install Short Bowl Protector And Energize Lock Down Studs 02:30 - 03:00 0.50 BOPSUR P DECaMP Held PJSM - Blow Down Choke Manifold, Kill And Choke Lines 03:00 - 05:00 2.00 CLEAN P DECaMP Held PJSM - Change Out Saver Sub And Grease Seals On IBOP Accuator On Tesco Top Drive 05:00 - 07:30 2.50 CLEAN P DECaMP Held PJSM - Make Up Mule Shoe And Single In The Hole With 64 Joints Of 5" Drill Pipe To 2013' 07:30 - 08:30 1.00 CLEAN P DECaMP Held PJSM - Circulate Out Diesel Freeze Protection To Tiger Tank At 4 BPM With 20 Psi. 08:30 - 09:00 0.50 CLEAN P DECaMP Held PJSM - Continue To Single In The Hole With 78 Joints Of 5" Drill Pipe From 2,013' To 2,492' 09:00 - 10:00 1.00 CLEAN P DECaMP Held PJSM - POH With 26 Stands Of 5" S-135 Drill Pipe Standing Back In Mast 10:00 - 12:45 2.75 CLEAN P DECaMP Held PJSM - PIU (1) 61/4" Steel Drill Collar, Make Up Cross Over, Bit Sub, Casing Scraper, 8 1/2" Hughes MX -C1 (RR) Bit Ser No. 6008101 - Continue To PIU (8) 61/4" Steel Drill Collars, Cross Over 12:45 - 14:00 1.25 CLEAN N HMAN DECaMP Shut Down Operation And Clean Up Barite Material - Loader Operator Was Attempting To Lift A Pallet Of Barite Onto Trolley On Mud Pallet Lift Under Hopper Room. The Trolley Moved To The Back Of The Pallet Lift And The Loader Operator Was Attempting To Use Some Of The Weight Of The Pallet To Straighten Out The Trolley And It Moved Forward In Doing So The Forks Slipped Out Of The Pallet And Part Of The Barite Sacks Fell To The Rig Mats Below In Secondary Containment See LCIR No. 2003-IR-479877 - Contacted Enviro-Tech - Cleaned Up And Recovered All Barite Product 14:00 - 15:30 1.50 CLEAN P DECaMP Held PJSM - Continue To RIH With BHA NO.1 Picking Up (15) Singles Of 5" HWDP - Steam Out Ice Plugs - Total BHA No.1 Length 740.22 15:30 - 00:00 8.50 CLEAN P DECaMP Held PJSM - RIH With Clean Out Assembly BHA NO.1 Picking Up 292 Singles Of 5" Drill Pipe From 740' To 10,006' 4/9/2003 00:00 - 00:30 0.50 CLEAN P DECaMP Held PJSM - Connect Tesco Top Drive And Establish Circulation At 10,006' - RPM 20, Torque Off Bottom 7,000 ft 1 Ibs - Pump Rate 424 gpm, SPP 1,490 psi, String Weight Up 232,000#, String Weight Down 185,000#, String Weight Rotating 210,000# 00:30 - 02: 15 1.75 CLEAN P DECaMP Held PJSM - RIH With Clean Out Assembly BHA NO.1 From 10,006' To 11,991' Total Of 354 Joints 5" Drill Pipe 02:15 - 03:45 1.50 CLEAN P DECaMP Held PJSM - Connect Tesco Top Drive And Establish Circulation At 11,991' - Pump Hi-Vis Sweep - Pump Rate 585 gpm, SPP 2,590 psi, String Weight Up 285,000#, String Weight Down 208,000# "'NOTE'" When Sweep Came Back To Surface Very Little Solids Back - Well Bore Very Clean - Mix Dry Job 03:45 - 04:00 0.25 CLEAN P DECaMP Held PJSM - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Tesco Top Drive 04:00 - 09:00 5.00 CLEAN P DECaMP Held PJSM - POH With Clean Out Assembly BHA NO.1 - Stand Back 5" Drill Pipe In Mast From 11,991' To 740' Printed: 4/28/2003 9:14:27 AM ) ) BP EXPLORATION OperationsSul1'llT1ary Rep.ort Page 3 of 15· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From -To Hours Task Code NPT Phase Description of Operations 4/9/2003 04:00 - 09:00 5.00 CLEAN P DECaMP 09:00 - 10:30 1.50 CLEAN P *NOTE* Some Drill Pipe Tool Joints Coated With Oil Soaked Ba rite DECaMP Held PJSM - Stand Back BHA NO.1 In Mast (5 Stands) 5" HWDP - (3 Stands) 61/2" Steel Drill Collars - Remove 8 1/2" Bit - Lay Down Cross Over, Bit Sub, And 9 5/8" Casing Scraper - Clear Rig Floor *NOTE* BHA Coated With Oil Soaked Barite 10:30 - 11 :00 0.50 CLEAN P DECaMP Hold Pre-Job Safety Meeting With Schlumberger, Haliburton, And Rig Crew - Regarding E-Line Operation 11 :00 - 12:00 1.00 EVAL P DECaMP Rig Up Schlumberger Tools And Equipment - Make Up 81/2" Gauge Ring, Junk Basket, And CCL - RIH With Logging Tools To 3,200' - Tagged Up, Work Tools Up And Down - Unable To Work Logging Tools Any Deeper 12:00 - 13:00 1.00 EVAL N DPRB DECaMP POH With Schlumberger Logging Tools - Note An Increase Of 1,200 Ibs. Drag Above Normal Up Weight - Junk Basket Full Of Oil Wet Barite 13:00 - 13:30 0.50 EVAL N DPRB DECaMP Held PJSM - Rig Down Schlumberger Logging Tools And Equipment - Clear Rig Floor 13:30 - 14:00 0.50 EVAL N DPRB DECaMP Held PJSM - Perform Upper Mast Inspection 14:00 - 14:30 0.50 EVAL N DPRB DECaMP Held PJSM - Service Rig - Top Drive - Traveling Blocks - And Crown Sheaves 14:30 - 16:00 1.50 CLEAN N DPRB DECaMP Held PJSM - Make Up BHA NO.2 And RIH - Pick Up (1) Stand Of 6 1/2" Steel Drill Collars Lay Down (1) Steel Drill Collar - Pick Up 8 1/2" String Mill, Bit Sub, 9 5/8" Casing Scraper, 8 1/2" Bit And RIH - Pick Up (1) 61/2" Steel Drill Collar - RIH With (2) Stands Of 6 1/2" Drill Collars From Mast - Make Up Cross Over And Pick Up 61/4" Daily Drilling Jars - RIH With (5) Stands Of 5" HWDP From Mast - Total Length Of BHA No.2 At 778.58 16:00 - 17:00 1.00 CLEAN N DPRB DECaMP Held PJSM - RIH With BHA NO.2 On 5" Drill Pipe From 778' To 4,003' 17:00 - 17:30 0.50 CLEAN N DPRB DECaMP Held PJSM - Install Full Opening Safety Valve And Head Pin - Make Up High Pressure Hose To Choke Manifold - Line Up Choke Manifold To Poor Boy Degasser 17:30 - 19:30 2.00 CLEAN N DPRB DECaMP Held PJSM - Reverse Circulate 20 Barrels BaraScrub, 25 Barrels Hi-Vis Sweep At 3 BPM With 100 Psi. - When BaraScrub Turned The Corner Increase Pump Rate To 10 BPM With 750 Psi. *NOTE* Very Little Barite And Lubes Returned At Bottoms Up 19:30 - 20:00 0.50 CLEAN N DPRB DECaMP Held PJSM - Rig Down Circulating Lines And Blow Down - Remove Floor Valve And Head Pin - Consult With Anchorage Drilling Engineer 20:00 - 22:00 2.00 CLEAN N DPRB DECaMP Held PJSM - RIH With BHA NO.2 On 5" Drill Pipe From 4,003' To 11,993' - Lay Down Top Single On Stand No. 118 22:00 - 22:30 0.50 CLEAN N DPRB DECaMP Held PJSM - Install Full Opening Safety Valve And Head Pin - Make Up High Pressure Hose To Choke Manifold - Line Up Choke Manifold To Poor Boy Degasser 22:30 - 00:00 1.50 CLEAN N DPRB DECaMP Held PJSM - Reverse Circulate 20 Barrels BaraScrub, 25 Barrels Hi-Vis Sweep At 12 BPM With 1,890 Psi. 4/10/2003 00:00 - 00:30 0.50 CLEAN N DPRB DECaMP Continue To Reverse Circulate 20 Barrels BaraScrub, 25 Printed: 4/28/2003 9:14:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) BP EXPLORATION Operations Summary Report 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Page 4 of 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 4/10/2003 00:00 - 00:30 From·- To Hours Task Code NPT Phase· DPRB DECaMP Barrels Hi-Vis Sweep At 12 BPM With 1,890 Psi. 00:30 - 01 :00 01 :00 - 02:00 02:00 - 04:45 04:45 - 05:00 05:00 - 09:00 09:00 - 09:30 09:30 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 19:30 0.50 CLEAN N 0.50 CLEAN N 1,00 CLEAN N 2.75 CLEAN N 0.25 CLEAN N 4.00 CLEAN N 0.50 CLEAN N 5.50 CLEAN N 1.50 CLEAN N 0.50 EVAL N 2.50 EVAL P Description of Operations "NOTE" Very Little Barite And Lubes Returned At Bottoms Up DPRB DECaMP Hold Pre-Job Safety Meeting With Little Red Hot Oil Services, Doyon Rig Crews And Baroid Mud Engineers Regarding Pumping Operation DPRB DECaMP Pressure Test Surface Lines To 1,000 Psi. For 5 Minutes (Test Good) - Pump 25 Barrels HI-Vis Spacer - Shut Down And Remove Head Pin - Hook Up Little Red Services To Head Pin And Pump 100 Barrels Of 185 Degree Diesel - Final Circulating Pressure At 800 Psi. - Shut In Full Opening Safety Valve DPRB DECaMP Held PJSM - Break Out Head Pin And Pick Up Single Of 5" Drill Pipe - Connect Tesco Top Drive And Pressure Up To 800 Psi. - Open Full Opening Safety Valve - Up Weight At 285K, Down Weight At 205K, Rotating Weight At 235K - Rotate Drill String At 60 RPM - Continue Pumping 25 Barrel Hi-Vis Spacer, 25 Barrel BaraScrub, 25 Barrel Hi-Vis Spacer, Followed Up With Seawater "NOTE" Lots Of Lubes Back On Bottoms Up - After Bottoms Up Rotary Torque Increased From 11 K To 23K, String Up Weight Increased To 31 OK, String Down Weight Decreased To 212K DPRB DECaMP Held PJSM - Rig Up To Reverse Circulate DPRB DECaMP Held PJSM - Reverse Circulate 25 Barrels, Hi-Vis Spacer 55 Barrels 185 Degree Diesel, 25 Barrels BaraScrub, 25 Barrels Hi-Vis Sweep Followed With Sea Water At 7 BPM With 710 Psi. - Increasd Rate To 14 BPM With 2,100 Psi. "NOTE" Minimal Of Lubes Back On Bottoms Up DPRB DECaMP Held PJSM - Pump Dry Job - Blow Down Top Drive - Choke Manifold - Choke And Kill Lines DPRB DECaMP Held PJSM - POH With Clean Out Assembly BHA NO.2 - Stand Back 5" Drill Pipe In Mast From 11,993' To 778' DPRB DECaMP Held PJSM - Stand Back (5) Stands Of 5" HWDP - Lay Down Daily Drilling Jars - Stand Back (2) Stands 6 1/2" Steel Drill Collars - Place (1) 6 1/2" Steel Drill Collar In Mousehole - POH With (2) 6 1/2" Steel Drill Collars - Break And Lay Down Cross Over, 8 1/2" String Mill, Bit Sub, 95/8" Casing Scraper, And 8 1/2" Bit - Pick Up (1) 6 1/2" Drill Collar From Mousehole And Stand Back (1) Stand Of Drill Collars - Clear Rig Floor "NOTE" BHA Clean From Lubes And Barite, Minimal Amount Located In Spirals On Drill Collars DPRB DECaMP Hold Pre-Job Safety Meeting With Schlumberger, Halliburton, And Rig Crew - Regarding E-Line Operation DECaMP Rig Up Schlumberger Tools And Equipment - Make Up Collar Locator, Weight Bar, And EZSV Running Tool - Make Up Halliburton EZSV And RIH With Logging Tools To 11,500' With No Problems - Record Up Weights Every 1,000 Feet - Log Up From 11,500' To 9,800' Unable To Detect Good Collar Signals And Marker Joint Location - Re-Log Again With Same Printed: 4/28/2003 914:27 AM ) ) BP EXPLORATION Operati ons Sum 111 a ry Report Page 50f 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date· From- To Hours Task Code NPT Phase Description of Operations 4/10/2003 17:00 - 19:30 2.50 EVAL P DECaMP Results 19:30 - 21 :30 2.00 EVAL N DPRB DECaMP Held PJSM - POH With Halliburton EZSV On Schlumberger Logging Tools - Change Out Collar Locator And Test On Surface - Check Out Haliburton EZSV (OK) 21 :30 - 22:30 1.00 EVAL N DPRB DECaMP Held PJSM - Logging Run No.2 - RIH With Collar Locator, Weight Bar, And EZSV Running Tool To 11,500' With No Problems - Good Collar Detection To 10,000' - Poor Quality To 11,600' 22:30 - 00:00 1.50 EVAL P DECaMP Log Up From 11,600' To 9,800' Poor Collar Signals - Re-Log Again At Different Speed With Same Results - Correlate Logs With GR Log 4/11/2003 00:00 - 00:30 0.50 EVAL P DECaMP Correlate Logs With GR Log - Log Up To Packer Setting Depth At 11,320 (Top Of Packer WLM) 5' Above Collar And Set Haliburton EZSV With 2,930 Ibs. On Weight Indicator *NOTE* Felt 2 Movements On E-Line Not 3 - Indicated Tool Not Released - Waited 10 Minutes 00:30 - 01 :00 0.50 EVAL N DFAL DECaMP Held PJSM - Clear Rig Floor - Pull Up On Setting Tool Above Normal Up Drag At 2,930 Ibs. To 4,000 Ibs. - Slack Off To 1,900 Ibs. Verify That Packer Set - Pull Up To Neutral Weight At 2,930 Ibs. And Wait 10 Minutes - Consult With Day Companyman And Decide To Pull Out Of Rope Socket - Stage Up Pulling Weights Repeatedly And Pulled Out With 7,289 Ibs. - 78 Percent Of Line Rating 01 :00 - 02:30 1.50 EVAL N DFAL DECaMP Held PJSM - POH With Schlumberger E-Line - Verify That Wire Indeed Pulled Out Of Rope Socket - Top Of Fish At 11,304.5' (WLM) *NOTE* Items Left In Hole: Rope Socket O.D. 2 1/4" Length 1.80 CCL 3 3/8" O.D. Length 2.30 AH-ESIC 5033/8" O.D. Length 1.80 Weight Bar 3 3/8" O.D. Length 6.60 EZSV Running Tool 7 3/4" O.D. Length 3.0 Total Length Of Fish In Hole At 15.50 02:30 - 03:00 0.50 FISH N DFAL DECaMP Held PJSM - Change Out Dies In Top Drive And Service Same - Move 6 1/2" Drill Collars On Pipe Rack 03:00 - 04:30 1.50 FISH N DFAL DECaMP Held PJSM - Pick Up And Make Up Baker Fishing Tools - Pick Up (1) Stand Of 5" HWDP And Lay Down Single - Pick Up Pump Out Sub, Bumper Jars, Top Sub, Extension, Over Shot Bowl And Guide Dressed With 3 3/8" Grapple - RIH With Fishing Assembly - Pick Up Single Of 5" HWDP - RIH With (4) Stands Of 5" HWDP From Mast - Total BHA NO.3 Length At 478.14 04:30 - 08:30 4.00 FISH N DFAL DECaMP Held PJSM - RIH With BHA NO.3 On 5" Drill Pipe From 478' To 11,248' 08:30 - 09:00 0.50 FISH N DFAL DECaMP Held PJSM - Connect Tesco Top Drive And Establish Circulation At 5 BPM With 200 Psi. - String Weight Up 285,000#, String Weight Down 185,000# - Wash Down To Top Of Fish - Note Pressure Increase To 1,000 Psi. At 11,333' (DPM) - Shut Down Pumps And Set Down 15,000# To Ensure Fish Engaged - Pick Up To 310,000# Sheared EZSV Running Tool From Bridge Plug - Pick Up String To 11,313' - Set Back Printed: 4/28/2003 9:14:27 AM ') ) BP EXPLORATION Operations Summary Report Page 6 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From - To Hours Task Code NPT Phase· Description of Operations 4/11/2003 08:30 - 09:00 0.50 FISH N DFAL DECaMP Down At 11,333' With 15,000# To Ensure Bridge Plug In Place (OK) 09:00 - 10:00 1.00 FISH N DFAL DECaMP Held PJSM - Dropped Ball And Pumped Open Circulating Sub With 1,300 Psi. - Pump Dry Job - Blow Down Top Drive 10:00 - 14:30 4.50 FISH N DFAL DECaMP Held PJSM - POH With BHA NO.3 On 5" Drill Pipe From 11,333' To 478' 14:30 - 15:30 1.00 FISH N DFAL DECaMP Held PJSM - Stand Back (5) Stands Of 5" HWDP - Pull Fish To Rig Floor Recovered 100 Percent - Break Out Fish From Over Shot And Lay Down - Break And Lay Down Over Shot, Bumper Sub, And Pump Out Sub - Clear Rig Floor 15:30 - 16:30 1.00 CLEAN P DECaMP Held PJSM - Pressure Tested 9 5/8" Casing And Halliburton Bridge Plug At 3,000 Psi. For 30 Minutes (Test Good) 16:30 - 19:00 2.50 STWHIP P WEXIT Held PJSM - Pick Up Whipstock And Milling Assembly BHA No.4 - Pick Up (1) Joint Of 5" HWDP - Make Up Upper String Mill, Lower String Mill, Starting Mill And RIH - Pick Up (1) Non Mag Flex Collar, And Float Sub - Pick Up Bumper Sub, Non Mag UBHO Sub, TM Non Mag Hang Off Collar - Orient MWD Tools - Pick Up Window Master Whipstock With Bottom Trip Anchor And RIH - Install Cross Over And RIH With (3) Stands Of 61/2" Steel Drill Collars -Install Cross Over And RIH With (5) Stands Of 5" HWDP - Total Length Of BHA No.4 At 854.81 19:00 - 19:30 0.50 STWHIP P WEXIT Held PJSM - Connect Tesco Top Drive - Test Sperry Sun MWD Tools At 420 GPM With 850 Psi. (Test Good) - Blow Down Top Drive 19:30 - 00:00 4.50 STWHIP P WEXIT Held PJSM - RIH With BHA NO.4 On 5" Drill Pipe From 854' To 9,418' - Fill Drill String Every 30 Stand On Trip In Hole 4/12/2003 00:00 - 01 :00 1.00 STWHIP P WEXIT Held PJSM - Continued To RIH With BHA No.4 From 9,814' To 11,304' - Connected Top Drive And Established Circulation 12 BPM With 1,540 Psi. 01 :00 - 02:00 1.00 STWHIP P WEXIT Held PJSM - String Weight Up 310,000#, String Weight Down 195,000# - Worked String To Orient Whipstock Slacked Off And Tripped Anchor With 22,000# - Whipstock Set At 51 Degrees Right Of High Side - Picked Up On String 10,000# Above Neutral Weight to Verify That Whipstock Set - Slacked Off 40,000# To Sheared Retaining Bolt. *NOTE* Tagged Bridge Plug With Bottom Of Whipstock At 11,344' (DPM) 02:00 - 03:30 1.50 STWHIP P WEXIT Held PJSM With Truck Drivers, Drilling Crews, And Service Personal Regarding Mud Displacement - Pumped 80 Barrel 9.7 PPG Hi-Vis Spacer Followed Up With 9.7 PPG GEM Mud At 12 BPM With 1,650 Psi. 03:30 - 09:00 5.50 STWHIP P WEXIT Held PJSM - Recorded Slow Pump Rates w/ New Mud System, String Weight Up 240,000#, String Weight Down 180,000#, String Rotating Weight 225,000#, Pump Rate 545 GPM, 2,150 Printed: 4/28/2003 9:14:27 AM } ) BP EXPLORATION Operati()ns Summary Report Page t0t 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date·· ··From- To Hours Task Code NPT Phase Desëription öt Operations 4/12/2003 03:30 - 09:00 5.50 STWHIP P WEXIT Psi. RPM 100, Torque 14,000 ft Ilbs - 17,000 ft/lbs. Milled Window in 9-5/8" Casing from 11,320' - 11,336', WOM 5,000#- 10,000#, RPM 100, Torque 22,000 ft /Ibs, Pump Rate 546 gpm, 2,150 psi. Exited Window at 11,336'. Continued To Mill Formation From 11,336' To 11,350', WOM 10,000# - 12,000#, RPM 100, Torque 22,000 ft Ilbs, Pump Rate 545 gpm, 2,150 psi. Observed Cement At Shakers While Milling At 11,329'. Recovered 155 Ibs. Of Metal During Milling And Stack Flushing Operation. 09:00 - 10:00 1.00 STWHIP P *NOTE*: Top Of Window 11,320' Bottom Of Window 11,336' WEXIT Held PJSM - Pumped 30 Barrel Hi-Vis Sweep At 13 BPM With 2,110 Psi. Circulated Until Returns over Shakers were Clean. WEXIT Held Pre-Job Safety Meeting ~ Pulled BHA Into Casing. R I U Circulating Head and Hose. Closed Upper Pipe Rams and Preformed FIT To 12.0 PPG EMW Strokes Pmp'd Pressure 5 130 psi 6 200 psi 10 300 psi 11 350 psi 12 400 psi 15 500 psi 17 580 psi 19 680 psi 21 740 psi 23 810 psi 25 880 psi 27 950 psi 29 993 psi 10:00 - 10:30 0.50 DRILL P 19:30 - 20:30 1.00 STWHIP P Held Test F/1 0 minutes w/1 0 psi Pressure Loss. MW 9.7 ppg, Csg Shoe TVD 8,304' Pressure 993 psi = 12.00 PPG. EMW. Bled Pressure To 0 Psi. - Opened Pipe Rams. Held PJSM - Pumped Dry Job - Blew Down 2" High Pressure Circulating Line - Removed Head Pin And Full Opening Safety Valve - Connected Tesco Top Drive. Held PJSM - Slipped And Cut 60' Of 1 3/8" Drilling Line- Serviced Rig And Tesco Top Drive Held PJSM - POOH wi 5" DP From 11,300' To 854' Held PJSM - Stood Back (5) Stands Of 5" HWDP In Mast- Removed Cross Over And Laid Down (9) 61/2" Steel Drill Collars, Broke Cross Over And Laid Down Bumper Sub, UBHO Sub, TM MWD Tool, Float Sub, (1) Joint Of 5" HWDP, Upper String Mill, Lower String Mill, And Window Starting Mill - Cleared Rig Floor Of Milling Tools WEXIT Held PJSM - Picked Up BOP Stack Flushing Tool With Magnet And Flushed BOP Equipment - Operated Rams And Reflushed - Recovered 5 Ibs. Of Metal On Magnet - Laid Down Magnet And Flushing Tool PROD1 Held PJSM - M I U BHA NO.5 - Picked Up 7.0" Sperry Drill Lobe 7/8 - 6.0 Stage Motor wi 1.50 Degree Bend - Picked Up 10:30 - 11 :00 0.50 STWHIP P WEXIT 11 :00 - 12:30 1.50 STWHIP P WEXIT 12:30 - 17:30 5.00 STWHIP P WEXIT 17:30 - 19:30 2.00 STWHIP P WEXIT 20:30 - 23:00 2.50 DRILL P Printed: 4/28/2003 9:14:27 AM ) BP EXPLORATION O:perations. Su I11l11ary· Report Page 8 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-258/L-27 3-258/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/12/2003 20:30 - 23:00 2.50 DRILL P 02:30 - 03:30 1.00 DRILL N PROD1 (1) 6 3/4" Non Mag Flex Drill Collar - M I U (1) Non Mag Integral Blade Stabilizer, Float Sub and Mud Motor - PI U TM MWD Non Mag Hang Off Sub - Orient MWD Tools To Motor And Installed Smith 8 1/2" PDC SGR89HSVPX Bit - Serial No. JS7517 Dressed With The Following Nozzles (4) 11's And (4) 12's - P / U (3) 6 5/8" Non Mag Flex Drill Collars, Daily Hydraulic Drilling Jars, And (5) Joints Of 5" HWDP - Connected Tesco Top Drive And Surface Tested MWD Tools At 430 GPM With 980 Psi. (Test Good) - Blew Down Top Drive - RIH With (5) Stands Of 5" HWDP From Mast - Total Length Of BHA NO.5 - 809.78' Held PJSM - Adjusted Mechanical Brakes On Draw Works - Washed Off Rig Floor Held PJSM - RIH With Directional BHA No.5 on 5" DP From 809' To 1 ,400' Held PJSM - RIH With Directional BHA No.5 on 5" DP From 1,400' To 11,290' - Fill Drill String Every 25 Stands Held PJSM - Connected Top Drive And Established Circulation - String Weight Up 270,000#, String Weight Down 205,000#. Oriented Motor - Shut Down Pumps And Worked Thru Window From 11,320' To 11,336'. PROD1 Held PJSM - Established Circulation At 11,340' - Washed And Reamed Under Gage Hole From 11,344 To 11,350'. Pump Rate 474 gpm, 2,040 psi. PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 11,350' To 12,220' WOB Rotating 10,000# - 22,000#, WOB Sliding 10,000# To 15,000#, RPM 60 To 70, Motor RPM 156, Torque Off Bottom 14,000 ft Ilbs - On Bottom 16,000 ft Ilbs, Pump Rate 541 gpm, SPP Off Bottom 2,650 psi, On Bottom 2,860 psi. String Weight Up 280,000#, String Weight Down 195,000#, String Weight Rotating 225,000# ART = 8.36 Hrs, AST = 8.09 Hrs. PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 12,220' To 12,351' WOB Rotating 10,000# - 22,000#, WOB Sliding 25,000# To 30,000#, RPM 60 To 70, Motor RPM 156, Torque Off Bottom 14,000 ft Ilbs - On Bottom 16,000 ft /Ibs, Pump Rate 541 gpm, SPP Off Bottom 2,650 psi, On Bottom 2,860 psi. String Weight Up 280,000#, String Weight Down 195,000#, String Weight Rotating 225,000# HMAN PROD1 At 02:21 Hours The Derrickman Notified The Driller To Shut Down The Mud Pumps Due To The Liner Gasket Leaking On The Number 1 Mud Pump - Prior To Pulling Off Bottom The Mud Motor Stalled And The Pump Pressure Increased To 3,400 Psi. - The String Was Raised And The Mud Pumps Were Shut Down - Number 1 Mud Pump Was Isolated And The Driller Started To Pump With The Number 2 Mud Pump At 11 BPM With 1,800 Psi. - The Driller Was Working The Pipe Attempting To Make A Tool Set To Continue On With Directional Work Per Sperry Sun - The Driller Rotated The String And Was Supposed To Hit The Switch On The Drillers Tesco Control Panel To Close The Grabber On The Tool Joint But Instead Closed The IBOP Valve Causing The Rotary Hose To Rupture - According To Sperry Sun Insite Readings Max 23:00 - 23:30 0.50 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 4/13/2003 00:00 - 04:30 4.50 DRILL P PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P 05:30 - 00:00 18.50 DRILL P 4/14/2003 00:00 - 02:30 2.50 DRILL P Printed: 4/28/2003 9:14:27 AM ) BP EXPLORATION QperationsSumrnaryReport Page 9 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-258/L-27 3-258/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From - To Hours Task Code NPT Phase Descri ption of Operations 4/14/2003 02:30 - 03:30 1.00 DRILL N HMAN PROD1 Pressure Climbed To 2,524 Psi. According To Pason Readings Max Pressure Climbed To 1,850 Psi. Pop Off Valves Set At 4,500 Psi. *NOTE* Pop Off Tripped - Drilling Mud Started To Fall To The Rig Floor And The Mud Pumps Were Shut Down - The Driller Notified The Night Company Man And Tour Pusher - The Night Company Man Notified The BP Enviro-Tech, Anchorage Drilling Team Leader (Mike Miller) And Day Company Man - The Drill String Was Pulled Inside Casing With No Problems - The Well Was Secured With A Full Opening Safety Valve And Monitored While Circulating Across The Top Of The Hole - See LCIR No. 2003-IR-484045 03:30 - 11 :00 7.50 DRILL N HMAN PROD1 Held Pre-Job Safety Meeting Concerning Clean Up And Changing Out Rotary Hose - Clean Up Spilled Material - BP Enviro-Tech Mud Called Spill 3 Barrels In Secondary Containment And 5 Gallon On Pad - Remove Rotary Hose From Tesco Top Drive And Stand Pipe - Remove Unions From Hose And Install On New Hose - Hang New Hose In Mast And Attach To Tesco Top - Secure With Safety Cables 11:00 -12:00 1.00 DRILL N HMAN PROD1 Held PJSM - Replace Pop Off On Mud Pump NO.2 And Tested To 4,000 Psi. (Test Good) - Establish Circulation - Test Rotary Hose To 4,000 Psi. (TEST Good) - Function Tested Pop Off 12:00 - 13:00 1.00 DRILL N HMAN PROD1 Held PJSM - Oriented Motor - Shut Down Pumps And Worked Thru Window From 11,320' To 11,336' - RIH With Directional BHA NO.5 On 5" DP From 11,336' To 12,252' - Connect Tesco Top Drive - Establish Circulation - As Precaution Wash And Ream From 12,252' To 12,351' - No Hole Problems On Trip 13:00 - 19:00 6.00 DRILL P PROD1 Drilled 81/2" Directional Hole By Rotating And Sliding From 12,351' To 12,577' WOB Rotating 10,000# - 22,000#, WOB Sliding 25,000# To 30,000#, RPM 60 To 70, Motor RPM 156, Torque Off Bottom 14,000 ft /Ibs - On Bottom 16,000 ft /Ibs, Pump Rate 541 gpm, SPP Off Bottom 2,650 psi, On Bottom 2,860 psi. String Weight Up 280,000#, String Weight Down 195,000#, String Weight Rotating 225,000# 19:00 - 19:45 0.75 DRILL N SFAL PROD1 Held PJSM - Unable To Get Good Tool Face Readings And Flow Rates With 1 Mud Pump - Circulate And Reciprocate Drill String While Working On Mud Pump NO.1 19:45 - 00:00 4.25 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating And Sliding From 12,577' To 12,700' WOB Rotating 10,000# - 22,000#, WOB Sliding 25,000# To 30,000#, RPM 60 To 70, Motor RPM 145, Torque Off Bottom 12,000 ft /Ibs - On Bottom 14,000 ft /Ibs, Pump Rate 516 gpm, SPP Off Bottom 2,580 psi, On Bottom 2,730 psi. String Weight Up 290,000#, String Weight Down 210,000#, String Weight Rotating 225,000# - For Last 24 Hours ART = 6.53 Hrs, AST = 3.76 Hrs. Preliminary Formation Tops: Formation Measured Depth TVD Tuffs 12,613' 9,016' 4/15/2003 00:00 - 00:00 24.00 DRILL P PROD1 DRILLED 81/2" DIRECTIONAL HOLE BY ROTATING AND SLIDING FROM 12,700' TO 13614' - WOB ROTATING 15K TO 20K - WOB SLIDING 25K TO 30K - RPM 80 - MOTOR RPM 145 - TORQUE OFF BOTTOM 1 OK - ON BOTTOM 15K - Printed: 4/28/2003 9:14:27 AM ) ') BP EXPLORATION Operation~ Summary .Report Page 10 of15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/15/2003 00:00 - 00:00 24.00 DRILL P PROD1 PUMP RATE 503 GPM - SPP OFF BOTTOM 3100 PSI- ON BOTTOM 3250 PSI - STRING WEIGHT UP 305K - STRING WEIGHT DOWN 210K - STRING WEIGHT ROTATING 245K 4/16/2003 00:00 - 00:30 0.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 13,614' TO 13,625' - WOB 15 TO 20K - RPM 80 - TQ ON BTM 15K - OFF BTM 10K - GPM 503 - PP ON BTM 3250 - OFF BTM 3000 - PU 305 - SO 210 - ROT 245 - CIRC 15 MINS STAND BACK STAND 135 00:30 - 04:00 3.50 DRILL P PROD1 PUMP HI-VIS SWEEP - ROTATE / RECIPROCATE PIPE- GPM 503 - PP 2,900 - RPM 80 - TQ 9,000 - P/U 300,000 - S/O 220,000 - ROT 245,000 - CIRCULATED HOLE CLEAN - TOTAL 20,000 STKS - 3 X BOTTOMS UP - STANDING ONE STAND BACK EVERY 30 MINS - FROM 13625' TO 13,309'. 04:00 - 05:00 1.00 DRILL P PROD1 POOH FROM 13,309' TO 11,285' - HOLE IN GREAT SHAPE- NO PROBLEMS THROUGH WINDOW. 05:00 - 05:30 0.50 DRILL P PROD1 MONITORED WELL - PUMP DRY JOB - BLOW DOWN TOP DRIVE 05:30 - 10:00 4.50 DRILL P PROD1 POOH w/ 5" DP FROM 11 ,285' TO 809'. 10:00 - 11 :30 1.50 DRILL P PROD1 POOH w/ BHA. BROKE OUT AND L / D JARS, HANG OFF SUB, MONEL COLLAR, MUD MOTOR AND BIT. 11 :30 - 12:00 0.50 BOPSURP PROD1 HELD PJSM. R / U EQUIPMENT TO TEST BOPE. 12:00 - 20:00 8.00 BOPSURP PROD1 HELD PJSM. TESTED BOPE. TESTED UPPER AND LOWER RAMS, BLIND RAMS, STAND PIPE MANIFOLD, CHOKE MANIFOLD, VALVES, HCR, KILL LINE, CHOKE LINE, UPPER / LOWER IBOP, DART VALVE, to 4,500 psi HIGH / 250 psi LOW. TESTED ANNULAR PREVENTER TO 3,500 psi HIGH /250 psi LOW. ALL TESTES HELD f/5 MIN. 4 1/2" TIW FLOOR VALVE WOULD NOT TEST - REPLACED WITH 4 1/2" TIW VALVE FROM RIG 16 - RETESTED - OK - ALL OTHER ASSOCIATED EQUIPMENT PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. WITNESSING OF BOPE TEST WAIVED BY AOGCC REP JOHN CRISP. 20:00 - 21 :00 1.00 BOPSURP PROD1 BLOW DOWN CHOKE MANIFOLD - RIG DOWN TESTING EQUIPMENT - PULL TEST PLUG - INSTALL WEAR RING - LD TEST JOINT - CLOSE ANNULUS VALVES 21 :00 - 23:00 2.00 DRILL P PROD1 DERRICK INSPECTION - INSPECT BLOCKS - TOP DRIVE 23:00 - 00:00 1.00 DRILL P PROD1 PJSM - PICK UP MOTOR - MAKE UP BIT 4/17/2003 00:00 - 04:00 4.00 DRILL P PROD1 CONTINUE PICK UP BHA - LOAD MWD TOOLS - LOAD NUKES - RIH TO 883' - TEST TOOLS 04:00 - 08:30 4.50 DRILL P PROD1 RIH FROM 883' TO 11173' - FILLING PIPE EVERY 25 STANDS 08:30 - 10:00 1.50 DRILL P PROD1 CUT DRLG LINE - RIG SERVICE 10:00 - 11 :30 1.50 DRILL P PROD1 RIH FROM 11173' TO 12631' - BENCH MARK SURVEY 11:30-13:00 1.50 DRILL P PROD1 RIH FROM 12631' TO 13572' - BREAK CIRC- PRECAUTIONARY CIRCULATE BOTTOMS UP 13:00 - 15:30 2.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 13625' TO 13708' - WOB 10K TO 15K - RPM 60 TO 80 - TQ ON BTM 16K - OFF BTM 14K- GPM 503 - PP ON BTM 3250 - ON BTM 3050 - PU 320K - SO 21 OK - ROT 250K 15:30 - 16:00 0.50 DRILL N RREP PROD1 UNION ON S-PIPE LEAKING - TIGHTEN UP UNION 16:00 - 20:00 4.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 13708' TO 13854' - WOB 10K TO 15K - RPM 50 TO 80 - TQ ON BTM 20K - OFF BTM 14K- GPM 445 - PP ON BTM 2650 - OFF BTM 2400 - PU 325K - SO 21 OK - ROT 250K Printed: 4/28/2003 9:14:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BPEXPLORATION Operations ·.SummaryReport 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: ') Page 1 t oft5 Spud Date: 4/6/2003 End: 4/24/2003 Date From -To Hours Task Code NPT Phase Description of Operations 4/17/2003 20:00 - 21 :30 1.50 DRILL N RREP PROD1 UNION LEAKING ON S-PIPE - PULL 4 STANDS FROM 13854' TO 13567' - KNOCK OFF ROTARY HOSE - TAKE DOWN S-PIPE - BREAK OFF UNION - INSPECT THREADS - NO VISUAL DAMAGE TO THREADS - REDOPE - MAKE UP UNION - REINSTALL S-PIPE AND ROTARY HOSE - TEST TO 4200 PSI - OK - RIH TO 13854' 21 :30 - 00:00 2.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 13854' TO 13880' - WOB 10K TO 30K - RPM 50 TO 80 - TQ ON BTM 18K - OFF BTM 14K- GPM 480 - PP ON BTM 3100 - OFF BTM 2950 - PU 330K- SO 21 OK - ROT 250K 4/18/2003 00:00 - 14:30 14.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 13880' TO 14350' - WOB 10K TO 15K - RPM 65 TO 90 - TQ ON BTM 22K - OFF 14K - GPM 480 - PP 3250 ON BTM - OFF 3100 - PU 360K - SO 235K- ROT 270K 14:30 - 16:00 1.50 DRILL P PROD1 CIRCULATE HI-VIS SWEEP AROUND - GPM 503 - PP 3000- PU 360K - SO 235K - ROT 270K 16:00 - 17:00 1.00 DRILL P PROD1 SHORT TRIP TO LAST BIT TRIP @ 13567' - RIH TO 14350'- HOLE IN EXCELLENT SHAPE 17:00 - 22:00 5.00 DRILL P PROD1 CIRCULATED WEIGHTED HI-VIS SWEEP - CIRCULATE 4 X BOTTOMS UP - SPOT LINER PILL - GPM 503 - PP 3100 - PU 360K - SO 235K - 270K 22:00 - 00:00 2.00 DRILL P PROD1 POH WT FROM 14350' TO 11268' - NO PROBLEMS PULLING THROUGH WINDOW - 1 ST 3 STANDS OFF BOTTOM WERE STICKY COMING OFF SLIPS OVER PULL 20K TO 30K 4/19/2003 00:00 - 01 :00 1.00 DRILL P PROD1 MONITOR WELL - WELL STATIC - PUMP DRY JOB - BLOW DOWN TOP DRIVE - DROP RABBIT w/1 00 FEET WIRE. 01 :00 - 06:00 5.00 DRILL P PROD1 CON'T POOH TO BHA FROM 11,173' TO 883' 06:00 - 07:30 1.50 DRILL P PROD1 LAY DOWN BHA - HWDP - JARS - FLEX DC'S 07:30 - 09:00 1.50 DRILL P PROD1 REMOVE SOURCES - DOWN LOAD MWD 09:00 - 10:00 1.00 DRILL P PROD1 LAY DOWN MWD - BREAK BIT - LAY DOWN MOTOR 10:00 - 11 :00 1.00 DRILL P PROD1 CLEAR FLOOR OF SUBS - XO'S 11 :00 - 12:00 1.00 CASE P PROD1 RIG UP CASING EQUIPMENT FOR RUNNING 4 1/2" HYDRIL 56312.6# LINER 12:00 - 17:30 5.50 CASE P PROD1 PICK UP AND RUN LINER AS FOLLOWS: TOTAL JTS 41/2" 12.6# HYDRIL 563 RAN 74 - FILLING EACH 10 JTS RAN: 8" BBL REAMER FLOAT SHOE 1 JT 41/2" 12.6# 13 CROME HYDRIL 563 41/2" HES SUPER SEAL FLOAT COLLAR 1 JT 412" 12.6# 13 CROME HYDRIL 563 4 1/2" BAKER LANDING COLLAR TYPE 1 8 JTS 41/2" 12.6# 13 CROME HYDRIL 563 220' MARKER JTS 41/2" 12.6# 13 CROME HYDRIL 563 64 JTS 41/2" 12.6# 13 CROME HYDRIL 563 XO BUSHINGS 7" X 41/2" HYDRIL 5631 PUP JT BAKER 9 5/8" X 7" FLEX LOCL 11 LINER HANGER 7" BAKER RS NIPPLE BAKER ZXP PACKER WIHRD SETTING TOOL BAKER TIE BACK SLEEVE 7" X 9 5/8" BAKER RUNNING TOOL LINER WEIGHT AT 3,309' - PU 97K - SO 97K 17:30 - 18:00 0.50 CASE P PROD1 MAKE UP LINER HANGER TO LINER - FILL CAVITY WITH Printed: 4/28/2003 9:14:27 AM ) ) BP EXPLORATION Operations Summary Report Page·120f15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-258/L-27 3-258/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From -To Hours Task Code NPT Phase 4/19/2003 17:30 - 18:00 0.50 CASE P PROD1 18:00 - 19:00 1.00 CASE P PROD1 19:00 - 19:30 0.50 CASE P PROD1 19:30 - 00:00 4.50 CASE P PROD1 Description of Operations 02:30 - 04:00 1.50 CASE P "PAL MIX" RIG DOWN LINER RUNNING TOOLS - CHANGE BAILS MAKE UP 1ST STAND 5" DP - CIRCULATE LINER VOLUME- 50 BBLS 300 PSI - 5 BPM RIH WITH 41/2" 12.6# HYDRIL 563 LINER ON 5" DP- FILLING EVERY 2000' - FROM 3,305' TO 11,206' 5,112' 120K - 120K 7,014' 153K - 147K 8,920' 190K - 155K 11,206' 215K - 170K PROD1 MAKE UP CEMENT HEAD - STAND BACK PROD1 CIRCULATE LINER I ANNULUS VOLUME - 605 BBLS -1300 PSI- 10 BPM - PU 215K - SO 170K 6 BPM - 625 PSI 7 BPM - 800 PSI 9 BPM -1100 PSI 10 BPM - 1300 PSI ROTARY TORQUE @ 25 RPM 6.5K PU 195K - 6.7K SO 190K - 6.3K BLOW DOWN TOP DRIVE PROD1 LAY DOWN 1 JT - CONTINUE RIH WITH 41/2" HYDRIL 563 LINER FROM 11,206' TO 14,350' PROD1 MAKE UP CEMENTING HEAD PROD1 BREAK CIRCULATION - CIRCULATE BOTTOMS UP 2 X- STAGE UP PUMP RATES 4.0 BPM - 775 PSI 5.0 BPM - 890 PSI 7.0 BPM - 1,300 PSI 7.5 BPM - 1,450 PSI 9.0 BPM - 1,500 PSI PI U WEIGHT 290,000#, S I 0 WEIGHT 200,00#. RECIPROCATED PIPE 25' WHILE CIRCULATING. HELD PJSM wI RIG CREW, DOWELL AND TRUCK DRIVERS 4-1/2" LINER SET AS FOLLOWS: ITEM LENGTH DEPTH REAMER SHOE 2.91' 14,348.00' 1 JT 4-1/2" 12.6# L-80 HYDRIL 563 Lnr 43.21' 14,303.88' FLOAT COLLAR 1.61' 14,302.27' 1 JT 4-1/2" 12.6# L-80 HYDRILI 563 Lnr 42.37' 14,259.90' LATCH COLLAR 1.50' 14,258.40' 8 JTS 4-1/2" 12.6# L-80 HYDRILI 563 Lnr 337.97' 13,920.43' 4-1/2" 12.6# L-80 HYDRIL 563 MKR Jt 19.82' 13,900.61' 4-1/2" 12.6# L-80 HYDRIL 563 MKR Jt 19.83' 13,880.78' 4/20/2003 00:00 - 01 :00 01 :00 - 02:30 1.00 CASE P 1.50 CASE P 04:00 - 04:30 04:30 - 09:00 0.50 CASE P 4.50 CASE P Printed 4/28/2003 9:14:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ') ) BPEXPLORATION Operations Siurnmary Report 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Page 13 of 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 4/20/2003 04:30 - 09:00 From - To Hours Task Code NPT Phase Description of Operations 09:00 - 11 :30 4.50 CASE P 2.50 CEMT P PROD1 64 JTS 4-1/2" 12.6# L-80 HYDRIL 563 Lnr 2,699.46' 11,181.32' CROSS OVER BUSHING 5.22' 11,176.10' LINER HANGER 9.34' 11,166.76' RS NIPPLE 2.83' 11,163.93' ZXP PACKER 8.28' 11,155.65' TIE BACK SLEEVE 10.96' 11,144.69' PROD1 SWITCHED OVER TO DOWELL. PUMPED 5 BBLS OF SEAWATER TO FLUSH THE LINES AND TO ESTABLISH CIRCULATION. SHUT IN CEMENT MANIFOLD AND TESTED LINES TO 4,500 psi, OK. PUMPED 75 BBLS OF MUD PUSH AT 5.0 bpm, 750 psi. PUMPED 160 bbls (680 sx) 15.8 ppg LATEX CEMENT wI 0.40% BWOC DISPERSANT, 0.30% BWOC RETARDER, 3.00 gal/sk EXPANDING AGENT, 0.20 gal/sk ANTI FOAM, 2.00 gal/sk GASBLOK. PUMPED CEMENT AT THE FOLLOWING RATES: PUMPED RATE PRESURE 5.0 bbls 5.00 bpm 920 psi 25.0 bbls 5.00 bpm 815 psi 50.0 bbls 5.00 bpm 800 psi 75.0 bbls 7.00 bpm 1,530 psi 100.0 bbls 7.00 bpm 1,406 psi 125.0 bbls 7.00 bpm 1,400 psi 150.0 bbls 7.00 bpm 1,400 psi 160.0 bbls 7.00 bpm 1,400 psi CLEANED UP BEHIND PLUG, DROPPED DRILL PIPE DART AND PUMPED OUT OF MANIFOLD w/5 bbls OF WATER AT 5.00 bpm, 330 psi. DISPLACED w/235 bbls OF MUD AT THE FOLLOWING RATES: PUMPED RATE PRESSURE 50.0 bbls 10.0 bpm 620 psi 100.0 bbls 10.0 bpm 620 psi 150.0 bbls 10.0 bpm 1,800 psi slw'd Pmps to 3.50 bpm 280 psi DRILL PIPE DART HIT wI 187.0 bbls PUMPED, PRESSURE INCREASED TO 700 psi, WIPER PLUG SHEARED, PRESSURE DROPPED TO 350 psi, INCREASED RATE 200.0 bbls 10.0 bpm 1,830 psi 215.0 bbls 4.5 bpm 1,200 psi 220.0 bbls 4.5 bpm 1,250 psi WIPER PLUG BUMPED wI 235 bbls PUMPED. CEMENT IN PLACE @ 1045 HRS. INCREASED PRESSURE TO 3,000 psi TO SET LINER HANGER, SLACKED OF ON LINER TO COMFIRM HANGER SET. BLED OFF PRESSURE TO CHECK FLOATS, (FLOATS HELD). PRESSURED UP TO 4,000 psi TO RELEASE RUNNING TOOL FROM LINER. BLED OFF PRESSURE. PI U TO EXPOSE SETTING DOGS. SET DOWN ON LINER wI 70,000# AND SET ZXP PACKER. P Printed: 4/28/2003 9:14:27 AM ) ) BPEXPLORATION Operations Summary Report Page 14 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From-To Hours Task Code NPT Phase Descri ptibn öf Operations 4/20/2003 09:00 - 11 :30 2.50 CEMT P PROD1 I U 10', ROTATED AND SET DOWN ON LINER wI 70,000# TO ENSURE LINER PACKER SET. CLOSED PIPE RAMS AND PRESSURED UP ON ANNULUS TO 2,000 psi fl 5 MINUTES TO TEST ZXP PACKER, OK. BLED OFF PRESSURE AND OPENED PIPE RAMS. PRESSURED UP DOWN DRILL PIPE TO 500 psi, PI U ON DRILL PIPE 20', OBSERVED PRESSURE DROP TO 0 psi TO CONFIRM LINER RUNNING TOOL RELEASED FROM LINER. 11 :30 - 13:30 2.00 CEMT P PROD1 CIRCULATED 2 x BOTTOMS UP TO CLEAN HOLE. PUMP RATE 10 BPM, 1,100 PSI.- NO CEMENT 13:30 - 16:30 3.00 CEMT P PROD1 DISPLACE TO SEAWATER - PUMP 100 BBLS BARA SCRUB - 50 HI-VIS SPACER - PUMP SEAWATER AROUND @ 70 SPM -1300 PSI 16:30 -17:00 0.50 CEMT P PROD1 RIG DOWN CEMENT HEAD - AND EQUIPMENT 17:00 - 17:30 0.50 CEMT P PROD1 CONDUCT TONG OPERATION I SAFETY SCHOOL WITH RIG TEAM 17:30 - 19:30 2.00 CEMT P PROD1 LAY DOWN 5" DRILL PIPE TOTAL DOWN 42 JOINTS 19:30 - 20:30 1.00 CEMT P PROD1 CUT DRILLING LINE - SERVICE TOP DRIVE I DRAWWORKS 20:30 - 00:00 3.50 CEMT P PROD1 LAY DOWN 5" DRILL PIPE TOTAL DOWN 210 JTOINTS 4/21/2003 00:00 - 04:30 4.50 CASE P PROD1 LAY DOWN 5" DRILL PIPE TOTAL DOWN 350 JOINTS- BREAK OUT - LAY DOWN BAKER RUNNING TOOL 04:30 - 05:00 0.50 CASE P PROD1 CONDUCT TONG OPERATION I SAFETY WITH RIG TEAM 05:00 - 06:00 1.00 CASE P PROD1 RIH WITH REMAINING 5" DRILL PIPE IN MAST - 27 STANDS 06:00 - 08:30 2.50 CASE P PROD1 LAY DOWN 81 JOINTS 5" DRILL PIPE 08:30 - 09:00 0.50 CASE P PROD1 PULL WEAR RING 09:00 - 09:30 0.50 CASE P PROD1 CLOSE BLINDS - TEST LINER LAP AND CASING TO 3000 PSI - OK 09:30 - 10:30 1.00 RUNCOrvP COMP RIG UP CASING EQUIPMENT - PJSM - 10:30 - 13:00 2.50 RUNCOrvP COMP PU AND RUN 41/2" 12.6# VAM ACE 13 CROME L-80 TUBING I COMPLETION TOTAL JOINTS RAN 42 13:00 - 14:00 1.00 RUNCOI\tf\J RREP COMP WORK ON TORQUE TURN EQUIPMENT 14:00 - 00:00 10.00 RUNCOrvP COMP PU AND RUN 41/2" 12.6# VAM ACE 13 CROME L-80 TUBING - TOTAL 180 JOINTS 7842' - TESTING EVERY 60 JOINTS RAN TO 3500 PSI - CHANGE COLLAR ON JOINT # 14 - BACK OUT AND INSPECT REDOPE MAKE UP JOINT # 39 4/22/2003 00:00 - 04:00 4.00 RUNCOrvP COMP CONTINUE RIH WITH 4 1/2" COMPLETION TO 9638' - TOTAL 223 JOINTS RAN - JOINT # 207 - BACK OUT INSPECT - REDOPE - MAKE UP - OK - TEST EVERY 60 JOINTS TO 3500 PSI 04:00 - 05:00 1.00 RUNCOrvP COMP TEST TUBING TO 3500 FOR 10 MINS - OK - MAKE UP SSSV -INSTALL CONTROL LINES - TEST LINES TO 5000 PSI- OK 05:00 - 08:30 3.50 RUNCOrvP COMP CONTINUE RIH WITH 41/2" COMPLETION TOTAL 259 JOINTS 08:30 - 09:00 0.50 RUNCOrvP COMP MAKE UP JOINT 260 - TAG AT BOTTOM OF HANGER 11173' - LAY DOWN JOINT # 260 1# 259 FOR SPACE OUT 09:00 - 10:00 1.00 RUNCOrvP COMP MAKE UP HANGER ON JOINT 258 - MAKE UP CONTROL LINES - HOOK UP CONTROL LINES - TOTAL 39 STAINLESS STEEL BANDS RAN ON CONTROL LINE 10:00 - 11 :00 1.00 RUNCOrvP COMP LAND HANGER - RUN IN LOCK DOWN SCREWS - TEST TUBING TO 3500 PSI - NO TEST - PU WEIGHT 170K - SO WEIGHT 125K Printed: 4/28/2003 9: 14:27 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Operations Suml11aryReport Page·15 of 15. 3-25B/L-27 3-25B/L-27 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 4/6/2003 Rig Release: 4/24/2003 Rig Number: Spud Date: 4/6/2003 End: 4/24/2003 Date From- To Hours Task Code NPT Phase Description of Operations 4/22/2003 11 :00 - 12:30 1.50 RUNCOIVN COMP BAD SEAL ON NSCTXOSUB-CHANGEOUTXOSUBS 12:30 - 13:00 0.50 RUNCOIVN COMP RIG UP TO TEST TUBING TO 3500 PSI 13:00 - 13:30 0.50 RUNCOIVP COMP TEST TUBING TO 3500 PSI FOR 10 MINS - OK 13:30 -14:00 0.50 RUNCOIVP COMP LAY DOWN LONG BAILS 14:00 - 14:30 0.50 RUNCOIVP COMP PJSM WITH SLICK LINE CREW - RIG UP SLICK LINE EQUIPMENT 14:30 - 18:00 3.50 RUNCOIVP COMP 1 ST RUN - PULL SSSV DUMMY SLEEVE - 2ND RUN - LATCH AND RETRIEVE D-16 PLUG - 3 RD RUN - RUN 3.62 DRIFT / BAILER TO 11300' - 4TH RUN - SET RHC SLEEVE IN XN NIPPLE - 5TH RUN - SET DUMMY SLEEVE IN SSSV - 18:00 - 18:30 0.50 RUNCOIVP COMP RIG DOWN SLICK LINE UNIT 18:30 - 19:00 0.50 RUNCOIVP COMP RIG UP TO REVERSE CIRCULATE 19:00 - 00:00 5.00 RUNCOIVP COMP REVERSE CIRCULATE AND DISPLACE ANNULUS WITH CLEAN SEAWATER WITH CORRISION INHIBITOR 4/23/2003 00:00 - 01 :00 1.00 RUNCOIVP COMP CONTINUE REVERSE CIRCULATE - SPOT CORRISION INHIBITOR - 3 BPM - 200 PSI- 602 TOTAL BBLS REVERSED CIRCULATED 01 :00 - 02:30 1.50 RUNCOIVP COMP PRESSURE UP TO 3500 PSI TO SET PACKER - RECORD FOR 30 MINS - OK - BLEED OFF TUBING PRESSURE TO 1500 PSI - PRESSURE UP ANNULUS TO 3000 PSI - RECORD FOR 30 MINS - OK - BLEED OFF TUBING PRESSURE - DCK VALVE SHEARED AT 200 PSI TUBING PRESSURE - CIRCULATE ANNULUS THROUGH TUBING TO CONFIRM VALVE SHEARED 02:30 - 03:00 0.50 RUNCOIVP COMP TERMINATE CONTROL LINES - BREAK DOWN TESTING EQUIPMENT - BREAK OUT / LAY DOWN LANDING JOINT - LAY DOWN CONTROL SPOOLS 03:00 - 03:30 0.50 BOPSUR P COMP SET TWC WITH CAMERON - TEST TO 1000 PSI BELOW - OK 03:30 - 15:30 12.00 BOPSUR P COMP PJSM - NIPPLE DOWN BOPS - REMOVE RAMS - CLEAN GREASE SAME - GREASE MACHINE PARTS, DOOR SEALS, RAMS, FOR STACK OUT - REMOVE KOOMEY LINES FROM BOP'S - HOOK UP SLINGS - UNBOLT BOP'S FRPM RISER PIPE - SET STACK ON BOP PLATFORM - LAY DOWN RISER PIPE - REMOVE MUD CROSS SPACER SPOOL 15:30 - 20:00 4.50 WHSUR P COMP NIPPLE UP TREE - HOOK UP CONTROL LINES AND TEST TO 5000 PSI - TEST ADAPTER FLANGE TO 5000 PSI - INSTALL BLIND FLANGE ON WING VALVE- 20:00 - 23:00 3.00 WHSUR P COMP FILL TREE WITH DIESEL - ATTEMPT TO TEST - NO TEST - PULL TWC - INSPECT TWC - NO VISUAL PROBLEMS - REPLACE WITH 2ND TWC - RETEST TO 5000 PSI - OK 23:00 - 23:30 0.50 WHSUR P COMP PULL TWC - LAY DOWN LUBICATOR 23:30 - 00:00 0.50 WHSUR P COMP RIG UP TO FREEZE PROTECT 4/24/2003 00:00 - 00:30 0.50 WHSUR P COMP PJSM - PRESSURE TEST HOT OIL LINE TO 3000 PSI 00:30 - 01 :30 1.00 WHSUR P COMP FREEZE PROTECT WITH 105 BBLS OF DIESEL IN ANNULUS - 2 BPM - 600 PSI 01 :30 - 03:30 2.00 WHSUR P COMP U-TUBE WELL - BACK SUCK LINES DRY 03:30 - 05:00 1.50 WHSUR P COMP SET BPV WITH CAMERON - TEST FROM BELOW TO 1000 PSI - OK 05:00 - 06:00 1.00 WHSUR P COMP SECURE WELL - REMOVE SECONDARY ANNULUS VALVE - CLEAN INSIDE WELL HOUSE - RELEASE RIG @ 06:00 HRS Printed 4/28/2003 914:27 AM ) ) Well: Field: API: Permit: Date 3-25B/L -27 Endicott 50-029-22125-02 203-021 Accept: Spud: Release: Rig: 04/07/03 04/13/03 04/24/03 Doyon 15 POST-RIG WORK 04/27/03 ASSIST PULLING BPV, PULLED 4 1/2" "X" DBV, PULLED BALL & ROD, SET GENERIC G/L DESIGN (TOP 2 STATIONS). PULLED 4 1/2" "RHC-M" PLUG BODY @ 11120" SLM (EMPTY) 04/28/03 RIH WI 3.r MILL AND MOTOR. TAG @ 141421 CTMD. START MILLING DRIFT & TAG SOFT BOTTOM WI 27/8" DG SB TAG TO @ 141181 CORR TO MD. 04/29/03 MILLING @ 141821. MILL TO 14,258' CTMD. PUMP FLO-PRO SWEEP AND CIRC BOTTOMS UP WI SW. OPEN CIRC SUB AND LAY IN DIESEL FROM 14,2581 TO SURFACE. 1ST RIH: LOG PRIMARY DEPTH CONTROL.TOOL = HEAD/AH38/SWIVEL/WEIGHT/ROLLERS/WEIGHTI PBMS/ROLLERS = 25.5 FT X 2.65" MAX OD. SET TOOL ON SWAB - ZERO SET TO 29 FT. RIG UP CABLE FLAGGED AND MEASURED = 176.6 FT TO TOP OF LUB. LOGGED A DOWN PASS. FROM 13500 FT TO TO, CABLE WAS STICKY DROPPING THROUGH FLOW TUBES. LOGGED AN UP PASS FROM TO TO 10500 FT = PRIMARY DEPTH CONTROL LOG. LOGGED ANOTHER DOWN PASS FROM 12800 FT TO TO TO SPLICE INTO 1ST DOWN PASS AT 12900 FT. TIED UP PASS INTO SPLICED DOWN PASS. WHILE AT TO, WHP = 600 PSI. BHP AT TO = 4213 PSI @ 214 DEGF. STATION AT MID- PERF = 4189.3 PSI @ 212.9 DEGF. 2ND RIH: PERFORATE 14182-14196 FT MD. TIED INTO SPERRY-SUN MWD AS REQUESTED BY CLlENT.RIH - TOOL = HEAD/AH38/PGGT-C/SAFE HEAD- ESIC/GUN/XOVERISHOCK ABSORBERI 2 PETREDAT GUAGES = 40.1 FT X 2.88" MAX 00. GUN = 20 FOOT STOCK WITH 14 FEET LOADED WITH 2906 POWERJET CHARGES @ 6 SPF. LOGGED MEMORY STATIC STATIONS, AFTER SHOOTING, AT 13948 FT MD AND 13819 FT MD. AT SURFACE - PETREDAT GAUGES HAD NO USEABLE DATA AFTER THE PERFORATIONS- INSTRUCTED TO RU TO LOG SBHP SURVEY 04/30/03 LOGGED A SBHP SURVEY. TOOL = HEAD/AH38/SWIVEU WEIGHT/ROLLERS/wEIGHT/PBMS/ROLLERS = 25.5 FT X 2.65" MAX 00. DID NOT TAG TO THIS RIH. LOGGED A TIE IN PASS. LOGGED A STATION AT 13948 FT MD = 4256.8 PSI @ 210.4 DEGF. LOGGED A STATION AT 13836 FT MD = 4222.7 PSI @ 209 DEGF. 05/02103 SET TTP AND DBV TO CHANGE OUT UNDERRATED 1/2" 90 DEG.. ELBOWS ON TUBING HEAD ADAPTOR. Legal Name: Common Name: Test Date 4/12/2003 FIT 3-25B/L-27 3-25B/L-27 Test Type Test Depth (TMD) 11,320.0 (ft) Test [)épth .(TVQ) 8,304.0 (ft) Surface··Pressure L.eaf(QffPte~sure(QHP) 992 (psi) 5,176 (psi) AMW 9.70 (ppg) EMW· 12.00 (ppg) ..~ Printed: 4/28/2003 9:14:16 AM ) ) 24-Apr-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3-258 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,318.16' MD Window / Kickoff Survey: 11,320.00' MD (if applicable) Projected Survey: 14,350.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 29 2003 NaIka o;¡ & Gas Cons. Commisafon AndKnge aÓ3 -0d./ Sperry-Sun Drilling Services Alaska State Plane 3 BPXA Endicott DI-SDI 3-25/M-27 - 3-258/L-27 -~ Job No. AKMW0002377690, Surveyed: 18 April, 2003 Survey Report 23 April, 2003 Your Ref: APlS00292212S02 Surface Coordinates: 5970978.01 N, 270283.14 E (70019'20.4002" N, 147051'45.8097" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 3 --' Surface Coordinates relative to Project Coordinates: 970978.01 N, 229716.86 W (Grid) Surface Coordinates relative to Structure Reference: 1595.46 N, 1998.96 W (True) Kelly Bushing: 54.07ft above Mean Sea Level Elevation relative to Project Elevation: 54.07ft Elevation relative to Structure Reference: 54.07ft spe""'F""'\/-5UI! DRILLING seRVIc:es A Halliburton Company Survey Ref: svy745 Sperry-Sun Drilling Services Survey Report for Endicott DI-SDI- 3-25/M-27 - 3-25B/L-27 Your Ref: API 500292212502 Job No. AKMW0002377690. Surveyed: 18 April, 2003 BPXA A/aska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11318.16 48.180 345.710 8248.48 8302.55 6338.74 N 2697.78 W 5977396.36 N 267780.65 E 6861.84 Tie On Point MWD Magnetic 11320.00 48.170 345.720 8249.71 8303.78 6340.07 N 2698.12 W 5977397.70 N 267780.35 E 0.685 6863.21 Window Point 11386.31 50.940 347.240 8292.73 8346.80 6389.13 N 2709.90 W 5977447.10 N 267770.07 E 4.527 6913.51 11417.45 52.370 347.960 8312.04 8366.11 6412.99 N 2715.14 W 5977471.10 N 267765.56 E 4.937 6937.82 11513.11 54.250 350.170 8369.20 8423.27 6488.29 N 2729.67 W 5977546.81 N 267753.34 E 2.701 7013.94 --~ 11548.11 55.220 350.980 8389.41 8443.48 6516.48 N 2734.35 W 5977575.13 N 267749.53 E 3.354 7042.20 11580.88 56.600 351.730 8407.78 8461.85 6543.31 N 2738.43 W 5977602.08 N 267746.28 E 4.618 7068.98 11609.74 56.680 352.400 8423.65 8477.72 6567.19 N 2741.76 W 5977626.04 N 267743.68 E 1.959 7092.71 11647.25 57.830 353.260 8443.94 8498.01 6598.49 N 2745.69 W 5977657.45 N 267740.70 E 3.622 7123.70 11678.38 58.470 353.980 8460.36 8514.43 6624.77 N 2748.63 W 5977683.80 N 267738.57 E 2.844 7149.60 11706.63 59.410 354.520 8474.94 8529.01 6648.84 N 2751.05 W 5977707.95 N 267736.89 E 3.708 7173.25 11742.94 59.350 356.770 8493.43 8547.50 6680.00 N 2753.43 W 5977739.16 N 267735.47 E 5.335 7203.62 11 801 . 11 58.720 359.500 8523.37 8577.44 6729.84 N 2755.05 W 5977789.03 N 267735.37 E 4.167 7251.54 11897.92 58.070 1.930 8574.11 8628.18 6812.28 N 2754.03 W 5977871.39 N 267738.91 E 2.241 7329.64 11993.71 57.750 1 .430 8625.00 8679.07 6893.40 N 2751.65 W 5977952.40 N 267743.77 E 0.554 7406.06 12090.27 57.160 359.800 8676.94 8731.01 6974.79 N 2750.77 W 5978033.73 N 267747.14 E 1.549 7483.21 12185.46 56.600 359.650 8728.95 8783.02 7054.51 N 2751.16 W 5978113.42 N 267749.20 E 0.603 7559.16 12280.99 56.060 359.540 8781.92 8835.99 7134.01 N 2751.72 W 5978192.90 N 267751.07 E 0.573 7634.96 12379.47 57.820 358.280 8835.64 8889.71 7216.53 N 2753.30 W 5978275.43 N 267752.02 E 2.084 7713.94 12476.14 57.420 358.390 8887.41 8941.48 7298.13 N 2755.67 W 5978357.07 N 267752.15 E 0.425 7792.29 12571.16 57.170 358.450 8938.75 8992.82 7378.06 N 2757.87 W 5978437.02 N 267752.39 E 0.268 7869.00 12663.45 58.830 0.670 8987.66 9041.73 7456.31 N 2758.46 W 5978515.26 N 267754.20 E 2.720 7943.62 12764.11 57.930 0.530 9040.43 9094.50 7542.02 N 2757.56 W 5978600.90 N 267757.72 E 0.902 8024.87 --/ 12860.43 55.200 359.910 9093.50 9147.57 7622.39 N 2757.25 W 5978681.23 N 267760.49 E 2.885 8101.22 12954.96 52.560 1.200 9149.22 9203.29 7698.74 N 2756.52 W 5978757.52 N 267763.56 E 3.002 8173.62 13051.58 50.580 0.080 9209.27 9263.34 7774.42 N 2755.67 W 5978833.13 N 267766.73 E 2.241 8245.34 13148.61 47.1 00 359.710 9273.12 9327.19 7847.46 N 2755.80 W 5978906.14 N 267768.84 E 3.598 8314.86 13242.82 42.280 0.040 9340.08 9394.15 7913.69 N 2755.95 W 5978972.35 N 267770.71 E 5.122 8377.91 13338.08 37.770 0.520 9413.01 9467.08 7974.94 N 2755.66 W 5979033.56 N 267772.87 E 4.745 8436.08 13433.44 32.840 359.210 9490.81 9544.88 8030.03 N 2755.75 W 5979088.63 N 267774.4 7 E 5.230 8488.51 23 April, 2003 - 14:28 Page 20f4 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for EndIcott D/-SD/- 3-251M-27 - 3-25B/L-27 Your Ref: AP/ 500292212502 Job No. AKMW0002377690, Surveyed: 18 April, 2003 BPXA A/aska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13528.61 30.990 359.380 9571.59 9625.66 8080.34 N 2756.37 W 5979138.93 N 267775.39 E 1.946 8536.56 13604.14 28.080 359.310 9637.30 9691.37 8117.56N 2756.80 W 5979176.15 N 267776.10 E 3.853 8572.10 13699.17 25.770 359.080 9722.02 9776.09 8160.59 N 2757.40 W 5979219.17 N 267776.82 E 2.433 8613.21 13796.44 25.090 359.630 9809.86 9863.93 8202.35 N 2757.87 W 5979260.93 N 267777.62 E 0.740 8653.08 13091.001 2G.320 1.000 9895.10 9949.17 8243.38 N 2757.63 W 5979301.94 N 267779.12 E 1 .444 8692.04 13987.52 28.120 1.060 9980.89 10034.96 8287.50 N 2756.84 W 5979346.01 N 267781.26 E 1.866 8733.76 ~ 14083.93 27.330 359.880 10066.23 10120.30 8332.35 N 2756.47 W 5979390.83 N 267783.01 E 0.998 8776.31 14180.22 27.020 1 .460 10151.90 10205.97 8376.32 N 2755.96 W 5979434.76 N 267784.86 E 0.816 8817.97 14276.43 25.700 0.250 1 0238. 1 0 10292.17 8419.03 N 2755.31 W 5979477.43 N 267786.82 E 1.481 8858.40 14289.37 25.380 0.500 10249.78 10303.85 8424.61 N 2755.27 W 5979483.01 N 267787.02 E 2.609 8863.70 14350.00 25.380 0.500 10304.56 10358.63 8450.60 N 2755.04 W 5979508.98 N 267788.05 E 0.000 8888.35 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 3. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 342.030° (True). Magnetic Declination at Surface is 26.343°(07-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 14350.00ft., The Bottom Hole Displacement is 8888.36ft., in the Direction of 341.943° (True). .~. 23 April, 2003 - 14:28 Page 3 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Endicott DI-SDI - 3-25/M-27 - 3-258/L-27 Your Ref: AP/500292212502 Job No. AKMW0002377690, Surveyed: 18 April, 2003 BPXA A/aska State Plane 3 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11318.16 11320.00 14350.00 8302.55 8303.78 10358.63 6338.74 N 6340.07 N 8450.60 N 2697.78 W 2698.12 W 2755.04 W Tie On Point Window Point Projected Survey .-" Survey tool program for 3-25/M-27 - 3-258/L-27 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11318.16 0.00 11318.16 8302.55 AK-1 BP _HG - BP High Accuracy Gyro (3-25/M-27) 8302.55 14350.00 10358.63 MWD Magnetic (3-25B/L-27) ..---" 23 April, 2003 - 14:28 Page 4 0'4 DrillQuest 3.03.02.005 ') ~ ~~~ !Þr~~ "E : F !Æ ~!Æ ~ '.~«!Æ ALASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK'. GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Endicott 3-25B/L-27 BP Exploration (Alaska) Inc. Permit No: 203-021 Surface Location: 2519' SNL, 759' WEL, SEC. 08, TI1N, RI7E, UM Bottomhole Location: 664' NSL, 3484' WEL, SEC. 32, T12N, RI7E, 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 until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the pennit. 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). Sincerely, ~/~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this .r a. day of February, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. W6 A- 2-/ c¡.lr)'~ 12. Distance to nearest property line 13. Distance to nearest well ADL 047502, No Close Approach /' 16. To be completed for deviated wells Kick Off Depth 11350' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Casina Weiaht Grade CouclinQ 4-1/211 12.6# 13Cr80 Hydril563 Hole 8-1/211 '\ STATE OF ALASKA ) ALASKI. ÒIL AND GAS CONSERVATION COMlvi~SSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test B Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned KBE = 55' Endicott Field I Endicott Pool 6. Property Designation ADL 312828 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number /' 3-25B/L-27 9. Approximate spud date ~. 03/20/03 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 ~14355' MD 110335' TVD 17. Anticipated pressure {s~O AAC 25.035 (e) (2)} 65 0 Maximum surface 3965 psig, At total depth (TVD) 10335' I 4998 psig Setting Depth Toc Bot,tom Quantitv of Cement Lenath MD TVD MD TVD (include staQe data) 3155' 11200' 8225' 14355' 10335' 691 sx Class 'G' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill B Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 270283, Y = 5970978 2519' SNL, 759' WEL, SEC. 08, T11 N, R17E, UM At top of productive interval x = 267788, Y = 5979370 512' NSL, 3486' WEL, SEC. 32, T12N, R17E, UM At total depth x = 267794, Y = 5979522 664' NSL, 3484' WEL, SEC. 32, T12N, R17E, UM Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 14428 feet 9983 feet 12970 feet 94889874 feet Length Plugs (measured) Top of Cement at 12970', Bridge Plug at 13488' MD Junk (measured) Lost 611 BHA/Drilling Assy. Top at 13494' Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 92' 3011 2409' 13-3/8" 13345' 9-5/8" 1009' 7" Driven 2629 cu. ft. Permafrost 131' 2448' 131' 2383' 3448 cu. ft. Class 'G' 13384' 9805' 454 cu. ft. Class 'G' (Top of Window) 13141' - 13571' 9619' - 9936' RECEiV'ED Perforation depth: measured None \ " ;. 1 "J ('I .')(\ n 3'- '-.>¡-\I\~ i. C, Lv!.'- true vertical Alasl<a Oil & Gas Gons. COrJmission Ä\1Q;nOf"í]ß B Filing Fee 0 Property Plat B BOP Sketch 0 Diverter Sketch B Drilling Program B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report B 20 AAC 25.050 Requirements None 20. Attachments Contact Engineer Name/Number: Fred Johnson, 564-5427 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the forypoing)s t)Ue nd correct to the best of my knowledge Signed Fred Johnson l :¡ /C.J4l tAl' Title Senior Drilling Engineer ,;eq~fItissiòn'U~"þnly,l, Date I /~8!o 3 Permit Number Z-03'-O.2./ Conditions of Approval: API Number 50- 029-22125-02 Samples Required 0 Yes 3No Hydrogen Sulfide Measures ~ Yes 0 No Required work~~M~r~PE D2K D3K Other: ~Lp\.VJ:ca.U '" 1f~oo P Sl · APproval,D1e /2 See cover letter 9ì ~ O? for other requirements Mud Log Require 0 Yes B No Directional Survey Required ~ Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU Approved By Form 10-401 Rev. 12-01-85 Commissioner . by order of the commission Date ~\~ 0.1) Submit In Triplicate ) ) Endicott 3-25B/L-27 Well Program p n ,'=, ,.,.~"".,,,, Zt ·'l7'¡; IWell Name: 13-25B/L-27 Drill and Complete Plan Summary Su rface Location: 1 Type of Well (service I producer I injector): 1 Producer Target Location: L-27 K2A Top Target Location: L-27 K1 Target Location: BHL Well TD /' 251~'SNL,7591VVEL, SEC. 08, T11N, R17E ' X=270,283.14 Y=5,970,978.01 512ì NSL, 34a6'WEL,SEG.32, T12N; R17E ~. X=267,788 Y=5,979,370 Z=10049' TVD 5941 NSL, 3485' WEL; SEC. 32,T12N, R17E X=267,791 Y=5,979,452 Z=10,203' TVD 6641 NSL, 3484' WEL, $EC~~2, T12N, R17E /' X=267,794 Y=5,979,522 Z=10,335' TVD 1 AFE Number: 1 END 727112 1 1 Rig: I Doyon 15 / I Estimat~d Start Date: 1 March 20, 2003 /1 I Operating days to complete: 1 MD: 114,355' I I TVD: 110,335' I 1 Max Inc: 165 @ 11,700' I I KOP: 111,350' I 1 KBE: 21 155.0 1 Well Design (conventional, slimhole, etc.): 1 Conventional Sidetrack Target Kekiktuk S2A3 & S2A 1 Sands Objective: Well . No recordable injuries. No spills. Objectives: . Drill and complete well successfully. No Trainwrecks . Run 4-1/2" liner to TD . Cement liner successfully to obtain zonal isolation across Kekiktuk sands Overview: MIRU Doyon 15. Pull tubing hanger and 2 joints of 4-1/2" tubing. Set whipstock at -11,400'. Mill window in 9-5/8". Kickoff in Seabee shale. Directionally drill to TD @ -14,335' MD, 150' below the K1 Zone in the Kekiktuk. Obtain real time triple combo LWD logs across Kekiktuk while drilling. Run and cement a 4-1/2" rotatable chrome liner in this 8-1/2" hole, followed by a 4-1/2" chrome completion. ) ) Endicott 3-25B/L-27 Well Program Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 1506 1500 8.65 KOP in Seabee 11350 8269 3720 8.65 Top Tuffs 12734 9016 4055 8.65 Top HRZ 13425 9519 4703 9.5 ¡Oo'S Base HRl/LCU 13746 9798 4840 9.5 Top K3A 13765 9815 4849 9.5 P3 Coals 13765 9815 4191 8.8 K2B 13909 9942 4550 8.8 K2A 14030 10049 4285 8.2 K1 14204 10203 4934 9.3 TO 14355 10335 4998 9.3 Mud PrOQram: 9-5/8" Window Milling Fluid Properties: Density Plastic Vis Yield Point (ppg) (cp) (lb/100ft2) 9.7 1 0-15 27 -32 GEM Freshwater L8NO mud tauO Gel Strengths API Filtrate (lb/100ft 10sec (mls/30min) 2) 4-7 1 0 6-10 pH 8.5-9.5 8-1/2" Production Hole Mud Properties: I GEM Freshwater L8NO Mud Interval Density PV YP TauO 10' Gel API/ HTHF pH LGS (ppg) (cp) (lb/100ft2) (lb/1001t2 (mls/30min 0/0 vol KOP-THRZ 9.7 / 10-15 27 - 32 4-7 10 6-10 8.5-9.5 <5 THRZ-TO 10.3 10 -15 20 - 25 3-7 10 < 4/< 10.0 8.5-9.5 <5 The window (with whipstock) will be milled with the planned drilling mud LCM Restrictions: Minimize use of organic LCM products in the Kekiktuk Waste Disposal:NO ANNULAR INJECTION. Waste mud and drill cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Be aware of Sag River Bridge load restrictions. Alternative mud disposal at Endicott is being reviewed. 2 of 9 7000 7500 8000 8500 .c - Q. C1) Q 9000 Q > I- 9500 10000 , K2A , 10500 11000 8 ) 3-25B/L-27 Mud Weight - Pore Pressure - II /' SEABEE .1 j" I TU =FS I ~..... I 11II -HZ II n i KEKIKTUK K11 n .;. - K2B I I I I III I I I I I I I I II III -+- Pore Pressure -8-Mud Weight I I I r I r 1 I I r 1 I I I 1 8.5 9 9.5 10 10.5 11 11.5 12 Mud Weight (Ib/gal) 3 of 9 ) Endicott 3-25B/L-27 Well Program ') Endicott 3-25B/L-27 Well Program Cement Pro~ram: Casin~ Size 14.5" 12.6-lb/ft 13Cr Hydril563 Production Liner in 8-1/2" hole Basis 300/0 excess over gauge hole. Planned TOC - 12,100' MD. 1640' above top of Kekiktuk, (but below hanger in gauge hole case) Wash None Spacer 65 bbI11.5-lb/gal MudPush XL Spacer ~:~d .~) (148-bbl) 15.8Ib/gal Prem G -~Uft/SX (top of tail- 12,100- Temp I BHST == 2150 F From SOR. BHCT 1650 F estimated by Dowell Evaluation Program: 8-1/2" Hole Section: KOP to Top Kekiktuk: MWD/GR/PWD Real Time and Recorded, INSITE Kekiktuk MWD/GR/Res/Neutron/Density/PWD LWD Real Time and Recorded, INSITE Cased Hole: None CasingITubing Program: Hole Csgl WtlFt Grad~ Conn Length Top Bottom Size Tbg O.D. ../" ~ MD I TVDrkb MD I TVDrkb 8-1 /2" 4-1/2" 12.6 # 13Cr80 Hydril563 3155' 11,200'/8225' 14,355'/10,335' Tubing 4-1/2" 12.6# 13Cr80 Vam ACE 11 ,150' 0/0 11,150'/8191 ' Recommended Bit Pro~ram: BHA Hole Depth (MD) Size 8-1/2" 8-1/2" 8-1/2" Bit Type Nozzles 1 Contingency Contingency 11 ,350' - 14,355' Tuffs HRZ/Kekiktuk PDC 437 Roller Cone PDC 6x12 (.663 TFA) .663 TFA 6x12 4 of 9 Directional Plan KOP: 111,350' MD Maximum Hole Angle: Close Approach Well: Survey Program: Well Control: Production Intervals BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure Casing Test Pressure (9-5/8" x 4-1/2") Planned completion fluids ) ') Endicott 3-25B/L-27 Well Program -Original wellbore is a 50°-55° slant well design -Maximum inclination 55° in original well bore at -8,400' MD. -Sidetrack builds inclination to 65° at 11,700', and then drops inclination from 65° to 28° at top of the Kekiktuk There are no downhole close approach issues with active wells. The closest well to the 3-258/L-27 is the original well at the 11,350' KOP. MWD surveys from kick-off to TO. 13-3/8", 5M, Double ram with annular (Hydril - GK) 499B-psi (~.3-lb/gal @ 10335-ft TVD) 39.95~siV(0.1-psi/ft gas gradient to surface) f11injte with 12.0 ppg emw FIT at KOP and 9.5 pressure ~'s test to 4500-psi/250-psi. "'" Annular test to 3,500-psi/250-psi 3,000-psi 8.5 Seawater & Diesel packer fluid 3-258/L-27 is being drilled as a K2A producer. The 10.3 Ib/gal recommended mud weight for the HRZ is the controlling mud weight requirement. All of the anticipated Kekiktuk intervals should be overbalanced with this mud weight. 5 of 9 ) ) Endicott 3-25B/L-27 Well Program Sidetrack and Completion Procedure Summary Pre-Ria Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Pressure test the tubing hanger seals to 5000 psi for 30 minutes. Completed 10/10/2002. Tubing hanger...........~,. seals tested to 5000 psi for 30 minutes. All tubing hanger lockdown screws were functioned. 2. Pressure test the 9-5/8" FMC casing hanger packoff to 3000 psi for 30 minutes. Completed 10/10/2002. Casing hanger packoff tested to 3000 psi for 30 minutes /' 3. RIH with CTU and set a P&A cement plug using 15.8 Ib/gal cement. Use adequate cement volume to fill the 7" liner from the bridge plug at 13488' up to 13050' in the 9-5/8" casing. Completed 1/212003. Estimated TOC 12,970'. Possible cement stringers above plua. Could not aet bond loa down. 4. RU eline. Run CBUVDL log from 12500'- 8500'. Completed 1/4/2003. Could not get below 11600. Poor-- cement at KOP. 5. Tag and document top of cement. 6. Displace well to seawater. Not Done: Well left with 9.4 brine Freeze protect the well to 2000' Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 7. Prep the well house, cleanout cellar, and rig down the flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Rig Operations: / 1. MIRU Doyon 15. 2. Pull BPV. Set TWC & test from below. /' , 3. Nipple down tree. Alignment marks should be made before removing the old tree. Nipple up and test BOPE to 250 / 4500 ps~Pull TWC. 4. Pull and lay down tubing hanger and 2 joints of 4-1/2" tubing. 5. RIH with full gauge whipstock mill on 5" drill pipe to 12000'. Circulate out freeze protect.,.........., 6. RU e-line. Run and set a 9-5/8" bridge plug to position top of whipstock at +/- 11,350'. Run GR log from 11- 350' to 7500' to establish "Primary Depth Control" 7. MU 9-5/8" whipstock and milling assembly and RIH with 5" DP. Orient and set whipstock on bridge plug. Mill window in 9-5/8" casing. 8. MU 8-1/2" PDC drilling assembly including MWD/GR. RIH to window. /' 9. Kick-off and drill the 8-1/2" hole section as per directional plan to TD at +/-14355" MD (10,335' TVD). Trip for triple combo LWD prior to the Kekiktuk. Condition hole for running liner, spot liner running pill, and POOH. /" 10. Run and cement a 4-1/2", 12.6 Ib/ft 13 Cr-80 production liner. Release from liner and set liner top packer. Test wellbore to 2000 psi to verify liner top packer is set. Displace well to seawater. 11. Run 4-1/2", 12.6 Ib/ft 13 Cr-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" ~r tie-back sleeve. If required, RU slickline and make drift run thru liner hanger to verify proper spacßPut. 12. Drop ball/rod & set packer. Test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 13. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 14. Freeze protect to 1500' MD and secure the well. 15. Rig down and move off. Post-Ria Work: 1. RU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the production packer. 2. CTU liner cleanuout to circulate out drilling mud from liner. 3. Install gas lift valves. 4. RU e-line. Perforate -50' of Kekiktuk interval with 2-7/8" guns. 6 of 9 '') ¡ ) Endicott 3-25B/L-27 Well Program Job 1: MIRU Hazards and Contingencies :¡. Two wells, 3-21, 3-23 will require shut-in before the 3-25 rig move. The well is located -10' from 3- 23(shut in producer) & 20' from 3-21 (800 BOPD producer). These wells will need to be shut-in at the both at the surface and the SSSV. All surface flowlines and gas lift lines will be de-pressured to header pressure. These offset wells will need to be secured during both rig moves and ND/NU BOP. Review the "Endicott Operations Simultaneous Operating Guidelines". Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. :¡. SDI is designated as an H2S site. Follow Standard Operating Procedures for H2S at all times. Recent H2S data from the pad is as follows: Adjacent producers at Suñace: 3-11 Max: 800 ppm (10/1/00), Last: 380 ppm (2/28/02) 3-19 Max: 1600 ppm (3/2/99), Last: 160 ppm (12/10/00) 3-21 Max: 167 ppm (3/1/02), Last: 47 ppm (3/07/02) 3-23 Max: 145 ppm (10/1/01), Last: 55 ppm (10/12/01 The maximum recorded level of H2S on the pad was 2000+ ppm from 3-43 on June 19,1999. )- Well cellar has had a new spray in liner installed. Check with Endicott Environmental to determine if the cellar is considered to be secondary containment and if the cellar could be used as a sump to catch fluids. )- Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud )- Note: A new 4" chrome tree will be installed on this well. load the new tree into the sub base prior to moving on the well. Job 2: Decomplete Well Hazards and Contingencies :¡. The old open hole interval should be isolated by the pre-rig cement plug and a 7" bridge plug. The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. Seawater will be underbalanced to the Kekiktuk reservoir pressures. :¡. NORM test all retrieved well head and completion equipment. :¡. The existing wellhead is a McEvoy SSH 13-5/8" 3m x 13-5/8" 5m and has a DX-2 SSH CCl tubing hanger with 4 1/2" NSCT landing thread. Utilize a 4" Cameron 'H' BPV. Verify the hanger type and connection. Be prepared with necessary equipment to remove. A new tubing hanger was installed in 2001 when the well was suspended. Have tubing hanger inspected and reuse if possible. !t..,),L-.l..";'¡';';"" ""~JI.._;~~.,.._""~ ~l.. M.....; ..I......,,,",--.\.I,.:,:J.--. ,~, ~_~~";,-¡;.¡,;I\J IO,:-n~"'\--~~T-.T-"'~'-Ul...;;, --,.;~I;J~..iII."~,"'_'~-, .),.:..:. ~....-.~,"..I-\...Jo¡.'¡"... I,...........~ ._._ ...:.-.......¡.;-j;..LI.:.:;,...: _~.....;.-T~~I~-In_- '.I,...\>.,., - ,),.........MJ.,,.~" .;;-U¡'-~--;,/II':-.I.;;,II-~ Job 3: Run Whipstock Hazards and Contingencies :¡. Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. 7 of 9 ) Endicott 3-25B/L-27 Well Program 1~1,I,\W.:.a.I}'",,',n:,l.IJ;,~..,., ~';';ÅlAlArAlAI,I,I,'I.W,IA";;AA.,I.I,I.I,I,IAWAW,\I),I,;.IAOO'Al.:'~-;"-;"I,I,-Ml.";-'w'l,I,l,I,In,-...,.:AI.1,I,.;I,I,I,OOIJ.l.W.I.rAIA:.I.I,I.I.I.I.l.I,I,I}.IAWA"#w.w.I,:,-;"-,;.I,I,I,W.IAI.I,I,I,I,IJ,I,-,rA-.l.-,I,I.lAAI,I.I,I,;.I.~\I.D.-.wA-...-m,I;,-,I,I.l.I,I.I.l.I.I.,I,I.l.l.lAAI;,I.l.OOI;,W.l.',I,I,I,I,I,IJ,W,l,..I.I,I,I;WAI»MI.I,I.I,I.I,I,I.I.I,I.:,nl,l.l,I,l,I.lm~rm,I,I,I,I,I,I.I.l.I.l.W.l.I,I,I,I.I'-,-AI,I,I,I.IAWAW.w.I.W.I,I,Iµ':,-"-:,-,l.-,I,-,I,IAI,I,I,-,',\-,I.1,I,1,I,1,IAA1,I,1,,;,.;tAI,I,I,I.I,IAAI,I,w.,:x.\:,I.:m,I,\I,I,w,I,I,I,I,W,I,I.I,I,Wmw;,I;.I.IAAI,I,IAI,I,I,:J,I,-"-,l,lJ.I.w.w.:.-.w.:.I.I.I.;,I,4.U.1,I.-.I.-~:..AA;A.I,l:.I.In.I.w.: Job 7: DrillinCl 8-1/2" Production Hole Hazards and Contingencies > The well will kick off in the Seabee with a 9.7 Ib/gal mud. The mud weight will be increased to 10.4 Ib/gal prior to drilling the HRZ. The 10.4 mud weight requirement for the HRZ should result in being overbalanced to all of the Kekiktuk reservoirs. Follow all shale drilling practices to minimize potential problems. > The well path will drill full sections of the Tuffs and HRZ shales, and both formations have been troublesome in the Endicott area. The Tuffs is typically slow and erratic drilling, which can wipe out a PDC bit if proper drilling parameters are not maintained. The HRZ on the other hand has shown severe hole instability problems if insufficient mud weight is used. Follow all (1) shale drilling practices, (2)ECD management to limit high ECD's, and (3) maintain proper mud weights and shale stabilizers in the drilling fluid. > The P-3 coal sections should be encountered at the top of the Kekiktuk interval in this well. These coals have caused packoff and stuck pipe problems in the past. Follow good coal drilling practices. > Differential sticking is the largest operational risk in this well. Differential sticking will be a problem if the drill string or liner is left stationary for any period of time across the high permeability Kekiktuk Sands. The GEM enhanced LSND drilling mud must be kept in excellent shape when drilling the Kekiktuk to provide good filter cake properties. The Kekiktuk K2A reservoir pressure is expected to be 4300 psi (8.2 ppg EMW) at the bottom hole location. The 10.4 Ib/gal mud required for HRZ stability will be 2.2 Ib/gal over balanced to the Kekiktuk. This 1200 psi pressure differential creates a severe differential sticking risk. > No major fault crossings are planned in the drilling of this well. The well path will cross over the major Midfield Fault but this fault does not extend upwards into the wellbore path. The directional plan will need to be followed closely in the target interval to prevent hitting the smaller faults to the south and north of the target. > The Kick Tolerance for the 8-1/2" open hole section at the KOP, based on the 9.5 Ib/gal expected pore pressure is infinite with an FIT of 12.0 Ib/gal EMW. Prior to penetrating the reservoir, hold a Pre- Reservoir Safety Meeting to raise awareness and communicate individual well control responsibilities to all members of rig team. > Drilling Close Approach: All wells pass BP Close Approach guidelines. IT...... 1-, A.-':'. Ir;- I-T r.'''. ..1. -III. ',;111I1 . .;;n--- .IIIIIIL .II__UII Job 9: Install 4Y2" Production Liner Hazards and Contingencies > Long shale intervals will be exposed while running the liner. Rotation of the liner may be necessary if downward progress is not possible. To minimize ECD spikes and associated shale stability problems, bring pumps on slow and minimize downward surges with pipe. The limits for working the liner to bottom are: Workina Ranaes o Torque in liner: < 5000 ft-Ibs o RPM in liner < 35 rpm o Pressure in liner < 2000 psi o Compression in liner < 50K Ibs o Tension in liner < 100 K Basis Max: Connections MU to 7000 ft-Ibs Max: 2625 psi sets Flexlock LH Max: 200K (HRD Setting Tool) Max: 288K (pipe) 8 of 9 ) ) Endicott 3-25B/L-27 Well Program > Differential sticking is a significant potential problem in the Kekiktuk. Minimize the time the pipe is left stationary while running the liner through this interval. > Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. W,I,JAIAI,I,w.;,I;,-;,:,I.\I,W.l.l.l.l,I,am.~.w.I,I.WA·A!,I,J,I.I,;.I,I.I)AAI,W,l).I.I,r,ammlm,lAAW.WA:Jo.W.IAAI,I.IAI.I,IAI,l,JA=A~,I.-m1,I,.I.I,I,I,I,I.W.W».l.w;.I,I,I,I,I,I,I,I,I....,IAAI.W.I,I,IAI,I,I,I,I,I,I.W.I,IJ,'I,I,W.\I,I.IAA~I.I.I.IAAI,l.I.l.I,\I,I,:AA'!AI',:AIAAI.-,l.l,I,I,I,Wml,l,l.I.I.I..AI,I.a;,I,I,W,I,!.l.IAI.I.WA"\I,I.I).W,IA..w.I,I..A;'¡'.AI,I,WAAl~,DW,l.IAI,I,WA""~I.o.:m~.I.~\I,I.-,,-¡,-¡.,-AI,I,I,I,I,I,I,IJ,I,I....,\IAI/,.!#I\Iþ,I,l.I,I,I,I,I,I,I,I,I,I,I,I,I,lAAI),I),IMI,I,I.;,¡.I,I,WIMl,I,\I,I,IA....I,I,I,:".:,I,W.D.:..MIAI,I,I,I,I,I,W,IAA',l.I,I,I.l.I,I,I.I.-AI,I,I;,a.a,l;,l,I.r,l.I,I,I.l.IAWAI¡\"I,I.I.I.I.I.lAa.;,I.I.I,I~-,'-A-AI,lMlma,W,I,I,DAAI,:,I,I,I.:,I,C Job 12: Run Completion Hazards and Contingencies > Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ,.. 0.1 psia at 100° F. Job 13: ND/NU/Release RiQ Hazards and Contingencies > See Job 1 for adjacent well spacing. These are close well centers. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. 9 of 9 TRE E: 4-1/16" 5m Cameron 8S Tre '{ith Double Actuator WELLHEAD: 13-5/8" 15000 psi L }voy) ") R.T. ELEV = 55.1' B.F. ELEV = 15.28' MAX. DEV. = 55:10 8400' M.D. .4'.·.·' .. . SSSV LANDING NIPPLE I 1500' OTIS (3.813" 1.0.) W/SSSV IN MIN 1.0.2.0" 13-3/8", 68#/ft, NT80 CYHE BUTT CSG ~ 2448' ... 4-1/2" x 1-1/2" GLM 4-1/2" 12.6 I bitt 13 Chome 80 Vam Ace Tbg . . 4-1/2" Selective X Nipple 3.813" I ~ X - 9-5/8" BAKER 8-3 PACKER AT 11150' . 4-1/2" No Go XN Nipple 3.75" I I . 1 4-1/2" Selective X Nipple 3.813" Top of 4-1/2" Liner 11200' Baker 9-5/8"x7" FL Liner Hgr & L TP AT 11200' 7" Window 13571 '-13583' 8-1/2" HOLE x 4-1/2" LINER 13 CR HYDRIL 563 LlNER./ TD 14355'MD, 10335'TVD 9-5/8" 47 Ib/tt NT80 XO to NT95HS at 11396' 9-5/8" Whipstock Window at 11350' Top of 7" TIW Liner 13141' 9-5/8" 47 Ib/tt NT95 HS, NSCC at 13384 ~ ~ PBTD 14060 ' > 7", 2 9#/ft, NT95 HS 1 4 1 50 ' > TKC Date By Comments 2/12/9 1 PGS PROPOSED COMPLETION 3/28/9 1 JLH INITIAL 10/29/93 RSA RWO COMPLETION 08119/02 FJ PROPOSED ST < 6" hole drilled to 14,429' MD Lett BHA fish in hole 13491 '-13623' Well suspended I I Existing perforations P&A'd during pre-rig operations in 2001 FNnl~nTT WF. .: ~-?5R/. -77 API NO. 50-0?9-??1?5-01 PROPOSFn COMP. FTION nlAGRAM BP EXPLORATION (ALASKA), INC ') ) sp......,Y-!!IU1 BPXA r,lIFUI.. lUll" s....v.c.. AI ka State PI 3 A HlII111uftø COIIIpIny as ane Eastings(Well) Scale: 1 inch = 500ft -3250 -2750 I I ~;:'~::;;79~; Total Depth: 14354.49ftMD,10335.49ftTVD 10203.10 TVD. HARD LINE 4 112"Llner 8393.74 N. 2750.35 W . - --1 14342.55ftMD 3·258/L·27 T2 GeoPo¡y I' , ì2oo.98 10324.95ftTVD Endicott DI-SDI 3-25BIL-27 Wp 22 DrillQues/'''' Well: Cu.....nt Well Properties 3-25B Horizonllll Coordlnàs; R.f.GlobelCoordln8les; 597~78.01 N.270283.14 E Ref. StruclUIW R.f....nce : 1595.48 N. 1998.98 W R.f. Geographlcel Coordinates; 70' 19' 20.4002' N, 147' 51' 45.809T' W RKB EleVlllion ; 55.1011 abow Mean Sea Lelllll 55.1011 Ibow StrUCIunl R.f....nce True North F..t (US) ~25B/L~7n \ Drillers @ 90 % \ J 10049.10 TVD, L..... . .- 8250 - 8311.87 N. 2751.07 W ' 3-25Bf1.·27 T1 Ge..·po¡y "''('\I .' ~3634.89 ;t-End Dir, Start Sail @ 28.000°: 13579.71ftMD,9651.26ftTVD ,... .P782.~6 ~ It) ~59 Begin Dir @ 4.0000/10Oft : 13139.59ft MD, 9300.0Oft TVD 7750 - - ã) ~ U; C) c: :E t:: ~ 7250 - 6750 - ð o It) II ..c: t,) .5 iD ~ 6250 - en 8250 - ã) 9000 - ~ .s:::. ë.. Q) c ~ t: Q) > 9750 - .t:: o It) ,... II ..c: t,) .5 ëD ~ cn 10500- DrllIQuest 3.03.02.002 North R.f.rence ; UnitB ; .:m~.~() J211Õ.~nd Dir, Start Sail @ 45.553°: 12734.02ftMD,9016.0OftTVD ~5.08 Begin Dir @ 5.0000/100ft: 12355.08ft MD, 8799.58ft TVD ___End Dir, Start Sail @ 64.432° : 11710.61ftMD,8521.43ftTVD 1472.30 ....-Decrease Dir Rate @ 5.0000/100ft: 11370.00ftMD,8337.26ftTVD - Sidetrack Point TF RT 34.80° 12.0000/100ft: 11350.0Oft MD, 8324.16ft TVD , 1163.IN , Sidetrack Point TF RT 34.80° 12.0000/10Oft : 11350.0Oft MD, 8324.16ft TVD Decrease Dir Rate @ 5.0000/100ft : 11370.0OftMD,8337.26ftTVD 1400.00 End Dir, Start Sail @ 64.432° : 11710.61ftMD,8521.43ftTVD egin Dir @ 5.0000/10Oft: 12355.08ft MD, 8799.58ft TVD 26oo.00End Dir, Start Sail @ 45.553°: 12734.02ftMD,9016.0OftTVD egin Dir @ 4.000°/1000: 13139.59ft MD, 9300.000 TVD End Dir, Start Sail @ 28.000° : 13579.71ftMD,9651.26ftTVD ~25B1L·27 T2 Drillers Ii 90% 10203.10 '7VD. 4200.00 8393.74 N. 2750.35 W / Total Depth : 14354.49ftMD,10335.49ftTVD 4 112'Uner 14342.55ftMD 10324.Q5IIT\IO I 7125 Scale: 1 inch = 750ft I 7875 8625 Section Azimuth: 342.000° (True North) Vertical Section (Well) ') ) .p.......,y-1iLI1 BPXA Endicott DI-SDI DrillQuest"" 1'!I,t9.0." .~" ø-...Vtc:.. Alaska State Plane 3 3-25BIL-27 Wp 22 A HlINIluI'lOll ComNIny CunentW.IPrope~ Well: 3-258 I:)¡I Hortzonllll Coordlnlllea: Ref. Giebel Coordlnlllea : 5970978.01 N. 270283.14 E Ref. Structure Relerence : 1695.46 N, 1998.98 W ReI. Geographical Coordlnøtee : 70' 19' 20.4002' N. 147' 51' 45.80970 W RKB ElevaUon : 56.101t lIbow Mean Sea Lewl 55.101t lIbow Structunt Relerence 11" North Relerence : True North Unlll: Feet (US) ~IIII' ~IIII 3-25BA.-27 WP22 Propoul Date ~II' ~~=~~n: Well Wall Moaeuremenl Unlta : It North Rllarenoe : T rua North =~~~~mJth: tI.~oper 100 la'" (US) Vertical Section Oeecription: Well Vertical SlCIlon 0rI91n : 0.00 N.O.OO E MeMUred Incl. Azlm. VerttÇIII NorthIng8 E8et1ng. V'1'I1cII1 ~II Depth Depth Section 11350.00 48.067 34UOl 8324.16 6360.99 N 2703.39 W 6885.05 /' 11370.00 5O.o.~2 347.587 8337.26 6375.69 N 2706.86 W 6900.11 12.000 11410.00 51.703 349.041 8362.50 6406.08 N 2713.14 W 6930.95 5.000 11710.61 64.432 358.506 8521.43 6658.88 N 2739.25 W 7179.44 5.000 m55.08 64.432 358.506 8799.58 7240.04 N 2754.40 W 7736.84 0.000 12734.02 45.553 0.497 90 16.00 7548.97 N 2757.72 W 8031.68 5.000 13139.59 45.553 0.497 9300.00 7838.50 N 2755.21 W 8306.26 0.000 13425.40 34.121 0.497 9519.10 8021.28 N 2753.62 W 8479.61 4.000 13579.71 27.949 0.503 9651.25 8100.79 N 2752.93 W 8555.01 4.000 14030.08 27.949 0.503 10049.10 8311.87N 21S1.07 W 8755.18 0.000 14204.49 28.046 0.510 10203.10 8393.74 N 2750.35 W 8832.82 0.000 14354.49 28.046 0.510 10335.49 8464.26 N 2749.72 W 8899.70 0.000 3-25B1L-27 Target Data Measurement Units: ft Target Coordinate Vertical Depth NOrthlngs Eaetlnga Vertical Depth Northlng8 Eastlng8 Target Name Point Type Well Well W.I MSL ASp·3 ASp· Shape (ft) (ft) (ft) (ft) (ft) (ft) 3-25B/L-27 Fault I Entry Point 5~UO 6980.98 N 4027.70W 0.00 5978079.00 N 266471.00 E Polygon Boundary Point A 55.10 6980.98 N 4027.70 W 0.00 5978079.00 N 266471.00 E B 55.10 7226.41 N 1861.20 W 0.00 5978258.00 N 268644.00 E C 55.10 6980.98 N 4027.70W 0.00 5978079.00 N 266471.00 E 3-25B/L-27 Fault 2 Entry Point 55.10 7526.77 N 3226.04 W 0.00 5978600.00 N 267289.00 E Polygon Boundary Point A 55.10 7526.77 N 3226.04 W 0.00 5978600.00 N 267289.00 E B 55.10 8015.86 N 2544.69 W 0.00 5979068.00 N 267985.00 E C 55.10 7526.77 N 3226.04 W 0.00 5978600.00 N 267289.00 E 3-25B/L-27 Fault 3 Entry Point 55.10 7506.97 N 3872.73 W 0.00 5978600.00 N 266642.00 E Polygon Boundary Point A 55.10 7506.97 N 3872.73 W 0.00 5978600.00 N 266642.00 E B 55.10 7411.50 N 2351.10 W 0.00 5978458.00 N 268160.00 E C 55.10 7506.97 N 3872.73 W 0.00 5978600.00 N 266642.00 E 3-25B/L-27 Tl Entry Point 10049.10 8311.87 N 2751.07 W 9994.00 5979370.19 N 267787.77 E Circle 3-25B/L-27 Tl Entry Point 10049.10 8311.87 N 2751.07 W 9994.00 5979370.19 N 267787.77 E Polygon Drillers @ 90 % Boundary Point A 10049.10 8361.22 N 2744.74 W 9994.00 5979419.32 N 267795.61 E B 10049.10 8353.68 N 2724.30 W 9994.00 5979411.16 N 267815.81 E C 10049.10 8339.64 N 2709.44 W 9994.00 5979396.67 N 267830.23 E D 10049.10 8322.44 N 2699.90 W 9994.00 5979379.19 N 267839.24 E E 10049.10 8302.60 N 2695.33 W 9994.00 5979359.22 N 267843.20 E F 10049.10 8280.46 N 2697.66 W 9994.00 5979337.16 N 267840.20 E G 10049.10 8260.25 N 2710.39 W 9994.00 5979317.35 N 267826.85 E H 10049.10 8249.47 N 2732.40 W 9994.00 5979307.25 N 267804.52 E I 10049.10 8252.22 N 2756.50 W 9994.00 5979310.74 N 267780.52 E J 10049.10 8265.41 N 2775.47 W 9994.00 5979324.50 N 267761.96 E K 10049.10 8283.15 N 2787.44 W 9994.00 5979342.60 N 267750.54 E L 10049.10 8302.68 N 2793.51 W 9994.00 5979362.31 N 267745.07 E M 10049.10 8323.55 N 2793.36 W 9994.00 5979383.16 N 267745.86 E N 10049.10 8343.78 N 2784.86 W 9994.00 5979403.12 N 267754.98 E 0 10049.10 8357.94 N 2767.14 W 9994.00 5979416.73 N . 267773.12 E 3-25B/L-27 1'2 Entry Point 10203.10 8393.74 N 2750.35 W 10148.00 5979452.00 N 267791.00 E Polygon Drillers @ 90% Boundary Point A 10203.10 8396.21 N 2782.34 W 10148.00 5979455.45 N 267759.10 E B 10203.10 8407.31 N 2763.74 W 10148.00 5979465.97 N 267778.03 E C 10203.1 0 8410.45 N 2730.76 W 10148.00 5979468.10 N 267811.09 E D 10203.10 8401.88 N 2707.50 W 10148.00 5979458.83 N 267834.08 E E 10203.10 8382.47 N 2695.56 W 10148.00 5979439.06 N 267845.42 E F 10203.10 8348.85 N 2697 .03 W 10148.00 5979405.50 N 267842.92 E G 10203.10 8333.83 N 2707.55 W 10148.00 5979390.81 N 267831.95 E H 10203.10 8322.19 N 2737.23 W 10148.00 5979380.08 N 267801.92 E I 10203.10 8326.86 N 2773.96 W 10148.00 5979385.88 N 267765.35 E J 10203.10 8339.03 N 2787.33 W 10148.00 5979398.45 N 267752.36 E K 10203.10 8369.98 N 2793.26 W 10148.00 5979429.57 N 267747.38 E 3-25B/L-27 1'2 GeoPoly Entl)' Poinl 10203.10 8393.74 N 2750.35 W 10148.00 5979452.00 N 267791.00 E Polygon Boundary Point A 10203.10 8469.88 N 2877.74 W 10148.00 5979532.00 N 267666.00 E B 10203.10 8477.53 N 2627.86 W 10148.00 5979532.00 N 267916.00 E C 10203.10 8m.62N 2621.73 W 10148.00 5979332.00 N 267916.00 E D 10203.1 0 8269.97 N 2871.62 W 10148.00 5979332.00 N 267666.00 E 3-25BIL-27 Fauh 4 Entl)' Point 55.10 8953.89 N 3570.88 W 0.00 5980037.00 N 266988.00 E Polygon Boundary Point A 55.10 8953.89 N 3570.88 w 0.00 5980037.00 N 266988.00 E B 55.10 8551.45 N 2206.92 W 0.00 5979593.00 N 268339.00 E C 55.10 8953.89 N 3570.88 W 0.00 5980037.00 N 266988.00 E DrllIOuest 3.03.02.002 Sperry-Sun Drilling Services Alaska State Plane 3 BPXA 3-25B/L-27 WP22 - Revised: 21 January, 2003 Proposal Report 21 January~ 2003 Surface Coordinates: 5970978.01 N, 270283.14 E (70" 19' 20.4002- N, 147" 51' 45.8097n W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 3 Kelly Bushing: 55. 10ft above Mean Sea Level '-' .-. - -- --..., 1_" ....... ,..-J ::I" II! DRILLING SERVICES A Halliburton Company Proposal Ref: pro996 Sperry-Sun Drilling Services Proposal Report for 3-25B/L-27 WP22 Revised: 21 January, 2003 BPXA Alaska SIBte Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11350.00 48.067 345.801 8269.06 8324.16 6360.99 N 2703.39 W 5977418.76 N 267775.72 E 6885.05 Sidetrack Point TF RT 34.80° 12.000°/1000: 11350.00ft MD, 8324.16ft TVD 11370.00 50.052 347.587 8282.16 8337.26 6375.69 N 2706.86 W 5977433.57 N 267772.70 E 12.000 6900.11 Decrease Dir Rate @ 5.oooo/100ft: 11370.00ftMD,8337.26ftTVr 11400.00 51.289 348.684 8301.17 8356.27 6398.40 N 2711.63 W 5977456.41 N 267768.63 E 5.000 6923.18 ~_/ 11410.00 51.703 349.041 8307.40 8362.50 6406.08 N 2713.14 W 5977464.13 N 267767.35 E 5.000 6930.95 11500.00 55.437 352.165 8360.85 8415.95 6477.50 N 2724.91 W 5977535.88 N 267757.77 E 5.000 7002.51 11600.00 59.669 355.321 8414.49 8469.59 6561.35 N 2734.05 W 5977619.97 N 267751.20 E 5.000 7085.09 11700.00 63.972 358.212 8461.71 8516.81 6649.33 N 2738.98 W 5977708.06 N 267748.97 E 5.000 7170.28 11710.61 64.432 358.506 8466.33 8521.43 6658.88 N 2739.25 W 5977717.61 N 267748.99 E 5.000 7179.44 End Dir, Start Sail @ 64.432° : 11710.61 ftMD,8521.43ftTVD 11800.00 64.432 358.506 8504.91 8560.01 6739.49 N 2741.35 W 5977798.25 N 267749.36 E 0.000 7256.76 11900.00 64.432 358.506 8548.07 8603.17 6829.66 N 2743.70 W 5977888.45 N 267749.77 E 0.000 7343.25 12000.00 64.432 358.506 8591.23 8646.33 6919.84 N 2746.05 W 5977978.66 N 267750.18 E 0.000 7429.74 12100.00 64.432 358.506 8634.39 8689.49 7010.02 N 2748.41 W 5978068.87 N 267750.59 E 0.000 7516.22 12200.00 64 .432 358.506 8677.55 8732.65 7100.19N 2750.76 W 5978159.07 N 267751.00 E 0.000 7602.71 12300.00 64.432 358.506 8720.71 8775.81 7190.37 N 2753.11 W 5978249.28 N 267751.41 E 0.000 7689.20 12355.08 64.432 358.506 8744.48 8799.58 7240.04 N 2754.40 W 5978298.96 N 267751.63 E 0.000 7736.84 Begin Dir @ 5.000°/1000: 12355.0 MD, 8799.58ft TVD 12400.00 62.192 358.700 8764.65 8819.75 7280.16 N 2755.38 W 5978339.09 N 267751.88 E 5.000 7775.30 12500.00 57.208 359.163 8815.09 8870.19 7366.45 N 2757.00 W 5978425.40 N 267752.91 E 5.000 7857.87 12600.00 52.226 359.681 8872.83 8927.93 7448.05 N 2757.84 W 5978506.99 N 267754.57 E 5.000 7935.74 12700.00 47.247 0.273 8937.44 8992.54 7524.34 N 2757.88 W 5978583.24 N 267756.86 E 5.000 8008.30 -- 12734.02 45.553 0.497 8960.90 9016.00 7548.97 N 2757.72 W 5978607.85 N 267757.78 E 5.000 8031.68 End Dir, Start Sail @ 45.553° : 12734.02ftMD,9016.0OOTVD 12734.16 45.553 0.497 8961.00 9016.10 7549.07 N 2757.72 W 5978607.96 N 267757.78 E 0.000 8031.78 Tuff Marker 12800.00 45.553 0.497 9007.11 9062.21 7596.07 N 2757.31 W 5978654.92 N 267759.63 E 0.000 8076.35 12900.00 45.553 0.497 9077.13 9132.23 7667.46 N 2756.69 W 5978726.26 N 267762.43 E 0.000 8144.05 13000.00 45.553 0.497 9147.15 9202.25 7738.85 N 2756.07 W 5978797.59 N 267765.24 E 0.000 8211.76 13100.00 45.553 0.497 9217.18 9272.28 7810.24 N 2755.45 W 5978868.93 N 267768.04 E 0.000 8279.46 13139.59 45.553 0.497 9244.90 9300.00 7838.50 N 2755.21 W 5978897.17 N 267769.15 E 0.000 8306.26 Begin Dir @ 4.000°/1000: 13139.5 MD, 9300.00ft TVD 13200.00 43.137 0.497 9288.10 9343.20 7880.72 N 2754.84 W 5978939.36 N 267770.81 E 4.000 8346.30 13300.00 39.137 0.497 9363.40 9418.50 7946.49 N 2754.27 W 5979005.08 N 267773.39 E 4.000 8408.68 13400.00 35.137 0.497 9443.10 9498.20 8006.85 N 2753.75 W 5979065.40 N 267775.76 E 4.000 8465.92 13425.40 34.121 0.497 9464.00 9519.10 8021.28 N 2753.62 W 5979079.82 N 267776.33 E 4.000 8479.61 Top HRZ 21 January, 2003 -14:48 Page2of9 DrillQuest 3.03.02.002 DrillQuest 3.03.02.002 Page 30f9 21 January, 2003 - 14:48 Based upon Minimum Curvature type calculations, at a Measured Depth of 14354.49ft., The Bottom Hole Displacement is 8899.70ft., in the Direction of 342.003° (True). Sperry-Sun Drilling Services Proposal Report for 3-25B/L-27 WP22 Revised: 21 January, 2003 BPXA Alaska State Plane 3 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 13500.00 31.137 0.500 9526.82 9581.92 8061.50 N 2753.27 W 5979120.01 N 267777 .91 E 4.000 8517.75 13579.71 27.949 0.503 9596.15 9651.25 8100.79 N 2752.93 W 5979159.27 N 267779.46 E 4.000 8555.01 End Dir, Start Sail @ 28.000° : 13579.71ftMD,9651.26ftTVD 13600.00 27.949 0.503 9614.08 9669.18 8110.31 N 2752.84 W 5979168.78 N 267779.83 E 0.000 -8564.03 13700.00 27.949 0.503 9702.42 9757.52 8157.17 N 2752.43 W 5979215.61 N 267781.68 E 0.000 8608.48 13745.94 27.949 0.503 9743.00 9798.10 8178.70 N 2752.24 W 5979237.12 N 267782.52 E 0.000 8628.90 Base HAZ ~- 13765.19 27.949 0.503 9760.01 9815.11 8187.72 N 2752.16 W 5979246.14 N 267782.88 E 0.000 8637.45 LCU 1 K3A 1 P3 Coals. 13800.00 27.949 0.503 9790.76 9845.86 8204.04 N 2752.02 W 5979262.44 N 267783.52 E 0.000 8652.93 13900.00 27.949 0.503 9879.09 9934.19 8250.90 N 2751.61 W 5979309.27 N 267785.37 E 0.000 8697.37 13908.95 27.949 0.503 9887.00 9942.10 8255.10 N 2751.57 W 5979313.46 N 267785.53 E 0.000 8701.35 K2B 13973.48 27.949 0.503 9944.00 9999.10 8285.34 N 2751.31 W 5979343.68 N 267786.73 E 0.000 8730.03 K2M 14000.00 27.949 0.503 9967.43 10022.53 8297.77 N 2751.20 W 5979356.10 N 267787.21 E 0.000 8741.82 14030.08 27.949 0.503 9994.00 10049.10 8311.87 N 2751.07 W 5979370.19 N 267787.77 E 0.000 8755.18 Top K2A / S2A3 Target - 3-25BIL-27 T1, 130.00 AOO 14100.00 27.988 0.506 10055.75 10110.85 8344.66 N 2750.78 W 5979402.96 N 267789.06 E 0.000 8786.28 14131.98 28.005 0.508 10083.99 10139.09 8359.67 N 2750.65 W 5979417.96 N 267789.65 E 0.000 8800.52 S2A2 Shale 14136.52 28.008 0.508 10088.00 10143.10 8361.80 N 2750.63 W 5979420.09 N 267789.74 E 0.000 8802.54 S2A1 14200.00 28.043 0.510 10144.04 10199.14 8391.63 N 2750.37 W 5979449.89 N 267790.92 E 0.000 8830.82 14204.49 28.046 0.510 10148.00 10203.10 8393.74 N 2750.35 W 5979452.00 N 267791.00 E 0.000 8832.82 K1 Target - 3-25BIL-27 T2 GeopoIy 14300.00 28.046 0.510 10232.29 10287.39 8438.64 N 2749.95 W 5979496.87 N 267792.77 E 0.000 8875.41 14354.49 28.046 0.510 10280.39 10335.49 8464.26 N 2749.72 W 5979522.47 N 267793.79 E 0.000 8899.70 Total Depth : 14354.49ftMD,10335.49ftTV' 41/2- Liner --" All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 3. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 342.000° (True). WEUPATIf DtTAILS PIm 3-25M..-21 3-25IM-21 113SO.00 . 29:25 lI6/I991 ooœ 55.101\ ~ ~ ~~ 0.00 0.00 0.00 ~:;,~~ Rig: Ref. DoIum: V.Seewn Angle 34200' Tool MWD SURVEY PROGRAM DepIh Fro Deplh To Sm-.yJPm 113SO.00 14354.62 Pbm>ed: 3-25M..-21 "1'22 V16 COMPANYDtTAILS BP AImeo CakuJalDn Method: Mm:œm c""..ture Error S}'st<m: ISCWSA Scæl Method: Tm' Cyli>der Nor1h Error Snrface: ~traI + Casilg Wanmg Method: Rules Based wp22 ANTI-COLUSION SETTINGS Interval: 50.00 To: 14354.62 Reference: Plan: 3-25BlL-27 Interpolation MethodMD Depth Range From: 11350.00 Maximum Range: 1631.40 SI:>I NIA LongWde 141·51'45.8IOW \ßiIude 7(}-19'20.4OON WELL DhT AILS Nor1Img Ea>oo8 5970'J78.0l 270283. +fJ·W ·1998.01 +NI-S 1595 ame ·251M- IHìF1ID - 1-21/K-25 {PIm 1-2IWN-24 Hjgb KOP). Major Risl ,.~ 1-2WM-25(I-2WM-25).MajorRisk - ~\JN-29 (~\JN-29), Mapr Risk - 3-01IN-28 (3-01IN-28), Mapr Risk ~ 3-01A1L-29 (3-mM.-29). Major Risk - 3--QM.-28 (3--O'NL-28). to. Risk - 3-25IM-21 (3-2W-21). NOFRRORS - 3-25IM-21 (3-25M'BI). NOERRORS = ~is(=~t~t:::k - 4-100.1-28 (PIm 4-1OM..-28). Major Risk - PIm 3-25M..-21 - 3-25&1...21 "1'22 ./ - Plan; 3-25BIL-21 "1'22 (3-2SlM-21n>1ao 3-25_~- <:railed By: BGoff Dale: 0112\12003 CbecUd: DaIt: R...iewcd: Dale: Appro"ed: DaIt: ToM 1135! 1150! 1175! 12OO! 1225! 1250! I 275! 1300! 1325! 1350! 1375! 1400! 1425( 1450! 1475( Colour 90 1 From Colour ToMD o ~. 11350 11350 - 11500 11500 ~ 11750 11750 -~ 12000 12000 - 12250 12250 - 12500 12500 ~ 12750 12750 - 13000 13000 - 13250 13250 - 13500 13500 - l3750 13750 - 14000 14000 - l4250 14250 - 14500 14500 - l4750 -20.0 -15.0 -10.0 -5.0 90 -om~ -5.0 -10.0 -15.0 -20.0 27() -182 -175 -ISO -100 -125 -100 -ISO -125 -175 -182 --so --so -75 -25 -25 -75 -0 vSee Tmget 6885.08 6/JOO.13 fR3iJ!n 1119.41 7136.F:1 8031.81 8306.23 8419.53 8554.29 8833.19 1.-21 KI 8899.97 TFace 0.00 34.110 34.81 34.89 0.00 115.62 0.00 181.00 180.00 0.00 0.00 Centre to Centre Separation [15ft/in] SæTION DETAILS +NI-S +E'-W DLeg 636\.00 -2103.52 0.000 6315.10 -2101.00 12000 6406.09 -2113.28 5.000 6658.89 -2139.38 5.000 1240.1» -2154.54 0.000 1549.08 -2151.84 5.000 1838.44 -2155.32 0.000 8021.18 -2153.12 4.000 8100.00 -2153.1» 4.000 8394.08 -21SO.47 0.000 8464.50 -2149.86 0.000 A:ri TVD 345.80 8324.16 341.59 8337.26 349.1» 8362.SO 358.51 852\.43 358.51 8199.58 O.SO 9016.10 0.50 9300.00 O.SO 9519.10 0.50 9650.00 O.SO 10203.10 0.50 10335.54 MD Inc 113SO.00 48.01 11310.00 SO.05 11410.00 51.70 11110.61 64.043 12355.08 6M3 12134.16 45.55 13139.54 45.ss 13425.32 34.12 13518.20 28.00 14204.62 28.00 14354.62 28.00 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs See I ? 3 4 5 6 1 8 9 10 11 Centre to Centre Separation [75ftlin] [deg] Travelling Cylinder Azimuth (TFO+AZI) ) Company: Field: Refere.n.c.e Site: Reference Well: Referen.ce 'Wellpath:· BPAmoco Endicott ehcls[)1 3~25/M-27 Plan 3-25B/L-27 \ ;~ ) .,~ Sper~y-Sun Anticollision Report Dåte: 0112112003 Time:. . .14;46:18 Page: 1 Co';ol"dinåte(NE) Referel1l.:e: W ell:3'-25/M-27 ,True North yertical(TVD) Reference: 29: 251/6/199100:0055.1 Db. Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are ~JBBIls in this fEtmcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval. 50.00 ft Error Model. ISCWSA Ellipse Depth Range: 11350.00 to 14354.62 ft Scan Method. Trav Cylinder North Maximum Radius. 1631.40 ft Error Suñace: Ellipse + Casing Survey Program for Definitive Wellpath Date: 05/13/2002 Validated. No Planned From To Survey ft ft 52.65 11350.00 11350.00 14354.62 Casing Points Version. 6 Toolcode Tool Name 1 : Schlumberger GCT multishot Planned: 3-25B/L-27 wp22 V16 GCT -MS MWD Schlumberger GCT multishot MW D - Standard 4.500 1-21/K-25 1-29/M-25 3-01/N-29 3-07/N-28 3-07A/L-29 3-09/L-28 3-25/M-27 3-25/M-27 4-08/P-27 4-10/M-28 4-10/M-28 8.500 41/2" Summary <-.....-.;.-------;.-..;.;.~- ()rrset Wellpath >--;.--...-..;.----~.......-...> Site Well Wellpath Plan 1-21a/N-24 High K 1-29/M-25 V1 3-01/N-29 V1 3-07/N-28 V1 3-07A/L-29 V5 3-09/L-28 V1 3-25/M-27 V1 3-25A/PB1 V1 4-08/P-27 V1 4-10/M-28 V1 Plan 4-10A/L-28 V14 PI Reference Offset Ctr~ëtl" .No~GÒ AlloWable MD MD Distance. Area Deviation Warning . .. ft ft ft ft .~ 14352.37 14800.00 1549.70 356.84 1215.67 Pass: Major Risk 14327.75 14250.89 1470.82 366.87 1115.67 Pass: Major Risk Out of range 11359.80 11950.00 1454.99 330.86 1227.82 Pass: Major Risk 13138.66 14300.00 1423.56 360.42 1142.53 Pass: Major Risk 14056.03 14900.00 785.76 402.75 382.95 Pass: Major Risk 11350.00 11350.00 0.00 0.00 0.00 FAIL: NOERRORS 11350.00 11350.00 0.00 0.00 0.00 FAIL: NOERRORS 11358.38 12150.00 1614.10 333.66 1325.56 Pass: Major Risk 13972.43 13850.00 1097.84 386.26 718.63 Pass: Major Risk 14117.71 13846.97 1065.16 357.28 773.76 Pass: Major Risk 14335.53 10318.69 ) End MPI End MPI End SDI End SOl End SOl End SOl End SOl End SOl End SOl End SOl End SDI Site. End MPI Well. 1-21/K-25 Well path. Plan 1-21a/N-24 High KOP VO Plan: 1-21a/N-24 wp01 Reference Offset Selßi·Major Axis MD TVD MD TVD Ref Offset TFO+AZI·TFO·HS Casing ft ft ft ft ft ft deg deg in 14337.09 10320.06 14600.00 10106.66 57.98 50.75 286.74 286.24 8.500 14340.42 10323.00 14650.00 10132.70 57.99 50.97 285.13 284.63 8.500 14344.08 10326.23 14700.00 10159.03 58.01 51.19 283.49 282.99 8.500 14348.06 10329.75 14750.00 10185.63 58.02 51.42 281.80 281.30 8.500 14352.37 10333.56 14800.00 10212.50 58.03 51.66 280.08 279.58 8.500 Rule Assigned. Inter-Site Error. Ctr-Ctr . · · No-Go Distance . Area ft ft 1625.64 352.52 1604.62 353.58 1584.92 354.66 1566.60 355.74 1549.70 356.84 Major Risk 0.00 ft Allowable Deviation ft 1304.43 Pass 1280.29 Pass 1257.42 Pass 1235.85 Pass 1215.67 Pass Site: End MPI Well. 1-29/M-25 Rule Assigned. Major Risk Wellpath. 1-29/M-25 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 13930.43 9961.00 13600.00 10018.20 56.79 56.65 266.21 265.71 7.000 1630.48 355.79 1320.34 Pass 13958.21 9985.53 13650.00 10059.27 56.87 56.87 264.91 264.41 7.000 1611.54 356.62 1297.61 Pass 13986.27 10010.30 13700.00 10100.51 56.94 57.08 263.57 263.07 7.000 1593.53 357.45 1275.82 Pass 14014.73 10035.44 13750.00 10142.00 57.03 57.29 262.22 261.72 7.000 1576.51 358.33 1254.99 Pass 14043.60 10060.93 13800.00 10183.70 57.11 57.50 260.85 260.35 7.000 1560.37 359.16 1235.12 Pass 14072.96 10086.85 13850.00 10225.66 57.19 57.71 259.47 258.97 7.000 1545.15 359.98 1216.26 Pass 14102.88 10113.27 13900.00 10267.97 57.28 57.92 258.07 257.57 7.000 1531.05 360.85 1198.51 Pass 14133.39 10140.21 13950.00 10310.66 57.37 58.13 256.66 256.16 7.000 1518.17 361.68 1182.13 Pass ,) 14164.77 10167.91 14000.00 10353.98 57.46 58.33 255.25 254.75 7.000 1506.97 362.49 1167.53 Pass 14197.01 10196.38 14050.00 10397.97 57.56 58.52 253.84 253.34 7.000 1497.62 363.30 1154.90 Pass P054996 DATE 12/19/2002 INV# CK121702E INVOICE I CREDIT MEMO 3-lS5\L-Z7 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE; BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY: TO THE ORDER OF: DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ DATE CHECK NO. 12/19/2002 P054996 GROSS VENDOR DISCOUNT NET H -' 56-389 4i2 No.···P 054996 NATIONAL CITY BANK Ashland; Ohio ".-.' ,:...-- .--=.';. .." '.' -."' - '. -. -. -.-'-." . '--' . .-' -.-"- - - - -.... . . " - __ n_,"__ _'," _ ._...'. .._ '. _ _ _ n.... . ALASKA OIL & GAS CONSERVATION C~rvfMIS$ION«·· 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK99501 CONSOLIDATED COMMERCIAL ACCOUNT .-- .'- "..-... - .- .. ~ . - . ',',', - - B. ..... ..............p f~·~m .;1"].. êtt~(::fit)1 çi!: ",_..- ~__:__-:;-:\. _..-;~_lf~. _ _...... tft1l .::,- .'-,urn ::. _:~::!IJ.Jt. _ti~_r) . . DATE) n. _ _ -:..."."'. ',. ******~~*'1'~****$1 00.00*** AMoUNT Deçêmbêr~ 9,.2002 n_ _. 'd. .'. _ .'.' . ...d. . _. --.,. ". .. .". .",','. - .. '-- ,"....,. " - " - .n ,..__ ".-..-u, - _n_ ..... ..- - -....... .... .".--.. . -- - - "- -".. '~ Nf~ti~~:f~·~:~;i5J~;~.:~~~t~:;i·~.~/~é~· '. ':.:'::~~~:\"~'""'~~_~'''''''':''h.''''''' . .. ~·/,~¡>~)~:.t~{~~~;~1f~i.~;;;~;~ma -"~~ 1110 5 ... 9 9 b III I: 0 L. ¡. 20 j 8 9 5 I: 0 ¡.. 2 ? a 9 b liD TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number 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. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 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. (Company 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. WELLPERMITCHECKLIST COMPANY ß¡I)( WELLNAMEP/u i'-.zSðÞ27PROGRAM:EXP_ Dev~ Redrll~ Re-Enter_ Serv_ Wellboreseg_ _ FIELD & POOL 2:¿d'/~ INITCLASS LJro-,)~ /-'ð') GEOLAREA 91'n - UNIT# /dC;T5ò ON/OFFSHORE.cd'f ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . f{J>.. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y I N 5. Well located proper distance from drilling unit boundary. ... . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ~¿.Þ 1/1, ~ 2 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N /.¥.L fLJ-I.Lct../ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ ~y r-J. 1'1, (Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . ., k ~ ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 'ÍÝ\ N 16. Surface casing protects all known USDWs. . . . . . . (Y N 17. CMT vol adequate to circulate on conductor & surf csg. . . . -v---N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -\f-N- 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N 20. Casing designs adequate for C, T, B& permafrost. . . . . . . N D 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . . N ~ If'I'-- ,ç: 22. If a re-drill, has a 10-403 fo~ abandonment been approved. . . N ¡ II 'l!z--I 0 z- 23. Ad~quate well~ore separ.~tlon propos~.. .'.' . . . . . . .~ . . . N lit- 24. If dlverter required, does It meet regulations. .. . . . . ... . "', .. 25. Drilling fluid program schematic & equip list adequate. . . . . . N Ih~./~ n1 bJ /0 I 5 p [J'i 26. BOPEs, do they meet regulation. . . . . . ,'I' . . . . . . . . _ N, r' 7, ~ E," f1 ~7.' BOPE press rating appropriate; test to 'TSOO psig. N ¡7Ij,~ r ~C; V'S P ~v ' 28. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N '30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N" (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . ¥--N"' ¡J/It- GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . . . . Y (Ñ) APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . J{Y N N,(' ¡q, ÆO" LJ~Æ. 3 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . v N . ¡r£ (, 7~ V' 35. Seabed condition survey (if.off-shore). . ~ . . .. ...... I- I (Explor 0 Only) 36. Contact namelphone for weekly progress reports. ...... .. N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE APPR DATE V-K* l-{ "103 UIC ENGINEER TEM JDH JBR Rev: 10/15/02 SFD_ WGA ..,/' MJW G:\geology\perm its\checklist.doc COMMISSIONER: COT ¡' DTS o2jO~ q) MLB O::l../o.r/o3 { (, Commentsllnstructions: ) ) Welll-iistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sin1'plify finding infonnation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) I 803 -ðåL \ $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 24 15:44:19 2003 I} fÒI Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/11/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/11/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Endicott SDI MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3-25B/L-27 Reprocess 500292212502 BP Exploration (Alaska) Inc. Sperry Sun 24-NOV-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002377690 P. ORTH C. GALLOWAY MWD RUN 3 MW0002377690 B. HENNINGSE C. GALLOWAY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 11N 17E 2519 759 MSL 0) .00 54.07 15.28 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 11320.0 8.500 9.625 11320.0 # REMARKS: 1. THIS FILE SUPERCEDES ALL PREVIOUS VERSIONS/CORRECTIONS, IS DATED 11/17/03, AND CONTAINS COMPENSATED THERMAL NEUTRON LWD DATA THAT IS REPROCESSED WITH UPDATED ALGORITHMS. RECEIVED 2. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. DEC 08 2003 Alaska Oil & Gas Cons. LOmmission Anchorage ~~ ('\"\. ~ ) ') THESE DEPTHS ARE MEASURED DEPTH (MD). 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND TO MILL THE WINDOW. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 6. MWD RUN 3 COMPRISED DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 7. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 29 APRIL 2003, PER E-MAIL INSTRUCTIONS FROM D. SCHNORR DATED 30 MAY 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 8. MWD RUNS 1 - 3 REPRESENT WELL 3-25B/L-27 WITH API#: 50-029-22125-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14350'MD/10359'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL- DERIVED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . ACAL = SMOOTHED ACOUSTIC CALIPER. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.5" BIT) MUD WEIGHT: 10.3 - 10.4 PPG MUD FILTRATE SALINITY: 1500 - 1800 PPM CHLORIDES FORMATION WATER SALINITY: 16800 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/11/24 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.OOO GR 11304.5 11311.0 11340.5 11366.5 11375.0 11377.0 11391.5 11394.5 11412.5 11492.5 11523.5 11533.0 11634.0 11646.5 11737.0 11931.0 11949.0 11988.0 12106.5 12131. 0 12157.0 12200.5 12209.0 12219.5 12254.5 12276.5 12415.5 12454.0 12470.5 12559.5 12563.0 12583.5 12616.0 12630.5 12633.0 12642.0 12662.5 12665.0 12677.0 12682.0 12699.0 12712.5 12716.5 12730.0 12738.5 12742.5 12749.5 BASELINE DEPTH 11301.0 11309.5 11340.5 11368.5 11377.5 11380.0 11393.0 11396.0 11415.0 11494.0 11526.0 11537.0 11642.5 11654.5 11742.0 11931.0 11948.5 11983.5 12109.5 12130.0 12157.0 12202.0 12211.0 12221. 0 12254.5 12278.5 12420.5 12458.0 12474.0 12566.0 12568.5 12588.5 12621.0 12635.0 12638.0 12647.0 12666.5 12669.0 12682.0 12686.0 12703.0 12718.0 12721.0 12732.5 12743.0 12746.0 12753.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- STOP DEPTH 14322.0 14355.0 14270.5 14270.5 14270.5 14272.5 14283.5 14283.5 14283.5 14314.5 14314.5 14314.5 14314.5 14314.5 START DEPTH 11292.0 11319.0 13541.5 13541.5 13541.5 13545.0 13555.5 13555.5 13555.5 13587.5 13587.5 13587.5 13587.5 13587.5 clipped curves; all bit runs merged. .5000 ) ) 1 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT NPHI CALA PEF DRHO RHOB FET RPD RPM RPS RPX $ ) ) 12756.5 12752.0 12762.5 12759.0 12765.0 12760.5 12768.0 12763.5 12777.0 12774.0 12780.0 12776.5 12787.0 12783.0 12809.0 12804.0 12821. 5 12816.5 12832.5 12827.5 12843.0 12837.5 12858.0 12853.5 12878.0 12875.0 12909.0 12904.5 12913.5 12909.0 12921.5 12916.0 12928.0 12922.5 12950.0 12944.0 12958.0 12953.0 12972.5 12968.0 12979.0 12972.0 12989.5 12983.0 12993.5 12985.5 13016.0 13010.0 13020.0 13012.5 13027.0 13020.5 13038.5 13032.0 13047.0 13040.0 13051.5 13044.0 13077.0 13071.5 13082.0 13077 . 5 13096.5 13092.0 13108.0 13101.0 13113.5 13106.0 13184.5 13178.0 13191.0 13185.5 13206.5 13201.5 13236.5 13230.5 13239.5 13234.5 13282.0 13278.5 13295.0 13290.0 13324.5 13319.5 13327.0 13322.0 13329.0 13325.0 13382.5 13379.5 13414.0 13409.0 13416.0 13410.5 13424.0 13418.5 13431.5 13427.0 13442.0 13437.0 13453.0 13448.5 13461.0 13457.5 13470.0 13465.5 13481.5 13476.5 13490.0 13485.0 13492.5 13488.5 13499.0 13495.5 13503.0 13497.5 13506.5 13502.5 13520.5 13515.5 13530.5 13526.0 13541.0 13537.0 13548.0 13543.0 13551.5 13547.5 13563.0 13557.5 13589.5 13584.0 13593.0 13588.0 13599.5 13595.5 13603.5 13599.0 13609.0 13605.5 13617.0 13613.0 13620.5 13616.0 13633.0 13630.5 13645.5 13641.5 13662.5 13658.5 13667.5 13663.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ .Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined MERGED MAIN PASS. $ # REMARKS: MERGE BASE 13625.0 14350.0 MERGE TOP 11295.5 13625.0 BIT RUN NO 2 3 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ 13677.0 13682.0 13689.0 13694.5 13729.0 13735.5 13739.0 13746.5 13749.0 13757.5 13765.0 13770.5 13789.0 13791.5 13794.0 13797.5 13829.5 13834.5 13841. 5 13846.5 13856.5 13899.5 13917.0 13922.0 13935.5 13973.5 13977.0 13984.5 13986.5 13987.5 13989.5 13991.5 13995.5 13999.0 14011.0 14014.5 14022.0 14026.5 14054.0 14058.5 14062.0 14072.5 14078.5 14082.5 14088.5 14109.0 14139.5 14142.5 14145.5 14154.5 14174.5 14208.5 14215.0 14217.5 14224.0 14231. 5 14238.0 13680.0 13686.0 13692.0 13699.0 13733.0 13740.0 13744.0 13751.0 13753.5 13761.5 13768.0 13775.0 13793.5 13795.5 13798.5 13802.5 13833.5 13838.0 13844.0 13851. 0 13860.5 13904.5 13922.5 13927.0 13940.0 13979.5 13982.5 13990.5 13992.0 13993.5 13996.0 13997.5 14001. 5 14005.0 14017.0 14021. 0 14028.5 14032.5 14060.5 14065.0 14069.0 14079.0 14085.0 14088.5 14095.0 14116.0 14146.0 14149.5 14152.5 14161.0 14181.0 14216.5 14221. 0 14224.0 14229.5 14238.0 14246.0 $ ) ) ) ) Absent value..................... .-999.25 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CTS/ 4 1 68 36 10 NCNT MWD CTS/ 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 APPC MWD IN 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11292 14355 12823.5 6127 11292 14355 ROP MWD FT/H 0.04 711.69 67.4508 6073 11319 14355 GR MWD API 12.47 397.92 115.626 6061 11292 14322 RPX MWD OHMM 1. 21 2000 349.321 1455 13587.5 14314.5 RPS MWD OHMM 1.19 2000 387.94 1455 13587.5 14314.5 RPM MWD OHMM 1.13 2000 440.002 1455 13587.5 14314.5 RPD MWD OHMM 1. 21 2000 615.134 1455 13587.5 14314.5 FET MWD HOUR 0.47 38.5 3.60142 1455 13587.5 14314.5 NPHI MWD PU-S 1. 41 72.07 25.5178 1459 13541.5 14270.5 FCNT MWD CTS/ 536 28011 1949.68 1459 13541.5 14270.5 NCNT MWD CTS/ 112152 428828 162416 1459 13541.5 14270.5 RHOB MWD G/CM 1.223 3.021 2.24306 1457 13555.5 14283.5 DRHO MWD G/CM -0.154 0.429 0.00363624 1457 13555.5 14283.5 PEF MWD BARN 0.84 9.24 2.71764 1457 13555.5 14283.5 APPC MWD IN 8.3968 12.5943 8.95486 1456 13545 14272.5 First Reading For Entire File......... .11292 Last Reading For Entire File.......... .14355 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/11/24 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/11/24 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 2 header data for each bit run in separate files. 2 .5000 ) FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 11295.5 11351.5 STOP DEPTH 13570.0 13625.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value................... ...-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 16-APR-03 Insite 66.37 Memory 13625.0 11351.0 13625.0 31. 0 59.4 TOOL NUMBER 69706 8.500 11320.0 GEM 9.70 43.0 9.0 2800 4.0 .000 .000 .000 .000 Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 6 8 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H Min 11295.5 0.04 Max 13 62 5 711.69 Mean 12460.3 70.2664 Nsam 4660 4548 ') .0 147.0 .0 .0 First Reading 11295.5 11351. 5 Last Reading 13 62 5 13625 ) ) GR MWD020 API 42.16 308.06 126.83 4550 11295.5 13570 First Reading For Entire File..... .... .11295.5 Last Reading For Entire File...... .... .13625 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/11/24 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/11/24 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log B IT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI CALA PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 13537.5 13537.5 13537.5 13540.5 13551. 0 13551. 0 13551. 0 13570.5 13582.0 13582.0 13582.0 13582.0 13582.0 13625.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ STOP DEPTH 14262.5 14262.5 14262.5 14264.5 14275.5 14275.5 14275.5 14314.0 14306.5 14306.5 14306.5 14306.5 14306.5 14350.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON 18-APR-03 Insite 66.37 Memory 14350.0 13625.0 14350.0 25.1 28.1 TOOL NUMBER 136692 102982 161646 174114 ) ) # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 11320.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: GEM 10.30 47.0 9.0 1800 2.7 1.120 .488 .900 2.050 76.0 183.2 76.0 76.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CTsl 4 1 68 36 10 NCNT MWD030 CTSI 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 APPC MWD030 IN 4 1 68 56 15 First· Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13537.5 14350 13943.8 1626 13537.5 14350 ROP MWD030 FT/H 0.18 251.1 61.6156 1450 13625.5 14350 GR MWD030 API 12.47 397.92 81.9378 1488 13570.5 14314 RPX MWD030 OHMM 1. 21 2000 349.3 1450 13582 14306.5 RPS MWD030 OHMM 1.19 2000 387.37 1450 13582 14306.5 RPM MWD030 OHMM 1.13 2000 438.588 1450 13582 14306.5 RPD MWD030 OHMM 1. 21 2000 612.966 1450 13582 14306.5 FET MWD030 HOUR 0.47 38.5 3.73477 1450 13582 14306.5 NPHI MWD030 Pu-s 1. 41 72.07 25.4656 1451 13537.5 14262.5 FCNT MWD030 CTSI 536 28011 1948.88 1451 13537.5 14262.5 NCNT MWD030 CTSI 112152 428828 162416 1451 13537.5 14262.5 RHOB MWD030 G/CM 1. 223 3.021 2.24518 1450 13551 14275.5 DRHO MWD030 G/CM -0.154 0.429 0.0042 1450 13551 14275.5 PEF MWD030 BARN 0.84 9.24 2.72729 1450 13551 14275.5 ') ) APPC MWD030 IN 8.3968 12.5943 8.95657 1449 13540.5 14264.5 First Reading For Entire File......... .13537.5 Last Reading For Entire File.......... .14350 File Trailer Service name........ .... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/11/24 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/11/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/11/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name....... ... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File