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Home My WebLink About198-216Nolan 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: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -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: Please include current contact information if different from above. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 13, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 11-38A PRUDHOE BAY UNIT 11-38A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2024 11-38A 50-029-22723-01-00 198-216-0 W SPT 4954 1982160 1500 1898 1896 1900 1909 273 539 532 528 REQVAR P Kam StJohn 10/18/2024 2 Year MIT-IA to minimum of 1500 psi per AIO 4E.040 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 11-38A Inspection Date: Tubing OA Packer Depth 338 2662 2625 2621IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS241018124716 BBL Pumped:1.3 BBL Returned:1.3 Friday, December 13, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 99 99 99 9 9 AIO 4E.040 James B. Regg Digitally signed by James B. Regg Date: 2024.12.13 12:45:25 -09'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-38A Mud Acid Stimulation Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-216 50-029-22723-01-00 13871 Conductor Surface Production Liner Liner 8875 80 3741 10825 5853 3061 10213 20" 9-5/8" 7" 4-1/2" 2-7/8" 8686 34 - 114 34 - 3775 31 - 10856 5037 - 10890 10802 - 13863 34 - 114 34 - 3773 31 - 8835 5034 - 8835 8832 - 8875 unknown 470 3090 5410 7500 11160 10213 1490 5750 7240 8430 10570 9822 - 13780 4-1/2" 12.6# L-80 30 - 5048 8471 - 8877 Structural 4-1/2" Baker S-3 Perm , 4956 , 4954 No SSSV 4956 4954 Bo York Operations Manager Dave Wages David.Wages@hilcorp.com 907-564-4545 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028325 0 0 10303 19988 420 400 1628 1899 323-636 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 30 - 5045 0 0 By Kayla Junke at 1:38 pm, Feb 15, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.02.15 12:26:31 - 09'00' Bo York (1248) DSR-2/15/24 RBDMS JSB 022824 WCB 7-3-2024 ACTIVITYDATE SUMMARY 12/31/2023 SLB MIRU, Pressure test lines to 4500 psi OK. Pumped Mud Acid treatment per schedule including pre-flush, HCl, Mud Acid and Diverter. Three OilSEEKER diverter stages were pumped between 4 total stages of 16.6 bbls of 12% HCl, 16.6 bbls of 9:1 Mud Acid than a acid flush of 16.6 bbls NH4Cl. Average treating pressure for the job was 716 psi with an average rate of 975 psi. 12/31/2023 T/I/O = 1300/0/0 Assist w/ Mud Acid Job. Pumped 17 bbls 60/40 down TBG. Well left in SLB control. DSO called upon departure FWHP = 0/0/0 1/19/2024 ***WELL FLOWING ON ARRIVAL*** Spot In/Rig Up PT PCE 200lp - 3,500hp Perf Run #1 RIH with 1 7/16" Cable Head, 2" Weight Bar, 3 1/8" GR/CCL, 3 1/8" Perf Gun (Max OD = 3.125", Max Lenth = 48') Perf Intervel = 10,109' - 10,138' , CCL Offset = 7.4' , CCL Stop Depth = 10,101.6' ***WELL FLOWING ON DEPARTURE*** Job continued on 1/20/2024 1/20/2024 Job continued from 1/19/2024 ***WELL FLOWING ON ARRIVAL*** PT PCE 200lp - 3,000hp Perf Run #2 RIH with 1 7/16" Cable Head, 2" Weight Bar, 3 1/8" GR/CCL, 3 1/8" Perf Gun (Max OD = 3.125", Max Lenth = 48') Perf Intervel = 10,080' - 10,109' , CCL Offset = 7.4' , CCL Stop Depth = 10,072.6' Perf Run #3 RIH with 1 7/16" Cable Head, 2" Weight Bar, 3 1/8" GR/CCL, 3 1/8" Perf Gun (Max OD = 3.125", Max Lenth = 48') Perf Intervel = 10,051' - 10,080' , CCL Offset = 7.4' , CCL Stop Depth = 10,043.6' LOG CORRELATED TO READ P/T LOG DATED 08-NOV22 ***WELL FLOWING ON DEPARTURE*** Job continued on 1/21/2024 Daily Report of Well Operations PBU 11-38A g Three OilSEEKER diverter stages were pumped between 4 total stages of 16.6 bblsgg of 12% HCl, 16.6 bbls of 9:1 Mud Acid than a acid flush of 16.6 bbls NH4Cl. Average treating pressure for the job was 716 psi with an average rate of 975 psi. ) 10,080' - 10,109' ) Perf Intervel = 10,109' - 10,138' ) 10,051' - 10,080' Daily Report of Well Operations PBU 11-38A 1/21/2024 Job continued from 1/20/2024 ***WELL SHUT IN ON ARRIVAL*** PT PCE 200LP - 3000HP Perf Run #4 (31' Load) RIH with 1 7/16" Cable Head, 2" Weight Bar, 3 1/8" GR/CCL, 3 1/8" Perf Gun (Max OD = 3.125", Max Lenth = 51') Perf Interval = 10,020' - 10,051' , CCL Offset = 7.4' , CCL Stop Depth = 10,012.6' Perf Run #5 (16' Load) RIH with 1 7/16" Cable Head, 2" Weight Bar, 3 1/8" GR/CCL, 3 1/8" Perf Gun (Max OD = 3.125", Max Lenth = 32') Perf Interval = 10,004' - 10,020' , CCL Offset = 8.3' , CCL Stop Depth = 9,995.7'' Perf Run #6 (20' Load) RIH with 1 7/16" Cable Head, 2" Weight Bar, 3 1/8" GR/CCL, 3 1/8" Perf Gun (Max OD = 3.125", Max Lenth = 38') Perf Interval = 9,984' - 10,004' , CCL Offset = 7.4' , CCL Stop Depth = 9,976.6' RIG DOWN/MOVE OFF ***WELL FLOWING ON DEPARTURE*** Job complete ) 10,004' - 10,020' ) 9,984' - 10,004' ) 10,020' - 10,051' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 11-38A Mud Acid Stimulation Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-216 50-029-22723-01-00 ADL 0028325 13871 Conductor Surface Production Liner Liner 8875 80 3741 10825 5853 3061 10213 20" 9-5/8" 7" 4-1/2" 2-7/8" 8686 34 - 114 34 - 3775 31 - 10856 5037 - 10890 10802 - 13863 2344 34 - 114 34 - 3773 31 - 8835 5034 - 8835 8832 - 8875 unknown 470 3090 5410 7500 11160 10213 1490 5750 7240 8430 10570 9822 - 13780 4-1/2" 12.6# L-80 30 - 50488471 - 8877 Structural 4-1/2" Baker S-3 Perm No SSSV 4956 4965 Date: Bo York Operations Manager David Wages David.Wages@hilcorp.com 713-380-9836 PRUDHOE BAY, PRUDHOE 11/30/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:52 am, Nov 22, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.11.21 12:58:04 - 09'00' Bo York (1248) 323-636 MGR24NOV23 10-404 2344 * Approved for bullhead stimulation but pressure (hydrostatic + pump pressure) at sand face to not exceed PB oil pool confining zones. DSR-11/22/23SFD 11/24/2023 , ADL0028326 SFD JLC 11/24/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.24 15:22:01 -09'00' RBDMS JSB 022824 Mud Acid Well: 11-38a PTD: 198-216 API: 50-029-22723-01 Well Name:11-38a API Number:50-029-22723-01 Current Status:Operable – Online – PWI Rig:Fullbore Estimated Start Date:Dec 2023 Estimated Duration:1 day AFE:Cost: IOR:Revision:1 Regulatory Contact:Carrie Janowski First Call Engineer:David Wages (713) 380-9836 (M) Second Call Engineer:Dave Bjork (907) 564-4672 (O)(907) 440-0331 (M) Current Bottom Hole Pressure:3224 psi @ 8,800’ TVDss 7.1 PPGE Max Anticipated Surface Pressure:2344 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:0 psi Min ID:2.387” @ 10,806’ MD 2-7/8” x 3-1/2” XO Max Angle:93 deg @ 11,200’+ MD. 70 deg Dev:10,370’ MD AIO 4E.040 (2 year MIT-IA and either WFL or MIT-T to confirm tubing integrity) Latest MITs:10/3/2022 MIT-IA to 2545 psi Latest WFL:11/8/2022 Mem temp log Brief Well Summary: 11-38 was completed as a Z1 horizontal well in January 1997. Initial production was near 10,000 bopd, but the GOR rose quickly and the well was SI after only producing approximately 500 MSTBO. The well was brought on occasionally but generally wouldn't cycle. The well was sidetracked with CTD in November 1998 as a horizontal producer solely in Z1A and was completed with 660 feet of perforations in Zone 1A. Production levels remained at approximately 1,000 BOPD for over a year as the GOR steadily increased,eventually to levels of close to 30000 by the last quarter of 2000. The well was SI in 2000 due to PC and TxIA issues but fixed with a RWO scab liner in 2006. During that RWO, a USIT was obtained to verify cement quality over the Ivishak interval out of concern of injecting out of zone cause by faster than expected responses seen in offset producers. The USIT showed very good cement over the entire Ivishak interval. At the same time the well was also converted to a WATER ONLY injector and put on injection. Well has a history of intermittent OAxIA communication. 11-38a is currently under-injecting by about 7400 bwpd. Injection volumes have been declining with a consistent wellhead pressure. Prosper modelling indicates that we have a total skin value of ~65 leaving much room for improvement. Acid jobs on PBE injectors have shown significant improvement in individual well injectivity. Expected uplift from this job is 7000 bwpd based on offsets. 1/19/1997: Drilled 12/1998: CTD sidetrack 1/2006: RWO to replace corroded tubing. During this workover, a USIT was run while the tubing was out of the well to confirm TOC in the 7” casing.The USIT showed very good cement to 9690’. Almost immediately after the RWO, the cellar started showing fluid. 2/8/2006: SBHPS, drifted to 10,585’ 2/19/2006: Hot MIT-IA passed 3/27/2006: MIT-OA showed communication to the IA 2/7/2008: Injecting MIT-IA passed 10/21/2008: Bleed IA from 1130 to 600 psi, OA pressure decrease by 360 psi. 11/20/2011: MIT-IA pass, OA pressure increased by ~30 psi Mud Acid Well: 11-38a PTD: 198-216 API: 50-029-22723-01 8/24/2013: Brightwater treatment pumped 2/1/2016: Coil attempt to test LTP, unable to enter liner top seal bore, slim junk mill tagged at 10,935’, 24 arm caliper showed 2.5’ of good sealbore remaining aboffve 2-7/8” crossover. 1.75” slim drift tagged again at 10,945’. 11/2016: Set IBP, MIT-T pass, pull IBP 11/8/2022: Memory temp log per AIO 4E (next log required 11/2024) 8/2023: SL drift, fullbore pump SBG and Eline set EVO and perforate 23P for pre-PAVE production 9/2023” SL pull EVO, EL perforate for PAVE injection 10/2023: Fullbore pump HOT Objective: Mud acid treatment Procedure: Ops – 1.Drop SBG sticks for schmoo cleanup prior to acid job Fullbore/Special Projects –Ensure OE is either on the slope or on the phone for job: 1. MIRU, pressure test to 4500 psi 2. Pump the following pump schedule: a. Initial Max pressure is 2100 psi. b. Max rate: 7 BPM c. For every divert stage, we expect pressure to increase. Since the fluids are all fairly close to the same density, the increase in pressure should be associated with backpressure from the diverter. d. When divert stages arrive on perfs, keep rate constant, whatever the treating pressure increases to, that is how much we will increase our max pressure e. Ultimate Max pressure is 4000 psi with 0 psi on the IA Pressure at sand face not to exceed PB confining zones fracture pressure. - mgr Mud Acid Well: 11-38a PTD: 198-216 API: 50-029-22723-01 Ops – POI as soon as possible. We want to take advantage of cold fluid injection potentially improving well injectivity. Mud Acid Well: 11-38a PTD: 198-216 API: 50-029-22723-01 Current Wellbore Schematic: 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-38A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-216 50-029-22723-01-00 13871 Conductor Surface Production Liner Liner 8875 80 3741 10825 5853 3061 10213 20" 9-5/8" 7" 4-1/2" 2-7/8" 8686 34 - 114 34 - 3775 31 - 10856 5037 - 10890 10802 - 13863 34 - 114 34 - 3773 31 - 8835 5034 - 8835 8832 - 8875 unknown 470 3090 5410 7500 11160 10213 1490 5750 7240 8430 10570 9822 - 13780 4-1/2" 12.6# L-80 30 - 5048 8471 - 8877 Structural 4-1/2" Baker S-3 Perm , 4968 , 4965 No SSSV 4968 4965 Bo York Operations Manager David Wages David.Wages@hilcorp.com 907.564.4545 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028325 30 - 5045 00 0 6936 13778 405 277 1890 1819 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" TIW SS 10758 , 8830 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 0 By Grace Christianson at 8:54 am, Nov 07, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.11.06 08:06:54 - 09'00' Bo York (1248) DSR-11/15/23 RBDMS JSB 110823 WCB 3-14-2024 ACTIVITYDATE SUMMARY 8/7/2023 ***WELL S/I ON ARRIVAL***(schmoo be gone, b&f, drift) LRS PUMPS 180 BBLS OF SBG @ 2 BPM RAN DUAL 4'1/2" BRUSH, 3.25" GAUGE RING, BRUSH DOWN TO AND DEVIATE OUT @ 10,693' SLM (82-85^) RAN DUAL 4-1/2" BRUSH, 3.80" GUAGE RING DEVIATE OUT @ 10,688' SLM RAN BARBELLED 3.70" CENT (6 ft), DRIFT TO DEP SLV @ 10,799' SLM / 10,802' MD (see log, lrs pump down hole) DRIFT W/ 34.5' x 2-7/8" DMY GUNS (2.98 od) TO 10,330' SLM, (target depth of 10,302' md, see log) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED*** 8/7/2023 T/I/O= 1294/0/34 LRS Unit 72 Assist Slickline Pump 180 BBLS Schmoo-B-Gone (SBG) down the TBG. Three hour soak. Pumped 133 BBLS 1% KCL down the TBG for flush. FWHP's 1315/0/28 8/17/2023 ***WELL FLOWING ON ARRIVAL*** PT PCE 250LP-3000HP PERFORATE FROM 10272' - 10304' MD, WITH 15 GRAM GEO RAZOR XDP CHARGES. 6 SPF, 60 DEG PHASED. CCL STOP DEPTH=10260.4' MD, CCL TO TS=11.6', TIED INTO READ PRESS/TEMP LOG 8-NOV-2022. SET 4.5" HES EVO TRIEVE AT 10345' MD, CCL STOP DEPTH=10314.9', CCL TO ME=30.1' SET 4.5" JUNK CATCHER ON EVO TREAVE AT 10345' MD. TOP OF JUNK CATCHER AT 10336' MD. (73" OAL) ***WELL READY FOR PRODUCATION, OPERATOR NOTIFIED*** 8/19/2023 T/I/O = 10/Vac/Vac. Temp = SI. T FL (Ops req). No AL. T FL @ 470'. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:20 9/17/2023 *** WELL S/I ON ARRIVAL*** RAN 4 1/2" GR TO 10,334' SLM (UNABLE TO LATCH JUNK CATCHER). RAN 10' x 3" PUMP BAILER TO 10,334' SLM (EMPTY). ***WSR CONTINUED ON 9-18-23*** 9/18/2023 ***WSR CONTINUED FROM 9-17-23*** RAN 4 1/2" GR TO 10,333' SLM, UNABLE TO LATCH CATCHER. RAN 2.5" PUMP BAILER TO 10,333' SLM (EMPTY, WITH FISHNECK MARKS). RAN KJ, 4 1/2" GR TO 10,333' SLM, UNABLE TO LATCH CATCHER. RAN 3.68" LIB TO 10,333' SLM, TWO OPPOSING HALF MOONS WITH 2.90" ID AND 3.25" OD. PULL 4-1/2" JUNK CATCHER FROM 10,334' SLM. PULL 4-1/2" EVOTRIEVE FROM 10,337' SLM. ***WELL LEFT S/I ON DEPARTURE*** 9/28/2023 ***WELL SHUT IN ON ARRIVAL*** Pressure test PCE from 200lp - 3000hp (1X) RIH with 1 7/16" Cable Head, (2x) 2" Weight Bars, 3.60" RB, 3.125" CCL/Gamma, Baker 10 Setting Tool, 3.50" CIBP ( Max OD = 3.60" , Max Lenth = 20') Plug Set Depth = 10,213.1' , CCL Offset = 13.1', CCL Stop Depth = 10,200' ***SHUT IN WELL ON DEPARTURE*** Job continued 29-SEP-23 Daily Report of Well Operations PBU 11-38A PERFORATE FROM 10272' - 10304' MD )g 3.50" CIBP Plug Set Depth = 10,213.1 Daily Report of Well Operations PBU 11-38A 9/29/2023 Job continued from 9/28/23 ***WELL SHUT IN ON ARRIVAL*** Pressure test PCE from 200lb - 3000lb Gun #1 RIH with 1 7/16" Cable Head, 3.60" RB, 3.125" Gamma/CCL, 3.60" RB, 3 3/8" Perf Guns, (Max OD = 3.60" , Max Lenth = 42') Shooting Depth = 9,982' - 9,951' , CCL Offset = 9.7' , CCL Stop Depth = 9,941.3' Gun #2 RIH with 1 7/16" Cable Head, 3.60" RB, 3.125" Gamma/CCL, 3.60" RB, 3 3/8" Perf Guns, (Max OD = 3.60" , Max Lenth = 42') Shooting Depth = 9,951' - 9,920' , CCL Offset = 9.7' , CCL Stop Depth = 9,910.3' ***WELL SHUT IN ON DEPARTURE*** Job continued on 9/30/23 9/30/2023 Job continued from 29-SEP-23 ***WELL SHUT IN ON ARRIVAL*** Pulled out of rope socket on surface. Shut down pending investigation. ***WELL SHUT IN ON DEPARTURE*** 10/4/2023 ***WELL SHUT IN ON ARRIVAL*** Pressure test PCE from 200lb - 3000lb Gun #3 RIH with 1 7/16" Cable Head, 3.60" RB, 3.125" Gamma/CCL, 3.60" RB, 3 3/8" Perf Guns, (Max OD = 3.60" , Max Lenth = 40') Shooting Depth = 9891' - 9920' , CCL Offset = 9.3' , CCL Stop Depth = 9881.7' Called to assist ASR rig Rig down/move off ***WELL SHUT IN ON DEPARTURE*** Job incomplete 10/6/2023 ***WELL SHUT IN ON ARRIVAL*** Rig Up/Spot In Pressure Test PCE from 200lp - 3000hp Job Continued on 10-7-23 10/7/2023 ***WELL SHUT IN ON ARRIVAL*** Pressure Test PCE from 200lp - 3000hp Gun #4 RIH with 1 7/16" Cable Head, 3.60" RB, 3.125" Gamma/CCL, 3.60" RB, 3 3/8" Perf Guns, (Max OD = 3.60" , Max Lenth = 40') Shooting Depth = 9862' - 9891' , CCL Offset = 9.3' , CCL Stop Depth = 9852.7' Gun #5 RIH with 1 7/16" Cable Head, 3.60" RB, 3.125" Gamma/CCL, 3.60" RB, 3 3/8" Perf Guns, (Max OD = 3.60" , Max Lenth = 40') Shooting Depth = 9833' - 9862' , CCL Offset = 9.3' , CCL Stop Depth = 9823.7' ****Job continues on 10-8-23**** ( Shooting Depth = 9891' - 9920' ( Shooting Depth = 9,982' - 9,951' ( Shooting Depth = 9862' - 9891' ( Shooting Depth = 9,951' - 9,920' ( Shooting Depth = 9833' - 9862' , Daily Report of Well Operations PBU 11-38A 10/8/2023 High pressure breakdown. *** Job continued on 10/09/23 *** 10/8/2023 ***CONTINUES FROM 07OCT23 WSR*** (ADPERF) Pressure Test PCE 200lp - 3000hp Gun #6 RIH with 1 7/16" Cable Head, 3.60" RB, 3.125" Gamma/CCL, 3.60" RB, 3 3/8" Perf Guns, (Max OD = 3.60" , Max Lenth = 30') Shooting Depth = 9822' - 9833' , CCL Offset = 12.2' , CCL Stop Depth = 9809.8' Rig Down/Move Off ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE 10/9/2023 T/I/O = 1830/140/140. Temp = 136°. Assist Ops w/ POI. OA FL @ surface. Bled OAP as needed to assist Ops returning a total of 0.2 bbls of fluid. Final WHPs = 1830/170/30. SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:00 10/9/2023 *** Job continued from 10/08/23 *** T/I/O 2443/0/50. Pump 3 bbl 60/40 and 280 bbl crude into TBG.Master, Wing, SSV, IA, OA left open. Swab left closed. FWHP 2246/1/83. Pad op notified upon depature. ( Shooting Depth = 9822' - 9833' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-38A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-216 50-029-22723-01-00 13871 Conductor Surface Production Liner Liner 8875 80 3741 10825 5853 3061 10345 20" 9-5/8" 7" 4-1/2" 2-7/8" 8735 34 - 114 34 - 3775 31 - 10856 5037 - 10890 10802 - 13863 34 - 114 34 - 3773 31 - 8835 5034 - 8835 8832 - 8875 10802 470 3090 5410 7500 11160 10345 1490 5750 7240 8430 10570 10272 - 13780 4-1/2" 12.6# L-80 30 - 5048 8709 - 8877 Structural 4-1/2" Baker S-3 Perm , 4968 , 4965 No SSSV 4968 4965 Bo York Operations Manager David Wages David.Wages@hilcorp.com 907.564.4545 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028325 30 - 5045 0 547 0 37826 0 29 0 0 0 878 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 3:35 pm, Sep 15, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.09.15 14:42:58 -08'00' WCB 3-13-2024 DSR-9/15/23 ACTIVITYDATE SUMMARY 8/7/2023 T/I/O= 1294/0/34 LRS Unit 72 Assist Slickline Pump 180 BBLS Schmoo-B-Gone (SBG) down the TBG. Three hour soak. Pumped 133 BBLS 1% KCL down the TBG for flush. FWHP's 1315/0/28 8/7/2023 ***WELL S/I ON ARRIVAL***(schmoo be gone, b&f, drift) LRS PUMPS 180 BBLS OF SBG @ 2 BPM RAN DUAL 4'1/2" BRUSH, 3.25" GAUGE RING, BRUSH DOWN TO AND DEVIATE OUT @ 10,693' SLM (82-85^) RAN DUAL 4-1/2" BRUSH, 3.80" GUAGE RING DEVIATE OUT @ 10,688' SLM RAN BARBELLED 3.70" CENT (6 ft), DRIFT TO DEP SLV @ 10,799' SLM / 10,802' MD (see log, lrs pump down hole) DRIFT W/ 34.5' x 2-7/8" DMY GUNS (2.98 od) TO 10,330' SLM, (target depth of 10,302' md, see log) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED*** 8/17/2023 ***WELL FLOWING ON ARRIVAL*** PT PCE 250LP-3000HP PERFORATE FROM 10272' - 10304' MD, WITH 15 GRAM GEO RAZOR XDP CHARGES. 6 SPF, 60 DEG PHASED. CCL STOP DEPTH=10260.4' MD, CCL TO TS=11.6', TIED INTO READ PRESS/TEMP LOG 8-NOV-2022. SET 4.5" HES EVO TRIEVE AT 10345' MD, CCL STOP DEPTH=10314.9', CCL TO ME=30.1' SET 4.5" JUNK CATCHER ON EVO TREAVE AT 10345' MD. TOP OF JUNK CATCHER AT 10336' MD. (73" OAL) ***WELL READY FOR PRODUCATION, OPERATOR NOTIFIED*** Daily Report of Well Operations PBU 11-38A SET 4.5" HES EVO TRIEVE AT 10345' MD, PERFORATE FROM 10272' - 10304' MD David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 11/16/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 11-38A PTD: 198216 API: 50-029- 22723-01-00 PRESSURE/TEMPERATURE LOG (08-Nov-2022) SFTP Transfer Please include current contact information if different from above. By Meredith Guhl at 3:42 pm, Nov 16, 2022 198-216 T37263 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.16 15:43:23 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 9, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 11-38A PRUDHOE BAY UNIT 11-38A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/09/2022 11-38A 50-029-22723-01-00 198-216-0 W SPT 4954 1982160 1500 1805 1811 1836 1831 260 496 496 498 REQVAR P Adam Earl 10/3/2022 MIT IA tested as per AIO 4E.040 to 1500psi 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UNIT 11-38A Inspection Date: Tubing OA Packer Depth 473 2614 2554 2545IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE221003205609 BBL Pumped:1 BBL Returned:1 Friday, December 9, 2022 Page 1 of 1 MIT IA tested as per AIO 4E.040 to 1500psi MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 20, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC II -38A PRUDHOE BAY UNIT 11-38A Sre: Inspector Reviewed By: P.I. Sup" JTz— Comm Well Name PRUDHOE BAY UNIT I t -38A API Well Number 50-029-22723-01-00 Inspector Name: Adam Earl Permit Number: 198-216-0 Inspection Date: 10/132020 Insp Num: mitAGE201018092021 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ]1 38A 'Type Inj p✓'iTVD 4954 - I Tubing 1855 1858 1856 1857 - — PTD 1982160 Type Test SPT `Test psi - 1500 1 IA 19 2395 - 2341 2329 BBL Pumped: 13 BBL Returned: 1.7 1 OA 310 577 - 573 567 Interval REQvAR IP/F P Notes: MIT IA tested as per AIO 4E.040� Tuesday, October 20, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ++ DATE: Wednesday,November 30,2016 P.I.Supervisor he�C IL;1`1w SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. I I-38A FROM: Lou Grimaldi PRUDHOE BAY UNIT 11-38A Petroleum Inspector Src: Inspector Reviewed By: ,, P.I.Supry �1-' ` - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-38A API Well Number 50-029-22723-01-00 Inspector Name: Lou Grimaldi Permit Number: 198-216-0 Inspection Date: 11/29/2016 Insp Num: mitLG161129192027 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min _- — — II 38A I i W TV 4954 = 729 -7 — 733 ,7 Well ' Type In � 'TVD Tubing 736 - 733 - 1982160 SPT1500 225 2300 _ PTD - lype Test ITest psi IA 2257 _ 2254 , Interval IIREQVAR — P ✓I OA 326 576 , 570 - ! 568 • Notes: 1.2 bbls ambient diesel pumped, 1.1 retumed.Good solid test required by Variance A.I.O.4E.040,all required paperwork supplied by Mr. Stephens. A4icteitiit.. 7 ( 1 f . ^es ply _)'-\ C i(yz'J— iJe l sc4e:uev c SCANNED APR 2 7 2017 Wednesday,November 30,2016 Page 1 of 1 • 0 • • _______. PIAAPri II , -‘ V" 3' -,....,. I 1 : • A• t.t I 0 0 i 1:1 M ..t • .1., • • ..4z • 19 -.. , 1 ,-1 i 1 .., , . ,, .,. . . . .1 , 1•1 MT 4-1/16.aw WELL YM�HEAa= FRAC SAFETY NOTES: WL AN0LE>70•a 1037W. Fes.F3 La/= 64.27 -38A DURING CTD SDTROBSTRUCTION K,AN OOBSTRUCTIONWAS MOTS IN 2-7/8"LNR 013700'(NO FORM). BF.B..EV= 30.10' KOP= 6100 Mix Angle= 97'Q 116611` ' r 2103' 4-1/2'HES X NIP,D.3.613• Datum 14)= 12932 Datum TVD= 8800'SS 9-5/8'CSG,401,L-80.13=8.835' H 3776' L 4878' -3-BKR BP(11/14/16) 11110-4 I I I 4925' -I4-1/2'HES XIV,D=3.813' Minimum ID =2.387"@ 10806' S 4956' 17•X4-1/2'BKR S 3 Rat D=3.875• 3-1/2"X 2-7/8" LNR XO ' ' 4849' --4-12'4E5 X rP,D=3.813' ' � 1 5029' 1--7'x 5'OKR ZXP LP TOP PKR w TIEBACK SLV,D=4.410' 14-12'TBG,12.61,L-80 TCA.0152 bpf,0=3.958' H 6040' ------- 5040' -14-112-M LE SHCOE,D=3.958' 1.1 �. 504T --1 T x 5'BKR RD( IR FG LOK LR,D=4.410' I 1/ 1414 1t 5057' -15-10 X 4-12D'XO, =4.00' � 1111 ♦�41 ( 9997' ,--I3'BKR BP(11/14/18) 111 ,111 • X•11, 11•i 1i' :1' 10662 H4-1rr 1-Es w c EmerrER 1!i' .i!i 1 ` 10674' H7'X4-1/2'BKR F3rPPPM,D=3.90' 4-1/2'SCAB LIR,12.6+1,L-80 BT,D=3.958' H 10749' 10758' J-7'X 4-1/2'TM/SS HORIZ P102,13=3.924' 2006 RWO NOM 0 1174$ (10'DISCREPANCY) ????? -F6-t MILLED FASORLL 14/304ANT(01/07/08 MO) 10802' H3-3/4"BKR DF3FLOY RENT SLV.13=3.00' ' 10808' H3-1/2"X 2-7/8'LNR XO,D=2.387' L-8 7'CSG,286, 0,D -- =8278' H 10868' } -• 4-1R'LIR SELLOUT WIIOOW 106!0`-10104' (OFF CMT RAMP) PERFORATION SUMMARY FIEF LOG:SINS MIAOW CAL ON 12101/98 111111. MOLE AT TOP PEW:87'Q 12970' 111111./111111.i Note:Refer to Production OB for historical pert data 1/1111414141111 SIZE SW INTERVAL OpnfSgz DATE 1111111111 2' 4 12970-13510 0 12/02/98 111114IN 1111♦ 2' 4 13660-13780 0 12/02/98 11111 11111 1/1/1/111 ♦111♦ 11111 1/11111/11 414141410 1/1/1/111/ 1/1/11111/ 11/1111111 ILM OBSTRUCTION? H 13780' /'1'1'111' .'' ///111111' PBTD 13828' 4-1/2'LNR 12.81,L-80,.0152 bpf,D=3.958' 13160' 2-7/8'L$,8.51,L-80,.0058 bpf,D=2.387' H 13863' DATE RTV BY OOMrBrTS DATE REV BY CO90.134175 PRUDHOEBAY I-NT 01119/87 ORIGINAL COMPLETION WELL: 11-38A 12/02/88 CTD OM-TRACK FER149T Pb: 1982160 01f00108 D16 ,_YO _ AR Pb: 50-029-22723-01 0122106 BMc WTLH ORLG GRAFT CORRECTIONS SEC 33,1-11N,R15E 5115'NSL 8101'WEL 11/17/16 KPS/.MO SET2 BKR Ws(11/14/16) BP Hrplorafloe(Alaska) I • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Sunday, November 20, 2016 6:31 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Field OTL;AK, OPS FS2 Facility OTL;AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr;G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov' Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;Worthington,Jessica; Dickerman, Eric; Regg,James B (DOA);Odom, Kristine Subject: OPERABLE :Injector 11-38A(PTD#1982160) All, Injector 11-38A(PTD#1982160),operating under Administrative Approval AIO 4E.040 for shallow packer depth, is now ready to be placed on injection. The well was shut in and classified as not operable due to not being online for its AA test anniversary date of October 26, 2015. At this time,the well has been reclassified as Operable to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Slickline: Perform temperature survey as required by AA 3. Downhole Diagnostics: Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Thank you, Jost /14t04, BP Well Integrity Specialist Office: 907-659-5766 Harmony-2377 A Its 7„ate°: Josh SCANNED NOV 2 2 2016 GYY OGlobanlW.mt�oreth ra 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, April 05, 2016 4:41 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL;AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Sinnok, Ralph; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Munk, Corey; Odom, Kristine; Pettus, Whitney Subject: NOT OPERABLE :Injector 11-38A (PTD #1982160) Due for AOGCC MIT-IA All, Injector 11-38A (PTD#1982160) is no longer available for injection. The well is reclassified as Not Operable until ready to be brought online for updated compliance testing and has been added to the Quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) APR 2 12010 BPPAllasska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, ell Integrity Coordinator Sent: Wednesday, March 30, 2016 6:12 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daa-rriel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; nnok, Ralph; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison,_Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA)'; Munk, Corey; Odom, Kristine; Pettus, Whitney �� Subject: UNDER EVALUATION : Injector 11-38A (PTD #1982160) Dueler,A0GCC MIT-IA All, Injector 11-38A(PTD#1982160), operating under Administrative Approval A10 4E.040 for shallow packer depth, is now ready to be placed on injection. At this time, the well has been reclassified as Under Evaluation to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~/- '~/~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts. Pages: <~7 / ~ Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha~owell Date: '~'//? ,s,,~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ OF ALAS AIWA OIL AND G STCONSERVATITION COMMI N RECEIVED REPORT OF SUNDRY WELL OPERATIONS SEP 25 2D3 1.Operations Abandon U Repair WellU Plug Perforations Lf PerforateLI Other nele terTreatment • g Performed: Alter Casing 0 Pull Tubin Stimulate-Frac 0 Waiver El Time Extensi `••+ Change Approved Program 0 Operat.Shutdown Stimulate-Other Li Re-enter Suspended WeIrj 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development] Exploratory 0 198-216-0 • 3.Address: P.O.Box 196612 Stratigraphi1 . Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-22723-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028325 • PBU 11-38A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL , 11.Present Well Condition Summary: Total Depth measured 13871 • feet Plugs measured None feet true vertical 8870.02 . feet Junk measured 10802 feet Effective Depth measured 13781 feet Packer measured See Attachment feet true vertical 8876.58 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 34-114 34-114 1490 470 Surface 3741 9-5/8"40#L-80 34-3775 34-3772.63 5750 3090 Intermediate None None None None None None Production 10825 7"26#L-80 31-10856 31-8835.03 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12970-13510 feet 13660-13780 feet SCANNED N O V 2 I z8),- True Vertical depth 8866.04-8879.4 feet 8880.42-8876.63 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 30-5048 30-5045.6 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12970'-13510',13660'-13780' Treatment descriptions including volumes used and final pressure: 5020 Gallons EC9360A Surfactant,25000 Gallons EC9398A Polymer,500 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 13878 • 0 1423 Subsequent to operation: 0 0 7219 0 546 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator)Q Development 0 Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas U WDSPtD GSTOR ❑ WINJ 0• WAG ❑ GINJ 0 SUSP ❑ SPLUCj 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catron@BP.Com Printed Name Garry Catron Title PDC PE Signature j 4 Phone 564-4424 Date 9/24/2013 V 1- is//5 //3 Atop// 41 ot A Form 10-404 Revised 10/2012 R +.T I N A L Submit Original Only R 4 BDMS OCT 11 , • • Packers and SSV's Attachment ADL0028325 SW Name Type MD TVD Depscription 11-38A PACKER 4968 4901.38 4-1/2" Baker S-3 Perm Packer 11-38A PACKER 5049 4982.38 5" Baker ZXP Top Packer Casing / Tubing Attachment ADL0028325 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20" 91.5#H-40 34 - 114 34 - 114 1490 470 LINER 5719 4-1/2" 12.6# L-80 5037 - 10756 5034.6 - 8830.13 8430 7500 LINER 125 4-1/2" 12.6#L-80 10765 - 10890 8830.6 - 8835.55 8430 7500 LINER 3061 2-7/8"6.4# L-80 10802 - 13863 8832.75 - 8870.73 10566 11165 PRODUCTION 10825 7"26#L-80 31 - 10856 31 - 8835.03 7240 5410 SURFACE 3741 9-5/8"40# L-80 34 - 3775 34 - 3772.63 5750 3090 TUBING 5018 4-1/2" 12.6# L-80 30 - 5048 30 - 5045.6 8430 7500 • • • • Daily Report of Well Operations ADL0028325 Irrrrrrmwr T/I/O = 500/50/100, Temp= 60*(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 551.25 gal. EC9360A(Surfactant) Average of 45 gph for 12.25 hrs. Pumped a total of 551.25 gal. since start of project. Pumped 2700 gal. EC9398A( Polymer) Average of 225 gph for 12 hrs. Pumped a total of 2700 gal. since start of project 8/24/2013 ***Establishing rates with proving pots*** ***Job continued to WSR*** ***Job continued from 8/24/13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection 7000 bwpd. P injection © P 9 9 Pumped 1080 gal. EC9360A(Surfactant) Average of 45 gph for 24 hrs. Pumped a total of 1631.25 gal. since start of project. Pumped 5400 gal. EC9398A( Polymer) Average of 225 gph for 24 hrs. Pumped a total of 8100 gal. since start of project 8/25/2013 ***Establishing rates with proving pots*** ***Job continued to 8/26/13 WSR*** ***Job continued from 8/25/13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 1080 gal. EC9360A(Surfactant) Average of 45 gph for 24 hrs. Pumped a total of 2711.25 gal. since start of project. Pumped 5400 gal. EC9398A( Polymer) Average of 225 gph for 24 hrs. Pumped a total of 13500 gal. since start of project 8/26/2013 ***Establishing rates with proving pots*** ***Job continued to 8/27/13 WSR*** ***Job continued from 8/26/13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 1080 gal. EC9360A(Surfactant) Average of 45 gph for 24 hrs. Pumped a total of 3791.25 gal. since start of project. Pumped 5400 gal. EC9398A( Polymer) Average of 225 gph for 24 hrs. Pumped a total of 18900 gal. since start of project 8/27/2013 ***Establishing rates with proving pots*** ***Job continued to 8/28/13 WSR*** ***Job continued from 8/27/13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped xx gal. EC9360A(Surfactant) Average of xx gph for 24 hrs. Pumped a total of xx gal. since start of project. Pumped xx gal. EC9398A( Polymer) Average of xx gph for 24 hrs. Pumped a total of xx gal. since start of project 8/28/2013 ***Establishing rates with proving pots*** ***Job continued to 8/29/13 WSR*** • Daily Report of Well Operations ADL0028325 ***Job continued from 8/27/13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 1080 gal. EC9360A(Surfactant) Average of 45 gph for 24 hrs. Pumped a total of 4871.25 gal. since start of project. Pumped 5400 gal. EC9398A( Polymer) Average of 225 gph for 24 hrs. Pumped a total of 24300 gal. since start of project 8/28/2013 ***Establishing rates with proving pots*** ***Job continued to 8/29/13 WSR*** ***Job continued from 8/28/13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 148.5 gal. EC9360A(Surfactant) Average of 45 gph for 3.3 hrs. Pumped a total of 5019.75 gal. since start of project. Pumped 700 gal. EC9398A( Polymer) Average of 225 gph for 3.11 hrs. Pumped a total of 25000 gal. since start of project ***Establishing rates with proving pots*** FWHP=500/20/180 WV, MV, SSV= Open SV= Shut IA, OA= OTG Well on injection 8/29/2013 at 7.3K BWPD at departure TREE= 4-1/16"CM/ • SOY NOTES: WELL ANGLE>70°@ 10370'. WELLHEAD= FMC D G CTD SDTRK,AN OBSTRUCTION WAS NOTED ACTUATOR= BAKER C 1 1 -38 A IN 2-7/8"LNR@ 13780'(HO FORM). KB. ELEV= 64.22' BF. ELEV= 30.10' KOP= 6100' Max Angle= 97 @ 11611' I I Datum MD= 12932' 2103' 1-14-1/2"HES X NIP, ID=3.813" Datum TVD= 8800'SS 9-5/8"CSG,404,L-80, ID=8.835" H 3775' 1-411 [ 1 1 I 4926' I-I4-1/2"HES X NIP,ID=3.813" I Minimum ID = 2.387" @ 10806' Z g-1 4956' I-17"X 4-1/2"BKR S-3 PKR, ID=3.875" I 3-1/2" X 2-7/8" LNR XO I I 4989' H4-1/2"HES X NIP,ID=3.813" I - 5029' I-7"x 5"BKR ZXP LNR TOP PKR w/TIEBACK SLV, ID=4.410" 4-1/2"TBG, 12.64, L-80 TCII, .0152 bpf, ID=3.958" H 5040' I - ■ 5040' H 4_1/2"MULE SHOE, ID=3.958" I ♦ `,: Ili 5047' H 7"x 5"BKR FLEX LOK LNR HNGR, ID=4.410" I 44 1•1 5057' H 5-1/2"X 4-1/2"XO, ID=4.00" •' 1 10652' H4-1/2"HES DV CEMENTER I V 10674' I-I 7"X 4-1/2"BKR ECP PKR, ID=3.90" I 14-1/2"SCAB LNR, 12.6#, L-80 IBT, ID=3.958" H 10749' I 21 '= 10758' I-7"X 4-1/2"TM/SS HORIZ PKR,ID=3.924" 2006 RWO NOTED @ 10748'(10'DISCREPANCY) 99999 IH FISH:MILLED FASDRILL REMNANT(01/07/06 RWO) I h1 10802'_ -I3-3/4"BKR DEPLOYMENT SLV, ID=3.00" I 7"CSG,264,L-80, ID=6.276" -I 10856' I--■ ■ 10806' -13-1/2"X 2-7/8"LNR XO, ID=2.387" I 4-1/2"LNR MILLOUT WINDOW 10890'-10894' (OFF CMT RAMP) PERFORATION SUMMARY OW REF LOG:SWS MEMORY CNL ON 12/01/98 �.�.�.�.�. ANGLE AT TOP PERF:87 @ 12970' .�.4..41 Note: Refer to Production DB for historical perf data 0..0 SIZE SPF INTERVAL Opn/Sgz DATE ....O∎ 2" 4 12970-13510 0 12/02/98 .04.4 ...**I ..... 2" 4 13660- 13780 0 12/02/98 ..... MO *O KI 13780' WM ��1�1�U LNR OBSTRUCTION? �.�.... 'MI/ 1/�//...1 PBTD -I 13826' ■ 4-1/2"LNR, 12.64,L-80, .0152 bpf, ID=3.958" H 13150' •••••' 2-7/8"LNR,6.5#,L-80, .0058 bpf, ID=2.387" H 13863' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/19/97 ORIGINAL COMPLETION WELL: 11-38A 12/02/98 CTD SIDETRACK PERMIT No: 1982160 01/09/06 D16 RWO API No: 50-029-22723-01 01/22/06 BMcN/TLH DRLG DRAFT CORRECTIONS SEC 33,T11 N, R15E 5115'NSL&101'WEL BP Exploration(Alaska) I • • SEAN PARNELL, GOVERNOR ALASKA OIL AND GrAs 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 �4 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4E.040 Mr. Douglas Cismoski, P.E. Wells Intervention Manager BP Exploration (Alaska) Inc. P.O. Box 196612 SLAMMED FEB (' 8 2012 Anchorage, AK 99519 -6612 RE: PBU 11 -38A (PTD 1982160) Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Cismoski: On its own motion, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS an administrative approval to continue water injection in the subject well pursuant to Rule 9 of Area Injection Order (AIO) 4E.000. PBU 11 -38A is a redrill of 11 -38 that was drilled and completed in December 1998 and converted to a service well in January 2006. A workover was conducted in association with the conversion to replace leaking tubing and to investigate the possibility of a Cretaceous casing leak. The tubing string was recovered and a long "scab" liner was set to isolate damaged casing. The new 4 -1/2" liner top was established at 5029' and and a new packer was set at 4956' md. As constructed, 11 -38A does not meet the requirements of 20 AAC 25.412 (b) for an injection well which is required to be equipped with a packer set not more than 200' measured depth above the top of the perforations. The purpose of this requirement is to ensure that the injection string can be monitored throughout its length via the casing tubing annulus for possible leakage. As constructed, in excess of 6000' of this wellbore cannot be monitored. Where fresh water is not affected, 20 AAC 25.450 gives the Commission authority to approve less stringent well construction and integrity requirements. For wells similarly constructed, the Commission has exercised this discretionary authority and approved injection operations with the fluid limited to water only. AOGCC's administrative approval to continue WATER INJECTION ONLY in PBU 11 -38A is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; I • • AIO 4E.040 January 9, 2012 Page 2 of 2 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates and volumes; 3. BPXA shall demonstrate the continued integrity of the injection string every 2 years. An MIT -T employing a deep plug set within 200' and of the 2 -7/8" liner top at 10802' and or by performing a diagnostic log such as water flow or temperature logs may be performed; 4. BPXA shall perform a mechanical integrity test of the inner annulus ("MIT - IA") to a minimum of 1500 psi every 2 years to demonstrate continued integrity of production casing; 5. BPXA shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and 6. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection; DONE at Anchorage, Alask.. • • :t -. . ary 9, 2012. 4414Ar‘Oe aniel T eamount • K. No a Cathy . Foerster Or,14 Chair, ommissioner Com ,• ' : oner Commissioner cc: BPXA Well Integrity Coordinator, PRB -20 n L . P.O. Box 196612 'j.'►''" .. 6 �. Anchorage, AK 99519 -6612 opt: `off 9Ti N cormA RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, December 23, 2011 TO: Jim Regg ( s P.I. Supervisor 1 �a 1 Z 1 03 / Il SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 11 -38A FROM: John Crisp PRUDHOE BAY UNIT 11 -38A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .,J - NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 11 - 38A API Well Number: 50 029 - 22723 - 01 - 00 Inspector Name: John Crisp Insp Num: mitJCr111125090226 Permit Number: 198 - 216 - Inspection Date: 11/23/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11 -38A 'Type Inj. W TVD 4954 -' IA 491 3021 - 2947 2934 - P.T.D 1982160 , TypeTest SPT Test psi 1500 - OA 107 420 408 401 Interval OTHER - P/Fi P ." Tubing 482 484 485 486 Notes: 2 year requirment due to shallow packer depth. 1.19 bbls pumped for test. Friday, December 23, 2011 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 - 14NED JAN 2 4 ZU l E 1F. " Mr. Tom Maunder � Alaska Oil and Gas Conservation Commission JAN 0 3 Q1'! 333 West 7 Avenue Anchorage, Alaska 99501 g u t e . A e. nit P - a ons c ; F SSiOR Pe Subject: Corrosion Inhibitor Treatments of GPB DS 11 ncrrrbR Dear Mr. Maunder, 1 1 — 3 6A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 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, Torin Roschinger BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12/21/10 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 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1 81 1280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100_ NA Sealed NA NA 6/25/2010 11 -04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 ,50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1 851 590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 _ NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 _ NA 42.50 7/1/2010 11-38A 1982160 50029227230100 _ NA 2.1 NA 22.10 6/28/2010 Recent MITIAs for 11-38A (PTD.#1960), R-03A (PTD #1981710), WGI-OS (PTD #1900250) Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~, ~'2e~~`~~ Sent: Sunday, February 17, 2008 6:41 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: Recent MITIAs for 11-38A (PTD #1982160), R-03A (PTD #1981710), WGI-05 (PTD #1900250) Follow Up Flag: Follow up ~ ~ ,,. ~ ~, Flag Status: Red Attachments: MIT PBU 11-38A 02-12-08.xis; MIT PBU R-03A 02-12-08.xfs; MIT PBU WGI-05 02-12-08.x1s Hi Jim, Tom, and Bob, Please find the attached MITIA forms for 11-38A (PTD #1982160), R-03A (PTD #1981710), and WGI-05 (PTD #1900250). /11-38A: 2-year MITIA for UIC compliance of a monobore injector R-03A: 4-year MITIA for UIC compliance and qualification for MI service WGI-05: 4-year MITIA for UIC compliance «MIT PBU 11-38A 02-12-08.x1s» «MIT PBU R-03A 02-12-08.x1s» «MIT PBU WGI-05 02-12-08.x1s» Please let us know if you have any questions. Thank you, 2/19/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT !PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. ~ ~ ~) 2LJ~ ~~ Prudhoe Bay /PBU / 11 02/12/08 Anna Dube Packer Dept Pretest Ini ' 15 Min. 30 Min. Well 11-38A Type Inj. W TVD 54 Tubing 1660 1 60 1660 1660 Interval O P.T.D. 1982160 Type test P Test psi 1500 Casing 40 ~ 3000 2900 2870 P/F P Notes: 2-year MIT-IA for UIC compliance for monobore OA 230 600 600 600 injector Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Nat Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 9!1/05 MIT PBU 11-38A 02-12.OS.xls Jim... A rig workover was completed on PBU 11-38A in January 2006. A 4-1/2" scab liner was run and cemented from 10,749' to 5,047', see the enclosed well bore diagram for details. Consequently the majority of the inner annulus below the packer at 4,956' is filled with cement. The AOGCC witnessed a passing mechanical integrity test on February 19, 2006. The subject well is operating in compliance with the Jan. 10, 2006 AOGCC Approved Application for Sundry Approval. A Report of Sundry Well Operations (10-404) was submitted to the AOGCC on Feb. 9, 2006. Please let me know if you have any questions regarding this well. Harry Engel Wells Group Staff Engineer 564-4194 "f"Ì>.j\,INEi ;;;:!''''>~¡ ,',., "c From: James Regg [mailto:jimJegg@admin.state.ak.us] Sent: Friday, February 24, 20065:02 PM To: NSU, ADW Well Integrity Engineer; Charles M Scheve; Winton GAubert Subject: Re: WGI-08 MIT-IA (PTD #1900490), 13-31A MIT-IA (PTD #2051600), 11-38A MIT-IA (PTD #1982160) 4 Year MITIA PBU 11-38A shows packer at 4956 ft, injection perfs beginning at 12970 ft. How will you verifY the well's mechanical integrity below the shallow set packer? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Jim, Winton, and Bob, Please see the attached MITIA forms for wells WGI-08 MIT-IA (PTO #1900490), 13-31A MIT-IA (PTO #2051600), 11-38A MIT-IA (PTO #1982160). WGI-08 and 11-38A where tested post rig workover. 13-31A was tested post initial injection post sidetrack. AOGCC representative Chuck Scheve witnessed the tests. «MIT PBU WGI-08 02-19-06.xls» «MIT PBU 11-38A 02-19-06.xls» «MIT PBU 13-31A 02-19-06.xls» I of2 3114/2006 10:05 AM Thank you, .Jlnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 e e .Jlnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 11-38A.pdf 11-38A.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 3114/2006 10:05 AM I TREE = 4-1/16" CrN SAFETY NOTES: WELL ANGLE> 700@ 10370'. FMC e OUR_TO SDTRK, AN OBSTRUCTION WAS NOTED ¡ WELLHEAD = 1 1-38A ÃêTUATOR;" .. BAKER C IN 2- NR@ 13780' (HO FORM). KB. ELEV = 64.22' >"........,_.-...........",............. "'- BF. ELEV = 30.10' KOP= 6100' Max Angle = 97@ 11611' I 2103' 1-4-1/2" HES X NIP, 10 = 3.813" I Datuml\J1D::: 12932' . Datum TV [) ,; 88()()'55 19-5/8" CSG, 40#, L-80, ID = 8.835" , 3775' -µ .. . I l 4926' 1-4-1/2" HESXNIP, 10=3.813" I ~ ~ 4956' l-j 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" I Minimum ID = 2.387" @ 10806' ~ 3-1/2" X 2-7/8" LNR XO I I 1 4989' H4-1/2" HES X NIP, ID = 3.813" I Il- l..-----{ 5029' 7" x 5" BKR ZXP LNR TOP PKR I I w /TIEBACK SL V, 10 = 4.410" 14-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" I 5040' 1-4-1/2" MULE SHOE, 10 = 3.958" I 5040' iii Ai- I -; 5047' 1-17" x 5" BKR FLEX LOK LNR HNGR, ID = 4.410" I ~ , 5057' H 5-1/2" X 4-1/2" XO, ID = 4.00" I 10652' 1-4-1/2" HES DV CEMENTER I ~ 10674' I- 7" x 4-1/2" BKR ECP PKR, ID = 3.90" I 4-1/2" SCAB LNR, 12.6#, L-80 IBT, 10 = 3.958" I 10749' ~ ~ 10758' 7" x 4-1/2" TIW SS HORIZ PKR, 10 = 3.924" ~ ~ 2006 RWO NOTED@ 10748' (10' DISCREPANCY) ...-, ...-H ????? FISH: MILLED FASDRILL REMNANT (01/07/06 RWO) r 10802' -H3-3/4" BKR DEPLOYMENT SLV, 10= 3.00" I ~ -.¡ ""- I 7" CSG, 26#, L-80, 10 = 6.276" I 10856' ~ ~I 10806' !-i3-1/2"X2-7/8"LNRXO, 10=2.387" I 4·1/2" LNR MILLOUT WINDOW 10890' - 10894' (OFF CMT RAMP) ~ ÆRFORA TION SUMMARY REF LOG: SWS MEMORY CNL ON 12/01/98 ANGLEAT TOP ÆRF: 87@ 12970' Note; Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12970 - 13510 0 12/02/98 2" 4 13660 - 13780 0 12/02/98 I LNR OBSTRUCTION? I 13780' r , I PBTD I 13826' -~ 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 13150' I I 12-7/8" LNR, 6.5#, L-80, .0058 bpf , 10 = 2.387" I 13863' 1 OATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 01/19/97 ORIGINAL COMPLETION WELL: 11-38A 12/02/98 CTD SIDETRACK ÆRMrr No: '1982160 01/09/06 D16 RWO API No: 50-029-22723-01 01/22/06 BMcN/TLH ORLG DRAFT CORRECTIONS SEC 33, T11 N, R15E 5115' NSL & 101' WEL BP Exploration (Alaska) MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg 7e10 bI6'C~, P.I. Supervisor <. DATE: Wednesday, February 22,2006 SUBJECT: Mechanical Integrity Tests DP EXPLORATION (ALASKA) INC Il-38A PRUDHOE BAY UNIT II -38A \ t\ ~ / '}.\ (p FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv J73f2-- Comm Well Name: PRUDHOE BAY UNIT 11-38A Insp Num: mitCS060220064927 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-22723-01-00 Permit Number: 198-216-0 Inspector Name: Chuck Scheve Inspection Date: 211912006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ;'~F~~~-!*:~~¿l~ ~p~¡E~::CI~~¡ -:~fF7:r:ue:~jT.. --- ~Int~a:vªL~O~~_.~;/F' -. -==~ ~=~~T·~bin~ 2~~~._~·~150Ju 2150.. _~2I50=~ ---~~~- - ---~== Notes The packer in this well is set at 4956' MD the top perf is at 12970'. This MIT tested the upper 1/3 of the well bore only, ~CJr.e~~~~~ :1 ~J Wednesday, February 22, 2006 Page I of I t( I:: L; I:: I V I:: U A STATE OF ALASKA _ ALAS~L AND GAS CONSERVATION COWRVIISSION FEB 092006 REPORT OF SUNDRY WELL OPERATIONSlaskaOiI&GasCons.Commi Anchorage 1. Operations Performed: o Abandon o Suspend o Operation Shutdown o Perforate o Other o Alter Casing IS! Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program IS! Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. permit 10 Drill Number: BP Exploration (Alaska) Inc. o Development o Exploratory 198-216 3. Address: o Stratigraphic IS! Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22723-01-00 7. KB Elevation (ft): 64.22' 9. Well Name and Number: PBU 11-38A 8. Property Designation: 10. Field / Pool(s): ADL 028326 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 13871 feet true vertical 8870 feet Plugs (measured) None Effective depth: measured 13826 feet Junk (measured) None true vertical 8874 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3741' 9-5/8" 3775' 3773' 5750 3090 Intermediate 10825' 7" 10856' 8835' 7240 5410 Production Liner 129' 4-1/2" 10765' - 10894' 8831' - 8836' 8430 7500 Liner 3061' 2-7/8" 10802' - 13863' 8833' - 8871' 10570 11160 Liner 5720' 4-1/2" 5029' - 10749' 5027' - 8830' ß430 7500 I ? [\. uti t;;.\;/},~~,f.·,lEU r (i~ '- - Perforation Depth MD (ft): 12790' - 13780' \1J..f,[¡;¡'~ ". ': .. Perforation Depth TVD (ft): 8866' - 8877' 4-1/2", 12.6# L-80 5040' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" TIW SS Horizontal Packer; 7" x 5" Baker 'ZXP' 10748'; 5029'; 4956' liner top packer/hanger; 7" x 4-1/2" Baker 'S-3' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5029' - 10749' (4-1/2" Scab Liner) Treatment description including volumes used and final pressure: RBDMS 8Ft FEE J :1 2006 Cemented Scab Liner with 504 sx Class 'G' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: IS! Daily Report of Well Operations o Exploratory o Development IS! Service IS! Well Schematic Diagram 16. Well Status after proposed work: OOil o Gas o WAG OGINJ IS! WINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to tne Dest OT my Knowleage. I Sundry Number or N/A If C.O. Exempt: Contact Paul Chan, 564-5254 305-246/ 306-006 Printed Name Terrie Hubble Title Technical Assistant Signature ~ 1\ ^ ~ 0 tIu ~ Phone 564-4628 o 2ft e Æ Prepared By Name/Number: Date 0 0& Terrie Hubble, 564-4628 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only Well: Field: API: Permit: e e 12/25/05 N/A 01/09/06 Doyon 16 05/07/05 DRIFTED WI 3.25 CENT AND 2.75 LIB. TAG PX PLUG AT 9571' SLM (IMPRESSION OF PRONG). LOGGED IN HOLE WI PDS TOOLS AT 100 FPM TO 9571' SLM, LOGGED OOH AT 60 FPM WHILE LRS PUMPED. 11-38A (Rig Workover) Prudhoe Bay Unit 50-029-22723-01-00 198-216 Accept: Spud: Release: Rig: 08/25/05 DRIFTED WITH 3.70" CENTRALIZER. TAGGED TOP OF PX PLUG PRONG AT 9577' SLM. PRE-RIG WORK 09/02105 DEPTH CORRELATED TO BP TUBING TALLY DATED 16-JAN-1997. JET CUT TUBING AT 9575'. DID NOT TAG TD. NO CHANGE IN PRESSURES BY END OF JOB. BP EXPLORATION Page 1 of 11 Operations Summary Report legal Well Name: 11-38 Common Well Name: 11-38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 1 2/25/2005 End: 1/9/2006 Contractor Name: DOYON DRilLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task I Code I N~~ Phase Description of Operations ----.---------- ... ....----.-... 12/23/2005 00:00 - 03:30 3.50 MOB P DECOMP Rig Down Top Drive and Bridal Up. LID Pipe Chute 03:30 - 04:00 0.50 MOB P DECOMP Move Rig Off of S-03 and Position on Pad. 04:00 - 07:00 3.00 MOB P DECOMP Remove BOPE from Cellar, Lay Derrick Over, Install Booster Wheels. 07:00 - 14:00 7.00 MOB P DECOMP Move Rig from S-Pad to Spine Road and Across Bridges. Drive System for Rig Broke Down. 14:00 - 00:00 10.00 MOB P DECOMP Troubleshoot and Repair Drive System for Rig. 12/24/2005 00:00 - 05:00 5.00 MOB P DECOMP Troubleshoot and Repair Rig Drive System. Change Out Hydraulic Drive Motor on Rear Drillers Side Wheel System. 05:00 - 20:30 15.50 MOB P DECOMP Move Rig to DS-11 . 20:30 - 21 :00 0.50 MOB P DECOMP Remove Rear Booster Wheels. 21 :00 - 22:30 1.50 MOB P DECOMP Raise and Pin Derrick. 22:30 - 00:00 1.50 MOB P DECOMP Install BOPE on Cellar Stand. Rig Up Floor. 12/25/2005 00:00 - 01 :30 1.50 MOB P DECOMP Spot Rig on Well 11-38A. Level Rig. 01 :30 - 03:30 2.00 MOB P DECOMP Spot Cuttings Tank. Berm Rig, Rig Up Floor. Install Secondary Annulus Valve. Take on Fluid. Accept Rig at 02:00 Hrs. 03:30 - 04:30 1.00 KILL P DECOMP Bleed Pressure Off IA. Starting Pressure 325 psi. 04:30 - 06:00 1.50 KILL P DECOMP Rig Up DSM and Pull BPV. Rig Down DSM. 06:00 - 07:00 1.00 KILL P DECOMP Displace Diesel Freeze Protect from Well. Pump Rate 250 gpm at 600 psi. 07:00 - 08:30 1.50 KILL P DECaMP Displace Well with 400 bbls of 9.7 ppg NaCI Brine Heated to 120 Degrees. Pump Rate 250 gpm at 900 psi. 08:30 - 10:00 1.50 WHSUR P DECaMP Monitor Well, Install TWC and Test from Below to 1,000 psi. 10:00 - 12:00 2.00 WHSUR P DECOMP Blow Down Lines and Nipple Down Tree 12:00 - 13:30 1.50 WHSUR P DECOMP Terminate Control Lines, Inspect Hanger Lifting Threads and Test XO, 8 Turns. Clear Cellar. 13:30 - 16:30 3.00 BOPSU P DECOMP Nipple Up BOP Stack and Riser. 16:30 - 17:30 1.00 BOPSU P DECOMP Make Up Test Equipment and Fill Lines. 17:30 - 22:30 5.00 BOPSU P DECaMP Tested Annular to 250 psi /3,500 Tested BOPE to 250 psi / 3,500 psi. Test #1. Hydril, Upper IBOP, Kill Line HCR, Choke HCR. Test #2. Manual Choke, Manual Kill, Lower IBOP, TIW. Test #3. Dart Valve, Manual Kill, Manual Choke, Lower IBOP. Test #4. Choke Valves #1,12,13,14. Test #5. Choke Valves #9, 11, Blind/Shear Rams. Test #6. Choke Valves #5,8,10. Test #7. Choke Valves #4, 6, 7. Test #8. Choke Valve #2. Test #9. Choke Valve #3 Test #10. Bottom Pipe Rams All BOPE Tests Held for 5 min Each. Accumulator Test-lnitial Pressure 3,000 psi, After Closure 1,750 psi, Initial 200 psi Recovery 16 sec, Final 1 min 20 sec. 5 btls at 2,200 psi Avg. Gas Detectors Callibrated and Tested. John Crisp of AOGCC Waived Witness of BOP Test. Test Witnessed by BP Drilling Supervisor and Doyon Tool Pusher 22:30 - 23:00 0.50 BOPSU P DECaMP Lay Down BOP Test Assembly. 23:00 - 00:00 1.00 BOPSU P DECOMP Rig Up DSM Lubricator and Lubricator Extension, Pull TWC. Rig Down Lubricator Assembly. 12/26/2005 00:00 - 00:30 0.50 PULL P DECaMP Make Up Landing Joint. 00:30 - 01 :30 1.00 PULL P DECaMP Back Out Lock Down Screws. Pull Hanger to Floor. Up Weight 150,000 Ibs. Lay Down Hanger. 01 :30 - 03:00 1.50 PULL P DECaMP Circulate Bottoms Up at 250 gpm with 1,000 psi. Took 20 bbls Printed: 1/16/2006 1:10:41 PM BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: 11-38 Common Well Name: 11-38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 12/25/2005 End: 1/9/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 I Date · From - To i Hours Task Code NPT· Phase Description of Operations · . · . ----.------ .. ._____n ....-----------.-- - - 12/26/2005 01 :30 - 03:00 1.50 PULL P DECOMP to Fill Well. 03:00 - 07:30 4.50 PULL P DECOMP Lay Down 41/2" , 12.6#, L-80 MBT Tubing with Dual Control Lines. 07:30 - 08:00 0.50 PULL P DECaMP Lay Down SSSV. Rig Down Camco Control Line Spooler. 08:00 - 15:30 7.50 PULL P DECaMP Lay Down 41/2" , 12.6#, L-80 MBT Tubing. Recovered 226 Joints, 5 GLM's, 1 SSSV, 36 Stainless Steel Bands and 1 Cut Joint 8.25'. 15:30 - 16:30 1.00 PULL P DECOMP Rig Down Tubing Handling Equipment. Clear and Clean Rig Floor. 16:30 - 17:00 0.50 CLEAN P DECaMP Install Wear Ring. 17:00 - 19:00 2.00 CLEAN P DECaMP P/U BHA #1. BHA is 6.125" Packer Mill, 3 x 4.75" Junk Baskets, Bit Sub, 4.75" Fishing Jar, XO, 18 x 4.75" Drill Collars, 21 x HWDP. Total Length is 1,224.71' 19:00 - 00:00 5.00 CLEAN P DECaMP P/U 4" HT-38 DP from 1,224' to 5,061 '. 12/27/2005 00:00 - 05:30 5.50 CLEAN P DECaMP PI U 4" DP from 5,061 Tag at 9,567'. PI U 261 Joints. 05:30 - 08:00 2.50 CLEAN P DECaMP Establish Milling Parameters, Pump Rate 360 gpm at 2,750 psi, 80 RPM at 9,000 ft / Ibs of Torque off Bottom, 10,000 - 11,000 ft Ibs on Bottom. Up Weight 195,000#, Down Weight 150,000#, Rotating Weight 165,000#. Mill Packer. 08:00 - 10:00 2.00 CLEAN P DECOMP Milled Packer, Well Taking Fluid. Initial Loss Rate 144 bph. Fill Well From the Top, Monitor Well. Cut Pit Volume From 9.7 ppg to 9.5 ppg. 10:00 - 12:00 2.00 CLEAN P DECOMP Displace Well to 9.5 ppg Brine. Loss Rate 25 bph. 12:00 - 13:00 1.00 CLEAN P DECOMP POOH with 4" Drillpipe to 8,615' 13:00 - 14:00 1.00 CLEAN P DECaMP PI U 30 Joints of 4" Drillpipe From Pipeshed to 9,574' 14:00 - 15:30 1.50 CLEAN P DECaMP Push Packer to 10,702' 15:30 - 16:30 1.00 CLEAN P DECaMP Break Circulation, Pump 20 bbl High- Vis Sweep Around. Pump Rate 420 gpm at 2,900 psi. Up Weight 185,000#, Down Weight 163,000#, Torque 9,000 ft Ilbs at 30 rpm. 16:30 - 21 :30 5.00 CLEAN P DECOMP Monitor Well. Mud Weight 9.5 ppg. Break Out and Blow Down Top Drive. POOH from 10,702'. 20,000 Ibs Excess Drag While Pulling Off Bottom. 21 :30 - 22:00 0.50 CLEAN P DECaMP Lay Down Mill and Boot Baskets. Recovered 1 Gallon of Metal Cuttings. 22:00 - 00:00 2.00 CLEAN P DECOMP Make Up BHA #2. Spear with 3.885" Grapple, 5.75" Stop Sub, 4.75" Bumper Sub, 4.75" Fishing Jar, XO, 9 x 4.75" Drill Collars, XO, 4.75" Intensifier, XO, 33 Joints 4" HT-38 Drillpipe, 9 x 4.75" Drill Collars, 21 Joints 4" HWDP. Total BHA Length 2,288.54' 12/28/2005 00:00 - 03:30 3.50 CLEAN P DECOMP RIH with BHA #2 to 10,675'. 03:30 - 05:00 1.50 CLEAN P DECOMP Established Parameters, Pump Rate 168 gpm, 815 psi. String Weight Up 210,000#, String Weight Down 150,000#, Rotating Weight 170,000#, Torque 7,500 ft / Ibs at 40 rpm. Slacked Off to 10,704' and Engaged Packer. Stacked 50,000# on Fish, Observed 20 psi Increase in Pump Pressure. Shut Off Pump and Picked Up. String Weight Up 220,000#, Slacked Off to 110,000#, Picked Up, String Weight Up 220,000#, POOH to 10,675'. 05:00 - 12:00 7.00 CLEAN N RREP DECaMP Repaired Drawworks Drive Chain. 12:00 - 13:00 1.00 CLEAN P DECaMP Slipped and Cut Drilling Line. 13:00 - 16:00 I 3.00 CLEAN P DECaMP Monitored Well. Static Losses 8.5 bph. Brine Weight 9.5ppg. POOH from 10,675' to BHA. 16:00 - 17:00 1.00 CLEAN P DECOMP Stand Back BHA. No Fish. Discuss BHA Options with Printed. 1/16/2006 1:10:41 PM BP EXPLORATION Operations Summary Report Page 3 of 11 Legal Well Name: 11-38 Common Well Name: 11-38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 12/25/2005 End: 1/9/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 Date From - To ! Hours I Task Code NPT Phase i Description of Operations I ~ ! --..-----'----------- . . .__u__.___.... 12/28/2005 16:00 - 17:00 1.00 CLEAN P DECOMP Anchorage. Lay Down Spear Assembly. 17:00 - 17:30 0.50 CLEAN P DECaMP Clean and Clear Rig Floor. 17:30 - 19:30 2.00 CLEAN P DECaMP Make Up BHA #3. BHA Consists of 3.75" 5 Blade Junk Mill, Spear Extension, XO, 3 x 4.75" Boot Baskets, Bit Sub, String Magnet, Fishing Jar, XO, 18 x 4.75" Drill Collars, 21 x HWDP. Total BHA Lenght 1,234.86' 19:30 - 23:30 4.00 CLEAN P DECOMP RIH with BHA #3 to 10,640'. Make Up Top Drive and Establish Parameters. Pump Rate 1,840 psi Off Bottom at 168 gpm. Up Weight 217,000#, Down Weight 145,000#, Rotating Weight 175,000# at 40 rpm and 7,500 ft Ilbs Off Bottom Torque. 23:30 - 00:00 0.50 CLEAN P DECOMP Wash from 10,640' to 10,702' 12/29/2005 00:00 - 02:30 2.50 CLEAN P DECaMP Milled Junk Inside Packer from 10,704' to 10,710', WOM 10,000#, rpm 40, Torque on Bottom 10,000 ft /Ibs, Pump Rate 4 bpm, 2,270 psi. After Milling to 10,710', Pumped 40 bbls Hi-Vis Sweep and Circulated Bottoms Up. Shut Down Pump and PI U to 10,690', Slacked Off to 10,710' to Ensure Packer Free of Junk, OK. Monitored Well, Static Loss Rate 4 bph. Blew Down Top Drive. Brine Weight 9.5 ppg. 02:30 - 07:00 4.50 CLEAN P DECOMP POOH wI 4" DP from 10,710' to 500'. 07:00 - 09:00 2.00 CLEAN P DECOMP POOH wI BHA, B I 0 Boot Baskets, String Magnet and Mill. C I o Boot Baskets and Magnet, Recovered 1/2 Gallon of Metal Cuttings, and 3 x Larger Pieces of Metal. 09:00 - 11 :30 2.50 FISH P DECaMP M I U BHA, Spear wI 3.885" Grapple, 5.75" Stop Sub, 4.75" Bumper Sub, String Magnet, 4.75" Fishing Jar, XO, 9 x 4.75" Drill Collars, XO, 4.75" Intensifier, XO, 33 Joints 4" HT-38 Drillpipe, 9 x 4.75" Drill Collars, 21 Joints 4" HWDP. Total BHA Length 2,294.04'. 11 :30 - 14:00 2.50 FISH P DECOMP RIH with BHA on 4" DP to 10,650'. 14:00 - 15:00 1.00 FISH P DECOMP M I U Top Drive, Established Parameters, String Weight Up 210,000#, String Weight Down 148,000#, Pump Rate 5 bpm, 1,250 psi. Washed Down to 10,704', Tagged Top of Packer at 10,704'. Worked Drill String to Engage Spear into Packer, Slacked Off and Stacked 30,000# on Fish, PI U to 10,680', Engaged Pump 5 bpm, 1,500 psi. 250 psi Increase in Pump Pressure. Shut Down Pump, RIH, Observed Increase in Drag wI Both Pick Up and Slack Off. 15:00 - 19:00 4.00 FISH P DECOMP POOH wI 4" DP, Observed Overpull of 40,000# - 50,000# Every 40' from 10,650' to 10,170'. Continue to POOH to BHA. 19:00 - 20:00 1.00 FISH P DECaMP Stand Back BHA #4 20:00 - 20:30 0.50 FISH P DECOMP Lay Down Recovered Packer and Tailpipe Assembly. 20:30 - 21 :00 0.50 FISH P DECOMP Clear and Clean Rig Floor. 21 :00 - 21 :30 0.50 CLEAN P DECOMP Make Up BHA #5, 6.125" Bit, 7" Casing Scraper, 3 x 4.75" Boot Baskets, Bit Sub, 4.75" Bumper Sub, String Magnet, 4.75" Fishing Jar, XO, 18 x 4.75" Drill Collars, 21 x 4" HWDP. Total BHA Length 1,238.47' 21 :30 - 00:00 2.50 CLEAN P DECaMP RIH with BHA #5 on 4" Drillpipe to 6,707' 12/30/2005 00:00 - 02:00 2.00 CLEAN P DECOMP RIH with BHA #5 on 4" Drillpipe from 6,707' to 10,741 '. Establish Parameters, Up Weight 210,000#, Down Weight 140,000#, Rotating Weight 172,000#, Off Bottom Rotary Torque 8,000 ft Ilbs at 40 rpm, Off Bottom Pump Pressure I 3,210 psi at 420 gpm. 02:00 - 02:30 0.50 CLEAN !P DECaMP Wash from 10,741' Tag Up at 10,748'. Set 20,000# Down on Top of Liner. Printed: 1/16/2006 1: 1 0:41 PM BP EXPLORATION Page 4 of 11 Operations Summary Report legal Well Name: 11-38 Common Well Name: 11-38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 12/25/2005 End: 1/9/2006 Contractor Name: DOYON DRilLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 I From - To Hours Task Code NPT' Phase L__.. Description of Operations I ...------ 12/30/2005 02:30 - 03:30 1.00 CLEAN P DECOMP Pump 40 bbl Safeclean Sweep followed by 420 bbls of Clean 9.5 ppg Brine. Pump Pressure 3,230 psi at 420 gpm. 03:30 - 04:00 0.50 CLEAN P DECOMP Monitor Well. Static Loss Rate 3 bph. Brine Weight 9.5. Pump Dry Job, Blow Down Top Drive. 04:00 - 09:00 5.00 CLEAN P DECOMP POOH with BHA #5 from 10,748' to BHA 09:00 - 09:30 0.50 CLEAN P DECOMP Stand Back BHA #5 09:30 - 10:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 10:00 - 13:00 3.00 EVAL P DECOMP Rig Up Schlumberger Wireline Unit and Surface Well Control Equipment. 13:00 - 15:30 2.50 EVAL P DECOMP RIH with USIT Logging Tools on E-Line to 10,650'. Unable to get Deeper Due to High Angle of Well Bore. 80 Degrees at 10,650'. 15:30 - 21 :30 6.00 EVAL DECOMP Logged Up from 10,650' to 2,000', Correlated Depth to MCNL, Dated 12/1/98. Log Indicated Good Cement Isolation 10,650' to 10,000'. Top of Cement 3,750'. Logged in High Resolution Mode 6.000' to 5,700', Unable to Locate Suspected Leak at 5,812'. 21 :30 - 00:00 2.50 EVAL P DECOMP Rig Down Schlumberger Wireline and Surface Well Control Equipment. 12/31/2005 00:00 - 00:30 0.50 EVAL P DECOMP M I U Halliburton 7" RBP. 00:30 - 03:00 2.50 EVAL P DECOMP RIH with Halliburton 7" RBP on 4" Drillpipe. 03:00 - 03:30 0.50 EVAL P DECOMP Set 7" RBP at 5,605'. 03:30 - 04:00 0.50 EVAL P DECOMP R I U Circulating Head and Lines. R I U Test Chart. 04:00 - 05:00 1.00 EVAL P DECOMP Closed Pipe Rams, Pressure Tested 7" Casing from Surface to 5,605' to 4,000 psi for 30 Minutes, OK. 05:00 - 05:30 0.50 EVAL P DECOMP Bled Down Pressure, Opened Pipe Rams, Released 7" RBP. 05:30 - 08:30 3.00 EVAL P DECOMP Monitored Well, Brine Weight 9.5 ppg. POOH wi 4" DP from 5,605'. 08:30 - 09:00 0.50 EVAL P DECOMP B I 0 and LID HES 7" RBP. 09:00 - 10:00 1.00 CASE P TIEB1 Held PJSM. R I U 4-1/2" Liner Handling Equipment. 10:00 - 10:30 0.50 CASE P TIEB1 M I U 4-1/2" Guide Shoe Assy wi FasDril Plug Set in Pup Joint and 1 Joint 4-1/2" 12.6# L-80 IBT Liner. Bakerloc'd Connection. Mixed and Poured Down Tubing 15 gal AS-1 Cement. 10:30 - 13:00 2.50 CEMT P TIEB1 Waited on AS-1 Cement to Set Up. 13:00 - 13:30 0.50 CASE P TIEB1 M I U ECP Payzone Packer Assy and ES Cementer Assy, Bakerloc'd All Connections Below ES Cementer. 13:30 - 18:30 5.00 CASE P TIEB1 M I U and RIH wi 138 Joints 4-1/2" 12.6# L-80 IBT Liner. Average M I U Torque 2,800 ft I Ibs. Applied Best-O-Life 2000 Pipe Dope to All Connections. Filled Liner Every 5 Joints. 18:30 - 19:30 1.00 CASE P TIEB1 C I 0 to 4" DP Handling Equipment. M I U Baker ZXP Liner Top Packer I Flex-Lok Liner Hanger Assy wi Hydraulic Setting Tool. 19:30 - 22:30 3.00 CASE P TIEB1 RIH wi 4-1/2" Liner on 4" DP to 10,749', Filled Pipe Every 5 Stands. 22:30 - 23:30 1.00 CASE P TIEB1 M I U Cement Head and Lines. 23:30 - 00:00 0.50 CASE P TIEB1 Hold PJSM with All Personnel Involved. 1/1/2006 00:00 - 01 :00 1.00 CEMT P TIEB1 Establish Parameters. Up Weight 173,000#, Down Weight 133,000#. Set at 10,749'. Pressure Up to 1,600 psi. S 10 to 80,000#, Pressure Up to 2,200 psi to Inflate ECP. Pressure Up to 2,850 psi Hold for 2 Minutes and Bleed to 0 psi. Pressure Up Cementer opened at 2,750 psi. Circulate Bottoms Up, 1,750 psi at 273 gpm. 01 :00 - 02:30 1.50 CEMT P TIEB1 Switched to Schlumberger, Pumped 5 bbls Water, 3 bpm, 450 Printed: 1/16/2006 1: 1 0:41 PM BP EXPLORATION Operations Summary Report Page 5 of 11 Legal Well Name: 11-38 Common Well Name: 11 -38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 12/25/2005 End: 1/9/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 , i I I Date From - To ¡Hours' Task ¡Code NPT ¡ Phase ! Description of Operations ___ ___________ _n_. _.. .._ ..___ ___u_._n_ 1/1/2006 01 :00 - 02:30 1 .50 CEMT P TIEB1 psi. Shut in Cement Manifold, Tested Lines to 4,500 psi, OK, Bled Down Pressure. 105 bbls (507 sxs) 15.8 ppg Premium Class G Cement wi 0.300 %bwoc Dispersant, 0.170 %bwoc Retarder, 0.200 gal I sk Antifoam, 2.00 gal I sk GASBLOK. Pumped Displacement at the Following Rates: Pumped Rate Pressure 5.00 bbls 6.00 bpm 440 psi 25.00 bbls 6.00 bpm 460 psi Slowed Pumps wi 45 bbls Pumped 50.00 bbls 2.00 bpm 65 psi Observed DP Dart Latch Up wi Closing Plug, Plug Sheared Out wi 53 bbls Pumped at 1,500 psi. 75.00 bbls 5.00 bpm 1,240 psi 100.00 bbls 5.00 bpm 1,750 psi 131.00 bbls 1.00 bpm 2,100 psi Bumped Plug wi 136.00 bbls Total Displacement Pumped. Pressured up to 2,750 psi to to Close ES Cementer, Cement In Place at 02:10 hours. Held Pressure fl 1 Minute and Bled Back to 0 psi. Checked fl Flowback, No Flow. Pressured Up to Set ZXP Liner Top Packer Sheared at 3,750 psi. Good Surface Indication of ZXP Packer Setting. Released from Setting Tool. 02:30 - 03:30 1.00 CEMT P TIEB1 Pressured Up to 1,000 psi. Picked Up on Drill String Until Pressure Loss Observed. Circulated Bottoms Up x 2, 10 bpm, 2,100 psi. Circulated Back Approximately 2 bbls of Cement. Shut Down Pump, Slacked Off and Stacked 25,000# on ZXP Packer, Rotated at 5 rpm to Insure ZXP Packer Set. 03:30 - 04:30 1.00 CEMT P TIEB1 B I 0 and LID Baker Dart Dropping Head. 04:30 - 08:00 3.50 CEMT P TIEB1 POOH from 5,029', LID 135 Joints of 4" Drillpipe. 08:00 - 08:30 0.50 CEMT P TIEB1 POOH, B I 0 and LID Liner Running Tool. 08:30 - 09:00 0.50 CEMT P TIEB1 Cleared and Cleaned Rig Floor. 09:00 - 10:30 1.50 BOPSU P TIEB1 Held PJSM, R I U BOPE Test Equipment, Pulled Wear Bushing, Ran and Set Test Plug and Test Joint. 10:30 - 18:30 8.00 BOPSU P TIEB1 Tested Annular to 250 psi 14,000 Tested BOPE to 250 psi I 4,000 psi. Test #1. Hydril, Upper IBOP, Manual Kill Line Valve, Choke Manifold Valves 1, 12, 13, 14. Test #2. Choke HCR, Kill Line HCR, Lower IBOP. Test #3. Lower Pipe Rams. Test #4. Manual Choke Line Valve. Test #5. Choke Manifold Valves #9, 11, Blind/Shear Rams. Test #6. Choke Manifold Valves #5,8,10, TIW Valve. Test #7. Choke Manifold Valves #4,6,7, Dart Valve. Test #8. Choke Manifold Valve #2. Test #9. Choke Manifold Valve #3 All BOPE Tests Held for 5 min Each. Accumulator Test-Initial Pressure 2,950 psi, After Closure 1,800 psi, Initial 200 psi Recovery 15 sec, Full Pressure in 1 min 13 sec. Nitrogen Bottles, 5 at 2,250 psi Avg. Gas Detectors Callibrated and Tested. Jeff Jones of AOGCC Waived Witness of BOP Test. Test Witnessed by BP Drilling Supervisor and Doyon Tool I Pusher I 18:30 - 19:00 0.50 BOPSU P TIEB1 Rig Down Test Assembly. 19:00 - 19:30 0.50 BOPSU P TIEB1 Install Wear Ring. Printed: 1/16/2006 1:10:41 PM BP EXPLORATION Operations Summary Report Page 6 of 11 Legal Well Name: 11-38 Common Well Name: 11 -38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 12/25/2005 End: 1/9/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 Date . From - To I Hours Task Icode. NPT; Phase Description of Operations .._n___..___ u.________ ____ .. n___.____..________ 1/1/2006 19:30 - 20:00 0.50 EVAL P TIEB1 Make Up Halliburton 7" RBP. 20:00 - 23:00 3.00 EVAL P TIEB1 RIH with 7" RBP on 4" Drillpipe to 5,000'. Set RBP at 5,000 psi. Up Weight 115,000#, Down Weight 113,000# 23:00 - 23:30 0.50 EVAL P TIEB1 Make UP Head Pin and Circulate. Pump Pressure 1,300 psi and 294 gpm. 23:30 - 00:00 0.50 EVAL P TIEB1 R I U to Pressure Test Casing. 1/2/2006 00:00 - 01 :30 1.50 EVAL P TIEB1 Pressure Tested 7" Casing to 4,000 psi for 60 Minutes. Monitored OA for Increase in Pressure. No Increase in OA Pressure During Test. Bled Down Pressure, Opened Pipe Rams. 01 :30 - 02:00 0.50 EVAL P TIEB1 Latched and Released Halliburton 7" RBP. Monitored Well. Brine Weight 9.5 ppg. POOH with 4" Drillpipe from 5,000' to 4,225'. 02:00 - 03:00 1.00 EVAL P TIEB1 Slipped and Cut 90' of Drilling Line. 03:00 - 05:00 2.00 EVAL P TiEB1 POOH with 4" Drillpipe from 4,225'. 05:00 - 05:30 0.50 EVAL P TIEB1 B I 0 and LID 7" RBP. 05:30 - 07:30 2.00 DRILL P TIEB1 RIH w/18 4-3/4" DC's and 21 Joints 4" HWDP. POOH, B / 0 and LID Same. 07:30 - 08:00 0.50 DRILL P TIEB1 Cleared and Cleaned Rig Floor. 08:00 - 09:00 1.00 DRILL P TIEB1 Held PJSM. R I U 2-7/8" Handling Equipment. 09:00 - 18:30 9.50 DRILL P TIEB1 M I U 3-3/4" Clean Out BHA: 3-3/4" Hycalog DS49 PDC Bit wI 4 x 10 jets, 3-1/4" Xtream Motor wI Float Sub, Jars, XO, 1 Joint 2-7/8" PAC DP, Circulating Sub, 186 Joints 2-7/8" PAC DP, XO, XO, 3 x Junk Baskets, Bit Sub, 4-3/4" String Magnet, XO. Total BHA Length: 5,867.57'. PI U 2-7/8" PAC DP 1 x 1 from Pipe Shed. Broke Circulation Every 65 Joints 2-7/8" DP. 18:30 - 19:30 1.00 DRILL P TIEB1 RID 2 7/8" Handling Equipment. 19:30 - 22:30 3.00 DRILL P TIEB1 RIH with BHA #6 on 4" Drillpipe to 10,517' Tag Cement. 22:30 - 23:00 0.50 DRILL P TIEB1 Make Up Top Drive and Establish Parameters. Up Weight 155,000#, Down Weight 126,000#, Rotating Weight 144,000#, Rotary Torque 2,000 ft Ilbs at 10 RPM, Pump Rate 84 gpm at 1,120 psi Off Bottom, 1,180 psi On Bottom. 23:00 - 00:00 1.00 DRILL P TIEB1 Wash from 10,517' to 10,570' 1/3/2006 00:00 - 00:30 0.50 DRILL P TIEB1 Washed Down from 10,570' to 10,652'. Pump Rate 2 bpm, 1 ,120 psi. 00:30 - 18:00 17.50 DRILL P TIEB1 Drilled Cement and Wiper Plug from 10,652' to 10,654' WOB 2,000# - 5,000#, Pump Rate 2.5 bpm, SPP Off Bottom 1,500 psi, SPP on Bottom 2,600 psi, 5 rpm, Torque 3,000 It Ilbs, String Weight Up 155,000#, String Weight Down 126,000#, Rotating String Weight 145,000#. 18:00 - 21 :00 3.00 DRILL P TIEB1 Dropped Opening Ball and Pump Down with 79 bbls 9.5 ppg Brine. Unable to Pump Ball on Seat. Circulated 20 bbl Hi-Vis Sweep Through Bit at 126 gpm 1470 psi followed by 250 bbis 8.6 ppg Clean Seawater. Reciprocated and Rotated Drill String While Circulating. Pump Dry Job. Monitor Well. Blew Down Top Drive. 21 :00 - 23:30 2.50 DRILL P TIEB1 POH wI 4" DP to 5,867' 23:30 - 00:00 0.50 DRILL P TIEB1 M / U Top Drive and Attempt to Open Circulating Sub by Ip Alternating Pump Speeds. Without Success 1/4/2006 00:00 - 01 :00 1.00 DRILL TIEB1 POOH to 5,029'. B I 0 and LID String Magnet, 3 x Boot I Baskets and 3 x XO's. Cleaned String Magnet and Boot Baskets, Recovered 3 Cups Fine Metal Shavings. 01 :00 - 02:30 1.50 DRILL P TIEB1 Circulated 20 bbl Hi-Vis Sweep Around at 3 bpm, 990 psi. R / U Printed: 1/16/2006 1:10:41 PM BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: 11-38 Common Well Name: 11-38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 12/25/2005 End: 1/9/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code: NPT Phase , Description of Operations , ----. -- - ------------ 1/4/2006 01 :00 - 02:30 1.50 DRILL P TIEB1 2-7/8" Handling Equipment. 02:30 - 04:30 2.00 DRILL P TIEB1 POOH wI 2-7/8" DP to 51' 04:30 - 05:00 0.50 DRILL P TIEB1 R I U 2-7/8" Manual Tongs, B I 0 and LID Circ. Sub, Jars, Float Sub, Xtreme Motor and Bit. 05:00 - 07:00 2.00 DRILL P TIEB1 Transported Bit and Motor to Baker Shop. Bucked Off Bit, M I U Junk Mill on New Xtreme Motor, Transport New Motor and Mill Back to Rig_ 07:00 - 09:00 2.00 DRILL P TIEB1 M I U 3-3/4" Clean Out BHA: 3-3/4" 5 Bladed Mill, 2-7/8" Xtream Motor wI Float Sub, Jars, XO, 1 Joint 2-7/8" PAC DP, Circulating Sub, 30 Stands of 2-7/8" PAC DP. Filled Pipe at 30 Stands, Could Not Circulate Drill String. Pressured Up to 2,000 psi. 09:00 - 13:00 4.00 DRILL N TIEB1 POOH wI 2-7/8" PAC DP. Attempted to Circulate After POOH w/15 Stands wI 0 Success. B I 0 Motor and Float Sub. Float Sub Above Float Plugged wI Fine Sand_ Motor Was Clear. 13:00 - 13:30 0.50 DRILL N TIEB1 Checked Motor, OK. Cleaned Out Float Sub and Float. 13:30 - 20:00 6_50 DRILL P TIEB1 M I U 3-3/4" Clean Out BHA: 3-3/4" 5 Bladed Mill, 2-7/8" Xtream Motor wi Float Sub, Jars, XO, Circulating Sub, 187 Joints 2-7/8" PAC DP, XO, XO, 3 x Junk Baskets, Bit Sub, 4-3/4" String Magnet, XO. Total BHA Length: 5,867.87'. Broke Circulation and Pumped 50 bbls at 5 Stands Run_ Broke Circulation and Pumped Drill String Volume Every 5 Stands 2-7/8" DP. 20:00 - 20:30 0.50 DRILL P TIEB1 RID 2 7/8" Handling Equipment, R I U 4" DP Handling Equipment. 20:30 - 00:00 3.50 DRILL P TIEB1 RIH wI 4" DP to 8,825'. Broke Circulation and Pumped Drill String Volume Every 10 Stands 4" DP_ 1/5/2006 00:00 - 00:30 0.50 DRILL P TIEB1 RIH wI 4" DP 10 10,570'. Broke Circulation and Pumped Drill String Volume Every 10 Stands 4" DP. 00:30 - 01 :00 0.50 DRILL P TIEB1 M I U Top Drive. String Weight Up 160,000#, String Weight Down 127,000#. Broke Circulation, Drill String Pressured Up to 500 psi. Bled Down Pressure and Checked Standpipe Valve Line Up_ Broke Circulation, String Pressued Up to 1,000 psi. B 10 and Stood Back 1 Stand DP. Attempted to Blow Air Through Top Drive, Kelly Hose and Standpipe wI 0 success. M I U 4" Circulating Headpin and Circulated Down Drill String at 2.5 bpm at 1,240 psi. Suspect Kelly Hose Froze Up. 01 :00 - 01 :30 0.50 DRILL N RREP TIEB1 Held PJSM with Toolpusher and Crew Members Involved in Removing Kelly Hose for Thawing. Monitoring Well with Trip Tank. Circulated 5 bbls Down Drill String Every 30 min. 01 :30 - 05:30 4.00 DRILL N RREP TIEB1 Removed Kelly Hose and Lower to Rig Floor. Thaw Upper Standpipe and Kelly Hose_ Reinstall Kelly Hose and Test to 4,000 psi. 05:30 - 06:00 0.50 DRILL P TIEB1 PI U 1 Stand 4" DP. M I U Top Drive. Established Parameters, String Weight Up 160,000#, String Weight Down 127,000#, Rotating String Weight 145,000#, Pump Rate 85 gpm, SSP Off I Bottom 1005 psi, SSP On Bottom 1,289 psi. Rotary 10 rpm, 3,000 IVlbs Off Bottom Torque. Wash Down from 10,575' to 10,654'. 06:00 - 15:00 9_00 DRILL P TIEB1 Mill Closing Plug from 10,654' to 10,655'. WOM 2,000#, Pump 115 gpm. SSP Off Bottom 1,280 psi, SSP On Bottom 2,100 psi, Rotary 5 rpm 2,000 ft/lbs Torque_ Having Problems Transfering Weight to Mill. Pumped 20 bbl Lube Pill. e Printed: 1/16/2006 1: 1 0:41 PM e BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: 11 -38 Common Well Name: 11 -38 Spud Date: 12/31/1996 Event Name: WORKOVER Start: 1 2/25/2005 End: 1/9/2006 Contractor Name: DOYON DRILLING INC. Rig Release: 1/9/2006 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours· Task Code· NPT I Phase Description of Operations i 1/5/2006 15:00 - 16:00 1.00 DRILL P TIEB1 Stand Back 1 Stand 4" DP. Drop 3/4" Circ. Sub Opening Ball. Open Circ Sub, Circulated 20 bbl Hi-Vis Sweep Around at 210 gpm 3,510 psi. Monitor Well, Static. MW 8.6 ppg 16:00 - 18:00 2.00 DRILL P TIEB1 POH wI 4" DP to 5,868'. 18:00 - 18:30 0.50 DRILL P TIEB1 B I 0 and LID XO, String Magnet, 3 x Boot Baskets, 2 x XO's. RID 4" Handling Equipment. R I U 2-7/8" Handling Equipment. 18:30 - 20:30 2.00 DRILL P TIEB1 POH wI 2-7/8" PAC DP. B I 0 and LID Circ. Sub, Float Sub, Xtreme Motor and Junk Mill 20:30 - 00:00 3.50 DRILL P TIEB1 PI U and M I U 3-5/8" x 2-1/2" Mill Shoe, 3-5/8" Reverse Circulating Jet Basket, 2-7/8" Xtreme Motor, Jars, Float Sub, Circulating Sub, XO, 105 jts 2-7/8" PAC DP. Flow Checked Motor at 84 gpm After 1 Stand of 2-7/8' DP in Hole. Circulate Drill String Volume with 35 Stands 2-7/8" DP in Hole, 105 gpm 900 psi. 1/6/2006 00:00 - 02:00 2.00 DRILL P TIEB1 RIH wI 3-3/4" Mill Shoe, 3-5/8" Reverse Circulating Jet Basket, 2-7/8" Xtreme Motor, Jars, Float Sub, Circ Sub, 187 jts 2-7/8" Pac DP, XO, XO, 3 x 4-3/4" Boot Baskets, Bit Sub, String Magnet, XO. BHA Length 5,872.64' 02:00 - 02:30 0.50 DRILL P TIEB1 RID 2-7/8" Handling Equipment. R 1 U 4" Handling Equipment 02:30 - 03:00 0.50 DRILL P TIEB1 M I U Head pin and Circulated String Volume at 105 gpm 1,100 psi. 03:00 - 04:30 1.50 DRILL P TIEB1 RIH wI 4" DP" to 10,575' 04:30 - 05:00 0.50 DRILL P TIEB1 M I U Top Drive, Established Parameters, String Weight Up 150,000#, String Weight Down 140,000#, Rotating String Weight 143,000#, Pump 2 bpm. 1,225 psi. RPM 10, Torque 1,500 ftllbs. 05:00 - 11 :30 6.50 DRILL P TIEB1 Milled on Closing Plug wI Mill Shoe and Reverse Circulating Basket from 10,654' to 10,656.5'. WOM 2,000# - 15,000#, Pump 2.5 bpm, SPP Off Bottom 1,275 psi, SPP On Bottom 2,650 psi, Rotary 5 - 55 rpm Torque Off Bottom 2,000 ftllbs, Torque on Bottom 3,000 ft 1 Ibs. Attempted to Mill Beyond 10,656.5' wI 0 Success. 11 :30 - 13:30 2.00 DRILL P TIEB1 B I 0 and BID Top Drive, Monitored Well, Static. MW 8.4 ppg. POOH wI 4" DP. 13:30 - 14:00 0.50 DRILL P TIEB1 B I 0 and LID 4-3/4" BHA Components. Cleaned String Magnet, c I 0 Junk Baskets, Recovered 1/2 cup Rubber. 14:00 - 14:30 0.50 DRILL P TIEB1 C I 0 4" DP Handling Equipment f/2-7/8" DP Handling Equipment. 14:30 - 17:30 3.00 DRILL P TIEB1 POOH wI 2-7/8" PAC DP. 17:30 - 18:00 0.50 DRILL P TIEB1 B I 0 and LID Circ sub, Float Sub, Xtreme Motor and Mill Shoe. 18:00 - 22:00 4.00 DRILL P TIEB1 Transport Xtreme Motor with Mill Shoe to Baker Shop. B I 0 Mill and Recovered Junk. M I U 3 Bladed Flat Mill on New Xtreme Motor and Transported Back to Rig. Reverse Circulating Basket Filled with Cement, Small Metal Shavings and Pieces of Aluminum 22:00 - 00:00 2.00 DRILL P TIEB1 PI U 3-3/4" 3 Bladed Flat Bottom Mill and 2-7/8" Xtreme Motor. M I U Jars, Float Sub, Circulating Sub, XO, 1 Jt. 2-7/8" PAC DP. Noticed Box on Jars was Swelled. Replaced Jars. 1/7/2006 00:00 - 05:00 5.00 DRILL P TIEB1 RIH with 3-3/4" 3 Bladed Flat Bottom Mill, 2-7/8" Xtreme Motor, Jars, Float Sub, Circ Sub, XO, 187 Jts 2-7/8" PAC DP, XO, XO, 3 x 4-3/4" Boot Baskets, Bit Sub, String Magnet, XO. BHA Length 5,869.01 '. Flow Check Motor at 60' at 1 bpm 250 psi. Printed: 1/16/2006 1:10:41 PM e BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-38 11-38 WORKOVER DOYON DRILLING INC. DOYON 16 :Codel I Date From - To Hours · Task NPT i Phase ! , ._n . _...._.. n__.___.__._..___._.----:...---__....._.. 1/7/2006 00:00 - 05:00 5.00 DRILL P TIEB1 05:00 - 05:30 0.50 DRILL P TIEB1 05:30 - 08:00 2.50 DRILL P TIEB1 08:00 - 09:00 1.00 DRILL P TIEB1 09:00 - 11 :00 2.00 EV AL P TIEB1 11 :00 - 13:00 2.00 DRILL P TIEB1 13:00 - 14:30 1.50 DRILL P TIEB1 14:30 - 16:00 1.50 DRILL P TIEB1 16:00 - 17:00 1.00 DRILL P TIEB1 17:00 - 19:30 2.50 DRILL P TIEB1 19:30 - 21 :00 1.50 DRILL P TIEB1 21 :00 - 00:00 3.00 DRILL P TIEB1 1/8/2006 00:00 - 01 :30 1.50 CLEAN P CLEAN 01 :30 - 02:00 0.50 CLEAN P CLEAN - 02:00 - 03:30 1.50 CLEAN P CLEAN 03:30 - 04:00 0.50 CLEAN P CLEAN I I Page 9 of 11 Start: Rig Release: Rig Number: Spud Date: 12/31/1996 End: 1/9/2006 12/25/2005 1/9/2006 16 Description of Operations --.--. __.__n......_...._._... _n._..__... Broke Circulation Every 15 Stands at 2 bpm 600 psi cIa Handling Tools from 2-7/8" to 4". Broke Circulation at 2 bpm 950 psi. RIH wI BHA on 4" DP to 10,570'. Broke Circulation at 8,250'. M I U Top Drive, Established Parameters, String Weight Up 150,000#, String Weight Down 137,000#, String Weight Rotating 143,000#, Pump Rate 2 bpm, 920 psi, 5 rpm, Torque 1,500 ft Ilbs, DH rpm 336. Washed Down f/1 0,570' to 10,656.5'. Tagged Up at 10,656.5'. Milled Cement from 10,656.5' to 10,657'. WOM 500#, 2 bpm, SPP off 920 psi, SPP on 1,120 psi. Fell Through at 10,657'. Worked Mill and Motor from 10,650' to 10,660' x 3. Washed Down to 10,699', 2 bpm, 920 psi. B I 0 and Blew Down Top Drive. R I U Circulating Head, Line, Valves and Chart. Closed Annular. Pressure Tested 7" x 4-1/2" Liner Top Packer to 4,000 psi f/30 Minutes, OK. Bled Down Pressure, Opened Annular, Blew Down Lines. RID Equipment. B I 0 and L / D Single. M / U Top Drive, Established Parameters, String Weight Up 152,000#, String Weight Down 140,000#, String Weight Rotating 143,000#, Pump Rate 2 bpm, 1,020 psi, 5 rpm, Torque 1,500 ft Ilbs, DH rpm 336. Washed Down f/1 0,699' to 10,723'. Tagged Up at 10,723'. Milled Cement and FasDril Plug from 10,723' to 10,745'. WOM 2,000# - 4,000#,2 bpm, SPP off 920 psi, SPP on 1,200 psi. Fell Through at 10,745'. Washed Down to Top of 3-3/4" x 2-7/8" Liner Top at 10,802', 2 bpm, 920 psi. Dropped Circ Sub Opening Ball, Pumped 20 bbl Hi-Vis Sweep, Opened Circ Sub, Circulated Sweep Around 5 bpm, 3,100 psi. B I 0 and Blew Down Top Drive. MW 8.6 ppg. POOH wI 4" DP B I 0 and LID XO, String Magnet, Bit Sub, 3 x 4-3/4" Boot Baskets, XO, XO. C I 0 Handling Equipment from 4" to 2-7/8". Clean String Magnet and Boot Baskets, Recovered 1 Cup Fine Metal Shaving and 3 Small Pieces of Rubber. POH wI 2-7/8" DP. B / 0 and LID Circ Sub, Float Sub, Jars, 2-7/8" Xtreme Motor and 3-3/4" Mill. Transport Motor and Mill to Baker Shop. M I U Reverse Circulating Jet Basket on New Xtreme Motor. Transport Motor and Reverse Circulating Basket Back to Rig. PI U 3-3/4" Mill Shoe with 2-7/8" Xtreme Motor. M I U Jars, Float sub, Circ Sub, XO, 120 Jts 2-7/8" PAC DP. Flow Check Xtreme Motor at 60', OK. Filled DP at 3,800' RIH wI 3-3/4" Mule Shoe, 3-5/8" Reverse Circulating Basket, 2-7/8" Xtreme Motor, Jars, Float Sub, XO, 187 Jts 2-7/8" PAC DP, XO, XO, 3 x 4-3/4" Boot Basket, Bit Sub, String Magnet, XO. BHA Length 5,873.01'. cIa Handling Equipment from 2-7/8" to 4". Broke Circulation at 2 bpm, 750 psi. RIH wI 4" DP to 10,768'. Filled DP at 8,900' M I U Top Drive and Washed Down from 10,768' to 10,802'. Pump 2 bpm 1,000 psi, 5 rpm at 1,500 ft/lbs Torque. String Weight Up 150,000#, String Weight Down 138,000#, Rotating Printed: 1/16/2006 1:10:41 PM e BP EXPLORATION Operations Summary Report Legal Well Name: 11-38 Common Well Name: 11-38 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To Hours Task ¡ Code; NPT ____......._... ... ..n __ ___..h.. .. . 1/8/2006 03:30 - 04:00 0.50 CLEAN P 04:00 - 05:30 1.50 CLEAN P 05:30 - 10:00 4.50 CLEAN P 10:00 - 10:30 0.50 CLEAN P 10:30 - 16:00 5.50 CLEAN P 16:00 - 16:30 0.50 BOPSU 116:30 - 17:30 1.00 17:30 - 18:00 0.50 18:00 - 00:00 6.00 1/9/2006 00:00 - 02:00 2.00 RUNCO 02:00 - 02:30 0.50 RUNCO 02:30 - 03:00 0.50 RUNCO 03:00 - 04:00 1.00 RUNCO P 04:00 - 05:30 1.50 RUNCO P 05:30 - 07:00 1.50 RUNCO P 07:00 - 10:30 3.50 RUNCO I P Page 10 of 11 Start: Rig Release: Rig Number: Phase Spud Date: 12/31/1996 End: 1/9/2006 12/25/2005 1/9/2006 16 Description of Operations ---------... CLEAN String Weight 145,000#. Work Reverse Circulating Basket from 10,790' to 10,802'. B I 0 Connection and Dropped Circ Sub Opening Ball. CLEAN Opened Circ Sub and Pumped 40 bbls Hi-Vis Sweep Around at 5.5 bpm 3,750 psi. Monitored Well, Static. Blew Down Top Drive. MW 8.4 ppg CLEAN POOH LID 4" DP. CLEAN B I 0 and LID 4-3/4" BHA Components. C 104" Handling Equipment f/2-7/8" Handling Equipment. CLEAN POOH LID 2-7/8" PAC DP and 3-3/4" Reverse Circulating Basket BHA. RUNCMP PI U Joint 4" DP, M I U Wear Ring Retrieving Tool, RIH and Engaged Wear Ring, BOLDS, Pulled Wear Ring, B / 0 and L I D Retrieving Tool and DP. RUNCMP Held PJSM; C/O Bails, R I U Compensator, Elevators, Power Tongs and Torque Turn Equipment. RUNCMP Held PJSM with Rig Crew, Grant Pridco Rep, Baker Packer Rep, Doyon Casing, Toolpusher and BP Drilling Supervisor. RUNCMP RIH wI 4-1/2" Mule ShoeTailpipe Assy, "X" Nipple Assy with RHC Plug, Baker 7" x 4-1/2" S-3 Packer Assy, "X" Nipple Assy, 80 Jts 4-1/2" TC II L-80 Tubing. Torque Turned TCII Connections to 3,850 It Ilbs. Connections Below Packer Bakerloked. All Other Connections Utilized Jet Lube Seal Guard Thread Compound. RUNCMP RIH wI 4-1/2" Mule ShoeTailpipe Assy, "X" Nipple Assy with RHC Plug, Baker 7" x 4-1/2" S-3 Packer Assy, "X" Nipple Assy, 118 Jts 4-1/2" TC II L-80 Tubing. Torque Turned TCII Connections to 3,850 ft Ilbs. Connections Below Packer Bakerloked. All Other Conneotions Utilized Jet Lube Seal Guard Thread Compound. Lost 8 bbls Seawater While RIH with Tubing. RUNCMP RID Compensator, R I U Circulating Head On Joint #119, PI U and M I U Joint #119, M I U Circulating Hose. RUNCMP RIH Circulated Down 4-1/2" Tubing at 3 bpm, 170 psi. Tagged Bottom of Tie-Back Receptacle at 5,041 '. Observed Pressure Increase of 100 psi. PI U and Retagged at 5,041' to Verify Depth with Same Pressure Increase. RUNCMP Broke Out and LID Circulating Hose, B I 0 and LID Joint #119, Removed Circulating Head. PI U and M I U Tubing Hanger and Landing Joint. RIH and Land Tubing in Well Head with Mule Shoe Set at 5,039', 9' Inside Liner Tie Back Sleeve. RILDS. M I U Circulating Head and Hose to Landing Joint. RUNCMP Circulated 235 bbl Clean 140 deg 8.4 ppg Seawater Down IA at 3 bpm, 200 psi. Followed by 45 bbls Corrosion Inhibited 8.4 ppg Seawater, 3 bpm, 200 psi. Took Returns Up 4-1/2" Tubing to Slop Tank. RUNCMP Held PJSM. R I U Little Red to Annulus and Tubing. Pressure Tested Lines to 3,500 psi, OK. Pumped 85 bbls Diesel Freeze Protect Down 7" x 4-1/2" lA, Took Returns Off of Tubing. 2 bpm, 900 psi. Shut Down Little Red, Swapped Valves and Allowed 7" x 4-1/2" IA and 4-1/2" Tubing to U - Tube. RUNCMP B / 0 Circulating Head, Dropped Ball / Rod Assy. M / U Circulating Head and Lines. Pressured Up to 2,500 psi to Set Printed: 1/16/2006 1;10;41 PM e e BP EXPLORATION Operations Summary Report Page 11 of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11 -38 11-38 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/25/2005 Rig Release: 1/9/2006 Rig Number: 16 Spud Date: 12/31/1996 End: 1/9/2006 . . . . Date : From - To ' Hours i Task Code· NPT ¡ Phase Description of Operations -..-.--.-. -...-----..- ...------.... ....----..-- ___u____ ...---- ____n... 1/9/2006 07:00 - 10:30 3.50 RUNcor lIP 10:30 - 12:30 2.00 RUNcor P 12:30 - 14:00 1.50 BOPSUF P 14:00 - 17:00 3.00 WHSUR P 17:00 - 19:00 2.00 WHSUR P RUNCMP Baker S-3 Packer, Pressure Tested 4-1/2" Tubing to 4,000 psi f/30 Minutes, OK. Bled Tubing Pressure Down to 2,000 psi, Shut In, Pressure Tested 7" x 4-1/2" IA to 4,000 psi f/30 Minutes, OK. Bled Down All Pressures. RUNCMP B I 0 and LID Circulating Head and Lines, B I 0 and L / D Landing Joint and XO. Ran and Set TWC, Tested from Below to 1,000 psi, OK. Blew Down and RID All Lines. RID Little Red. RUNCMP Held PJSM, N I D BOPE. RUNCMP N I U Adapter Flange and Tree, Tested Neck Seal and Void to 5,000 psi. Tested Tree to 5,000 psi. RUNCMP R I U DSM and Pull TWC. Set BPV, Remove Secondary Annulus Valve, Install Blind Flanges and Pressure Gauges on Annulus Valves, Secure Well, Clean Cellar Area. Released Rig at 1900 hrs, 1/9/2006. I I Printed: 1/16/2006 1:10:41 PM ÆRfORA TION SUMMARY REf LOO: SWS M8\I!ORY CNL ON 12/01/98 TOP 87 @ 12970' D6f PRUDHOE SA Y UNIT WELL: ii-3M 198-2160 API No: 50-029-22723-01 SEC 33, T11N, R15E 5115' NSl & 101' WEL BP e e FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PaulChan Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 a / ~ V\P \O\Tl Re: Prudhoe Bay, 11-38A Sundry Number: 306-006 f:iC~N~~FY . ... ,I Dear Mr. Chan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A reque~t for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this-,º- day of January, 2006 Encl. c,«} "10 - () l- e STATE OF ALASKA 04IÞ¡/;Ojk, ALASKA Oil AND GAS CONSERVATION COMMISSION JAN 0 9 2006 APPLICATION FOR SUNDRY APPROV4Lk Oit&G C C .. 20 AAC 25 280 . A1ãs a as ons. o/'l'mlsstOn . '.. Anchorage W41t- /101 z.f)O{P RECEIVED 1. Type of Request: 0 Abandon o Alter Casing II Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 0 Other II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: M Development 0 Exploratory o Stratigraphic -IJ"Service ¡,Jiik' 9. Well Name and Number: 5. Permit To Drill Number 198-216/305-246 / 6. API Number: 50- 029-22723-01-00 ../ 64.22' PBU 11-38A / 8. Property Designation: 11. Total Depth MD (ft): 13871 10. Field / Pool(s): ADL 028326 Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13826 8874 9583 None MD TVD Burst Colla se 110' 20" 110' 110' 1490 470 3741' 9-5/8" 3775' 3773' 5750 3090 10825' 7" 10856' 8835' 7240 5410 129' 4-1/2" 10765' - 10894' 8831' - 8836' 8430 7500 Liner 3061' 2-7/8" 10802' - 13863' 8833' - 8871' 10570 11160 Liner 5717' 4-1/2" 5041' - 10758' 5039' - 8830' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12790' - 13780' 8866' - 8877' 4-1/2", 12.6# L-80 5498' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer Packers and SSSV MD (ft): 4990' 12. Attachments: IS! Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 0 Development IS! Service 17. Decemb r , 2005 Dat. 12/30/2005 J. Norman r¡. i g is true and correct to the best of my knowledge. Title Drilling Engineer 15. Well Status after proposed work: o Oil o Gas o WAG 0 GINJ o Plugged IS! WINJ o Abandoned o WDSPL Contact Paul Chan, 564-5254 Date -OtYR Phone 564-5254 Commission Use Only b Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity æn;op Test œ(Mechanicallntegrity Test 0 Location Clearance Other: Te-c; t B 0 ,,& to f9 }Il I íJ C¿M.~t , o yJCA-. , It I,ç; Y V' e¿; u.-{I\.{ d . RBDMS BFL JAN] j 2006 COMMISSIONER APPROVED BY THE COMMISSION Date /.. Submit In Duplicate AL e e Well Status: Shut-in produced water injector. Well has corroded tubing and a confirmed leak in the 7" production casing at -61 OO'md. Well is secured with a tubing tail plug. Project: Retrieve existing 4.5", 12.6#, L-80 MBT completion, mill & recover packer and tail-pipe. Fully cement in place a 4.5", 12.6#/ft, L-80 IBT scab liner with liner top at -5500'md. Re-complete with 4.5", 12.6#/ft, L-80 TC-II tubing with WLEG stung into scab liner-top tie-back receptacle. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. Revision: The 4-1/2" liner top was setting depth was changed from the planned -5500' MD to -5041' MD to bring the scab liner coverage higher in the Cretaceous interval. The packer set depth will also be changed. See attached r schematic. Verbal approved received from J. Norman 12/30/2005. Note: The 7" casing cut and pull operation was not required as the casing had a successful pressure test (W. Aubert emaiI11/17/2005). 1. MIRU 4ES. Pull BPVs, set and test TWC in 4.5" tubing hanger. ND tree and adapter flange. NU BOPE. Test~n r to 250 psi (low)/3500 psi (high), remaining BOPE to 250 psi (low)L 0 psi (high) per BP and AOGCC regulations. c······· 2. Fully circulate thru the pre-RWO jet cut with heated seawater. 3. Pull 4.5", 12.6#/ft, L-80 MBTdown to the jet cut just above the packer. 4. Mill and recover the 4.5" x 7" 8-3 packer. 5. Run 6-1/8" bit and 7" casing scraper and clean wellbore to top of TIW horizontal liner top at 10756'md. 6. RU e-line and log with USIT from 10500' (hole angle = 74 degrees and getting higher) in both cement evaluation mode and corrosion mode. Log up to -5400'md. 7. Run 4.5", 12.6#/ft, L-80 IBT scab liner from top of 4.5" x 7" TIW SS horizontal liner top packer/hanger at 10756'md up to -5500'md. Fully cement liner in /' place. 8. PT liner/casing to 4000 psi for 30-min (charted). Drill out shoe-track. CBU with hi-vis sweeps to clean up wellbore. 9. Run new 4.5", 12.6#/ft, L-80 TC-II completion with WLEG stung into liner top packer's tie-back receptacle. Set and test packer to 4000 psi (tubing and inner annulus). 10. RDMO 4ES. / 11. Tie well in and place on injection. MITIA with AOGCC witness once well is on injection and stabilized. TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= 4-1/16" CrN FMC BAKER C 64.22' 30.10' 6100' 97@11611' 12932' 8800' SS 11-.A Proposed Co~letion - Revised I 9-5/8" CSG, 40#, L-80, ID = 8.835" I Minimum ID = 2.387" @ 10806' 3-1/2" X 2-7/8" LNRXO 14-1/2" TBG, 12.6#, L-80, TC-II, ID = 3.958" H -5498' Liner to be fully cemented in place, seals stung into TIW tie-back receptacle, ZXP to be set -500' above PC leak. 14-1/2", 12.6#, L-80, IBT, SCAB LINER H 10758' I I 7" CSG, 26#, L-80, ID = 6.276" I PERFORA TION SUMMARY REF LOG: SWS MEMORY CNL ON 12/01/98 ANGLE AT TOP PERF: 87 @ 12970' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 12970 - 13510 0 12/02/98 2" 4 13660 - 13780 0 12/02/98 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I DATE 01/19/97 12/02/98 01/16/01 03/01/01 11/24/01 13150' REV BY SIS- SIS-MD CHlTP COMMENTS ORIGINAL COMPLETION CTD SIDETRACK CONVERTED TO CANV AS FINAL CORRECTIONS DATE 03/11/02 REV BY RL/tlh 2100' -f4 1/2" HES X NIP, ID = 3.813" I H4 1/2" HES X NIP, ID - 3.813" I -4990' H 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" H4 1/2" HES X NIP, ID = 3.813" I - 5041' H 7" X 5" BKR ZXP LINER TOP PKRlHNGR - PC leak diagnosed at -61 OO'md 4-1/2" LNR MILLOUTWINDOW 10890' - 10894' (OFF CMT RAMP) I LNR OBSTRUCTION? H 13780' P 12-7/8" LNR, 6.5#, L-80, .0058 bpf , ID = 2.387" I COMMENTS SET PLUG PRUDHOE BAY UNIT WELL: 11-38A PERMIT No: 198-2160 API No: 50-029-22723-01 SEC 33, T11 N, R15E 5115' NSL & 101' WEL BP Exploration (Alaska) Re: Sundry No. 305-246 Well 11-38A workover ... .. .... . ........)1 q{~.llt¿;. ...... ~~¡,þJ~ct: ..~e:.su~d~~O~<3q5~446V\1eI11.1~3ªA.~Of~9Y~r .... .... .'. F~~'T; ~inton.A.ubent.<"¥i~ton4a~q~r1(Qt~dmin~$t9te,ak.us> .' . Pª~': Tñu, '17"N()v200510:43:94~()9QO :,.,."", 'fñ~ ) Dave, I'll add this to the information in the current sundry, and nothing else is required. Winton Aubert AOGCC 793-1231 Reem, David C wrote: Winton, quick question for you. This well has added another twist to the workover scope in that it will reqire a cut-and-pull of the 7" casing inside the 9-5/8" casing Oust above the 9-5/8" shoe). The 7" will be replaced with gas-tight premium threaded 7" (same weight and grade). This 7" will be fully cemented in place. The remainder of the work scope is unchanged. Please advise if an additional Sundry application is required. Thanks. Dave Reem Wells/Workover Engineer 564-5743 (w) 632-2128 (c) :)!;ANNE[) NO\f'l 7 2005 1 of 1 11/17/2005 10:47 AM ) ) 1'1"\' " Cu' :r~ ',I.Î7.",ëJ i fJ'\ :: I¡ ::.~ I' 'I" \ ': ,\:\ t, II \ 'I i: :1 '--, <.»:.i'J ~ I' :.;o."I'CI~...J ,-FJ ,:::.::1 : :1 , , :,_:1 1-\ ]'11 f ,H "II ,/ jJ '\ LFl.\1 ! II .'1 / / 1/ ,. / FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AIWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 lC~'V - ~ttP Re: PBU 11-38A Sundry Number: 305-246 t.~',>"\'«'''Æ' h.),J<\~~::r: ~~E" Ii) ~~ ~;: 2005 1:;;.~'I...'1i¡i~IJ')D~¡.\¡;";"\,,'" U ~ t. ,~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, CJti¡~f/ John K. Norman Chairman $"1 DATED this2/ day of September, 2005 Enc!. wGA- q l'ti 12...:,oç 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate o Alter Casing II Repair Well 0 Plug Perforations 0 Stimulate o Change Approved Program II Pull Tubing 0 Perforate New Pool 0 Waiver ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL SEP 1 (~~J Z005 20 AAC 25.280 R¿V¡~~1æ ~~A'2fd~ EBR~ekqH'!mièë~ór /'.I~ :r~' !:~':. ~:'~ c ~:~ :~~: I~~.\~::; II Other Convert to Inj~"ctor o Re-Enter Suspended Well o Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: I!I' Develo~~.t 0 Exploratory o Stratigraphic -It5'ervice 5. Permit To Drill Number 198-216 6. API Number: 50- 029-22723-01-00 99519-6612 64.22' 9. Well Name and Number: PBU 11-38A 8. Property Designation: ADL 028326 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool ,:.: I?RESENTi:MjI:::Lhl'€a~lb'TI~N '~U~I1I\JlAR·Y I,,' "i':,:' .:"".,:: ,,':,,:'I',:,",.',!,:, "',.",1"",,,. :1,',::, .,'!I,:,':,.·.':.'.:':.". ,..:.:".,:.".:',',.", :""':,1',": ".,',,',,:,"",,,:,,",.'.':""..',:,',,:,"".'.111,'.":"'.:',1'I ,'"I, '~':'i' " I, ,', '"ill': I ,I ".~ , .'i,.'" I,~ I, I:~', ""q: """~'" ,1,~U~t,I' I, .',1·,., 'I".. (",,, ,',' ",1" I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 13826 8874 9583 MDTVP, Burst Junk (measured): None , Collapse 011 Total Depth MD (ft): 13871 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 8870 Length Size 110' 3741' 10825' Liner 129' 3061' 20" 110' 110' 1490 470 9-5/8" 3775' 3773' 5750 3090 7" 10856' 8835' 7240 5410 4-1/2" 10765' - 10894' 8831' - 8836' 8430 7500 2-7/8" 10802' - 13863' 8833' - 8871' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): 12790' - 13780' 8866' - 8877' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" Camco 'Bal-O' SSSV Nipple Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 9576'; 2195' Tubing MD (ft): 9623' 12. Attachments: IS! Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: o Exploratory 0 Development B Service 16. Verbal Approval: Commission Representative: 17. I hereby certif that the foregoing is true and correct to the best of my knowledge. Printed Nam )avid Ree Title Drilling Engineer November 25,2005 Date: 15. Well Status after proposed work: BOil o Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Phone 564-5743 Commission Use Only Contact David Reem, 564-5743 Marvin Harris, 564-5018 Prepared By Name/Number: Terrie Hubble, 564-4628 Signature Date W1z.jo S- ~O~·- L4~ Sundry Number:. ~ rfJ rl(PO¡ .. VJ ¿,k Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test [!('MeChanicallntegrity Test 0 Location Clearance Test j.5cPE Other: M 1:. T I tc 4còo l?k, U ..<- ~H_t- 'b tv..L í ht Ù 1 ~ð4N'J . R8DMS BFL SEP 2 ] 2005 Subsequent Form Required: \ C .- 4 c4 . Approved BY:~ ¡J~~ 9- ?-!~Ò5""" COMMISSIONER Form 10-403 Revised ;1/2004 ORIGINAL APPROVED BY THE COMMISSION Date 9. -¿¡ /05-- Submit In Duplicate ) ) Well Status: Shut-in oil producer. Well has corroded tubing and a confirmed leak in the 7" production casing at -6100'md. Well is secured with a tubing tail plug. Project: Complete as produced water injector. Retrieve existing 4.5", 12.6#,L-80 MBT completion, mill & recover packer and tail-pipe. Fully cement in place a 4.5", 12.6#/ft, L-80 ruT scab liner with liner top at -5500'md. Re-complete with 4.5", 12.6#/ft, L-80 TC-II tubing with WLEG stung into scab liner-top tie-back receptacle. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer· setting. 1. MIRU 4ES. Pull BPVs, set and test TWC in 4.5" tubing hanger. ND tree and adapter flange. NU BOPE. Test annular to 250 psi (low)/3500 psi (high), remaining BOPE to 250 psi (low)/4000 psi (high) per BP and AOGCC regulations. 2. Fully circulate thru the pre-RWO jet cut with heated seawater. 3. Pull 4.5" , 12.6#/ft, L-80 MBT down to the jet cut just above the packer. 4. Mill and recover the 4.5" x 7" S-3 packer. 5. Run 6-1/8" bit and 7" casing scraper and clean wellbore to top of TIW horizontal linertopat10756'md~ 101-;-§' WGk 6. RU e-line and log with SI from 19500' (hole angle = 74 degrees and getting higher) in both cemen uation mode and corrosion mode. Log up to -5400'md. 7. Run 4.5", 12.6#/ft, L-80 IBT scab liner from top of 4.5" x 7" TIW SS horizontal liner top packer/hanger at 10756'md up to -5500'md. Fully cement liner in plaèe. 8. PT liner/casing to 4000 psi for 30-min (charted). Drill out shoe-track. CBU with hi- vis sweeps to clean up wellbore. 9. Run new 4.5", 12.6#/ft, L-80 TC-II completion with WLEG stung into liner top packer's tie-back receptacle. Set and test packer to 4000 psi (tubing and inner annulus). 10. RDMO 4ES. 11. Tie well in and place on injection. MITIA with AOGCC witness once well is on injection and stabilized. I$P ) ) DS 11-38A Planned Conversion ,/' ~05-13A '- 0~-32A ,iii' 1 ',:",'icf 1320' ¡---",/ ,i// 11/4 Mile radius buffer I )1C ~""'''.,.'''' }¥11-38A ( _---. 0:1~ . I '-VVI , ~ 1-24A ~1-13A e11-05A '...'..""'" e 05-24A '-'""",---- \ ~ 05-058 ~ 05-39" ,~ '~ \ 05-10B \, -'-."- \ \~ \05-0~ 0:>-40 ~ ~()~A _05-~'9 LEGEND . Oil Producer - Flowing . Oil Producer - Gas Lift + Oil Producer - Shut-in .. Water Injector J · . ') TREE = WaLHEAD = Ä cTLLÄ"TÖR· = KB. ELEv = B F. ÈL.EV= 'KOP= Max An~~ = Datum MD = DatumTVD = 4-1/16"CIW FMC BÄKERC 64.22' 30.10' 6100" ~!(~ 11611' 12932' 8800' SS 19-518" CSG, 40#, L-80, ID = 8.835" H 3775' Minimum 10 = 2.387" @ 10806' 3-1/2" X 2-7/8" LNR XO 14-112" 1BG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9576' 14-1/2" TIP, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9622' 1 7" CSG, 26#, L-80, ID = 6.276" H 10856' µ PffiFORA TION SUrvTv1ARY REF LOG: SWS rvEWORY CI\L ON 12/01/98 ANGLEATTOPÆRF: 87 @ 12970' Note: ~fer to Production DB for historcal perf data SIZE SPF INTERV AL Opn/Sqz [)A. TE 2" 4 12970 -13510 0 12IU2198 2" 4 13660 - 13780 0 12IU2198 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 13150' 1 OL\1E 01/19197 12/02/98 01/16/01 03101/01 11/24/01 REV BY SIS- SteMM) OJfTP COMrvENTS ORlGINA.L COMA..ETION cm SIDETRACK CONVER1ED TO CANV AS FINA.L CORRECllONS DATE 03/11/02 ) 11-38A SAFETY NOTES: WELL ANGLE> 70° @ 10370' & > 90° @ 11050·... DlRlNG CTD SDTRK, AN OBSTRUCTION WAS NOTED IN 2-7/8" Lt-R @ 13780' (HAN:>OVER FORM). <I 2195' H4-1/2" CAMOO BAL-O SSSVN, ID = 3.812" ~ GAS LFT MA.NDRELS .. ST MD TVD ŒV TYPE VLV LATOJ 1 3464 3462 1 KBG-2LS r:N INT 2 5192 5190 0 KBG-2LS r:N INT 3 6589 6498 54 KBG-2LS r:N INT 4 7905 7293 51 KBG-2LS r:N INT 5 9222 8104 51 KBG-2LS r:N INT FDRf DATE o 01/23/01 o 01/23/01 o 01/23/01 o 01/23/01 o 01/23/01 L ~ ~ S- 9576' H 7" X 4-1 /2" BKR 8-3 PKR, ID = 3,875" 1 9583' SLMH4-1/2" PX PLUG SET IN X NIP(03/11/02) 9600' H4 1/2" HES X NIP, ID = 3.813" 9623' 9614' H4 1/2" WLEG, ID = 3.958" 1 H EUvD TT LOGGe:> 11/02/98 I :8: 10758' H7" X 4-1/2" TIW SS HORIZ A<R, ID = 3.924" ~ -, 10802' 1-13-3/4" BKRDEA..OYrvENTSLV, 0 =3.00" 10806' H 3-1/2" X 2-7/8" LNR XO, ID = 2.387" 1 ~ 4-1/2" LNR MILL OUT WINDOW 10890' - 10894' (OFF Ov1T RArvP) 1 LNR OBSTRLCTON? H 13780' P l2-7/8" LNR, 6.5#, L-80, .0058 bpf , ID = 2.387" H 13863' 1 REV BY COMrvENTS RUtlh SET A.. UG PRUDHOE BAY !.NIT WELL: 11-38A PffiMT t-b: 198-2160 AA t-b: 50-029-22723-01 SEC 33, T11 N, R15E 5115' NSL & 101' WEL BP Exploration (Alaska) .. TREE=' · WELLHEA D = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD == Datum NO = ) 11-38A Proposeu) 4-1/16" CrN FMC BAKER C 64.22' 30.10' 6100' 97@11611' 12932' 8800' SS 1 9-5/8" CSG, 40#, L-80, 10 = 8.835" 1-1 3775' ~ Minimum 10 = 2.387" @ 10806' 3-1/2" X 2-7/8" LNR XO 14-1/2" TBG, 12.6#, L-80, TC-II, 10 = 3.958" 1-1 -5498' Liner to be fully cemented in place, seals stung into TIW tie-back receptacle, ZXP to be set -500' above PC leak. 14-1/2",12.6#, L-80, IBT, SCAB LINER 1-1 10758' I I 7" CSG, 26#, L-80, 10 = 6.276" 1-1 1 0856' ~ ÆRFORA TION SUMMARY REF LOG: SWS MEMORY CNL ON 12/01/98 A NGLE AT TOP ÆRF: 87 @ 12970' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 12970 - 13510 0 12/02/98 2" 4 13660 - 13780 0 12/02/98 14-1/2" LNR. 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 13150' 1 DATE 01/19/97 12/02/98 01/16/01 03/01/01 11/24/01 COMM8\ITS ORIGINAL COMR..ETlON CTD SIDETRACK CONVERTED TO CANV AS FINAL CORRECTIONS DATE 03/11/02 REV BY SIS- SIS-MD CI-VTP ·1 i 2100' 1-14 1/2" HES X NIP, 10 = 3.813" 1 ~ 1 Z ~ -5435' 1-14 1/2" HES X NIP, 10 = 3.813" 1 -5455' 1-17" X 4-1/2" BKR S-3 PKR, 10 = 3.875" -5480' 1-14 1/2" HES X NIP, 10 = 3.813" 1 -5500' 1-17" X 5" BKR ZXP LINER TOP PKR/HNGR I Z ~ - PC leak diagnosed at -61 OO'md 2S. I 10758' 1-17" X 4-1/2" TrN SS HORIZ PKR, 10 = 3.92L 10802' 1-13-3/4" BKR DEPLOYMENT SLV. 10 = 3.00" 10806' 1-13-1/2" X 2-7/8" LNRXO, 10 = 2.387" 1 u " 4-1/2" LNR MILLOUT WINDOW 10890' - 10894' (OFF CMT RAMP) I LNR OBSTRUCTION? 1-1 13780' P 12-7/8" LNR, 6.5#, L-80. .0058 bpf , 10 = 2.387" 1-1 13863' 1 REV BY COMMENTS RL/tlh SET R.. UG PRUDHOE BAY UNIT WELL: 11-38A ÆRMIT No: 198-2160 API No: 50-029-22723-01 SEe 33, T11N, R15E 5115' NSL & 101' WEL BP Exploration (Alas ka) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ,f'h~s~Œ Oi! 8~ ) AUG 2, 4 2D05 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing II Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well f.!ass: Wl1,-r œ'Development 0 Exploratory o Stratigraphic ~rvice 5. Permit To Drill Number 198-216 ,/ 6. API Number: 50- 029-22723-01-00 /' 99519-6612 64.22' 9. Well Name and Number: PBU 11-38A -" ADL 028326 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool ,pßE$ENæ.WEL~'CQNDlrI9~'ß~tY1MABy,::i:,,:.. :'¡':,:h' Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): 13826 8874 9583 Size· MD . TVD.. Burst 8. Property Designation: ~1'. Total Depth MD (ft): 13871 Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 8870 Length Junk (measured): None Collapse Liner 129' 3061' 20" 110' 110' 1490 470 9-5/8" 3775' 3773' 5750 3090 7" 10856' 8835' 7240 5410 4-1/2" 10765' - 10894' 8831' - 8836' 8430 7500 2-7/8" 10802' - 13863' 8833' - 8871' 10570 11160 110' 3741' 10825' Perforation Depth MD (ft): Perforation Depth TVD (ft): 12790' - 13780' 8866' - 8877' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer; 4-1/2" Camco 'Bal-O' SSSV Nipple Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 9576'; 2195' Tubing MD (ft): 9623' 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Verbal Approval: Commission Representative: 17. I hereby cert~'= that the foregoing is true and correct to th. e best of my know. ledge. Printed Nam~ avidReem Þ 0 Title Drilling Engineer Signature ( ../. ~ Phone 564-5743 Commission Use Only Î) Novem~r,:!' 2005 Date: \- 15. Well Status after proposed work: o Oil 0 Gas o WAG DGINJ o Plugged 181 WINJ o Abandoned o WDSPL Contact David Reem, 564-5743 Date g/2~f)S Prepared By NamelNumber: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3oS--;)-(j l o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: Subsequent Form Required: Approved By: Form 10-403 Revised 11/2004 COMMISSIONER APPROVED BY THE COMMISSION Date (~) S: I G l ~lJL\L Submit In Duplicate ) ) Well Status: Shut-in produced water injector. Well has corroded tubing and a confirmed ¡"" leak in the 7" production casing at -6100'md. Well is secured with a tubing tail plug. Project: Retrieve existing 4.5", 12.6#, L-80 MBT completion, mill & recover packer and tail-pipe. Fully cement in place a 4.5", 12.6#/ft, L-80 IBT scab liner with liner top at -5500'md. Re-complete with 4.5", 12.6#/ft, L-80 TC-II tubing with WLEG stung into r' scab liner-top tie-back receptacle. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. 2. 3. 4. 5. 1. MIRU 4ES. Pull BPVs, set and test TWC in 4.5" tubing hanger. ND tree and adapter flange. NU BO~.. TJst annular to 250 psi (low)/3500 psi (high), remaining BOPE to 250 psi (low)/~99(Ypsi (high) per BP and AOGCC regulations. ~-.... Fully circulate thru the pre-RWO jet cut with heated seawater. Pull 4.5", 12.6#/ft, L-80 MBT down to the jet ~ just above the packer. Mill and recover the 4.5" x 7" S-3 packer. Run 6-1/8" bit and 7" casing scraper and clean wellbore to top of TIW horizontal liner top at 10756'md. 6. RU e-line and log with USIT from 10500' (hole angle = 74 degrees and getting higher) in both cement evaluation mode and corrosion mode. Log up to -5400'md. 7. Run 4.5", 12.6#/ft, L-80 IBT scab liner from top of 4.5" x 7" TIW SS horizontal / liner top packer/hanger at 10756'md up to -5500'md. Fully cement liner in place. 8. PT liner/casing to 4000 psi for 30-min (charted). Drill out shoe-t.rack. CBU with hi- (""/ vis sweeps to clean up wellbore. 9. Run new 4.5", 12.6#/ft, L-80 TC-II completion with WLEG stung into liner top packer's tie-back receptacle. Set and test packer to 4000 psi (tubing and inner annulus ). 10. RDMO 4ES. 11. Tie well in and place on injection. MITIA with AOGCC witness once well is on / injection and stabilized. /' .r ) TREE = 4-1/16"CIW WELLHEAD = FMC ACfUA"fóR;i3Akiðfc RäËCË\Ï'';;;' m_ . .. ^"'""64~:r2i' ~B F. ELEV = ' 3 Õ~1··Õì 'KÖp'; ........_"."....^..~...._...m61Õö' ,~~.·.·.~.~'~·~,~~=·)!.^·,'~~~.~I3"it' Datum MD = 12932' Datum TVO = 8800' SS 19-5/8" CSG, 40#, L-80, 10 = 8.835" 1-1 3775' Minimum ID = 2.387" @ 10806' 3-1/2" X 2-7/8" LNR XO 14-112" lBG, 12.6#, L-80, .0152 bpf, 10 =3.958" 1-1 9576' 14-1/2" TIP, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 9622' ) 11-38A SAFETY NOTES: WELL ANGLE> 700 @ 10370' & > 900 @ 11050'. 'I< DURING CTD SDTRK, AN OBSTRUCTION WAS NOTED IN 2-7/8" LNR @ 13780' (HANOOVER FORM). {I 2195' H4-1/2" CAMCO BAL-OSSSVN, 10= 3.812" ~ GAS LFT I\Að.NDRELS DEV TYPE VLV LATCH 1 KBG-2LS rN INT o KBG-2LS rN INT 54 KBG-2LS rN INT 51 KBG-2LS rN INT 51 KBG-2LS rN INT FORT DA TE o 01/23/01 o 01/23/01 o 01/23/01 o 01/23/01 o 01/23/01 ~ ST MD TV D 1 3464 3462 2 5192 5190 3 6589 6498 4 7905 7293 5 9222 8104 L ~ ~ S- 9576' H 7" X 4-1 /2" BKR 8-3 PKR, ID = 3.875" I 19583' SLMI-14-1/2" PX PLlK3 SET IN X NIP(03/11/02) 9600' 1-14 1/2" HES X NIP, ID = 3.813" 9623' 9614' 1-14 1/2" WLEG, ID = 3.958" 1 l-i ELMD TT LOGGED 11/02/98 1 ~ 10758' H 7" X 4-1/2" TIW SS HORlZ A<R, 10 = 3.924" ~ ~ 10802' 1--13-3/4" BKRDER.OYMENTSLV, 0 =3.00" 10806' 1-13-1/2" X 2-7/8" LNR XO, 10 = 2.387" I 17" CSG, 26#, L-80, ID = 6.276" 1-1 10856' µ ~ PffiFORA TION SUMv1ARY REF LOG: SWS MEIvDRY CNL ON 12/01/98 ANGLE AT TOP ÆRF: 87 @ 12970' Note: RBfer to Production DB for historcal perf data SIZ E SPF INTERV AL Opn/Sqz DA TE 2" 4 12970 - 13510 0 12/02/98 2" 4 13660 - 13780 0 12/02/98 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" H 13150' 1 DA.1E 01/19/97 12/02/98 01/16/01 03101/01 11/24/01 REV BY SI8- SIS-1'vD CH/TP COfv1tvENTS ORIGINAL COfv1R.E1l0N cm SIDETRACK CONVER1EDTO CANV AS FINAL CORREC1l0NS DATE 03/11/02 4-1/2" LNR MlLLOUT WINDOW 10890' - 10894' (OFF OV1TRAMP) 1 PBm H 13826' I ILNR OBSTRLCTON? I~ 13780' P 12-7/8" LNR, 6.5#, L-80, .0058 bpf ,ID = 2.387" H 13863' 1 REV BY COfv1tvENTS RUtlh SET R. UG PRUDHOE BAY LNIT WELL: 11-38A PffiMITf\b: 198-2160 A R f\b: 50-029-22723-01 SEC 33, T11 N, R15E 5115' NSL & 101' WEL BP Exploration (Alas ka) "I TREE = WELLHEAD = }!' A CTUA TOR = KB. ELEV = BF. ELEV = KOP= ."",,, ,,,,,.., """ .'" _~ax..A.~gle= Datum MD = Datum TVD = ) 11-38A Propose a ) 4-1/16" CrN FMC BAKER C 64.22' 30.10' 6100' 97 @ 11611' 12932' 8800' SS I 9-5/8" CSG, 40#, L-80, ID = 8.835" l-i 3775' r--JI Minimum 10 = 2.387" @ 10806' 3-1/2" X 2-7/8" LNR XO 14-1/2" TBG, 12.6#, L-80, TC-II, ID = 3.958" l-i -5498' Liner to be fully cemented in place, seals stung into TIW tie-back receptacle, ZXP to be set .....500' above PC leak. 14-1/2", 12.6#, L-80, IBT, SCAB LINER l-i 10758' 1 I 7" CSG, 26#, L-80, ID = 6.276" l-i 1 0856' ~ ÆRFORA TION SUMMA RY REF LOG: SWS MEMORY CNL ON 12/01/98 ANGLEATTOPÆRF: 87@ 12970' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 12970 - 13510 0 12/02/98 2" 4 13660 - 13780 0 12/02/98 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 13150' 1 DATE 01/19/97 12/02/98 01/16/01 03/01/01 11/24/01 REV BY SIS- SIS-MD CH/TP COMMENTS ORIGINAL COMPLETION CTD SIDETRA CK CONVERTED TO CANV AS FINAL CORRECTIONS DATE 03/11/02 I I 1-i4 1/2" HES X NIP, ID = 3.813" 1 2100' ~ I Z ~ I Z ~ -5435' 1-i4 1/2" HES X NIP, ID = 3.813" 1 -5455' I-iT' X 4-1/2" BKR S-3 PKR, ID = 3.875" -5480' 1-i4 1/2" HES X NIP, ID = 3.813" 1 -5500' l-i 7" X 5" BKR ZXP LINER TOP PKR/HNGR PC leak diagnosed at -61 OO'md I 10758' I-iT' X 4-1/2" TrN SS HORIZ PKR, ID = 3.924" I 10802' l-i 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" 10806' l-i 3-1/2" X 2-7/8" LNR XO, ID = 2.387" 1 u ~ 4-1/2" LNR MILLOUT WINDOW 10890' - 10894' (OFF CMT RAMP) I LNR OBSTRUCTION? l-i 13780' P I 2-7/8" LNR. 6.5#, L-80, .0058 bpf , ID = 2.387" l-i 13863' I REV BY RL/tlh COMMENTS SET PLUG PRUDHOE BAY UNrT WB..L: 11-38A ÆRMrT No: 198-2160 API No: 50-029-22723-01 SEC33. T11N, R15E5115' NSL & 101' WEL BP Exploration (Alaska) ) ) MECHANICAL INTEGRITY REPORT· '... ~ ? U D I) .~. :::: : U./ (p //9 '1 f :. .:: G R :s L S ;_ ~ =: : 12/ s ¡ I q ~ f OPER & FIELD - Er ~ p Y..U w=:U NUMBER l t - ~~ ft-- lq~Z.I& Cê.si~g: II 7 2. 71 1/ _::..:¡e::-: ~. '8 :'--10 i:: g: 4" 'I ¿ ,I P acke.r 101 S·~ HI) g c.' II :.ole Siz.e . oJ TD : 1~~1( .MD.. ~{1 0 TVD ; ::?BTD : / Š .g2.& MD 8£74 TVD Shoe: lO~S(P MD 8-9~Ç TVD i DV: HD ·Tvl) Shoe: 1~~0S }ill ·8·~ II TifD j :CP: (0302 HD ~f ') ~ ;:"'¡T) 7n: ~LL DATA TVD i Set ë. t anå II ; -1/f Perfs l~q70 to 1~7;O ::-s CF..Þ_NI Cl-.L INTEGRITY - PART i 1 Annulus Press Test: ~p 15 m.~n 3 0 min C 0 r:r:ü:il e n t oS: M r '1- vt 1 (."(,,,1(' f¿.cl. (j ,,- ~CBÞ_1qICÞ...L INTEGRITY - PART /2 ". . ~ g l ~ (., \ &9 .asP( ¡ ~lÞ 11)7 (;) z.ttl ~O( ?4{ 14A-l L q"S 2..04- Ce.ment: Volumes:' .Amt. Line.r27.~ bbk; Csg~SO Sf! i DV CLIlt -..rol to cove'!:' per=s I V ht,;¡./c;.. (i> ~o?þ' 0"1...(¡¿t;Ç t- 500 I. Theoret:ical Toe \OOtoGo C TO L I (? f 0 2.' ) 7' I ~ kµ 10 8I:S&" J Ce.me!1t Bond Log (Yes or No) ~I In AOGCC File . eBL ~valuation, ~one ëDove perfs C Q I ~1 l.Uìi'.eJ Prociu~tion Log: Type Evalu.a.tion .. CONCtUSIONS: ? ar t ; 1: Nl.L T r.,p;) ~·\"-..l.d rI. ./.- If+-" I I ¡ ? ar:: f. 2: l,{ JIVl-tw·u ~l ¿LA.,t {,. CM 10 1 '01',1 ~.AA p\l C1. ' ~Þ.i . N-C-t1 vc! <~ ~ f- t>...{I Iw ¡¿ ,....Jllf, \ ""d1r --p .~\ uL.. 1"- ~r1~ . A-t tJ h.?\t'.¿J q ¡'z I I '1,0" ç- 'y.j (, MJ'-·.YJ STATE OF ALASKA ALA~i~ OIL AND GAS CONSERVATION COMIV'i7~SI(~ ~1 WELL COMPLETION OR RECOMPLETION REP'OR* 1. Status o! well Classification of Service Well Oil r~ Gas O Suspended [~] Abandoned D Service [~ 2. Name o! Operator 7. Permit Number ARCO Alaska, Inc. 98-216 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22723-01 4. Location of well at sudace 9. Unit or Lease Name 5115' FSL, 101' FEL, SEC. 33, T11N, R15E, UM At Top Producing Interval !'~/~":;~/:" 670' FSL, 3637' FEL, SEC 28, Tl1", R15E, UM ~!__ ..... .;_~1~_... 3945' FSL, 288' FEL, SEC 32, T11N, R15E, UM ~ ....... '~~ ........ PRUDHOE BAY FIELD 5. Elevation in feet (Indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 64 feetI ADL 28326 PRUDHOE BAY OIL POOL 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, il ol/shore 16. No. of Completions November 6, 1998 November 28, 1998 December 3, 1998 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 13871' MD /8870' TVD 13781' MD /8877' TVD YES ['~ No [--~I red depth) fee~ MD 1900' (approx) 22. Type Electric or Other Logs Run SWS GR/CNL/CCL, MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20' 91.5~ H-40 Surface 110' 30' 260 sx Arctic Set 9-5/8' 40# L-80 34' 3775' 12-1/4" 1490 Sx CS lit, & 335 Sx Class G 7' 26# L-80 31' 10856' 8-1/2' 350 Sx Class G 4-1/2' 12.6# L-80 10765' 10894' 6' Uncemented (slotted liner) 2-7/8' 6.4# L-SO 10802' 13863' 3-3/4' 27.8 bbls 15.8 ppg LARC 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD .... interval, size and number) SIZE DEPTH SET (MD) PACKER',~:IIt~~ 4-1/2' 9623' 9576' 12790' - 13510' MD; 8862' - 8879' TVD; @ 4 SPF 13660' - 13780' MD; 8880' - 8877' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 5, 1998 Flowing Date of Test Hours Tested Production for OIL-BBL iGAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 12/8/1998 5.0 Test Pedod >I 18501 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 1660 psi 24-Hour Rate > 1151 21294 0 28. CORE DATA Brief description ot lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved October 27, 1998 (Permit #98-216) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Shublik Top Top of Sadlerochit Top of Zone 1/1B GEOLOGIC MARKERS ...... ' MEAS. DEPTH 9626' 9688' 10925' 30. '- ...... FORMATION TESTS TRUE VERT. DEPTH 8354' 839Z 8838' Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF A'I-rACHMENTS Summary of 11-38A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify thai the following Is true and correct to the best of my knowledge. Signed ~~~ Title AA I Coil Tubin,q Ddl in.q Supervisor Bruce E. Smith, P.E. Date Prepared by Paul Rauf 263-4990. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 198-216-0 PRUDHOE BAY UNIT 11-38A 50- 029-22723-01 BP EXPLORATION (ALASKA) INc Roll #1: Start: Stop Roll #2: Start Stop MD 13871 TVD 08870 Completion Date: 12/3/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D C Temp/Press/GR/CCL FINAL 10250-11700 Digital Data CH 11/28/00 1/3/01 D 9145 4-12 SPERRY GR OH 5/20/99 5/21/99 ~L MCNL FINAL 9500-13780 CH 2 1/6/99 1/15/99 L.~L MCNL FINAL 1255-13764 CH 2 2/16/99 2/18/99 L/L NGP-MD FINAL 10806-12115 OH 5/21/99 5/21/99 L/L Temp/Press/GR/CC FINAL 10250-11700 BL, Sepia CH 5 11/28/00 1/3/01 L USIT FINAL 12600-13770 CH 1/21/99 1/28/99 ~r~ R SRVY RPT SPERRY 10806-13870. OH 12/9/98 12/17/98 T 8950 1 SCHLUM MCNL CH 1/6/99 1/15/99 T 8987 1 SCHLUM MCNL CH 2/16/99 2/18/99 Thursday, January 18, 2001 Page 1 of 1 11-38A .... DESCRIPTION OF WORK COMPLETED~--~ COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/06/1998: 11/07/1998: 11/08/1998: 11/09/1998: 11/10/1998: 11/11/1998: 11/12/1998: 11/13/1998: 11/14/1998: 11/15/1998: 11/16/1998: 11/17/1998: 11/18/1998: 11/19/1998: 11/20/1998: 11/21/1998: 11/22/1998: 11/23/1998: 11/24/1998: 11/25/1998: (Drilling operations cont. f/P&A job). RIH & milled Cement f/10836' to 10890' MD. Time milled to 10902'. Drilled to 11020' but stayed in casing, no kickoff. POOH w/BHA. RIH w/nozzle & tagged BTM @ 11018' MD. C/O liner to 10000'. Pumped 17.5 bbls of 17 ppg Neat Class G Cement to form a KOP. Attained a max sqz press of 1400 psi w/<1 bbl of Cement behind pipe. Contaminated Cement w/Biozan & jetted contaminated Cement to 10775'. POOH w/nozzle. RIH w/BHA & coil parted @ ~8235'. Top of fish @ -2540'. Stabbed into BOP stack & FP'd CT. RIH & retrieved fish located @ 2572' MD. Swapped CT reels & performed rig maintenance. Completed rig maintenance. Tested BOPE. RIH w/BHA to 10560' MD. Tagged TOC @ 10785'. Drilled to 10890'. POOH. RIH & milled Cement to 10891.5'. Time milled the 4-1/2" fiberglass MLAS Sub window f/10894' to 10908'. Press up w/water to 1000 psi & shut in. Bled to 500 psi in 5 min. POOH. RIH w/bi-centered bit. Unable to get past 7576' so POOH w/BHA. Rill & dressed window interval. Drilled to 10919' & swapped to FIo Pro. Drilled to 11084' w/short trips to window. Performed LOT to EMW of 9.5 ppg. Drilled FM to 11525' & POOH. RIH & reamed interval around 11348'. POOH w/BHA. RIH & drilled f/11525' to 11600'. Drilled to 11684' & CT stuck. Pumped Crude & freed CT. Cont drilling to 11878'. Circulated new FIo Pro mud. Drilled to 12104' MD. Drilled f/12104' to 12114'. POOH. Tested BOPE. Performed rig maintenance. RIH w/BHA. Reamed 11800' to 11900'. Tagged BTM & drilled to 12495'. Drilled to 12680' where CT became stuck. Freed CT w/Crude. Drilled to 12733' & again became stuck. Pumped Crude to free pipe & drilled ahead to 12814'. Swapped to new FIo Pro. Drilled to 12955' & POOH. RIH & drilled to 13197'. Drilled to 13270' MD & POOH. Sidetrack Summary Page I ....... 11-38A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/26/1998: 11/27/1998: 11/28/1998: 11/29/1998: 11/30/1998: 12/01/1998: 12/02/1998: 12/03/1998: Drilled to 13330' MD w/short trips to window. Drilled to 13360' MD. Drilled to TD @ 13871'. Circulated new FIo Pro pill in OH while POOH. RIH w/2-7/8" liner & worked it to 12930'. Landed liner @ 13863'. Released liner & stabbed back into it. Pumped 27.8 bbls of 15.8 ppg LARC to cement liner in place. Launched dart & bumped press to 3000 psi. Cleaned out liner w/Biozan to 9600'. POOH. TOL=10802'. Press tested BOPE. RIH w/logging tools & logged to PBTD @ 13781'. Logged up f/BTM & POOH. Performed liner press test. Press bled f/1850 psi to 1600 psi in 30 min - passed. RIH w/Per[ guns to PBTD & shot 840' of Initial Perforations located @: 12790' - 13510' MD (Zone lB) Ref Log: CNL mem log 12/1/1998 13660'- 13780' MD (Zone lB) Used 2" carriers & shot all Peris @ 4 SPF' 0° phasing, overbalanced, & random orientation. POOH w/guns circulating 2% KCL Water. ASF. RDMOL. Placed well on initial production & obtained a valid well test. Sidetrack Summary Page 2 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS ~ ~ , Slot ~ ~.38A ~ 1-38A Job No. AKMMgOOIO, Surveyed: 27 November, 1998 ORIGINAL S UR VEY REPORT 9 December, 1998 RECEIVED DEC 17 1998 A~as~a Oi~ & Gas Con~. Commi~on Your Reft API-500292272301 KBE- 64.22' MWD Survey Instrument Surface Coordinates: 5949527.60 N, 707457.40 E (70° 15' 55.8828' N, 148° 19' 20.8655' W) DRILLINI~ SERVICES Survey Reft svy4192 Sperry-Sun Drilling Services Survey Report for 11-38A Your Ref: API-500292272301 Job No, AKMM90010, Surveyed: 27 November, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 10806.00 86,760 234.100 8768.70 10831.00 87,650 233.390 8769.92 10856.00 88.530 232,680 8770.75 10881.00 89.420 231.980 8771.20 10890.00 89,740 231,700 8771.27 10918.03 83.160 226,800 8773.00 10952.79 83,100 220.780 8777.16 10996.98 83.940 220.530 8782.15 11031.26 87.010 218.770 8784.85 11077.11 92.990 219.480 8784.85 11105.70 92.460 223.690 8783.49 11135.10 89.910 231.400 8782.89 11167.92 87.890 228.800 8783.52 11191.19 89.560 222.300 8784.03 11220.49 91,490 224.600 8783.77 11247.93 92.640 223.500 8782.78 11274.90 93.340 221.200 8781.37 11306.88 91.840 217.700 8779.92 11335.18 91.490 218.600 8779.10 11373.38 89.120 218.600 8778.90 11404.92 88.330 215.800 8779.60 11447.85 91.230 215.400 8779.77 11492.35 90.530 214.900 8779.08 11525.68 92.640 211.600 8778.16 11559.70 95.710 210.500 8775.68 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8832.92 909.49 N 3444.35W 8834.14 894.72 N 3464.49W 8834.97 879.70 N 3484.45W 8835.42 864.42 N 3504.23W 8835.49 858.86 N 3511.31W 8837.22 840.62 N 3532.49W 8841.38 815.72 N 3556.36W 8846.37 782.41N 3584.97W 8849.07 756.10 N 3606.77W 8849.07 720.55 N 3635.69W 8847.71 699.19 N 3654.64W 8647.11 679.37 N 3676.31W 8847.74 658.32 N 3701.48W 8848.25 642.04 N 3718.07W 8847.99 620.77 N 3738.22W 8847.00 601.06 N 3757.29W 8845.59 581.16 N 3775.43W 8644.14 556.50 N 3795.72W 8843.32 534.25 N 3813.20W 8643.12 504.40 N 3837.03W 8843.82 479.29 N 3856.09W 8843.99 444.38 N 3881.08W 8843.30 408.00 N 3906.69W 8842.38 380.15 N 3924.96W 8839.90 351.08 N 3942.46W 5950341.83 N 703989.30 E 5950326.51N 703969.57 E 5950310.95 N 703950.03 E 5950295.13 N 703930.68 E 5950289.38 N 703923.76 E 5950270.56 N 703903.09 E 5950245.01 N 703879.91 E 5950210.92 N 703852.24 E 5950184.02 N 703831.17 E 5950147,69 N 703803.24 E 5950125.82 N 703784.88 E 5950105.41N 703763.77 E 5950083.67 N 703739.19 E 5950066.94 N 703723.05 E 5950045.13 N 703703.49 E 5950024.90 N 703684.98 E 5950004.50 N 703667.39 E 5949979.29 N 703647.78 E 5949956.57 N 703630.93 E 5949926.07 N 703607.93 E 5949900.44 N 703589.57 E 5949864.87 N 703565.55 E 5949827.79 N 703540.95 E 5949799.44 N 703523.46 E 5949769.91 N 703506.77 E Alaska State Plane Zone 4 PBU EOA DS 11 Dogleg Rate (o/looft) Vertical Section (ft) Comment 4.552 4,522 4.529 4,724 29.243 17.195 1.982 10.315 13.134 14.825 27.614 10.030 28.832 10.247 5.798 8.903 11.897 3.411 6.204 9.222 6.819 1.933 11.748 9.583 2126.91 2151.86 2176.84 2201.83 2210.83 2238.76 2272.95 2316.08 2349.52 2394.30 2422.43 2451.73 2484.53 2507.66 2536.67 2563.86 2590.45 2621.69 2649.22 2686.46 2717.02 2758.31 2801.02 2832.67 2864.46 Tie-on Survey Window Point Continued... 9 December, 1998 - 12:07 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 11-38A Your Ref: API-500292272301 Job No. AKMMgOOfO, Surveyed: 27 November, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 11610.65 96.500 203.000 8770.26 11644.82 94.480 198.600 8766.99 11672.97 90.970 197.200 8765.65 11703.01 89.030 195.600 8765.65 11732.33 90.700 190.500 8765.72 11768.58 95.620 195.400 8763.72 11796.37 93.690 197.700 8761.46 11830.00 89.740 198.400 8760.46 11865.03 86.020 195.500 8761.75 11936.31 89.030 198.600 8764.83 11966.15 86.920 200.000 8765.89 11996.25 85.340 199.400 8767.92 12033.77 84.990 195.600 8771.08 12066.36 84.110 189.400 8774.18 12096.08 83.410 189.600 8777.41 12131.35 85.870 192.900 8780.70 12173.19 87.190 198.400 8783.24 12208.55 86.220 202.100 8785.27 12236.08 85.600 205.400 8787.24 12265.68 88.070 207.000 8788.87 12285.34 89.120 209.980 8789.35 12323.48 88.420 213.150 8790.17 12351.18 89.030 216.490 8790.79 12367.13 89.410 219.620 8791.01 12381.19 89.210 219.120 8791.17 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northlngs Eastlngs (ft) (ft) (ft) (ft) (ft) 8834.48 305.88 N 3965.25W 5949724.09 N 703485.23 E 8831.21 274.09 N 3977.32W 5949691.99 N 703474.04 E 8829.87 247.34 N 3985.96W 5949665.00 N 703466.14 E 8829.87 218.52 N 3994.44W 5949635.97 N 703458.46 E 8829.94 189.97 N 4001.06W 5949607.24 N 703452.63 E 8827.94 154.72 N 4009.16W 5949571.78 N 703445.50 E 8825.68 128.17 N 4017.05W 5949545.02 N 703438.34 E 8824.68 96.21N 4027.46W 5949512.80 N 703428.82 E 8825.97 62.74 N 4037.67W 5949479.05 N 703419.54E 8829.05 5.33 S 4058.54W 5949410.44 N 703400.54E 8830.11 33.47 $ 4068.40W 5949382.03 N 703391.47 E 8832.14 61.74 S 4078.52W 5949353.49 N 703382.13 E 8835.30 97.39 $ 4089.76W 5949317.55 N 703371.87 E 8838.40 129.05 $ 4096.78W 5949285.71N 703365.73 E 8841.63 158.19 S 4101.66W 5949256.44 N 703361.66 E 8844.92 192.62S 4108.51W 5949221.84N 703355.76 E 8847.46 232.82 S 4119.77W 5949181.34N 703345.61E 8849.49 265.93 S 4131.99W 5949147.90 N 703334.31E 8851.46 291.06 S 4143.05W 5949122.48 N 703323.95 E 8853.09 317.58 S 4156.09W 5949095.61N 703311.64E 8853.57 334.85 S 4165.47W 5949078.09 N 703302.74 E 8854.39 367.34 S 4185.43W 5949045.07 N 703283.69 E 8855.01 390.07 S 4201.24W 5949021.91 N 703268.51 E 8855.23 402.62 S 4211.07W 5949009.09 N 703259.03 E 8855.39 413.49 S 4219.98W 5948997.98 N 703250.41E Alaska State Plane Zone 4 PBU EOA DS 11 Dogleg Rate (°/'tOOft) Vertical Section (ft) Comment 14.718 14.115 13.422 8.371 18.302 19.138 10.783 11.928 13.461 6.059 8.484 5.613 10.135 19.129 2.448 11.637 13.495 10.801 12.167 9.938 16.067 8.510 12.254 19.766 3.830 2910.46 2939.71 2963.14 2987.73 3010.70 3039.00 3061.72 3089.78 3118.62 3177.36 3202.61 3228.15 3259.15 3284.37 3306.35 3333.16 3367.02 3397.21 3421.52 3448.25 3466.34 3502.20 3528.73 3544.24 3557.99 Continued... 9 December, 1998 - 12:07 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 11-38A Your Ref: API-500292272301 Job No, AKMM90010, Surveyed: 27 November, 1998 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 12410.65 89.820 224.920 8791.42 12440.16 88.420 222.990 8791.88 12469.90 88.770 217.190 8792.61 12514.56 90.970 212.620 8792.71 12560.72 91.410 216.840 8791.75 12595.07 90.090 220.530 8791.30 12643.42 91.410 226.330 8790.67 12692.24 86.540 230.410 8791.54 12729.28 86.660 229.320 8793.74 12749.63 87.360 232.480 8794.80 12788.00 85.340 233.010 8797.24 12827.25 90.620 240.740 8798.63 12865.14 91.840 243.380 8797.81 12899.14 87.360 240.570 8798.05 12965.06 86.680 240.600 8801.48 12999.44 84.110 239.690 8804.24 13020.25 84.730 242.850 8806.26 13053.96 87.310 244.300 8808.60 13092.88 89.300 246.190 8809.75 13133.99 87.890 250.590 8810.76 13163.73 91.410 252.700 8810.94 13196.53 89.910 252.500 8810.56 13228.10 90.000 252.900 8810.59 13267.06 91.490 258.100 8810.08 13296.60 93.160 257.100 8808.88 Vertical Local Coordinates Global Coordinates Depth Northings Eastlngs Northings Eastings (ft) (ft) (ft) (ft) (ft) 8855.64 435.37 S 4239.69W 5948975.57 N 703231.31E 8856.10 456.61S 4260.17W 5948953.77 N 703211.43 E 8856.83 479.34 $ 4279.31W 5948930.52 N 703192.92 E 8856.93 515.96 S 4304.86W 5948893.21N 703168.39 E 8855.97 553.88 S 4331.14W 5948854.58 N 703143.16 E 8855.52 580.68 S 4352.61W 5948827.19 N 703122.45 E 8854.89 615.78 S 4385.83W 5948791.20 N 703090.20 E 8855.76 648.19 S 4422.29W 5948757.80 N 703054.65 E 8857.96 672.02 S 4450.56W 5948733.19 N 703027.05 E 8859.02 684.84S 4466.33W 5948719.95 N 703011.64E 8861.46 708.02 S 4496.81W 5948695.94 N 702981.81E 8862.85 729.42 S 4529.62W 5948673.63 N 702949.60 E 8862.03 747.17 S 4563.09W 5948654.97 N 702916.64E 8862.27 763.14 S 4593.09W 5948638.18 N 702887.08 E 8865.70 795.47 S 4650.43W 5948604.28 N 702830.65 E 8868.46 812.53 S 4680.15W 5948586.41N 702801.42 E 8870.48 822.48 S 4698.31W 5948575.96 N 702783.54E 8872.82 837.45 S 4728.42W 5948560.17 N 702753.85 E 8873.97 853.74 S 4763.75W 5948542.92 N 702718.99 E 8874.98 868.87 $ 4801.95W 5948526.74 N 702681.22 E 8875.16 878.23 S 4830.17W 5948516.60 N 702653.27 E 8874.78 888.04 S 4861.46W 5948505.94 N 702622.25 E 8874.81 897.43 S 4891.60W 5948495.72 N 702592.38 E 8874.30 907.18 S 4929.31W 5946484.93 N 702554.96 E 8873.10 913.51S 4958.13W 5948477.80 N 702526.32 E Alaska State Plane Zone 4 PBU EOA DS 11 Dogleg Rate (o/,iooft) Vertical Section (ft) Comment 19.796 8.079 19.532 11.356 9.190 11.408 12.301 13.011 2.955 15.884 5.442 23.834 7.674 15.553 1.033 7.927 15.404 8.774 7.050 11.236 13.799 4.614 1.299 13.883 6.588 3587.04 3616.29 3645.42 3688.22 3732.41 3765.90 3813.75 3862.47 3899.43 3919.75 3958.03 3997.03 4034.26 4067.68 4132.68 4166.55 4186.95 4219.83 4257.60 4296.91 4324.81 4355.40 4364.82 4420.39 4446.88 Continued,.. 9 December, 1998 - 12:07 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 11-38A Your Ref: API-500292272301 Job No, AKMMgO010, Surveyed: 27 November, ~998 Prudhoe Bay Unit Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastlngs (ft) (ft) (ft) (ft) (ft) 13343.58 90.000 255.300 8807.59 8871.81 924.71 S 5003.73 W 5948465.35 N 702481.05 E 13370.51 89.380 253.200 8807.73 8871.95 932.02 S 5029.65 W 5948457.33 N 702455.35 E 13415.86 87.280 250.100 8809.06 8873.28 946.29 S 5072.67 W 5948441.88 N 702412.74 E 13441.91 87.100 252.200 8810.33 8874.55 954.70 S 5097.29 W 5948432.80 N 702388.36 E 13469.35 85.690 248.600 8812.06 8876.28 963.88 S 5123.08 W 5948422.91 N 702362.82 E 13513.71 85.600 245.300 8815.43 8879.65 981.20 S 5163.78 W 5948404.48 N 702322.62 E 13551.69 88.940 245.100 8817.24 8881.46 997.11 S 5198.21 W 5948387.63 N 702288.64 E 13580.01 90.000 242.300 8817.50 8881.72 1009.65 S 5223.59 W 5948374.39 N 702263.61 E 13613.42 91.490 238.600 8817.06 8881.28 1026.13 S 5252.65 W 5948357.12 N 702235.02 E 13646.90 90.900 240.400 8816.37 8880.59 1043.11 $ 5281.49 W 5948339.34 N 702206.66 E 13674.62 90.880 239.500 8815.94 8880.16 1056.99 S 5305.48 W 5948324.81 N 702183.06 E 13705.00 91.400 238.200 8815.33 8879.55 1072.71 S 5331.48 W 5948308.39 N 702157.51 E 13870.00 95.180 231.400 8805.85 8870.07 1167.57 S 5465.99 W 5948209.85 N 702025.66 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. · , ' Magnetic Declination at Surface is 28.047° (03-Nov-98) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 231.450° (True). Based upon' Minimum Curvature type calculations, at a Measured Depth of 13870.00ft., The Bottom Hole Displacement is 5589.30ft., in the Direction of 257.942° (True). Alaska State Plane Zone 4 PBU EOA DS 11 Dogleg Rate (°~'~O0~t) Vertical Section (ft) Comment 7.740 8.131 8.254 8.081 14.065 7.420 8.810 10.571 11.938 5.657 3.247 4.608 4.709 4489.52 4514.34 4556.88 4581.37 4607.27 4649.89 4686.73 4714,40 4747.39 4780.53 4807.95 4838.07 5002.38 Projected Survey Continued... 9 December, 1998 - 12:07 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 11-38A Your Ref: API-500292272301 Job No. AKMM90010, Surveyed: 27 November, 1998 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 11 Comments Measured Depth (ft) 10806.00 10890.00 13870.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8832.92 909.49 N 3444.35 W 8835.49 858.86 N 3511.31 W 8870.07 1167.57 S 5465.99 W Comment Tie-on Survey Window Point Projected Survey 9 December, 1998 - 12:07 - 6 - DrillQuest D I~ I I--I--I N 13 WELL LOG TRANSMITTAL To: State of Alaska May21, 1999 Alaska Oil and Gas Conservation Comm. Arm: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ <~, ~IQ:) RE: MWD FormafionEvaluafionLogs: 11-38A, AK-MW-90012 The technical data listed below is being subn-dtted-herewitk Please address any problems or cone, ems to the attention oF Fun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 D.S. 11-38A: 2" x 5" MD C_mnmm Ray Logs: 504)29-227234)1 2"x 5" TVl~.Cammaa RayLogs: 504)29-22723-01 1 Btu~' 1 Folded Sepia No TVD log Gas Cons. CommissiOn ~h0rage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company C] FI I I--I-- I N [:S WELL LOG TRANSM1TFAL To: State of Alaska May 20, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 11-38A, AK-MW-90012 The technical data listed below is being submitted herewitk Please acknowledge receipt by renaming a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~ Anchorage, AK 99518 1 LDWG formatted Disc with vedfica~n l/sting. API#: 50-029-22723-01. RECEIVED 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 2/16/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al-tN: Sherrie NO. 12332 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 5-1 OB ~'-1~ ~ 98425 RST 980528 1 1 1 D.S. 5-12 ~<x:~ ~ 99046 RST 981216 1 1 1 D.S. 5-17B '~, ~'cl~ 99062 MCNL (PDC) 980818 I I 1 D.S. 11-38A "~c~'~l 99048 MCNL BORAX 990105 1 ] 1 D.S. 18-14A ~c~ ~ 99051 RST-SIGMA 980630 I 1 ] SIGN DATE: I' ~,Et 1 8 1999 .,/tllil~ka 0il & Gas Cons. C~'~r~'~i~i~ Please sign and return o py of this transmittal to Sherrie at the above address or fax to (907) 562-65~1~1~'~ you, 1/21/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Ar[N: Sherrie NO. 12264 Compan~ Alaska Oil & Gas Cons Corem Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 -- wq-o~.3 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 4-21 99014 RST-SIGI~ '5~ ~(o"2...~ 980810 1 1 1 D.S. 12-01 99017 RST --~ :~;;>~"~ 980908 I 1 1 D.S. 15-48 99015 iRST-SIGMA ~ ~~ 980802 1 1 1 D. S. 11-38 ~ PRODUCTION PROFILE 990105 I 1 D. S. 12-01 ~PRODUCTION PROFILE 990102 I 1 D.S. 12-02 t~t~_ ~INJECTION PROFILE 990113 1 1 RECEIVED SIGN DATE:~ ^,.~ o 7 '~COa / Please sign and return one of this transmittal to Sherrie at the above address or fax to 1/6/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12207 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape 077 OWDW-SE ~'1(~, ?EMP PRESSURE S~Y 981219 1 1 O~W-CENTER [~/ ~ T~P P~SS~ S~Y 981219 1 1 O~W-~ ~Y/ ~ T~P P~SS~ S~Y 981219 1 1 L2-08A P~ ~LRY LOG 981225 1 1 D.S. 5-31A (~) 98635 MCNL 981108 1 *REDO-TO CORRECT K.B. 71, D.F. 35 & G.L. 70 -PLEASE CORRECT PRINTS SENT PREVIOUSLY. ~ '~ ~ ~.s. s-~ ~ ~c~ ~ ~~ ~os 1 1 1 ~.s. ~-~e ~8~58 RST-SIGMA '~ ~~ ~sn~5 1 1 1 ~.s. ~-30 . ~8~5~ MCNL -~ ~~ ~S~03 1 1 1 ~.s. ~-38~ e~002 MCNL ~ ~ ~ ~8~2~ ! 1 1 ~.s. ~5-0~ ~00~ MCNL ~ ~q~ ~2~ 1 1 1 ~.s. ~s-3~ ~8~85 ~st-~o~ .~ ~~ ~0~ 1 1 1 DATE: ~At,I i5 1999 Alaska Oil & Gas Oono. Oommi~ior, Please sign and return one copy of this transmittal to Sherrio at the above address or fax to (907] 562-652.~l~Jl~you. ri F! I I_1_1 I~ G SE I:l~JI I-- E S 09-Dec-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 11-38A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,806.00' MD 10,890.00' MD 13,870.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Octobcr 27. 1998 Erin M. Oba Enginccring Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Pmdhoe Bay Unit 11-38A ARCO Alaska. Inc.. Permit No: 98-216 SurLoc: '~II_NSL. 101'WEL. Sec. 33. TI1N. R15E. UM Btmholc Loc. 1394'NSL 232'WEL. Sec. 32. T1 IN. R15E. UM Dear Ms. Oba: Enclosed is thc approvcd application for permit to rcdrill thc above rcfcrcnccd well. The permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting detcrminations arc madc. Blowout prevention cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25 035. Sufficient notice (approximatcly 24 hours) lnust bc givcn to allow a rcprcscntativc of thc Commission to witncss a tcst of BOPE installcd prior to drilling ncw hole. Noticc may bc given by contacting !h~e olcum field inspcctor on thc North Slope pager at 659-3607. David W. 'JohNnston Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosurcs CC: Dcpartmcnt of Fish & Gan]c. Habitat Scction v,-/o cncl. Departmcnt of Environmental Conscrvation w/o cncl. STATE OF ALASKA ~:-, ALAS~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill_ Redrill X~ I lb. Type of Well Exploratory_ Stratigraphic Test_ Development Oil~X Re-Entry__ Deepen -I Service_ Development Gas_ Single Zone.~X Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 028325 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 .&AC 25.025) 5115' NSL, 101' WEE, Sec 33, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 746' NSL, 2597' WEL, Sec 28, T11 N, R15E, UM 11-38A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1394' NSL, 232' WEL, Sec 32, T11N, R15E, UM November, 1998 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'i'VD) properly line No Close Approach 14120' MD / 8879' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10890' MD Maximum hole angle 91° Maximum surface 2800 psi~ At total depth (TVD) 3435 psi9 @ 8879' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling ILength MD TVD MD TVD (include stage data) 3-3/4 2-7/8" 6,4 L-80 FL4S 3345' 10775' 8831' 14120' 8879' 18 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13150 feet Plugs(measured) PBTD Tagged @ 13105' MD (4/4/98) true vertical 8867 feet Effective depth: measured 13105 feet Junk (measured) true vedical 8868 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 260 Sx Arctic set 110' 110' Surface 3741' 9-5/8" 335 Sx Class G & 1490 Sx CS III 3775' 3773' Production 10825' 7" 350 Sx Class G 10856' 8835' Liner 2392' 4-1/2" Uncemented 13150' 8867' Pedoration depth: measured 11349' - 13122'. (Slotted Liner) RECEIVED true vertical 8833' - 8868'. (Slotted Liner) NC Oil & 8as Cons. comm ion 20. Attachments Filing fee % Property plat_ BOP Sketch ~X Diverter~'"'~k ~S~et~n10ra~e Drilling program X Drilling fluid program __ Time vs depth plot -- Refraction analysis _ Seabed report _ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions: Call Steven Ward @ 265-1305. Signed '~/¢.~ %. ~ Titlle Engineering Supervisor Date //0-- Erin Oba Commission Use Only Prepared by Paul RaW263-4990 Permit Number ,~_ .~../t~:,~' IAP' "umber 50- a.:z 7.3 -o/ I Appr°va? e'-.RotherSee cover letter ,Orrequirements Conditions of approval Samples required_Yes ~No Mud log required _ Yes _,,,~'No Hydrogen sulfide measures ,~'Yes _ No Directional survey required /,3~es _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M?_~500 psi for CTU Other: Approved by O~vici W. Johnsto~ by order of Form 10-401 Rev. 7-24-89 Submit in triplicate DS 11-38A CT Drilling and Completion Intended Procedure Objective: Directionally drill-~3000', 3-3/4" horizontal hole from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Cement squeeze the current slotted liner and plugback the existing completion to -~ 10800' md. Mill window in 4-1/2" liner at -10890' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to -91 °. Directionally drill 3-3/4" x 3000' horizontal well to access Lower Romeo reserves. Run and cement 2-7/8" liner to TD. Perforate selected intervals. Place well on production. October 14, 1998 8000- 8200 8400 8600 8800 9000 9200 9400 ARCO Alaska, Inc. ............. ~T,:';ii'i-'JT;'";'"E'E'"¥'i ................................... '~;'ii'"..'"T'{'"'i~' .................... : Field : Prudhoe Bay Location : North Slope, Alaskoi <- West (feet) 6900 6600 6300 6000 5700 5400 5100 4800 4500 4200 3900 3600 3300 3000 2700 2400 2100 Tie on - 90.03 Inc, 10875.00 Md, 8770.80 Tvd, 2193.84 Vs Kick off Point 11-38bhs 11-$Sehs 869.53 N, 3498.08 Tie on - 8770.80 Tvd. Kick off Poi~3/'i'1_38bh ,. ... ... /. ., ... ?' ,.. ,/' 11-38ihs 4 J" 11 -~38iihs · 7 T.D. & End of Build - 8815.00 Tvd, 1230.50 S, 5410.00 W 11-38ihs 11-38iihs 45 6 7 ll-$Sehs T.D. & End of Build/Turn - 90.96 Inc, 14119.93 Md, 8815.00 Tvd, 4997.81 Vs 1200 900 6OO 300 o Z~- 30O 600 -,. I 900 V 1200 1500 1800 2100 I I I I i I I I I I i i I I i I i i I I I i I I i i I I i I i i I i i i i i i i i i i I 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 Z~200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 Vertical Section (feet) -> Azimuth 251.45 with reference 0.00 N, 0.00 E from 11-58 Company: Well: Calculation Method: Vertical Sect. Plane: Vertical Sect. Plane: Measured Depth from: True Vertical Depth: Proposal Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN ARCO Alaska~ lnc. I 1-38A Miuimum Curvature 231.450 TRUE 0.000 G RID RKB Sca level Rig: CDR-Naborsffransocean Field: Prudhoe Bay~ Alaska Mag. Declination: 28.070 Grid Correction: 1.580 Total Correction: 26.490 RKB Height: 64.22 869.53 721.58 721). 17 703.84 685.85 667.61 649.13 647.(94 630.41 611.45 3498.08 3484.65 3211.06 Coords. - ASP N(+)/S{,-) i£(+)/W(-) Lat. (Y) Del}. (X) 5952330.29 703936.$5 Coords.-GRID N(+)/S(-) Lat.(Y) 772.69 761.90 3507.42 5952319,50 703923.72 5952314.36 703917.59 756.76 3501.29 5952313.07 703916.06 755.47 3499.76 703898.56 5952298,15 5952281,71 703879.72 5952278.73 703876.35 5952265.03 703861.10 5952248.09 703842.72 5952246.72 7{i)3841.26 5952230.89 703824.59 5952213.42 703806.71 5952195.70 703789.08 5952177.73 70377t.71 5952176.28 703770.33 5952159.51 703754.60 5952141.05 703737.75 5952122.35 7{)3721. 5952103.41 703704.86 5952101.8~, 7(.)3703.57 59520~4.23 70308~.g2 5952064.83 703(~73.07 703057.59 5952045,21 740.55 3482.26 3463.42 3460.O5 3444.80 3426.42 3424.96 507.23 487.61 467.76 3226.10 592.25 3195.33 5952025.30 703042.40 3194.08 5952023.70 703041.19 466.16 3224.89 5952005.30 703627.49 447.70 3211.19 5951985.(12 703612.~8 427.42 3196.58 3182.26 5951964.54 703598.56 5951943.85 703584.53 5951942.19 703583.42 5951922.96 703570.81 5951901.88 59518g[).61 703544.26 7O3531.45 5951859,15 703530.44 491.32 472.45 451.75 430.84 4{)9.75 301.55 299.82 279.91 3102.66 4(}8.05 5951857.42 388.46 3066.76 5951837.51 7035 l g.90 3053.97 5951815.69 703506.77 258.09 3090.47 5951793.69 707,494.9t) 236.09 3078.60 Job No: AFE No: API No: Job Start Date: Job End Date: BHi Rep: Comments Tie in Position Kick off Point 3 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASI' Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle Az{. Az{. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Comments (deg) (deg) (de~) (it) Lat. (Y) Dep. (X) Lat. (Y) Dcp. (X) Lat. (Y) Dep. (X) (°/100ft) (from,TIP) (°/100ft) (°/100ft) 11598.00 88.56 208.70 207.12 8785.46 323.49 3029.34 5951771.53 703,183.34 213.93 3067.04 3.30 -90.00 2900.71 -0.04 -3.32 11600.00 88.55 208.63 207.05 8785.51 321.74 3028.38 5951769.75 7013482.43 212.15 3066.13 3.3{.i -90.00 2902.55 -0.50 -3.50 11623.00 88.54 207.88 206.30 8786.09 3(11.48 3017.5{) 5951749.21 703472. I I 191.61 3055.81 3.3{) -9(I.0{) 2923.69 -0.04 -3.26 11648.00 88.53 207.05 205.47 8786.73 279.31 3005.97 5951726.72 703461.2{) 169.12 3044.90 3.30 -90.{~) 2946.52 -0.04 -3.32 11673.00 88.52 206.22 204.64 8787.37 256.97 2994.77 5951704.08 703450.62 146.48 3034.32 3.30 -90.00 2969.20 -0.04 -3:32 11698.00 88.50 205.40 203.82 8788.02 234.47 2983.88 595168 t.29 703440.36 123.69 3024.06 3.30 -90.00 2991.74 -0.08 -3.28 11700.00 88.50 205.33 203.75 8788.08 232.66 2983.03 5951679.46 703439.55 121.86 3023.25 3.3{) -911.00 2993.53 0.00 -3.50 11723.00 88.49 204.57 202.99 8788.68 211.82 2973.33 5951658.36 703430.43 100.76 31.114.13 3.30 -90.0{.t 3014.11 -0.{54 -3.30 11748.00 88.48 203.75 202.17 8789.34 189.02 2963.10 5951635.28 703420.84 77.68 3004.54 3.30 -90.00 3036.32 -0.04 -3.28 11773.00 88.47 202.92 201.34 8790.01 166.07 2953.20 5951612.1.17 703411.58 54.47 2995.28 3.30 -90.00 3058.36 -0.04 -3.32 11798.00 88.46 2{'12.10 2(10.52 8790.68 142.98 2943.63 5951588.73 71.13402.65 31.13 2986.35 3.30 -90.00 3080.23 -0.04 -3.28 11800.00 88.46 202.03 200.45 8790.73 141.13 2942.88 5951586.86 703401.95 29.26 2985.65 3.30 -90.00 3081.97 0.00 -3.50 11823.00 88.45 201.27 199.69 8791.35 119.76 2934.40 5951505.26 703394.06 7.66 2977.76 3.30 -90.00 3101.92 -0.04 -3.30 11848.00 88.43 200.45 198.87 8792.03 96.41 2925.50 5951541.67 7{13385.81 - 15.93 2969.51 3.311 -90.00 3123.44 -0.08 -3.28 11873.00 88.42 199.62 198.04 8792.72 72.93 2916.94 5951517,97 703377.90 -39.63 2961.60 3.30 -9{).{){)3144.76 -0.04 -3.32 11898.00 88.41 198.80 197.22 8793.41 49.33 2908.72 5951494.15 703370.33 -63.45 2954.1.13 3.3(I -90.00 3165.91.1 -0.04 -3.28 11900.00 88.41 198.73 197.15 8793.47 47.44 2908.07 5951,192.24. 703369.74 -65.36 2953.44 3.30 -90.00 3167.59 0.00 -3.50 11923.00 88.40 197.97 196.39 8794.11 25.62 2900.84 5951471.1.23' 703363.1{} -87.37 2946.80 3.30 -90.00~ 3186.85 -0.04 -3.30 11948.00 88.39 197.15 195.57 8794.81 1.79 2893.30 5951446.21/ 703356.22 - 111.40 2939.92 3.30 -90.(t{) 32{)7.59 -0.1114 -3.28 11973.00 88.39 196.32 194.74 8795.51 -22.14 2886.1{I 5951422.08 703349.69 -135.52 2933.39 3.3{) -90.(10 3228.13 0.00 -3.32 11998.00 88.38 195.50 193.92 8796.21 -,16.17 2879.25 5951397.87 703343.50 - 159.73 2927.20 3.30 -90.00 3248.47 -0.04 -3.28 12000.00 88.38 195.43 193.851 8796.27 -48.10 2878.72 5951395.93 703343.03 - 161.67 2926.73 3.30 -90.00 3250.08 0.00 -3.50: 12023.00 88.37 194.67 193.{.19 8796.92 -70.30 2872.75 5951373.57 703337.67 - 184.03 2921.37 3.3('} -90.0(t 3268.59 -0.04' -3.30 12048.00~ 88.36 193.85 192.27 8797.63 -94.52 2866.59 5951349.19 703332.18 -208.41 2915.88 3.30 -90.00 3288.50 -0.04 -3.28 12073.00 88.35 193.02 191.44 8798.35 -118.83 2860.79 5951324.74 703327.05 -232.86 2910.75 3.30 -90.00 3308.19 -0.04 -3.32 12098.00 88.35 192.20 190.62 8799.07 - 143.21 2855.33 5951300.21 703322.27 -257.39 2905.97 3.3{.) -90.00 3327.65 0.00 -3.28 12100.00 88.34 192.13 190.55 8799.13 - 145.17 2854.91 5951298.24 7(33321.9{3 -259.36 2905.60 3.30 -90.00 3329.20 -0.50 -3.50 12123.00 88.34 191.37 189.79 8799.80 - 167.68 2850.23 5951275.61 7(13317.84 -281.99 2901.54 3.3{) -90.{X'} 3346.89 0.00 -3.30 12148.00 88.33 190.55 188.97 8800.52 - 192.21 2845.48 5951250.96 703313.77 -306.64 2897.47 3.30 -90.00 3365.89 -0.04 -3.28 12173.00 88.33 189.72 188.14 8801.25 -216.81 2841.08 5951226.25 703310.05 -331.35 2893.75 3.30 -90.00 3384.66 0.00 -3.32 12198.00 88.32 188.90 187.32 8801.98 -241.47 2837.04 5951201.49 71.13306.69 -356.11 2890.39 3.30 -90.00 3403.19 -0.04 -3.28 12200.00 88.32 188.83 187.25 8802.04 -243.45 2836.73 5951199.5o 709306.44 -358.10 2890.14 3.30 -90.00 34(14.66 0.00 -3.50 12223.00 88.31 188.07 186.49 8802.72 -266.19 2833.35 5951176.68 703303.(19 -380.92 2887.39 3.30 -90.00 3421.47 -0.04 -3.30 12248.00 88.31 187.25 185.67 8803.45 -290.95 2830.02 5951151.83 703301.04 -405.77 2884.74 3.30 -90.00 3439.51 0.00 -3.28 12273.00 88.30 186.42 184.84 8804.19' -315.76 2827.{15 5951 ~20.95 7o3298.75 -430.65 2882.45 3.23{i) -9{i.00 3457.30 -0.{)4 -3.32 12298.00 88.30 185.59 184.01 8804.94 -340.61 2824.43 5951102.03 70329(i.82 -455.57 2880.52 3.30 -90.1.10'3474.83 0.00 -3.32 12300.00 88.30 185.53 183.95 8804.99 -342.60 2824.24 59511 {10.04 7{13290.(~9 -457.56 2880.39 3.30 -90.00 3476.22 0.00 -3.00 12323.00 88.29 184.77 183.19 8805.68 -365.50 2822.17 5951(177.09~ 703295.25 -480.51 2878.95 3.30 -90.00 3492.1 -0.04 12348.00 88.29 183.94 182.36 8806.43 -390.42 2820.28 5951052.13 71113294.04 -505.47 2877.74 3.30 -90.00 3509.12 0.00 -3.32 12373.00 88.29 183.12 181.54 8807.17 -415.36 2818.74 5951t~27.16 703293.19 -530.44 2876.89 3.30 -90.{t0 3525.87 0.00 -3.28: 12398.00 88.28 182.29 180.71 8807.92 -440.32 2817.56 59510{)2.17 70'3292 7{~ -555.43 2876.40 3.30 -90.00 3542.34 -0.04~ -3.32 12400.00 88.28 182.23 180.65 8807.98 -442.32 2817.48 59510[10.18 703292.68 -557.42 2876.38 3.30 -90.00 3543.65 0.00 -3.00 12423.00 88.28 181.47 179.89 8808.67 -405.29 2816.74 5950977.19 7{.13292.57 -580.41 2876.27 3.30 -9U.UO 3558.55 0.00 -3.30 12448.00, 88.28 180.64 179.06 8809.42 -490.28 2816.28 5950952.20 703292.80 -605.40 2876.50 3.30 -90. bXl 3574.48 0.00 -3.32 12467.74 88.28 179.99 178.41 8810.0 -510.01 2816.17 5950932.47 703293.24 -625.13 2876.94 3.30 179.00 3586.86 0.00 -3.29 4 12473.00 87.86 180.00 178.42 8810.19 -515.27 2816.17 5950927.22 703293.38 -630.38 2877.08 8.00 179.00 3590.14 -7.98 0.19 12478.32 87.43 180.0O 178.42 8810.4 -520.58 2816.17 595{)921.90 703293.53 -635.70 2877.23 8.00 87.00 3593.45 -8.08 0.00 5 12498.00 87.49 181.57 179.99 8811.28 -540.24 2815.90 5950902.25 703293.8{} -655.35 2877.50 8.00 87.00 3605.91 0.30 7.98 12500.00 87.50 181.73 180.15 8811.37 -542.24 2815.84 59509o0.25 703293.8o -657.35 2877.50 8.00 87.00 3607.20 0.50 8.00 12523.00 87.57 183.57 181.99 8812.36~ -505.19 2814.78 5950877.27 703293.37 -680.33 2877.07 8.00 87.00 3622.34 0.30 8.00 12548.00 87.66! 185.57 183.99 8813.40 -590.09 2812.79 5950852.33 703292.07. -705.27 2875.77 8.00 87.{~1 3639.4 {}.36' 8.00 12573.00 87.75 187.57 185.99 8814.40 -614.90 2809.93 5950827.45 703289.89 -730.15 2873.59 8.{')(} 87.00 3657.1 0.36 8.(~) 12598.00 87.84 189.57 187.99 8815.36 -639.60 2806.21 5950802.65 703286.85 -754.95 2870.55 8.00 87.00 3675.42 0.36 8.00 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Comments (deg) (deg) (de~) (ft) Lat. (Y) Del). (X) Lat. (Y) l)ep. (X) Lat. (Y) Dep. (X) (°/100ft) , (from TIP) (°/100ft) (°/100ft) 12600.00 87.85 189.73 188.15 8815.44 -641.57 2805.88 5950800.67 703286.57 -756.93 2870.27 8.00 87.00 3676.91 0.50 8.0(1 12623.00 87.93 191.57 189.99 8816.28 -664.16 2801.63 5950777.98 703282.95 -779.62 2866.65 8.00 87.00 3694.31 0.35 8.00 12648.00 88.03 193.57 191.99 8817.16 -688.55 2796.19 595{~753.45 703278.19 -804.15 2861.89 8.0(} 87.00, 3713.76 0.40 12673.00 88.13 195.57 193.99 8818.00 -712.73 2789.91 5950729.11 7(B272.57 -828.49 2856.27 8.00 87.00 3733.74 0.40 12698.00 88.23 197.57 195.99 8818.80 -736.68 2782.78 595{,}7{.14,97 703266.1t -852.63 2849.81 8.00 87.00 3754.24 0.40 8.00 12700.00 88.24 197.73 196.15 8818.86 -738.58 2782.17 5950703.05 7{`)3265.56 -854.55 2849.26 8.00 87.00 3755.90 0.50 8.00 12723.00 88.33 199.57 197.99 8819.55 -76{`}.36 2774.82 595()681.07 703258.81 -876.53 2842.51 8.(}{`} 87.{)0 3775.22 0.39 8.0(1 12748.00 88.43 201.56 199.98 8820.25 -783.76 2766.{)4 595{)657.45 703250.68 -900.15 2834.38 8.00 86.00 3796.67 0.40 7.96 12773.00 88.54 203.56 201.98 8820.91 -806.84 2756.46 5950634. I 1 703241.73 -923.49 2825.43 8.00 86.00 3818.55 O.44 8.00 12798.00 88.65 205.56 203.98 8821.53 -829.57 2746.07 595{`)611.10 703231.97 -946.50 2815.67 8.00 86.00 3840.84 0.44 8.00 12800.00 88.66 205.72 204.14 8821.57 -831.37 2745.20 595{.1609,28 703231.16 -948.32 2814.86 8.(10 86.00 3842,64 0.50 8.0{'1 12823.00 88.76 2(}7.56 205.98 8822.09 -851.92 2734.89 5950588.45 7{)3221.42 -969.15 2805.12 8.00 86.(}0 3863,51 0.43 8.00 12848.00 88.87 209.55 207.97 8822.61 -873.87 2722.95 5950566.18 703210.(tU -991.42 2793.78 8.00 86.00 3886,53 0.44 7.96 12873.00 88.98 211.55 209.97 8823.08 -895.40 271 {`}.24 5950544.31 7{`)3197.9~ - 1013.29 2781.68 8.(10 86.00 3909.88 0.44 8.00 12898.00 89.10 213.55, 211.97 8823.50 -916.47 2696.79 5950522.88 703185.1 I - 1034.72 2768.81 8.00 86.00 3933,53 0.48 12900.00 89.11 213.71 212.13 8823.53 -918.13 2695.69 595()521.1~ 703184.05 -1036.42 2767.75 8.0(} 86.00 3935.44 0.50 8.00 12923.00 89.21 215.55 213.97 8823.87 -937.06 2682.62 5950501.91 703171.51 - 1055.69 2755.21 8.00 86.00 3957.45 0.43' 8.00 12948.00 89.33 217.54 215.96 8824.18 -957.14 2667.73 595{,/481.42 703157.19 - 1076.18 2740.89 8.00 86.00 3981.60 0.48~ 7.96 12973.00 89.45 219.54 217.96 8824.45 -976,69 2652.16 595{.)461.45 703142.16 - 1096.15 2725.86 8.00 86.(}0 4{)05.97 (}.48 8.1,10 12998.00 89.56 221.54 219.96 8824.67 -995.69 2635.91 5950442.01 703126.44 - 1115.59 2710.14 8.00 86.00 4030.51 0.44 8.0{) 13000.00 89.57 221.70 220.12 8824.68 -997.18 2634.58 595{)44(}.48 703125.15 -1117.12 2708.85 8.00 86.00 4032.49 0.50 8.00 13023.00 89.68 223,53 221.95 8824.83 -1014.11 2619.01 5950423.13 70311{,i.05 -1134.47 2693.75 8.00 86.00 4055.21 0.48 7,96 13048.00 89.80 225.53 223.95 8824.95 -1(131.93 2601.48 595{i)4{14.83 703093.02 -1152.77 2676.72 8.(}0 86.0(} 4080.03 0.48 8,00 13073.00 89.92 227.52 225.94 8825.01 -1{,)49.13 2583.34 5950387.14 703075.36 -1170.46 2659.06 8.00 86.0{,i 4104.93 0.48 7,96 13089.32 90.00 228.83 227.25 8825.02 -1060.01 2571.18 5950375.92 703063.51~ -1181.68 2647.20 8.00 89.00 4121.23' 0.49 8,03 6 13098.00 9(I.01 229.52 227.94 8825.02 - 1065.69 2564.61 5950370.07 7{.}305'7.09 - 1187.53 2640.79 8.00 89.00 4129.90 0.12 7,95 13100.00 90.01 229.68 228.10 8825.02 - 1(166.98 2563.09 5950368.73 703055.61 - 1188.87 2639.31 8.00 89.00 4131.9{,I 0.00 8,00 13123.00 90.04 231.52 229.94 8825.01 - 1 (}81,58 2545.31 5950353.65 703038.24 - 12{`)3.95 2621.94 8.00 89.{)0 4154.90 0.13 8,00 13148.00 90.08 233.52 231.94 8824.98 - 1096.79 2525.48 5950337.9(I 703018.83 - 1219.70 2602.53 8.00 89.00 4179.89~ 0.16 8,00 13173.00 90.11 235.52 233.94 8824.94 -1111,30 2505.12 5950322.83 702998.88 -1234.77 2582.58 8.00 89.00 4204.85 0.12 8.00 13198.00 90.14 237.52 235.94 8824.88 - I 125,09 2484.27 5950308.47 7021978,42 - 1249.13 2562.12 8.00 89.00 4229.75 0.12 8.{,10 13200.00 90.15 237.68 236.10 8824.88 - 1126,16 2482.58 595{)307,36 702976.76 - 1250.24 2560.46 8.00 89.00 4231.74 0.50 8.0{) 13223.00 90.18, 239.52 237.94 8824.81 -1138.15 2462.95 595~,}294.84 702957.47 - 1262.76 2541.17 8.00 89.00 4254.56 0.13 8.00 13248.00 90.21 241.52 239.94 8824.73 - I 15{`},45 2441.19 59502~ 1.94 702936.06 - 1275.66 2519.76 8.00 89.011 4279.25 0.12 8.00 13273.00 90.24~ 243.52 241.94 8824.63 - I 161.98 2419.01 59502(>9,~0 702914.211 - 1287.80 2497.90 8.0(I 89.(10 4303.78 0.12 8.00 [ .,.13298.00 90.28 245.52 243.94 8824.52 -1172.74 2396.44 5950258.42 702891.94 -1299.18 2475.64 8.00 89.(}0 4328.13 0.16 8.0{) .' 13300.00 90.28 245.68 244.10 8824.51: -1173.56 2394.62 5951}257.55 702890.14 -1300.05 2473.84 8.00 89.00 4330.07 0.00 8.00 ,, 13323.00 90.31 247.52 245.94 8824.39 - 1182.70 2373.51 5950247.83 702869.30 - 1309.77 2453.00 8.00 89.00 4352.27 0.13 8.00 13348.00 90.34 249.52 247.94 8824.25 - I 191.85 2350.25 5950238.{N: 702846.30 - 1319.56 2430.00 8.{`)0 89.00 4376.17 (I. 12 8.0{1 13373.00 90.37 251.52 249.94 8824.09 - 1200.19 2326.68 5950229.06 702~22.97' - 1328.54 2406.67 8.00' 89.0(} 4399.79 0.12 8.{,10 ., 13398.00 90.40 253.52 251.94 8823.92 -1207.70 2302.84 5950220.90 702799.34 -1336.70 2383.04 8.00 89.00 4423.12 0.12 8.00 13400.00 90.41 253.68 252.10 8823.91 - 1208.26 230D.92 595{,)2211.28 71~2797.44 - 1337.32 2381.14 8.00 89.00 4424.97 0.50 8.0ti 13423.00 90.43 255.52 253.94' 8823.74 - 1214.37 2278.75 5951~213,5t~ 702775.44 - 1344.04 2359.14 8.0o 89.00 4446.12 0.09 8.00~ 13448.00 90.46 257.52 255.94 8823.55 -1220.20 2254.44 5951~21~7.07 702751.30 -1350.53 2335.00 8.00 89.00 4468.76 0.12 8.(10 13473.00 90.49 259.52 257.94 8823.34 - 1225.17 2229.94 595~}2t~1.42 71~2726.95 - 1356,18 2310.65 8.00 89.00 4491.02 0.12' 8.00 13479.02 90.50 260.0{.) 258.42 8823.29 - 1226.24 2224.02 5951)21}0.19 7{)2721.06 - 1357,41 2304.76 8.00 88.00 4496.32 0.17 7.97 7 13498.00 90.5 260.57 258.99 8823.12 - 1229.44 2205.31 595(3196.47 702702.45 - 1361,13 2286.15 3.00 88.00 4512.95 0.05 3.0{) 13500.00 90.52 260.63 259.05 8823.10 - 1229.77 22(}3.34 595~ 196.09 7{)270~.48 - 1361,51 2284.18 3.00 88.00 4514.701 0.50 3.{10 13523.00 90.53 261.32 259.74 8822.89 - 1233.38 2180.62 5950191.85 702677.88 - 1365.75 2261.58 3.00 88.00 4534.71 0.04 3.00 13548.00 90.55 262.07 260.49 8822.66 -1236.99 2155.89 5950187.56 702053.25 -1370.04 2236.95 3.00 88.0t), 4556.30 0.08 3.00 13573.00 90.57 262.82 261.24 8822.4 - 124~1.28 2131. I I 5950183.50 7{~2628.57 - 1374.01 2212.27 3.t}t) 88.00! 4577.73 0.{`)8 3.0{) 13598.00 90.59 263.57 261.99 8822.16 - 12-13.24 2106.28 5~951/179.95 7{~261)3.84 - 1377.65 2187.54 3.(1[1 88.1,~{} 4598.99 0.08 3.0{) 13600.00 90.59 263.63 262.05 8822.14 - 1243.46 2104.30 595(}179.67 7026~11.~6 - 1377.93 2185.56 3.00 88.00 46t}0.68 0.00 3.00 Meas. Incl. TRUE GRID Subsea Corn-ds. - TRUE Com'ds. - ASI' Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle Azi. Azi. TV1) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Comments (deg) (deg) (deg) (ft) Lat. (Y) Dep. (X) Lat. (Y) Dcp. (X) Lat. (Y) Dep. (X) (°/100ft) (from TIP) (°/100ft) (°/100t't) 13623.00 90.61 264.32 262.74 8821.90 - 1245.88 2081.43 5950176.63 7(.)2579.()6 - 1380.97 2162.76 3.00 88.00 4620.08 0.09 3.00 13648.001 90.63 265.07 '" 263.49 8821.63 -1248.19 21.)56.53 59501T3.63 7(..'12554.24 -1383.97 2137.94 3.00 88.00 4640.98 0.08 3.00 . 13673.00 90.65 265.82 264.24 8821.35 -1250.17 2031.61 5950170.96 702529.39 -1386.64 2113.09 3.00 88.1,)0 4661.71 0.08... 3.00 13698.00 90.67 266.57 264.99 8821.06 - 1251.83 2006.67 5950168.61 71.~2504.511 -1388.99 2088.20 3.00 88.0(') 4682.25 0.08 3.00 13700.00 90.67 266.63 265.05 8821.04 -1251.95 2004.68 5950168.44 70251.)2.51 -1389.16 2086.21 3.00 88.00 4683.88 0.00 3.00 13723.00 90.69 267.32 265.74 8820.76 -1253.16 1981.71 5951,)166.5!:) 711)2479.58 -1391.01 2063.28 3.00 88.00 4702.60 0.09 3.00 13748.00 90.70 268.07 266.49 8820.46 -1254.17 1956.73 5950164.90 711)2454.64 -1392.70 2038.34 3.00 88.01.) 4722.76 0.04 3.00 13773.00 90.72 268.82 267.24 8820.15 - 1254.85 1931.74 5950163.53 702429.68 - 1394.07 2013.38 3.00 88.00 4742.73 0.08 3.00 13798.00 90.74 269.57 267.99 8819.83 -1255.20 1906.75 5951,)11!,2.49 702404.71 -1395.11 1988.41 3.00 88.00 4762.49 0.08 3.00 13800.00 90.74 269.63 268.05 8819.81 - 1255.21 1904.75 595[)162.42 70241,)2.71 - 1395.18 1986.41 3.00 88.1.)0 4764.07 0.00 3.00 13823.00 90.76 270.32 268.74 8819.50 -1255.22 1881.75 5950161.78 702379.72 -1395.82 1963.42 3.00 88.00 4782.06 (').(')9 3.00 13848.00 90.78 271.07 269.49 8819.17 -1254.92 1856.75 5950161.39 702354.72 -1396.21 1938.42 3.00 88.()0 4801.42 {').{')8 3.00 ,. 13873.00 90.79 271.82 270.24 8818.83 -1254.29 1831.76 5951)11,~1.33 702329.73 -1396.27 1913.43 3.00 88.00 4820.57 0.04 3.00 13898.00 90.81 272.57 270.99 8818.48 -1253.33 1806.79 5951~161.60 71,)231,)4.73 -1396.00 1888.43 3.1.)1.) 88.0(3 4839.50 0.1.)8 3.00 13900.00 90.81 272.63 271.05 8818.45 - 1252>,.24 181)4.79 5950161 .(>4 71`)2302.73 - 1395.96 1886.43 3.00 88.()1`)4841.01 0.(.)0 3.00 /~r 13923.00 90.83 273.32 271.74 8818.12 - 1252.05 1781.82 5951) 1 (,;2.21.i 7{}227~9.74 - 1395.40 1863.44 3.00 88.00 4858.23 0.09 3.00 ,. 13948.00 90.85 274.07 272.49 8817.75 -1250.44 1756.88 5951,1163.12 702254.76 -1394.48 1838.46 3.00 88.00 4876.73 0.08 3.00 13973.00 90.86 274.82 273.24 8817.38 -1248.50 1731.95 5950164.37 702229.811 -1393.23 1813.50 3.00 88.00 4895.01 0.04 3.00 -- 13998.00 90.88 275.57 273.99 8817.01,} -1246.24 1707.06 59511165.95 702204.85 -1391.65 1788.55 3.{'11,1 88.00 4913.07 0.{}8 3.00 14000.00 90.88 275.63 274.05 8816.97 -1246.04 1705.07 5950166.{}9 70221~2.85 -1391.51 1786.55 3.0{} 88.00! 4914.50 0.00 3.00 14023.00 90.90 276.32 274.74 8816.61 -1243.65 1682.20 59511167.85 71)2179.92 -1389.75 1763.62 3.00 88.00 4930.90 0.09 3.00 14048.00 90.92 2'17.07 275.49 8816.22 - 1240.73 1657.37 5951,)171.}.08 71.)2155.03 - 1387.52 1738.73 3.00 88.01.) 4948.50 0.08 3.00 3.1/4 14073.00 91,}.93 277.82>, 276.25 8815.81 - 1237.49 1632.59 5951.)172.63 71112130.16 - 1384.97 1713.86 3.00 88.11)11) 4965.86 (}.1')4 3.(.)t.) 14098.00 90.95 278.58 277.00 8815.40 -1233.92 1607.84 5951)175.52 702105.33 -1382.08 1689.03 3.00 88.00 4982.99 0.08 · 14100.00 90.95 278.64 277.1.)6 8815.37! -1233.62 161.)5.87 5951.)175.71~ 7102102~.:t51 -1381.84 1687.05 3.001 88.00 4984.35 0.001 3.00! 14119.93 90.96 279.23 277.65 8815.1.)4 -1230.53 1586.18 5~.)511178.31 7021}83.58 -1379.29 1667.28 3.00 1`).00 4997.8 0.1.')5 2.96 T.D. C 1- Drilling Wellhead ue[a~ - L~(~ ~ ]~- O'~ I~CT,njectorHead ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I "'- 7" Riser Methanol Injection ConnectOtis 7" WLA Quick~ Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual ~ Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold ) Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Hydraulic over Electric ~ 7-1/16" ID with Pipe/Slip Rams Manual Master Valve O.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8"Annulus 4-1/2" Production Tubing 4-1/2" Camco Bal-o SSSV Nipple @2195' 4-1/2"KBG GLM's 7" S-3 Pckr. @ 9576' 4-1/2" HES X Nipple @ 96OO' 4-1/2" TT @ 9623' 10758' MD TIW SS Hgr. 0856' MD 7" Liner shoe DS 11-38A PROPOSED CT ST AND COMPLETION TD @ - 14120' Initial perforations 2-7/8" Cmt'd liner 3.75" hole Window cut in MLAS sub in 4.5" liner and cmt in 6" annulus @ -10890' 13148' MD End of 4-1/2" liner & 6" OH 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 4-1/2" Slotted Liner shoe at 13148' Sqz'd 4-1/2" Production Tubing 4-1/2" Camco Bal-o SSSV Nipple @2195' 4-1/2"KBG GLM's 7" S-3 Pckr. @ 9576' 4-1/2" HES X Nipple @ 9600' 4-1/2" TT @ 9623' DS 11-38 PROPOSED CT Cement Plugback 4-1/2" TIW MLAS Composite sub from 10887 - 10924 TIW NoGO sub 3.010" ID @ 10993' RECLiVED ,~chorage 10758' MD TIW SS Hgr. 0856' MD 7" Liner shoe 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 13148' MD End of 4-112" liner &6' OH 4-1/2" Slotted Liner shoe at 13148' Sqz'd '4-1/2" Production Tubing 4-1/2" Camco Bal-o SSSV Nipple @2195' 4-1/2"KBG GLM's 7" S-3 Pckr, @ 9576' 4-1/2" HES X Nipple @ 9600' 4-1/2" TT @ 10758' MD TIW SS Hgr. 9623' MD 7" Liner shoe DS 11-38A PROPOSED CT ST AND COMPLETION TD @ ~ 14120' Initial perforations 2-7/8" Cmt'd liner 3.75" hole Window cut in MLAS sub in 4.5" liner and cmt in 6" annulus @ -10890' 13148' MD End of 4-1/2" liner & 6" OH 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 4-1/2" Slotted Liner shoe at 13148' Sqz'd DS 11-38A '- f CT Drilling and Completion Intended Procedure Objective: Directionally drill N3000', 3-3/4" horizontal hole from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Cement squeeze the current slotted liner and plugback the existing completion to N 10800' md. Mill window in 4-1/2" liner at ~10890' md. Drill 10' of formation and perform Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to -91 o. Directionally drill 3-3/4" x 3000' horizontal well to access Lower Romeo reserves. Run and cement 2-7/8" liner to TD. Perforate selected intervals. · Place well on production. RECeiVeD A~ka Oil & ~as Cons. Con]mission Anchorage October 14, 1998 8O0O 8200 8400 8600 8800 @000 9200 9400 ARCO Alaska, Inc. Structure : O.S. 11 Well · 11-38 ............. ?..t.e.J..d....!....P..r...u..d...h...°..?.....B.~..Y. .............. .L..°..~S.t!..°...q..."....~.°..~t..h.....S.!..°...P..e.:.....A!?.~..k.S.~, <- West (feet) 6900 6600 6500 6000 5700 5400 5100 4800 4500 4200 3900 3600 3500 3000 2700 24-00 2100 11-$8ehs Tie on - 8770.80 Tvd, 869.55 N. 54-98,08 W ./~ ...... . Kick off Point,.~x"~ 1-58bhs ...... " ..,/,,..,/ 11-38ih,~ 7 T.D. & End of Build - 8815.00 Tvd, 12,50.50 S, 5410.00 W 11-$8ehs Tie on - 90.05 Inc, 10875.00 Md, 8770.80 Tvd, 2195.84 Vs Kick off Point ............. ~..~ .......... 11 -`58ihs 11-58iihs 11-58bhs 5 6 7 T.B. & End of Build/Turn - 90.96 Inc, 14119.95 Md, 8815.00 Tvd, 4997.81 Vs 12OO 900 600 300 0 :D'- 500 600 I 9oo V 12OO 1600 1800 21 O0 i i i i i i i i i i i i ~ , i i i i i , i ~ i i i i i , i ~ ~ ~ ~ i i i i i i i i i i 2000 2200 2400 2600 2800 3000 3200 .5400 ,5600 3800 4000 4-200 4400 4600 4800 6000 5200 6400 5600 5800 6000 6200 Vertical Section (feet) -> Azimuth 231.45 with reference 0.00 N, 0.00 E from 11-38 C · Drilling vvellneaa L)e]:all Methanol Injection Otis 7" WLA Quick Connect '~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual J Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold Cutters or Combination CuttedBlinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Hydraulic over Electric j 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger 9-5/8" Annulus 13-3/8" Annulus 4-1/2" Production Tubing 4-1/2" Camco Bal-o SSSV Nipple @2195' 4-1/2"KBG GLM's DS 11-38A PROPOSED CT ST AND COMPLETION TD @ - 14120' Initial perforations 2-7/8" Cmt'd liner 3.75" hole 7" S-3 Pckr. @ 9576' 4-1/2" HES X Nipple @ 9600' 4-1/2" TT @ 9623' Window cut in MLAS sub in 4.5" liner and cmt in 6" annulus @ ~10890' II 10758' MD TIW SS Hgr. MD 7" Liner shoe 13148' MD End of 4-1/2" liner & 6" OH 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 4-1/2" Slotted Liner shoe at 13148' Sqz'd Ala,ska LAYOUT Company: Wcll: Calculation Method: Vertical Sect. Plane: Vertical Sect. Plane: Measured Depth from: True Vertical Depth: Proposal Calculations Coordinates pros4ded in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN ARCO Alaska, Inc. 11-38A Minimum Curvature 231.450 TRUE 0.000 GRID RKB Sea level Rig: Field: Mag. Declination: Grid Correction: Total Correction: RKB Height: CDR-Nabors/Tra nsocean Prudhoe Bay, Alaska 28.070 l~q80 26.490 64.22 Coords. GRID Coords. TRUE 854.13 852.89 838.45 822.54 819.65 806.39 789.96 788.63 773.26 756.30 739.07 Coords.- ASP N(+)/S(-) E(+)/W(-) Lat. (Y) 5952330.29 703936.85 5952319.50 703923.72 5952314.36 703917.59 5952313.07 703916.06 5952298.15 703898.56 5952281.71 703879.72 5952278.73 5952265.03 703861.10 5952248.09 703842.72 5952246.72 703841.26 689.12 595223(I.89 703824.59 673.29 5952213.42 703806.71 655.82 5952195.7(} 703789.08 638.10 3328.79 5952177.73 703771.71 620.13 3327.38 5952176.28 703770.33 618.68 3311.19 5952159,51 703754.60 601.91 3293.84 5952141.05 703737.75 583.45 3321.45 3276.75 5952122.35 703721.17 564.75 3304.87 5952103.41 703704.86 545.81 3288.56 5952101.88 703703.57 544.28 3287.27 5952084.23 703688.82 526.63 3272.52 5952064.83 703673.07 507.23 3256.77 5952045,21 71)3657.59 487.61 3241.29 430.84 409.75 408.05 388.46 366.98 345.32 5952025.36 5952023.76 5952005.30 5951985.02 5951964.54 5951943.85 5951942.19 5951922.96 5951901.88 5951880.61 5951859.15 5951857.42 5951837.51 5951815.69 5951793.69 703642.40 467.76 3226.10 703641.19 466.16 3224.89 703627.49 447.70 3211.19 703612.88 703598.56 703584.5~ 703583.42 703570.81 703557.38 703544.26 703531.45 703530.44 703518.96 703506.77 703494.90 3196.58 3182.26 3168.23 Job No: AFE No: API No: Job Start Date: Job End Date: BHI Rep: Comments Tie in Position Kick off Point 3 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Ve~ical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)P~V(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)P~7(-) Section Commen~ (de~) (deg) (de~) (R) Lat. (Y) Dep. (X) l.,at. (Y) l)ep. (X) Lat. (Y) DeF. (X) (°/100ft) (from TIP) (°/100ft) (°/1001i) 11598.00 88.56 208.70 207.12. 8785.46 323.49 3029.34 5951771.53 703483.34 213.93 3067.04 3.30 -90.00 2900.71 -0.04 -3.32 11600.00 88.55 208.63 207.05 8785.51 321.74 3028.38 5951769.75 703482.43 212.15 3066.13 3.30 -90.00 2902.55 -0.50 -3.50 11623.00 88.54 207.88 206.30 8786.09 301.48 3017.50 5951749.21 703472. li 191.61 3055.81 3.30 -90.00 2923.69 -0.04 -3.26 11648.00 88.53 207.05 205.47 8786.73 279.31 3005.97 5951726.72 703461.20 169.12 3044.90 3.30 -90.00 2946.52 -0.04 -3.32 11673.00 88.52 206.22 204.64 8787.37 256.97 2994.77 5951704.08 703450.62 146.48 3034.32 3.30 -90.00 2969.20 -0.04 -3.32 11698.00 88.50 205.40 203.82 8788.02 234.47 2983.88 5951681.29 703440.36 123.69 3024.06 3.30 -90.00 2991.74 -0.08 -3.28 11700.00 88.50 205.33 203.75 8788.08 232.66 2983.03 5951679.46 711)3439.55 121.86 3023.25 3.30 -90.00 2993.53 0.00 -3.50 11723.00 88.49 204.57 202.99 8788.68 211.82 2973.33 5951658.36 703430.43 100.76 3014.13 3.30 -90.00 3014.11 -0.04 -3.30 11748.00 88.48 203.75 202.17 8789.34 189.02 2963.10 5951635.28 703420.84 77.68 3004.54 3.30 -90.00 3036.32 -0.04 -3.28 11773.00 88.47 202.92 201.34 8790.01 166.07 2953.20 5951612.07 703411.58 54.47 2995.28 3.30 -90.00 3058.36 -0.04 -3.32 11798.00 88.46 202.10 200.52 8790.68 142.98 2943.63 5951588.73 703402.65 31.13 2986.35 3.30 -90.00i 3080.23 -0.04 -3.28 11800.00 88.46 202.03 200.45 8790.73 141.13 2942.88 5951586.86 703401.95 29.26 2985.65 3.30 -90.00 3081.97 0.00 -3.50 11823.00 88.45 201.27 199.69 8791.35 119.76 2934.40 5951565.26 703394.06 7.66 2977.76 3.30 -90.00 3101.92 -0.04 -3.30 11848.00 88.43 200.45 198.87 8792.03 96.41 2925.50 5951541.67 703385.8 -15.93 2969.51 3.30 -90.00 3123.44 -0.08 -3.28 11873.00 88.42 199.62 198.04 8792.72 72.93 2916.94 5951517.97 703377.90 -39.63 2961.60 3.30 -90.00 3144.76 -0.04 -3.32 11898.00 88.41 198.80 197.22 8793.41 49.33 2908.72 5951494.15 703370.33 -63.45 2954.03 3.30 -90.00 3165.90 -0.04 -3.28 11900.00 88.41 198.73 197.15 8793.47 47.44 2908.07 5951492.24 703369.74 -65.36 2953.44 3.30 -90.00 3167.59 0.00 -3.50 11923.00 88.40 197.97 196.39 8794.11 25.62 2900.84 5951470.23 703363.10 -87.37 2946.80 3.30 -90.00 3186.85 -0.04 -3.3~ 11948.00 88.39 197.15 195.57 8794.81, 1.79 2893.30 5951446.20 7(13356.22 -111.40 2939.92 3.30 -90.00 3207.59 -0.04 -3.28 11973.00! 88.39 196.32 194.74 8795.51 -22.14 2886.10 5951422.08 703349.69 -135.52 2933.39 3.30 -90.00 3228.13 0.00 -3.32 11998.00 88.38 195.50 193.92 8796.21 -46.17 2879.25 5951397.87 703343.50 -159.73 2927.20 3.30 -90.00 3248.47 -0.04 -3.28 12000.00 88.38 195.43 193.85 8796.27 -48.10 2878.72 5951395.93 703343.03 -161.67 2926.73 3.30 -90.00 3250.08 0.00 -3.5~ 12023.00 88.37 194.67 193.09 8796.92 -70.30 2872.75 5951373.57 703337.67 -184.03 2921.37 3.30 -90.00 3268.59 -0.04 -3.3fl 12048.00 88.36 193.85 192.27 8797.63 -94.52 2866.59 5951349.19! 703332.18 -208.41 2915.88 3.30 -90.00 3288.50 -0.04 -3.28 12073.00 88.35 193.02 191.44 8798.35 -118.83 2860.79 5951324.74 703327.05 -232.86 2910.75 3.30 -90.00 3308.19 -0.04 -3.32 12098.00 88.35 192.20 190.62 8799.07 -143.21 2855.33 5951300.21 703322.27 -257.39 2905.97 3.30 -90.00 3327.65 0.00 -3.28 12100.00 88.34 192.13 190.55: 8799.13 -145.17 2854.91 5951298.24 703321.90 -259.36 2905.60 3.30 -90.00 3329.20 -0.50 -3.5fl 12123.00 88.34 191.37 189.79 8799.80 -167.68 2850.23 5951275.61 703317.84 -281.99 2901.54 3.30 -90.00 3346.89 0.00 -3.3fl 12148.00 88.33 190.55 188.97 8800.52 -192.21 2845.48 5951250.96 703313.77, -306.64 2897.47 3.30 -90.00 3365.89 -0.04 -3.28 12173.00 88.33 189.72 188.14 8801.25 -216.81 2841.08 5951226.25 703310.05 -331.35 2893.75 3.30 -90.00 3384.66 0.00 -3.32 12198.00 88.32 188.90 187.32 8801.98 -241.47 2837.04 595121)1.49 703306.69 -356.11 2890.39 3.30 -9~00 3403.19 -0.04 -3.28 12200.00 88.32 188.83 187.25 8802.04 -243.45 2836.73 5951199.50 703306.44 -358.10 2890.14 3.30 -90.00 3404.66 0.00 -3.5fl 12223.00 88.31 188.07 186.49 8802.72 -266.19 2833.35 5951176.68 703303.69 -380.92 2887.39 3.30 -90.00 3421.47 -0.04 -3.30' 12248.00 88.3l 187.25 185.67 8803.45 -290.95 2830.02 5951151.83 7033(}1.04 -405.77 2884.74 3.30 -90.00 3439.5 0.00 -3.28 12273.00 88.30 186.42 184.84 8804.19 -315.76 2827.05 5951126.95 703298.75 -430.65 2882.45 3.30 -90.00 3457.30 -0.04 -3.32 12298.00 88.30 :185.59 184.01 8804.94 -340.61 2824.43 5951102.03 703296.82 -455.57 2880.52 3.30 -90.00 3474.83 0.00 -3.32 ( 12300.00 88.30 185.53 183.95 8804.99 -342.60 2824.24 5951100.04 703296.69 -457.56 2880.39 3.30 -90.00 3476.22 0.00 -3.00 12323.00 88.29 184.77 183.19 8805.68 -365.50 2822.17 5951077.09 703295.25 -480.51 2878.95 3.30 -9~} 3492.1 -0.04 -3.30 12348.00 88.29 183.94 182.36 8806.43 -390.42 2820.28 59511)52.13 703294.04 -505.47 2877.74 3.30 -90.00 3509.12 0.00 -3.32 12373.00 88.29' 183.12 181.54 8807.17 -415.36 2818.74 5951027.16 703293.19 -530.44 2876.89 3.30 -90.00 3525.87 0.00 -3.28 12398.00 88.28 182.29 180.71 8807.92 -440.32 2817.56 5951002.17 703292.70 -555.43 2876.40 3.30 -90.00 3542.34 -0.04 -3.32 12400.00 88.28 182.23 180.65 8807.98 -442.32 2817.48 5951000.18 703292.68 -557.42 2876.38 3.30 -90.00 3543.65 0.00 -3.00 12423.00 88.28 181.47 179.89 8808.67 -465.29 2816.74 5950977.19 7(13292.57 -580.41 2876.27 3.30 -90.00 3558.55 0.00 -3.30 12448.00 88.28 180.(~ 179.06 8809.42 -490.28 2816.28 5950952.20 703292.80 -605.40 2876.50 3.30 -90.00 3574.48 0.00 -3.32 12467.74 88.28 179.99 178.41 8810.01 -510.01 2816.17 5950932.47 703293.24 -625.13 2876.94 3.30 179.00 3586.86 0.00 -3.29 4 12473.00 87.86 180.00 178.42 8810.19 -515.27 2816.17 5950927.22 703293.38 -630.38 2877.08 8.00 179.00 3590.14 -7.98 0.19 12478.32 87.43 180.00 178.42 8810.41 -520.58 2816.17 5950921.90 711}3293.53 -635.70 2877.23 8.00 87.00 3593.45 -8.08 0.00 5 12498.00 87.49 181.57 179.99 8811.28 -540.24 2815.90 5950902.25 703293.80 -655.35 2877.50 8.00 87.00 3605.91 0.30 7.98 12500.001 87.50 181.73 180.15 8811.37 -542.24 2815.84 5950900.25 703293.80 -657.35 2877.50 8.00 87.00 3607.20 0.50 8.00 12523.00 87.57 183.57 181.99 8812.36 -565.19 2814.78 5950877.27 703293.37 -680.33 2877.07 8.00 87.00 3622.34 0.30 8.00 12548.00 87.66 185.57 183.99 8813.40 -590.09 2812.79 5950852.33 703292.07 -705.27 2875.77 8.00 8TO0 3639.41 0.36 8.00 12573.00 87.75 187.57 185.99 8814.40 -614.90 2809.93 5950827.4.5 7(13289.89 -730.15 2873.59 8.00 87.00 3657.11 0.36 8.00 12598.00 87.84 189.57 187.99 8815.36 -639.60 2806.21 5950802.65 703286.85 -754.95 2870.55 8.00 87.00 3675.42 0.36 8.00 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Ve~ical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)~V(-) N(+)/S(-) E(+)fW(-) Section Commen~ (deE) (deg) (de~) (fl) Lat. (Y) Dep. (X) Lat. (Y) Dcp. (X) Lat. (Y) Dep. (X) (°/100ft) (from TIP) (°/100ft) (°/100t~) 12600.00 87.85 189.73 188.15 8815.44 -641.57 2805.88 5950800.67 703286.57 -756.93 2870.27 8.00 87.00 3676.91 0.50 8.00 12623.00 87.93 191.57 189.99 8816.28 -664.16 2801.63 5950777.98 703282.95 -779.62 2866.65 8.00 87.00 3694.31 0.35 8.00 12648.00 88.03 193.57 191.99 8817.16 -688.55 2796.19 5950753.45 703278.19 -804.15 2861.89 8.00 87.00 3713.76! 0.40 8.00 12673.00 88.13 195.57 193.99 8818.00 -712.73 2789.91 5950729.11 703272.57 -828.49 2856.27 8.00 87.00 3733.74 0.40 8.00 12698.00 88.23 197.57 195.99 8818.80 -736.68 2782.78 5950704.97 703266.11 -852.63 2849.81 8.00 87.00 3754.24 0.40 8.00 12700.00 88.24 197.73 196.15 8818.86 -738.58 2782.17 5950703.05 703265.56 -854.55 2849.26 8.00 87.00 3755.90 0.50 8.00 12723.00 88.33 199.57 197.99 8819.55 -760.36 2774.82 5950681.07 703258.81 -876.53 2842.51 8.00 87.00 3775.22 0.39 8.00 12748.00 88.43 201.56 199.98 8820.25 -783.76 2766.04 5950657.45 703250.68 -900.15 2834.38 8.00 86.00 3796.67 0.40 7.96 12773.00 88.54 203.56 201.98 8820.91 -806.84 2756.46 5950634.11 703241.73 -923.49 2825.43 8.00 86.00 3818.55 0.44 8.00 12798.00 88.65 205.56 203.98 8821.53 -829.57 2746.07 5950611.10 703231.97 -946.50 2815.67 8.00 86.00 3840.84 0.44 8.00 12800.00 88.66 205.72 204.14 8821.57 -831.37 2745.20 5950609,28 703231.16 -948.32 2814.86 8.00 86.00 3842.64 0.50 8.00 12823.00 88.76 207.56 205.98 8822.09 -851.92 2734.89 5950588.45 703221.42 -969.15 2805.12 8.00 86.00 3863.51 0.43 8.00 12848.00 88.87 209.55 207.97 8822.61 -873.87 2722.95 5950566.18 703210.08 -991.42 2793.78 8.00 86.00 3886.53 0.44 7.96 12873.00 88.98 211.55 209.97 8823.08 -895.40 2710.24 5950544.31 703197.98 -1013.29 2781.68 8.00 86.00 3909.88 0.44 8.00 12898.00 89.10 213.55 211.97 8823.50 -916.47 2696.79 5950522.88 703185.11 -1034.72 2768.81 8.00 86.00 3933.53 0.48 8.00 ,' 12900.00 89.11 213.71 212.13 8823.53 -918.13 2695.69 5950521.18 703184.05 -1036.42 2767.75 8.00 86.00 3935.44 0.50 8.00 12923.00 89.21 215.55 213.97 8823.87 -937.06 2682.62 5950501.91 703171.51 -1055.69 2755.21 8.00 86.00 3957.45 0.43 8.00 12948.00 89.33 217.54 215.96 8824.18 -957.14 2667.73 5950481.42 703157.19 -1076.18 2740.89 8.00 86.00 3981.60 0.48 7.96 12973.00 89.45: 219.54 217.96 8824.45 -976.69 2652.16 5950461.45 703142.16 -1096.15 2725.86 8.00 86.00 4005.97 0.48 8.00 12998.00 89.56 221.54 219.96 8824.67 -995.69 2635.91 5950442.01 703126.44 -1115.59 2710.14 8.00 86.00 4030.51 0.44 8.00 13000.00 89.57 221.70 220.12 8824.68 -997.18 2634.58 5950440.48 703125.15 -1117.12 2708.85 8.00 86.00 4032.49 0.50 8.00 13023.00 89.68 223.53 221.95 8824.83 -1014.11 2619.01 5950423.13 703110.05 -1134.47 2693.75 8.00 86.00 4055.21 0.48 7.96 13048.00 89.80 225.53 223.95 8824.95 -1031.93 2601.48 5950404.83 703093.02 -1152.77 2676.72 8.00 86.00 4080.03 0.48 8.00 13073.00 89.92 227.52 225.94 8825.01 -1049.13 2583.34 5950387.14 703075.36 -1170.46 2659.06 8.00 86.00 4104.93 0.48 7.96 13089.32: 90.00 228.83 227.25 8825.02 -1060.01 2571.18 5950375.92 703063.50 -1181.68 2647.20 8.00 89.00: 4121.23 0.49 8.03 6 13098.00 90.01 229.52 227.94 8825.02 -1065.69 2564.61 5950370.07 703057.09 -1187.53 2640.79 8.00 89.00 4129.90 0.12 7.95 13100.00 90.01 229.68 228.10 8825.02 -1066.98 2563.09 5950368.73 703055.61 -1188.87 2639.31 8.00 89.00 4131.90 0.00 8.00 13123.00 90.04 231.52 229.94 8825.01 -1081.58 2545.31 5950353.65 703038.24 -1203.95 2621.94 8.00 89.00 4154.90 0.13 8.00 13148.00 90.08 233.52 231.94 8824.98i -1096.79 2525.48 5950337.90 703018.83 -1219.70 2602.53 8.00 89.00 4179.89 0.16 8.00 13173.00 90.11 235.52 233.94 8824.94 -1111.30 2505.12 5950322.83 702998.88 -1234.77 2582.58 8.00 89.00 4204.85 0.12 8,00 13198.00 90.14 237.52 235.94 8824.88 -1125.09 2484.27 5950308.47 702978.42 -1249.13 2562.12 8.00 89.00 4229.75 0.12 8.00 13200.00 90.15 237.68 236.10 8824.88 -1126.16 2482.58 5950307.36 702976~76 -1250.24 2560.46 8.00 89.00 4231.74 0.50 8.00 13223.00 90.18 239.52 237.94 8824.81 -1138.15 2462.95 5950294.84 702957.47 -1262.76 2541.17 8.00 89.00 4254.56 0.13 8.00 13248.00 90.2 241.52 239.94 8824.73 -1150.45 2441.19 5950281.94 702936.061 -1275.66 2519.76 8.00 89.00 4279.25 0.12 8.~} 13273.00 90.24 243.52 241.94 8824.63 -1161.98 2419.01 5950269.80 702914.20' -1287.80 2497.90 8.00 89.00 4303,78 0.12 8.00 · 13298.00 90.28 245.52 243.94 8824.52 -1172.74 2396.44 5950258.42 71)2891.94 -1299.18 2475.64 8.00 89.00 4328.13 0.16 8.00 ~ 13300.00 90.28 245.68 244.10 8824.51 -1173.56 2394.62 5950257.55 702890.14 -1300.05 2473.84 8.00: 89.00 4330.07 0.00 8.00~. 13323.00 90.31 247.52 245.94 8824.39 -1182.70 2373.51 5950247.83 702869.30 -1309.77 2453.00 8.00 89.00 4352.27 0.13 8.00 13348.00 90.34 249.52 247.94 8824.25 -1191.85 2350.25 5950238.04 702846.30 -1319.56 2430.00 8.00 89.00 4376.17 0.12 8.0{} 13373.00 90.37 251.52 249.94 8824.09 -1200.19 2326.68 5950229.06 702822,97 -1328.54 2406.67 8.00 89.00 4399.79 0.12 8.00 13398.00 90.40 253.52 2511.94 8823.92 -1207.70 2302.84 5950220.90 702799.34 -1336.70 2383.04 8.00 89.00 4423.12 0.12 8.00 13400.00 90.41 253.68 252.10 8823.91 -1208.26 2300.92 5950220.28 702797.44 -1337.32 2381.14 8.00 89.00 4424.97 0.50 8.0'0 13423.00 90.43 255.52 253.94 8823.74 -1214.37 2278.75 5950213,56' 7(12775.44 -1344.04 2359.14 8.00 89.00 4446.12 0.09 8.00 13448.00 90.46 257.52 255.94 8823.55 -1220.20 2254.44 5950207.07 702751.30 -1350.53 2335.00 8.00 89.00 4468.76 0.12 8.00 13473.00 90.49 259.52 257.94 8823.34 -1225.17 2229.94 5950201.42 702726.95 -1356.18 2310.65 8.00 89.00 4491.02 0.12 8.00 13479.02 90.50 260.00 258.42 8823.29 -1226.24 2224.02 5950200.19 702721.06 -1357.41 2304.76 8.00 88.00 4496.32 0.17 7.97 7 13498.00 90.51 260.57 258.99 8823.12 -1229.44 2205.31 5950196.47 702702,45 -1361.13 2286.15 3.00 88.00 4512.95 0.05 3,00 13500.00 90.52 260.63 259.05 8823.10 -1229.77 2203.34 5950196.09 702700,48 -1361.51 2284.18 3.00 88.00 4514.70 0.50 3,00 13523.00 90.53' 261.32 259.74 8822.89 -1233.38 2180.62 5950191.85 702677.88 -1365.75 2261.58 3.00 88.00 4534.71 0.04 3.00 13548.00 90.55 262.07 260.49 8822.66 -1236.99 2155,89 5950187.56 702653.25 -1370.04 2236.95 3.00 88.00 4556.30 0.08 3.00 13573.00 90.57 262,82 261.24 8822.4 -1240.28 2131.11 595(}183.59 702628.57 -1374.01 2212.27 3.00 88.00 4577.73 0.08 3.0~ 13598.00 90.59 263.57 261.99 8822.16 -1243.24 2106.28 5950179.95 702603.84 -1377.65 2187.54 3.00 88.00 4598.99 0.08 3.00 13600,00 90.59 263.63 262.05 8822.14 -1243.46 2104.30 5950179.67 702601.86 -1377.93 2185.56 3.00 88.00 4600.68 0.00 3.00 Meas. Incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N{+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Commen~ (de~) (deg) (de~) (ft) Lat. (Y) Dep. (X) Lat. (Y) l)ep. (X) Lat. (Y) Dep. (X) (°/100ft) (from TIP) (°/100ft) (°/100fi) 13623.00' 90.61 264.32 262.74 8821.90 -1245.88 2081.43 5950176.63 702579.06 -1380.97 2162.76 3.00 88.00 4620.08 0.09 3.00 13648.00 90.63 265.07 263.49 8821.63 -1248.19 2056.53 5950173.63 702554.24 -1383.97 2137.94 3.00 88.00 4640.98 0.08 3.00 13673.00 90.65 265.82 264.24 8821.35 -1250.17 2031.61 5950170.96 702529.39 -1386.64 2113.09 3.00 88.00 4661.71 0.08 3.00 13698.00 90.67 266.57 264.99 8821.06 -1251.83 2006.67 5950168.61 702504.50 -1388.99 2088.20 3.00 88.00 4682.25 0.08 3.00 13700.00 90.67 266.63 265.05 8821.04 -1251.95 2004.68 5950168.44 702502.51 -1389.16 2086.21 3.00 88.00 4683.88 0.00 3.00 13723.00 90.69 267.32 265.74 8820.76 -1253.16 1981.71 5950166.59 7{)2479.58 -1391.01 2063.28 3.00 88.00 4702.60 0.09 3.00 13748.00 90.70 268.07 266.49~ 8820.46 -1254.17 1956.73 5950164.90 702454.64 -1392.70 2038.34 3.00 88.00 4722.76 0.04 3.00 13773.00 90.72 268.82 267.24 8820.15 -1254.85 1931.74 5950163.53 702429.68 -1394.07 2013.38 3.00 88.00 4742.73 0.08 3.00 13798.00 90.74 269.57 267.99 8819.83 -1255.20 1906.75 5950162.49 702404.71 -1395.11 1988.41 3.00 88.00 4762.49 0.08 3.00 13800.00 90.74 269.63 268.05 8819.81 -1255.21 1904.75 5950162.42 702402.7 -1395.18 1986.41 3.00 88.00 4764.07 0.00 3.00 13823.00 90.76 270.32 268.74 8819.50 -1255.22 1881.75 5950161.78 702379.72 -1395.82 1963.42 3.00 88.00 4782.06 0.09 3.00 13848.00 90.78 271.07 269.49 8819.17 -1254.92 1856.75 5950161.39 702354.72 -1396.21 1938.42 3.00 88.00 4801.42 0.08 3.00 13873.00 90.79 271.82 270.24 8818.83 -1254.29 1831.76 5950161.33 702329.73 -1396.27 1913.43 3.00 88.00 4820.57 0.04 3.00 13898.00 90.81 272.57 270.99 8818.48 -1253.33 1806.79 5950161.60 702304.73 -1396.00 1888.43 3.00 88.00 4839.50 0.08 3.00 13900.00 90.81 272.63~ 271.05 8818.45 -1253.24 1804.79 5950161.64 702302.73 -1395.96 1886.43 3.00 88.00 4841.01 0.00 3.00 ,~ 13923.00 90.83 273.32 271.74 8818.12 -1252.05 1781.82 5950162.20 702279.74 -1395.40 1863.44 3.00 88.00 4858.23 0.09 3.00 ~ 13948.00 90.85 274.07 272.49 8817.75 -1250.44 1756.88 5950163.12 702254.76 -1394.48 1838.46 3.00 88.00 4876.73 0.08 3.00 13973.00 90.86 274.82 273.24 8817.38 -1248.50 1731.95 5950164.37 702229.80 -1393.23 1813.50 3.00 88.00 4895.01 0.04 3.00 13998.00 90.88 275.57 273.99 8817.00 -1246.24 1707.06 595(1165.95 702204.85 -1391.65 1788.55 3.00 88.00 4913.07 0.08 3.00 14000.00 90.88 275.63 274.05 8816.97 -1246.04 1705.07 5950166.09 702202.85 -1391.51 1786.55 3.00 88.00 4914.50 0.00 3.00 14023.00 90.90, 276.32 274.74 8816.61 -1243.65 1682.20 5950167.85 702179.921 -1389.75 1763.62 3.00 88.00 4930.90 0.09 3.00 14048.00 90.92 277.07 275.49 8816.22 -1240.73 1657.37 5950170.08 702155.03 -1387.52 1738.73 3.00 88.00 4948.50 0.08 3.00 14073.00 90.93 277.83 276.25 8815.81 -1237.49 1632.59 5950172.63 702130.16 -1384.97 1713.86 3.00 88.00 4965.86 0.04 3.04 14098.00 90.95 278.58 277.00 8815.40 -1233.92 1607.84 5950175.52 702105~33 -1382.08 1689.03 3.00 88.00 4982.99 0.08 3.00 14100.00 90.95 278.64 277.06 8815.37 -1233.62 1605.87 5950175.76 702103.35 -1381.84 1687.05 3.00 88.00 4984.35 0.00 3.00! 14119.93 90.96 279.23 277.65 8815.04 -1230.53 1586.18 5950178.31 702083.58 -1379.29 1667.28 3.00 0.00 4997.81 0.05 2.96 T.D. 4-1/2" Production Tubing 4-1/2" Camco Bal-o SSSV Nipple @2195' 4-1/2"KBG GLM's DS 11-38 PROPOSED CT Cement Plugback 7" S-3 Pckr. @ 9576' 4-1/2" HES X Nipple @ 9600' 4-1/2" TT @ 9623' 4-1/2" TiW MLAS Composite sub from 10887 - 10924 End of 4-112" liner &6'OH TIW NoGO sub 3.010" ID @ 10993' 10758' MI:) 1.,~~0856~ m~~ ~/ ' MD 13148' MD TIgV SS Hgt. 7" Liner shoe ~ 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 4-1/2" Slotted Liner shoe at 13148' Sqz'd 4-1/2" Production Tubing 4-1/2" Camco Bal-o SSSV Nipple @2195' 4-1/2"KBG GLM's DS 11-38A PROPOSED CT ST AND COMPLETION TD @ ~ 1412O' Initial perforations 2-7/8" Cmt'd liner 7" S-3 Pckr, @ 9576' 4-1/2" HES X Nipple @ 9600' 4-1/2" TT @ 9623' II 10758' MD TIW SS Hgr. 0856' MD 7" Liner shoe 3.75" hole Window cut in MLAS sub in 4.5" liner and cmt in 6" annulus @ -1O89O' 17 ppg cement plug in 4-1/2" liner and 4.5"x 6" annulus 13148' MD End of 4-112" liner & 6" OH 4-1/2" Slotted Liner shoe at 13148' Sqz'd R. EC, !VE, D ~iT'~" ~ 0 Alask~ Oil & Gas Cons. C0mmissior, A,nchora§a o WELL PERMIT CHECKLIST ADMINISTRATION 1 1 COMPANY ..,~, ,,,-"~-_,.-~ ENGINEERING WELL NAME INIT CLASS ,~L,," /~-~. ~/) GEOL AREA 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3 Unique well name and number .................. 4 Well Iocaled in a defined pool ................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 0. Operator has appropriate bond in force ............. 1. Permit can be issued without conservation order ........ 2. Permit can be issued without administrative approval ...... 3. Can permit be approved before 15-day wait ........... N N N N N N N ~y2-~ ...... N N Q N (~ N PROGRAM: exp [] dev~;~redrll~serv [] wellbore seg II ann. disposal para req UNIT# ' ,,/'//~"",,'~ ON/OFF SHORE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ '18. CMf will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. 27. 28. 29. GEOLOGY 30. 31. 32. 33. 34. APPR DATE ANNULAR DISPOSAL 35. With proper cementing records, this plan/'- (A) will contain waste in a suitable recei,~fig zone; ....... APPR DATE (B) will not ~ter; o~ause drilling waste... to surface; (C) will not ~ity ofth.e we~posal; (D) will not d~npair recovery trb-h'~ a pool; an,_,....~ ~- (,E) will n rcumvent 20 AAC 25.252 or 20 AAC 25.412. BOPE press rating appropriate; test to ~ ~"-~ (-_~ . psig ....... Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. DataPermit presented can be issued on potential w/o hydrogen overpressure sulfidezones measures ....... .....~ YvY Nt~/,_Z._~___~ Y ............. Seismic analysis of shallow gas zones. ' Seabed condition survey (if off-shore) ............. Y N Cogtact.na~e/phon~ ~or weekly progress reports ....... ~Y N .................................................................................................................................................................................................................. lexp~orato~ omyJ Y N Y N Y N GEOLOGY: R ENGINEERING: J D H,.,.,,.,,-----. COMMISSION: DWJ ~ RNC Comments/Instructions: MchoMist lev 05/29198 dlfC \rns()ffi(.n\wr)ufi,ml\dirula\,:hr~, kh!,l Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 11-38A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292272301 REFERENCE NO : 99002 LIS TaPe Verification Listing Schlumberger Alaska Computing Center 5-jANt'~.~99 15:50 PAGE * * * * REEL HEADER * ** * SERVICE NAME : EDIT DATE · 99/01/ 5 ORIGIN : FLIC REEL NAME : 99002 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/ 5 ORIGIN · FLIC TAPE NAME · 99002 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 11-38A API NUMBER: 500292272301 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-JAN-99 JOB NUMBER: 99002 LOGGING ENGINEER: HERRMANN OPERATOR WITNESS: A. KIRK SURFACE LOCATION SEC TI ON: 33 TOWNSHIP: 1 iN RANGE: 15E FNL: FSL: 5115 FEL: 1 O1 FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: 64.22 DERRICK FLOOR: 63. O0 GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 4. 500 10894.0 12.60 2ND STRING 2. 875 13837.0 8.60 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JANL2-~ 15:50 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: AIT LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: SCHLUNfl3ERGER WELL SERVICES BASELINE DEPTH 88888.0 10809.5 10733.0 10634.0 10583.0 10582.0 10571.5 10570.0 10554 5 10553 5 10488 0 10483 0 10440 5 10426 5 10313 5 10313 0 10266 0 10264 0 10260 5 10259 5 10253.5 10187.5 10157.0 10156.5 10150.0 10149.5 10138.5 10076.5 10041.0 9960.0 9959.0 9935.5 9928.5 9927.5 9925.0 9924.0 9887.0 9886.0 9840.0 9838.0 9811.5 9809.5 9784.5 9783.0 9743.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH MCNL .............. 88887.0 10808.5 10731.5 10633.0 10582.5 10570.0 10552.5 10487.0 10481.0 10439.0 10425.0 10313.0 10265. 0 10259.0 10252.0 10185.0 10155.5 10148.5 10137.5 10074.5 10039.5 9959.5 9935.0 9928.0 9923.5 9886.5 9838.5 9810.0 9783.0 9741.5 88887.0 10808.5 10731.5 10582.5 10570.0 10552.5 10487.0 10481. 0 10439.0 10425.0 10313.0 10265.0 10259. 0 10252.0 10185. 0 10155.5 10148.5 10137.5 10074.5 10039.5 9959.5 9935.0 9928.0 9923.5 9886.5 9838.5 9810.0 9783.0 9741.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-~j9 15:50 9736.0 9721.5 9717.0 9700.0 9692.5 9689.5 9685.0 9668.0 9666.5 9661.5 9653.5 9646.0 9631 0 9613 5 9605 0 9603 0 9600 5 9585 0 9573 5 9571.5 9561.5 9542.0 9533.5 9521.5 9513.0 9506.5 100.0 $ REMARKS: 9735.0 9735.0 9720.5 9720.5 9716.0 9716.0 9698.5 9698.5 9691.0 9691.0 9688.0 9684.0 9684.0 9666.5 9666.5 9660.5 9660.5 9652.5 9652.5 9644.5 9644.5 9629.5 9629.5 9613.0 9613.0 9603.5 9603.5 9601.0 9601.0 9598.0 9598.0 9583.5 9583.5 9572.5 9572.5 9571.0 9571.0 9560.0 9560.0 9541.0 9541.0 9532.5 9532.5 9519.5 9519.5 9512.0 9512.0 9505.0 9505.0 98.5 98.5 CONTAINED HEREIN IS THE MCNL DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 11-38A ON 1-DEC-98. THE DEPTH SHIFTS SHOWN ABOVEREFLECT THE MAIN PASS GRCH TO THE BASELINE GAIV~IA RAY PROVIDED BY THE CLIENT (GR.AIT); AND THE MAIN PASS NRAT TO GR.AIT. NO DEPTH SHIFTS WERE APPLIED BELOW THE KICK-OFF POINT OF 10890'. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-'i'~-~9 15: 50 PAGE: FILE SUM~iARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13766.0 9500.0 MCNL 13774.0 9500.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH MCNL REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE MCNLMAIN PASS. THIS DATA HAS BEEN DEPTH CORRECTED TO THE PARENT WELL ABOVE THE KICK-OFF POINT OF 10890' AND IS NOW CONSIDERED TO BE THE PRIMARY DEPTH CONTROL FOR DS 11-38A. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-i~9 15:50 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NI]M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI 0000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13773.000 GRCH. CNT -999.250 NCNT. CNT 7736.991 NRAT. CNT 13.695 CCL.CNT 85.000 GR.AIT -999.250 DEPT. 8944.000 GRCH. CNT -999.250 NCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GR.AIT 225.429 FCNT. CNT FCNT. CNT 451.601 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .00i SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15:50 PAGE: DEPTH INCREMENT: 0.5000 FILE SUb~qARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13764.0 13464.0 MCNL 13772.0 13464.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 13766.0 13760.0 13756.0 13755.0 13748 0 13742 5 13718 0 13705 0 13695 5 13692 0 13686 0 13676.5 13660.5 13658.5 13634.5 13619.5 13611.5 13605.5 13585.0 13580.0 13575.5 13563.5 13549.5 13549.0 13541.0 13526.5 13520.5 13516.5 13514.5 13499.5 13494.5 13492.5 13490.5 13486.0 13480.0 13475.0 100.0 .......... EQUIVALENT UNSHIFTEDDEPTH GRCH MCNL 88886.0 88889.0 13758.0 13754.0 13748.0 13717.0 13704.5 13690.0 13660.5 13636.0 13618.5 13603.5 13579.5 13548.0 13539.5 13528.0 13523.0 13515.5 13494.0 13489.5 99.0 13767.0 13760.5 13755.0 13741.5 13695.0 13685.0 13676.0 13662.0 13612.5 13586.0 13575.0 13564.5 13550.0 13517.5 13498.0 13490.0 13482.5 13476.5 13472.5 97.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE REPEAT PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE REPEAT PASS GRCH TO THE MAIN PASS GRCH; AND THE REPEAT PASS NRAT TO THE MAIN PASS NRAT. ONLY NRAT, CCL, AND GR AREPRESENTED ON THE BLUELINE FOR THE REPEAT PASS AND WERE SUPPLIED ON THE FIELD TAPE FOR INCLUSION IN THIS FILE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB N73M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNT V 0000000 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5 -JAN-'~9'9 15: 50 PAGE: DEPT. 13773.000 GRCH. CNT DEPT. 13461.500 GRCH. CNT -999.250 N-RAT. CArT -999.250 NRAT. CNT 13.380 CCL. CNT 18.400 CCL.CNT 85.000 85.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 1000 FILE SUA94ARY VENDOR TOOL CODE START DEPTH MCNL 13790.08 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO)'. STOP DEPTH .......... 9482.98 1-DEC-98 0035E 423 1-DEC-98 13840.0 13780.0 9500.0 13780.0 1800.0 NO LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-i~'9 15: 50 PAGE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY MCNL COMP. NEUTRON $ TOOL NUFiBER ........... GR MCNL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10894.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -110 FAR COUNT RATE HIGH SCALE (CPS): 2090 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: TIED INTO SPERRY SUN MWD LOG OF 1/12/97. INJECTOR HEAD SLIPPING WHILE LOGGING. DID NOT AFFECT DEPTH. THIS FILE CONTAINS THE RAW MCNL DATA FOR THE MAIN PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JANJI~'9 15:50 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 CVEL PS1 F/HR 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 GR PS1 GAPI 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT PS1 CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT PSl CPS 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT PS1 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 CCL PS1 V 0000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. FCNT. PS1 13790.084 CVEL.PS1 -999.250 NRAT. PS1 2.174 GR.PS1 -999.250 NCNT.PS1 -999.250 -999.250 CCL. PS1 -999.250 DEPT. FCNT. PSl 9482.984 CVEL.PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 -999.250 -999.250 NRAT. PS1 -999.250 CCL.PS1 85.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 1000 FILE SUMSIARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13788.02 13451.92 MCNL $ LOG HEADER DATA DATE LOGGED: 1-DEC-98 SOFTWARE VERSION: 0035E TIME LOGGER ON BOTTOM: 423 1-DEC-98 TD DRILLER (FT) : 13840.0 TD LOGGER (FT) : 13780.0 TOP LOG INTERVAL (FT): 9500.0 BOTTOM LOG INTERVAL (FT): 13780.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMFIA RAY MCNL COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... GR MCNL LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 12 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10894.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -110 FAR COUNT RATE HIGH SCALE (CPS): 2090 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: TIED INTO SPERRY SUN MWDLOG OF 1/12/97. INJECTOR HEAD SLIPPING WHILE LOGGING. DID NOT AFFECT DEPTH. THIS FILE CONTAINS THE RAW MCNL DATA FOR THE REPEAT PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 13 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.1 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS2 GAPI 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT PS2 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 CCL PS2 V 0000000 O0 000 O0 0 4 1 1 4 68 0000000000 * * DATA * * DEPT. 13788.018 DEPT. 13451.918 GR.PS2 -999.250 NRAT. PS2 0.000 CCL.PS2 -999.250 GR.PS2 -999.250 NRAT. PS2 -999.250 CCL.PS2 85.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION . O01CO1 mATE . 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 14 * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 99/01/ 5 ORIGIN : FLIC TAPE NAME : 99002 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/ 5 ORIGIN : FLIC REEL NAME : 99002 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 * ALASKA COMPUTING CENTER * . ............................ . ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 11-38A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22723-01 REFERENCE NO : 99048 RECEIVED -.-q 18 1999 roll & Gas Cons. Commission LIS ~pe Verification Listing Schlumberger Alaska Computing Center lO-FE~=~99 09:27 PAGE: * * * * REEL HEADER ** * * SERVICE NAME : EDIT DATE : 99/02/10 ORIGIN : FLIC REEL NAME : 99048 CONTINUATION # : PREVIOUS REEL : COMMENT · ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE · 99/02/10 ORIGIN · FLIC TAPE NAME · 99048 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 11~38A API NOY4BER: 50029227230 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-FEB-99 JOB NUMBER: 99048 LOGGING ENGINEER: R. HERRMANN OPERATOR WITNESS: J. MIDDENDORF SURFACE LOCATION SECTION: 33 TOWNSHIP: liN RANGE: 15E FNL: FSL: 5515 FEL: 10! FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 64.00 DERRICK FLOOR: 63.00 GROUND LEVEL: 0.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 4 . 500 10802. 0 12. 60 2ND STRING 2 . 875 13837. 0 8.60 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(M~ASURED DEPTH) LIS 'i%~pe Verification Listing Schlumberger Alaska Computing Center lO-FEB-~99 09:27 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MCNL LDWG CURVE CODE: GRCH RUN NUMBER: 1 PASS NUMBER: 1 DATE LOGGED: 1-DEC-98 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 13750.0 13748.0 13736.5 13734 5 13729 5 13717 0 13707 0 13691 0 13690 5 13680 0 13673 0 13654 5 13643 0 13637.0 13624.0 13607.0 13599.0 13580.5 13565.5 13545.0 13527.5 13515.5 13514.5 13510.0 13490.0 13466.0 13460.5 13429.5 13428.0 13421 5 13418 5 13415 5 13409 0 13398 5 13393 5 13387 0 13384 5 13365 0 13319 5 13302 0 13300 0 13293 0 13283 5 13278.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNT 88884.5 88886.5 13748.5 13744.5 13735.5 13728.5 13715.0 13706.0 13690.0 13674.5 13654.5 13642.5 13635.5 13624.0 13607.0 13579.5 13545.5 13516.0 13511.5 13489.5 13464.5 13459.0 13427.0 13421.5 13414.0 13407.5 13392.5 13384.0 13364.5 13301.5 13290.5 i 3278.5 13732.0 13691.5 13680.5 13599.0 13566.0 13528.0 13515.5 13490.5 13429.5 13417.5 13398.0 13386.5 13318.0 13299.5 13282.5 PAGE: LIS r'~pe Verification Listing Schlumberger Alaska Computing Center 13261.5 13261.0 13237.5 13208.0 13205.5 13199.5 13175.0 13168.0 13163.0 13156.0 13147.5 13143.0 13119.5 13113.5 13109.5 13098.0 13088.0 13082.0 13075.5 13073.0 13053.5 13036.5 13022.5 13000.5 12995.0 12982.0 12968 0 12955 0 12954 5 12943 5 12932 0 12930 5 12917 5 12910 5 12907 5 12906 0 12896 0 12866.5 12850.0 12841 . 0 12836.5 12830.5 12816.0 12811 . 0 12788.0 12775.5 12765.0 12762.0 12761 . 5 12747.0 12745.0 12732.5 12724.0 12721.0 12704.5 12701 . 0 13261.0 13207.0 13199.0 13165.5 13155.5 13141.5 13112.0 13097.0 13082.0 13074.5 13052.5 13036.0 12999.5 12966.5 12954.0 12930.0 12914.5 12909.5 12905.0 12847.5 12839.0 12828.0 12814.0 12774.0 12764.5 12760.0 12746.5 12733.5 12725.0 12722.0 12705.5 12702.0 13260.5 13236.5 13205.0 13174.5 13163.0 13147.0 13120.0 13111.5 13089.5 13073.0 13023.0 12995.0 12982.0 12956.0 12944.0 12929.5 12905.0 12894.5 12865.0 12837.0 12810.0 12786.5 12760.5 12743.0 lO-FEB%~99 09:27 PAGE: LIS '-'~..~pe Verification Listing Schlumberger Alaska Computing Center 12699.5 12695.5 12693.0 12677.5 12656.5 12650.0 12642.5 12638.5 12610.0 12602.0 12599.5 12594.5 12592.0 12576.5 12566.5 12557.5 12544.5 12542.5 12533.0 12529.0 12518.0 12509.0 12491.0 12483.0 12479.5 12478.5 12471.5 12466.0 12457.5 12446.5 12432.5 12422.0 12421.0 12394.0 12388.5 12386.0 12379.0 12367.5 12363.0 12341.0 12337.5 12337.0 12322.0 12317.5 12311.0 12300 0 12292 5 12285 5 12273 5 12267 0 12258 5 12255 5 12246 5 12245.5 12242.5 12241.0 12698.0 12694.5 12679.0 12651.0 12644.0 12608.0 12601.5 12598.0 12591.5 12588.5 12575.5 12565.0 12538.5 12526.0 12504.5 12479.0 12474.0 12469.5 12456.0 12430.0 12419.0 12392.5 12383.0 12377.0 12362.0 12338.5 12335.5 12315.5 12300.0 12292.5 12283.5 12265.0 12253.0 12244.0 12242.0 12239.5 12699.0 12657.0 12639.0 12594.5 12558.5 12545.0 12533.0 12517.5 12490.5 12479.0 12467.5 12446.5 12423.0 12389.0 12368.0 12338.0 12322.0 12311.5 12273.0 12257.5 12244.0 lO-FEB-.~99 09:27 PAGE: LIS 'r~'pe Verification Listing Schlumberger Alaska Computing Center 12231.5 12230.5 12223.0 12206.0 12204.0 12193.0 12175.0 12169.5 12166.0 12158 0 12156 0 12141 5 12129 0 12120 5 12112 5 12110.0 12109.0 12106.0 12075.5 12074.0 12070.5 12068.0 12064.5 12054.5 12051.5 12048.5 12042.5 12041 . 5 12028.5 12026.5 12024.5 12022. 0 12009 5 11988 0 11984 0 11966 5 11959 5 11948 5 11937 5 11931 5 11926 0 11916.5 11903.0 11893.5 11881.5 11875.0 11872.5 11866.0 11865.5 11863.0 11857.5 11852.5 11847.5 11839.0 11834. 0 11832.5 12229.5 12221.5 12204.0 12191.5 12167.0 12164.5 12157.5 12154.5 12126.5 12110.0 12106.5 12105.0 12072.5 12068.0 12063.0 12053.5 12049.5 12041.0 12027.5 12022.5 12020.5 12007.5 11987.0 11958.5 11945.0 11933.5 11921.5 11914.0 11902.0 11892.0 11873.0 11869.5 11863.5 11862.0 11855.0 11851.0 11839.0 11832.0 12229.5 12207.0 12175.0 12140.5 12120.5 12110.0 12075.0 12068.0 12049.0 12041.5 12026.0 12007.5 11983.5 11966.5 11929.5 11914.5 11881.0 11865.0 11846.5 11828.5 lO-FEB-'~ff/99 09:27 PAGE: LIS 'fa~'e Verification Listing Schlumberger Alaska Computing Center 11823.0 11809.0 11796.0 11794.0 11774.0 11767.0 11 764.0 11762.0 11749.5 11744.5 11722.0 11719.5 11701.0 11693.5 11689.0 11679.0 11673.0 11661 5 11648 5 11641 0 11633 0 11630 5 11630 0 11623 5 11617 5 11615 0 11612 5 11612 0 11608.5 11606.0 11601.5 11595.5 11589.0 11588.5 11576.0 11572.5 11560.5 11556.0 11548.0 11539.0 11524.5 11517.5 11507.5 il 480.0 11452.5 11420.5 11400.0 11372.5 11356.0 11354.0 11319.0 11306.5 11286.5 11281.5 11278.0 11272.5 11821.0 11807.5 11795.0 l1793.5 11772.5 11762.0 11747.5 11743.5 11720.5 11701.0 11689.5 11680.5 11663.0 11648.0 11641.0 11629.5 11623.0 11617.0 11612.0 11609.5 11606.5 11593.0 11587.0 11569.5 11556.5 11553.0 11545.5 11535.5 11521.5 11515.0 11503 5 11475 5 11450 5 11418 0 11397 0 11369 5 11353 5 11352 0 11317 5 11306 0 11285.5 11280.5 11276.0 11271.0 11808.0 11766.5 11762.0 11720.0 11693.0 11672.5 11635.0 11631.0 11612.0 11606.5 11602.0 11590.0 11577.0 iO-FEBL~z=~9 09:27 PAGE: LIS ":~Pe Verification Listing Schlumberger Alaska Computing Center 11250.5 11246.0 11235 0 11224 0 11212 0 11203 5 11189 5 11183 0 11176 0 11152 0 11144.5 11136.5 11111.5 11095.0 11085.5 11077.5 11059.5 11051.5 11040.5 11025.5 10992.5 10986.5 10964.5 10959.0 10956.0 10930.5 10911.5 10888.5 10884.0 10876.0 10862.5 1 0852.5 10840.0 10834.5 10816.0 10798.0 10786 0 10757 5 10751 0 10747 0 10738 0 10734 0 10730 0 10726 5 10715.5 10696.5 10691.5 10651.5 t 0643.5 10642.0 10637.5 10614.5 10606.5 10595.0 10593.5 10589.0 11250.5 11245.5 11233.5 11222.0 11211.5 11202.0 11188.0 11182.0 11174.0 11151.0 11142.5 11135.0 11110.0 11093.5 11084.0 11075.5 11058.0 11050.5 11039.0 11024.5 10992.5 10985.0 10963.5 10956.5 10954.0 10928 5 10909 5 10887 5 10882 5 i 0874 0 10860 0 10850 5 10838 0 10831 5 10814 5 10797.5 10783.0 10754.5 10749.5 10743.5 10735.5 10731.5 10727.0 10711.5 10691.5 10641.5 10635.0 10604.5 10592.0 10588.0 lO-FEB~99 09:27 10726.5 10694.5 i 0654.0 10643.5 10616.5 10595.0 PAGE: LIS "~Pe Verification Listing Schlumberger Alaska Computing Center lO-FEB'l~99 09:27 10584.0 10578.0 10572.0 10570.0 10555.5 10543.5 10543.0 10532.5 10518.0 10484.0 10468.0 10464.5 10443.5 10442 0 10435 5 10427 5 10421 0 10417 0 10406 5 10395 5 10384 0 10380.5 10346.0 10342.0 10338.5 10330.5 10325.5 10322.0 10317.0 10309.5 10305.5 10304.0 10300.0 10296.5 10291 5 10273 5 10271 0 10268 0 10261 5 i00 0 $ REMARKS 10582.5 10570.0 10552.5 10541.0 10514.5 10481.0 10463.0 10439.0 10425.5 10381.0 10343.0 10341.0 10329.0 10309.5 10302.5 10298.0 10288.5 10271.5 10265.0 10259.0 97.5 10578.0 10570.0 10543.0 10534.0 10471.0 10447.0 10439.0 10420.5 10417.0 10407.0 10396.5 10380.5 10341.0 10329.0 10324.5 10320.5 10309.5 10299.0 10273.0 102. 0 CONTAINED HEREIN IS THE LDWG EDITTED DATA FOR THE CASED HOLE MCNL DATA ACQUIRED ON ARCO ALASKA'S D.S. 11 - 38A WELL. 1 BASELINE PASS WAS LOGGED AND 2 BORAX PASSES. THE DEPTH SHIFTS SHOP~N ABOVE REFLECT DEPTH CORRELATIONS BETWEEN BASE PASS #1 GRCH AND THE GRCH. PDC, ALSO BET~EEN BASE PASS #1 NRAT AND THE GRCH. PDC CARRYING A~L CNT CURVES WITH THE NRAT SHIFTS. DUE TO ONLY 1 BASE PASS BEING LOGGED NO AVERAGING IS BEING DONE. PAGE: LIS h~e Verification Listing Schlumberger Alaska Computing Center IO-FEBt~9 09:27 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/10 MAi~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUN2VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13758.0 10259.0 CNT 13764.0 10269.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT O~VSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNT $ REMARKS: THIS FILE CONTAINS THE EDITTED BASE PASS DATA. NO PASS TO PASS TO DEPTH SHIFTS _HAVE BEEN APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FOP~4AT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 LIS ;~Pe Verification Listing Schlumberger Alaska Computing Center 10 -FEB-~=999 09: 27 PAGE: 10 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NOY4~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU?4B SAMP ELEM CODE (HEX) DEPT FT 6012502 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 6012502 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 6012502 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 6012502 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 6012502 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V 6012502 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH PDC GAPI 6012502 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13765.000 GRCH. CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GRCH. PDC 53.209 DEPT. 9498.500 GRCH. CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 GRCH. PDC 64.408 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O0!CO1 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS ~Pe Verification Listing Schlumberger Alaska Computing Center 10-FEB£~9 09: 27 PAGE: 11 **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE ' : FILE HEADER FILE NIIMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASSNUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~L&RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13760.0 12611.0 CNT 13766.0 12620.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NIIMBER: 1 BASELINE DEPTH 88888.0 13758.5 13750.0 13736.0 13731.0 13728.5 13712.0 13707.5 13697.0 13683.5 13675.0 13667.5 13665.0 13662.5 13656.5 13655.0 13653.0 13650. 0 13635.5 13633. O 13607.5 .......... EQUIVALENT ONSHIFTED DEPTH .......... GRCH CNT 88886.0 88888.5 13759.0 13748.0 13734.5 13729.5 13726.5 13712.5 13707.0 13697.5 13684.0 13673.5 13668.5 13663.0 13661.5 13655.0 13656.5 13652.0 13650.5 13634.0 13634.0 13607.0 LIS ~e Verification Listing Schlumberger Alaska Computing Center 10 -FEB-~7~9 09: 27 PAGE: 12 13606 5 13596 5 13580 0 13568 0 13563 0 13539 0 13528 5 13528 0 13521 0 13519 0 13510 5 13503 0 13494 5 13490 0 13479 5 13470 5 13466.5 13460 0 13456 5 13447 5 13443 5 13440 5 13435 5 13429 0 13427 5 13424 5 13411 0 13407.0 13403 0 13396 5 13387 5 13385 0 13366 0 13353 0 13346 0 13343 0 13338 0 13332 5 13324 0 13314.5 13302.5 13290.5 13285.5 13283 0 13275 5 13271 0 13261 0 13248 0 13241 5 13232 5 13232 0 13210 5 13209 5 13187 5 13176 0 13579.5 13528.0 13510.5 13503.0 13495.5 13490.5 13480.5 13472.5 13459.0 13449.0 13444.0 13430.0 13427.0 13407.5 13388.5 13366.0 13347.0 13345.0 13339.0 13325.0 13316.0 13305.0 13284.5 13274.0 13264.5 13253.5 13238.0 13216.5 13608.0 13597.5 13568.0 13562.5 13540.0 13529.5 13525.0 13522.0 13496.5 13467.5 13459.0 13456.5 13442.5 13437.0 13429.5 13424.5 13412.5 13407.5 13405.0 13397.5 13384.0 13365.5 13353.0 13333.0 13292.5 13285.5 13275.5 13245.0 13239.5 13232.0 13208.5 13187.5 13175.0 LIS ~e Verification Listing Schlumberger Alaska Computing Center iO-FEB~£~99 09:27 PAGE: 13 13169.0 13168.5 13166.5 13172.0 13161.5 13163.0 13150.5 13155.0 13145.5 13145.5 13143.5 13148.5 13141.0 13141.0 13136.5 13139.5 13132.0 13135.5 13121.5 13122.0 13116.5 13118.0 13111.5 13111.5 13105.5 13109.0 13096.5 13097.0 13100.5 13092.0 13095.5 13089.5 13091.5 13085.0 13089.5 13080.5 13083.0 13076.5 13077.0 13069.5 13071.0 13052.0 13052.5 13052.0 13042.5 13043.5 13041.5 13043.0 13022.5 13023.5 13019.5 13019.5 13021.5 13010.0 13011.0 13002.5 13003.5 13000.5 13001.0 12967.5 12970.0 12966.5 12966.5 12963.0 12964.0 12958.0 12959.0 12957.0 12960.0 12954.5 12956.5 12950.0 12951.0 12929.5 12930.5 12929.0 12929.5 12922.5 12923.5 12919.5 12921.5 12915.5 12915.5 12905.5 12905.0 12903.5 12905.0 12890.0 12892.0 12884.5 12887.5 12880.5 12880.0 12867.5 12864.0 12864.5 12865.5 12853.5 12855.5 12850.5 12849.5 12843.5 12843.5 12830.5 12832.0 12825.0 12825.0 12818.5 12817.0 12809.0 12805.5 12804.5 12804.0 LIS ~'~!~e Verification Listing Schlumberger Alaska Computing Center lO-FEBS~99 09:27 PAGE: 14 12785.5 12786.5 12777.5 12777.5 12776.0 12774.0 12775.0 12775.0 12771.5 12771.0 12769.0 12766.5 12766.0 12766.5 12763.5 12764.5 12758.5 12756.5 12752.0 12752.5 12745.0 12746.5 12742.0 12743.0 12731.5 12733.5 12729.5 12729.5 12723.5 12721.5 12715.0 12715.0 12694.5 12694.5 12692.5 12693.0 12685.5 12687.0 12683.0 12685.0 12676.0 12677.5 12659.5 12661.5 12655.0 12657.5 12652.5 12655.0 12632.5 12631.5 12623.5 12624.0 12613 . 5 12616.0 100.0 102.5 102.5 $ REMARKS: THIS FILE CONTAINS EDITTED BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT DEPTH CORRELATIONS BETWEEN GRCH BORAX PASS #! AND THE GRCH FROM THE BASE PASS, ALSO THE NRAT FROM BORAX PASS #! AND THE NNAT FROM THE BASE PASS CARRYING ALL CNT CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 LIS ;l'~e Verification Listing Schlumberger Alaska Computing Center 10 -FEB-~z~99 09:27 PAGE: 15 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 6012502 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI 6012502 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS 6012502 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS 6012502 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 6012502 O0 000 O0 0 2 ! 1 4 68 0000000000 CCL CNT V 6012502 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13766.500 GRCH. CNT -999.250 NCNT. CNT 7767.680 FCNT. CNT NRAT. CNT 13.760 CCL.CNT -999.250 480.739 DEPT. 12613.500 GRCH. CNT 35.125 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL.CNT -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS ~e Verification Listing Schlumberger Alaska Computing Center iO-FEB~'~-~9 09:27 PAGE: 16 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 13764.0 12633.0 CNT 13770.0 12642.0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 13733.0 13728.0 13723.0 13705.5 13699.0 13687.0 13673.0 13655 0 13637 0 13636 5 13615 0 13614 5 13604 0 13601 0 13583 5 13567 5 13564 5 13560 0 13546.5 13534.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT 88886.5 88887.0 13726.5 13721.5 13704.5 13673.5 13654.5 13636.0 13615.0 13604.0 13565.5 13547.5 13534.0 13732.0 13697.5 13687.0 13638.0 13614.5 13600.0 13582.0 13568.0 13560.0 LIS ~p~e Verification Listing Schlumberger Alaska Computing Center 10 - FEB-'r~-~9 09: 27 PAGE: 17 13531.5 13521.0 13509.0 13508.5 13497.0 13494.5 13489.5 13473.5 13468.0 13462.5 13449.0 13446.5 13444.5 13430.5 13429.5 13412 5 13412 0 13408 0 13373 0 13372 5 13368 0 13356 5 13346 5 13339 0 13305 5 13292 0 13285.0 13280.0 13275.0 13265.0 13249.5 13245.0 13226.0 13222.5 13194.0 13186.0 13185.0 13169.0 13166.5 13158.0 13154.0 13150.0 13146.0 13144.0 13118 5 13114 0 13106 5 13078 0 13066 5 13058 5 13053 5 13050 5 13044 5 13020 5 13016.5 13531.5 13521.5 13508.5 13495.5 13489.5 13472.5 13459.5 13446.5 13427.0 13410.0 13404.0 13368.0 13223.5 13192.0 13183.0 13166.0 13153.5 13148.0 13112.5 13057.5 13050.5 13043.0 13019.5 13508.5 13496.0 13472.5 13468.0 13447.0 13445.5 13428.0 13409.5 13369.5 13364.0 13353.0 13344.5 13335.0 13302.0 13288.0 13280 5 13275 5 13269 0 13260 5 13245 5 13240 0 13218.5 13181.5 13163.0 13149.0 13141.0 13138.5 13114.5 13101.0 13073.0 13060.0 13048.5 13011.0 LIS ~e Verification Listing Schlumberger Alaska Computing Center IO-FEB-'~-~'9 09:27 PAGE: 18 13015.5 13007.0 13001.5 12997.0 12977.5 12968.5 12961.0 12955.5 12952.0 12937.5 12931.5 12912.5 12897.0 12892.0 12886.5 12877.0 12875.0 12866.0 12843.5 12833.5 12813.0 12807.5 12803 5 12797 0 12794 0 12788 0 12779 0 12777 0 12768 0 12749.0 12747.5 12727.5 12715.0 12704.0 12682.5 12680.0 12661.0 12652.5 100.0 $ 13013.0 13006.0 12999.5 12996.5 12977.5 12966.5 12959.0 12954.0 12949.5 12930.0 12895.5 12882.5 12873.5 12861.5 12839.0 12809.0 12802.5 12797.5 12787.0 12781.0 12770.5 12760.5 12746.5 12721.5 12708.0 93.0 12933.5 12908.5 12887.5 12872.0 12831.0 12803.5 12792.5 12775.0 12743.0 12699.0 12676.0 12674.0 12657.0 12647.5 95.0 REMARKS: THIS FILE CONTAINS EDITTED BOP~4X PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT DEPTH CORRELATIONS BETPfl~EN GRCH BORAX PASS #2 AND THE GRCH FROM THE BASE PASS, ALSO THE N-RAT FROM BORAX PASS #2 AND THE N-RAT FROM THE BASE PASS CARRYING ALL CNT CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA LIS ~pe Verification Listing Schlumberger Alaska Computing Center iO-FEB-X-~9 09:27 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6012502 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNT GAPI 6012502 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNT CPS 6012502 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNT CPS 6012502 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNT 6012502 O0 000 O0 0 3 i t 4 68 0000000000 CCL CNT V 6012502 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA DEPT. 13769.000 GRCH. CNT -999.250 NRAT. CNT 12.809 CCL.CNT -999.250 DEPT. 12626. 000 GRCH. CNT -999. 250 NRAT. CNT 999 . 250 CCL. CNT -999. 250 NCNT. CNT 7724. 495 FCNT. CNT NCNT. CNT -999.250 FCNT. CNT 476.521 -999.250 ** END OF DATA ** LIS ~ Verification Listing Schlumberger Alaska Computing Center 10-FEB-~9 09: 27 PAGE: 20 * *** FILE TRAILER * * * * FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * FILE HEADER * * * * FILE NAME : EDIT .004 SERVICE · FLIC VERSION : 001C01 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13764 . 0 10259.0 MCNL $ LOG HEADER DATA DATE LOGGED: 05 -JAZI- 99 SOF~gARE VERSION: RELOO35E TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 13764.0 TD LOGGER (FT) : 13764.0 TOP LOG INTERVAL (FT) : 10259.0 BOTTOM LOG INTERVAL (FT) : 13770.0 LOGGING SPEED (FPHR) '. DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MCNL MEMORY CNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SiZE (IN): DRILLERS CASING DEPTH (FT): TOOL NDY~BER LTTN A13 10802.0 LIS Tap'~ Verification Listing Schlumberger Alaska Computing Center iO-FEB-~9 09:27 PAGE: 21 LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 10802.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -90 FAR COUNT RATE HIGH SCALE (CPS): 2110 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): RE~IARKS: PUMPED A TOTAL OF 75 BBLS 1% KCL WATER INTO BEFORE BASE PASS. PUMPED A TOTAL OF 316 BBLS 1% KCL WATER AND 52 BBLS OF BORAX INTO FORMATION BEFORE LOGGING BORAX PASS #1. PUMPED A TOTAL OF 316 BBLS 1% KCL WATER AND 70 BBL BORAX INTO FORlV~ATION BEFORE LOGGING BORAX PASS #2. PUMPED A TOTAL OF 316 BBLS 1% KCL WATER AND 91 BBLS BO~ UP TO COMPLETION OF BORAX PASS #2. FIELD PICK GOC AT 10424'. BORAX CHANNEL FOUND FROM 13602' TO 12650' (END OF LOGGING PASS) W~EN COMPARED WITH PRODUCTION LOG RUN ON SA2~E DAY (1/5/99). THERE IS A LEAK AT 12794' (COOLING EFFECT ON TEMPERATURE LOG). THIS FILE CONTAINS THE RAW DATA FOR THE BASE PASS. $ LIS FORMAT DATA LIS T~-pe Verification Listing Schlumberger Alaska Computing Center 10-FEB-~ 09: 27 PAGE: 22 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ~FOMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6012502 O0 000 O0 0 4 1 ! 4 68 0000000000 CCLD BAS V 6012502 O0 000 O0 0 4 1 1 4 68 0000000000 CVEL BAS F/HR 6012502 O0 000 O0 0 4 1 ! 4 68 0000000000 GR BAS GAPI 6012502 O0 000 O0 0 4 i 1 4 68 0000000000 NCNT BAS CPS 6012502 O0 000 O0 0 4 ! ! 4 68 0000000000 FCNT BAS CPS 6012502 O0 000 O0 0 4 1 i 4 68 0000000000 NRAT BAS 6012502 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13781.551 CCLD.BAS -999.250 CVEL.BAS -999.250 GR.BAS -999.250 NCNT. BAS -999.250 FCNT.BAS -999.250 NR~T. BAS -999.250 DEPT. 10256.551 CCLD.BAS 85.000 CVEL.BAS -999.250 GR.BAS -999.250 NCNT. BAS -999.250 FCNT.BAS -999.250 NRAT. BAS -999.250 * * END OF DATA * * LIS "z~e Verification Listing Schlumberger Alaska Computing Center iO-FEBt~-~9 09:27 PAGE: 23 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE · 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE · 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.1000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH .......... 13764.0 10259.0 MCNL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : bOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MCNL M~4ORY CNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 05-JAN-99 RELOO35E 13764.0 13764.0 10259.0 13770.0 NO TOOL NUMBER LTTN A13 10802.0 LIS '~JPe Verification Listing Schlumberger Alaska Computing Center iO-FEB£~9'9 09:27 PAGE: 24 LOGGERS CASING DEPTH (FT): 10802.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WI~H~OW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -90 FAR COUNT RATE HIGH SCALE (CPS): 2110 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: PUMPED A TOTAL OF 75 BBLS 1% KCL WATER INTO BEFORE BASE PASS. PUMPED A TOTAL OF 316 BBLS 18 KCL WATER AND 52 BBLS OF BORAX INTO FORMATION BEFORE LOGGING BORAX PASS #1. PUMPED A TOTAL OF 316 BBLS 18 KCL WATER AND 70 BBL BORAX INTO FORMATION BEFORE LOGGING BORAX PASS #2. PUMPED A TOTAL OF 316 BBLS 1 ~ KCL WATER AND 91 BBLS BORAi~ UP TO COMPLETION OF BORAX PASS #2. FIELD PICK GOC AT 10424'. BORAX CHA~,~IEL FOUND FROM 13602' TO 12650' (END OF LOGGING PASS) WHEN COMPARED WITH PRODUCTION LOG RUN ON SAME DAY (1/5/99). THERE IS A LEAK AT 12794' (COOLING EFFECT ON TEMPERATURE LOG). THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #i. $ LIS FORMAT DATA LIS"~e Verification Listing Schlumberger Alaska Computing Center 10-FEB£TI~N99 09:27 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6012502 O0 000 O0 0 5 1 1 4 68 0000000000 CCLD BX1 V 6012502 O0 000 O0 0 5 1 1 4 68 0000000000 CVEL BX1 F/HR 6012502 O0 000 O0 0 5 1 1 4 68 0000000000 GR BX1 GAPI 6012502 O0 000 O0 0 5 1 1 4 68 0000000000 NCNT BX1 CPS 6012502 O0 000 O0 0 5 1 1 4 68 0000000000 FCNT BX1 CPS 6012502 O0 000 O0 0 5 1 1 4 68 0000000000 NRAT BX1 6012502 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA DEPT. 13783.018 CCLD.BX1 -999.250 CVEL.BX1 -999.250 GR.BX1 -999.250 NCNT. BX1 -999.250 FCNT.BX1 -999.250 NRAT.BX1 -999.250 DEPT. 12608.217 CCLD.BX1 NCNT. BX1 -999.250 FCNT. BX1 84.792 CVEL.BX1 -999.250 GR.BX1 -999.250 -999.250 NP~T. BX1 -999.250 ** ENE OF DATA ** LIS "z-&~e Verification Listing Schlumberger Alaska Computing Center 10 - FEB '-~9'9 09: 27 PAGE: 26 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION : O01CO1 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.1000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 13764.0 10259.0 MCNL $ LOG HEADER DATA DATE LOGGED: 05-JAN-99 SOFTWARE VERSION: RELOO35E TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 13764.0 TD LOGGER (FT) : 13764.0 TOP LOG INTERVAL (FT) : 10259.0 BOTTOM LOG INTERVAL (FT) : 13770.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MCNL MEMORY CNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) TOOL NUMBER LTTN Al3 10802.0 LIS ~l:~e Verification Listing Schlumberger Alaska Computing Center IO-FEB-~9 09:27 PAGE: 27 LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG): 10802.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NO~IZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGIAYEER FAR COUNT RATE LOW SCALE (CPS): -90 FAR COUNT RATE HIGH SCALE (CPS): 2110 NEAR COUNT RATE LOW SCALE (CPS) '. 0 NEAR COUNT RATE HIGH SCALE (CPS): 32500 TOOL STANDOFF (IN): REMARKS: PUMPED A TOTAL OF 75 BBLS 1% KCL WATER IN'fO BEFORE BASE PASS. PUMPED A TOTAL OF 316 BBLS 1% KCL WATER AND 52 BBLS OF BORAX INTO FORMATION BEFORE LOGGING BORAX PASS #1. PUMPED A TOTAL OF 316 BBLS 1% KCL WATER AND 70 BBL BORAX INTO FORMATION BEFORE LOGGING BORAX PASS #2. PUMPED A TOTAL OF 316 BBLS 1% KCL WATER AND 91 BBLS BORAX UP TO COMPLETION OF BORAX PASS #2. FIELD PICK GOC AT 10424 '. BORAX CHA~EL FOUND FROM 13602' TO 12650' (END OF LOGGING PASS) ~¢HEN COMPARED WITH PRODUCTION LOG RUN ON SAME DAY (1/5/99). THERE IS A LEAK AT 12794' (COOLING EFFECT ON TEMPERATURE LOG). THIS FILE CONTAINS THE RAW DATA FOR BORAX PASS #2. LIS FORMAT DATA LIS '~pe Verification Listing Schlumberger Alaska Computing Center IO-FEBt~J'9 09:27 PAGE: 28 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT ll 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6012502 O0 000 O0 0 6 1 1 4 68 0000000000 CCLD BX2 V 6012502 O0 000 O0 0 6 1 1 4 68 0000000000 CVEL BX2 F/HR 6012502 O0 000 O0 0 6 1 1 4 68 0000000000 GR BX2 CAPI 6012502 O0 000 O0 0 6 1 1 4 68 0000000000 NCNT BX2 CPS 6012502 O0 000 O0 0 6 1 1 4 68 0000000000 FCNT BX2 CPS 6012502 O0 000 O0 0 6 1 1 4 68 0000000000 NRAT BX2 6012502 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. NCNT.BX2 t3787.217 CCLD.BX2 999.250 CVEL.BX2 -999.250 GR.BX2 -999.250 -999.250 FCNT.BX2 999.250 NkAT.BX2 -999.250 DEPT. NCNT. BX2 12630.918 CCLD.BX2 85.000 CVEL.BX2 -999.250 GR.BX2 -999.250 -999.250 FCNT. BX2 -999.250 ~H~AT.BX2 -999.250 ** END OF DATA ** LIS 'r~JJpe Verification Listing Schlumberger Alaska Computing Center lO-FEBh-~-~J99 09:27 PA GE: 29 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION . O01CO1 DATE ' 99/02/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 99/02/10 ORIGIN · FLIC TAPE NAME : 99048 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT . ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/02/10 ORIGIN · FLIC REEL NAME : 99048 CONTINUATION # : PREVIOUS REEL : CO~4ENT : ARCO ALASKA, PRUDHOE BAY, DS 11-38A, API #50-029-22723-01 Sperry-Sun Drilling Services LIS Scan Utility Tue May 18 14:53:49 1999 Reel Header Service name ............. LISTPE Date ..................... 99/05/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/05/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRIIDHOE BAY UNIT m~D/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-90012 D. LABRECQUE M. JOHNSON 11-38A 500292272301 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 18-M3tY-99 MWD RUN 5 MWD RUN 7 AK-MW- 90012 AK-MW- 90012 D. LABRECQUE W. JACKSON M. JOHNSON A. KIRK RECEIVED D ,AY 1999 A~Oi~ &Gas Cons. Comm~ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 9 AK-MW-90012 W. JACKSON A. KIRK MWD RUN 10 AK-MW-90012 W. JACKSON M. JOHNSON MWD RUN 11 AK-MW-90012 W. JACKSON M. JOHNSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 12 A/K-MW-90012 D. LABRECQUE A.KIRK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 23 liN 15E 5115 101 64.20 .00 .00 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 3775.0 7.000 10856.0 4.500 10890.0 3.750 13870.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1,2,3,6 AND 8 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 3. MWD RUNS 4,5,7,9,10,11 AlqD 12 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA PJkY (NGP) . 4. MWD DATA HAS BEEN SHIFTED/CORRECTED USING THE MCNL GR LOGGED ON 01 DECEMBER, 1998 BY SCHLUMBERGER. (KBE: 64.22). 5. DUE TO HIGH ANGLE KICK-OFF OUT OF PARENT WELLBORE, THERE ARE NO TRUE VERTICAL DEPTH (TVD) INTERVALS GREATER THAN 15'. THEREFORE NO TRUE VERTICAL DEPTH (TVD) LOG IS PRESENTED. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13871'MD, 8806'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10779.0 ROP 10805.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ---- BASELINE DEPTH 10779.0 10812.5 10849.0 10864.5 10869.0 10874 0 10875 5 10881 0 10912 5 10916 0 10921 5 10926 5 10938 5 10950 5 10956.5 10963.5 10969.0 10980.5 11001.5 11020.5 11036.0 11053.5 11178.5 11187.5 11201.5 11224.0 11243.5 11257.5 11533.5 11552.5 11556.5 11559.0 11595 5 11599 0 11606 5 11629 0 11634 5 11817 5 11876 0 11890 0 11895 0 11902 0 11990 5 12001 5 12007 5 12028 5 GR 10780 0 10813 5 10850 5 10862 5 10867 0 10872 5 10875 5 10879 5 10909 5 10914 0 10918 0 10925 0 10937 0 10946 5 10954 0 10963 0 10968 5 10978 5 10997 5 11016 0 11032 0 11051.0 11176 0 11183 5 11197 5 11224 5 11240 5 11259 5 11531 5 11552 0 11554 0 11556 5 11593 5 11596 0 11603 5 11624 5 11628 5 11809 5 11862 5 11871 5 11875.5 11882.5 11980.0 11987.0 11993.5 12013.0 STOP DEPTH 13677.5 13874.5 EQUIVALENT UNSHIFTED DEPTH 12036.0 12049.0 12068.0 12098.0 12105.0 12110.0 12115.0 12220.5 12225.5 12230.5 12233.5 12235.5 12468.5 12492.0 12495.5 12584.0 12631.5 12797.0 12847.5 12901.0 12905.5 12929.5 13001.0 13427.0 13430.0 13459.0 13464.5 13470.0 13509.0 13874.5 $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD $ REMARKS: DATA SOURCE TOOL CODE 12019 0 12033 5 12052 5 12080 5 12085 0 12090 0 12096 5 12204 0 12208 5 12213 0 12215 5 12220 5 12454 5 12482.0 12485 5 12576 5 12620 0 12792 5 12842 5 12897 0 12902 0 12928 5 13000 5 13424 0 13425.5 13454.0 13460.0 13465.0 13505.0 13870.5 BIT RUN NO MERGE TOP MERGE BASE 4 10806.0 10890.0 5 10890.0 10905.0 7 10905.0 11525.0 9 11525.0 12115.0 10 12115.0 13002.0 11 13002.0 13270.0 12 13270.0 13871.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10779 13874.5 12326.8 6192 10779 ROP 1.1 2592 85.0324 6140 10805 GR 23.57 220.66 68.6225 5798 10779 Last Reading 13874.5 13874.5 13677.5 First Reading For Entire File .......... 10779 Last Reading For Entire File ........... 13874.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 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 ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10780.0 10863.0 ROP 10806.0 10890.0 $ LOG HEADER DATA DATE LOGGED: 10-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 SPC 5.74 PCD 3.01e MEMORY 10890.0 10806.0 10890.0 .0 .0 TOOL NUMBER NGP SPC 40 3.750 3.8 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .000 -17.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10780 10890 10835 221 10780 GR 23.57 46.42 34.3006 167 10780 ROP 20.86 547.44 34.9204 169 10806 Last Reading 10890 10863 10890 First Reading For Entire File .......... 10780 Last Reading For Entire File ........... 10890 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 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 ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10863.0 10879.5 ROP 10890.5 10905.5 $ LOG HEADER DATA DATE LOGGED: il-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Loggin9 Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 SPC 5.74 PCD 3.01e MEMORY 10905.0 10890.0 10905.0 .0 .0 TOOL NUMBER NGP SPC 40 3.750 3.8 SEAWATER .00 .0 .0 0 .0 .000 .000 .000 .000 29.1 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 5 API 4 1 68 ROP MWD 5 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 10863 10905.5 10884.2 86 GR 36.61 57.86 49.0859 34 ROP 1.1 5.65 2.77387 31 First Reading 10863 10863 10890.5 Last Reading 10905.5 10879.5 10905.5 First Reading For Entire File .......... 10863 Last Reading For Entire File ........... 10905.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 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 ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NIIMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10881.0 11499.5 ROP 10907.0 11524.5 $ LOG HEADER DATA DATE LOGGED: 14-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPC 5.74 PCD 3.01e MEMORY 11525.0 10905.0 11525.0 83.1 93.3 TOOL N-UMBER NGP SPC 140 3.750 3.8 SEAWATER/FLOPRO 8.80 .0 9.0 6.0 .000 .000 .000 .000 17.4 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 ROP MWD 7 FT/H 4 1 68 4 2 8 3 Name Min Max Mean Nsam DEPT 10881 11524.5 11202.8 1288 GR 36.35 220.66 88.6941 1238 ROP 7.73 147.4 58.844 1236 First Last Reading Reading 10881 11524.5 10881 11499.5 10907 11524.5 First Reading For Entire File .......... 10881 Last Reading For Entire File ........... 11524.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................. LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P~AW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11500.0 12082.5 ROP 11526.5 12114.5 $ LOG HEADER DATA DATE LOGGED: 18-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: MSC 1.32 SPC 5.74 PCD 3.01e DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 12115.0 11525.0 12115.0 84.1 96.5 TOOL NUMBER NGP SPC 40 3.750 3.8 FLO-PRO 8.80 .0 8.0 8.3 .000 .000 .000 .000 20.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 API 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 11500 12114.5 11807.2 1230 GR 30.69 181.18 77.9575 1166 ROP 4.48 2011.23 63.6598 1177 First Reading 11500 11500 11526.5 Last Reading 12114.5 12082.5 12114.5 First Reading For Entire File .......... 11500 Last Reading For Entire File ........... 12114.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12085.0 12972.0 ROP 12116 . 0 13002 . 0 $ LOG HEADER DATA DATE LOGGED: 22 -NOV- 98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: SPC 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY PCD 3.01e TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 13002.0 12115.0 13002.0 83.4 91.8 TOOL NUMBER NGP SPC 40 3.750 3.8 FLO-PRO 8.90 .0 9.0 5.1 .000 .000 .000 .000 18.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 API 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 Name Min Max Mean DEPT 12085 13002 12543.5 GR 30.46 124.64 48.5097 ROP 19.27 2592 111.169 Nsam 1835 1775 1773 First Reading 12085 12085 12116 Last Reading 13002 12972 13002 First Reading For Entire File .......... 12085 Last Reading For Entire File ........... 13002 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NI/MBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12970.0 13238.5 ROP 13000.0 13269.5 $ LOG HEADER DATA DATE LOGGED: 24 -NOV- 98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWN-HOLE SOFTWARE VERSION: SPC 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 13270.0 PCD 3.01e 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 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 13002.0 13270.0 84.7 91.4 TOOL NUMBER NGP SPC 140 3.750 3.8 FLO-PRO 8.80 .0 9.5 5.1 .000 .000 .000 .000 21.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 API 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 12970 13269.5 13119.8 600 GR 42.8 212.16 72.4073 538 ROP 15.69 609.48 67.4128 540 First Reading 12970 12970 13000 Last Reading 13269.5 13238.5 13269.5 First Reading For Entire File .......... 12970 Last Reading For Entire File ........... 13269.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE N-UMBER: 8 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13242.5 13673.5 ROP 13270.0 13870.5 $ LOG HEADER DATA DATE LOGGED: 27-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: SPC 5.74 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 13871.0 TOP LOG INTERVAL (FT) : 13270.0 PCD 3.01e 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 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 13871.0 85.6 95.1 TOOL NUMBER NGP SPC 217 3.750 3.8 FLO-PRO 8.80 55.0 8.5 8.8 .000 .000 .000 .000 23.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 API 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 13242.5 13870.5 13556.5 1257 GR 33.36 112.08 71.4042 863 ROP 13.65 2268 115.6 1202 First Reading 13242.5 13242.5 13270 Last Reading 13870.5 13673.5 13870.5 First Reading For Entire File .......... 13242.5 Last Reading For Entire File ........... 13870.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/05/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/05/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... IINKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/05/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File