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Home My WebLink About203-006Nolan 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: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date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y Samantha Carlisle at 1:59 pm, Nov 30, 2021 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU SFD 12/3/2021MGR31DEC2021 RBDMS HEW 11/30/2021 DSR-11/30/21 tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϮͲϮϴ ^ůŝĐŬůŝŶĞ ϱϬͲϬϮϵͲϮϭϴϰϳͲϬϮͲϬϬ ϮϬϯͲϬϬϲ ϭϭͬϭϳͬϮϬϮϭ ϭϭͬϭϳͬϮϬϮϭ ϭϭͬϭϵͬϮϬϮϭͲ&ƌŝĚĂǇ t>>&>Kt/E'KEZZ/s>͘WdϮϱϬ>ͬϮϱϬϬ,͘Wh>>ϰͲϭͬϮ;ƐŶ͗,ϰͲϮϴͿ&ZKD^s>EΛϭϱϮϱΖD͘t>>^/KE WZdhZ͘ ϭϭͬϭϳͬϮϬϮϭͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ ^dϰͲϭͬϮΗ<Z/WdϭϬ͕ϲϵϬΖD͘^dϰͲϭͬϮΗ;ƐĞƌŝĂůηͲ,ϰͲϮϴͿ/E^s>Edϭ͕ϱϮϱΖD͘WZ&KZD^h^^&h> ZtKtEd^dt/d,WKW͘>dh/E'&ZKDϮϮϬϬͲϭϴϬϬƉƐŝ͘t>>^,hdͲ/EKEWZdhZ͕EKd/&/WKW͘ ϭϭͬϭϴͬϮϬϮϭͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ 0DUNHU-RLQW '20( -&0*/9&KDQJHRXW-&0*/9&KDQJHRXW 2 7')3XOO6WUDGGOH3DFNHUZ&RLO7')3XOO6WUDGGOH3DFNHUZ&RLO %DNHU&,%3VHW# 0' &ORVHG 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: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL END MPI 2-28B (PTD 203-006) GASSAT AND TMD3D 10/16/2020 Please include current contact information if different from above. Received by the AOGCC 12/22/2020 PTD: 2030060 E-Set: 34437 Abby Bell 12/23/2020 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Remove Straddle Packer w/ Coil Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,058 feet N/A feet true vertical 10,373 feet N/A feet Effective Depth measured 10,967 feet 8,152 feet true vertical 10,300 feet 8,130 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / 13Cr80 8,170' 8,148' 1,525' MD Packers and SSSV (type, measured and true vertical depth)9-5/8" x 4-1/2" S-3 4-1/2" HES HXO SSSV See Above 1,525' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 2,260psi 4,760psi 7,500psi Burst N/A 5,020psi 6,870psi 8,430psi 30" 13-3/8" 9-5/8" 4-1/2" 2,503' 8,259' 10,373' Length 131' 2,504' 8,284' Surface Intermediate N/A measured 2,907' N/A Production Casing Conductor Size 1,800 DUCK IS UNIT MPI 2-28B 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 404 Gas-Mcf 1,750 Casing Pressure Tubing Pressure 11,809 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 530 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-006 50-029-21847-02-00 Plugs ADL0034633 5. Permit to Drill Number: ENDICOTT / ENDICOTT OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 115 Representative Daily Average Production or Injection Data 3117,935 12,348 Oil-Bbl measured true vertical Packer 11,058' WINJ WAG 392 Water-Bbl MD 131' 2,504' 8,284' TVD 131' OO PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:27 pm, Aug 04, 2020 Chad A Helgeson 2020.08.04 13:27:39 -05'00' SFD 8/4/2020 RBDMS HEW 8/4/2020 DSR-8/4/21 4-1/2" Marker Joint DOME 16 10/7/16 10/7/16 10/7/1632 10/12/17 JCM GLV Change out10/12/17 JCM GLV Change out 10650 - 10655 O 7/15/2020 TDF Pull Straddle Packer w/ Coil7/15/2020 TDF Pull Straddle Packer w/ Coil Well Name Rig API Number Well Permit Number Start Date End Date END 2-28B CTU 50-029-21847-02-00 203-006 4/18/2020 7/15/2020 No operations to report. CTU 6: MIRU 14,468' of 2" coil and BOP Test to 250 psi low and 4,000 psi high. M/U BHA #1: 3.13" CTC, 3.13" DBPV, 3.16" Jar, 3.38" Disconnect, 3.13" Rupture disk, 3.5" GS Spear. OAL = 13.76'. Open well. 1,860/1,945/3 psi. RIH at 80 fpm (chrome). P/U weights 7,800-lbs @ 2,000', 24k-lbs @ 6,000', 28k-lbs. @ 8,000', 39k-lbs @ 10,500'. Tag top of Straddle Packer assembly at 10,645' ctmd. POH with packer latched to 57k-lbs (max pull) at 18k-lbs overpull and jar 25 times. Gas leak found coming from LDS #5. Attempt to repair. Unable. POH to surface and address leaking LDS. RDMO to END1-29 with intention to return to pull straddle packer once integrity issue resolved. NOTE: FR will be needed in fluid in order to reduce P/U weights when this job is tried again. 4/18/2020 - Saturday PT PCE 250L/3500H. RAN B. GUIDE & SPLIT SKIRT TO 1,468' SLM, RECOVERED LOST TOOLSTRING FROM 04/19/2020 WSR. RAN 3.70" WIRE FINDER, 4-1/2" BL-BRUSH & 3 PRONG WIRE GRAB TO SSSV @ 1,490' SLM, NOTHING RECOVERED. RAN 3.70" LIB TO 1490' SLM, IMPRESSION OF F.N. OF LOCK ON SSSV, SMALL WIRE MARKS AROUND SSSV F.N. RAN DOGLESS GS TO 1,490' SLM, GS SHEARED. PULLED 4-1/2" BBE SSSV (ser#HNBB-54) @ 1,525' MD. RAN 3.70" WIRE FINDER, 4-1/2" BL- BRUSH & 3-PRONG WIRE GRAB TO 1490' SLM, RECOVERED 5' OF WIRE. DRIFT W/ 3.70" WIRE FINDER, 4-1/2" BL-BRUSH & 3- PRONG WIRE GRAB TO 3,000' SLM, NO ISSUES. SET 4-1/2" BBE SSSV (serail# HBB4-63, OAL=60", w/ sec lockdown, 3 sets standard packing W/ o-rings) @ 1,525' MD. 4/21/2020 - Tuesday 4/19/2020 - Sunday PT PCE 250L/3500H. ATTEMPT TO SET XX-PLUG IN X-NIP AT 8,125' SLM/ 8,138' MD (unsuccessful). WELL TECH WORK ON WELL AND PT (pass). SET 4-1/2" BBE SSSV (sn# HNBB-54) @ 1,525' MD, UNABLE TO ESTABLISH CONTROL/BALANCE LINE INTEGRITY. ATTEMPT TO PULL 4-1/2" BBE @ 1,525' SLM, WIRE PARTED FROM TOOLSTRING JUST ABOVE ROPE SOCKET . RAN 2-1/2" SPLIT SKIRT JUS TO TOOLSTRING @ 1,468' SLM, APPEARS PULLING TOOL WENT BESIDE ROPE SOCKET. RAN 3.50" LIB TO TOOLSTRING @ 1,468' SLM, IMPRESSION OF ROPE SOCKET & WIRE TAIL. 4/20/2020 - Monday 4/17/2020 - Friday No operations to report. 4/15/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/16/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date END 2-28B CTU 50-029-21847-02-00 203-006 4/18/2020 7/15/2020 7/10/2020 - Friday No operations to report. 7/8/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/9/2020 - Thursday WELL FLOWING ON ARRIVAL, PT PCE 250L/3,500H. PULLED 4-1/2" BBE SSSV (sn# HBB463, note: sn# on vlv does not have a dash as stated on tag (HBB4-63)) @ 1,525' MD. No operations to report. MIRU CTU #6 2" CT .156" WT Job Scope: Pull Straddle PKR isolating the existing K2B perforations. Perform BOPE test using AOGCC 10-424 form. 300/4000 psi MASP Passed with no issues. Flushed diesel from CT to 100bbl recovery / recycle tank using 2% KCL. Stack 35' of lubircator and MU BHA & pressure test. Set up to recover 4-1/2"Straddle PKR set PCE on deck of CTU. BHA configuration on end of coil stack PCE on back deck. Suspend operation for night. 7/11/2020 - Saturday MIRU CTU #6 2" CT .156" WT Job Scope: Fish lower Straddle PKR from lower X-Nipple. RIH W/ 3.05" CTC, 3.13" DBPV, 3.13" Accelerator, Three 3.44" weight bars, 3.13" Up/Down Jar, 3.13" TJ Disco (7/8" ball), 4" Hydraulic G Spear, OAL= 29.52' Latch and pull lower section of 4-1/2" Straddle PKR left in X Nipple @ 8,138' CTMD. Hung up in X Nipple above completion packer pulled 7k over to continue trip OOH. Recovered PKR. Flush CT w/ 45 bbls of diesel. RD CTU. 7/14/2020 - Tuesday 7/12/2020 - Sunday MIRU CTU #6 2" CT .156" WT Job Scope: Pull Straddle PKR isolating the existing K2B perforations. PU CT injector with 35' of lubricator perform low/high pressure test of PCE on wellhead 300/4,200 psi. RIH W/ 3.05" CTC, 3.13" DBPV, 3.13" Accelerator, Three 3.44" weight bars, 3.13" Up/Down Jar, 3.13" TJ Disco (7/8" ball), 4" Hydraulic G Spear, OAL= 29.52' Latch and pull upper section of 4-1/2" Straddle PKR @ 10,643' CTMD. Jarred two times and upper section released at disigned releasing point shearing brass screws (7,360 lbs) Recovered upper section; 13.9', with no missing parts or packing. RIH and latch lower section @ 10,654' CTMD Jar two times and came free. Wait 15 min and RIH 20' past to verify PKR had released. Stopped at 16,682' CTMD POOH. Hung up in XN @ 8,159' over pulled 24k/52k and popped through. Hung up in lower X Nipple @ 8,138' went down to get run at it popped through. POOH At surface and found that we had left the fish behind. More than likely at the lower X Nipple. Sespend operations for the night. 7/13/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date END 2-28B CTU 50-029-21847-02-00 203-006 4/18/2020 7/15/2020 No operations to report. No operations to report. 7/18/2020 - Saturday No operations to report. 7/21/2020 - Tuesday 7/19/2020 - Sunday No operations to report. 7/20/2020 - Monday 7/17/2020 - Friday No operations to report. 7/15/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL FLOWING ON ARRIVAL, PT PCE 250L/3500H. BRUSHED SSSV NIP @ 1,525' MD W/ 4-1/2" BL-BRUSH & 3.80" G. RING. SET 4-1/2" BBE SSSV (sn# HNBB48, OAL=60", 3 SETS STD PKG, sec. steel lockdown) @ 1525' MD. GOOD DRAWDOWN TEST W/ PAD-OP. 7/16/2020 - Thursday No operations to report. • • E4 v `L `:_r Post Office Box 244027 3 Anchorage, AK 99524-4027 Hilcorp Alaska,LL€ ,JUL 0 2015 3800 Centerpoint Drive Suite 100 AOGC Anchorage,AK 99503 (~J' Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 1D3- a°'� Commissioner Cathy Foerster �'` ,Q c,V- p`Z A...)Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request scpNNE® AUG 2 3 201E 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 i Orig • New I I 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A ;50029218470200 2030060 DUCK IS UNIT MPI 2-28B/O19 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/513 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 1 SEP 2 2U14 Mr. Jim Regg _ Q� Alaska Oil and Gas Conservation Commission a,0 3 � a - g 333 West 7 Avenue — a� Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, r - Vn--y Mehreen Vazir BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 2 Date: 03/20/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / Q -16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 ___- 'END2 -28B / 0-19 2030060 _ 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S-22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -468 / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0-13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / Q -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / Q-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 01/20/11 ScNumh8Nger NO. 5676 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 14-43 BGZ7 -00010 CROSSFLOW CHECK ."- f 9 � / ( 9 — ® r 11/13/10 1 a046 1 NGI-14 AV114-00052 USIT t )S. f `1- `j 12/23/10 .,A, , . I 1 1 L -205 BLPO -00073 MEM LDL ♦ : -- 12/21/10 1 6•T•71riitcl 1 A-42A BL6S -00012 MEM PRODUCTION PROFILE .: • . - / 01/06/11 1 r1 1 01 -30 BCZ2 -00031 INJECTION PROFILE ) Z f e/a r/ it 12/03/10 1 " 1 1 02 -20 BBSK -00040 RST - - 11/19/10 1 d 1 � 07 -238 Art M -00056 wTL�L� ' r2( 1 K -IIA B088 -00073 MCNL 7 11/03110 1 1 04 -24 AYIM -00058 RST ) 12/05/10 1 1 - • 11 -12 BCZ2 -00033 RST -- • 12/07/10 1 Vgyfif ! 1 2- 288/0-19 BCRJ -00055 VeZ. ' ' o P 1 1 _ S -128 BCZ2 -00 BEIWOL T• _ i y 1 1 W -220 BG4H -00025 T , 'l r 1 1 S-41A 10AKA0108 OH MWO/ W - D EDIT -MICFSIMIIIIIIMMEMIOnalliallEME 10115/10 2 �� 1 S41AL1 10AKA0108 OH MWD /LWD EDIT )4/7 ... /A H -11 BGZ7 -00014 RST J la'( - Nail 12/18/10 1 p, 1 _ ..I c- 0 -- -- t 960 fyl PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Site 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • MAR 1 4 '0-11 I 0, /9 12/30/10 SChhnberger NO. 5672 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838A Attn: Christine. Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 o - 6 Anchorage, AK 99501 ek /� Job 8 Log Description Date BL Color CD E -05 BL65 -00011 MEM DDL 12/18/10 1 1 - 3B AY1M -00056 PROD PROFILE ,96 j -/ ' ' • 11/27/10 1 ii 1 11 -12 BCZ2 -00033 PROD PROFILE _ C — . 12106/10 1 'L'ce 1 01 -25 BG4H -00022 INJECTION PROFILE S,Alrf!j�� _ r ,, 1 04 -24 AY1M -00058 PROD PROFILE •-' 1 P2-16 B5JN -00077 SBHPS f S r ' 7 �`� 11/26/10 1 RAF 1 A-41 BCZ2 -00030 LDL ' 4 ,_ f 11/26/10 1 ± 1 04 -08 _ BCRJ -000566 e • • e �I MID 12/06/10 1 'efixigici 1 01 -24A BBSK -00043 W8144010IJ :taldis4• u VrItw�ilf 1 04-10 AV1H -00051 I`J Is • - • u / • _ 12/07/10 1 Li W 1 15 -268 81388 -00080 MEM PROD PROFILE a -- Z 12/12/10 1 1 2- 28810 -19 BCRJ -00055 (9:Zel.tl .1 lIc : • Qi7•T G 8 e ti, ti{T: 1 III 07-238 AY1M -00056 SCMT _ 1 I l - 11/28/10 ., 6[A 1 02 -21A BBSK -00042 SCMT Oecit — e'f `7 ' 11/23110 _ a L. ,21111M 1 02 -22B BL65 -00006 SCMT JO ,- i c 12/11/10 . ?i, "ammo 1 18 -12B BBUO -00029 SCMT t , l J 08 /30/10 o 1 B-00049 l , 09 / a 11/28/10 1 05 -275-27 6 BAUJ-00049 MCNL . • — 09/18/10 I i 1 16-06B BBSK- 00037 •Ti. - • 11/15/10 1 ±,1 1 G -09B BGZ7 -00005 RST _ 1 R 09/20/10 1 _ - a 1 E -34L1 8D88.00050 MCNL - / 7 A 09/28/10 1 ., 1)5; 1 W -219 BGZ7 -00012 CH EDIT PD -GR USIT — a 11/22/10 _ 4 . -t,,, ?] 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnicat Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 e,4q) M4 R I 4 ?Or • • ~ -.~ =--- MICROFILMED 03/01/2008 DO NOT PLACE »»•.. ~. ~'' --. ~_ >.e--.: . ~ .~ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc 11 /21 /07 Alaska Data $ Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Inh it ~~~~~~,~ NOV 2 9 2~D7 .,,. new,. .,~:.... . _. N0.4509 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken !1 333 West 7th Ave, Suite 100 (~ ~3~' V Anchorage, AK 99501 d\~ Field: P.Bay, Milne Pt., Endicott .,_.,, e~ Z-10 11676974 GLS =` ~:a. -.- 11/11/07 1 06-16 11686797 PPROF & RS ~ ^ ( _ (' "%•r~" 11115/07 1 MPL-33 11661179 MEM INJECTION PROFILE a:,7 ~1-n` ,a ,•/ _~ "~ "~ `~ "~ 11/13/07 1 MPF-25 11846827 USIT t °'p ; ~ r ~~ ~- 11/10/07 1 GNI-04 11846828 USIT ~j_j`;~'~_ ._ j °"}. 11/11/07 1 OWDW-SW 11626128 RST y °,^~ s"~`tl -, t ss "~''-t. ~ 10110/07 1 1 3-35/L-36 11630502 RST l ~~" ~ ~ ~ t'l, ~ , ~ _ -a_ /'per 09/09/07 1 1 15-266 11661165 MCNL ~',t,~ 1-~~-.~' t=~.t ~x ~- ~'~ 08124/07 1 1 OS-36A 10928638 MCNL ~~ /7°~_,~`,'0 " ""~' ~. 06/11/05 1 1 07-16A 11216211 MCNL ~ ~~~ ae- & ~ ;' d 08/27/06 1 1 2-286/0-19 11638650 ro- RST "'` `)'~~ ~-faCi ro ~ ) 07/05/07 1 1 07-02A 11649983 MCNL l ~~ 1' - (~'i5''`~~' ~'`• i r~--- ~. /~~~ 08/07/07 1 1 N-27 40015763 OH MWD/LWD EDIT ) 1 :~.__'fy; ~` ; ~ "?. / 09/11/07 2 1 . ....r ..... ................w..,~ .. ~.."r , u, .awe. n.~a nnv nc, a~~ci.uw y,~C..'t.. vr~r-EHl.n ~v: BP Exploration (Alaska) Inc. p~ ~° 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 99503-283~j ATTN' Beth ~ ~ y r ;, ~, %I Received b i i ,,~" • ~ h.I-VL-I" L...LJ . STATE OF ALASKA . ~.~.p-; JUL 2 5 20(17 Al A Oil AND GAS CONSERVATION COMMISSION ~J REPORT OF SUNDRY WELL OPERA TIONSska Oil & Gas Cons. o StimulateO Other r¡~¡iIDh Tubing o Waiver 0 Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0060 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 20268 626 0 o 0 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil P' Gas WAG ~ 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P' Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 54.85 KB 8. Property Designation: ADLO-034633 < 11. Present Well Condition Summary: Total Depth measured 11058 ' feet true vertical 10373.35 feet Effective Depth measured 10967 feet true vertical 10300.12 feet Casing Length Size MD Conductor 80' 30" Surface - 131 ' Surface 2504' 13-3/8" NT-80 Surface - 2504' Production 8284' 9-5/8" 47# NT-80S Surface - 8284' Liner 2917' 4-1/2" 12.6# 13CR80 8141' - 11058' Perforation depth: Measured depth: 10796 - 10806 True Vertical depth: 10165.03 -10172.79 - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# Packers and SSSV (type and measured depth) 9-5/8" BAKER S-3 PAKER o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 34 shut-in x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Exploratory Service 6. API Number: 50-029-21847-02-00 9. Well Name and Number: 2-28B/0-19 10. Field/Pool(s): ENDICOTT Field/ ENDICOTT OIL Pool Plugs (measured) None Junk (measured) None TVD Bu rst Collapse Surface - 131' Surface - 2503' 5020 2270 Surface - 8259' 6870 4760 8119' - 10373' 8430 7500 SCANNED JUL 3 1 2007 - 13CR80 Surface - 8170' 8113' o o o R8DMS BFL JUl :3 0 1D07 Tubing pressure 3017 o Service WDSPl Title Data Management Engineer Date 7/23/2007 Signature Phone 564-4944 Form 10-404 Revised 04/2006 ORIGIAL 'k"1 'de.,. ~ ~~'7submit Original Only . . ~ ... 2-28B/O-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/19/2007 CTU # 8 w/ 1.75" OD CT. Set Liner Patch. Continued from WSR 07/18/07. RIH w/ 3.70" drift assembly. Drifted down to 10750'. POOH. RIH w/ SLB GR/CCL memory tools. Log correlation pass from 10800' to 10300'. Flag pipe at 10700' and 10550'. POOH. Depth correct (+49') to tie-in log. Continued on WSR 07/20/07. 7/20/2007 #8 w/ 1.75" Patch liner. from 07/19/07. MU and RIH with lower 45 KB snap latch packer assembly. Correct depth at flag. Set lower packer assembly at 10665' md (ref: SLB Primary Depth Control Log 12-April-2003). Set upper packer assembly at 10655' md. POOH. Tools indicate good set on packer. RD CTU #8. Well left shut in. *** Job Complete *** Note: TOL of Straddle Packer assembly is 26.2' with top of assembly at 10643'. Minimum I.D. = 2.375" FLUIDS PUMPED BBLS 284 1 % KCL w/0.6% SAFELUBE 15 50/50 METHANOLJWATER 299 TOTAL 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): ~ I STATE OF ALASKA - 6~/S..p~ ALA Ä Oil AND GAS CONSERVATION COM~ION ~ REPORT OF SUNDRY WELL OPERATIONS <P~ D Stimulate D Other D ~ ./ D Waiver D Time Extension D ~~ ð o Re-enter Suspended Well D ~~ tJ' ~ '"'q;, 5. Permit to Drill Number: ~ . C! 203-0060 ~q % tJ'~. ~<? Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Exploratory Service 6. API Number: 50-029-21847-02-00 / 9. Well Name and Number: 54.85 KB 2-28B/0-19 ADLO-034633 - 11. Present Well Condition Summary: 10. Field/Pool(s): ENDICOTT Field/ ENDICOTT OIL Pool - 8. Property Designation: Total Depth measured 11058 feet Plugs (measured) None true vertical 10373.35 feet Junk (measured) None Effective Depth measured 10967 feet true vertical 10300.12 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 30" Surface - 131 ' Surface - 131' Surface 2504' 13-3/8" NT-80 Surface - 2504' Surface - 2503' 5020 2270 Production 8284' 9-5/8" 47# NT-80S/NH Surface - 8284' Surface - 8259' 6870 4760 Liner 2917' 4-1/2" 12.6# 13Cr80 8141' - 11058' 8119' - 10373' 8430 7500 Perforation depth: Measured depth: 10796 - 10806 - True Vertical depth: 10165.03 - 10172.79 - - - 5CANNE!) JUN 2 6 2007 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 Surface - 8170' Packers and SSSV (type and measured depth) 9-5/8" BAKER S-3 PACKER o o o 8113' o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 369 34 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 14192 6197 0 19606 616 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure 1509 3013 13. Service x Contact Gary Preble WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Data Management Engineer Signature Phone 564-4944 Date 6/12/2007 sed 04/200t) R / h I f\/ !J I P'<"l\, Submit Original Only . . 2- 28B/O-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/5/2007 ***WELL FLOWING ON ARRIVAL *** SHUT-IN TO PERFORATE. TIIA/OA = 2500/2050/50. PERFORATED 10650'-10655' WI 27/8" HSD 6SPF 60 DEG PHASED PJ2906 GUN. DEPTH CORRECTED TO SPERRY MWD LOG PLOT DATED 18-JUL Y-2003. ALL SHOTS FIRED. ***JOB COMPLETE*** FLUIDS PUMPED BBLS I 1 DI ESEl 1 TOTAL Schlumb8Pger NO. 4246 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~3-00'=) % (:;-l"~ Company: State of Alaska Alaska Oil & Gas ConI, Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII J b# L 0 o BL CI CD e 0 og escrlptlon ate o or 1-01/J-19 11421026 RST 09/14/06 1 1 2-28/0-19 11226003 RST 09/04/06 1 1 14-41 10830811 RST 05/30/04 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGN.I~.....~... ~tiD",....!\E,;. :L.,wm.,.. {N.I~. P... ..~.. t·..·-.~.·..p." PY EACH TO: BP Exploration (Alaska) Inc. 1t;;~E~l:\F" 1\ \/111:. t), :~~~e~~~i~~~ ~~~~center LR2·1 I" .,=. J7h-" '.- 5CANNED JUN 0 6 2007 Anchorage, Alaska 99508 ~1AY ~i; 1 20CH Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 1 ATTN Be. ~ Received by: ~1 ~ -"'.,", Date Delivered: . ~ ""I n" 10··· ""-í\'Y'I",,,jc¡'" ':\~).f\!ì.t~ till f,;~ t.!~0 ,,!.ii (~, \..".1, U. ,,,, d I 05/18/07 . . · .""-; J~'t;:,,< , './l,_Q'1'1'.f" 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_O-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: {)03-00<O 1Í14490 Digital Log Images: 50-029- 2184 7 -02 I CD Rom 03-17E_K-30: Qo'd -g<!+ ti (LfLf'":f;), Digital Log Images: 50-029-21946-05 1 CD Rom 03-25B_L-27: ;J03-()é)/ 1t /4'-191 Digital Log Images: 50-029-22125-02 1 CD Rom SCANNED FEB 0 1 2007 £.{ e e /3547 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 17, 2003 RE: MWD Formation Evaluation Logs: 2-28B/O-19, AK-MW-2347857 2-28B/O-19: Digital Log Images 50-029-21847-02 a b ').- D oft? 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2- ] 900 E. Benson Blvd. Anchorage, Alaska 99508 "~"oj .-::¡ Date1l-~!t)~ (}f!Q Signed:· )) 0 f ¡.---.,., / 0 ) } À M'-) ì\lJ0 \ ""- DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030060 Well Name/No. DUCK IS UNIT MPI 2-28B/019 MD 11058 I TVD 10373!.- Completion Date 4/12/2003v1 REQUIRED INFORMATION ----.----- ------- Mud log No DATA INFORMATION Types Electric or Other Logs Run: MWD, PWD, GR, CCl, ASI, DEN, NEU Well log Information: log/ Data Digital Type Med/Frmt IED-----------¡) ! i Rpt D I ,fED D Las :1 :1 J j 1 " .j Ii ED i I I I I I I fED ! i I D C Asc r ED C Pds ¿ED C Pds '/ v( ¡ I ED C Pds II i~. ~tt I i L-- Electr Dataset Number Name Directional Survey Directional Survey 11834 Rate of Penetration 11834 LIS Verification 12018 LIS Verification 12018 Casing collar locator 12018 Temperature 12018 Pressure 12018 Temperature Operator BP EXPLORATION (ALASKA) INC Jt.td. À)-- ~ ÀANð3 API No. 50-029-21847-02-00 Completion Status 1-01l Current Status 1-01l UIC N Samples No Directional Survey ~ (data taken from logs Portion of Master Well Data Maint) Log log Scale Media Interval Start Stop 8279 11058 8279 11058 8233 11067 OH/ CH Open Open Open Run No 1 -" Received 4/29/2003 4/29/2003 12/8/2003 Comments A Directional Survey log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/6/2003. 3 8233 11031 Open 6/25/2003 An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 2/6/2003. Wireline report for Primary Depth Control log wfTemp and Pressure data. GR, CCl, TENS 9000 10954 Case 6/10/2003 Primary Depth Control log wfTemp and Pressure data. GR, CCl, TENS 9000 10954 Case 6/10/2003 9000 10954 Case 6/10/2003 Primary Depth Control log wfTemp and Pressure data. GR, CCl, TENS 9000 10954 Case 6/10/2003 Primary Depth Control log wfTemp and Pressure data. GR, CCl, TENS 9000 10954 Case 6/10/2003 Primary Depth Control log wfTemp and Pressure data 5 5 5 5 Slu ~ DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030060 Well Name/No. DUCK IS UNIT MPI 2-28B/019 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21847-02-00 MD 11 058 lVD 10373 Completion Date 4/12/2003 Completion Status 1-01L Current Status 1-01L UIC N vtE--------- 12019 LIS Verification 9990 10964 Case 6/10/2003 RST-Sigma Mode Log k i ED C Asc wlTemp and Pressure Data ED C Pds 12019 Reservoir Saturation 5 9990 1 0964 Case 6/10/2003 RST-Sigma Mode Log wlTemp and Pressure Data ED C Pds 12019 Temperature 5 9990 1 0964 Case 6/10/2003 RST-Sigma Mode Log wlTemp and Pressure Data ED C Pds 12019 Pressure 5 9990 10964 Case 6/1 0/2003 RST-Sigma Mode Log wlTemp and Pressure Data ¡ Rpt 12019 Reservoir Saturation 5 Blu 9990 10964 Case 6/10/2003 RST -Sigma Mode Log ~ wlTemp and Pressure Data Rpt Rate of Penetration 8233 11067 Open 12/8/2003 ED D Las 11834 Induction/Resistivity 8233 11067 Open 12/8/2003 Rpt Induction/Resistivity 8233 11067 Open 12/8/2003 Rpt Neutron 8233 11067 Open 12/8/2003 ED D Las 11834 Neutron 8233 11067 Open 12/8/2003 ED D Las 11834 Rate of Penetration 8233 11067 Open 12/8/2003 Rpt Density 8233 11067 Open 12/8/2003 ED D Las 11834 Density 8233 11067 Open 12/8/2003 --- Well Cores/Samples Infonnation: Sample IntelVal Set Name Start Stop Sent Received Number Comments -~ ADDITIONAL INFORMATION Well Cored? Y /Q) Daily History Received? 0N 6/N Chips Received? ~( / N Formation Tops Analysis Received? y / t-L_ ---- Comments: Permit to Drill 2030060 MD 11058 TVD Compliance Reviewed By: 10373 DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Well Name/No. DUCK IS UNIT MPI 2-28B/019 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21847-02-00 i~~on Date 4/12/2003 1-01L CurrentStatus 1-01L ¡V}A.^. UIC ~ Date: J ~ , V-) ~ ~ Completion Status - .~ ) ') d 03 --coCo WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmtn. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 02, 2003 RE: MWD Formation Evaluation Logs - 02-28B / 0-19, AK-MW-2347857 The technical data listed below is being subllÙtted herewith. Please acknowledge receipt by returning a signed copy of this transnùttalletter to the attention of: R~is~, S¡::eny-SunDrilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ~f-~W ~ ~\.() &i ~ ~/V, 1 LDWG formatted Disc with verification listing. \, 83 ~ API#: 50-029-21847-02 Note: This data replaces any previous data for well 02-288 / 0-19 and contains compensated thennal neutron L WD data that is reprocessed \vith updated algorithms. RECEIVED DEC 08 2003 Naske Ofi & Gas Cons. Commi88i0n Anchorsge ~~'ù{Y\~ ) ~Dó-DD(o \ 1 <t>3Y- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7t11 Avenue, Suite 100 Anchorage, Alaska June 20, 2003 RE: MWD Formation Evaluation Logs - 2-28B / 0-19, AK-MW-2347857 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, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21847-02 Gj r' . G!E.(J idd 7; &ifs- ~~ c;:::> -\-_ ~ . ~ ( ~ ' \...;~V~,~ ~0-~C-0\ Jd.-d-Cß ,.c. ~~L'-.;~\ Jd-S-03 ~ð~~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well 2-28B/0-19 ¡!JÖ"3-crJl 0 2-28B/0-19~O~ -(JOlt¿ 3-17E/K-30~~ 'a Lf 1-. 3-25B/L-27'-' 03 ~ i I 4-10A/L-28 tJJ:).- é). ~ IS' Job# 23205 23204 23292 23256 23321 Log Description PDC GRlCCL RST SIGMA PDC GRlCCL PDC GRlCCL 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: ~~m~ ta /' (Ô - 03 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 Color Date Blueline Prints CD 04/12/03 1 1 Jd0{?r 04/12/03 1 1 02/25/03 1 1 ~1 04/29/03 1 1 02/28/03 1 1 ï . n --- ~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth RECE\VED ~//' Received by: JUN 1 0 2003 Alaska o;,¡ & Gas Cons. Comrffission f\ .....J.. i'\fiW'1Q Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well :J,O $ OJþ 2-28B/O-t'9-J 2-28B/0-19'J ~ ~ Jj '7 3-17E/K-3~ ~ð~3 ,- 0 ~ I 3-25B/L-2N 19 '1-' Q5.J 4-10A/L-2s-1 Job# 23205 23204 23292 23256 23321 Log Description Date PDC GRlCCL RST SIGMA PDC GRlCCL PDC GRlCCL PDC GRlCCL 04/12/03 04/12/03 02/25/03 04/29/03 02/28/03 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//0 ---o? Blueline 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 Color Prints CD -' ,~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receiv~~J 1t1 / (1% STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well Ia 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 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1863' SNL, 540' WEL, SEC. 36, T12N, R16E, UM X = 260669, Y = 5982500 10. Well Number At total depth 1822' SNL, 372' WEL, SEC. 36, T12N, R16E, UM X = 260838, Y = 5982535 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Endicott Field / Endicott Pool KBE = 54.85' ADL 034633 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3-25-2003 4-1-2003 4-12-2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11058 10373 FT 10967 10300 FT Ia Yes 0 No 22. Type Electric or Other Logs Run MWD,GR,PWD,RES,NEU,DEN,CCL Classification of Service Well 7. Permit Number 203-006 8. API Number 50- 029-21847 -02 9. Unit or Lease Name X = 258967, Y = 5982474 Duck Island Unit/Endicott 2-288/0-19 15. Water depth, if offshore 16. No. of Completions 6' - 12' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1525' 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" Structural Drive Surface 131' Driven 13-3/8" 68# NT -80 Surface 2504' 17-1/2" 3687 cu ft Permafrost 9-5/8" 47# NT-80S I NT95H Surface 8284' 12-1/4" 575 cu ft Class IG' 4-1/2" 12.6# 13Cr80 8141' 11058' 8-1/2" 983 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 25. SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 8170' PACKER SET (MD) 8114' MD TVD 10796' - 10806' 10165' - 10173' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 105 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 12, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL 4/18/2003 4 TEST PERIOD 1534 826 292 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL Press. 24-HoUR RATE CHOKE SIZE GAS-OIL RATIO 40 538 OIL GRAVITY-API (CORR) o CORE DATA Brief description of lithology, porosity, fractures, apparent dips and p,res~nce of oil, gas or water. Submit core chips. No core samples were taken. t·,., ...- ; ':~i;;\~~~~At. R r:: C E! V 1:: f) ¡~~~\"~J : --~~C;;,.. ' 28. htih'.;' '" ,n t {.~ ,.~ MAY 12 1Ðfn O~~C, NA~_ ~~~ (~;,~~,~~, ç..~)~&J.~'~ ~s / . -;- c.j / I~"f .J' .................. :~, :'H'il ~!'''I''~~ r, Form 10-407 Rev. 07-01-80 RBDMS BFL Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. K3A 10358' 9843' K28 10548' 9978' K2M 10731' 10115' K2A 10776' 10150' S2A2 1 0881' 10232' S2A1 10896' 10243' K1 11009' 10334' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Work Summary and a Leak-Off Integrity Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed SOndraf~~-~~~ Title Technical Assistant Date CfS' \ 1. - m 2-288/0-19 203-006 Prepared By NamelNumber: Sandra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Walter Quay, 564-4178 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) Operations Summary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Date From - To Hours Task Code NPT Phase Description of Operations --- --~----- 3/18/2003 03:00 - 04:00 1.00 MOB P PRE SKID RIG FLOOR - LIFT SUB FEET 04:00 - 05:00 1.00 MOB P PRE MOVE PIT COMPLEX FROM SUB - SPOT COMPLEX FOR RIG MOVE 05:00 - 06:00 1.00 MOB P PRE MOVE SUB COMPLEX FROM WELL 3-17E - SPOT FOR RIG MOVE 06:00 - 08:00 2.00 MOB P PRE MOVE SUB - PIT COMPLEX FROM SDI TO MPI 08:00 - 10:00 2.00 MOB P PRE LAY DOWN HERCULlTE - SET RIG MATS FOR MOVE ON OF SUB - PIT COMPLEXS 10:00 - 11 :00 1.00 MOB P PRE MOVE SUB COMPLEX OVER WELL 2-28B 11 :00 - 11 :30 0.50 MOB P PRE MOVE PIT COMPLEX TO SUB 11 :30 - 12:00 0.50 MOB P PRE LOWER FEET ON SUB AND SECURE 12:00 - 14:00 2.00 MOB P PRE SKID RIG FLOOR - CLOSE UP CELLAR 14:00 - 15:00 1.00 MOB P PRE RIG UP STEAM, AIR, WATER, GYLCOL LINES - WELD ON NEW DRAIN LINES NIPPLES 15:00 -16:30 1.50 MOB P PRE RIG DOWN GAS LINE @ SDI - RIG UP GAS LINE TO RIG - CONTINUE RIGGING UP 16:30 - 18:30 2.00 MOB P PRE BERM UP AROUND RIG - SPOT ROCK WASHER AND BERM UP SAME 18:30 - 19:30 1.00 MOB P PRE TAKE ON SEA WATER IN PITS - CONTINUE RIGGING UP 19:30 - 20:30 1.00 MOB P PRE RIG UP DSM LUBICATOR - PULL BPV - RIG DOWN LUBICATOR - NO PRESSURE ON TUBING 20:30 - 22:00 1.50 MOB P PRE CONTINUE RIGGING UP - CIRCULATING WATER - AIR- STEAM - THROUGH OUT RIG - ACCEPT RIG @ 22:00 HRS ON 3/18/2003 22:00 - 00:00 2.00 CLEAN P DECOMP INSTALL HERCULlTE OVER WELL HOUSES UNDER SUB- RIG UP HARD LINE FROM 2-28 ANNULUS TO 2-32 FLOW LINE TO CIRCULATE FREEZE PROTECT AND BRINE OUT OF WELL 3/19/2003 00:00 - 01 :30 1.50 RIGU P DECOMP HELD PJSM. RIGGED UP HARD LINE WITH DSM - TESTED TO 3,000 PSI 01 :30 - 06:00 4.50 CLEAN P DECOMP TESTED INJECTION LINE TO 3,000 PSI - ESTABLISHED CIRCULATION DISPLACED FREEZE PROTECTION AND BRINE STAGING UP AT 2 BPM 300 PSI 4 BPM 1100 PSI 5 BPM 1450 PSI PUMP 265 BBLS - SHUT DOWN 30 MINS - CONTINUED DISPLACING AT 2 BPM - 700 PSI 4 BPM - 1100 PSI 6 BPM -1800 PSI PUMP 265 BBLS - SHUT DOWN 30 MINS - CONTINUED DISPLACING AT 2 BPM 500 PSI 4 BPM 900 PSI 6 BPM 1400 PSI DISPLACED WELL WITH TOTAL OF 800 BBLS OF 8.6 # SEAWATER 06:00 - 06:30 0.50 CLEAN P DECOMP DISCONNECTED CIRC LINES - BLEW DOWN 06:30 - 07:00 0.50 CLEAN P DECOMP FLOW CHECKED WELL - WELL STATIC 07:00 - 07:30 0.50 WHSUR P DECOMP INSTALLED TWC - TESTED TO 1,000 PSI FROM BELOW FOR 15 MINS 07:30 - 09:00 1.50 WHSUR P DECOMP N / D TREE AND ADAPTER FLANGE. CHECKED THREADS I Printed: 4/8/2003 8:58:52 AM ) -) BP EXPLORATION Operations .Sum maryReport Page 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Date From - To Hours Task Code NPT Phase Descri ptionof Opërations 3/19/2003 07:30 - 09:00 1.50 WHSUR P DECOMP IN TUBING HANGER. SOME THREAD DAMAGE DUE TO PREVIOUS TTRD OPERATION. 09:00 - 13:00 4.00 BOPSURP DECOMP N / U 13-5/8" BOPE w/ ANNULAR, 3-1/2" x 6" VARIABLE RAMS IN TOP, BLIND RAMS AND 4-1/2" x 7" VARIABLE RAMS IN THE BOTTOM. 13:00 - 14:00 1.00 RIGU P DECOMP CREWS ATTENDED BP SAFETY INDUCTION 14:00 - 17:30 3.50 BOPSUR P DECOMP CONTINUED N / U - BOPE - RISER - FLOWLINE - INSTALLED MOUSE HOLE - BLEED OFF LINE. 17:30 - 19:00 1.50 RIGU P DECOMP RIGGED UP TEST JOINT - FLOOR VALVES - TESTED SUB FOR TOP DRIVE - FILLED STACK / CHOKE MANIFOLD 19:00 - 00:00 5.00 BOPSURP DECOMP TESTED BOPE - TESTED TOP PIPE RAMS - CHOKE MANIFOLD - KILL / CHOKE HCR'S - KILL / CHOKE MANUAL VALVES - FLOOR VALVES - UPPER / LOWER IBOP- TESTED LOWER PIPE RAMS HINGE PIN LEAKING HYD OIL ON ODS - NO TEST - REPLACED 2 SEALS ON RAMS IN HINGE PIN FLUID HOUSING. 3/20/2003 00:00 - 02:00 2.00 BOPSUR P DECOMP HELD PJSM. TESTED ANNULAR TO 250 LOW 3,000 HIGH 5 MINS EACH TEST - TESTED LOWER PIPE RAMS - BLIND RAMS 250 LOW 4,500 HIGH 5 MINS EACH TEST - ACCUMULATOR TEST - RIGGED DOWN TEST JOINT 02:00 - 02:30 0.50 PULL P DECOMP BLEW DOWN CHOKE / KILL LINE - CHOKE MANIFOLD- NIPPLED UP SECONDARY VALVE ON WELL HEAD 02:30 - 04:00 1.50 PULL P DECOMP HELD PJSM. PICKED UP SHOOTING FLANGE - PICKED UP LUBRICATOR - PULLED TWC - RIGGED DOWN LUBRICATOR 04:00 - 05:00 1.00 PULL P DECOMP HELD PJSM. M / U BAKER DOUBLE SPEAR w/ 4.020" MAX CATCH 3.947" NOMINAL CATCH GRAPPLES, 2 JTS 5" DP. 05:00 - 05:30 0.50 PULL P DECOMP RIH w/ SPEAR ASSEMBLY, M / U TO TOP DRIVE. SPEAR ASSEMBLY WOULD NOT PASS THROUGH HANGER. POOH w/ TO CHECK GRAPPLES. REATTEMPTED TO ENGAGE SPEAR, SPEAR ASSEMBL Y WOULD NOT PASS THROUGH HANGER. 05:30 - 07:00 1.50 PULL N DPRB DECOMP POOH TO CHANGE OUT GRAPPLES. PERFORMED DERRICK INSPECTION. 07:00 - 07:30 0.50 PULL N DPRB DECOMP DRESSED SPEAR w/ 3.958" MAX CATCH 3.885" NOMINAL CATCH GRAPPLES, RIH, TOOK 30,000# DOWN WEIGHT TO PASS THROUGH TUBING HANGER, P / U AND ENGAGED GRAPPLES. 07:30 - 08:00 0.50 PULL P DECOMP CHECKED ANNULUS FOR PRESSURE, ZERO PRESSURE. BOLDS. 08:00 - 09:00 1.00 PULL P DECOMP PULLED ON SPEAR ASSEMBLY w/ 165,000#, TUBING HANGER CAME FREE, PULLED TUBING HANGER TO FLOOR, STRING WEIGHT UP 150,000#. TERMINATED CONTROL LINES, BROKE OUT AND L /0 SPEAR ASSEMBLY AND TUBING HANGER. 09:00 - 11 :00 2.00 PULL P DECOMP HELD PJSM. M / U HEAD PIN, XO AND CIRCULATING HOSE. CIRCULATED 2 x BOTTOMS UP PUMP RATE 10 BPM, 750 PSI. NO GAS. R / U CAMCO CONTROL LINE SPOOLING EQUIPMENT. 11 :00 - 13:00 2.00 PULL P DECOMP POOH, L /038 JOINTS OF 4-1/2" 12.6# L-80 BTC TUBING, SPOOLED UP CONTROL LINE. RECOVERED 19 CONTROL LINE CLAMPS AND 4 STAINLESS STEEL BANDS. 13:00 - 13:30 0.50 PULL P DECOMP R / 0 CAMeo CONTROL LINE SPOOLING EQUIPMENT. Printed: 4/8/2003 8:58:52 AM ) ) Legal Well Name: 2-288/0-19 Common Well Name: 2-288/0-19 Spud Date: 3/18/2003 Event Name: REENTER+COMPLETE Start: 3/18/2003 End: 4/6/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 4/6/2003 Rig Name: DOYON 15 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/20/2003 13:00 - 13:30 0.50 PULL P DECOMP BROKE OUT AND L/DSSSVASSEMBLY. 13:30 - 21 :00 7.50 PULL P DECOMP POOH, L / 0 225 JOINTS OF 4-1/2" 12.6# L-80 BTC TUBING + CUT OFF JOINT 34.62 21 :00 - 22:00 1.00 PULL P DECOMP CLEARED FLOOR OF TUBING EQUIPMENT - XO'S 22:00 - 23:30 1.50 PULL P DECOMP PJSM - SCHLUMBERGER - PICKED UP 9 5/8" EZVS BRIDGE PLUG TO FLOOR - RIGGED UP SCHLUMBERGER EQUIPMENT - 23:30 - 00:00 0.50 PULL P DECOMP RIH WITH -GR / CCL / JB / GAUGE RING 8.5" 3/21/2003 00:00 - 03:00 3.00 EVAL P DECOMP PJSM. RIH TO 8800' WITH CCL / GR / JB / DRIFT 8.5 - LOGGED UP TO 8000' - POH WITH TOOLS - (NO JUNK IN JUNK BASKET) 03:00 - 03:30 0.50 EVAL P DECOMP PJSM - MADE UP 9 5/8" EZSV BRIDGE PLUG ON E-LlNE RUNNING TOOL 03:30 - 04:30 1.00 EVAL P DECOMP RIH WITH 9 5/8" EZSV PLUG TO 8490' - SET PLUG RELEASE OFF SETTING TOOL 04:30 - 06:30 2.00 EVAL P DECOMP POH WITH SETTING TOOL - SHUT BLIND RAMS TEST CASING TO 3000 PSI FOR 10 MINS - TEST GOOD - RIG DOWN SCHLUMBERGER 06:30 - 07:30 1.00 STMILL P WEXIT INSTALL WEAR RING 07:30 - 08:00 0.50 STMILL P WEXIT SERVICE TOP DRIVE - CROWN - RIG 08:00 - 08:30 0.50 STMILL P WEXIT PJSM - PREPARE FOR PICKING UP 5" DP FROM PIPE SHED 08:30 - 17:30 9.00 STMILL P WEXIT PICK UP 5" DRILL PIPE FROM SHED - RIH TO 7275' 17:30 - 18:30 1.00 STMILL P WEXIT PULL 20 STANDS S-135 DP - RACK BACK FOR DRILLlNG- FROM 7275' TO 5325' 18:30 - 21 :00 2.50 STMILL P WEXIT CONTINUE PICKING UP 5" DRILL PIPE FROM PIPE SHED FROM 5325' TO 8394' 21 :00 - 21 :30 0.50 STMILL P WEXIT BREAK CIRCULATION 60 SPM - 200 PSI - WASH FROM 8394' TO 8484' TAG BRIDGE PLUG DRILL PIPE MEASUREMENT - PICK UP 10 FEET TO 8474' 21 :30 - 22:00 0.50 STMILL P WEXIT RIG UP DISPLACEMENT LINE FROM 2-28 TO 2-32 - TEST TO 2000 PSI 22:00 - 22:30 0.50 STMILL P WEXIT PRODUCTION NOT ABLE TO TAKE RETURNS DOWN FLOW LINE - BLOW DOWN LINE - RIG DOWN LINE - PREPARE TO DISPLACE INTO ROCK WASHER 22:30 - 23:30 1.00 STMILL P WEXIT DISPLACE 8.6 BRINE WITH 9.7 MILLING FLUID @ 93 SPM - 2100 PSI - PUMP 50 BBL FRESH WATER SPACER - DISPLACED 565 BBLS 23:30 - 00:00 0.50 STMILL P WEXIT SPOT 20 BBL 18 PPG PILL ON BTM - PICK UP WEIGHT 195K - SLACK OFF WEIGHT 195K - ROTATING WEIGHT 195K - RPM 90 - TORQUE 5500K 3/22/2003 00:00 - 00:30 0.50 STMILL P WEXIT CONTINUE TO SPOT 18 PPG PILL ON BTM 00:30 - 01 :00 0.50 STMILL P WEXIT PJSM - PULL 5 STANDS FROM 8474' TO 8009' 01 :00 - 02:00 1.00 STMILL P WEXIT PJSM - CUT DRILLING LINE - RIG SERVICE - RIG SERVICE TOP DRIVE 02:00 - 06:00 4.00 STMILL P WEXIT POOH w/ 5" DP FROM 8,009' TO MULE SHOE. 06:00 - 06:30 0.50 STMILL P WEXIT CLEARED AND CLEANED RIG FLOOR. 06:30 - 09:00 2.50 STMILL P WEXIT HELD PJSM. M / U SECTION MILL BHA: #7 LOCK-O-MATIC- JET SUB - CIRCULATING SUB - 9 x 6-1/4" DC - JARS -15 x 5" HWDP. BHA LENGTH 757.35'. 09:00 - 14:00 5.00 STMILL P WEXIT RIH wI SECTION MILL BHA ON 5" DP TO 8,284'. Printed: 4/8/2003 8:58:52 AM ) ') BP EXPLORATION Operations Summary Report Page 4 of 13 Legal Well Name: 2-288/0-19 Common Well Name: 2-288/0-19 Spud Date: 3/18/2003 Event Name: REENTER+COMPLETE Start: 3/18/2003 End: 4/6/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 4/6/2003 Rig Name: DOYON 15 Rig Number: - To Hours Task Code NPT Phase Description of Operations 3/22/2003 14:00 - 15:00 1.00 STMILL P WEXIT M / U TOP DRIVE AND BROKE CIRCULATION. PUMP RATE 425 GPM, 2,250 PSI. STRING WEIGHT UP 250,000#, STRING WEIGHT DOWN 229,000#. CIRCULATED BOTTOMS UP. 15:00 - 00:00 9.00 STMILL P WEXIT STARTED MILLING SECTION AT 8,284' - 8302' WOB 8K TO 12K - RPM 72 TO 80 - TORQUE 7K TO 11K - PUMP RATE 645 GPM - 3200 PSI- ROTATING WEIGHT 230,000# - PU 250K - SO 225K - MILLED 18 FEET = 846# METAL MILLED - RECOVERED 625# METAL = 74% RECOVERED 3/23/2003 00:00 - 12:30 12.50 STMILL P WEXIT MILLING WINDOW FROM 8,302' TO 8,334' WOB 8,000 - 14,000, RPM 75 - 85, TORQUE 7,000 - 14,000 ft/lbs, PUMP RATE 650 GPM, 3,200 PSI, ROTATING WEIGHT 230,000#- STRING WEIGHT UP 250,000#, STRING WEIGHT DOWN 225,000#. MILLED 50 FEET = 2,350# METAL MILLED, RECOVERED 3520# METAL / CEMENT = 150% RECOVERED. 12:30 - 15:30 3.00 STMILL P WEXIT CIRCULATED HOLE CLEAN OF METAL CUTTINGS, RECIPROCATED AND ROTATED PIPE THROUGH WINDOW, WORKED MILL ON TOP STUMP TO CLEAR CUTTINGS NEST OFF MILL, 110 RPM, TORQUE 7,000 ft / Ibs, PUMP RATE 675 GPM, 3,250 PSI, PUMPED 1-10 BBL LO-VIS SWEEP, 2-30 BBL WEIGHTED SWEEPS. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. FLOW CHECKED WELL, WELL STATIC. (WHILE MILLING AND CIRCULATING PUMPED 7 TOTAL SWEEPS- THEY WERE WEIGHTED, HI-VIS, AND HI-VIS WEIGHTED) 15:30 - 16:00 0.50 STMILL P WEXIT SHUT DOWN PUMPS, PULLED UP INTO CASING 95', w/ 10,000# - 15,000# OVERPULL. DROPPED BALL AND PUMPED OPEN CIRCULATING SUB w/ 1,500 PSI. PUMPED DRY JOB. 16:00 - 17:00 1.00 STMILL P WEXIT POOH w/ 5" DP. - PULL 7 STANDS - DRESSER SLEEVE ON TRIP TANK LINE LEAKED 2 BBLS MUD INTO SECONDARY CONTAINMENT 17:00 - 18:00 1.00 STMILL N SFAL WEXIT CLEAN UP SPILLED MUD FROM TRIP TANK LINE WITH VAC TRUCK - ENVIRONMENTAL TECH INSPECTED AREA - ALL NECESSARY NOTIFICATIONS WERE MADE 18:00 - 00:00 6.00 STMILL P WEXIT CONTINUE POH WITH MILLING ASSY TO 1232' - AT 2280' STARTED SEEING 20K TO 30K OVER PULL EVERY 40' COMING OUT - RAN BACK IN DID NOT SEE ANY SET DOWN WEIGHT - CONTINUE POH WITH OVERPULL EVERY 40' TO BHA 3/24/2003 00:00 - 00:30 0.50 STMILL WEXIT CONTINUE POH TO BHA 00:30 - 02:30 2.00 STMILL P WEXIT STAND BACK 5" HWDP - LAY DOWN OIL JARS - 9 61/4" DC'S - BAKER SECTION MILLING TOOLS - OVERPULL OF 30K WHEN PULLING MILL THROUGH WEAR RING 02:30 - 03:00 0.50 STMILL P WEXIT CLEAR FLOOR OF ALL TOOLS 03:00 - 04:30 1.50 CLEAN P WEXIT PICK UP BAKER MAGNET - MAKE UP TO STACK WASHER - FLUSH BOP STACK FROM METAL CUTTINGS - BREAK OUT AND LAY DOWN STACK WASHER - BAKER MAGNET- (RECOVERED 20# METAL OUT OF BOP'S) 04:30 - 09:00 4.50 REMCM-P WEXIT MAKE UP 5" MULE SHOE AND RIH TO SET KICK OFF PLUG @ 8200' - (FILL PIPE EVERY 25 STANDS) 09:00 - 10:00 1.00 REMCM-P WEXIT BREAK CIRCULATION - WASH FROM 8200' TO 8369' Printed: 4/8/2003 8:58:52 AM ,) ) BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Date From - To Hours Task Code NPT Phase Description of Operations 3/24/2003 10:00 - 14:00 4.00 REMCM-P WEXIT CIRCULATE AND CONDITION HOLE AND MUD FOR KICK OFF PLUG - 530 GPM - 1300 PSI 14:00 - 15:00 1.00 REMCM-P WEXIT PUMP 5 BBLS WATER - TEST LINES TO 3500 PSI-15 BBLS WATER - 39 BBLS 17 PPG CEMENT -7.3 BBLS WATER- DISPLACE WITH RIG 133 BBLS MUD @ 10 BPM 950 PSI - CIP 1500 HRS 15:00 - 15:30 0.50 REMCM-P WEXIT POH 8 STANDS SLOWLY OUT OF CEMENT TO 7682' - TOC @ 7984' 15:30 - 16:30 1.00 REMCM-P WEXIT CIRC @ 7682' - PUMP 40 BBL NUT PLUG PILL - @ 20 BPM - 2400 PSI 16:30 - 19:00 2.50 REMCM-P WEXIT PREFORM HESITATION SQUEEZE - RU HEAD PIN - TIW - CIRC LINE - CLOSE TOP RAMS - PERFORM SQUEEZE- 300 PSIINCERMENTS - HOLDING 10 MINS EACH STEP 14 STKS 300 PSI- 260 PSI 21 STKS 600 PSI - 590 PSI 27 STKS 910 PSI - 900 PSI 33 STKS 1200 PSI-1180 PSI 40 STKS 1500 PSI-1480 PSI 46 STKS 1800 PSI - 1790 PSI 50 STKS 2000 PSI - HOLD FOR 1 HR FINAL PRESSURE 1970 PSI BLEED OFF PRESSURE - 3 BBLS BACK - RIG DOWN CIRC LINE - HEAD PIN - TIW - OPEN RAMS 19:00 - 23:00 4.00 REMCM-P WEXIT MONITOR WELL - PUMP DRY JOB - POH - LAY DOWN MULE SHOE 23:00 - 00:00 1.00 BOPSURP PROD1 PULL WEAR RING - INSTALL TEST PLUG - RIG UP TESTING EQUIPMENT 3/25/2003 00:00 - 05:00 5.00 BOPSUR P PROD1 TESTING BOP'S - ANNULAR 250 LOW 3000 HIGH 5 MINS EA TEST - TOP RAMS - BTM RAMS - BLIND RAMS - CHOKE MANIFOLD - HCR CHOKE / KILL - MANUAL CHOKE / KILL - FLOOR VALVES - UPPER / LOWER IBOP - 250 LOW 4500 HIGH 5 MINS EA TEST - ALL OK - ACCUMLATOR TEST- JOHN CRISP WITH AOGCC WAIVED WITNESS OF TEST 05:00 - 06:00 1.00 BOPSURP PROD1 PULL TEST PLUG - INSTALL WEAR RING - CLOSE ANNULUS VALVES - RIG DOWN TESTING EQUIPMENT- BLOW DOWN CHOKE / KILL LINES 06:00 - 09:30 3.50 DRILL P PROD1 MAKE UP DLG ASSYEMBL Y - MOTOR SET 1.76 - TIH TO 810 - SURFACE TEST MWD 09:30 - 10:00 0.50 DRILL P PROD1 RIG SERVICE - TOP DRIVE - DRAWWORKS 10:00 - 13:30 3.50 DRILL P PROD1 RIH FROM 810' 0 6710' - FILLING EVERY 25 STANDS 13:30 - 15:30 2.00 DRILL P PROD1 PJSM - CUT DRLG LINE - LUBRICATE RIG 15:30 - 16:30 1.00 DRILL P PROD1 CONTINUE RIH FROM 6710' TO 7682' 16:30 - 17:00 0.50 DRILL P PROD1 BREAK CIRC - WASH FROM 7682' TO 7935' - TAG CEMENT AT 7935' 17:00 - 21 :30 4.50 DRILL P PROD1 DRLG CEMENT FROM 7935' TO 8286' - WOB 1 OK - RPM 70 - GPM 435 - PP 1800 - TQ 6K - PU 250 - SO 220 - ROT 230 21 :30 - 00:00 2.50 DRILL P PROD1 DIRECTIONAL DRILL - KICK OFF AT 8286' DRILL TO 8318'- WOB 15 - 50 - GPM 435 -1800 3/26/2003 00:00 - 03:30 3.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 8318' TO 8354' (20' PAST CASING STUMP AT 8334') 03:30 - 04:30 1.00 DRILL P PROD1 CIRCULATE AND CONDITION HOLE FOR FIT. 04:30 - 05:00 0.50 DRILL P PROD1 LAID DOWN ONE SINGLE AND PULLED ONE STAND INTO CASING AT 8246'. RIG UP FOR FIT. Printed: 4/8/2003 8:58:52 AM ) ) BP EXPLORATION Operations Summary.· Report Page 6 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Date From -To Hours Task Code NPT Phase Description of Operations 3/26/2003 05:00 - 05:30 0.50 DRILL P PROD1 PERFORMED FIT TO 12.2 PPG EMW. MUD WEIGHT 9.9 PPG-1025 PSI-TVD 8300'. PRESSURE BLED FROM 1025 PSI TO 1000 PSI IN 10 MINUTES. 05:30 - 07:00 1.50 DRILL P PROD1 RIG DOWN LINES - BLOW DOWN KILL LINE. RUN BACK IN HOLE - TO 8354' - DISPLACE MILLING FLUID TO GEM MUD 07:00 - 00:00 17.00 DRILL P PROD1 DIRECTIONAL DRILLING FROM 8354' TO 8661' - WOB 50K- RPM 60 - TO 6K TO 8K ON BTM - 5K TO 6K OFF BTM - GPM 550 - PP 2400 ON BTM 2300 OFF BTM - PU 255K - SO 225K - ROT 250K 3/27/2003 00:00 - 21 :00 21.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 8661' TO 9007' - WOB 60K TO 65K - RPM 70 - TO ON BTM 7K - OFF BTM 5K - GPM 550 - PP ON BTM 2600 - OFF BTM 2450 - PU 260K - SO 240K - ROT 250K 21 :00 - 23:30 2.50 DRILL P PROD1 CBU 2.75 X - HOLE CLEAN - SET BACK STAND EVERY 30 MINS - 70 RPM - TO 4K - 500 GPM - PP 2200 23:30 - 00:00 0.50 DRILL P PROD1 PULL 4 STANDS TO 8245' - MONITOR WELL - PUMP DRY JOB 3/28/2003 00:00 - 00:30 0.50 DRILL P PROD1 MONITOR WELL - PUMP DRY JOB - BLOW DOWN TOP DRIVE / LINES 00:30 - 04:00 3.50 DRILL P PROD1 POH FROM 8245' TO BHA @ 810' 04:00 - 05:00 1.00 DRILL P PROD1 POH WITH BHA - LAY DOWN JARS 05:00 - 06:00 1.00 DRILL P PROD1 CHANGE BITS - ADJUST MOTOR FROM 1.76 TO 1.5 DEGREE 06:00 - 07:00 1.00 DRILL P PROD1 RIH WITH BHA TO 810' 07:00 - 11 :00 4.00 DRILL P PROD1 RIH FROM 810' TO 7957' - FILLING PIPE EVERY 25 STANDS 11 : 00 - 11: 30 0.50 DRILL P PROD1 RIG SERVICE - TOP DRIVE 11:30-12:00 0.50 DRILL P PROD1 RIH FROM 7957' TO 8915' 12:00 - 12:30 0.50 DRILL P PROD1 BREAK CIRC - WASH FROM 8915' TO 9007' - NO FILL - NO PROBLEMS 12:30 - 00:00 11.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 9007' TO 9393' - WOB 40K TO 60K - RPM 60 - TO ON BTM 6K - OFF BTM 5K - GPM 525 - PP 2650 ON BTM - OFF BTM 2450 - PU 262K - SO 245K - ROT 250K 3/29/2003 00:00 - 14:30 14.50 DRILL P PROD1 DIRECTIONAL DRILL FROM 9393' TO 9870' 14:30 - 17:00 2.50 DRILL P PROD1 CBU 3 X - 500 GPM - PP 2800 - RPM - STAND BACK ONE STAND EVERY 30 MINS 17:00 - 18:00 1.00 DRILL P PROD1 POH 11 STANDS TO SHOE 8245' - NO PROBLEMS HOLE IN GOOD SHAPE 18:00 - 18:30 0.50 DRILL P PROD1 MONITOR WELL - PUMP DRY JOB - BLOW DOWN TPOP DRIVE 18:30 - 22:30 4.00 DRILL P PROD1 CONTINUE POH FROM 8245' TO BHA 810' - STAND BACK HWDP - JARS 22:30 - 00:00 1.50 DRILL P PROD1 CHECK SCRIBE ON MWD / MOTOR OK - FLUSH MWD I MOTOR - ATTEMPT TO RESET MOTOR FROM 1.5 TO 0 - NO BREAK ON ADJUSTMENT SUB - BREAK OUT BIT - LAY DOWN 1 FLEX DRILL COLLAR - MOTOR - STABILlZER- HANG OFF SUB 3/30/2003 00:00 - 00:30 0.50 DRILL P PROD1 PJSM - CLEAR RIG FLOOR 00:30 - 02:30 2.00 DRILL P PROD1 PICK UP BHA # 4 - MOTOR SET 1.75 DEGREE 02:30 - 05:00 2.50 DRILL P PROD1 LOAD I INITIALIZE MWD - NO SIGNAL - CIO ADAPTER TIP - SURFACE TEST 364 GPM - 760 PSI - OK - BLOW DOWN TOP DRIVE - PJSM - LOAD NUKE SOURCE 05:00 - 08:30 3.50 DRILL P PROD1 RIH FROM 68' TO 7988' - FILLING EVERY 25 STANDS Printed: 4/8/2003 8:58:52 AM ) ) BP EXPLORATION Operations Summary Report Page 7 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Date From - To Hours Task Code NPT Phase Descri pHon· of Operations 3/30/2003 08:30 - 09:00 0.50 DRILL P PROD1 RIG SERVICE - TOP DRIVE - CROWN - BLOCKS - CHECK OIL IN SWIVEL 09:00 - 09:30 0.50 DRILL P PROD1 MAKE UP TOP DRIVE - ACAL BASE LINE TEST - BLOW DOWN TOP DRIVE 09:30 - 10:30 1.00 DRILL P PROD1 CONTINUE RIH FROM 7988' TO 9812' 10:30 - 11 :00 0.50 DRILL P PROD1 WASH FROM 9812' TO 9870' - MAD PASS - NO FILL NO PROBLEMS 11 :00 - 00:00 13.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 9870' TO 10190' - WOB 50K- RPM 50 - TO 8K ON BTM - 7K OFF BTM - GPM 480 - PP 2850 ON BTM - 2650 OFF BTM - PU 280K - SO 240K - ROT 258K 3/31/2003 00:00 - 00:00 24.00 DRILL P PROD1 DIRECTIONAL DRILL FROM 10190' TO 10912' WOB 35K TO 55K - RPM 55 - TO ON BTM 9K - OFF BTM 8K - GPM 490 - PP ON BTM 2950 - OFF BTM 2650 - PU 290K - SO 235K - ROT 260K 4/1/2003 00:00 - 04:30 4.50 DRILL P PROD1 Drilled 8 1/2" Directional Hole By Rotating From 10,912' to 11,058' TD. WOB Rotating 55,000# - RPM 67, Motor RPM 139, Torque Off Bottom 7,000 ft / Ibs - On Bottom 8,000 ft / Ibs, Pump Rate 480 gpm, SPP Off Bottom 2,650 psi, On Bottom 2,750 psi. String Weight Up 290,000#, String Weight Down 240,000#, String Weight Rotating 265,000# 04:30 - 06:30 2.00 DRILL P PROD1 Pumped and Circulated Hi-Vis Sweep, Pump Rate 480 gpm, 2,700 psi. Circulated 2 x Bottoms Up, Rotated and Reciprocated while Circulating. RPM 75, String Weight Up 290,000#, String Weight Down 240,000#, String Weight Rotating 265,000#. Flow Checked Well, Static. 06:30 - 09:00 2.50 DRILL P PROD1 Made Wiper Trip (Wet) From 11,058' To Window At 8,284'. Maximum Overpull 20,000#, Average Drag 10,000# - No Problems 09:00 - 09:30 0.50 DRILL P PROD1 Serviced Rig, Flow Checked Well, Static. 09:30 - 10:30 1.00 DRILL P PROD1 RIH after Wiper Trip From 8,276' - Connect Top Drive And As Precaution Wash Last Stand To Bottom At 11,058' - No Problems On Trip 10:30 -14:30 4.00 DRILL P PROD1 Pumped and Circulated Hi-Vis Sweep, Pump Rate 480 gpm, 2,700 psi. Circulated 4 x Bottoms Up, Rotated and Reciprocated while Circulating. RPM 75, String Weight Up 290,000#, String Weight Down 240,000#, String Weight Rotating 265,000#. Flow Checked Well, Static - Spot 200 bbl. Liner Running Pill - Flow Checked Well, Static 14:30 - 16:00 1.50 DRILL P PROD1 Held PJSM - POH (Wet) w/ 81/2" Directional BHA On 5" DP From 11,058' To 8,278' - With No Hole Problems Over Pull Maximum At 20,000# Average Drag 10,000# 16:00 - 16:30 0.50 DRILL P PROD1 Monitor Well Bore (Static) - Pump Dry Job - Blow Down Tesco Top Drive - Wash And Clean Rig Floor 16:30 -19:30 3.00 DRILL P PROD1 Held PJSM - POH w/ 81/2" Directional BHA On 5" DP From 8,278' To 845' 19:30 - 21 :30 2.00 DRILL P PROD1 Held PJSM - Lay Down Directional BHA - Laid Down 20 Joints 5" HWDP, Daily Hyd. Drilling Jars, 2 x Non Mag Flex Drill Collars 21 :30 - 22:30 1.00 DRILL P PROD1 Held PJSM For Radioactive Sources - Pulled BHA To Rig Floor And Removed Sources - Down Load MWD Data 22:30 - 23:00 0.50 DRILL P PROD1 Held PJSM - POOH And Laid Down Remainder Of BHA 1 Flex Drill Collar, FEMWD Printed: 4/8/2003 8:58:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) BF>E><PLG>FRATPIG1N Oþerati.ons SummélryReport 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 4/1/2003 22:30 - 23:00 From - To Hours Task Code NPT Phase PROD1 4/2/2003 23:00 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 02:30 02:00 - 07:30 07:30 - 09:00 09:00 - 10:30 10:30 - 14:30 14:30 - 16:00 16:00 - 18:00 18:00 - 18:30 0.50 DRILL P 0.50 DRILL P 0.50 CASE P 2.00 CASE P 0.50 CASE P 5.50 CASE P 1.50 CASE P 1.50 CASE P 4.00 CASE P 1.50 CASE P 2.00 CASE P 0.50 CASE P PROD1 CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Description of Operations TM-SLD-ACAL-CTN-DM-DGR-EWR-PWD, Integral Blade Stab, And Float Sub - Removed Hughes Bit And Laid Down Sperry Mud Motor. Held PJSM - Cleared Rig Floor Of 81/2" Drilling Tools Held PJSM - Rigged Up Casing Tools And Equipment Held PJSM - Rigged Up Casing Tools And Equipment Held Safety Meeting With All Personal Regarding 4 1/2" Liner Running Operation P I U And Made Up 67 Jts, 4 1/2" 12.6# L-80 13 Cr Liner. P I U Shoe Track And Bakerlocked, Make Up Torque At 8,560 ftllbs - Verified Floats Working, RIH With 9 Joints 4 1/2" Liner, PI U 2 Marker Joints, Continue To RIH wi 67 Total Jts. Held PJSM - M I U Baker Flex Lock Liner Hanger, ZXP Packer wi HRD Setting Tool, Liner Tie Back Sleeve, And Running Tool - Mix And Pour Gel Into Liner Running Tool And Allow Time For Set Up - Rig Down Casing Tongs RIH w/1 Stand 5" Drill Pipe From Mast - Install Head Pin And Circulate 4 1/2" Liner Volume At 7 BPM With 600 Psi. - Recorded Liner Weights- String Weight Up 90,000#, String Weight Down 85,000#, Block Weight 52,000# - Extend Out Tesco Top Drive Change Out Bales And Elevators - Rig Down Compensator With Casing Tools And Equipment - Clear Rig Floor Held PJSM RIH wi 67 Jts, 41/2" 12.6# 13 Cr Liner On 5" Drill Pipe From 3,020' To 8,252' - Recorded Pick Up Slack Off Weights And Filled 5" Drill Pipe Every 10 Stands Stand Depth Up Weight Down Weight 1 3,020' 90K 85K 10 3,867' 110K 100K 20 4,807' 120K 120K 30 5,747' 145K 145K 40 6,687' 163K 160K 50 7,627' 180K 180K 56 8,252' 190K 190K Held PJSM MIU Top Drive Circulate Liner Volume And Annular Volume - Pump Rate 9 BPM With 850 Psi. String Weight Up 190,000#, String Weight Down 190,000#, Rotating Weight 190,000# - RPM 15 Torque 1,100 ftllbs - Held PJSM - MIU Cement Head With 5" DP Pup Joint (10') Safety Valve - Place On Pipe Lay Down Machine - Rig Up Line To Fill 5" Drill Pipe On The Fly In Open Hole Section - Blow Thru Cement Lines And Stand Pipe Manifold - Rig Up Cement Head Manifold And Wash Up Line Held PJSM RIH wi 67 Jts, 4 1/2" 12.6 lb. 13 Chrome Liner On 5" Drill Pipe From 8,252' To 11,032' With No Problems - Fill 5" Drill Pipe On The Fly Pick Up Cementing Head And Make Up To Tesco Top Drive- Install Manifold And Circulating Lines - Secure With Safety Lines - Work Casing String And Establish Circulation - Tag Bottom At 11,058' With No Problems. 4-112" Liner Set As Follows: Item Length Top At Printed: 4/8/2003 8:58:52 AM ) ) Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Date From - To Hours Task Code NPT Phase 4/2/2003 18:00 - 18:30 CaMP 0.50 CASE P 18:30 - 21:15 CaMP 2.75 CASE P 21 :15 - 23:00 1.75 CEMT P CaMP Spud Date: 3/18/2003 End: 4/6/2003 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Description of Operations Reamer Shoe 1 Jt 4-1/2" 12.6# L-80 Hydril563 Lnr Float Collar 1 Jt 4-1/2" 12.6# L-80 Hydril563 Lnr Latch Collar 7 Jts 4-1/2" 12.6# L-80 Hydril 563 Lnr 4-1/2" 12.6# L-80 Hydril563 Mkr Jt 4-1/2" 12.6# L-80 Hydril563 Mkr Jt 2.89' 42.37' 1.60' 42.37' 1.72' 296.63' 19.84' 19.81' 58 Jts 4-1/2" 12.6# L-80 Hydril 563 Lnr 2,455.19' Cross Over Bushing 5.24' Liner Hanger 7.42' RS Nipple 2.83' ZXP Packer 7.64' Tie Back Sleeve 10.97' Stage Up Pump Rates as Follows: Rate Pressure 5.0 BPM 640 psi 8.0 BPM 1,300 psi 10.0 BPM 1,730 psi 11,055.11' 11,012.74' 11,011.14' 10,968.77' 10,967.05' 10,670.42' 10,650.58' 10,630.77' 8,175.58' 8,170.34' 8,162.92' 8,160.09' 8,152.45' 8,141.48' String Weight Up 252,000#, String Weight Down 228,000# Continue To Circulate to Cool and Condition the Hole While Reciprocating Casing String Continuously - Held PJSM wi Dowell, Truck Drivers and Rig Crew - Batch Mix Cement And Continue To Reciprocate And Circulate At 10 BPM With 1,730 Psi. Switched Over To Dowell. Pumped 5 bbls Of Fresh Water 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, 720 psi. Pumped 175 bbls (818 sx) 15.8 ppg Latex Cement wi 0.35% BWOC Dispersant, 3% BWOC Retarder, 3.00 gal/sk Expanding Agent, 0.20 gal/sk Antifoam, 2.00 gal/sk GASBLOK. Pumped Cement At The Following Rates: Pumped Rate Pressure 5.0 bbls 4.00 bpm 654 psi 25.0 bbls 5.20 bpm 859 psi 50.0 bbls 5.20 bpm 854 psi 75.0 bbls 5.20 bpm 855 psi 100.0 bbls 5.20 bpm 832 psi 125.0 bbls 5.20 bpm 856 psi 150.0 bbls 5.20 bpm 840 psi 175.0 bbls 5.20 bpm 837 psi Cleaned Up Behind Plug, Dropped Drill Pipe Dart And Pumped Out Of Manifold wi 5 bbls Of Water At 3.00 bpm, 125 psi. Displaced wi 177.5 bbls Of Mud At The Following Rates: Pumped Rate Pressure 30.0 bbls 10.0 bpm 610 psi 60.0 bbls 11.0 bpm 740 psi 90.0 bbls 11.0 bpm 1,180 psi 120.0 bbls 11.0 bpm 1,950 psi slw'd Pmps to 3.5 bpm 440 psi Printed: 4/8/2003 8:58:52 AM ') ) Legal Well Name: 2-288/0-19 Common Well Name: 2-288/0-19 Spud Date: 3/18/2003 Event Name: REENTER+COMPLETE Start: 3/18/2003 End: 4/6/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 4/6/2003 Rig Name: DOYON 15 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/2/2003 21:15 - 23:00 1.75 CEMT P CaMP Drill Pipe Dart Hit wI 135.1 bbls Pumped, Pressure Increased To 1,200 psi, Wiper Plug Sheared, Pressure Dropped to 515 psi, Increased Rate 150.0 bbls 11.0 bpm 2,610 psi 160.0 bbls 11.0 bpm 2,744 psi slw'd Pmps to 3.5 bpm 1 ,160 psi 170.0 bbls 3.5 bpm 1,390 psi 175.0 bbls 3.5 bpm 1 ,460 psi Wiper Plug Bumped wI 178 bbls Pumped. Cement in Place @ 22:48 Hrs. 23:00 - 23:30 0.50 CASE P CaMP Increased Pressure To 3,000 psi To Set Liner Hanger, Slacked Off On Liner To Confirm Hanger Set - Pressured Up To 4,000 psi To Release Running Tool From Liner, Bled Pressure Off And Check Floats (Floats Held). P I U On DP (212K) Confirm Running Tool Released - Continue To P I U to Expose Setting Dogs. Rotate And Set Down On Liner Top wI 42,000# and Observed ZXP Packer Set. Held PJSM. Closed Annular and Pressure Tested Liner Top And Casing To 2,000 psi f/5 minutes. OK. Bled Down Pressure And Opened Annular Pressure Up On Liner To 1,000 psi, PI U On Drill Pipe 10', Observed Pressure Drop To 650 psi To Reconfirm Liner Running Tool Released from Liner. 23:30 - 00:00 0.50 CASE P CaMP Circulated Bottoms Up To Clean Possible Cement Out Of Hole. Pump Rate 14 bpm, 2,770 psi. 4/3/2003 00:00 - 00:45 0.75 CASE P CaMP Continue To Circulate Bottoms Up To Clean Possible Cement Out Of Hole. Pump Rate 14 bpm, 2,770 psi. Circulated Back 58 bbls Of Contaminated Mud Push Spacer. 00:45 - 02: 15 1.50 CASE P CaMP Held PJSM wI Truck Drivers And Rig Crew - Displaced The Well wI Clean Seawater. Pump Rate 14 bpm, 2,420 psi. - 68 bbls Hi-Vis Pill - Displace With 768 bbls. Sea Water 02:15 - 03:30 1.25 CASE P CaMP Held PJSM - Break And Lay Down Baker Plug Dropping Head And Circulating Lines - Clear Rig Floor - Blow Down Circulating Lines 03:30 - 10:30 7.00 CASE P CaMP Held PJSM - POH wI Baker Liner Running Tool Laying Down 5" Drill Pipe From 8,141' 10:30 - 11 :00 0.50 CASE P CaMP Lay Down Baker Running Tool And Clear Rig Floor 11 :00 - 12:00 1.00 BOPSUR P CaMP Hold Pre-Job Safety Meeting - Remove Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Flush Lines With Water 12:00 - 13:00 1.00 BOPSURN DFAL CaMP Test Plug Leaked - Pull Test Plug And Install New Seal- Reset Test Plug 13:00 - 17:00 4.00 BOPSUR P CaMP 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, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves, Manual And HCR Valves On The Choke And Kill Lines At 250 Psi. Low And 4,500 Psi. High - Perform Accumulator Test 17:00 - 17:30 0.50 BOPSUR P CaMP Hold Pre-Job Safety Meeting - Rig Down Testing Equipment - Remove Test Plug - Install Short Bowl Protector And Energize Lock Down Studs 17:30 - 18:00 0.50 BOPSUíP CaMP Held PJSM - Blow Down Choke Manifold, Kill And Choke Lines Printed: 4/8/2003 8:58:52 AM ') ) BPEXPLORA TION OperationsSu mmary . Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Date From -To Hours Task Code NPT Phase 4/3/2003 18:00 -19:00 19:00 - 20:30 20:30 - 22:30 22:30 - 23:30 1.00 CASE P 1.50 CASE P 2.00 CASE P 1.00 CASE P COMP COMP COMP COMP 4/4/2003 23:30 - 00:00 00:00 - 01 :00 COMP COMP 0.50 BOPSURP 1.00 RUNCOrvP 01 :00 - 01 :30 0.50 RUNCOrvP COMP 01:30 -12:00 10.50 RUNCOrvP COMP 12:00 - 13:00 1.00 RUNCOrvP COMP 13:00 - 13:30 0.50 RUNCOrvP COMP 13:30 -16:00 2.50 RUNCOrvP COMP 16:00 - 17:30 1.50 RUNCOrvP COMP 17:30 - 19:00 1.50 RUNCOIVN SFAL COMP 19:00 - 20:30 1.50 RUNCOrvP COMP 20:30 - 21 :30 1.00 RUNCOrvP COMP Page 11 of 13 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Description of Operations Held PJSM - RIH With 23 Stands Of 5" Drill Pipe From Mast Held PJSM - Slip And Cut 60 Feet 1 3/8" Drilling Line Held PJSM - POH Laying Down 5" Drill Pipe Held PJSM - Close Blind Rams - Test 9 5/8" Casing And 4 1/2" Liner To 3,500 Psi - Hold For 30 Minutes And Record On Circle Chart - Test Good Held PJSM - Pick Up Test Joint And Remove Wear Bushing Held PJSM - Rig Up Tubing Tongs, Compensator, And Other Completion Running Equipment Hold Pre-Job Safety Meeting With Rig Crews, Service Hands Regarding 4 1/2" Completion Running Operation Pick Up And RIH With 4 1/2" Completion Per Well Program - Make Up Tail Pipe Assembly - Baker Lock And Torque Vam Ace Connections Below Baker S-3 Packer To 3,650 ftIIbs - Pick Up "X" Nipple Assembly Verify D-16 Plug Installed - Pick Up And RIH With 152 Joints Of 41/2" 12.61b 13 Chrome Vam Ace Tubing - Make Up Torque At 3,620 ft/lbs - Test Completion String Every 50 Joints To 3,500 Psi For 10 Minutes Held PJSM wI Halliburton and Drilling Crew on Rigging Up and Running Control Line. R I U Control Line Equipment. M I U SSSV Assembly, M I U Control Lines and Tested Same to 5,000 psi fl 15 minutes, OK. Ran 4-1/2" 12.6# 13Cr Vam ACE Tubing Total Joints Run 187 String Weight Up 150,000#, String Weight Down 145,000#. M I U Jts 188 & 189, Tagged Up at 8,176' wI 9' of Jt 189. Held PJSM. Broke out and LID Jts 189,188 & 187. M I U Pup Jt - Length 6.20', M I U Jt 187, M I U Tubing Hanger and Landing Jt. M I U Dual Continous Running Control Lines to Tubing Hanger. Have Problems With Swedge Lock Fittings Making Up To Control Port M I U Dual Continous Running Control Lines to Tubing Hanger. Tested Same to 5,000 psi fl 15 minutes, OK. Drained BOP Stack, RIH and Landed Tubing Hanger Energize Lock Down Studs. M I U Circulating Head and Tested Tubing and Hanger to 3,500 psi fl 10 minutes, OK. Completion Equipment Set At The Following Depths: Item Length Depth XN Nipple Assembly 22.37' 8,149.32' X Nipple Assembly 20.93' 8,128.39' S-3 Packer Assembly 24.54' 8,103.85' X Nipple Assembly 20.97' 8,082.88' 1 Jt 4-1/2" 12.6# 13Cr Vam Ace Tbg 39.87' 8,043.01' #1 GLM Assembly 28.41' 8,014.60' 16 Jts 4-1/2" 12.6# 13CrVam Ace Tbg 669.39' 7,345.21' #2 GLM Assembly 28.37' 7,316.84' 17 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 713.76' 6,603.08' #3 GLM Assembly 28.41' 6,574.67' 18 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 755.71' 5,818.96' #4 GLM Assembly 28.38' 5,790.58' 17 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 713.92' 5,076.66' #5 GLM Assembly 28.44' 5,048.22' 35 Jts 4-1/2" 12.6# 13Cr Vam Ace Tbg 1,467.73' 3,580.49' Printed: 4/8/2003 8:58:52 AM ) ) BP EXPLORA TIQN Operations Summary Report Page 12 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/4/2003 20:30 - 21 :30 1.00 RUNCOrvP COMP #6 GLM Assembly w/ DCR Valve 28.46' 3,552.03' 48 Jts 4-1/2" 12.6# 13CrVam Ace Tbg 2,013.47' 1,538.56' SSSV Assembly 22.53' 1,516.03' 34 Jts 4-1/2" 12.6# 13CrVam Ace Tbg 1,427.71' 88.32' 4-1/2" 12.6# 13Cr Vam Ace Pup Jt 6.20' 82.12' 1 Jt 4-1/2" 12.6# 13Cr Vam Ace Tbg 42.00' 40.12' Tubing Hanger 3.22' 36.90' 21 :30 - 22:00 0.50 RUNCOrvP COMP Held PJSM - Rig Up Haliburton Slick Line Unit And Pulling Tools 22:00 - 22:30 0.50 RUNCOrvP COMP Slick Line Run NO.1 - RIH With Tools And Pull Dummy Valve In SVLN - POH And Break Down Dummy Valve Retrieving Tools 22:30 - 23:30 1.00 RUNCOrvP COMP Slick Line Run NO.2 - Make Up Equalizer Tools - RIH To D-16 Test Plug And Equalize - POH - Break And Lay Down Tools 23:30 - 00:00 0.50 RUNCOrvP COMP Slick Line Run No.3 - Make Up Pulling Tools For D-16 Plug - RIH 4/5/2003 00:00 - 01 :30 1.50 RUNCOrvP COMP Slick Line Run NO.3 Continued RIH And Latch Up D 16 Plug - POH With D-16 Plug - Lay Down Plug And Break Down Tools 01 :30 - 03:00 1.50 RUNCOrvP COMP Slick Line Run No.4 - Make Up 3.625 Drift And Sample Bailer - RIH To 10,331' - POH - Break And Lay Down Tools 03:00 - 04:30 1.50 RUNCOrvP COMP Slick Line Run NO.5 - Make Up RHC-M Plug And Running Tools - RIH With RHC-M Plug And Set In "XN" Nipple 04:30 - 05:30 1.00 RUNCOrvP COMP Slick Line Run NO.6 - Make Up Check Set Tool - RIH And Verify That RHC-M Plug Set In "XN" Nipple At 8,159' - POH - Break And Lay Down Tools 05:30 - 06:00 0.50 RUNCOrvP COMP Slick Line Run NO.7 - Make Up Setting Tool And Dummy Sleeve - RIH And Set Dummy Sleeve In SVLN Valve At 1,525' - Test Control Lines And Dummy Sleeve - Shear Off Of Sleeve And POH - Break And Lay Down Tools 06:00 - 06:30 0.50 RUNCOrvP COMP Held PJSM - Rig Down Haliburton Slick Line Unit - Clear Rig Floor 06:30 - 07:30 1.00 RUNCOrvP COMP Held PJSM - Rig Down Tubing Running Equipment - Change Out Bales On Top Drive To Short Set - Rig Up To Reverse Circulate 07:30 - 12:30 5.00 RUNCOrvP COMP Hold Pre Job Safety Meeting With Truck Drivers And Rig Personnel - Reverse Circulate 20 Barrels Hi-Vis Spacer, 60 Barrels Casing Cleaner, 25 Barrels Hi-Vis Spacer, 200 Barrels Sea Water, 200 Barrels Sea Water With Corrosion Inhibitor, 180 Barrels Sea Water 12:30 - 14:30 2.00 RUNCOrvP COMP Held PJSM - Drop Ball And Rod & Allow To Seat - Pressure Up On Tubing String To 2,500 Psi. To Set Packer - Continue To Pressure Up Down Tubing To 3,500 Psi. And Test For 30 Minutes Record On Circle Chart - Bleed Back Tubing Pressure To 1,500 Psi. And Test Annulus To 3,000 Psi. For 30 Minutes - Bleed Off Tubing Pressure Quickly And Shear DCR Valve - Pump Down The Tubing And Annulus To Verify That DCR Valve Sheared (OK) - Back Out 4 1/2" Landing Joint And Lay Down 14:30 - 15:30 1.00 BOPSURP COMP Held PJSM - Set Two Way Check Valve And Test From Below To 1,000 Psi. (Test Good) - Blow Down Stand Pipe, Choke Manifold, Choke And Kill Lines 15:30 - 20:30 5.00 BOPSURP COMP Held PJSM - Nipple Down BOP And Related Equipment 20:30 - 21 :30 1.00 WHSUR P COMP Held PJSM - Clean Off Tubing Hanger - Terminate DHCV Printed: 4/8/2003 8:58:52 AM ) ) mREt~F>LøFR/¥"'I()N Operations ·Sunlmary ··Repórt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-288/0-19 2-288/0-19 REENTER+COMPLETE DOYON DRILLING INC. DOYON 15 Start: 3/18/2003 Rig Release: 4/6/2003 Rig Number: Spud Date: 3/18/2003 End: 4/6/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/5/2003 20:30 - 21 :30 1.00 WHSUR P COMP Ports And Test Control Line's To 5,000 Psi. (Test Good) 21 :30 - 00:00 2.50 WHSUR P COMP Held PJSM - Orient And Nipple Up Cameron Adaptor Flange And Production Tree - Test Adaptor Flange Void To 5,000 Psi. (Test Good) 4/6/2003 00:00 - 01 :00 1.00 WHSUR P COMP Held PJSM - Rig Up To Test Production Tree - Close Accuator On Wing Valve 01 :00 - 02:00 1.00 WHSUB P COMP Held PJSM - Test Production Tree To 5,000 Psi. For 30 Minutes 02:00 - 03:00 1.00 WHSUR P COMP Set Clocks Ahead 1 Hour Due To Day Light Savings Time Change 03:00 - 04:30 1.50 WHSUR P COMP Held PJSM - Rig Up DSM Lubricator And Pull Two Way Check Valve - Rig Down Lubricator And Clear Rig Floor 04:30 - 05:00 0.50 WHSUR P COMP Held PJSM - Rig Up Circulating Lines And Equipment 05:00 - 06:30 1.50 WHSUR P COMP Held PJSM - Test Little Red Services Surface Lines And Equipment At 1,000 Psi. (Test Good) - Pump 105 Barrels Of Diesel At 3 BPM With 420 Psi. 06:30 - 07:30 1.00 WHSUR P COMP Held PJSM - U-Tube Diesel From Annulus To Tubing 07:30 - 08:00 0.50 WHSUR P COMP Held PJSM - Suck Back Diesel In U-Tube Lines - Drain And Rig Down Same 08:00 - 09:00 1.00 WHSUR P COMP Held PJSM - Pick Up T-Bar And Install Back Pressure Valve - Install Tree Cap And Test Back Pressure Valve From Below At 1,000 Psi. For 5 Minutes 09:00 - 10:00 1.00 WHSUR P COMP Held PJSM - Remove Secondary Annulus Valve And Install Flange - Install Tree And Annulus Gauges - Secure Well- Clean Up Well House And Cellar Area "NOTE" - Rig Released From Well Work On 2-28 B / 0-19 At 10:00 Hours On 4-06-2003 Printed: 4/8/2003 8:58:52 AM ') ) Well: Field: API: Permit: 2-28B/O-19 Endicott Field I Endicott Pool 50-029-21847-02 203-006 Accept: Spud: Release: Rig: 03-18-03 03-25-03 04-06-03 Doyon 15 POST-RIG WORK 04/09/03 RU DSM AND PULL BPV. PT LUB AND TEST WIRE. PULL DSSSV @ 14931 WLM. RIH WITH 3.5" BG AND 2" RB TO 81211 WLM. LATCH AND PULL BALL & ROD. RIH WI 4.5" OM-1 & 1.625" JDC TO STATION # 5 @ 50311 WLM. LATCH AND PULL DGLV RIH WITH SAME TO STATION # 6 @ 3537' WLM LATCH AND PULL SHEAR VALVE. RIH WITH SAME TO STATION # 6 AND SET GENERIC GLV (1/4" PORT, 1500# TRO) RIH WITH SAME TO STATION # 5 AND SET GENERIC ORIFICE ( 5/16" PORT) RIH WITH 4.5" GS TO 8126' WLM LATCH AND PULL RHC PLUG. RIH WITH 2.80 TS AND 2.2" X 101 SPENT DUMMY GUN. TAG STICKY BOTTOM @ 107901 WLM. 04/11/03 RIH WITH 3" JS NOZZLE ON WEATHERFORD MHA. BEGIN JETTING AT 8200 USING C-H20 WITH FLO-PRO SWEEPS. TAG UP AT 10828 (UP). UNABLE TO JET THROUGH. POH FOR MOTOR AND MILL. RIH WI WEATHERFORD 2 7/8" MOTOR AND 3.70" THREE BLADE JUNK MILL. MILL THRU CEMENT STRINGERS FROM 108281 - 109671 (MD). CONFIRM CEMENT IN RETURNS. FLO-PRO SWEEPS OFF BTM, PUMP BTMS UP WI SEA WATER & LAY IN DIESEL FROM 85001 TO SURFACE. MILL MEASURED 3.685" AT END OF JOB. 04/12/03 RIH WI RST TOOLSTRING. LOGGED PRIMARY DEPTH CONTROL PASS FROM TD TO 9000 FT. PRIOR TO ACTIVATING MINITRON IN INTERVAL. TAGGED TD @ 10977' MD (REF SPERRY SUN). LOGGED RST -SIGMA PASSES (REF PRIMARY DEPTH CONTROL) FROM TD TO 10000 FT. SENT LOG DATA TO TOWN FOR PERF DEPTH CONFIRMATION. POOH. RIH WI 10 FT. GUN AND PERFORATE UNDERBALANCED FROM 10796' TO 108061 (REF. SPERRY SUN) AS PER TOWN REQUEST. FLOWED WELL FOR 5 MINUTES AT 30 BEANS ON CHOKE. SHUT IN WELL AND TOOK PRESSURE STOPS WI MEMORY TOOL BOTTOM @ 106501 MD=100001 TVDSS AND 10517' M D = 99001 TVDSS. Legal Name: 2-288/0-19 Common Name: 2-288/0-19 Test Date 3/26/2003 Test Type FIT Test Depth (TMD) 8,354.0 (ft) BPEXPLQRATION Leak-Qff"FestSummary Test.Depth··{TVD) 8,300.0 (ft) AMW 9.90 (ppg) SurfacePtessure LeakOffPreSsUr~ (BHP) 1,000 (psi) 5,269 (psi) EMW 12.22 (ppg) ~ Printed: 418/2003 8:58:45 AM ') ) aQ3-öð0 22-Apr-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2-288 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,279.45' MD Window / Kickoff Survey: 8,284.00 I MD (if applicable) Projected Survey: 11,058.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECE,\\JEO ~PR 2. 9 2.003 , ..... ì~1mts~n Ai,\ &. Gas cons. \.i01 A\as\(a V11 Mt'hoœge Attachment(s) " Sperry-Sun Drilling Services Alaska State Plane 3 BPXA Endicott DI-MPI 2-28/P-19 - 2-288/0-19 ~. Job No. AKMW0002347857, Survey Report 15 April, 2003 Your Ref: AP/500292184702 Surface Coordinates: 5982473.39 N, 258966.93 E (700 21' 09.9111" N, 1470 57' 26. 7039" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 3 Surface Coordinates relative to Project Coordinates: 982473.39 N, 241033.07 W (Grid) Surface Coordinates relative to Structure Reference: 3207.81 N, 2183.73 E (True) Kelly Bushing: 54. 85ft above Mean Sea Level Elevation relative to Project Elevation: 54. 85ft Elevation relative to Structure Reference: 54. 85ft ~ spef""''-'y-sul! DRILLING seRVlc::es A Halliburton Company Survey Ref: svy741 ". Sperry-Sun Drilling Services Survey Report for Endicott DI·MPI- 2-28IP-19 - 2-288/0-19 . Your Ref: API 500292184702 Job No. AKMWOOO2347857, BPXA Alaska 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) 8279.45 12.930 134.660 8199.24 8254.09 173.468 161.82 E 5982294.81 N 259123.08 E 32.44 Tie-on Point MWD Magnetic 8284.00 12.920 134.710 8203.68 8258.53 174.188 162.54 E 5982294.07 N 259123.78 E 0.331 32.62 Window Point 8366.57 14.440 103.040 8284.01 8338.86 183.01 8 179.15E 5982284.71 N 259140.10 E 9.136 41.12 8403.77 17.700 93.070 8319.76 8374.61 184.36 8 189.32 E 5982283.04 N 259150.23 E 11 .452 48.66 8435.85 20.550 85.130 8350.07 8404.92 184.148 199.81 E 5982282.91 N 259160.71 E 12.010 57.36 8463.78 23.070 78.350 8376.01 8430.86 182.628 210.06 E 5982284.11 N 259171.00 E 12.744 66.61 8498.22 25.770 73.530 8407.36 8462.21 179.138 223.85 E 5982287.15 N 259184.90 E 9.738 79.90 ~/ 8531.04 27.900 70.070 8436.65 8491.50 174.498 237.91 E 5982291.33 N 259199.10 E 8.045 94.07 8561.47 29.790 67.500 8463.31 8518.16 169.178 251.59 E 5982296.21 N 259212.95 E 7.427 108.32 8597.21 31.650 67.630 8494.03 8548.88 162.21 8 268.46 E 5982302.63 N 259230.04 E 5.208 126.12 8628.64 32.790 70.090 8520.62 8575.47 156.17 8 284.09 E 5982308.16 N 259245.85 E 5.528 142.38 8660.31 33.950 71.580 8547.07 8601.92 150.458 300.55 E 5982313.34 N 259262.48 E 4.484 159.12 8691.60 34.990 75.030 8572.87 8627.72 145.388 317.51 E 5982317.88 N 259279.60 E 7.069 175.91 8722.52 36.660 74.860 8597.94 8652.79 140.67 8 334.98 E 5982322.01 N 259297.21 E 5.411 192.91 8750.39 38.250 74.720 8620.06 8674.91 136.238 351.34 E 5982325.93 N 259313.70 E 5.713 208.84 8784.55 40.790 75.830 8646.41 8701.26 130.71 8 372.36 E 5982330.77 N 259334.89 E 7.718 229.21 8816.90 42.170 77 .550 8670.64 8725.49 125.788 393.21 E 5982335.03 N 259355.89 E 5.531 249.09 8844.30 43.630 79.140 8690.72 8745.57 122.028 411 .48 E 5982338.20 N 259374.27 E 6.633 266.20 8880.12 44.840 83.350 8716.39 8771.24 118.228 436.16 E 5982341.20 N 259399.06 E 8.866 288.56 8913.10 46.230 87.540 8739.49 8794.34 116.378 459.62 E 5982342.30 N 259422.56 E 9.997 308.81 8940.86 46.940 89.170 8758.57 8813.42 115.798 479.77 E 5982342.23 N 259442.73 E 4.973 325.62 9041.46 45.880 88.890 8827.93 8882.78 114.568 552.62 E 5982341.11 N 259515.58 E 1.073 385.90 9138.06 42.310 91.630 8897.31 8952.16 114.81 8 619.82 E 5982338.70 N 259582.73 E 4.189 440.69 9231.83 39.520 90.830 8968.16 9023.01 116.148 681.21 E 5982335.39 N 259644.05 E 3.027 490.13 9330.56 37.970 87.130 9045.17 9100.02 115.078 742.97 E 5982334.47 N 259705.81 E 2.822 541.23 9424.37 36.450 83.200 9119.89 9174.74 110.338 799.47 E 5982337.40 N 259762.44 E 3.007 590.17 9456.63 38.040 82.280 9145.57 9200.42 107.868 818.84 E 5982339.24 N 259781.87 E 5.222 607.42 -- 9519.56 39,600 82.500 9194.60 9249.45 102.648 857.94 E 5982343.21 N 259821.12 E 2.489 642.40 9615.21 41 ,300 85.770 9267.39 9322.24 96.33 8 919.65 E 598234 7.53 N 259883.01 E 2.842 696.49 9710.48 41 ,380 92.350 9338.96 9393.81 95.30 8 982.50 E 5982346.53 N 259945.85 E 4.561 748.47 9805.49 40.170 96.080 9410.92 9465.77 99.83 8 1044.36 E 5982340.01 N 260007.54 E 2.862 796.44 9839.61 39.230 90.680 9437.17 9492.02 101.138 1066.10E 5982338.02 N 260029.22 E 10.475 813.47 9872.12 40.290 85.610 9462.17 9517.02 100.448 1086.86 E 5982338.03 N 260050.00 E 10.491 830.84 9904.39 42.590 85.900 9486.36 9541.21 98.87 8 1108.16 E 5982338.93 N 260071.34 E 7.152 849.17 9937.12 44.600 85.770 9510.07 9564.92 97.23 8 1130.67 E 5982339.84 N 260093.88 E 6.147 868.51 9967.14 45.920 84.460 9531.20 9586.05 95.41 8 1151.91E 5982340.97 N 260115.18 E 5.380 886.93 9998.69 46.610 80.940 9553.01 9607.86 92.51 8 1174.52 E 5982343.15 N 260137.86 E 8.352 907.08 10029.08 48.060 77.340 9573.61 9628.46 88.29 8 1196.45 E 5982346.65 N 260159.92 E 9.931 927.45 10063.93 49.550 73.260 9596.57 9651.42 81.63 8 1221.81 E 5982352.50 N 260185.48 E 9.791 952.01 10096.09 49.640 70.840 9617.41 9672.26 74.088 1245.10 E 5982359.29 N 260209.00 E 5.737 975.40 -------- 15 Aprif, 2003 - 11:37 Page 2 of 4 DrillQuest 3.03.02.004 DrillQuest 3.03.02.004 Page 3 of4 15 April, 2003 - 11:37 Tie-on Point Window Point Projected Survey 161.82E 162.54 E 1867.62 E 173.46 S 174.18S 121 .88 N 8254.09 8258.53 10373.35 8279.45 8284.00 11058.00 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) ~ Comments Based upon Minimum Curvature type calculations, at a Measured Depth of 11058.000., The Bottom Hole Displacement is 1871.59ft., in the Direction of 86.266° (True). Magnetic Declination at Surface is 26.3300(21-Mar-03) The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 54.850° (True). Sperry-Sun Drilling Services Survey Report for Endicott DI-MPI- 2-28/P-19 - 2-288/0-19 Your Ref: API 500292184702 Job No. AKMWOO02347857, BPXA Alaska 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) 10128.27 50.060 69.490 9638.16 9693.01 65.74 S 1268.24 E 5982366.89 N 260232.39 E 3.462 999.12 10161.62 49.820 69.340 9659.63 9714.48 56.76 S 1292.13 E 5982375.09 N 260256.57 E 0.798 1023.83 10194.90 49.740 68.180 9681.12 9735.97 47.56 S 1315.82 E 5982383.53 N 260280.53 E 2.672 1048.50 10224.70 49.660 68.470 9700.39 9755.24 39.16 S 1336.94 E 5982391.24 N 260301.91 E 0.789 1070.60 10258.72 49.320 67.500 9722.49 9777 .34 29.47 S 1360.92 E 5982400.16 N 260326.19 E 2.387 1095.78 10319.32 48.670 66.620 9762.25 9817.10 11.64 S 1403.03 E 5982416.62 N 260368.86 E 1.533 1140.48 10350.79 47.940 67.940 9783.19 9838.04 2.57 S 1424.70 E 5982424.99 N 260390.81 E 3.897 1163.43 10445.33 44.690 73.310 9848.50 9903.35 20.18 N 1489.11 E 5982445.65 N 260455.92 E 5.354 1229.19 '-'" 10511.15 43.130 72.570 9895.92 9950.77 33.56 N 1532.75 E 5982457.63 N 260499.97 E 2.495 1272.58 10608.46 40.900 71.740 9968.21 10023.06 53.51 N 1594.75 E 5982475.57 N 260562.58 E 2.362 1334.75 10704.84 41.520 76.410 10040.74 10095.59 70.91 N 1655.78 E 5982490.99 N 260624.13 E 3.256 1394.67 10800.48 39.120 77.150 10113.65 10168.50 85.07 N 1716.01 E 5982503.21 N 260684.79 E 2.559 1452.07 10894.93 37.490 76.790 10187.77 10242.62 98.26 N 1773.05 E 5982514.56 N 260742.22 E 1.742 1506.30 10989.45 36.390 75.640 10263.31 10318.16 111 .79 N 1828.22 E 5982526.31 N 260797.80 E 1.374 1559.20 11058.00 36.390 75.640 10318.50 10373.35 121.88 N 1867.62 E 5982535.12 N 260837.50 E 0.000 1597.22 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. Sperry-Sun Drilling Services Survey Report for Endicott DI-MPI- 2-28/P-19 - 2-288/0-19 Your Ref: AP/500292184702 Job No. AKMW0002347857, BPXA Alaska State Plane 3 Survey tool program for 2-28/P-19 - 2-288/0-19 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8279.45 0.00 8279.45 8254.09 AK-1 BP _HG - BP High Accuracy Gyro(2-28/P-19) 8254.09 11058.00 10373.35 MWD Magnetic(2-28B/O-19) ~ '-' 15 April, 2003 - 11:37 Page 4 of4 DriflQuest 3.03.02.004 ) (QJ ~J~' $i.ð IF;C nJ ') ., u J: ,-,.... .91~ ! I I ~¡, ' [Æ~[Æ~~~!Æ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 202.42 Ms. Katie Nitzberg Endicott Staff Geologist BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Spacing Exception for Endicott 2-28BjO-19 Well Ms. Nitzberg: The Alaska Oil and Gas Conservation Commission ("Commission") has received your correspondence, dated March 10, 2003, requesting a spacing exception for drilling and completion of the Endicott 2-28BjO-192-28BjO-19 well. Well 2-28BjO-19 will be a producer in Subzones 2A and 2B of the Kekiktuk Formation. Nearby existing well 1-05 j 0-20 is a gas injector that is also completed in Subzone 2B of the Kekiktuk .Formation. Rule 3 of Conservation Order 202, which governs this area, states: "The pool may not be opened in a well closer than 1000 feet to any well opened to the poo1." The information you submitted indicates the interval intended for completion within 2-28B j 0-19 is approximately 960 feet horizontal distance and 490 ft. vertically from the 1- 05 j 0- 20 existing well. The separation between this proposed producer and the existing injector are substantively equivalent to the requirements of Rule 3 in Conservation Order No. 202. The Commission has determined drilling and completion of the Endicott 2- 28BjO-19 well will not promote waste, will enhance recovery, and hereby approves the drilling and completion of the well within Kekiktuk Subzones 2A and 2B as proposed pursuant to Rule 3 of Conservation Order No. 202. :~N~in AnC~,?f~' ~aska this 12fu day of ~arCh 2003. , ,/~~:~: .~~.c:1l~ ß-~ /~~ _ ~-- S~ Palin \~ Randy Ruedrich ,<$\0'> OIL ~ Commissioner Commissioner ,/, ~J}t1; \. 1'1' -~ /. ~ If' \ f1\ \ / / I ~ l .;' "'-, :.;~} \, . .;~ ,:.\"'- 1.. ~ ¡? '- " tj",I/"",~ '-. '.' -'~;' \ ( {, ".. nl "~ -~~ ""i ,<. ~ ,..,~:.?,A;"J ~ t. ! . ì~ -,":"\. ,~., .,'~~' .;\. t f-J lJ"""- ~ ~~·.;s '-':\""/\' .".~ H. I ~ '~) ~ \\~i{¡1~¡;~:~:) BY ORDER OF THE COMMISSION C~ C:-~J {ð\ e-::1'"t:-J æJ _ lro .,j J: I-~ ) f [Æ~rÆ~~~!Æ FRANK H. MURKOWSKI, GOVERNOR ~ AT/ASKA. ORAND GAS CONSERVATION COMMISSION 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 2-28B/0-19 BP Exploration (Alaska) Inc. Permit No: 203-006 Surface Location: 1944' SNL, 2240' WEL, SEC. 36, TI2N, RI6E, UM Bottomhole Location: 1832' SNL, 355' WEL, SEC. 36, T12N, R16E, 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 peID1it may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the COlllmission 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 ~~ day of February, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. jki6A-L/ $/ (/'~ 12. Distance to nearest property line 13. Distance to nearest well ADL 312828, 355' MD 1-03/P-16 is 576' away at 10275' MD 16. To be completed for deviated wells Kick Off Depth 8275' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couolina 4-1/2" 12.6# 13Cr Hydril 563 Hole 8-1/2" J'.. STATE OF ALASKA "') ALASK;, ··IL AND GAS CONSERVATION COMh,....jSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [J Exploratory [J Stratigraphic Test /I Development Oil [J Service [J Development Gas [J Single Zone [J Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan KBE = 55' Endicott Field I Endicott Pool 6. Property Designation ADL 034633 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-288/0-19 9. Approximate spud date 02126/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11025' MD /10324' TVD o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 45 Maximum surface 4173 psig, At total depth (TVD) 9750' / 5148 psig Setting Depth Top Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 2900' 8125' 8103' 11025' 10324' 954 cu ft Class 'G' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work [J Drill /I Redrill [J Re-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 1944' SNL, 2240' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1900' SNL, 686' WEL, SEC. 36, T12N, R16E, UM At total depth 1832' SNL, 355' WEL, SEC. 36, T12N, R16E, UM Number 2S100302630-277 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 1 0223 feet 1 0086 feet 9342 feet 9297 feet Length Plugs (measured) Abandonment Plug 9342' - 9680'; Whipstock at 9675'; Perf Abandonment Cement below Whipstock (03/01) 3 Bowspring Leafs at 10448' 3-1/2" tailpipe cut and dropped to bottom (03/01) Cemented MD TVD Junk (measured) Size Structural Conductor Su rface Intermediate Production Liner 92' 30" Driven 2465' 13-3/8" 3687 cu ft Permafrost 9605' 9-5/8" 575 cu ft Class 'G' 1144' 7" 517 cu ft Class 'G' 131' 2504' 131' 2503' 9644' 9383' - 9675' 9597' 9338' - 9627' RECEiV'E[) Perforation depth: measured None JAN 0 B 200~) true vertical Jì!aska OU & ~as Cons. Gommissiof: /I Filing Fee 0 Property Plat [J BOP Sketch [J Diverter Sketchg.tfu~lIiH~tprogram /I Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis [J Seabed Report /I 20 MC 25.050 Requirements None 20. Attachments Contact Engineer Name/Number: Walter Quay, 564-4178 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I hereby certify that the f:?rgOi, ~.s tr~e /~d correct to the best of my ~nOwl~~ge . Signed Fred Johnson II 14Lðf ~ Title Senior Dnlllng Engineer . ., ' .......:..,...,'.. :.,~i,: '::"i,,:,>, ··...··.·.·.....:~':F':'".::!:,"'i,:~~~;Uf8øníy::;:,~:,',},~..,!,::';":;:;";.'!:,'?.: Permit Number 20___ < - 0 0 .t: Conditions of Approval: Date I /7 / (j 3 Approved By Form 10-401 Rev. 12-01-85 API Number So - 02. 9 - ..2 / 'il'"'o/ > -' o.z.. ApprovgJ lat~ 50. 02021047-02 /f'/c- ,~f.. ) VJ (j'1) Samples Required 0 Yes t'8I No Mud Log Requir d Hydrogen Sulfide Measures 18:1 Yes 0 No Directional Survey Required Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K Other: T£st g~ P E ~ (j~oc eit. ORIGINAL SIGNED BY MLBtl1 See cover letter for other reauirements DYes gJ No 181 Yes 0 No o 3.5K psi for CTU Commissioner by order of the commission Date :J... ' C; }o ~1 SJbmi In Triplicate ) ) I Well Name: 12-288/0-19 Drill and Complete Plan Summary Surface Location: I Type of Well (service I producer I injector): I Producer Target Location: 0-19 K2B Target Location: 0-19 K2A Target Location: BHL Well TD I AFE Number: 1 Estimated Start Date: 1944' FNL, 22401 FEL, SEC. 36,T12N, R16E X=258,967 Y=5,982,473.39 19001 FNL, 686' FEL, SEC. 36, T12N, R16E X=260,521.96 Y=5,982,467.06 Z=9963' TVD 18661 FNL, 519' FEL, SEC. 36, T12N, R16E X=260,689.23 Y=5,982,495.69 Z=1 0,145.00' TVD 18321 FNL, 355' FEL, SEC. 36, T12N, R16E X=260,854.40 Y=5,982,523.98 Z=10,324.70' TVD I END 727109 I I Rig: I Doyon 15 / I Operating days to complete: I Feb 26,2003 I Max Inc: 145 @ 8,900' I I KOP: 18,275' I MD: 111,025' I I TVD: 110,324 I I Conventional Sidetrack I Well Design (conventional, slimhole, etc.): I Objective: Kekiktuk K2BL & S2A3 Sands / I 22 I KBE: 155.0 Overview: Mill Window in 9-5/8" at -8275' MD in Seabee shale. Directionally drill to TD @ -11,024' MD, 150' below the deepest K2A oil bearing sand in the Kekiktuk. Run and cement a 4-1/2" liner in this 8-1/2" hole, followed by a 4-1/2" completion. Version 1.0 07 Jan 2003 ) )88 Well Program Mud PrOQram: 9-5/8" Milling Fluid Properties: Density Viscosity Yield Point (ppg) // (seconds) (lb/100ft2) 9.7 200 - 300 > 70 I Bentonite Milling Fluid tauO Gel Strengths (lb/100ft2) 1 Osec/1 Omin > 15 25-40/30-60 API FL (mls/30min) <8 pH 8.5- 9.5 8.5-in Intermediate Hole Mud Properties: I GEM Freshwater Mud Density Plastic Viscosit Yield Poi TauO 10' GI API/ HTH (ppg) (cp) (lb/100ft~ (lb/100ft~ (mls/30mi 9.7 10 - 15 27 - 32 4 - 7 10 6-10 pH LGS 0/0 vo Drill out of Surf Casing To Top HRZ Top HRZ to TD 10.4 ~ 10 -15 20 - 25 3 -7 10 < 4/< 10.0 8.5-9.5 < 5 LCM Restrictions: Minimize use of organic LCM products in the Kekiktuk Waste Disposal:NO ANNULAR INJECTION. Waste mud and drill cuttings taken to DS-4 disposal site Notify Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. 8.5-9.5 <5 Cement Program: Casin~ Size I 4.5" 12.6-lb/ft 13Cr Hydril 563 Production Liner 8asisl500/o excess over ga~e hole. Planned TOC - 8,775' MD. -500' below the window if possible. Spacer 75 bbI11.5-lb/gal MudPush XL Spacer Lead ~ Tail (170-bbl) 15.8 Ib/gal Prem G - ~. cuft/sx (top of tail - 8,775-ft Temp Evaluation Program: 8-1/2" Hole Section: Open Hole: MWD/GR PWD for the entire section RES/NEU/DEN through Kekiktuk Cased Hole WL USIT Log and Static Pressure Log after the rig leave this well. Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/Qal)* KOP in Seabee 8,275 8,259 Tuffs 8,939 8,827 THRZ 9,691 9,355 BHRZ/LCU/FIV 1 0,064 9,622 FII 10,157 9,690 5093 10.2 10 ,~ P3 1 0,44 1 9,897 4832 9.4 K28 10,531 9,963 4510 8.8 K2A 10,780 1 0, 145 4289 8.2 K1 10,992 10,300 4956 9.3 TO 11,025 10,325 4967 9.3 *Based on sub-surface depths. Version 1.0 2 of 6 03 Jan 2003 ') CasinglTubing Program: "18 Well Program Hole Size 8.5-in Tubing Csgl Tbg C.D. 4.5" 4.5" WtlFt Grade Conn/ Length ./ / 12.6 # 13Cr Hydril 563 2900 12.6# 13 Cr Vam ACE 8,125 Bottom MD I TVDrkb' 11,025/10,325 8,125/8,103 Directional Plan KOP: I 8,275' 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 Version 1.0 Top M D I TVDrkb 8,125/8,103 0/0 -Original wellbore is a relatively vertical well design -Maximum inclination 13° in original well bore at -8150' MD. -Sidetrack builds inclination 45° at 8800' and drops slightly to 43° at TO There are no close approach issues: (1 )The closest well is 1-03/P-16 with a 576' distance at 10,275' MD. MWD surveys from kick-off to TD. 13-3/8", 5M, Double ram with annular (Hydril - GK) 5148-psi (10.2-lb/gal @ 9,750-ftTVD) 4173-psi (O.1-psi/ft gas gradient to surface) Infinite with 12.2 ppg emw FIT / Rams test to 4500-psi/250-psi.-/ Annular test to 3,500-psi/250-psi 3,OOQ-psi /' 8.5 Seawater & Diesel packer fluid 3 of 6 07 Jan 2003 ) )88 Well Program Sidetrack and Complete Procedure Summary Pre-Ri~ Work: 1. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. COMPLETE (10/10/01): Packoff passed test to 3000 psi, Tubing hanger passed test to 5000 psi. All lock-down screws functioned. 2. Test the integrity of the cement plug w/ 1000 psi inside the tubing. This plug was previously verified and tested with 2000 psi and by setting 30K # of weight. 3. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut @ -9,050'. Tubing was drifted(3.625") and cement tagged @ 9126' WL on 11/10/02. 4. Pull one of the lower DGLMs. Displace the well to clean seawater by circulating down tubing lower GLM. Freeze protect top 1500' MD with diesel. 5. RU E-line. Cut the 4 ¥2" L-80 tubing at approximately 9050' MD using either a jet or chemical cutter. 6. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. If necessary, level the pad. Riq Operations: 1. MIRU Doyon 15. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. 3.~NiPPle downj.tße. Alignment marks should be made before removing the old tree. Nipple up and test BOPE L\-;DQ to 250 / ~ psi. Pull TWC. /' /' 1(4. Pull and lay down 4-1/2" tubing from E-line cut and above. / ~ 5. RU WL. Run gauge ring/junk basket to -8500' Run and set a bridge plug on WL @ - 8,425' 6. MU 9-5/8" window section milling assembly and RIH with 5" DP to the bridge plug. Displace well to milling fluid. /' 7. Spot a balanced 18.0 ppg mud pill from -8,425' to 8p5'. 8. Section mill window from 8,275' to 8,325'. POOH. 9. MU cementing mule-shoe and TIH to 8,425'. Circulate and condition. / 10. Mix and pump cement kickoff plug. POOH. 11. MU 8-1/2" PDC drilling assembly including MWD/GR RIH to top of cement. Clean out cement to kick-off point. 12. Kick-off and drill the 8-1/2" hole section as per directional plan to TD at +/-11,025' MD (10,325' TVD)..-/' Condition hole for running liner, spot liner running pill, and POOH. f"/ 13. Run and cement a 4 ¥2", 12.6# 13 Cr80 production liner. Release from liner and set liner top packer. Test wellbore to 1000 psi to verify liner top packer is set. /~ 14. Run 4-1/2", 12.6# 13 Cr-80 gas lift completion. Space-out tubing so the WLEG is inside the 4-1/2" liner tie- back sleeve. 15. Drop ball/rod & set packer. Test the tubing to 3000 psi and annulus to 3000 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. /' 17. Freeze protect and secure the well. 18. Rig down and move off. Post-RiQ Work: 1. RU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the production packer. Install gas lift valves. 2. RU CTU to clean much from 4-1/2" liner. 3. RU e-line. Perforate -50' of Kekituk interval with 2-7/8" guns. Version 1.0 4 of 6 03 Jan 2003 ) ~)sB Well Program Job 1: MIRU Hazards and Contingencies ~ Four wells, 2-24, 2-26, 2-30 and 2-32 will require shut-in before the 2-28 rig move. The well is located -10' the 2 adjacent wells(2-26 & 2-30) and 20' from the other two. 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. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. MPI 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 Surface: 2-26 Max: 195 ppm (9/21/99), Last: 170 ppm (11/22/00) 2-28 Max: 28 ppm (1/07/01), Last: 128 ppm (4/09/98) r"/ 2-32 Max: 115 ppm (3/8/02), Last: 125 ppm (10/11/01) The maximum recorded level of H2S on the pad was 2000+ ppm from 1-03 on January 2, 2001 Job 2: Decomplete Well Hazards and Contingencies ~ The existing perforations should be isolated by the pre-rig cement 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. ~~,,»:>~~,}»~~w:~~«-:«rmvc Job 4: Section Mill Hazards and Contingencies ~ Ensure that the Baker section mill is dressed with the older style 3-arm cutters. ~ Ensure that the milled cuttings are being cleaned from the hole. Adjust mud and milling parameters as required to provide for good hole cleaning. ~ Once section milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Job 7: DrillinQ Intermediate/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. A 10.4 mud weight is required for the Fill, FII and FI intervals as the pressures are expected in the 10.2 ppg emw. This will result in being overbalanced to in the K2A sands with 8.2 ppg emw in 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 Version 1.0 5 of 6 03 Jan 2003 ') ')8B Well Program 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+ 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. ~~m~~ ~ 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: WorkinQ RanQes 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) );> 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. ~~X\.,,:-~X>C-~I(>,.'I1\.~~-:-~"t-"~:-''':-~~'''''~'''''''''~~¡ro,~~~ .;, 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. ~~~~~ "",:mv ~""''''.....''''''''''' ." ,.., ,y .,. ~ ,..,... .... N , Job 13: ND/NU/Release Rig 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. Version 1.0 6 of 6 03 Jan 2003 RT. ELEV = 55. 0' BF. ELEV = 15.8' 1'vJo\X. DEV. = 13: 33 @ - 8000' tvÐ 4-1/2"X1-1/2" GLM Station # 1 2 3 4 5 6 DATE 8/20/01 01/03/03 Propo )d Completion 2·28b/O·19 ''''') TREE: 4-1/16" I 5000 psi I M::EVOY . \JlELLHEAD: 13- 51 8" I 5000 psi I M::Evoy 13-3/8", 68#/ft, NT- 80 CYHE, BTRS. CSG 2504' MD 3547 5056 5806 6557 7314 8075 o SSSV Landing Nipple 1555' on S (3.813" M N. I D) W SSSV M N I . D. 2" ..A ~ ~ TVD 3500 5000 5750 6500 7250 8000 I. I I. I 4-1/2" 12.6 LB/FT 13 CR 80 VAM ACE TUBING 4-1/2" X LANDING NIPPLE 9-5/8" BAKER S-3 PACKER AT 8100' 4-1/2" X LANDING NIPPLE 4-1/2" XN LANDING NIPPLE SECTION MILL 50' WINDOW /' KICK OFF CMT PLUG AT 8275'MD 8-1/2" HOLE X 4-1/2" LINER 13 CR HY.. DRIL 563 LINER 7'"' t. r. ,.v, Z- ora ( oJ') p VI. L tA.~" 1: c. /" TD 11,025'MD, 10,325'TVD ~:-- ..- 9-5/8", 47#/ft, NT80S XO TO NT95HS " 'I,¿ I I ...- CAMCO SLIDING SLEEVE 9265 (' z. ~ BAKER "SBR" (12" long) )- ~ ~ 9-5/8" PACKER .~ Milled up 3-1/2" x-over , (3.72" ID) 9324' 9339' 9347' TOP OF 7" LINER 9383' ____ Top of window 9665' 9-5/8", 47#/ft, NT95HS, 9644' ~ 9340 - 9680' .. Cement plug ..... '" Abandoned TTRD sidetrack PBTD 10,448'~ 10, 527' ~ ~= 3-1/2" tailpipe & BOWSPRING LEAFS 7" - 29 #/ft, SM-110,BTRS-TKC REV. BY FJ WOO - - : X X )< COMMENTS Proposed Sidetrack Proposed Sidetrack ENDI COTT \'ELL 2- 28Bf 0- 19 API NO 50- 029- 21847- 02 cavPLETIO\I DI AGRAM BP EXPLORATION, INC. ., REFERENCE INFORMATION SURVEY PROGRAM Plan: 2·28B/O-19 wp23 (2-28/P-19/Plan: 2·28B/O·19 Shallow) C<HJrdina1e (NIE) Rel<renœ: Wen Centte: 2-2&11'-19, True Nor1h Depth Fm Depth To S""'ey¡Plan Tool CreaIed By: Ken Allen Dale: 9/1212002 Vertical (IVD) Referenœ: 34: 28 7ßOII988 00:00 55J{) 8275.00 1102552 PIaooed: 2-28B/0-19 "1'23 V8 MWD Seclioo (VS) Reference: Slot - 28 (O.OON,O.OOE) Checked: Date: M"",,-ured Depth Reference: 34: 28 7ßO!I988 00:00 55.00 Ca1culation MetbJd.: Mininnnn CUl"iature Reviewed: Date: CASING DErAILS WELL DETAIlS Na= +Ni-S +EI-W N~ Ea>tiog Lalitude LongRude Slot No. TVD MD Name Size 2-28IP-19 320855 2182.88 598247339 258966.93 70"21'09.9I1N 147°57'26.704W 28 10324.70 11025.51 41/2" 4.500 TARGET DETAILS Name 1VD +N'-S +EI-W Northing Easling Shape 2-28B'0-19 K2B 9963.00 43.70 1554.48 5982467J16 260521.96 Circle (Radius: 1(0) FORMATION TOP DErAILS 2·288/0-19 K2A 10145.00 71.71 1720.75 5982495.69 26068923 Circle (Radius: 100) No. TVDPath MDPath Formation SECTION DErAILS 1 8827.00 8939.76 Tuffs Sec MD Inc Azi TVD +N/-S +Fl-W DLeg TFace VSec Target 2 9355.00 9691.17 THRZ 3 9622.00 10064.69 BHRZ 1 ": 7",.00 12.95 134.58 8249.76 -172.75 161.02 0.00 0.00 150.56 4 9690.00 10157.67 FIT 2 "_""',.00 14.43 126.57 8269.]9 -175.8] 164.62 12.00 -56.0] 153.97 5 9897.00 10440.71 P3 3 i\ '~"'.OO 15.63 120.41 83]7.48 -182.93 175.43 4.00 -56.0] 164.34 6 9963.00 10530.95 K2B 4 "">d9 45.36 78.45 88]8.87 -]81.08 455.2 ] 6.00 -56.06 443.74 7 10145.00 10779.80 K2A 5 .., .11.24 45.36 78.45 9396.5] -63.92 1028.26 0.00 0.00 ] 022.70 8 10300.00 10991.74 K] 6 1'" '<'~·.69 43.00 78.44 9622.00 -20.02 1242.94 0.75 -179.90 ]239.60 7 1"" '''.95 43.00 78.44 9963.00 43.70 ] 554.48 0.00 0.00 ] 554.35 2-28B/O-19 K2B "--' 8 1"77'·.80 43.00 78.44 10145.00 77.71 1720.75 0.00 0.00 ] 722.34 2-28B/O-]9 K2A 9 1"" 7"·.52 43.00 78.44 102]5.00 90.79 1784.71 0.00 0.00 1786.95 10 ] 11.'_' :-.52 43.00 78.44 10324.70 ] ] 1.29 1884.93 0.00 0.00 ] 888.21 COMPANY DETAILS Minimum (ìm~'uro ISCWSA T 1"3" Cylindo:f North ElIiplic.1J + casing RuJ", ßas,:d All TVD depths are ssTVD plus 55' for RKBE. Caku!3'i<>" Melbod: ~: ~~~:r Error Swrac~: Wami/l~ MclhOO: bp O'<'f -';; . .:;,: 8275' MD, 8249.76'TVD 8295' MD, 8269. I 9'TVD 8345' MD, 83 I 7.48'TVD 12/100' 8000- 8400 -- /$"00 / // ..../$00 ~ ~ o ~oo 9000 I1r~OO 6000 1ØO 0.000 éOO ~OOO I 2000 9750.24' MD, 9396.51'TVD :I Dir : 10064.69' MD, 9622' TVD II Del I 800 1200 Vertical Section at 86.62° [400ft/in] 8928.19' MD, 8818,87' TVD I~ 400 8800 9200 0400 9600 0000 ~ ¢: g :!. ..c: i5. Ö ] 'i:: >- 2 f- Plan: 2-28B/0-19 wp23 (2-28/P-19/Plan: 2-28B/0-19 Shallow) Created By: Keo Allen Date: 911212002 Date: Date: Checked: Reviewed: SURVEY PROGRAM Depth Fro Depth To Sun"yiPlan Tool 8275.00 11025.52 PIanœd: 2-28&'0-19 "1'23 V8 MWD WElL DETAILS Name +NI-S +EI-W Northing E3sting Latitude Longitude Slot 2-2M 3208.55 2182.88 598247339 258966.93 70"2\'09.91IN 147°57'26.704W 28 TARGET DETAILS Name 1VD +NI-S +EI-W Nonbing E3sting Shape 2-28BíO-19 K28 9%3.00 43.70 1554.48 5982467.06 260521.96 Cin:1e (Radius: 1(0) 2-28810-19 K2A 10145.00 77.71 1720.75 5982495.69 26068923 Cin:1e (Radius: 1(0) SECTION DEI AILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 1 8275.00 12.95 134.58 8249.76 -172.75 161.02 0.00 0.00 150.56 Size 2 8295.00 14.43 126.57 8269.19 -175.81 164.62 12.00 -56.01 153.97 3 8345.00 15.63 120.41 8317.48 -182.93 175.43 4.00 -56.01 164.34 4.500 4 8928.19 45.36 78.45 8818.87 -181.08 455.21 6.00 -56.06 443.74 5 9750.24 45.36 78.45 9396.51 -63.92 1028.26 0.00 0.00 1022.70 6 10064.69 43.00 78.44 9622.00 -20.02 1242.94 0.75 -179.90 1239.60 7 10530.95 43.00 78.44 9963.00 43.70 1554.48 0.00 0.00 1554.35 2-28B/O-19 K2B 8 10779.80 43.00 78.44 10145.00 77.71 1720.75 0.00 0.00 1722.34 2-28B/O-19 K2A -~ 9 10875.52 43.00 78.44 10215.00 90.79 1784.71 0.00 0.00 1786.95 10 11025.52 43.00 78.44 10324.70 111.2 9 1884.93 0.00 0.00 1888.21 REFERENCE INfORMATION Co-<>n1inate (N/E) Reference: Well CeoIre: 2-2&p·19, Trœ North Verti<31 (IVD) Reference: 34: 28 713011988 00:00 55.00 Section (VS) Reference: Slot- 28 (O.OON,O.OOE) Measured Depth Reference: 34: 28 713011988 00:00 55.00 C~u1alion Method: Minimum ÛJI\'3_ FORMATIONTOPDETArrS No. TVDPath MDPath Formation 1 8827.00 8939.76 Tuffs 2 9355.00 9691.17 THRZ 3 9622.00 10064.69 BHRZ 4 9690.00 10157.67 FIT 5 9897.00 10440.71 P3 6 9963.00 10530.95 K2B 7 10145.00 10779.80 K2A 8 10300.00 10991.74 Kl CASING DETAILS No. TVD MD Name 10324.70 025.51 41/2' COMPANY DETAII.S Ca'I,'U].alion McClk1d: Minimum Cun'3ture ~ ~l=~ ~~V~~UA" NortI. Error Surfucl!: Ellipe.ic:1I + Casing Warn;! M.1bod: Ruk... flam O··_···^,b."...P... "»- All TVD depths are ssTVD plus 55' for RKBE. aoq, /.sq, ~ ~ I~ ./ ¡P I -I ,1/ III II ~ 4' ..... # '/Sq, .# ----- wp23 I 2000 Total Depth: 1102552' __I . MD,10324.7'TVD ,.... ')~'" - - \ .J ! ~'2iB/C_14-~~·nl.~ I.' .. ,_ . ¡"i'on,! ~~ / \)---"-- ~ \ "*"ì'1IQß¡i ==>'f / \ ,,\l'-28B/O-I' I "i'1j:-'P-.vL __;-/,~r~~4 -,----f("f I~"~,!' ~ / i i~==/' ~/4 I I ~ I .~ , I . ,- I - --" . : -:: I - ~ ' - ,- ~- T '-. I I HÙO 2 800 1600 -I I I 1200 West(-)/East(+) [200ft/in] I I 9(122' 1000 800 600 ~__-r--""í- EndDi 2-28 'P-19 (2-28/P719) St ift Dif 12/100' : 8275'MD, g249.76'TVD II ~art Dif 4/100' : 8295' MD, ~269_19'TVD : ~rt Di, 6/100' , 8345' ML 8311,48'fV0 400 200 200 o -200 -400 :5 ¢: o o ~ ~ t: o ~ :; o CIJ ') ') BP KW A Planning Report MAP .CODJpany: :l1'~~ld: . .~i~e: . · Well: WêÜpåtÏ1: Date: 9112/2002 Til11e: 14:24:44 . ... .... Page: Ço~~din~te(l\JE) ~efereJjçe:... ; YYell;2~28~P;.1~,Tn~~:.Norttl:..·. . Y'et(itål(1VQ):R~J~rençe: .·34:.:287/30/198800:0055.0 . Sêçtiôl1(YS)Ret~í-êl1ce:. ·VY~II ~Ù.O()~,0·Þ()r::,t3~:92J\zi) Survêy ÇálcuiâtiôriMetÏ1od: . Mihimurrf QUrVatürå . ... ... . Db: BPAmoco . Erïdicott .1;r¡ldMPI . 2~28/P;; 19 ¡:ilaQ:2":28a/0" 19 $hallpw Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: End MPI TR-12-16 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5979337.49 ft 256681.13 ft Well: 2-28/P-19 2-28/P-19 Well Position: +N/-S 3208.55 ft Northing: 5982473.39 ft +E/-W 2182.88 ft Easting: 258966.93 ft Position Uncertainty: 0.00 ft Wellpath: Plan: 2-28B/0-19 Shallow Current Datum: Magnetic Data: Field Strength: Vertical Section: 34: 287/30/198800:00 3/19/2001 57550 nT Depth From (TVD) ft 0.00 Height 55.00 ft +N/-S ft 0.00 Plan: 2-28B/0-1.9 wp23 Principal: Yes Map Zone: Coordinate System: Geomagnetic Model: Latitude: Longitude: North Reference: Grid Convergence: Slot Name: Latitude: Longitude: Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Date Composed: Version: Tied-to: Alaska, Zone 3 Well Centre BGGM2002 70 20 38.358 N 147 58 30.505 W True -1.86 deg 28 70 21 9.911 N 147 57 26.704 W 2-28/P-19 8275.00 ft Mean Sea Level 27.10 deg 80.91 deg Direction deg 86.62 9/11/2002 8 From: Definitive Path Casing Points MD TVD Dianieter Hóle Size Name ft ft in in 11025.51 10324.70 4.500 8.500 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 8939.76 8827.00 Tuffs 0.00 0.00 9691.17 9355.00 THRZ 0.00 0.00 10064.69 9622.00 BHRZ 0.00 0.00 10157.67 9690.00 FII 0.00 0.00 10440.71 9897.00 P3 0.00 0.00 10530.95 9963.00 K2B 0.00 0.00 10779.80 10145.00 K2A 0.00 0.00 10991.74 10300.00 K1 0.00 0.00 Targets Map Map <- Latitude·--> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 2-28B/0-19 K2B 9963.00 43.70 1554.48 5982467.06 260521.96 70 21 10.339 N 147 56 41.269 W -Circle (Radius: 100) -Plan hit target 2-28B/0-19 K2A 10145.00 77.71 1720.75 5982495.69 260689.23 70 21 10.673 N 147 56 36.409 W -Circle (Radius: 100) -Plan hit target ) BP KW A Planning Report MAP ) ·CoDipany: BPAmoco . Fie.I(): .. . EndiCott Site~. End MPI . Well: 2~2ß/p,,;19 . ··Wellpath:· Þlåh: 2L26B/O~19Shällow Plan Section Information Date: 9/12/2002 Time: 14:2.4:44 . ... .. .. ..·..Page: . qp';p"4i"~te(~~) )iefet¡en,ce: : Well:g~28/Pr1WT~üe N(.')r1h . Vé#~cal(TV»):Refer~~ëe:.·. ... Ø4: ?87/~0/1~~8 PO;()() 55.0 . ·Sèctión (VS)Rëfer~l1êe: VV~.II.(0;()qN;q;()qf:,8ç.62Azi) SûrvøY.Calculåtiôn:Metbod: ... ... M¡nimLimCurvalure .. .. Db: . MI) Inci Azim TV» · +N/-S fE/;'W OLS BUild : Turn .··TFO .. ..{t; : dØg· Pª~l· ft ft ft . . (jegJ1 ()Oft degt10()ft d~g/1 qOft ··dØQ 8275.00 12.95 134.58 8249.76 -172.75 161.02 0.00 0.00 0.00 0.00 8295.00 14.43 126.57 8269.19 -175.81 164.62 12.00 7.39 -40.06 -56.01 8345.00 15.63 120.41 8317.48 -182.93 175.43 4.00 2.41 -12.33 -56.01 8928.19 45.36 78.45 8818.87 -181.08 455.21 6.00 5.10 -7.19 -56.06 9750.24 45.36 78.45 9396.51 -63.92 1028.26 0.00 0.00 0.00 0.00 10064.69 43.00 78.44 9622.00 -20.02 1242.94 0.75 -0.75 0.00 -179.90 10530.95 43.00 78.44 9963.00 43.70 1554.48 0.00 0.00 0.00 0.00 2-28B/0-19 K2B 10779.80 43.00 78.44 10145.00 77.71 1720.75 0.00 0.00 0.00 0.00 2-28B/0-19 K2A 10875.52 43.00 78.44 10215.00 90.79 1784.71 0.00 0.00 0.00 0.00 11025.52 43.00 78.44 10324.70 111.29 1884.93 0.00 0.00 0.00 0.00 Survey -~.~_._..._..,-~~..-~~~_._.......,..~.......__..-...~......~..-..-"-..~"~---.--.-,.-..-~..-~..-,.-...."..-...-.,,..,, ..._----_.~-'_.._._-~_.~._---_.~._..-.'-.,-_._._.--.-......'_.-............._~-,_.__._-~-~~---~.'.,..._~-~_...~..-.__..~.__.._-,..__._~~-_...........~-~.'~-~.~- ,.,. .. , ....... .., ..... ...., Mn loCi Azim TVD SysTVP l\iapN ·l\1IlPE VS OLS· TooliComment. ft (jag dég ft ft . ft ft ft .. d~g/10Oft 8275.00 12.95 134.58 8249.76 8194.76 5982295.55 259122.31 150.56 0.00 Start Dir 12/100' : 8275' MD, 8295.00 14.43 126.57 8269.19 8214.19 5982292.38 259125.80 153.97 12.00 Start Dir 4/100' : 8295' MD, 8 8300.00 14.54 125.91 8274.03 8219.03 5982291.61 259126.79 154.93 4.00 MWD 8345.00 15.63 120.41 8317.48 8262.48 5982284.92 259136.38 164.34 4.00 Start Dir 6/100' : 8345' MD, 8 8350.00 15.80 119.49 8322.30 8267.30 5982284.20 259137.53 165.47 6.00 MWD 8400.00 17.68 111.36 8370.18 8315.18 5982277.67 259150.33 178.09 6.00 MWD 8450.00 19.83 104.84 8417.53 8362.53 5982272.25 259165.43 193.05 6.00 MWD 8500.00 22.17 99.60 8464.21 8409.21 5982267.94 259182.81 210.30 6.00 MWD 8550.00 24.65 95.34 8510.09 8455.09 5982264.76 259202.40 229.81 6.00 MWD 8600.00 27.23 91.82 8555.05 8500.05 5982262.73 259224.17 251.51 6.00 MWD 8650.00 29.88 88.88 8598.97 8543.97 5982261.84 259248.04 275.35 6.00 MWD 8700.00 32.59 86.38 8641.72 8586.72 5982262.10 259273.96 301.26 6.00 MWD 8750.00 35.33 84.23 8683.19 8628.19 5982263.51 259301.84 329.18 6.00 MWD 8800.00 38.12 82.35 8723.26 8668.26 5982266.06 259331.63 359.02 6.00 MWD 8850.00 40.93 80.69 8761.83 8706.83 5982269.75 259363.22 390.71 6.00 MWD 8900.00 43.76 79.21 8798.79 8743.79 5982274.56 259396.55 424.15 6.00 MWD 8928.19 45.36 78.45 8818.87 8763.87 5982277.77 259416.06 443.74 6.00 End Dir : 8928.19' MD, 8818.8 9000.00 45.36 78.45 8869.33 8814.33 5982286.39 259466.42 494.32 0.00 MWD 9100.00 45.36 78.45 8939.60 8884.60 5982298.39 259536.55 564.75 0.00 MWD 9200.00 45.36 78.45 9009.87 8954.87 5982310.39 259606.68 635.18 0.00 MWD 9300.00 45.36 78.45 9080.13 9025.13 5982322.39 259676.81 705.60 0.00 MWD 9400.00 45.36 78.45 9150.40 9095.40 5982334.39 259746.94 776.03 0.00 MWD 9500.00 45.36 78.45 9220.67 9165.67 5982346.39 259817.07 846.46 0.00 MWD 9600.00 45.36 78.45 9290.93 9235.93 5982358.39 259887.20 916.89 0.00 MWD 9700.00 45.36 78.45 9361.20 9306.20 5982370.39 259957.33 987.32 0.00 MWD 9750.24 45.36 78.45 9396.51 9341.51 5982376.42 259992.57 1022.70 0.00 Start Dir 0.75/100' : 9750.24' 9800.00 44.99 78.45 9431.58 9376.58 5982382.37 260027.35 1057.63 0.75 MWD 9900.00 44.24 78.44 9502.77 9447.77 5982394.22 260096.57 1127.15 0.75 MWD 10000.00 43.49 78.44 9574.88 9519.88 5982405.91 260164.86 1195.73 0.75 MWD 10064.69 43.00 78.44 9622.00 9567.00 5982413.39 260208.54 1239.60 0.75 End Dir : 10064.69' MD, 9622' 10100.00 43.00 78.44 9647.82 9592.82 5982417.45 260232.28 1263.44 0.00 MWD 10200.00 43.00 78.44 9720.96 9665.96 5982428.96 260299.50 1330.94 0.00 MWD 10300.00 43.00 78.44 9794.09 9739.09 5982440.47 260366.72 1398.45 0.00 MWD 10400.00 43.00 78.44 9867.23 9812.23 5982451.98 260433.93 1465.95 0.00 MWD 10500.00 43.00 78.44 9940.37 9885.37 5982463.49 260501.15 1533.46 0.00 MWD 10530.95 43.00 78.44 9963.00 9908.00 5982467.06 260521.96 1554.35 0.00 2-28B/0-19 K2B 10600.00 43.00 78.44 10013.50 9958.50 5982475.00 260568.37 1600.96 0.00 MWD 10700.00 43.00 78.44 10086.64 10031.64 5982486.51 260635.59 1668.47 0.00 MWD 10779.80 43.00 78.44 10145.00 10090.00 5982495.70 260689.24 1722.34 0.00 2-28B/0-19 K2A 10800.00 43.00 78.44 10159.77 10104.77 5982498.02 260702.81 1735.98 0.00 MWD ) BP KW A Planning Report MAP ·Company:BP Amöco Field,: . . Endicqtt ~ite: ,... "EridMPI. Wem 2~?8/P-1~ W~Îlpåth: . Plan: 2,j28B/O~19Shánöw D~t~: 9/1,2/:Z002 . ...... Time:' 14:24:44 ~agè: C9~9r4iµ~tç<N)!Jij.efere..ce: . W§II: 2}281Pë19,Trl,AeN?rth ...... . . yêr~içal (TVJ)J:tl~fer~Íice; . ' ·34: 287/30/1988 ÖO:Ö055.0 ' ~eêtioli ('vs~~~re"ênce: .. .. ..' "" .·W§II (P.QON ;q.()OE,a~t62AZi) SUtvèyCal~ulåtionMethQd:··· ..MinimumCürvatüre········ i.Db: Survey :[MÖ". ft 10875.52 10900.00 11000.00 11025.51 11025.50 11025.52 lliel deg 43.00 43.00 43.00 43.00 43.00 43.00 Azitn 'deg· 78.44 78.44 78.44 78.44 78.44 78.44 ...., , TVD ft 10215.00 10232.91 10306.04 10324.70 10324.69 10324.70 SysTVD ft 10160.00 10177.91 10251.04 10269.70 10269.69 10269.70 ..MapN ft ... .' 5982506.71 5982509.53 5982521.04 5982523.98 5982523.98 5982523.98 lVI~pE <ft 260753.57 260770.03 260837.25 260854.40 260854.39 260854.40 ) VS ft 1786.95 1803.48 1870.99 1888.21 1888.20 DLS · Tool/Comment. d~g/1 OOft . 0.00 MWD 0.00 MWD 0.00 MWD 0.00 4 1/2" 0.00 Total Depth: 11025.52' MD, 10 1888.21 0.00 MWD SURVEY PROGRAM Depth Fro Depth To SurYey/P1an Tool 8275.00 11025.52 PIanœd: 2-28BX>-19 ""1'23 V8 MWD COMPANY DETAILS BP Amoco ANTI-COLLISION SEITINGS Interval: 25.00 To: 1l025.52 Reference: Plan: 2-28B/0-19 wp23 Interpolation Method:MD Depth Range From: 8275.00 Maximum Range: 1298.50 _J '~ SECTION DETAILS See MD Inc An TVD +NI-S +EJ-W DLeg l1'ace vSee Target I 8275.00 12.95 134.58 8249.76 -172.75 161.02 0.00 0.00 150.56 2 8295.00 14.43 12657 8269.19 -175.81 164.62 12.00 -56.01 153.97 3 8345.00 15.63 120.41 8317.48 -182.93 175.43 4.00 -56.01 164.34 4 8928.19 4536 78.45 8818.87 -181.08 45521 6.00 -56.06 443.74 5 975024 4536 78.45 9396.51 -<>3.92 102826 0.00 0.00 1022.70 6 10064.69 43.00 78.44 %22.00 -20.02 1242.94 0.75 -179.90 1239.60 7 10530.95 43.00 78.44 9963.00 43.70 1554.48 0.00 0.00 155435 2-28&'0-19 K2B 8 10779.80 43.00 78.44 10145.00 77.71 1720.75 0.00 0.00 1722.34 2-28&'0-19 K2A 9 10875.52 43.00 78.44 10215.00 90.79 1784.71 0.00 0.00 1786.95 10 11025.52 43.00 78.44 10324.70 11129 1884.93 0.00 0.00 188821 WELLPATH DETAILS Plan: 2-28B1O-19 Shallow Parent We11path: 2-28IP-19 TIe 00 MD: 8275.00 Rig: 55.00ft Ref. Datum: 34 : 28 7ß(j!1988 00:00 V..section Origio Origio Starting AI¥Ie +W-S +EJ-W From TVD 86.62" 0.00 0.00 0.00 LEGEND 1-03/P-16 (plan 0I-03No-I9), MajocRisk 1-05X>-20 (l-05X>-20), Majo¡ Risk 1-25/N-22 (l-25/N-22), Major Risk 1-25NK-22 (1-25NK-22), Majo¡ RisI: 1-27/P-20 (1-27/P-20), Major Risk 1-39/P-17 (l-39/P-I7), MajorRisl: 1471Q-21 (1471Q-21), Major Risk 147NM-20 (l47NM-20), Majo¡ Risk 147NPBI (147A1PBI), Majo¡Risk 147A1PB2(147A1PB2), Majoc Risk 1-531Q-20 (1-531Q-20), Majoc Risk 1~11Q-20 (1~11Q-20), Majo¡ Risk 1~1IQ-20 (plan 1~IAIO-I9), Major Risk 2-0211'-18 (2-0211'-18), Major Risk 2-04/M-19 (2~1-19), Major Risk 2-12IQ-16 (2-I2IQ-I6), Major Risk 2-1410-16 (2-1410-16), Major Risk 2-28/P-19 (2-28IP-19), NOERRORS 2-28/P-19 (2-28APBII0-19), NOERRORS 2-34/P-14 (2-34IP-14), MajorRisl: 2461Q-15 (246IQ-IS), Major Risk 246AIPBI (2-46AiPBI), Major Risk 2-46A1R-IO (246NR-IO), Majo¡ Risk 246B1S-13 (246B/S-I3), Major Risk 2~2IQ-17 (2~2IQ-17), Majoc Risk Plan: 2-28BX>-19 ShaDow 2-28BIO-19 wp23 - ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 6000 8000 11000 12000 15000 Colour - 90 - CakuJation Melbod: Minimum ÛIlv.!ture Error System: ISCWSA Sc<m Melbod: T ray Cyw.Ier North Error Surface: EIIipôcal + Casing Warning MeIbod: Rok:s Based From o 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 o 6000 8000 11000 12000 o N.>m.: ;NI-S d'l-W Nonhil1ß E3sûn8 LatilOOë Longitude 51, 2-28/P- J 9 3208.55 2182.88 5982473. 258966.' 70"21'09.9JJN 147'57'26.704W 28 -128 -120 -100 -80 -60 -40 -20 -0 270 -20 -40 -60 ~þ ~ cP cP ';õ ';õ ~ ~ ~ ~0 -80 o ~ ~ cP cP ';õ ~ ~ ~ :B .... 0 -100 ~ -120 -128 ) BP Anticollision Report ) 'CQQJjuïny: BPArilocöDate:. 9/12/2002: Time: 13;51:29 Ifl¢~d::. Endicott .. .. ........ .... . .. .. . .:..' .'.:.. ...:: : .... .. :.:...".. ., .R¢~et~nc~Slte: ,. .. End MP,· C()~()rdinå.t~@E) Reference:·· .. .. W~,t: ~~2~/p·19.Tfue NQI'iR .R:er~r~nceWeU: 2~2E.VP-19 . . .. ..... .... ., yêrticål (tYJ[»:ij.~fe~ençê: ·34: 2f3 i/30i198f3 00;QQ55.Q J{efer~nceWeilp~tlï: Plait 2':'28B/0-19Shänow . Db:' Ötaclë' GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ardmfEiii1èftells in th¡>~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 8275.00 to 11025.52 ft Scan Method: Trav Cylinder North Maximum Radius: 1298.50 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/15/2002 Validated: No Planned From To Survey ft ft 50.00 8275.00 8275.00 11025.52 Version: 14 Toolcode 1 : Schlumberger GeT multishot Planned: 2-28B/0-19 wp23 V8 GCT -MS MWD Casing Points MD . ¡YI> :ft ft 11025.51 10324.70 Tool Name Schlumberger GCT multishot MWD - Standard Diari1~ter in 4.500 Hole Size , in 8.500 4 1/2" Offset .Ctr':'Ctr ·No~Go A.ilowable MD ··DistlÏnce . Area Deviation 'ft tt ft ft 11400.00 576.48 131.59 486.67 10375.00 1063.98 182.01 965.79 9375.00 1235.27 171.97 1158.86 9325.00 1235.29 136.07 1147.22 9025.00 910.39 99.23 827.90 8475.00 617.90 117.80 557.20 11825.00 659.63 213.11 503.47 11825.00 656.49 212.91 499.76 11825.00 659.66 213.17 503.98 9300.00 847.88 109.91 741.50 9225.00 745.70 105.20 643.82 10725.00 610.99 132.92 528.87 10375.00 1140.95 183.11 982.37 8425.00 581.48 71.38 512.60 8300.00 0.66 67.19 -65.97 8300.00 0.66 Summary <..;... .~. -, Site . ~~-~--.··()ffsetWellpath ..___~_L___..;..':'__.;-:"':_>- Reference Well 'Wellpåth . MD ::. ··ft 1-03/P-16 Plan 01-03A10-19 VO PI 10275.79 1-05/0-20 1-05/0-20 V1 11003.70 1-25/N-22 1-25/N-22 V1 10012.37 1-25A1K-22 1-25A1K-22 V5 9970.01 1-27/P-20 1-27/P-20 V1 9333.27 1-39/P-17 1-39/P-17 V1 8284.53 1-47/0-21 1-47/0-21 V1 1-47A1M-20 1-47A1M-20 V3 Plan: Un 10838.55 1-47A1PB1 1-47A1PB1 V3 10835.34 1-47A1PB2 1-47A1PB2 V2 10838.54 1-53/0-20 1-53/0-20 V1 9518.33 1-61/0-20 1-61/0-20 V1 9438.56 1-61/0-20 Plan 1-61A10-19 V1 Pia 10249.20 2-02/P-18 2-02/P-18 V1 2-04/M-19 2-04/M-19 V1 11017.59 2-12/0-16 2-12/0-16 V1 2-14/0-16 2-14/0-16 V1 8289.17 2-28/P-19 2-28/P-19 V4 8299.98 2-28/P-19 2-28APB1/0-19 VO 8299.98 2-34/P-14 2-34/P-14 V1 2-46/0-15 2-46/0-15 V1 2-46A1PB 1 2-46A1PB 1 V2 2-46A1R-10 2-46A1R-10 V5 2-46B/S-13 2-46B/S-13 V3 2-62/0-17 2-62/0-17 V1 8275.00 8375.00 End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI End MPI Site: End MPI Well: 1-03/P-16 Wellpath: Plan 01-03A10-19 VO Plan: 01-03A10-19 wp01 V1 Reference Offset Semi-Major Axis MD TVD MD TVD Ref Offset TFO+AZI TFO-HSCasing ft ft ft ft ft ft deg deg in 10332.07 9817.55 10300.00 10046.45 20.54 14.64 333.33 254.89 10339.69 9823.12 10325.00 10055.22 20.62 14.58 332.85 254.41 10346.25 9827.92 10350.00 10062.16 20.69 14.51 332.41 253.97 10351.72 9831.92 10375.00 10067.23 20.75 14.45 332.02 253.58 10356.17 9835.18 10400.00 10070.59 20.79 14.40 331.68 253.24 10360.46 10364.75 10369.03 10373.08 10375.86 14.34 331.34 252.90 14.28 330.98 252.54 14.23 330.60 252.16 14.17 330.20 251.76 14.10 329.74 251.30 9838.31 10425.00 10073.67 9841.45 10450.00 10076.75 9844.58 10475.00 10079.83 9847.54 10500.00 10082.86 9849.58 10525.00 10085.60 20.84 20.89 20.93 20.98 21.01 719.16 70.20 650.54 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft Ctr-Ctr No-Go Distance Area ft ft 1281.80 142.08 1260.53 142.26 1238.38 142.42 1215.45 142.55 1191.92 142.66 Allowable Deviation ft 1147.21 1125.83 1103.59 1080.61 1057.05 1168.34 142.75 1033.46 1144.80 142.85 1009.93 1121.30 142.95 986.46 1097.88 143.03 963.09 1074.67 143.03 940.05 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Out of range Pass: Major Risk FAIL: Major Risk No Offset Errors Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Warning Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass p054976 DATE INVOICE / CREDIT MEMO 11/18/02 INV# CKll1402Q ~. THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 PAY DESCRIPTION PERMIT TO DRILL FEE TOTAL ~ GROSS J,. .-2!2/ø lo - 19 NATIONAL CITY BANK Ashland, Ohio D P~ t:Î~ Ufr' ,IUI~ JlfIIlt ,('!-tn" IT' V 0 oMLI..I.. tlllll f'III" 0';;;:' ~::::, ,:,:: TO THE ORDER OF ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 10D ANCHORAGE, AK 99501 DATE DATE CHECK NO. 11/18/02 P054976 VENDOR DISCOUNT NET H RECEIVED JAN 0 8 200J Alaska Oil & Gas Cons. Commission Anchoraç Ð 56-389 412 No.P 054976 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT NOV 18, 2002 ****$100.00**** NOT VALID AFTER 120 DAYS II- 0 5 ~ q '7 b II- I: 0 ~ . 2 0 38 g 5 I: O. 2 '7 B 1:1 b II- r:·.··.··- ·.·-::~~;~·~?~~~F-) . - ..-.:..~..::..:------.._..--_.:...::~-- _::...._~~-~..._----~~ .-. - . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well PermitN 0, 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(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (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. WELLPERMITCHECKLlST COMPANY I3rX WELLNAME.bIU2:¿<6ß~-/9PROGRAM: Exp_ DeV~RedrliL Re-Enter_ Serv_ Wellboreseg_ . FIELD & POOL ¿ ~ / (') ~ INIT CLASS L/P.L..- / -,('"'VI "" GEOL AREA <?;7 /'J UNIT# /<3 '7" ¿- n ON/OFF SHORE.~.~..jt..~_~¿, ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . (y. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N ~ S \ 3. Unique well ~ame and number. . . . . . . . . . . . . . . . . Y N 14(..1 f'4 4. Well located In a defined pool.. . . . . . . . . . . . . . . . . Y N ;¡¡ \ .// <J 5. Well located proper distance from drilling unit boundary. .. . Y ~¥~¡1:tj)) J:1c, 6. W ell located proper distance from other wells.. . . . . . . . . Y W 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . t Y N 12. Permit can be i..ssued without administrative approval.. . . . . 7w N /l (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ Y Â/c¡J-1 \ (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥---N- 16. Surface casing protects all known USDWs. . . . . . . . . ¥--N- rIll 17. CMT vol adequate to circulate on conductor & surf csg. . . . ¥--N'-' Af/f'r 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . .¥-N- 19. CMT will cover all known productive horizons. . . . . . . . . . iN 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . . N D 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . .. N 1 ()v{ ~'v'- 15 22. If a re-drill, has a 10-403 for abandonment been approved. . . ~ N j I (')J,?-! tJ 2- · 23. Adequate wellbore separation proposed.. . . . . . . . . . . . &. N 24. If diverter required, does it meet regulations. ..' . . . . . . . Y N ~ A;l1A.- , 25, Drilling fluid program schematic & equip list adequate. . . . . N 1///..,(1,/1£ rYl k.l 1(;'" L/ P P1 . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N) 27. BOPE press rating appropriate; test to 45"00 psig. N fYts. I 4/73 P ~ ¿ . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N / 31. Mechanical condition of wells within AOR verified. . . . . . . . ~NIA- 32. Permit can be issued w/o hydrogen sulfide measures. . . .. ;r@ 33. Data presented on potential overpressure zones. . . . . . . . Y N ß 34. Seismic analysis of shallow gas zones. . . . . . . .. .. .. .. .. .. Yy . ~ A/~ \ 35. Seabed condition survey (if off-shore).. . . . . .. ...... 36. Contact namelphone for weekly progress reports. GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP&' APPR DATE ðL~ APPR DATE VJ6A- 'Z (-) {Q; (Service Well Only) GEOLOGY APPR DATE h~ ¡/~ .. (Exploratory Only) Rev: 10/15/02 UIC ENGINEER TEM JDH JBR SFD_ WGA /' MJW G:\geology\permits\checklist.doc e)< <---rJ! ðn /'f:> -4 of! /i' //>)v rft,.\re., be.(~~e- J,(~,s-f ,r04), /$ ~ 1J'ð; ....IfG (~ { COMMISSIONER: Comments/lnstructions: COT DTS Ot jr:;l¡-' /r:Jj MLB O:¿/ð'.+t:J3 ) ) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plìfy finding information, 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. ') ) ~03 -ool.p Sperry-Sun Drilling Services LIS Scan Utility J J xg}~ $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 01 13:07:21 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/01 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. . . . . . . . . . . . . . . . . . . . .03/12/01 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2-28B/0-19 Reprocess 500292184702 BP Exploration Inc. Sperry Sun 30-NOV-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002347857 T. GALVIN C. GALLOWAY MWD RUN 2 MW0002347857 T. GALVIN E. VAUGHN MWD RUN 3 MW0002347857 T. GALVIN E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 12N 16E 1944 2240 .00 15.75 39.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 8.500 8.500 CASING SIZE (IN) 9.625 9.625 9.625 DRILLERS DEPTH (FT) 8284.0 8284.0 8284.0 # REMARKS: 1. THIS FILE SUPERCEDES ALL PREVIOUS VERSIONS/CORRECTIONS, IS DATED 11/30/03, AND CONTAINS COMPENSATED THERMAL NEUTRON LWD DATA THAT IS REPROCESSED WITH UPDATED ALGORITHMS. RECEIVED 2. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE DEC 0 8 2003 ~~\\M\~ Aìas~a Oi¡ & Gas G\)ns. \.AJwmi,ðion Anchorage ) ) NOTED. 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 4. MWD RUNS 1 - 2 COMPRISED DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH GM; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); COMPENSATED THERMAL NEUTRON POROSITY (CTN); AND STABILIZED LITHO-DENSITY (SLD). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN 2-28B/0-19 ON 12 APRIL 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 11 JUNE 2003. 7. MWD RUNS 1 - 3 REPRESENT WELL 2-28B/0-19 WITH API#: 50-029-21847-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11058'MD / 10373'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED 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: 8.5" MUD WEIGHT: 10.4-10.5 PPG MUD FILTRATE SALINITY: 100 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...... .03/12/01 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT NPHI RHOB DRHO PEF CALA RPX RPS RPM RPD FET $ ) .5000 START DEPTH 8233.0 8288.5 9778.0 9778.0 9778.0 9792.0 9792.0 9792.0 9803.0 9835.5 9835.5 9835.5 9835.5 9835.5 ) STOP DEPTH 11031.0 11067.0 10975.0 10975.0 10975.0 10988.0 10988.0 10988.0 10977.5 11023.5 11023.5 11023.5 11023.5 11023.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8233.0 9020.5 9031.0 9043.0 9046.0 9049.0 9052.0 9059.0 9071.5 9075.0 9085.0 9099.0 9109.5 9116.5 9128.0 9142.5 9145.5 9149.0 9165.0 9177.5 9179.5 9185.0 9187.0 9190.5 9199.5 9203.0 9210.5 9218.5 9231.0 9241.0 9249.5 9252.0 9255.0 9262.5 9277.5 9288.5 9293.5 9305.5 9336.0 9352.0 9405.0 9411. 5 9416.0 9423.0 9425.0 9427.5 9455.5 9468.0 9481. 5 9497.0 9502.0 9511.5 GR 8229.0 9016.5 9027 . 0 9039.0 9041.5 9045.0 9048.0 9055.5 9067.0 9071.5 9081.0 9096.0 9106.0 9113.0 9124.0 9139.5 9142.5 9145.5 9161.0 9173.5 9176.0 9181.0 9183.0 9187.5 9195.5 9199.0 9206.5 9214.5 9227.5 9237.5 9245.0 9246.5 9249.0 9257.0 9272.5 9286.0 9289.5 9301.0 9331.5 9346.5 9401.0 9408.5 9414.0 9418.5 9420.5 9423.5 9450.0 9462.5 9476.0 9492.0 9498.0 9507.0 ) ) 9526.5 9524.0 9555.0 9551.0 9557.0 9554.0 9562.0 9559.5 9580.5 9576.5 9620.5 9615.0 9695.5 9690.5 9703.0 9698.5 9707.5 9703.0 9719.5 9713.5 9722.5 971 7.5 9730.0 9728.0 9736.0 9736.5 9740.5 9738.5 9748.5 9748.0 9756.0 9757.0 9765.5 9766.5 9768.0 9768.0 9776.0 9774.0 9777.0 9775.5 9779.0 9779.0 9792.0 9791.0 9794.0 9792.0 9797.5 9796.0 9800.0 9798.0 9812.5 9805.5 9818.0 9811. 0 9826.0 9816.0 9832.5 9823.0 9849.5 9844.5 9853.0 9848.0 9866.0 9862.5 9880.5 9876.0 9886.0 9881.5 9889.0 9884.0 9892.5 9887.5 9895.5 9891.0 9898.0 9893.5 9902.5 9897.5 9908.5 9901.5 9917 . 0 9910.5 9918.5 9914.0 9921.0 9916.0 9929.5 9924.0 9932.0 9926.5 9942.0 9936.0 9944.0 9937.5 9956.0 9951.0 9960.0 9954.0 9969.5 9965.0 9977.0 9973.0 9984.5 9979.5 9990.5 9986.0 9998.5 9994.0 10005.0 9998.5 10011.0 10006.0 10012.5 10007.5 10035.5 10027 . 5 10059.0 10051. 0 10065.0 10056.5 10090.0 10082.0 10170.0 10162.5 10203.0 10197.0 10206.5 10199.5 10210.0 10203.5 10229.0 10222.0 10259.5 10252.5 10267.5 10260.5 10277 . 0 10270.0 10287.5 10280.5 10296.0 10292.0 10307.5 10303.5 10319.0 10312.5 10339.0 10331.5 10352.0 10344.5 10354.0 10346.5 10357.0 10368.0 10407.5 10410.5 10413.5 10426.5 10437.5 10442.5 10448.5 10455.5 10458.0 10459.5 10463.0 10467.0 10473.5 10496.0 10513.0 10566.5 10602.0 10618.5 10622.5 10743.0 10765.0 10770.0 10791.0 10815.5 10915.5 10934.0 10941. 5 10958.5 11067.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: ') 10349.0 10360.5 10400.0 10403.0 10406.0 10418.5 10429.0 10435.0 10441. 0 10448.0 10451.0 10452.5 10456.0 10460.0 10466.5 10488.0 10506.0 10560.0 10595.5 10613.0 10616.0 10736.0 10758.0 10762.5 10783.5 10809.5 10908.5 10926.0 10932.0 10948.5 11057.5 BIT RUN NO 1 2 3 MERGE TOP 8229.0 9007.0 9870.0 MERGED MAIN PASS. $ MERGE BASE 9007.0 9870.0 11057.5 # 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 Spa c i n g. . . . . . . . . . . . . . . . . . . . . 60 . 1 IN Max frames per record............ .Undefined Absent value..................... .-999.25 Depth units.......... . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD CALA MWD Name Service Unit Units FT FT/H API OHMM OHMM OHMM OHMM HOUR PU-S CNTS CNTS G/CM G/CM BARN IN Min Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 Nsam Rep 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 Max Code Offset o 4 8 12 16 20 24 28 32 36 40 44 48 52 56 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Mean Nsam ) First Reading Last Reading ) ') DEPT FT 8233 11067 9650 5669 8233 11067 ROP MWD FT/H 0.44 247.22 40.2842 5558 8288.5 11067 GR MWD API 12.33 345.7 123.262 5597 8233 11031 RPX MWD OHMM 1. 46 2000 89.3302 2377 9835.5 11023.5 RPS MWD OHMM 1. 34 2000 110.768 2377 9835.5 11023.5 RPM MWD OHMM 1. 29 2000 125.517 2377 9835.5 11023.5 RPD MWD OHMM 1. 52 2000 232.8 2377 9835.5 11023.5 FET MWD HOUR 0.81 22.84 2.23123 2377 9835.5 11023.5 NPHI MWD PU-S 0.37 122.73 27.8782 2395 9778 10975 FCNT MWD CNTS 484 30000 1635.85 2395 9778 10975 NCNT MWD CNTS 102021 450000 142721 2395 9778 10975 RHOB MWD G/CM 1.211 2.903 2.36184 2393 9792 10988 DRHO MWD G/CM -0.229 0.525 0.0603999 2393 9792 10988 PEF MWD BARN 1. 43 10.75 3.83252 2393 9792 10988 CALA MWD IN 8.25 11.05 8.7759 2350 9803 10977.5 First Reading For Entire File......... .8233 Last Reading For Entire File.......... .11067 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/01 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...... .03/12/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 8229.0 8284.5 STOP DEPTH 8951. 5 9007.0 # 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: 27-MAR-03 Insite 4.3 Memory 9007.0 8229.0 9007.0 12.9 47.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 69706 # ) 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... ..0 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 8.500 8284.0 GEM 9.70 49.0 9.5 100 4.8 .000 .000 .000 .000 Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) .0 150.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8229 9007 8618 1557 8229 9007 ROP MWD010 FT/H 0.55 240.92 24.236 1446 8284.5 9007 GR MWD010 API 50.4 213.4 108.903 1446 8229 8951.5 First Reading For Entire File......... .8229 Last Reading For Entire File.......... .9007 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .03/12/01 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...... .03/12/01 ) Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ') header data for each bit run in separate files. 2 .5000 START DEPTH 8952.0 9007.5 STOP DEPTH 9814.5 9870.0 # 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 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......... . . . . . . . . .0 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 29-MAR-03 Insite 4.3 Memory 9870.0 9007.0 9870.0 36.5 45.9 TOOL NUMBER 69706 8.500 8284.0 GEM 10.40 43.0 9.4 100 3.8 .000 .000 .000 .000 .0 147.0 .0 .0 ) ') Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8952 9870 9411 1837 8952 9870 ROP MWD020 FT/H 1.18 247.22 45.4511 1726 9007.5 9870 GR MWD020 API 87.36 334.48 184.401 1726 8952 9814.5 First Reading For Entire File......... .8952 Last Reading For Entire File.......... .9870 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT RHOB DRHO PEF CALA GR RPX RPS RPM FET RPD ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 9777.5 9777.5 9777.5 9791. 0 9791.0 9791.0 9800.0 9815.0 9826.5 9826.5 9826.5 9826.5 9826.5 9870.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): STOP DEPTH 10965.0 10965.0 10965.0 10978.0 10978.0 10978.0 10967.5 11021.5 11014.0 11014.0 11014.0 11014.0 11014.0 11057.5 01-APR-03 Insite 6.02 Memory 11057.5 9870.0 11057.5 ) BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN ACAL $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON Acoustic Caliper # 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 . UN Max frames per record............ .Undefined Absent value..................... .-999.25 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ) 36.4 50.1 TOOL NUMBER 155789 134760 120993 179954 143790 8.500 8284.0 GEM 10.50 39.0 9.1 100 2.7 1.750 1.088 2.000 2.550 100.0 186.8 69.0 69.0 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 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 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 CALA MWD030 IN 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9777.5 11057.5 10417.5 2561 9777.5 11057.5 ) ) ROP MWD030 FT/H 0.44 232.72 46.2913 2375 9870.5 11057.5 GR MWD030 API 12.33 345.7 88.2093 2414 9815 11021.5 RPX MWD030 OHMM 1. 46 2000 90.2014 2376 9826.5 11014 RPS MWD030 OHMM 1. 34 2000 111.919 2376 9826.5 11014 RPM MWD030 OHMM 1. 29 2000 126.965 2376 9826.5 11014 RPD MWD030 OHMM 1. 52 2000 236.228 2376 9826.5 11014 FET MWD030 HOUR 0.81 22.84 2.31654 2376 9826.5 11014 NPHI MWD030 PU-S 0.37 122.73 27.8765 2376 9777.5 10965 FCNT MWD030 CNTS 484 30000 1636.81 2376 9777.5 10965 NCNT MWD030 CNTS 102021 450000 142723 2376 9777.5 10965 RHOB MWD030 G/CM 1.211 2.903 2.36207 2375 9791 10978 DRHO MWD030 G/CM -0.229 0.525 0.0604598 2375 9791 10978 PEF MWD030 BARN 1. 43 10.75 3.83794 2375 9791 10978 CALA MWD030 IN 8.25 11.05 8.78259 2336 9800 10967.5 First Reading For Entire File......... .9777.5 Last Reading For Entire File.......... .11057.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/12/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/12/01 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. . . . . . . . . . . . . . . . . . . . .03/12/01 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