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198-010
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ESP Swap Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,125 feet 12,792 (Fill)feet true vertical 7,454 feet N/A feet Effective Depth measured 12,792 feet 2,975 feet true vertical 7,148 feet 2,723 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 1/4" Stainless Steel 2,975' 2,723' Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / L-80 / EUE 8rd 12,574' 6,942' Packers and SSSV (type, measured and true vertical depth)7" x 2-7/8" D&L ESP Ret.N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A Ryan Lewis 323-240 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ryan.lewis@hilcorp.com 303-906-5178 20 Size 112' 4,516' 0 000 Water-BblOil-Bbl Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 107 Gas-Mcf 954 3408.9 341 MILNE PT UNIT L-40 Plugs Junk measured Length measured true vertical Packer MD measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-010 50-029-22855-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509 & ADL0388235 MILNE POINT / KUPARUK RIVER OIL Collapse N/A 3,090psi 5,410psi Casing Conductor 13,007' 7,560'Surface Production 20" 9-5/8" 7" 74' 7,524' 112' 5,750psi 7,240psi13,040' 7,375' Burst N/A Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:41 pm, Dec 01, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533) Date: 2023.12.01 15:23:59 - 09'00' David Haakinson (3533) RBDMS JSB 120523 WCB 1-21-2025 DSR-12/5/23 _____________________________________________________________________________________ Revised By TDF: 11/27/2023 SCHEMATIC Milne Point Unit Well: MPU L-40 Last Completed: 11/2/2023 PTD: 198-010 TD =13,125’ (MD) / TD = 7,454’(TVD) 20” RA Tags @ 12,389’ and 12,428’ Orig. KB Elev.: 50.6’ / GL Elev.: 17.55’ (Nabors 27E) Nabors 27E / RT to Tbg Spool= 33.0’ 7” 7, 8 & 9 9 13 9-5/8” 1 6 Min ID = 2.205”@ 12,432’ KUP B-Silts PBTD =12,957’(MD) / PBTD = 7,298’(TVD) 11 & 12 KUP B Sands 10 KUP A3/A2 Sands 2 4 5 14 Howco ES Cementer @ 2,139’ 3 1/4” Control Tube CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,560’ 7" Production 26 / L-80 / BTCM 6.276 Surface 13,040’ TUBING DETAIL 1/4” Control Tube SS N/A Surface 2,975’ 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 12,574’ JEWELRY DETAIL No Depth Item GLM Detail: Patco 2-7/8” x 1” 1 168’GLM #3: BK-DGLV Installed 2 2,975’ 7” x 2-7/8” D&L ESP Retrievable PKR w/ dual WFT PVV 3 3,038’GLM #2: BK-DGLV Installed 4 12,345’GLM #1: BK-DGLV Installed 5 12,432’ 2-7/8” XN-Nipple w/ RHC-M Installed (Min ID = 2.205” No-go) 6 12,473.7’ Discharge Head: Bolt On PMP 400 7 12,474’ Pump #3: PMP 400PMSSD 126 FLEX7 ER 8 12,496 Pump #2: PMP 400PMSSD 126 FLEX7 ER 9 12,518’ Pump #1: PMP 400PMSSD 126 FLEX7 ER 10 12,540’ Gas Separator: 400 GSTHVV 11 12,544’ Upper Tandem Seal: GSB3DB FER HL SSCV SB/SB CL-5E 12 12,551’ Lower Tandem Seal: GSB3DB FER HL SSCV SB/SB CL-5E 13 12,558’ Motor: 562 XP 150 Hp / 2,420 V /38 A - 06R 6CRC 10R 14 12,569’ Zenith Motor Gauge w/ Centalizer – Btm @ 12,574’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup B Silt 12,643’ 12,663’ 7,004’ 7,022’ 20 10/30/2023 Open Kuparuk B 12,656’ 12,664’ 7,025’ 7,032’ 8 2/24/2009 Open Kuparuk A3/A2 12,705’ 12,725’ 7,069’ 7,087’ 20 5/10/1998 Open 12,725’ 12,745’ 7,087’ 7,105’ 20 8/8/2004 Open 12,746’ 12,754’ 7,097’ 7,104’ 8 10/29/2023 Open 12,762’ 12,782’ 7,120’ 7,139’ 20 2/24/2009 Open Ref Log: GR / CCL dated 5/8/1998 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8"650 sx PF ‘E’, 750 sx Class ‘G’ in 12-1/4” Hole plus 1,200 sx PF ‘E’ through ES cementer 7” 250 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle = 71 deg. @ 10,130’ Max Hole Angle through perforations = 25 deg. TREE & WELLHEAD Tree 2-9/16” x 11” – 5M CIW Wellhead 11” 5M FMC Gen 5a, w/ 7-1/16” FMC Tbg. Hngr., 3” LH Acme top and 2-7/8”btm., 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-22855-00-00 Drilled and Cased by Nabors 27E – 3/6/1998 Completed by Nabors 4ES – 5/15/1998 ESP Change-out by Nabors 4ES – 11/24/2000, 8/9/2004, 9/18/2005 ESP Change-out by Nabors 3S – 2/18/2006 and 2/28/2009 ESP Change-out by Doyon 16 – 1/18/2012 ESP Change-out by ASR – 11/2/2023 STIMULATION DETAIL 5/11/1998 - Frac’d w/ 55,480# of 16/20 Carbolite (w/ChemFlow) + 118,385# CarboLite LTC behind pipe Well Name Rig API Number Well Permit Number Start Date End Date MP L-40 ASR 50-029-22855-00-00 198-010 10/21/2023 11/3/2023 10/20/2023 - Friday No operations to report. 10/18/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/19/2023 - Thursday No operations to report. Cont. RIH w/ 7'' casing scraper BHA on 3-1/2" 10.37# DP to 12,093'. Pump 20 BBLS of corrossion inhibitor in the drill string. POOH with the 7'' Casing scraper form 12,093' - 1,284' . Observed diesel / crude flow out of Drill pipe. Stab TIW & close annular. Drill pipe out of balance. Clean up crude & diesel on rig floor. Fluid escaped rig floor containment, eviormental assessed 8 gallons of hydrocarbon mist on pad. Cont. to clean up hydrocarbons, Report of BOPE use sent to AOGCC. PHASE 2 CONDITIONS, resume work. Complete rig acceptance checklist. Accept rig at 03:00. Test BOPE as per appoved sundry. AOGCC waived witness to test. Test BOPE t/ 250 psi low & 3500 psi for 5/5 charted mins. Pull hanger & secure ESP cable. Begin POOH. 10/21/2023 - Saturday Cont. POOH lay down 2-7/8" 6.5# L-80 EUE TBG. Clean & Clear rig floor. NORM Inspect the 2 7/8'' tubing and jewelry laid down. Passed. Unload 2-7/8" tubing from the shed. Load and strap 3-1/2" drill pipe, 4 3/4'' drill collars and 7'' casing scraper BHA. Make up BHA. Trip in hole picking up singles of 3-1/2" DP. 10/24/2023 - Tuesday 10/22/2023 - Sunday Completed the BOP test. AOGCC waived witness of the test. Rig down test equipment. Make up landing joint. BOLDS, pull tubing hanger to the rig floor with 75K upweight. Well took 5 BBLS to fill. Terminate ESP cable - POOH lay down 2-7/8 Tubing. 10/23/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP L-40 ASR 50-029-22855-00-00 198-010 10/21/2023 11/3/2023 Cont. RIH w/ 2-7/8", 6.5#, L, EUE - ESP Completion F/ 6,211 - T/ 7,895' while pumping single displacement and filling hole/monitoring during 1000' Cable tests. Make cable-to-cable splice, continue RIH to Packer ~3,000'. CONT. RIH @ 60 FPM W/ TEST PACKER ON 3-1/2" DRILL PIPE WHILE PUMPING SINGLE DISPLACEMENT TO set the test packer at 12010' DPM. Fill the IA with 6 BBLS, and pressure test IA to 1800 PSO - 30 minutes on a chart, Good test. Release packer. Monitor well - static. POOH with the 7'' test packer from 12,010' to 2,480' pumping single displacement. 10/28/2023 - Saturday CONTINUE VARIOUS MAINT. PROJECTS WHILE STBY FOR E-LINE. RU E-LINE PCE & TEST TO 3500 PSI. PERFORATE B-SILT INTERVAL 12,643' - 12,663' ELM. RD E-LINE, SWAP HANDLING EQUIPMENT FOR ESP RUN. SPOT IN SPOOLERS, COMPRESSORS, GENERATORS. LOAD ESP & PACKER IN PIPE SHED. 10/31/2023 - Tuesday 10/29/2023 - Sunday Continue POOH with 7'' test packer from 2,480'. LD Test Packer - all intact. ND Flow Spool, Bird Bath. NU Shooting Flange, QTS. RU E-Line. Attempt to pressure test PCE, Dual Pack-Off unable to hold more than 2800psi. LD PCE, RU w/ Grease Head. Obtain 3500psi pressure test, Remove Test Plug. MU Guns & RIH to 12,757.9' ELMD, log on depth w/ +33' Depth Shift. Correlate log. Perforate Kuparuk A2 interval 12,745.9' - 12,753.9'. Log OOH, monitor well - static. POOH w/ E-Line. Operator indicated to Rig crew tools were in Head Catcher, shut Blind Rams. Estabish well parameters 24 BBL/HR losses. Blind Rams were closed w/ E- Line tools 237' in hole. Open Blinds and POOH w/ Tools - All equipment accounted for. RD E-Line for the night. Report of BOPE use sent to AOGCC. 10/30/2023 - Monday 10/27/2023 - Friday Test BOPE 250/3,500 - Annular 250/3,000. 1 F/P due to Blind Rams not sealing. C/O Elements - retested good. RIH w/ YJOFS 7" AS1X Test Packer on 3-1/2" DP - 60 FPM Pumping single displacement to 4,370' MD. 10/25/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Continue to clean up hydrocarbons on rig & pad. Circulate 10.5 PPG Brine at 1284' to displace crude/diesel out of pipe. Well static, and on a vaccuum, IA & TBG. TIH with 3-1/2'' DP & 7'' scraper BHA from 1,284' - 11,210'. 10/26/2023 - Thursday Contimue TIH with 3-1/2'' DP & 7'' scraper BHA from 11,210' - 12,068'. Circulate 55 BBLS 10.7 ppg NaCl / NaBr & monitor well. Continue TIH to 12092' DPM. Continue circulate 10.7 PPG Brine to balance the well. Monitor well, observed IA & TBG on a slight vacuum. Blow down lines, and POOH with 7'' casing scraper, at 60' / minute F/ 10,092' to 575' MD . Well Name Rig API Number Well Permit Number Start Date End Date MPU L-40 ASR #1 50-029-22855-00-00 198-010 10/21/2023 11/3/2023 11/3/2023 - Friday Take on fresh water and clean pits, vac out pits. Remove Spools and Tong Rack from Rig Floor. Lift off Rig Floor from Cellar. Install production Tree, torque & test - good, pull BPV. Baker test ESP system - good. PVV line test - good. RIG RELEASED @ 18:00. Slickline: WELL SHUT-IN ON ARRIVAL. PULL BALL & ROD FROM RHC IN XN-NIPPLE AT 12,431' MD. PULL BK-DGLV FROM ST#3 (168' md) AND SET BEK-DPSOV. PULL 2-7/8" RHC FROM XN-NIPPLE AT 12,431' MD. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. 11/1/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Cont. RIH w/ 2-7/8", 6.5#, L, EUE - ESP Completion F/ 6,211' while pumping single displacement and filling hole/monitoring during 1000' Cable tests. AT 7,895' Make Reel-to-Reel cable splice , continue RIH to Packer at 9,604' (~3,000' from surface). Feed ESP Cable through Packer. Purge and test PVV to 4500 psi - Good Test. Continue RIH T/ 11,131' MD. 11/2/2023 - Thursday CONT RIH W/ 2-7/8", 6.5#, L, EUE ESP COMPLETION @ 60FPM, PUMPING SINGLE DISPLACEMENT F/ 11,131' MD. INSTALL TIW IN LANDING JOINT, RU KELLY HOSE. TERMINATE ESP AND PVV LINES IN TBG HANGER. LAND HANGER, RILDS. DROP B&R, PRESS. UP ON TBG TO 3800 PSI & SET PACKER. PRESSURE UP ON IA 50 PSI/MIN UNTIL 1,600 PSI HOLD FOR 30 MIN CHARTED. LOST 75 PSI THE FIRST 15 MIN AND 25 PSI THE SECOND 15 MIN. GOOD TEST. INSTALL BPV. RD ASR-1 No operations to report. No operations to report. 11/4/2023 - Saturday No operations to report. 11/7/2023 - Tuesday 11/5/2023 - Sunday No operations to report. 11/6/2023 - Monday CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Lewis To:DOA AOGCC Prudhoe Bay Subject:PTD198-010 : MPU L-40 BOPE use Sundry 323-240 Date:Wednesday, October 25, 2023 3:19:45 PM Attachments:MPL-40 Reporting BOPE Use.docx Some people who received this message don't often get email from ryan.lewis@hilcorp.com. Learn why this isimportant If you have any questions please let me know. Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Milne Point Unit L-40 PTD 1980100 10/24/23, 22:31 MPU L-40/MPU L-Pad/PTD 198-010 ASR-1 Hilcorp Alaska Ryan Lewis, Operations Engineer, 303-906-5178 Summary of events: We moved on this well, performed BOP test, and pulled the ESP from 12,600’ to surface. RIH with a 7” CSG scraper to 12,000’. While tripping out of the hole after running 7” CSG scraper at 22:31 at a depth of 1,284’. The well was filled through the hole fill line on the backside. While the joint was broken out, it was noticed that the pipe connection was spraying fluid. After looking closer it was determined that the pipe was filling or full. The driller proceeded to break out the pipe & rack it off to the side. Fluid escaped out of the joint (broke out wet). The TIW was stabbed & shut in. The annular was closed. The drill pipe had 50 psi on it initially then reduced to 25 psi & the IA was 0. The string had diesel/crude trace inside the pipe & was thought to be as a kick and treated as such. Before starting our circulation, the well shut in with 45 psi on both the tubing and annulus. We circulated 2x the hole volume at 1,284’ (100 BBLs), the fluid weight that returned was from a 9.8 ppg and ended the circulation at 10.3 ppg. We shut in the well, monitored for 30 minutes and the tubing and annulus are at 0 psi. Our BOPE used was the annular and TIW valve that were last tested on 10/22/23. The tubing started flowing so we installed the TIW valve and we closed the Annular as a precaution when fluid came out the tubing. After being shut in the annulus built up to 45 psi indicating we had most likely swabbed something in with the 7” scraper while tripping out of the hole. Plan Forward: Trip back in to bottom from 1,284’ to 12,000’ MD. Circulate a full column of 10.6 ppg around the tubing and annulus. Trip out of the hole with the 7” CSG scraper to surface. Retest our Annular and TIW to 3,000 psi for 5 min and we plan to test the rest of the BOPE stack since our current BOPE test expires 10/29/23 and we will not be finished by then. Then we will proceed forward with the 7” packer run and casing test. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 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: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230416 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPB-15 50029213740000 185121 5/16/2021 READ Caliper Survey MPC-02 50029208660000 182194 4/26/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/17/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/21/2023 READ Caliper Survey MPL-40 50029228550000 198010 4/18/2023 READ Caliper Survey PBU D-03A 50029200570100 200134 5/28/2023 READ MRCBL PBU L-212 50029232520000 205030 4/14/2023 READ Injection Profile PBU S-210 50029236300000 219057 4/17/2023 READ Injection Profile PBU V-212 50029232790000 205150 5/13/2023 READ Injection Profile Please include current contact information if different from above. T37721 T37722 T37723 T37723 T37724 T37725 T37726 T37727 T37728 MPL-40 50029228550000 198010 4/18/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.12 14:32:41 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,125'12,792' Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9-5/8" 7" 7,524' 13,007' Perforation Depth MD (ft): MD N/A 5,750psi 7,240psi 4,516' 7,375' 7,560' 13,040' Length Size Proposed Pools: 112' 112' TVD Burst PRESENT WELL CONDITION SUMMARY 7,454' 12,792' 7,148' 3,093 12,958' 74' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355023 & ADL0388235 198-010 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22855-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT L-40 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5# / L-80 / EUE 8rd 12,586' 5/10/2023 N/A and N/A N/A and N/A See Schematic See Schematic 2-7/8" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-240 By Kayla Junke at 8:54 am, Apr 20, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.19 19:04:41 -08'00' David Haakinson (3533) MDG 4/20/2023 10-404 ADL0025509 DSR-4/20/23MGR24MAY23 3,093 BOPE test to 3500 psi. Annular to 3000 psi. GCW 05/25/23JLC 5/25/2023 05/25/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.25 11:06:58 -05'00' RBDMS JSB 052523 Well: MPL-40 PTD: 198-010 API: 50-029-22855-00-00 Well Name:MPU L-40 API Number:50-029-22855-00-00 Current Status:Oil Well Pad:L-Pad Estimated Start Date:5/10/2023 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:198-010 First Call Engineer:Scott Pessetto (907) 564-4373 (801) 822-2203 Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number:Job Type:ESP Repair Current Bottom Hole Pressure: 3,784 psi @ 6,907’ TVD SBHP 4/13/2023 10.5 PPGE Maximum Expected BHP:3,784 psi @ 6,907’ TVD MPSP:3,093 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU L-40 was drilled in March 1998, fracture stimulated and completed in May as a Kuparuk River producer. ESP installation history: May 1998 (initial), November 2000, August 2004, September 2005, February 2006, February 2009, and January 2012. An ESP swap is planned to restore MPU L-40 to production. Notes Regarding Wellbore Condition x The 7” production casing was tested to 2670 psi / 12,505’ MD on January 15, 2012. x Supporting injector F-82 was shut-in February 2023. x A separate request has been submitted to the AOGCC to free flow the well to production to lower reservoir pressure prior to working the well over. Objective: Pull 2-7/8” ESP completion, perforate B-1 silt & Kup A sands and run new 2-7/8” ESP completion. Pre-Rig Procedure (Non-sundried Work): 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 10.7 brine down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. 7. RD Little Red Services and reverse out skid. 8. Set BPV. 9. ND Tree. NU BOPE. ,p 3,093 psi Well: MPL-40 PTD: 198-010 API: 50-029-22855-00-00 Brief RWO Procedure (Approved Sundry Required): 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If required, kill well w/ 10.7 ppg brine prior to setting CTS. 12. Test BOPE to 250 psi Low/ 3,500 psi High, annular to 250 psi Low/ 3,000 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Bleed any pressure off casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well w/ 10.7 ppg brine as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 14. Call out Centrilift for ESP pull. 15. RU spooler to handle ESP cable. 16. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2012 ESP swap was 115K lbs. (Doyon 16 block weight not recorded) b. Expected PU weight is 68K lbs. 17. Confirm hanger free, lay down tubing hanger. 18. POOH and lay down the 2-7/8” tubing. Lay down ESP. a. Note any sand or scale inside or on the outside of the ESP on the morning report. b. Look for over-torqued connections from previous tubing runs. c. Clamp totals: i. Cannon Clamps: 210 ii. Half Cannon Clamps at ADV: 2 iii. Protectolizers: 5 iv. Flat Guards: 3 19. RIH with casing scraper to 12,000’ MD. Reciprocate casing scraper across test packer setting interval. 20. POOH with casing scraper, reciprocate over ESP packer set depth on trip out of hole. 21. PU 7” test packer and RIH to 12,000’ MD. 22. Perform 7” casing test to 1,800 psi for 30 minutes. 23. POOH with 7” test packer. 24. MIRU E-line and pressure test PCE to 250 psi low / 3,500 psi high. 25. RIH with 3-3/8 HC gun assembly and perforate B-silt from 12,643’ - 12,663’ MD and Kup A2 from 12,746’ – 12,754’ MD. a. Run in two runs or run two guns on switches. b. Correlate to log provided by John Salsbury (Cell# 907-350-1088) / 3,500 psi H Well: MPL-40 PTD: 198-010 API: 50-029-22855-00-00 c. Inclination at perf depths 27°. Max inclination 70°. 26. POOH and RDMO E-line. 27. PU new ESP and RIH on 2-7/8” tubing. Set base of ESP at ± 12,584’ MD. a. Check electrical continuity every 1,000’. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint. d. Photograph vent packer prior to running in hole. Nom. (OD)Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 ~12,584’ MD 4.5 2 Intake Sensor 30 5.62 34 Motor 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 5.2 8 Gas Separator 52 5.38 ~57 Pump 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” XN-nipple 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~9,360 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” X-nipple with RHC profile 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 30 Packer, Viking ESP Retr. Dual Vent ~3,000 MD 2-7/8" ~2,650 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 ~150 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 28. PU and MU Viking packer. Verify that there are four (4) setting shear pins and confirm with OE number of release shear pins. Well: MPL-40 PTD: 198-010 API: 50-029-22855-00-00 a. Modeled PUW of completion is 68 kip. Target release pins to shear at 20,000 pounds overpull. 29. Terminate the ESP cable and make up the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 30. Make up the control line to the dual vent valves. Pressure up on the control line to 5,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in the daily report). Bleed the pressure to 500 psi and maintain 500 psi while running in hole. a. Periodically confirm control line is maintaining 500 psi. 31. Continue running ESP completion per plan. 32. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator. MU the control line to the tubing hanger and dummy off any additional control line ports if present. 33. Land tubing hanger, avoiding any damage to ESP cable or control line. RILDS. Lay down landing joint. Note PU and SO weights on tally and in daily report. 34. Drop ball and rod. 35. Pressure up on tubing to 4,000 psi and hold for 15 minutes to set the ESP packer. 36. Bleed tubing to 0 psi. 37. Pressure up on tubing to 4,000 psi and hold for 5 more minutes and then bleed to 0 psi. 38. Bleed packer control line to 0 psi, closing packer vent valves. 39. Slowly pressure up IA at 50 psi/min to 1,500 psi and hold for 30 minutes. Chart test. 40. Lay down landing joint. 41. Set BPV. 42. RDMO ASR Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline 1. Retrieve ball and rod, pull RHC plug 2. Set screen OV in top GLM Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By TDF: 4/19/2023 SCHEMATIC Milne Point Unit Well: MPU L-40 Last Completed: 1/18/2012 PTD: 198-010 TD =13,125’ (MD) / TD = 7,454’(TVD) 20” RA Tags @ 12,389’ and 12,428’ Orig. KB Elev.: 50.6’ / GL Elev.: 17.55’ (Nabors 27E) Nabors 27E/ RT toTbgSpool= 33.0’ 7” 6 8 11 13 9 9-5/8” 1 5 Min ID = 2.25”@ 12,503’ PBTD =12,957’(MD) / PBTD = 7,298’(TVD) 9 & 10 KUPBSands 7 KUP A3/A2 Sands 2 3 4 12 Howco ES Cementer @ 2,139’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,560’ 7" Production 26 / L-80 / BTCM 6.276 Surface 13,040’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 12,586’ JEWELRY DETAIL No Depth Item GLM Detail: Camco KBMM 2-7/8” x 1” 1 143’GLM #3: Side pocket, w/DPSOV (Set 1/18/2012) 2 201 GLM #2: Side pocket, w/ Dummy (Set 1/18/2012) 3 12,360’GLM #1: Side pocket, w/ Dummy (Set 1/18/2012) 4 12,503’ 2-7/8” XN-Nipple (Min ID = 2.25” No-go) 5 12,518’ Auto-Diverter Valve 6 12,527’ Discharge Head GPDIS 7 12,528’ Pump 137-P17 SXD 8 12,547’ Centrilift Gas Separator GRSFTXARH6 9 12,552’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 10 12,559’ Lower Tandem Seal: GSB3DBLT SB/SB PFSA 11 12,565’Centrilift Motor CL-6 KMH, 190 HP, 2415 VT, 48 Amp, rerated to165 HP, 2230 VT / 43 amp 12 12,582’ WellLift MGU Sensor (TVD – 6,973’) 13 12,584’ 6 Fin Centralizer – Bottom @ 12,586’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk B 12,656’ 12,664’ 7,025’ 7,032’ 8 2/24/2009 Open Kuparuk A3/A2 12,705’ 12,725’ 7,069’ 7,087’ 20 5/10/1998 Open 12,725’ 12,745’ 7,087’ 7,105’ 20 8/8/2004 Open 12,762’ 12,782’ 7,120’ 7,139’ 20 2/24/2009 Open Ref Log: GR / CCL dated 5/8/1998 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8"650 sx PF ‘E’, 750 sx Class ‘G’ in 12-1/4” Hole plus 1,200 sx PF ‘E’ through ES cementer 7” 250 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle = 71 deg. @ 10,130’ Max Hole Angle through perforations = 25 deg. TREE & WELLHEAD Tree 2-9/16” x 11” – 5M CIW Wellhead 11” 5M FMC Gen 5a, w/ 7-1/16” FMC Tbg. Hngr., 3” LH Acme top and 2-7/8”btm., 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-22855-00-00 Drilled and Cased by Nabors 27E – 3/6/1998 Completed by Nabors 4ES – 5/15/1998 ESP Change-out by Nabors 4ES – 11/24/2000, 8/9/2004, 9/18/2005 ESP Change-out by Nabors 3S – 2/18/2006 and 2/28/2009 ESP Change-out by Doyon 16 – 1/18/2012 STIMULATION DETAIL 5/11/1998 - Frac’d w/ 55,480# of 16/20 Carbolite (w/ChemFlow) + 118,385# CarboLite LTC behind pipe _____________________________________________________________________________________ Revised By TDF: 4/19/2023 PROPOSED Milne Point Unit Well: MPU L-40 Last Completed: 1/18/2012 PTD: 198-010 TD = 13,125’ (MD) / TD = 7,454’(TVD) 20” RA Tags @ 12,389’ and 12,428’ Orig. KB Elev.: 50.6’ / GL Elev.: 17.55’ (Nabors 27E) Nabors 27E / RT to Tbg Spool= 33.0’ 7” 6 11 9 9-5/8” 1 5 Min ID = 2.25”@ 12,503’ KUP B-Silts PBTD =12,957’(MD) / PBTD = 7,298’(TVD) 8, 9 & 10 KUP B Sands 7 KUP A3/A2 Sands 2 3 4 12 Howco ES Cementer @ 2,139’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 112' 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 7,560’ 7" Production 26 / L-80 / BTCM 6.276 Surface 13,040’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±12,586’ JEWELRY DETAIL No Depth Item GLM Detail: Camco KBMM 2-7/8” x 1” 1 ±143’GLM #2: Side pocket, w/DPSOV 2 ±2,500’ 7” x 2-7/8” Vented Packer 3 ±12,360’GLM #1: Side pocket, w/ Dummy 4 ±12,503’ 2-7/8” XN-Nipple (Min ID = 2.25” No-go) 5 ±12,527’ Discharge Head 6 ±12,528’ Pump 7 ±12,547’ Gas Separator 8 ±12,552’ Upper Tandem Seal 9 ±12,559’ Lower Tandem Seal 10 ±12,565’ Motor 11 ±12,582’ Sensor 12 ±12,584’ Centralizer – Btm @ ±12,586’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup B Silt ±12,643’ ±12,663’ ±7,004’ ±7,022’ 20 Future Proposed Kuparuk B 12,656’ 12,664’ 7,025’ 7,032’ 8 2/24/2009 Open Kuparuk A3/A2 12,705’ 12,725’ 7,069’ 7,087’ 20 5/10/1998 Open 12,725’ 12,745’ 7,087’ 7,105’ 20 8/8/2004 Open ±12,746’ ±12,754’ ±7,097’ ±7,104’ 8 Future Proposed 12,762’ 12,782’ 7,120’ 7,139’ 20 2/24/2009 Open Ref Log: GR / CCL dated 5/8/1998 OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in 24” Hole 9-5/8"650 sx PF ‘E’, 750 sx Class ‘G’ in 12-1/4” Hole plus 1,200 sx PF ‘E’ through ES cementer 7” 250 sx Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ Max Hole Angle = 71 deg. @ 10,130’ Max Hole Angle through perforations = 25 deg. TREE & WELLHEAD Tree 2-9/16” x 11” – 5M CIW Wellhead 11” 5M FMC Gen 5a, w/ 7-1/16” FMC Tbg. Hngr., 3” LH Acme top and 2-7/8”btm., 2-1/2” CIW “H” BPV profile GENERAL WELL INFO API: 50-029-22855-00-00 Drilled and Cased by Nabors 27E – 3/6/1998 Completed by Nabors 4ES – 5/15/1998 ESP Change-out by Nabors 4ES – 11/24/2000, 8/9/2004, 9/18/2005 ESP Change-out by Nabors 3S – 2/18/2006 and 2/28/2009 ESP Change-out by Doyon 16 – 1/18/2012 STIMULATION DETAIL 5/11/1998 - Frac’d w/ 55,480# of 16/20 Carbolite (w/ChemFlow) + 118,385# CarboLite LTC behind pipe Updated 6/21/18 11” BOPE 11'͛-5000 11" - 5000 2-7/8" x 5" VBR Blind 11'͛- 5000 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManual Stripping Head ManualManual Milne Point ASR 11” BOP w/ Jacks 05/17/2017 Milne Point ASR 11” BOP (Triple) 5/24/2022 2-3/8" Pipe Ram tiOF Tit gwI/7 7 s. THE STATE Alaska Oil and Gas frt , of T TA Conservation Commission ist2 333 West Seventh Avenue GOVERNOR BILL WALKERAnchorage, Alaska 99501-3572 • oI ^ rh'P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager scANNFsi JA i\ 0 8 )11'i, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU L-40 Permit to Drill Number: 198-010 Sundry Number: 317-549 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 10-Cer Hollis S. French Chair DATED this/b day of November, 2017. • • RECEIVED NOV• 2 0 ?017 Orr r/1a,/ ) STATE OF ALASKA AOGCC c ALASKA OIL AND GAS CONSERVATION COMMISSION �r APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Repair Well ❑� Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑✓ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Cl Other: ESP Change-out El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory El Development Q- 198-010 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22855-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No El / MILNE PT UNIT L-40 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0355023/ADL0388235 MILNE POINT/KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,125' ' 7,454' . 12,792'. 7,148'' 1,758 12,958' 12,792' Casing Length Size MD TVD Burst Collapse Conductor 74' 20" 112' 112' N/A N/A Surface 7,524' 9-5/8" 7,560' 4,516' 5,750psi 3,090psi Production 13,007' 7" 13,040' 7,375' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ✓ See Schematic 2-7/8" 6.5#/L-80/EUE 8rd 12,586' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A and N/A N/A and N/A 12.Attachments: Proposal Summary ❑� Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑r Exploratory ❑ Stratigraphic❑ Development❑� - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/8/2017 OIL ❑✓ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS El WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: pChan fl hllCOrp.COm Contact Phone: 777-8333 Authorized Signature Date: 11/20/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i7. 5.419 Plug Integrity ❑ rr�BOP Test 11 Mechanical Integrity Test ❑ Location Clearance CI Other: ` —2.560 fi 5 4 �-J f�w- 3 Post Initial Injection MIT Req'd? Yes ❑ No ❑ E r, "t' Spacing Exception Required? Yes ❑ No ' /Subsequent Form Required: 6 c./G ` `"`� (-- L- ;.. r i ,.!? APPROVED BY Approved by: aXt. COMMISSIONER THE COMMISSION Date: tl 30 l *Pm "AP ,--7/*//i7 / //..-zy./7 ORIGINAL Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate i i Well Prognosis Well: MPU L-40 Hilcorp aka,LLIDate:11/17/2017 Well Name: MPU L-40 API Number: 50-029-22855-00 Current Status: Oil Well Pad: L-Pad Estimated Start Date: December 8th, 2017 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 198-010 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Number: t." 4: 49b ;" A Current Bottom Hole Pressure: 2,450 psi @ 6,918' TVD (ESP Gauge 11/16/2017/6.81 ppg EMW) Maximum Expected BHP: 2,450 psi @ 6,918' TVD (No new perfs being added) i MPSP: 1,758 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU L-40 was drilled in March 1998, fracture stimulated and completed in May as a Kuparuk River producer. ESP installation history: May 1998 (initial), November 2000,August 2004,September 2005, February 2006, February 2009, and January 2012. Well has a suspected ESP failure. Notes Regarding Wellbore Condition • The 7" production casing was tested to 2670 psi/12,505' MD on January 15, 2012.of • CO 390A: Hilcorp Alaska respectfully requests that a packer not be required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW. r iG. Objective: ` Replace failed ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. • 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house.Spot mud boat. • Well Prognosis Well: MPU 1-40 Hiksorp Alaska,LL, Date:11/17/2017 Brief RWO Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to,2 c nsi 2.500.1si High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. F a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. F'G b. Notify AOGCC 24 hours in advance of BOP test. lc 5' c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure k✓, c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2012 ESP swap was 120K lbs. (block weight not noted) b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Number all joints. Tubing will be re-used as noted. Lay down ESP. a. Replace bad joints of tubing as necessary and note on tally new tubing run. b. Note any sand or scale inside or on the outside of the ESP on the morning report. c. Look for over-torqued connections from previous tubing runs. 18. PU new ESP and RIH on 2-7/8" tubing. Set base of ESP at± 12,584' MD. • • Well Prognosis Well: MPU 1-40 Ililcorp Alaska,LL Date:11/17/2017 a. Upper GLM @ ± 143' MD w/SO b. Lower GLM @ ± 12,360' MD w/DGLV c. 2-7/8" XN (2.205" No-Go) @ ±12,502' MD d. Base of ESP centralizer @ ± 12,584' MD 19. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 20. Set BPV. Post-Rig Procedure: 21. RD mud boat. RD BOPE house. Move to next well location. 22. RU crane. ND BOPE. 23. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 24. RD crane. Move 500 bbl returns tank and rig mats to next well location. 25. Replace gauge(s) if removed. 26. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Existing Tree/Wellhead 5. Blank RWO MOC Form • Tree: 2 9/16" - 5M CI* MPU L-A 0 OriiB Elev. = 50.6' (N 27E) Wellhead: 11" 5M FMC Gen. 5a w/ �F Orig. GL Elev. = 17.55' 7 1/16" FMC Tbg. Hng. , 3" LH RT To Tbg. Spool = 33.0' (N 27E) Acme top and 2-7/8" btm., 2.5" CIW "H" BPV profile II 20" 91.1 ppf, H-40 112' 1111,44-.%L..1...1,11 Camco 2-7/8" x1" 143' KOP @ 300' sidepocket KBMM GLM Max. hole angle = 71 deg. @ 10,130' • 60+ deg. (3,550' - 10,970') Camco 2-7/8" xl" Hole angle thru' perfs = > 28 deg. . sidepocket KBMM GLM 201` Howco ES cementer 2139' 9 5/8", 40#/ft, L-80 Btrc. 7,560' a X Camco 2-7/8"x1"• 12,360' Marker Joints ( 12,389' - 12,428' ) sidepocket KBMM GLM / X 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. I I XN- Nipple-2.313"landing profile, 2.250" NO-GO 12,502' ( drift ID = 2.347", cap. = .00579 bpi Auto-Divert Valve 12,518' 7" 26 ppf, L-80, BTC production casing ( drift ID =6.151", cap. = 0.0383 bpf: Discharge Head FPHVDIS 12,527' Pump SXD 137-P17 TUNGS 12,528' oilso Centrilift Gas Separator 12,547' Note: Can not tag lGRSFTXARH6 U Centrilift Tandem seal section pump shaft due to GSB3DBUT SB/SB PFSA 12,552' auto fill valve above , 1 GSB3DBLT SB/SB PFSA Centrilift KMH 190 HP 2415/48 ESPl Re-Rated to 165 HP 2230 Volt/ 12,565` t, 43 Amp WellLift MGU Gauge 12,582' Stimulation Summary r g 05/11/98 - Kuparuk A Gauge TVD 6973' 55,480#of 16/20 CarboLite (w/ChemFlow) + 118,385#of 16/20 C D 6 Fin Centralizer 12,584' CarboLite LTC behind pipe Perforation Summary Ref log:GR/CCL dated 5/8/98 Size SPF Interval (TVD) 4.5 5 12,656'- 12664' 7025'-7032' 3-3/8 6 12,705'- 12,725' 7,069'to 7,087' 4.5 6 12,725`- 12745' 7087'-7105' 7 7 4.5 5 12,762`- 12782' 7120`-7139' Q c-•,—Tagged fill 2/24/09 @ 12,792' ---_-_,,,-_ 7"float collar(PBTD) 12,958' ' 7"float shoe 13,040' DATE REV. BY COMMENTS MILNE POINT UNIT 11/23/00 MDO ESP RWO 4-ES 08/09/04 JRC ESP RWO 4-ES WELL MPL-40 9/ ESP RWO 2/16/06 L.Hu8/05 L Hullme me ESP RWO 3S 4-ES API No: 50-029-22855 2/26/09 L. Hulme ESP C/O,Add Perfs&Screens/Shroud 3S 01/21/12 Brian Bixby ESP Changeout Doyon 16 Hilcorp Alaska LLC Tree: 2 9/16" - 5M CIA MPU L-40 OriOB Elev. = 50.6' (N 27E) Wellhead: 11" 5M FMC Gen. 5a w/ Orig. GL Elev. = 17.55' 7 1/16" FMC Tbg. Hng. , 3" LH RT To Tbg. Spool = 33.0' (N 27E) Acme top and 2-7/8" btm., 2.5" CIW "H" BPV profile 20" 91.1 ppf, H-40 112' PROPOSED SCHEMATIC Netcerrp:va.la,I I r±143' Camco 2-7/8"x1" KOP @ 300' sidepocket KBMM GLM Max. hole angle = 71 deg. @ 10,130' 60+ deg. (3,550' - 10,970') Hole angle thru' perfs = > 28 deg. Howco ES cementer L±2139' 9 5/8", 40#/ft, L-80 Btrc. 7,560' X Camco 2-7/8" x1" • ±12,360' Marker Joints ( 12,389' - 12,428' ) sidepocket KBMM GLM i X 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. I I XN-Nipple-2.313" landing ±12,502' (drift ID = 2.347", cap. = .00579 bpi profile, 2.250" NO-GO 7" 26 ppf, L-80, BTC production casing (drift ID = 6.151", cap. = 0.0383 bpf; Discharge Head ±12,527' Pump ±12,528` J I , , U Tandem Seal Section ±12,552` Motor 112,565' Stimulation Summary r L 05/11/98 - Kuparuk A 55,480#of 16/20 CarboLite (w/ChemFlow) + 118,385#of 16/20 C 3 6 Fin Centralizer ±12,584' CarboLite LTC behind pipe Perforation Summary Ref log:GR/CCL dated 5/8/98 Size SPF Interval (TVD) 4.5 5 12,656'-12664' 7025'-7032' 3-3/8 6 12,705'- 12,725' 7,069'to 7,087' 4.5 6 12,725`- 12745' 7087'-7105' 4.5 5 12,762`- 12782' 7120`-7139' ,-Tagged fill 2/24/09 @ 12,792' 7"float collar(PBTD) 12,958' ' 7"float shoe 13,040' DATE REV.BY COMMENTS MILNE POINT UNIT 11/23/00 MDO ESP RWO 4-ES 08/09/04 JRC ESP RWO 4-ES WELL MPL-40 LESP RWO 2/116/06 8/05 L.Hullme me ESP RWO 3S 4-ES API No: 50-029-22855 2/26/09 L. Hulme ESP C/O,Add Perfs&Screens/Shroud 3S 01/21/12 Brian Bixby ESP Changeout Doyon 16 Hilcorp Alaska LLC • Milne Point ASR Rig 1 BOPE Hitrorp AI**k .r. IA. 2017 11" BOPE Stripping Head ( 711, 4.48' 16 PLtdril GILQ werii" -.5000 Mr mialitigirrilllia IP IPI111III Ill � ` \ _ ANL_ 6U 4.54' C AID H VBR or Pipe Rams ` 111 11u- 5000 li � = Blind =sir , _ . ire= `i< : illI IIII11 it 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves el n ii , ! .45 3 , 1 ! ti_ . : I I iii IiI=I1 Ill i I _. itTi 2.00 iII : : : :6 IP �e i , v<f ,., ,,, i i 1 i4,„,. gi i 11 .IIII Ill lt1►111 i' °= e w M Manual ' Manual Manual HCR Updated 11/20/2017 Swab Valve-Cameron FLS-2p 9/16" PR2 MPL-40im_ 5K,manual gate valve,EE PSL2, 11/16/2017 11 Nimpg Wing Valve,Cameron FLS 2 9/16" 2 9/16"5K tree with 5K, reverse acting,actuated gate 2 7/8"FMC Tubing Hanger �r valve,w/Baker actuator,EE PSL2 a ._ PR2 SCoFS " , reverseSVamer actingn,actuatedL29/16gate5K 1111 a valve,w/Baker actuator,EE Fii � �f!s 1® iI I PSL2 PR2 MamFLS S 2 " ,. c) J,‘ SK,manual sterCagear valve,FLEE PSL29/16 PR2 ..'rift.% •+ — ••, T9/131g6,,Hd Adpter,FMC 7"5K x 2 SK,rotating flanges top I and bottom,w/lea 3/8"control line prep,w/ESP mandrel.No '''''.1 'k..!.'" -- Heat trace run.Bottom prepped for 2 7/8"seal sleeve .. .11..I':I, ..., ,i—„4,11,10.kv,4, mill C 011 I -� 1ni U L .,.' . ■■ ` • • § k2 Q Z 0 £ k � 2 a & Q 7,3 v3 .) CA 0 >2 o o 1,2 .27 <2Q.Q.2 § ® « ...- E " . ..-Ea • 0 o 3 13C % § > d \ § I k. \ O. »t < c k / / / < 0 A'% _ w � @ � m % .- ■ ■ \ / 0 0 O as Co @ 0 � • 0 — o a k / C.) = k > & kf k Om CO '§ Q \ -o0 - cu $ 0 § < o C.) 0 ■ E § = = © 2 -0 § R /a \ / c ,-.,--i, a c - co § — 4 , > > c ■ o J � g § ) 0gi E § ■ § L. Ci <N @ C13 2 LU 4 Q I_ 2 % / 0 _ q Q $ 2 » § § ■ E ca 0 : > C g � a) a) a) ) O O o ii 0 0 / V ¢ $ E % 0 § co 0 Cl) Cl) CO < a- • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 0 . 198 - 010 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 .0 50 - 029 - 22855 - 00 - 00 7. Property Designation: ♦ A m 8. Well Name and Number: / 34651 %3 ADL 388235 A( 11 .. MPL �/ 9. Field / Pool(s): s Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 13125' feet Plugs (measured) 12792' (Fill) feet true vertical 7454' feet Junk (measured) None feet Effective depth: measured 12957' feet Packer: (measured) None feet true vertical 7298' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" 112' 112' 1490 470 Surface 7524' 9 -5/8" 7560' 4515' 5750 3090 Intermediate Production 13006' 7" 13040' 7375' 7240 5410 Liner SIANNED FEB 9 2012 Perforation Depth: Measured Depth: 12656' - 12782' True Vertical Depth: 7025' - 7139' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 12586' 6962' Packers and SSSV (type, measured and true vertical depth): None RECEIVED 11. Stimulation or cement squeeze summary: FEB 0 t Intervals treated (measured): B 0 8 2012 Treatment description including volumes used and final pressure: 8! -p . , Oil & Ges Con Commission Anchorage 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 606 99 23 300 257 Subsequent to operation: 739 245 67 200 240 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory #„,® Development ❑ Service ❑ Stratigraphic IS Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ `" ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. 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: Contact David :'ork, 564 -5683 N/A Printed Jo- IN; • Title Drilling Technologist Prepared By Name /Number: Signatur , Phone 564 Date Joe Lastufka, 564 -4091 Form 10-404 R d 10/201 ` t S FEB 0 9 2912440 0 , 2 1 • 12. Afn /03. bmit Original Only • MPL -40, Well History (Pre Rig Workover) Date Summary 12/01/11 T /I /O =SSV /550/0, Temp =SI. PPPOT-T (PASS), PPPOT -IC (PASS). Pre RWO. PPPOT -T: Stung into test port (0 psi). Functioned LDS, all moved freely. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (0+ psi). Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 12/07/11 WELL S/I ON ARRIVAL. RAN 2" CENT S.S & DUAL SPARTEK GAUGES. S/D 11' SLM.LRS HOT TBG, WORKED DOWN TO 23' SLM. LRS ASSISTED W/ B &F. PUMPED 20 BBLS OF CRIESEL. RAN 2.5" BLB & 2.12" GAUGE RING. S/D C© 6490' SLM. UNABLE TO GET ANY DEEPER. RAN 2" CENT, 3' X 1.5" STEM, 2.12" GAUGE RING. TAGGED ESP © 12524' SLM. RAN 2.24" CENT, 3' X 1.5" STEM, 2.31" GAUGE RING. S/D EP 6490' SLM, WORKED DOWN TO 8150' SLM. 12/08/11 RAN 2.25" GUAGE RING. S/D © 8110' SLM WORKED DOWN TO 8510' SLM. QUIT MAKING HOLE. RAN 2.12" GAUGE RING. S/D © 8510' SLM. APPEARS TBG PLUGGED OFF. MADE MULTIPLE RUNS W/ 2" X 10' DRIVE DOWN BAILER. BAILED FROM 8510' SLM TO 8522' SLM. RECOVERED FORMATION SAND. LRS ASSISTED W/ B &F. RAN 2.5" BLB & 2.12" GAUGE RING. S/D CO 9368' SLM. RAN 2" X 10' DRIVE DOWN BAILER. S/D © 9370' SLM, WORKED THRU, S/D © 12503' SLM. RFC;C)VFRFf SANE) 12/09/11 LRS PUMPED 29 BBLS OF 130° DIESEL. MADE MULTIPLE RUNS W/ 2.25" x 10' DRIVE DOWN BAILER. WORKED FROM 8140' SLM TO 9575' SLM. PULLED 1" DPSOV & SET DGLV © 172' MD. R/D DUE TO PRIORITY JOBS. RETURN ON LATER DAY. WELL S/I ON DEPARTURE. 12/11/11 T /I /0= 600/600/0. Conducted PJSM. Verified barriers. R/U VR lubricator to front side IA & PT to 300 low /3500 high (charted). Set 2- 1/16" FMC VR plug. PT to 300 low /3500 high (charted & recorded). Removed IA valve & installed it on backside IA valve, torqued to spec. PT to 300 low /3500 high (charted & recorded). Installed blind flange w/ needle valve on front side of tbg spool, torque to spec & PT to 300 low /3500 high. 12/13/11 T /I /O = 600/640/0. Conducted PJSM. Verified barriers. Demobed well from wing valve, removed well house, and foundation. Installed blinds, TQ'd to spec. P/T wing flange to 300 low / 5000 high. (charted and recorded). NOTE: NO BPV SET 12/15/11 MIRU. RIH cleaned out to top of pump 12553' CTM.no injectivity. POOH. RIH w SLB 1.69" tubing punch 12/16/11 RIH w / SLB 1.69 "x 2' tubing punch. Park at 12525' and shoot 2' tubing punch w/ TCP E -Fire. Good pressure indication on both tubing and IA that guns fired. POOH. Freeze protect tubing w / 47 bbls of 50/50 methanol. Confirm gun is spent. RDMO. 12/17/11 WELL S/I ON ARRIVAL. RAN 2.07" CENT, 3' X 1.5" STEM, 1.5" LIB. S/D C© 12527' SLM / 12565' MD. RECOVERED SHAFT IMPRESSION. RAN PDS CALIPER AS PER PROCEDURE. RECOVERED GOOD DATA. 12/18/11 RAN 2.07" CENT, S.S & DUAL SPARTEK GAUGES. MADE 3 HOUR STOP C© 12500' MD & 15 MINUTE STOP C© 11921' MD. HELD SAFETY DRILLS W/ WSL. PULLED 1" DGLV FROM 12394' MD. POCKET LEFT OPEN. ASSISTED SUPPORT TECHS INSTALL BPV. BPV SET. WELL LEFT S/I ON DEPARTURE. Page 1 of 1 __ i • • North. America - ALASKA - BP Page 1 of 7 Operation Summary Report Common Well Name: MPL -40 AFE No Event Type: WORKOVER (WO) Start Date: 12/31/2011 End Date: X4- 00VHV -E (830,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/23/1998 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @38.95ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/12/2012 00:00 - 05:00 5.00 RIGD P PRE HOLD PRE -SPUD MEETING WITH RIG CREW - DISCUSS UPCOMING OPERATIONS ON MPL -40 PJSM -OFF LOAD 11.7 FLUID TO TIGER TANK ON LOCATION FOR REUSE -CLEAN OUT PITS WITH FRESH WATER -FLUSH LINES - SECURE CELLAR 05:00 - 07:30 2.50 MOB P PRE MOVE OFF OF MPL -03 -PAD OPERATOR NOTIFIED, WSL AND TOOL PUSHER PRESENT - MOBILIZE TO MPL -40 LEFT MESAGE AT AOGCC NORTH SLOPE PAGER, 659 -3607 AT 06:30 HRS 1/12/2012. 07:30 - 12:00 4.50 MOB P PRE SPOT CUTTING BOX -WHP: 500 TBG, 720 IA, 450 OA. -TAKE ON HEATED SEAWATER TO PITS. -SPOT CREW TRAILER AND FUEL TRAILER. ACCEPT RIG AT 0900 HRS 1/12/2012 12:00 - 13:30 1.50 RIGD P PRE SPOT FLOW BACK TANK -HARD LINE CREW LAY HARD LINE AND FLUID TESTED WITH DIESEL TO 4200 PSI. -BLEED OA TO 200 PSI -RU FROM PRODUCTION TREE, CIRCULATION MANIFOLD TO CHOKE. 13:30 - 14:30 1.00 RIGU P PRE HELD RIG EVACUATION DRILL AAR: ALL PRESENT, LOADER WAS ROAD GUARD. 14:30 - 17:30 3.00 RIGU P PRE PJSM, BLOW THROUGH SURFACE LINE AND CLEAR HARD LINE. -TEST RIG SURFACE LINES TO 3500 PSI. -TEST CIRC- MANIFOLD AND TREE KILL LINES TO 3500 PSI. -NEW HI- PRESSURE HOSE FAILED AND WAS REPLACED. (PIN HOLE LEAK) - INSPECT FLOW BACK TANK AND CONFIRM TANK SUCTION IS CLEAR. AOGCC INSPECTOR LOUIS GRIMALDI RETURNED CALL AND SAID TO CALL BACK WITH 2 HRS NOTICE OF TEST TIME. 17:30 - 20:00 2.50 WHSUB P DECOMP PU WELL SUPPORT LUBRICATOR -LOW TEST TO 250, HIGH TEST TO 3500 BOTH CHARTED FOR 5 MIN -PULL BPV AND RD LUBRICATOR -RU CIRCULATING LINE TO TREE - TUBING PRESSURE = 500 PSI, IAP = 660 PSI, OAP = 180 PSI Printed 1/23/2012 7:54:51AM *orth America - ALASKA - BP Page 2 of 7 Operation Summary Report Common Well Name: MPL -40 AFE No Event Type: WORKOVER (WO) Start Date: 12/31/2011 End Date: X4- 00VHV -E (830,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/23/1998 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @38.95ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 KILLW P DECOMP PJSM FOR WELL KILL WITH RIG CREW, MUD ENGINEER, TRUCK PUSHER, SCS AND WSL - BLEED IA FROM 660 TO 0 PSI IN 25 MIN -BLEED TUBING TO 0 PSI IN 20 MIN - PRESSURE DOWN STREAM OF CHOKE MAINTAINED BELOW 150 PSI -PUMP 75 BBLS DOWN TI IBIN(; WITH RETURNS UP IA (a.. 3 BPM, ICP = 750 PSI, FCp = 650 PSI -40 BBLS FLUID RETURNED DURING CIRCULATING -SI CHOKE AND BULLHEAD 25 BBLS DOWN TUBING INITIALLY AT 5 BPM THEN REDUCING TO 2 BPM TO KEEP BELOW 2000 PSI - MONITOR WELLHEAD PRESSURES FOR 10 MIN, FINAL IAP = 640 PSI, TUBING = 270 PSI, OAP = 475 PSI -PUMP 380 BBLS OF SEAWATER DOWN TUBING WITH RETURNS UP IA TO FLOW BACK TANK @ 5 BPM AND 1950 PSI -BLEED OA DURING CIRCULATION TO KEEP UNDER 500 PSI - REDUCE RATE TO 3 BPM AND 1110 PSI TO KEEP PRESSURE DOWN STREAM OF THE CHOKE BELOW 150 PSI. 1/13/2012 00:00 - 02:00 2.00 KILLW P DECOMP CONTINUE CIRCULATING DOWN TUBING AND UP IA OUT TO FLOW BACK TANK AT 3 BPM AND 1310 PSI - RETURNS CLEANING UP FROM OIL TO SEAWATER -450 TOTAL BBLS PUMPED 02:00 - 03:00 1.00 KILLW P DECOMP SHUT DOWN PUMP AND MONITOR PRESSURES - AFTER 30 MIN TUBING PRESSURE = 70 PSI, IAP = 40 PSI - MONITOR 15 MORE MIN TUBING = 50 PSI, IAP = 30 PSI 03:00 - 05:00 2.00 KILLW P DECOMP CIRCULATE BOTTOMS UP THROUGH THE CHOKE AND GASBUSTER - 8.5 PPG FLUID IN, 8.4 PPG FLUID OUT INITIALLY -8.5 PPG SEAWATER RETURNS AT BOTTOMS UP - MONITOR WELL, 0 PSI ON TUBING AND IA - WSL VERIFIED TUBING ON A VAC 05:00 - 06:00 1.00 WHSUR P DECOMP SET 2 -1/2" H TYPE TWC -TEST FROM ABOVE 250 LOW, 3500 PSI FOR 5 CHARTED MIN. - PERFORM ROLLING TEST FROM BELOW AT 2 BPM / 500 PSI FOR 10 CHARTED MIN. -LOST 13 BBLS SEAWATER. 06:00 - 07:00 1.00 WHSUR P DECOMP BLOW DOWN ALL CIRCULATING LINE AND MANIFOLD. -CLEAR MANIFOLD AND HOSES FROM WORK AREA PRIOR TO NEXT TASK. 07:00 - 08:00 1.00 WHSUR P DECOMP ND 2 9/16" PRODUCTION TREE AND ADAPTFR FLANGE. -5 AND 3/4 TURNS TO MU 3" L.H. ACME CROSS OVER INTO TBG HANGER LIFT THREADS. Printed 1/23/2012 7:54:51AM orth America - ALASKA - BP Page 3 of 7 Operation: Summary Report Common Well Name: MPL -40 AFE No Event Type: WORKOVER (WO) Start Date: 12/31/2011 End Date: X4- 00VHV -E (830,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/23/1998 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @38.95ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 11:00 3.00 BOPSUB P DECOMP NU 13 5/8 ANNULAR, 2 7/8" x 5" VBR. BLIND SHEAR RAMS MUD CROSS. 2 7/8" x 5" VRR AND 13 5/8" x 7 1/16" XO SPOOL. - NOTIFIED AOGCC INSPECTOR LOUIS GRIMALDI OF 2 HRS LEAD TIME ON BOPE TEST. 11:00 - 17:30 6.50 BOPSUB P DECOMP TEST BOPE -TEST BOPE PER WELL PLAN AND AOGCC REGS. -TEST WITNESSED BY LOU GRIMALDI OF AOGCC -TEST VARIABLE RAMS TO 250 PSI LOW AND ` 3500 PSI HIGH - HYDRIL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2 -7/8" AND 4" TEST JOINT - PRESSURE TEST FOR 5 CHARTED MIN EACH. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT -AK -10-4 KOOMEY TEST: -2850 PSI SYSTEM PRESSURE - 1650 PSI AFTER CLOSURE -200 PSI INCREASE IN 20SEC -FULL PRESSURE ATTAINED IN 92 SEC -6 N2 BOTTLES AT 1900 PSI 17:30 - 18:30 1.00 BOPSUR P DECOMP R/D BOP TEST EQUIPMENT -BLOW DOWN LINES -CLEAR RIG FLOOR 18:30 - 21:30 3.00 PULL P DECOMP PJSM -SUCK OUT STACK -R/U DSM LUBRICATOR -TEST 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED -PULL TWC -R/D DSM LUBRICATOR -CLEAR RIG FLOOR 21:30 - 23:30 2.00 MOB P DECOMP PJSM - REVIEW ESP SHEAVE HANGING PROCEDURE -R/U ESP SHEAVE AND EQUIPMENT -HANG SHEAVE IN DERRICK AND SECURE 23:30 - 00:00 0.50 MOB P DECOMP AAR WITH RIG CREW, TOOL PUSHER, AND WSL - REVIEW ESP SHEAVE HANGING PROCESS IN WINDY CONDITIONS TOTAL FLUID LOSS =103 BBLS 1/14/2012 00:00 - 00:30 0.50 MOB P DECOMP PJSM -SPCC AND RIG CHECKS - INSPECT ESP SHEAVE AND SPOOL UNIT Printed 1/23/2012 7:54:51AM orth America - ALASKA - BP Page 4 of 7 Operation Summary Report Common Well Name: MPL -40 AFE No Event Type: WORKOVER (WO) Start Date: 12/31/2011 End Date: X4- 00VHV -E (830,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/23/1998 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @38.95ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 01:30 1.00 PULL P DECOMP M/U LANDING JT -SCREW LANDING JOINT INTO HANGER -BACK OUT LOCK DOWN SCREWS -PULL HANGER OFF OF SEAT AT 108K - STRING BROKE OVER AND PULLED FREE AT 120K -FINAL PUWT =108K, SOWT =110K 01:30 - 02:00 0.50 PULL P DECOMP CENTRILIFT DISCONNECT ESP HANGER - REMOVE PENETRATOR -PULL 1 JT AND REMOVE CLAMP -SLACK BACK DOWN TO FLOOR AND UD HANGER - R/U CIRCULATING LINES 02:00 - 05:00 3.00 PULL P DECOMP CLOSE ANNULAR AND CBU THROUGH GAS BUSTER -4.5 BPM = 1800 PSI FOR 380 TOTAL BBLS PUMPED - MONITOR WELL FOR 10 MIN FROM GAS BUSTER TO PITS, NO FLOW -R /D AND BLOW DOWN CIRC LINES AND GAS BUSTER -R/U TO POOH -PHASE 2 LEVEL 2 AT 0300 HRS. 05:00 - 18:30 13.50 PULL P DECOMP PJSM FOR POH WITH ESP. -PULL 2 -7/8" ESP COMPLETION F/12655' MD T /SURFACE , - MAINTAIN CONTINUOUS HOLE FILL. -UD ONE GLM, LOOKS GOOD. -DRIFT BOTTOM CONNECTION OF EACH STAND AND LAY DOWN ANY BAD JOINTS. -PHASE 1 LEVEL 2 AT 10:30 HRS. -LAY DOWN 3 BAD JOINTS AND PICK UP REPLACEMENTS FROM THE PIPE SHED - LOSSES DURING DECOMPLETE 7 -8 BPH 18:30 - 19:30 1.00 PULL P DECOMP CLEAN, CLEAR RIG FLOOR - PREP FLOOR AND PIPE SHED TO LAY DOWN ESP PUMP AND MOTOR 19:30 - 00:00 4.50 PULL P DECOMP -LAY DOWN PERFORATED JOINT -LAY DOWN ESP PUMP AND MOTOR ASSY WITH SHROUD PER CENTRILIFT - PUNCHED 2 HOLES IN SCREENS = CLEAN AND EMPTY -LAY DOWN4 -1/2" SCREENS - RECOVERED 206 LASALLE CLAMPS, 12 CANNON CLAMPS, 2 SINGLE CANNON CLAMPS -BP EFFICIENCY TEAM VISITED RIG TO TALK WITH WSL, TOOL PUSHER AND RIG CREW -TOTAL 24 HR FLUID LOSS = 208 BBLS 1/15/2012 00:00 - 01:00 1.00 DEMOB P DECOMP PJSM - PERFORM SPCC PRE -TOUR CHECKS -CLEAN AND CLEAR RIG FLOOR -C /O ELEVATORS AND FLOOR VALVES 01:00 - 01:30 0.50 DEMOB P DECOMP M/U WEAR BUSHING TOOL - INSTALL WEAR BUSHING - 6 1/8" 01:30 - 02:00 0.50 DHB P DECOMP MOBILIZE CHAMP PACKER TO RIG FLOOR -M /U CHAMP PACKER Printed 1/23/2012 7:54:51AM OsEorth America - ALASKA - BP Page 5 of 7 Operation Summary Report Common Well Name: MPL-40 AFE No Event Type: WORKOVER (WO) Start Date: 12/31/2011 End Date: X4- 00VHV -E (830,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/23/1998 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @38.95ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 06:00 4.00 EVAL P DECOMP P/U AND RIH WITH PACKER ON DRILL PIPE 1X1 F /SURFACE T/4700' MD - MAINTAIN AND MONITOR CONTINUOUS HOLE FILL W/8.6# SEAWATER. 06:00 - 12:00 6.00 EVAL P DECOMP CONTINUE TO P/U 4" DP AND RIH W /7" CHAMP PACKER - F/4700' T/ 9982' MD. -PUW 145K, SOW 95K. - MAINTAIN CONTINUOUS HOLE FILL AT —8 BPH LOSS RATE W/ SEAWATER. 12:00 - 12:30 0.50 EVAL P DECOMP PJSM, CHANGE OUT RIG CREWS - PERFORM PRE -TOUR CHECKS -RIG SERVICE. 12:30 - 15:00 2.50 EVAL P DECOMP CONTINUE TO P/U 4" DP AND RIH W/7" CHAMP PACKER -F/ 9982' MD T/11860' MD -PUW 150 K, SOW 95 K. - MAINTAIN CONTINUOUS HOLE FILL AT —8 BPH LOSS RATE W/ 8.6# SEAWATER. 15:00 - 17:00 2.00 EVAL P DECOMP PJSM WITH TOOL PUSHER -CUT AND SLIP 95 FT OF 1 1/4" DRILL LINE - INSPECT DRAWWORKS 17:00 - 18:00 1.00 EVAL P DECOMP CONTINUE RIH W /DP F/11860' T/12509' MD - LOSSES 8 BPH 8.6 PPG SEAWATER 18:00 - 19:00 1.00 EVAL P DECOMP ESTABLISH CIRCULATION TO CLEAR WELLBORE AT PACKER SETTING DEPTH -SPR MUD PUMP #1: 2.5 BPM = 270 PSI, 3.4 BPM = 390 PSI -PUW = 186K, SOW = 110K -PUMP 3 BPM @ 230 PSI FOR 40 TOTAL BBLS PUMPED -PJSM WITH HES REP FOR SETTING CHAMP PACKER 19:00 - 21:00 2.00 EVAL P DECOMP SET 7" CHAMP PACKER PER HES REP AT 12,505' MD TO CENTER OF ELEMENT -BLOW DOWN TOP DRIVE AND INSTALL TIW VALVE -SET 20K ON PACKER TO CONFIRM SET -CLOSE UPPER PIPE RAMS 1/1 - PRESSURE UP CASING DOWN IA VALVE CS - PRESSURE TEST CASING TO 2670 PSI FOR 0 30 MIN, NO PRESSURE DROP IN 30 MIN CHARTED TEST, GOOD TEST -CALL RWO ENGINEER AND WELLS TEAM LEAD TO CONFIRM TEST RESULTS - RELEASE PACKER PER HES REP 21:00 - 00:00 3.00 EVAL P DECOMP POH AND LAY DOWN 4" DP FROM 12505' TO 9427' MD - LOSSES 10 BPH ON 8.6 PPG SEAWATER -TOTAL 24 HOUR FLUID LOSS = 152 BBLS 1/16/2012 00:00 - 09:00 9.00 EVAL P DECOMP POH LAYING DOWN 4" DP 1x1 FROM 9427' TO SURFACE. - MAINTAIN CONTINUOUS HOLE FILL OF 8.5 SEAWATER -8 BPH LOSS RATE. 09:00 - 09:30 0.50 WHSUR P DECOMP UD 7" CHAMP PACKER WITH HES REP. -PULL WEAR RING. Printed 1/23/2012 7:54:51AM i lorth America ALASKA - BP Page 6 of 7 Operation Summary Report Common Well Name: MPL -40 AFE No Event Type: WORKOVER (WO) Start Date: 12/31/2011 End Date: X4- 00VHV -E (830,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/23/1998 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @38.95ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:00 0.50 RUNCOM P RUNCMP PJSM -R/U TO RUN 2 7/8" 6.5# L80 8RD ESP COMPLETION. 10:00 - 12:00 2.00 RUNCOM P RUNCMP P/U ESP MOTOR -M /U ESP MOTOR PER CENTRILIFT 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM -C /O RIG CREWS - PERFORM SPCC AND PRE -TOUR CHECKS 12:30 - 14:00 1.50 RUNCOM P RUNCMP R/D ESP CABLE TRUNK -SNAKE ESP CABLE THROUGH SHEAVE IN DERRICK. 14:00 - 16:00 2.00 RUNCOM P RUNCMP MAKE UP ESP MOTOR ASSEMBLY - INSTALL POTHEAD TO PUMP WITH 5 PROTECTORS AND 3 FLAT GUARD CLAMPS 16:00 - 00:00 8.00 RUNCOM P RUNCMP RIH FROM 84' TO — 6700' MD - MAINTAIN CONTINUOUS HOLE FILL WITH 8.5 SEAWATER - PERFORM CONTINUITY CHECK ON ESP CABLE EVERY 2000' LOSS RATE 8 BPH 8.5 PPG SEAWATER 1/17/2012 00:00 - 02:00 2.00 RUNCOM P RUNCMP RIH FROM — 6700' TO —8000' - MAINTAIN CONTINUOUS HOLE FILL WITH 8.5 SEAWATER 02:00 - 04:00 2.00 RUNCOM P RUNCMP PERFORM ESP CABLE SPLICE AND TEST BY CENTRILIFT REP - ESTABLISH CIRCULATION DOWN TUBING AT 1 BPM AND 70 PSI FOR TOTAL OF 10 BBLS PUMPED 04:00 - 08:30 4.50 RUNCOM P RUNCMP RIH FROM —8000' TO 12563' MD - MAINTAIN CONTINUOUS HOLE FILL WITH 8.5 SEAWATER - PERFORM CONTINUITY CHECK ON ESP CABLE EVERY 2000' -LOSS RATE 6 BPH OF 8.5 PPG SEAWATER 08:30 - 12:00 3.50 RUNCOM P RUNCMP CIRC. TBG VOLUME @ 1BPM AT 100 PSI - TERMINATE ESP CABLE TO TBG HANGER -CHECK CONDUCTIVITY -LAND TBG HANGER - PUW =115K / SOW =73K -TOTAL NUMBER CANON CLAMPS RUN= 210/ 2 SINGLE CLAMPS. 12:00 - 13:00 1.00 RUNCOM P RUNCMP PJSM, L/D LANDING JOINT - INSTALL TWO WAY CHECK VALVE. 13:00 - 14:00 1.00 RUNCOM P RUNCMP RIG UP ROLLING PRESSURE TEST BELOW TWO WAY CHECK - 1BPM@500 PSI FOR 10 MINUTES. CHARTED - TOTAL OF 17 BBLS PUMPED AWAY DURING ROLLING TEST - B/D LINES. 14:00 - 14:30 0.50 RUNCOM P RUNCMP R/U TO PRESSURE TEST ABOVE TWO WAY CHECK - 250 LOW/ 3500 HIGH PSI FOR 5 MINUTES. CHARTED. - R/D TEST EQUIPMENT. 14:30 - 15:00 0.50 RUNCOM P RUNCMP B/D LINES - REMOVE FLUID FROM BOP'S 15:00 - 16:30 1.50 RUNCOM P RUNCMP PJSM - N/D BOP'S - REMOVE ADAPTER FLANGE. Printed 1/23/2012 7:54:51AM .111.4orth America - ALASKA - BP Page 7 of 7 Operation Summary Report Common Well Name: MPL -40 AFE No Event Type: WORKOVER (WO) Start Date: 12/31/2011 End Date: X4- 00VHV -E (830,000.00 ) Project: Milne Point Site: M Pt L Pad Rig Name /No.: DOYON 16 Spud Date/Time: 2/23/1998 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: Kelly Bushing / Rotary Table @38.95ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 17:30 1.00 RUNCOM P RUNCMP N/U PRODUCTION TREE. 17:30 - 18:30 1.00 RUNCOM P RUNCMP PRESSURE TEST TBG HEAD ADAPTER AND VOID TO 5000 PSI FOR 30 MINUTES WITH FMC REP. 18:30 - 19:30 1.00 RUNCOM P RUNCMP CHECK ESP CONDUCTIVITY WITH CENTRILIFT REP. 19:30 - 22:00 2.50 RUNCOM P RUNCMP R/U DRILL SITE MAINTENANCE - PRESSURE TEST LUBRICATOR AND TREE TO 250 LOW/ 3500 HIGH/ 5000 FINAL PSI - CHART EACH TEST / 5 MINUTES -PULL TWO WAY CHECK - RETEST LUBRICATOR AND SET BPV -R/D DRILL SITE MAINTENANCE. AT 20:30 CALL AOGCC WITH 24 HR NOTICE FOR INITIAL BOP TEST ON L -06 22:00 - 23:00 1.00 RUNCOM P RUNCMP PERFORM ROLLING PRESSURE TEST FROM BELOW BPV 1 BPM @ 500 PSI -CHART FOR 10 MINUTES - PUMPED AWAY 22 BBLS -B /D LINES 23:00 - 00:00 1.00 RIGU P POST SERVICE RIG AND PREP FOR MOVE TO L -06 1/18/2012 00:00 - 02:30 2.50 WHSUR P POST R/U LRS TO FREEZE PROTECT -PUMP 65 BBLS OF DEAD CRUDE DN IA © 2BPM/1300 PSI - PUMPED 15 BBLS OF DEAD CRUDE DN TBG @ 1.5 BPM/ 1350 PSI -R/D LRS AOGCC INSPECTOR JOHN CRISP WAIVED WITNESS OF INITIAL BOP TEST AT 02:30 02:30 - 04:00 1.50 RIGD P POST CLEAN PITS AND SLOP TANK -RIG DOWN CELLAR -STAGE EQUIPMENT FOR RIG MOVE -FINAL WELL HEAD PRESSURES: TBG = 0 PSI, IA = 50 PSI, OA = 0 PSI * *RIG RELEASE AT 0400 ** Printed 1/23/2012 7:54:51AM Tree: 2 9/16" - 5M CIW Orig. KB = 50.6' (N 27E) ' Wellhead: 11 5M FMC Gen. 5a w/ MPU L 40 Orig. GL Elev. = 17.55' To Tbg. Spool = 33.0' (N 27E 71 /16 " FMC TTbg. n .,3 "LH RT o g p ( 27E) 9 9 Acme top and 2 -7/8" btm., 2.5" CIW "H" BPV profile 20" 91.1 ppf, H -40 112' Camco 2 -7/8" x1" I 143' KOP @ 300' sidepocket KBMM GLM Max. hole angle = 71 deg. @ 10,130' 60+ deg. (3,550' - 10,970) Camco 2 -7/8" x1" Hole angle thru' perfs = > 28 deg. sidepocket KBMM GLM 201' I 11 i Ho ES cementer I 2139' 9 5/8 ", 40 # /ft, L-80 Btrc. 7,560' ,E X Camco 2 -7/8" x1" I 12,360' Marker Joints ( 12,389' - 12,428' ) sidepocket KBMM GLM 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. XN- Nipple - 2.313" landing 1 12,502' profile, 2.250" NO -GO ( drift ID = 2.347 ", cap. = .00579 bpi Auto - Divert Valve 12,518' 7" 26 ppf, L -80, BTC production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf) Discharge Head FPHVDIS 1 12,527' '4 Pump SXD 137 -P17 TUNGS ( 12,528' 1. Centrilift Gas Separator 1 12,547' GRSFTXARH6 Centrilift Tandem seal section GSB3DBUT SB /SB PFSA 112,552' GSB3DBLT SB /SB PFSA Centrilift KMH 190 HP 2415/48 1 12 , 565` ° Re -Rated to 165 HP 2230 Volt / e . - 43 Amp 12,582' Stimulation Summary WeIILift MGU Gauge 05/11/98 - Kuparuk A Gauge TVD I 6973' 55,480# of 16/20 CarboLite li (w/ ChemFlow) + 118,385# of 16/20 j) 6 Fin Centralizer 1 12,584' I / CarboLite LTC behind pipe Perforation Summary Ref log: GR /CCL dated 5/8/98 Size SPF Interval (TVD) 4.5 5 12,656' - 12664' 7025' - 7032' 3 -3/8 6 12,705' - 12,725' 7,065' - 7,074' 4.5 6 12,725' - 12745' 7087` - 7105' 4.5 5 12,762' - 12782' 7120' - 7139' Tagged fill 2/24/09 @ 12,792' 7" float collar (PBTD) 12,958' 7" float shoe I 13,040' DATE REV. BY COMMENTS MILNE POINT UNIT 11/23/00 08/09/04 JRC ES RWO 4 -ES WELL MPL-40 9/18/05 L. Hulme ESP RWO 4-ES API No: 50 -029 -22855 2/16/06 L. Hulme ESP RWO 3S 2/26/09 L. Hulme ESP C /O, Add Perfs & Screens /Shroud 3S 01/21/12 Brian Bixby ESP Changeout Doyon 16 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 SONNED FEB ci 4 Z ° Mr. Tom Maunder g — ©+ 0 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue P Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPL -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPL -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPL -Pad Date: 10/08/11 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 gal MPL -01A 2030640 50029210680100 Sealed conductor N/A N/A N/A N/A NA MPL -02A 2091470 50029219980100 Sealed conductor N/A N/A N/A N/A NA MPL -03 1900070 50029219990000 Tankoconductor N/A N/A N/A N/A NA MPL-04 1900380 50029220290000 Sealed conductor N/A N/A N/A N/A NA MPL -05 1900390 50029220300000 Sealed conductor N/A N/A N/A N/A NA MPL-06 1900100 50029220030000 Sealed conductor N/A N/A N/A N/A NA MPL -07 1900370 50029220280000 Sealed conductor N/A N/A N/A N/A NA MPL -08 1901000 50029220740000 Sealed conductor N/A N/A N/A N/A NA MPL -09 1901010 50029220750000 Sealed conductor N/A N/A N/A N/A NA MPL -10 1901020 50029220760000 Sealed conductor N/A N/A N/A N/A NA MPL -11 1930130 50029223360000 Sealed conductor N/A N/A N/A N/A NA MPL -12 1930110 50029223340000 Sealed conductor N/A N/A N/A N/A NA MPL -13 1930120 50029223350000 Sealed conductor N/A N/A N/A N/A NA MPL -14 1940680 50029224790000 Sealed conductor N/A N/A N/A N/A NA MPL -15 1940620 50029224730000 3.3 N/A 3.3 N/A 15.3 8/9/2011 MPL -16A 1990900 50029225660100 23 Needs top job MPL -17 1941690 50029225390000 0.2 N/A 0.2 N/A 5.1 9/1/2011 MPL -20 1971360 50029227900000 0.4 N/A 0.4 N/A 3.4 8/10/2011 MPL -21 1951910 50029226290000 1.7 N/A 1.7 N/A 8.5 8/10/2011 MPL -24 1950700 50029225600000 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL -25 1951800 50029226210000 1.7 N/A 1.7 N/A 15.3 8/10/2011 MPL -28A 1982470 50029228590100 0.3 N/A 0.3 N/A 8.5 10/8/2011 MPL -29 1950090 50029225430000 0.5 N/A 0.5 N/A 3.4 8/7/2011 MPL -32 1970650 50029227580000 0.5 N/A 0.5 N/A 5.1 8/10/2011 MPL -33 1971050 50029227740000 0.2 N/A 0.2 WA 8.5 10/8/2011 MPL -34 1970800 50029227660000 1.7 N/A 1.7 N/A 8.5 8/9/2011 MPL -35A 2011090 50029227680100 0.2 N/A 0.2 N/A 8.5 10/8/2011 MPL-36 1971480 50029227940000 0.1 N/A 0.1 N/A 7.6 9/1/2011 MPL-37A 1980560 50029228640100 6 N/A 6 N/A 47.6 8/13/2011 MPL -39 1971280 50029227860000 1.7 N/A 1.7 N/A 6.8 8/8/2011 " MPL-40 1980100 50029228550000 1 N/A 1 N/A 6.8 8/8/2011 MPL-42 1980180 50029228620000 5.3 N/A 5.3 N/A 30.6 8/14/2011 MPL-43 2032240 50029231900000 17.5 Needs top job MPL-45 1981690 50029229130000 10 N/A 10 N/A 8.5 8/10/2011 STATE OF ALASKA ~~~~ A~~ OIL AND GAS CONSERVATION CON~SION REPQRT OF SUNDRY WELL (~'~®~JS .309 Form 10-404 Revised 04/2006 ~~~ 1. Operations Performed: ^ ,.Q~~~ ISSlOt! mi~~~ ^ Abandon ^ Repair Well Re-Enter Suspended Well ^ Plug Perforations L.I Sfi ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ®Perforate - ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development- ^ Exploratory 198-010 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22855-00-00 7. KB Elevation (ft): 50 6' - 9. Well Name and Number: . MPL-40 8. Property Designation: ~ 10. Field /Pool(s): ~ ADL 388235 ,C~Q/O~,~Oo?,3 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 13125' - feet true vertical 7454' - feet Plugs (measured) 12792' (Fill) Effective depth:. measured 12957' feet Junk (measured) None true vertical 7298' feet Casing Length Size MD TVD Burst Collapse Structural ,,._ ._. Conductor 74' 20" 112' 112' 1490 470 Surface 7524' 9-5/8" 7560' 4515' 5750 3090 Intermediate Production 13006' 7" 13040' 7375' 7240 5410 Liner Perforation Depth MD (ft): 12656' - 12782' Perforation Depth TVD (ft): 7025' - 7139' 2-7/8", 6.5# L-80 12698' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: 1 ~,~ ~~ ~~ `~. "~ r~~ ~ Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf .Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 121 15 302 310 266 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Bjork, 564-5683 N/A Printed Name Terrie Hubble Title Drilling Technologist ~ Prepared By Name/Number: Signature ~ Phone 564-4628 Date Terrie Hubble 564-4628 ~~~~ ~~ ! ~~ t ~ Submit Original Only `~ ~~s • • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPL-40 Common Well Name: MPL-40 Spud Date: 2/23/1998 Event Name: WORKOVER Start: 2/10/2009 End: 2/28/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/28/2009 Rig Name: NABOBS 3S Rig Number: Date !From - To ' Hours Task Code NPT Phase Description of Operations 2/10/2009 21:00 - 00:00 3.00 RIGD N WAIT PRE Wait on weather to warm up from -47 degF to lay down derrick. -54 degF at 24:00 hrs. 2/11/2009 00:00 - 00:00 24.00 RIGD N WAIT PRE Continue to wait on weather to warm up from -54 degF. Hold leadership meetings with ADW Anchorage Leadership Team in Deadhorse. Continue to wait on weather and Slickline post-rig operations on MPL-12 before moving to MPL-Pad. 2/12/2009 00:00 - 08:00 8.00 RIGD N WAIT PRE Continue to wait on weather to warm up from -44 degF. Continue to wait on weather and Slickline post-rig operations on MPL-12 before moving to MPL-Pad. Ambient temperature ranging from -37 to -45 degF throughout the day. 08:00 - 00:00 16.00 RIGD P PRE Weather warmed up to -29 degF. Conduct PJSM for laying down Derrick. Scope and lay down Derrick. Load shed and separate from carrier. 2/13/2009 00:00 - 01:00 1.00 RIGD P PRE Continue to RD unit. Jack down pits, blow down steam lines and disconnect electrical. Slickline still attempting to pull plug on well L-12 next to L-40. 01:00 - 10:00 9.00 MOB N WAIT PRE Wait on Slickline to finish job prior to moving rig over well slot. 10:00 - 11:00 1.00 RIGD P SURE Discuss with Anchorage Engineering on new plan. Due to Slickline issues on MPL-12, the rig will now move to MPI-11 and complete that RWO first. DIMS reports starting now can be found on MPI-11. 2/22/2009 00:00 - 02:30 2.50 RIGD P PRE Job continued from the 2-13-09. Rigging downfrom MPI-11. Prep rig floor and Derrick inspection. Scope and Lay down Derrick. 02:30 - 04:30 2.00 RIGD P PRE Jack down, pin wheels and roll pipe shed away from carrier. Disconnect electrical and blow down steam lines. Jack down and remove matts from pit module. Trucks on location at 04:00 hrs. 04:30 - 08:00 3.50 MOB P PRE PJSM with truck crews. Hook up trucks to pipe shed, pits, gen skid, shop, camp, and parts house. Roll wheels on carrier and function test controls. Jack down carrier. 08:00 - 11:00 3.00 MOB P PRE Travel from MPI Pad to MPL pad. 11:00 - 17:30 6.50 RIGU P PRE / MIRU on MPL-40. 17:30 - 00:00 6.50 RIGU N RREP PRE Tail pin on Derrick broken and needs to be replaced. Set up cellar with fire blankets and herculite to prevent fire. Set out fire extinguisher and PJSM with all crews. Welder cut off damaged Derrick lock down bolts. Weld on 2 new bolts. Load upright and pits with heated seawater. 2/23/2009 00:00 - 03:00 3.00 RIGD N RREP PRE Continue to weld on 2 new bolts. Tuboscope inspection performed on Derrick bolts and weld spots. 03:00 - 04:00 1.00 RIGU P PRE Prep floor to scope Derrick. Scope Derrick, string lines and raise windwall. Tie in electrical and check skate extension. Riq accented at 04:00 hrs on 2-23-09. 04:00 - 06:00 2.00 KILL P DECOMP RU lines to wellhead and kill manifold. Install double annulus valve and MU integral on wing valve. Tie in LRS to kill manifold. Connect lines and hardline from blooey line to Tiger Tank. Blow air and steam thru lines, double check connections. 06:00 - 07:00 1.00 KILL P DECOMP RU LRS. Pressure test all hardline to 2500 psi to closed choke, and 500 psi downstream of choke to Tiger tank. 07:00 - 08:30 1.50 WHSUR P DECOMP PUMU lubricator. Pressure test with diesel to 500 psi. Pump open dual SSV's. Pull BPV with T/IA/OA of 800 / 920 / 140. Rig down lubricator and prep for kill. Load pits and upright Printed: 3/6/2009 1:43:17 PM • • BP EXPLORATION Operations Summary Report Page 2 of 4 Legal Well Name: MPL-40 Common Well Name: MPL-40 Spud Date: 2/23/1998 Event Name: WORKOVER Start: 2/10/2009 End: 2/28/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/28/2009 Rig Name: NABOBS 3S Rig Number: ~ ~ Date 2/23/2009 From - To Hours Task Code I NPT Phase Description of Operations 07:00 - 08:30 08:30 - 12:00 12:00 - 15:00 15:00 - 20:00 20:00 - 22:00 22:00 - 00:00 2/24/2009 00:00 - 02:00 02:00 - 07:00 07:00 - 08:00 08:00 - 13:00 13:00 - 14:30 14:30 - 16:00 - 1.50 WHSUR P DECOMP - tank. PJSM 3.50 KILL P DECOMP Bleed gas from IA thru choke to tiger tank. Bleed to 110 psi and come on line pumping 120 deg F SW down tubing taking returns from IA to Tiger. Circulate 75 Bbls at 6 BPM, 170 psi, close choke and Bullhead 50 Bbls into formation at 80 psi and 3 BPM. Tubing on vacuum, IA with 170 psi. Open choke and circulate another 160 Bbls, without returns. Close choke and bullhead 250 Bbls down IA at 5 BPM, with pressure building to 1900 psi and rate decrease to 2 BPM. Shut down and monitor well. Well slowly bleed to 180 psi. 3.00 KILL P DECOMP Circulate SW down tubing with returns from IA to Tiger Tank at 5 BPM, 1100 psi (tubing pressure), 180 psi IA pressure. Circulate total of 350 Bbls and lose 100 Bbls to formation. Gas and oil in returns. Wait for SW. 5.00 KILL P DECOMP Monitor well. Tbg on vacuum, IA at 80 psi. RU shieve, elephant trunk in derrick for pulling ESP. Get hydraulic tongs and equipment to Rig floor for pulling ESP. Wait for SW to circulate well again. Load pits and Upright tank with heated seawater. 2.00 KILL P DECOMP PJSM. Initial SITP: TBG = 0 psi, IA = 30 psi, OA = 0 psi. Break circulation with rig pump and Little Red at 3.5 BPM / 75 psi down the tubing taking returns thru choke to Tiger Tank. Caught fluid at surface 118 bbls into circulation, continue to circulate at 5.5 BPM / 2060 psi thru choke to Tiger tank. Returns li ht crude throu hout. Circulate with FCP of 4 BPM / 1110 psi, returns cleaned up to good seawater. Circulated a total of 398 bbls and returned 211 bbls at surface 53% returns. OA did not increase over 0 psi during circulation. Monitor well for 30 min, tubing and IA on strong vac. 2.00 WHSUR P DECOMP D rod TWC with FMC. Test from above to 3 500 si for 10 min -charted. Iniect 2.5 BPM down IA at 1,000 psi for 10 min - 2.00 WHSUR P DECOMP Remove kill manifold and RD lines. Bleed hanger void, ND tree. Remove seal from hanger neck and check hanger threads with 3" L.H. ACME XO - 6 turns. 5.00 BOPSU P DECOMP NU ROPE. Function test and fill with fluid for testing. 1.00 BOPSU P DECOMP RU test equipment. 5.00 BOPSU P DECOMP Test 13-5/8" BOPE wit 2-7/8" test 'oint. Test to 250 / 3500 psi and chart each test for 5 minutes. AOGCC right to witness testing waived by Lou Grimaldi. Feeding IA w/ 20 Bbl/Hr SW w/ LRS while BOPE testin .Tubing on vacuum. 1.50 BOPSU P DECOMP PUMU Opso-Lopso w/ 3" LH acme XO torqued up. Screw into hanger. PUMU lubricator and pull TWC. Tubing and IA on Vacuum. RD lubricator and Opso-Lopso. Close blind rams. 1.50 PULL P DECOMP PUMU 3-1/2" DP landing joint with TIW valve and PI sub, and XO for hanger (3" LH Acme). Torque XO. Screw into hanger with 8 turns. Break out hanger lock down screws. Pull Hanger off seat. Tubing and IA on vaccum. Start hole fill ~ -20 Bbl/Hr. PUW 82K /SOW of 42K. Break out and lay down tubing hanger. Lay down landing joint. Lay down 10' pup joint. 1.50 PULL P DECOMP PUMU 1 joint of 2-7/8" tubing. Cut, clamp, and band, ESP cable to tubing. RIH total of 7 joints of 2-7/8" tubing. Tag with 16:00 - 17:30 Printed: 3/6/2009 1:43:17 PM s • BP EXPLORATION .Legal Well Name: MPL-40 Common Well Name: MPL-40 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date I From - To ;Hours Task 'Code ~' NPT Page 3 of 4 Spud Date: 2/23/1998 Start: 2/10/2009 End: 2/28/2009 Rig Release: 2/28/2009 Rig Number: Phase I Description of Operations 2/24/2009 16:00 - 17:30 1.50 PULL P DECOMP 17:30 - 18:30 1.00 PULL P DECOMP 18:30 - 00:00 5.50 PULL P DECOMP 2/25/2009 00:00 - 04:30 4.50 PULL P DECOMP 04:30 - 07:30 3.00 PULL P DECOMP 07:30 - 09:30 2.00 PULL P DECOMP 09:30 - 15:00 5.50 PERFO P OTHCMP 15:00 - 16:30 1.50 PERFO P OTHCMP 16:30 - 17:30 1.00 PERFO P OTHCMP 17:30 - 18:30 1.00 PERFO P OTHCMP 18:30 - 19:30 1.00 PERFO P OTHCMP 19:30 - 20:30 1.00 PERFO P OTHCMP 20:30 - 22:00 1.50 PERFO P OTHCMP 22:00 - 23:30 1.50 PERFO P OTHCMP 23:30 - 00:00 0.50 PERFO P OTHCMP 2/26/2009 00:00 - 02:00 2.00 PERFO P OTHCMP 02:00 - 04:00 2.00 BUNCO P RUNCMP 04:00 - 13:00 9.00 BUNCO P RUNCMP 13:00 - 15:30 2.50 BUNCO RUNCMP 15:30 - 21:00 5.50 BUNCO RUNCMP 5.80' of stickup on joint #7, for depth of 12816'.,, POH lay down 7 joints of 2-7/8" tubing. RU to pull ESP, pull ESP cable over sheave in Derrick. POH standing back 2-7/8" tubing in derrick. Pump SW into well at -20 Bbl/Hr as POH. No fluid at surface. 97 stands out at 00:00 hrs. Continue to POH from stand #97 to stand #199 with 2-7/8" ESP completion assembly. Pump SW into well at -20 Bbl/Hr. BO/LD ESP assembly. Recovered 206 LaSalle Clamps, 5 Protectolizers, 3 Flat Guards. Clean and clear rig floor and pipe shed of ESP equipment. Remove shieve and elephant trunk from derrick. Install Dutch system. RILDS and align. Close annular on Dutch nipple. PJSM. Load SLB a-line equipment into pipe shed. RU to rig floor. Maintain hole fill at -20 Bbl/Hr. Load lubricator/BOP's with SW and test to 500 psi. Leak on pin hole of BOP's. Tighten connection, test to 500 psi w/ no visible leaks PU 20' of 4-1/2" PJ Omega guns with 5 spf / 72 deg phasing, GR/CCL. MU and test break with SLB quick test system. Open blinds and RIH RIH w/guns to 500' and come on line with charge pump to fill hole at 3 BPM. Hole full with 138 Bbls of SW pumped. Circulate across top. Tag PBTD C~ 12796' a-line corrected depth. Loa and tie in to_ short marker joints and formation gamma. Make depth adjustment. Perforate interval 12782' - 12762'. Monitor well. Losses C~3 80 Bbls/Hr. Reduce rate to -20 Bbls/Hr as POH with perforating guns. UD 20' guns and MU 10' of 4-1/2" PJ Omega gums with 5 spf / 72 deg phasing, GR/CCL. MU and test break with SLB quick test system. Open blinds and RIH Log and tie in to short marker joints and formation gamma. Make depth adjustment. Perforate interval 12656' - 12664'. Monitor well. Losses f~ 80 BblslHr. Reduce rate to -20 Bbls/Hr as POH with perforating guns. RD SLB a-line equipment into pipe shed. Continue RD SLB E-line equipment into pipe shed. ND / LD Dutch lubricator system. Hang ESP cable sheave in Derrick, and RU floor to run 2-7/8" ESP completion. PU / MU 4-1/2" screens, Shear out joint pinned with 3 pins (26,000 #'s) and 5-1/2" Shroud for ESP assembly. PSJM and HACL for handling and lifting of Shroud to rig floor and hanging int he rotary table. PUMU90 HP motor with Well Lift gauges. Test conductivity and gauges prior to RIH on tubing. Upper gauge not reading.discharge pressure and temperature. Trouble shoot upper well lift gauge. Break out and lay down gauge, Hot shot new gauge assembly from Centrilift shop and install new gauge assembly and test. Gauge still not reading properly. POH w/ ESP from inside of Shroud, removing clamps, bands, and Packoff from shroud. No damage to I-wire. Inspect lower Well Lift gauge. Prong in pump mate sensor assembly Operations Summary Report Printed: 3/6/2009 1:43:17 PM • BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPL-40 Common Well Name: MPL-40 Spud Date: 2/23/1998 Event Name: WORKOVER Start: 2/10/2009 End: 2/28/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/28/2009 Rig Name: NABOBS 3S Rig Number: Date ;From - To Hours __II - 2/26/2009 115:30 - 21:00 5.50 Task ~, Code I NPT Phase Description of Operations RUNCMP damaged. Break out lower sensor. Hotshot new censor from Centrilift shop and install. RUNCMP Crew change and perform pre-tour checks. MU /RIH with 2-7/8", 6.5#, L-80, EUE 8rd, pup, XN, (3) joints 2-7/8" tbg, GLM w /Dummy and RIH from Derrick to stand # 36. Centrilift check conductivity of cable, fill and flush pump with 10 bbls SW at 1 bph / 1,000 psi. Pump SW into well at ~20 BbI1Hr. 45 stands ran at 00:00 hrs. RUNCMP Continue to RIH with ESP on 2-7/8" tubing from Derrick from stand # 45. Centrilift check conductivity of cable at 70 stands, fill and flush pump with 10 bbls SW at 1/2 bph / 1,000 psi. 105 stands = 1/2 bpm / 1,400 psi, 124 stands = 1/2 bpm / 1,480 psi. Pump SW into well at -20 Bbl/Hr. RUNCMP Centrilift tech make Reel to Reel cable splice. RUNCMP Continue RIH with completion on 2-7/8" tubing from derrick. Check conductivity of cable at 165 stands in hole, fill tubing and flush pump. Continue RIH with 199 stands total. Load tubing and flush pump with 10 Bbls of SW. Ran 12 Cannon clamps, 2 ea Cannon "Half" clamps, 215 Lasalle clamps. RUNCMP PUMU tubing hanger on landing joint with TIW valve installed. Orient properly. Install penetrator. Centrilift make penetrator splice. RUNCMP PUW of 83K /SOW of 43K. Land tubing hander. Run in Lock down screws. Break out and lay down landing joint and 3" LH acme XO. RUNCMP Dry Rod TWC. Test from above to 1000 psi and chart for 10. minutes. Unable to test from below. RUNCMP Blow down lines, suck out Bop stack, ND BOPE. LRS adding SW to IA at rate of -20 Bbls hr during ND process. RUNCMP Crew change made in Phase 2 wearther to MPU Camp, convoy only. Perform pre-tour checks. RUNCMP Continue to ND BOPE, and lay down in shipping cradle. RUNCMP Nu tree and adaptor flange. RUNCMP Continue to NU tree and adaptor flange. RUNCMP FMC wellhead tech tested tubing hanger void to 5,000 psi for 30 minutes. Test tree with diesel to 5,000 psi for 5 charted minutes. Centrilift perform final checks. RUNCMP PU / RU lubricator, test to 500 psi. Well__s~port tecl~ulled 21:00 - 00:00 I 3.00 2/27/2009 ~ 00:00 - 04:30 ~ 4.50 04:30 - 09:30 5.00 09:30 - 13:30 4.00 13:30 - 17:00 I 3.50 17:00 - 18:00 I 1.00 18:00 - 19:00 1.00 RUNCO~P 19:00 - 21:00 2.00 WHSUR P 21:00 - 21:30 I 0.50 I W HSUR I P 21:30 - 23:30 2.00 WHSUR P 23:30 - 00:00 0.50 WHSUR P 2/28/2009 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:00 1.00 WHSUR P 02:00 - 03:00 I 1.001 WHSUR I P TWC and installed BPV. Tubing and IA on a vaccum. 03:00 - 04:00 1.00 WHSUR P RUNCMP LRS freeze protect Well with diesel, tubing 15 bbls, IA 65 bbls. Remove second annulus valve, secure well and normal up tree. Rig released at 04:00 hrs. Printed: 3/6/2009 1:43:17 PM Tree: 2 9/16" - 5M CIW ! M P U L-40 Wellhead: 11" 5M FMC Gen. 5a w/ 7 1/16" FMC Tbg. Hng. , 3" LH Acme top and 2-7/8" btm., 2.5" CIW "H" BPV profile Orig.3~Elev. = 50.6' (N 27E) Orig. GL Elev. = 17.55' RT To Tbg. Spool = 33.0' (N 27E) 20" 91.1 ppf, H-40 112' KOP @ 300' Max. hole angle = 71 deg. @ 10,130' 60+ deg. (3,550' - 10,970') Hole angle thru' perfs = > 28 deg. Camco 2-7/8" x1" 172' sidepocket KBMM GLM Howco ES cementer 2139' 9 5/8", 40#/ft, L-80 Btrc. 7,560' Camco 2-7/8" x1" 12,394' Marker Joints (12,389' - 12,428') i sidepocket KBMM GLM 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift ID = 2.347", cap. _ .00579 bpi 7" 26 ppf, L-80, BTC production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ; ESP Shroud 12,598 - 12,641' Stimulation Summary 05/11/98 - Kuparuk A 55,480# of 16/20 CarboLite (w/ ChemFlow) + 118,385# of 16/20 CarboLite LTC behind pipe Perforation Summary Ref loa: GR/CCL dated 5/8/98 Size SPF Interval (TVD) 4.5 5 12,656` - 12664' 7025` - 7032' 3-3/8 6 12,705' - 12,725' 7,065' - 7,074' 4.5 6 12,725` - 12745' 7087` - 7105' 4.5 5 12,762` - 12782' 7120` - 7139' DATE I REV. BY 1 COMMENTS XN- Nipple - 2.313" landing 12,505' profile, 2.250" NO-GO Discharge Head FPHVDis 12,565` Tandem Pumps 127-P6 PMSXD 12,566' Centrilift Gas Separator 12,595' GRSFTXARH6 Centrilift Tandem seal section GSB3DBUT AB/HSN PF5A in shroud GSB3DBLT AB/HSN FSA CL5 Centrilift KMH 562 series in shroud 114 hp motor, 2330 / 30 Amp WeIILift MGU Gauge w/ 6 fin 12,598' centralizer Gauge TVD 6973` 4 1/2" Pup and X-Over 12,641' BOT Safety Shear Sub 26k 12,646' WFD Duragrip Screen w/ bull plug 12,655 - 98' Tagged fill 2/24/09 @ 12,792` 7" float collar (PBTD) 12,958' 7" float shoe 13,040' 9/18/05 2/16/06 L. Hulme L. Hulme ESP RWO 4-ES ESP RWO 3S 2/16/06 L. Hulme ESP RWO 3S 2/26/09 L. Hulme ESP C/O, Add Perfs & Screens/Shroud 3S MILNE POINT UNIT WELL MPL-40 API No: 50-029-22855 BP EXPLORATION (AK) STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jir~ _re~g.~ y~as(<.~_~i;> dzz€..an cr. E"urii~:~n.~;~v'~~:iaslCa.~zuv I~~,i~.f et: kr:~:~tei3~~'r3 a.la;<€~;~, t3uv -------------9..._--- -----~ -------~---------......-- Contractor: Nabors Ri No.: 3S DATE: 2/24/2009 Rig Rep.: J.Greco / R.E~jorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: J.Menke / D. Rohdes Field/Unit & Well No.: MPL-40 PTD # 1980100 Operation: Drlg: _ Workover: X Explor.: Test: Initial: _ X Weekly: Bi-Weekly Test Pressure: Rams: 2:50/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK : Quantity Size Annular Preventer 1 13 5/8 5000 Pipe Rams 1 2 7/8 X 5 Lower Pipe Rams 0 NA Blind Rams 1 E31ind/Shear P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8-2 1/16" P Kill Line Valves 1 2 1 /16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test ,Alarm Test Trip Tank P I' Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Result P P P Test Result P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1750 P 200 psi Attained 30 P Full Pressure Attained 2:40 P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @ 1950 Test Results Number of Failures: Test Time: 5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope ~' Inspector 659-3607, follow with written confirmation to Superviser at: ji:.::.reg~~`alasKa.~{c;v 'Remarks: Tested against 2 way ck -test with 2 7/8" 24 HOUR NOTICE GIVEN YES _ x NO Waived By Lou Gramaldi Date _ 02/22/09 Time 16:00 Wifiess J.Menke /J.Greco Test start 8:00 Finish 13:00 BOP Test (for rigs) ~~~>.~4:i~~:' ~i~~ 1a ~ ~~~e BFL 11/14/07 Nabors 3s BOP Test MPL-40 2-24-2009.x1s e 0 og escrlpt on ae o or 03-36 10831325 CH EDIT PDC GR 08/11/04 1 MPL-40 98160 OH EDIT MWD/LWD (REVISED) 03105/98 4 1 L2-18A 11421036 RST 10/14/06 1 1 A-04 11221855 RST 03/22/06 1 1 06-04A 11320998 RST 08/02/06 1 1 C-24A 11209609 MCNL 06/19/06 1 1 P2-57 A 10831796 RST 04/29/06 1 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WI! J b# iCf7r-O/Ò L D 05/15/07 NO. 4260 .- .-:;1 IS' /9S Company: State. of Alaska' Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . tl D t CI BL CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 1- I\I¡".'~V ·..i,l. ¡ t'". ~) zom g SCANNED MAY 172007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: STATE OF ALASKA I ALAS~IL AND GAS CONSERVATION CO MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 388235 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): Ch~nge Out ESP o Suspend o Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver 181 Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit 0 Dri Number: 198-010 6. API Number: 50-029-22855-00-00 99519-6612 KBE = 50.60' 9. Well Name and Number: MPL-40 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 13125 7454 12957 7298 feet feet Plugs (measured) NIA feet Junk (measured) 12389' - 12428' feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 9-5/S" 7560' 4515' 5750 3090 7" 13040' 7375' 7240 5410 74' 7524' 13006' 12690' - 12745' 7055' - 7105' )110 iii" CIII ~ CD ~26~ rzo J;> ::I I» g.CIt t-:ì o n c::> .... 0 co ~ r....::> = m n = ~. en C ø ø is' ::I 2-7/8", 6.5# L·SO Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Tubin Pressure Re resentative Dail Gas-Mcf o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: 17. Printed Name Sondra Stewman Title Technical Assistant Phone Fl2 f¡ -:-rY ~ Prepared By Name/Number: Date L/U- t<9 U\ß'ondra Stewman, 564-4750 Submit Original Only U ¡"\ GJi~AI 564-4750 RBDMS BFL MAR 20 2006 ~ Tree: 29/16" - 5M CIVI.A MPU L 40 Wellhead: 11" 5M FMC~n. 5a wI - 71/16" FMC Tbg. Hng. , 3" LH Acme top and 2-7/8" btm., 2.5" CIW "H" BPV profile 20" 91.1 ppf, H-40 112' KOP @ 300' Max. hole angle = 71 deg. @ 10,130' 60+ deg. (3,550' - 10,970') Hole angle thru' perfs = > 28 deg. 95/8", 40#/ft, L-80 Btrc. I 7,560' I 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift 10 = 2.347", cap. = .00579 bpi 7" 26 ppf, L-80, BTC production casing (drift 10 = 6.151", cap. = 0.0383 bpf ¡ Stimulation Summary 05/11/98 - Kuparuk A 55,480# of 16/20 CarboLite (w/ ChemFlow) + 118,385# of 16/20 CarboLite LTC behind pipe Perforation Summary Ref loa: GR/CCL dated 518/98 Size SPF Interval (TVO) 3-3/8 6 12,705' - 12,725' 7,065' - 7,07' 4.5 6 12,725' - 12745' 7087' - 7105' DATE 05111/98 OS/22/98 11/23/00 08/09/04 9/18/05 2/16/06 COMMENTS RWO - Perf and Frac Initial Completion 4-ES ESP RWO 4-ES ESP RWO 4-ES ESP RWO 4-ES ESP RWO 3S REV. BY KJW M. Linder MOO JRC L. Hulme L. Hulme Ori B Elev. = 50.6' (N 27E) Orig. GL Elev. = 17.55' RT To Tbg. Spool = 33.0' (N 27E) Cameo 2-7/8" x1" sidepocket KBMM GLM Howco ES cementer 172' I 2139' I Cameo 2-718" x1" I 12,394' I sidepocket KBMM GLM XN- Nipple - 2.313" landing 112,536' 1 profile, 2.205" NO-GO Tandem Pumps 229P6 SSO & 112,554' I 19GC8200 513 Series . GPMTAR 1:1 Centrilift Gas Separator 112,583' I GRSFTXARH6 . Centrilift Tandem seal section GSB3DBUT AB/HSN PFSA GSB3DBL T AB/HSN FSA CL5 Centrilift KMH 562 series 114 hp motor, 2330 / 30 Amp PumpMate w/6 fin centralizer PumpMate TVD 112,588' 1 112,601'1 112,612' I 1 6985' I Marker Joints ( 12,389' - 12,428' ) Tagged fill 8/04 @ 12,779' 7" float collar (PBTO) 7" float shoe MILNE POINT UNIT WELL MPL-40 API No: 50-029-22855 12,958' 13,040' BP EXPLORATION (AK) e BP EXPLORATION Operations Summary Report Start: 2/14/2006 Rig Release: 2/18/2006 Rig Number: N3S I c~~~:J~PT : Phase ___ . _____ Description of O~:~~tions ______ P PRE Rig-Down Pipe Shed and Mud Pits from Rig Sub. Move Rig Sub off MPF-14. Move Pipe Shed and Mud Pits away from Rig Sub. Move Rig Components from MPF-14 to MPL-40. Spot Rig over well, move other Rig Components into position and connect to Rig Sub. Raise and Scope Derrick. Finish R/U and make line connections to Rig Components. Install Hardlines to Tiger Tank and test. Accept Rig @ 1800 hours. Held PJSM. Bleed OA pressure from 1000 psi to 0 psi. P/U Lubricator, pull BPV, UD same. TIIIO = 300/20010. Bleed Tubing to 50 psi, IA to 100 psi. Hook up kill line to Production Tre.e and prep to displace tubing to seawater. Take on Seawater to Pits, Hold PJSM. Check lines. PJSM. Line up & pump down tubing wI heated seawater, taking returns up IIA, thru choke to tiger tank. 440 bbls pumped down tubing, still no returns up I/A. Tubing on vacuum. PJSM. Line up & pump down IIA wI heated seawater. Increase rate to 3-bpm. Pumped 120 bbls, monitor well, both sides on strong vacuum. Shut down pump. Monitor both IA and Tubing. P/U TWC and install and test to 3,500 psi (in anticipation of BOPE testing). N/D Tree and Adaptor Flange. N/U BOPE. BOPE test to 250 psi low and 3,500 psi high. Tests witnessed by M. Rooney / N. Frazier I E. Potter 1 R. Claiborne I J. Fritts. Chuck Scheve wi AOGCC waived witnessing the BOPE tests. Rig Down BOPE test equipment, drain lines and prepare to P/U lubricator to pull TWC. PUMU lubricator. Pull TWC. SITP = O. SICP=O. UD lubricator. PUMU landing jt. Screw into tubing hanger. BOLDS. Unland tubing hanger. Some gas vented to surface. Bags were closed. SICP=30 psi. Bled gas from the IA to the tiger tanks untillA was 0 psi. Monitored well to ensure dead, well on vacuum. Released bags. P/U wt, to unland hanger = 95K. P/U wt. after hanger free = 80K. Filled hole with 85 bbls. seawater prior to UD tubing hanger, Pit volume after fill - 156 bbls. Pull and UD landing jt. and tubing hanger. FMC transported tubing hanger to their shop for redress or replacement. String ESP cable over cable sheave and connect to cable spool in cable spooler. POH with ESP completion; SIB Doubles in Derrick; filling hole every 10-joints using double displacement. Recover 206-LaSalle Clamps, 3-Flat Guards, and 6-Protectolizers. Break out, Service and UD ESP components, Pump was locked up and motor was burned out. RID Elephant Trunk. Add 50-Bbls of seawater to wellbore at 1230 hrs. Clear and clean Rig Floor. Prepare to P/U new ESP completion. Shoot Fluid level at 1600 hrs and find at 935' from surface. P/U, Service, and M/U new ESP completion assembly. Legal Well Name: MPL-40 Common Well Name: MPL-40 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 3S Date I From - To : Hours I Task ".--... 2/14/2006 06:00 - 09:30 3.50 RIGD 09:30 - 11 :30 2.00 MOB P PRE 11 :30 - 17:00 5.50 MOB P PRE 17:00 - 19:30 2.50 MOB P PRE 19:30 - 22:30 3.00 WHSUR P DECOMP 22:30 - 23:59 1.48 WHSUR P DECOMP 2/15/2006 00:00 - 03:15 3.25 WHSUR P DECOMP 03:15 - 04:45 1.50 WHSUR P DECOMP 04:45 - 06:00 1.25 WHSUR P DECOMP 06:00 - 08:30 2.50 WHSUR P DECOMP 08:30 - 16:30 8.00 BOPSUF P DECOMP 16:30 - 21 :00 4.50 BOPSUF P DECOMP 21 :00 - 22:00 1.00 BOPSUF P DECOMP 22:00 - 23:30 1.50 BOPSUF P DECOMP 23:30 - 23:59 0.48 BOPSUF P DECOMP 2/16/2006 00:00 - 12:00 12.00 PULL P DECOMP 12:00 - 15:00 3.00 PULL P DECOMP 15:00 - 16:00 1.00 PULL P DECOMP 16:00 - 19:30 3.50 RUNCorfP RUNCMP Page 1 of 2 Spud Date: 2/23/1998 End: Printed: 2/21/2006 10:55:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/16/2006 2/17/2006 2/1812006 19:30 - 00:00 00:00 - 01 :00 01 :00 - 04:15 04:15 - 09:00 09:00 - 11 :00 11 :00 - 13:00 13:00 - 13:30 13:30 - 18:00 18:00 - 23:59 00:00 - 06:00 e BP EXPLORATION Operations Summary Report Page 2 of 2 Spud Date: 2/23/1998 End: Start: 2/14/2006 Rig Release: 2/18/2006 Rig Number: N3S I ; ! Code NPT· Phase I 3.25 RUNCMP MPL-40 MPL-40 WORKOVER NABORS ALASKA DRILLING I NABORS 3S From - To I Hours I Task t I 4.50 I RUNCO RUNCMP RUNCMP RUNCMP 4.75 RUNCMP 2.00 RUNCMP RUNCMP RUNCMP 0.50 RUNCO 4.50 BOPSU 5.98 WHSUR P RUNCMP 6.00 RIGD P POST _..__.1 . .... .....___. . Description of Operations .--.------------ RIH wI new Centrilift ESP completion using Best-O-Lite Pipe Dope and Optimum Torque of 2,300 ft-Ibs on all connections. Test electrical integrity of ESP cable and downhole ESP unit each 2000' ran in hole, Break circulation every 2000 ft. and pump 10 bbls through ESP per program. RIH wI new Centrilift ESP completion using Best-O-Life Pipe Dope and Optimum Torque of 2,300 ft-Ibs on all connections, Test electrical integrity of ESP cable and downhole ESP unit each 2000' ran in hole. Break circulation every 2000 ft. and pump 10 bbls through ESP per program. Centrilift service tech. make reel to reel Cable splice at 7065 ft. in hole. RIH wI new Centrilift ESP completion using Best-O-Life Pipe Dope and Optimum Torque of 2,300 ft-Ibs on all connections. Test electrical integrity of ESP cable and downhole ESP unit each 2000' ran in hole. Break circulation every 2000 ft. and pump 10 bbls through ESP per program. P/U and M/U Landing Joint to Tubing Hanger. Install Penetrator and dummy plugs. Find bad threads on the 2-7/8" pin after removing thread protector. FMC personnel onsite replaced the seal and junk rings on the Hanger that had been removed during decompletion. The Penetrator and dummys were then installed and the Hanger was M/U on the Landing Joint. Space out ESP Cable to Hanger and make electrical connection to the Penetrator. Install TWC. Land Tubing Hanger, RILDS, and test TWC to 2,500 psi. N/D BOPE and also remove all the armored BOP Control Lines from the Stack and the Control Line Manifolds. These lines will be replaced by new lines when the BOP Stack is N/U on the next well, MPL-12. N/U lockdown flange, tubing head adapter and tree. PIT tubing head adapter and tree to 5000 psi. Good test. Centriflift run final checks, P/U lubricator. Pull TWC. Set BPV. UD Lubricator. Secure well. Secure cellar. RDMO primary unit to MPL-12. Released rig @ 0000 hrs. 2/18/06. Printed: 2/21/2006 10:55:33 AM , STATE OF ALASKA E,.,..IVED ALASKA JL AND GAS CONSERVATION CC )IISSION -= I .. . - REPORT OF SUNDRY WELL OPERATIONS NOV 0 8 Z005 Cons. Commissi( Change d~t¡E§¥ia'!J.~ 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 388235 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 13006' Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend 0 Operation Shutdown 0 Perforate 181 Other o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension KBE = 50.60' 13125 7454 12957 7298 74' 7524' 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 198-010 6. API Number: 50-029-22855-00-00 99519-6612 9. Well Name and Number: MPL-40 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) 12389' - 12428' feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 9-5/8" 7560' 4515' 5750 3090 7" 13040' 7375' 7240 5410 ~CANNtED NO\! {} 9 2005 12690' - 12745' 7055' - 7105' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8", 6.5# L-80 12614' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): NONE RBDMS 8Ft NO \I 0 g 2005 Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casino Pressure 15 146 380 289 130 500 Oil-Bbl Prior to well operation: 135 Subsequent to operation: 208 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Tubino Pressure 342 333 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant ,.---~ èï9~ture~4y'-ê_.£;:-+r~ Phone 564-4750 Form 10-404 Revised 0412004 0 RIG I N A l. \ t t 0'7/ --- Prepared By Name/Number: Date 05 Sondra Stewman, 564-4750 Submit Original Only ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPL-40 MPL-40 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/16/2005 Rig Release: 9/18/2005 Rig Number: Spud Date: 2/23/1998 End: 9/18/2005 Date From- To HOUrs Task Code NPT Phase Descri ptiö nofOper¢ltiohs 9/16/2005 01 :00 - 05:00 4.00 RIGD P PRE Rig out Nabors 4ES. 05:00 - 08:00 3.00 MOB P PRE Move Nabors 4ES rig & equipment from MPE-12 to MPL-40. 08:00 - 11 :00 3.00 RIGU P PRE PJSM. Spot & rig in Nabors 4ES rig & equipment. Rig accepted @ 11 :00 hrs, 09/16/2005. 11 :00 - 13:00 2.00 KILL P DECOMP PJSM. Take on heated seawater. P/U lubricator, pull BPV. SITP = 900 psi, I/A = 375 psi, O/A = 100 psi. 13:00 - 15:30 2.50 KILL P DECOMP PJSM. Test lines to 3500 psi, test tiger tank line to 140 psi wI air, OK. Notify Milne Pt of gas bleeding operations & bleed gas off tubing. Line up & pump down tubing wI heated seawater, taking (gas) returns up IIA, thru choke to tiger tank. Increase rate to 4 bpm I 60 psi. wI 275 bbls pumped down tubing, still no returns up I/A. Tubing on screaming vacuum. 15:30 - 16:30 1.00 KILL P DECOMP PJSM. Line up & pump down II A wI heated seawater. Increase rate to 5 bpm 1100 psi. Pumped 250 bbls, monitor well, both sides on strong vacuum. 16:30 - 17:00 0.50 WHSUR P DECOMP PJSM. Set two way check & test to 1000 psi, OK. 17:00 - 18:30 1.50 WHSUR P DECOMP PJSM. N/D exisitng wellhead. 18:30 - 21 :30 3.00 BOPSUP P DECOMP PJSM N/U BOPE 21 :30 - 00:00 2.50 BOPSUP P DECOMP PJSM. NU BOPE. Test BOPE as per AOGCC and BP requirements 250 psi low 13500 psi high charted. Test witness waived by AOGCC Jeff Jones. Test witnessed by S. Bounds Nabors and M. Hefley - BP-Rep. 9/17/2005 00:00 - 01 :00 1.00 BOPSUP. P DECOMP Continue testing of BOPE. 01 :00 - 01 :30 0.50 DHB P DECOMP PJSM. Pull TWC. 01 :30 - 02:00 0.50 PULL P DECOMP PJSM. Pull Hanger to floor 105K P/U Wt., Remove hanger & test and secure cable. 02:00 - 03:00 1.00 EVAL P DECOMP PJSM. RIH with 2-7/8" Tbg. Tag fill 25' in on Jt # 7 @ 12,812'. 03:00 - 06:00 3.00 PULL P DECOMP PJSM. TOH with 2-7/8" Completion racking back in stands. Triple displace wI POOH. 06:00 - 12:00 6.00 PULL P DECOMP PJSM wI day crew. Switch ESP cable spools. Continue to POOH wI ESP assembly, standing 2-7/8" Tbg. 12:00 - 14:00 2.00 PULL P DECOMP Cut out suspeted damaged area of ESP cable for analysis. Lay out ESP assembly. Top pump locked up. Recovered 205 LaSalle clamps, 3 Flat Guards, & 5 Protectrolizers, nothing lost. 14:00 - 16:00 2.00 PULL P DECOMP Clean and clear rig floor. Load spooler with new ESP cable. Prepare ESP assembly to RIH. 16:00 - 23:00 7.00 RUNCOrvP RUNCMP PJSM. P/U Centrilift ESP assembly. TIH w/2-7/8" L-80 Tbg and ESP cable. 23:00 - 00:00 1.00 RUNCOrvP RUNCMP PJSM. Make reel to reel splice 67 stands in @ 6552 (+ -). 9/18/2005 00:00 - 02:30 2.50 RUNCOrvP RUNCMP Continue wI reel to reel splice. 02:30 - 07:00 4.50 RUNCOrvP RUNCMP PJSM. Continue in hole wI 2 7/8" EUE 8 rnd tubing & ESP completion, testing cable every 2000' & pumping @ 1 bpm @ 75 psi to clear pump, OK. 07:00 - 09:00 2.00 RUNCOrvP RUNCMP PJSM. Make up hanger, attach field connection & penetrator. 0.50 RUNcol Test same, OK. 09:00 - 09:30 RUNCMP PJSM. Land hanger, RILD's. 09:30 - 10:30 1.00 RUNCOrvP RUNCMP Install TWCV in Tbg hanger. Tèst TWC to 2500psi. Test held 100%. 10:30 - 12:30 2.00 I RUNCOrvP RUNCMP PJSM. Nipple down BOPE. 12:30 - 14:00 1.50 RUNCOrvP RUNCMP NU lock down flange, tubing head adaptor and tree. Pressure test TH adaptor and tree to 5000 psi. Test held 100%. 14:00 - 14:30 0.50 RUNCOrvP RUNCMP PJSM. Install lubricator, pull TWC and set BPV. I Printed: 9/19/2005 8:03: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) Bp···E*RI...(])R~,..tQN º:p~rätiÐI'1$.·SUrnrtlªry·..Rep()rt MPL-40 MPL-40 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/16/2005 Rig Release: 9/18/2005 Rig Number: Spud Date: 2/23/1998 End: 9/18/2005 Description ofOperatiÖns 9/18/2005 14:30 - 15:00 FrOm-To Hours·.··.·TaSkCöde NPT Phase 0.50 WHSUR P RUNCMP Secure well. Have Centralift perform final check on equipment - all good. Rig released @ 15:00 hrs, 09/18/2005. RUNCMP PJSM. Scope down top section and layover derrick. Rig out Nabors 4ES equipment. Date 15:00 - 0.00 RIGD P Printed: 9/19/2005 8:03:11 AM ~ STATE OF ALASKA ~ ALASKA "IL AND GAS CONSERVATION COlvllv1ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 50.60' 8. Property Designation: ADL 388235 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 74' Surface 7524' Intermediate Production 13006' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 0 Repair Well 0 Plug Perforations II Pull Tubing 0 Perforate New Pool 0 Operation Shutdown II Perforate Chan e Out ESP 0 Stimulate II Other 0 Waiver 0 Time Extension 0 Re-Enter Suspended Well 4. Current Well Class: II Development 0 Exploratory 0 Stratigraphic 0 Service 198-010 6. API Number: 50-029-22855-00-00 9. Well Name and Number: MPL-40 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 13125 7454 12957 7298 feet feet Plugs (measured) N/A feet Junk (measured) 12389' - 12428' feet Size MD TVD Burst 20" 112' 112' 1490 9-5/8" 7560' 4515' 5750 7" 13040' 7375' 7240 5410 Collapse 470 3090 12690' - 12745' 7055' - 7105' 2-7/8",6.5# RECE'VED SEP 1 3 2004 12603' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): A\aska Oi\ & Gas ons. Anchorage II"'. Treatment description including volumes used and final pressure: RBDMS 8FL SEt> 1 4 1004 13. Oil-Bbl Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run II Daily Report of Well Operations II Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory II Development 0 Service 16. Well Status after proposed work: II Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my no ge. Printed Name Sondra Stewman Sundry Nu~r N/A if C.O. Exempt: if ,...2CM'-272 Title Technical Assistant Prepared By NameiNumber: Datec:;s:1-lO ,-oL{ Sondra Stewman, 564-4750 Submit Original Only I\.~U L-40 Tree: 29/16" - 5M CIW Wellhead: 11" 5M FMC Gen. Sa w/ 71/16" FMC Tbg. Hng. ,3" LH Acme top and 2-7/8" btm., 2.5" CIW "H" BPV profile 20" 91.1 ppf, H-40 I 112' KOP @ 300' Max. hole angle = 71 deg. @ 10,130' 60+ deg. (3,550' - 10,970') Hole angle thru' perfs = > 28 deg. 9 5/8", 40#/ft, L-80 Btrc. I 7,560' I 2-7/8" 6.5 ppf, L-80, 8rd EUE tbg. ( drift 10 = 2.347", cap. = .00579 bpI 7" 26 ppf, L-80, BTC production casing (drift 10 = 6.151", cap. = 0.0383 bpf) Stimulation Summary 05/11/98 - KuparukA 55,480# of 16/20 Carbo Lite (w/ ChemFlow) + 118,385# of 16/20 Carbo Lite LTC behind pipe Perforation Summary Ref loa: GA/CCL dated 5/8/98 Size SPF Interval (TVO) 3-3/8 6 12,705' - 12,725' 7,065' - 7,074' 4.5 6 12,725' - 12745' 7087' - 7105' DATE REv. BY COMMENTS 05/11/98 KJW AWO - Perf and Frac OS/22/98 M. Linder Initial Completion 4-ES 11/23/00 MOO ESP AWO 4-ES 08/09/04 JRC ESP RWO 4-ES ~ Orig. KB Elev. = 5 (N 27E) Orig. GL Elev. = 17.55' AT To Tbg. Spool = 33.0' (N 27E) Camco 2-7/8" x1" side pocket KBMM GLM Howco ES cementer Camco 2-7/8" x1" side pocket KBMM GLM XN- Nipple - 2.313" landing profile, 2.205" NO-GO 140' I 2139' I I 12,393' I 112,535' 1 Centrilift GC 1150 ESP series 513, GPMTAA 1:1 159 stages Centrilift Tandem Gas Separator 112 567' 1 GRSFTXARH6 ' Centrilift Tandem seal section GSB3DBUTILH6PFS GSB3DBLTH6 Centrilift KMH 562 series 114 hp motor, 2330/30 Centrilift Pumpmate 112,550' I 112,572' I 112,586' I 112,600' 1 Marker Joints ( 12,389' - 12,428' ) Tagged fi1l8/04 @ 12,779' 7" float collar (PBTO) 7" float shoe I 12,958' I I 13,040' I MILNE POINT UNIT WELL L-40 API No: 50~29-22855 BP EXPLORATION (AK) Legal Well Name: MPL-40 Common Well Name: MPL-40 Event Name: WORKOVER Start: 8/6/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/9/2004 Rig Name: NABORS 4ES Rig Number: 4ES .... Date ~~~m - T~ Hours Tas~_I_~~~etl ~p2.-l!hase - __-=,escription of Operatio~~_.._- ---.- 8/6/2004 16:00 - 22:00 6.00 RIGU P PRE RDMO MPU-F90; move to MPU-L40 and re-assemble sub base, Pipe Shed, Mud Pits. 22 00 - 23 00 1 00 KILL P [ DECOMP Accept rig @ 2200 hrs. R/U lines to tree and Tiger Tank. Install : : . HCR valve on IA. Take on 140 F seawater to pits. 23:00 - 23:30 0.50 KILL P I DECOMP Test lines to 3500 psi. Flow check line to Tiger Tank. 23:30 - 00:00 0.50 KILL P DECOMP P/U lubricator and pull BPV. SI both sides: TP 540 psi, CP 540 psi. 0.50 KILL P DECOMP Bleed off both sides to TT. TP and CP = 0 psi. 2.50 KILL P DECOMP Circulate 72 Bbls of 140 F seawater to pump, then bullhead 20 Bbls to formation. Open up, take returns to Tiger Tank; no liquid until 6100 strokes, then crude oil, foamy crude and gas. Full hole volume of 450 Bbls circulated, returning foamy crude oil and gas. Circulated 600 Bbls with only 80 Bbls of crude oil returned to Tiger Tank. DECOMP Stop circulating and bleed down well to 0 psi. SI and monitor for 20 minutes, TP 0 psi, CP 20 psi. Wait on load of 130 F seawater to continue circulating for well cleanup. DECOMP Load 130 F seawater into pits. DECOMP Circulate to find fluid level in tubing; level @ -5300'. Switch over to bullhead down annulus. DECOMP Finish Bull Head Well with 400 bbls. Monitor Well. Well on vac. Install TWC. Test. Blow down and rig down lines. Nipple Down Production Tree. Nipple Up BOPE. Rig up test equipment. Test BOPE to BP/AOGCC requirements at 250/3500 psi. State's right to witness waived by J. Chrisp. DECOMP Blow down Lines. Rig down Test equipment. Suck out BOP Stack. DECOMP Pick-up Lubricator and pull TWC. Lay down same. Well remains on slight vac. DECOMP Pick-up Landing Joint. Pull Tubing Hanger to floor. Dragging up to 125K...then broke back (free) to 110K. Change out elevators, check cable. POH and SIB 2-7/8" tubing and spool ESP cable Change out ESP spools. POH and SIB 2-7/8" tubing and spool ESP cable Breakout and UD ESP Assembly. Cut cable and pull over sheave. DECOMP Clear and clean rig floor. Remove elephant hose. Wait on SWS. OTHCMP PJSM. R/U SWS E-Line equipment. M/U 20', Hollow carrier perf guns wI 6-JSPF. P/U and install lubricator. OTHCMP RIH wi SWS 4-1/2" guns, and tag for fill. Found fill at 12,779'. OTHCMP Tie-in CCL wi GR/CCL of 5/8/98 with the short joints and existing perfs at 12,705' to 12,725'. Peforate 12,725' to 12,745' with 4-1/2" guns. OTHCMP POH wi SWS guns, B/O and UD. OTHCMP P/U lubricator and UD same. SI well and monitor pressures. RID SWS and prepare to RlU Centrilift to run new ESP completion. RUNCMP Pick-up and service new ESP Assembly. 8/7/2004 00:00 - 00:30 00:30 - 03:00 03:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 10:30 10:30 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 18:30 18:30 - 19:00 19:00 - 22:00 22:00 - 00:00 8/8/2004 00:00 - 01 :00 01 :00 - 02:00 02:00 - 03:00 03:00 - 03:30 03:30 - 04:30 04:30 - 06:00 06:00 - 08:30 ~ ~ .' BP EXPLORATION Operations Summary Report Page 1 of 2 Spud Date: 2/23/1998 End: 1.50 KILL P 0.50 KILL 1.00 KILL P P 1.00 KILL P 1.00 WHSUR P 1.00 WHSUR P 1.50 BOPSUF P 3.50 BOPSUF P DECOMP DECOMP DECOMP DECOMP 0.50 BOPSUF P 0.50 BOPSUF P 1.00 WHSUR P 2.50 PULL 0.50 PULL 3.00 PULL 2.00 PULL P P P P DECOMP DECOMP DECOMP DECOMP 1.00 PULL P 1.00 PERFOE P 1.00 PERFOE P 0.50 PERFOE P 1.00 PERFOE P 1.50 PERFOE P 2.50 RUNCorfP Printed: 8/9/2004 9:35:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ~ /.--.... BP EXPLORATION Operations Summary Report Start: 8/6/2004 Rig Release: 8/9/2004 Rig Number: 4ES NPT I Phase I I ' MPL-40 MPL-40 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date I From - To ¡ Hours Task Code 8/8/2004 08:30 - 13:00 .... ..... .....-.....--- ..-..-.--. .........-... .-..-....-- ..uo.--. RUNCMP 13:00 - 15:00 15:00 - 18:30 18:30 - 19:00 19:00 - 20:30 20:30 - 21 :30 21 :30 - 22:00 22:00 - 23:30 8/9/2004 23:30 - 00:00 00:00 - 01 :00 RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 0.50 BOPSU P 1.50 WHSUR P RUNCMP RUNCMP 0.50 WHSUR P 1.00 WHSUR P RUNCMP RUNCMP Spud Date: 2/23/1998 End: Description of Operations .-.-.-..--- Start to RIH with ESP Assembly and 2 7/8" Tubing. Stop for reel to reel splice (-7,600'). Make reel to reel cable splice. Check cable. Continue RIH with ESP Assembly and 2 7/8" Tubing. M/U landing it and tubing hanger; install penetrator; cut cable and pull over sheave. Make upper cable connector splice, connect and test same. Good test. Land tbg hanger; P/U wt = 98K, SIO wt = 35K. RILDS; set and test TWC to 2500 psi; drain BOPE. N/D BOPE. N/U tree. Pressure test tubing head adaptor and tree to 5000 psi. P/U lubricator and pull and UD TWC. Install BPV, UD lubricator. Secure tree and cellar area. Rig released at 0100. Printed: 8/9/2004 9:35:34 AM . STATE OF ALASKA j ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Æ '. , - ,í "1' ~)Ù "'\-l\l~ /'/<7 >: 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program Change Out ESP 0 Repair Well 0 Plug Perforations 0 Stimulate II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown II Perforate 0 Re-Enter Suspended Well II Other 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 Class: III Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Dr!j1. Number 198-010 V 6. API Number: V 50- 029-22855-00-00 99519-6612 KBE = 50.60' 9. Well Name and Number: MPL-40 8. Property Designation: 11. Total Depth MD (ft): 13125 Casing Structural Conductor Surface Intermediate Production Liner 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): 7454 12957 7298 NIA Length Size MD TVD' Burst Junk (measured): 12389' - 12428' Collapse ADL 388235 74' 7524' 20" 9-5/8" 112' 7560' 112' 4515' 1490 5750 470 3090 13006' 7" 13040' 7375' 7240 5410 Perforation Depth MD (ft): 12690' - 12710' Packers and SSSV Type: nONE Perforation Depth TVD (ft): 7055' - 7073' Tubing Size: 2-7/8".6.5# Tubing Grade: L-80 Packers and SSSV MD (ft): Tubing MD (ft): 12596' 12. Attachments: 181 Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby ce~if that the foregoing is true and correct to the best of my knowledge. Printed Na e David Reem Title Drilling Engineer Signature .. ~ r --' ~ Phone Commission Use Only 0 BOP Sketch 13. Well Class after proposed work: 0 Exploratory 181 Development 0 Service August 03. 2004 Date: 15. Well Status after proposed work: iii Oil 0 Gas 0 WAG 0 GINJ 0 Plugged DWINJ 0 Abandoned 0 WDSPL Contact David Reem. 564-5743 Date +/15/04 Prepared By N&rr.eINumber' Sondra Stewman. 564-4750 Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity ~ Test 0 Mechanical Integrity Test 0 Location Clearance I Sundry Number: 3D tj-?7.?- Other: SS()a~\ ~,,~\~~~ ~C)ç' \-t:.S-\- COMMISSIONER APPROVED BY THE COMMISSION SUbSeqUenIF~~ Approved By: Form 10-403 Re . n D 1 G \ J\,1 ð 1 t8)\I.S Bf~ Date 1ftJ Iu/ ,~S~~licate Project: l\,IPL--t-O Add Perfs during R\VO to Changeout Failed ESP l\lPL--+O Status: SI Producer due to ESP failure Scope of \Vork: Though a frac was performed on !\'Pl--+O in 1998 via the A3 Sand perfs and is expected to have frac'd down into the A2 Sands, add perfs in the ..-\2 Sand are requested during the R\\¡'O, if accessible. to ensure the ..-\2 Sand is still in communication with the wellbore. If the tag with the existing tbg indicates that the desired add perf section is not covered with fill. A2 perfs will be added. Follow alll\,'PU/BP safety procedures - No accidents, spills, or harm to the environment! Nabors -I-ES 1) !\/IIRU Nabors -t-ES 2 ) Kill \Ve II 3) Pull existing failed ESP -t-) Tag fill {with existi ng ESP/tbg string) 5) If tag at 12750' 1\ID or deeper, add A2 perfs wI e-line from 12725' - 127-15' 1\ID using -t--l/2" HSO. -t-505 Power Jet @, 5 SPF. Reference log: 5/8/98 GR CCl 6) Run new ESP on same 2-7/8" tbg T) ROIVI0 Nabors -t-ES (Note: The current \Vellbore schematic lists the existing A3 Sand perfs from 12,690' - 12710' l'iIO which is based on the original L \VO log, these perfs were tied in to the 5/8/98 GR CCl log. These should be changed on the schematic to 12,705' - 12,725' l\IO to reference the 5/8/98 GR CCl log. The actual 5/10/98 CCl Perf Record collaborates that this was the section perf'd. though the telex for this event lists the perf section referenced to the L \\'0.) Tree: 2 9/16" - 5M CIW \ Wellhead: 11" 5M FMC Gen. 5a wI 7 1/16" FMC Tbg. Hng. .3" LH Acme top and 2-7/8" btm., 2.5' CIW "H" BPV profile 20" 91.1 ppf, H-40 112' I- KOP @ 300' Max. hole angle = 71 deg. @ 10,130' 60+ deg. (3,550' - 10,970') Hole angle thru' perfs = > 28 deg. 9 5/8", 40#/ft, L-80 Btrc. I 7.560' I j 2-7/8" 6.5 ppf. L-80, 8rd EUE tog ( drift 10 = 2 347", cap, = 00579 bpI 7" 26 ppf, L-80, BTC production casing ( drift 10 = 6.151", cap. = 0.0383 bpf ) Stimulation Summary 05/11/98 - Kuparuk A 55,480# of 16/20 CarboLile (w/ ChemFlow) + 118,385# of 16/20 CarboLite LTC behind pipe Perforation Summary Ref loa: GR/CCL dated 5/8/98 Size SPF Interval (TVO) 3-3/8 E 12.690'-12.710' 7.065'-7.07' MPU L-40 ~ T-l ~ t . ~ 3 I ~ I; '{ ~ r .~ ~ r;rJ ' l ~ I ot ~ ~ r-----f ,.. p , ~ , '. , ~' , . , ~. , j , . ; j , , , , . , , , < , I , , , . , , , , , ~~D" , ~ .. ~ ¡ ~: "4 ,~ ~ ~ ¡ , ¡ '. ,I ~ tl" :Xh ~ ':, 'i' ~:, ì .. ~'M~ ~. 00 , 0 , , d ~ ~.~ '4 '" , I: f ". ;1 .. ~ % % % ¿; ~~~ Orig( Elev. = 50.6' (N 27E) Orig. GL Elev. = 17.55' RT To Tbg. Spool = 33.0' (N 27E) Camco 2-7/8" x 1" sidepocket KBMM GLM 0 Howco ES cementer 130' 2139' I 12382' I 12525' I 12539' I 12560' I 12564' I 12578' I 12596' I 12958' I 130.¡O I DATE REV. BY COMMENTS MILNE POINT UNIT 03/08/98 MOO Drilled and cased 27E WELL L-40 05/11/98 KJW RWO - Perf and Frac API No: 50-029-22855 OS/22/98 M. Linder Initial Completion 4-ES 11/23/00 MOO ESP RWO 4-ES BP EXPLORATION (AK) i Cameo 2-7/8" x1" sidepocket KBMM GLM XN- Nipple.. 2.313" landing profile, 2.205" NO-GO Cenlrilift GC 2200 ESP, series 513, GPMTAR 1:1. 122 slgs. Purnp intélke ... gas separator I Ccnlrilift GSB3DBUTILH6PFS I seal section Cenlrilill KMH. 171 hfJ motor I 23QO v /44 amp Centtllift PHD X Marker Joints ( 12,389' - 12,428' ) ~ % % ~ 7" float collar (PBTD) 7" float shoe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _X WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4326' FNL, 2378' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 2358' FNL, 1994' FEL, Sec. 08, T13N, R10E, UM At effective depth 2324' FNL, 2230' FEL, Sec. 08, T13N, R10E, UM At total depth 2317' FNL, 2283' FEL, Sec. 08, T13N, R10E, UM 5. Type of Well: Development Exploratory Stratigraphic_ Service X (asp's 558083, 602923~, (asp's 547889, 6031130) (asp's 547653, 6031162) (asp's 547600, 6031169) 6. Datum elevation (DF or KB feet) RKB 48 feet 7.. Unit or Property name Miline Point Unit MPC-36 9. Permit number / approval number 198-0010 10. APl number 50-029-22853-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 112' Surface 8470' Production 13842' 13896 feet Plugs (measured) 7583 feet 13787 feet Junk [measured) 7495 feet Size Cemented 20" 250 sx Arcticset 1 (approx) 2156 SX PF 'E', 747 sx 9-5/8" Class 'G' 7" 225 sx Class 'G' MAR Measured Dep~!,,,.;:h,~.~.~.~9,.. True Vertical Depth 145' 145' 8501' 4750' 13871' 7561' Perforation depth: measured Open Perfs 13320'- 13333', 13360'-13374', 13385'-13392', 13468'-13520', 13542'-13550' true vertical Open Perfs 7088'-7099', 7122'-7133', 7143'-7149', 7213'-7258', 7276'- 7283' tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 TBG to 13479' MD. 7" x 3-1/2" S-3 Baker PKRs @ 13198' & 13259'; & 7" x 3-1/2" SABL-3 Baker PKR @ 13448'. 3.5" H.E.S. 'X' Nipple @ 2141'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 02/25/2003 Subsequent to operation 03/01/2003 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 1570 2236 Casing Pressure Tubing Pressure 4740 3131 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations 16. Status of well classification as: Oil Gas __ Suspended __ Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~ ~J~'~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · BFL ORIGINAL Date March 04, 2003 Prepared b~/DeWayne R, $chnorr 564-5174 SUBMIT IN DUPLICATE 02/27/2003 O2/27/O3 MPC-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS WAG SWAP --- GAS TO WATER INJECTION. EVENT SUMMARY WELL SUPPORT TECHS RIGGED UP AND GREASED TREE, FLUSHED SENSOR LINES, SWAPPED BLINDS AND CHECKED THE ORIFICE PLATE SIZE. ALL FLANGES WERE TORQUED TO SPEC. FESCO RIGGED UP AND PUMPED 10 METHANOL FOLLOWED WITH 90 BBLS SOURCE WATER AND THEN 3 BBLS METHANOL TO FREEZE PROTECT THE TRUCK. PUMPED FROM 1.4 TO 2.1 BPM FROM 4700 TO 3500 PSI. JOB WAS COMPLETED WITH NO PROBLEMS. FLUIDS PUMPED BBLS DISCRIPTION 13 METHANOL 90 SOURCE WATER 103 TOTAL Page 1 STATE OF ALASKA ALASKA,-:~L AND GAS CONSERVATION COMrv~--.~JION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 50.60' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service , 4. Location of well at surface " 8. Well Number 3142' NSL, 5018' WI:L, SEC. 8, T13N, R10E, UM MPL-40 At top of productive interval 9. Permit Number / Approval No. 198-010 742' NSL, 3641' WEL, SEC. 12, T13N, R9E, UM 10. APl Number At effective depth 50-029-22855-00 712' NSL, 3747' WEL, SEC. 12, T13N, R9E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 694' NSL, 3809' WEL, SEC. 12, T13N, R9E, UM Sands 12. Present well condition summary Total depth: measured 13125 feet Plugs (measured) true vertical 7454 feet Effective depth: measured 12957 feet Junk (measured) true vertical 7298 feet Casing Length Size Cemented MD TVD Structural Conductor 74' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 7524' 9-5/8" 1850 sx PF 'E', 750 sx Class 'G' 7560' 4515' Intermediate Production 13006' 7" 250 sx Class 'G' 13040' 7375' Liner Perforation depth: measured 12690' - 12710' ~ true vertical 7055' - 7073' ~" Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 12596' ~iaska ©ii & A~chor~ Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: ~ r 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the fore, going is true and correct to the best of my knowledge Signed TerrieHubble-~0~./~-"/ ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPL-40 Common Well Name: MPL-40 Spud Date: 212311998 Event Name: REPAIR Start: 11/22/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: Date From To HOurs I: :: : : - :Task: :~ :~ Phase:: :::::::::: ::::::::Descnptlon::of Ooe~ations~:: ::: :: ~: :~ :::: ::::: ::,: 1 1112212000 06:00 - 08:00 2.00 MOB PRE MOVE FROM J-24 TO MPU L-40. 08:00 - 10:30 2.50 RIGU PRE RIG UP RIG 4 ES. ACCEPTED RIG @ 1200 HRS. 10:30 - 12:00 1.50 RIGU PRE ~ISE & SCOPE DERRICK. 12:00 - 14:00 2.00 RIGU PRE ~U TIGER TANK & HARD LINES. 14:00 - 15:00 1.00 RIGU PRE ~U HCR VALVE & LINES TO TREE. 15:00 - 15:30 0.50 WHSUR DECOMP PULL BPV. SlTP 350 PSI. 15:30 - 16:30 1.00 KILL DEGOMP PRESSURE TEST LINES TO 2500 PSI. 16:30 - 17:00 0.50 KILL DEOOMP OPEN WELL. SlTP 450 PSI. SlOP 500 PSI. 17:00 - 21:00 4.00 KILL DEGOMP KILL WELL W/452 BBL S~WATER. 3 BPM 300 -1400 PSI. 21:00 - 21:30 0.50 KILL DEOOMP OBSERVE WELL, WELL DEAD. 21:30 - 22:00 0.50 WHSUR DECOMP SET ~C VALVE & TEST SAME TO 3000 PSI. 22:00 - 23:00 1.00 WHSUR DECOMP BLEED OFF HANGER VOID & N/D TREE. 23:00 - 00:00 1.00 BOPSUF DEOOMP N/U BOPE. 11/23/2000 00:00 - 01:00 1.00 BOPSUF DEOOMP N/U BOPE. 01:00 - 03:30 2.50 BOPSUF DECOMP PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSi. 03:30 - 04:00 0.50 WHSUR DECOMP PULL ~C. 04:00 - 05:00 1.00 WHSUR DEOOMP TP 10 PSI, CP 60 PSI. BLEED OFF PRESSURE. 05:00 - 08:00 3.00 PULL DECOMP MAKE UP ~NDING JT & PULL HANGER TO FLOOR. PULLED 120K. MONITOR WELL & SHOOT FLUID LEVEL. UD HANGER & ~NDING JT. 08:00 - 10:30 2.50 PULL DEGOMP PULL OUT OF HOLE W/COMPLETION. SHOOT F/L EVERY 10 STANDS. 10:30 - 11:00 0.50 PULL DEOOMP CHANGE OUT SPOOL ~ SPLICE ~ 4300'. 11:00- 16:30 5.50 PULL DEOOMP PULLOUTOF HOLE W/ COMPLETION. 16:30 - 21:30 5.00 PULL DECOMP UD ESP & DESANDER ASSY. PUNCH HOLES IN TBG TAIL PIPE & UD SAME. HAD 75' SAND IN ~ST 2 1/2 JTS. RUBBER DANCED. (SEE E-MAIL PHOTOS) 21:30 - 23:00 1.50 PULL DECOMP UD TBG PUNCH. CL~R FLOOR & ~U TO RUN COMPLETION. 23:00 - 00:00 1.00 PULL DECOMP P/U NEW ESP & SERVICE SAME. 1112412000 00:00 - 08:00 8.00 RUNOOA~ COMP TRIP IN HOLE W/COMPLETION 08:00 - 11:00 3.00 RUNCOA~ COMP ~KE MID RUN CABLE SPLICE. 11:00 - 14:00 3.00 RUNCOA COMP RUN IN HOLE W/COMPLETION. 14:00 - 14:30 0.50 RUNGOA COMP MAKE UP ~NDING JT. 14:30 - 16:30 2.00 RUNOOA COMP INSTALL & TEST PENET~TOR. 16:30 - 17:00 0.50 RUNCOA COMP ~NDIND COMPLETION STRING ~ 12595'. RILDS. 17:00 - 17:30 0.50 RUNCOA COMP INSTALL & TEST ~C VALVE. 17:30 - 19:00 1.50 BOPSUR COMP N/D BOPE. 19:00 - 20:00 1.00 WHSUR COMP N/U & TEST X-MAS TREE. 20:00 - 20:30 0.50 WHSUR COMP PRESSURE TEST ADAPTER F~NGE & ESP. 20:30 - 21:30 1.00 WHSUR: COMP PULL ~C & INSTALL BPV. 21:30 - 22:00 0.50 WHSUR COMP SECURE WELL & CLaN CEL~R. REL~SE RIG ~ 2200 HRS, 11-24-00. FEB 0 7 200! Aiask~ Oi! & G~s Cons, Commission Anohorag~ Printed: 11/28/2000 8:54:21 AM MEMORANDUM TO: THRU: Julie Heusser, "~\~ Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 22, 2000 FROM: John Crisp, Petroleum Inspector SUBJECT: Safety Valve TeSts Milne Point Field L Pad December 22, 2000: I traveled to BPx's Milne Point Field L Pad to witness Safety Valve System tests. I conducted wellhouse inspections during SVS tests. Larry Niles was BP rep. in charge of SVS testing. As usual, Larry was ready to begin testing as soon as I arrived on location. Wellhouses on L Pad are heated & have lights, this makes for safe working conditions & minimal SVS failUres. Wellhouses are clean & in good condition. The ^OGCC test report is attached for SVS failure reference. SUMMARY: I traveled to BPX MPU L Pad for SVS tests. 20 wells, 40 components tested. 1 Failure witnessed. 2.5% failure rate. 20 wellhouses inspected. No failures to report, Attachments: SVS MPU L pad 12-22-00jc cc; NON-CONFIDENTIAL SVS MPU L Pad 12-22,00jc.doc Alaska Oil and Gas ConserVation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: John Crisp Submitted By: John Crisp Field/Unit/Pad: PBU MPU L Pad Separator Psi: LPS 140 Date: 12/22/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLE L-01 1840050 L-02 1900060~ 140 100 90 P P OIL L-03 1900070! L-04 1900380 140! 100 105 P P OIL L-05 1900390~ 140! 100 100 P P OIL L-06 1900100 140 100 100 P P - OIL, L-07 1900370 140 100' 1001 P P OILI L-08 1901000 4000 2000' 1950 P P WAG L-09 1901010! L-Il 1930130 140 100 115 P P OIL L-12 1930110 140 100 100 p p oIL L-13 1930120 140 100 100 P P OIL L-14 1940680 1401 100 95 P P , OIL L-15 I 1940620 L-16A 1990900 L-17 1941690 L-20 1971360 140 100 100 P P OIL L-25 1951800 140 100 105 P P: OIL L-28A 1982470 140 100 110 P P OIL L-29 1950090 140 100 95 P P OIL L-32 1970650 140 100 100 P P OIL , L-33 1971050 . L-35 1970920 140 100 105 P P OIL L-36 1971480 140 100 105 P P ' OIL L-37A 1980560 L-40 1980100 140 100 100 P P U--~\~ ~ -X~ .~,c~ \~ ' OIL L-45 1981690 140 100 105 P P ~' OIL · ! , L-34 1970800 4000 2000 1900 P 4- WAG ,, Wells: 20 CompOnents: 40 Failures: 1 FailUre Rate: 2.5% Remarks: /9.6/00 Page 1 of 2 SVS MPU L Pad 12-22-00jc.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE Page 2 0£2 SVS MPu L Pad 12-22-OOjc.xls Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage,' Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 18, 1998 TO: BP Exploration (Alaska) Inc. Petmtectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Measured Depth CDR/ADN, CDR/ADN TVD'S for well MPL-40, Job # 98160 was sent to: 0 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS- 8/14/98 3 Bluelines each 1 film each /.--'"State of Alaska // Alaska Oil & Gas Conservation ~ Attn: Lori Taylor L3001 Porcupine Drive Anchorage, AK 99501 I OH L~ T~~~'~~ I Blueh'ne each "~ 1 RFolded Sepia each ~ Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 ~I-OFt~S Tape 1 Blueline each 1 RFolded Sepia each Sent Certified Mail: P 067 695 487 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska Date Delivered: AUG £0 998 Oil & Gas Cons. Commission ~,n~n~n~. Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by~~~ 8/4/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11398 Company: Field: Alaska Oil & Gas Cona Corem Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 MIIne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPH-13 ;~Z.~~._ 98397 GR/CCL 980531 1 MPL-40 ~ . 98399 GR/BCL 980508 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center MB3-3 900 E. Benson .Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Ala~618-1199 Received by: / ~ -~~ ~'/ · .~ STATE OF ALASKA - .- ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas I-q Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-10 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22855 4. Location of well at surface ,.-~-,,---,,,~,--, 9. Unit or Lease Name 3142' NSL, 5018' WEL, SEC. 8, T13N, R10E, UM-! ..... ,,.;~-~.,:~ :~:,-~ ~ i Milne Point Unit At top of productive intervali' -~'~)~¢~¢~_,~_,-,/ !i'%_~_ ~,--r, ~ ,"-~ 10. Well Number 748' NSL, 3627! WEL, SEC. 12, T13N, i9E, UM ~ MPL-40 699' NSL, 3795' WEL, SEC. 12, T13N, ReE, UM ! -~-~--.~i* ~' 11. Field and Pool ,-., ...... -~-;r.. j'. Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Desigh~'~ion and Serial No. Sands KBE = 50.60' ADL 388235 12. Date Spudded2/23/98 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' water depth' if OffshOre 116' NO' Of cOmpletiOns3/4/98 5/15/98 N/A MSLI One 117. Total Depth (MD+TVD)[18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost'" 13125 7454 FTI 12957 7298 FTI [~Yes I--INo N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/CCL 23. CASlNG~ LINER AND CEMENTING RECORD CASING SEq-I'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 7560' 12-1/4" 1850 sx PF 'E', 750 sx Class 'G' 7" 26# L-80 34' 13040' 8-1/2" 250 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 12665' MD TVD MD TVD 12690'-12710' 7056'-7074' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 75 bbls diesel Frac, 12690'-12710' 167105# 16/20 Carbolite Chemflow/LTC behind pipe :27. PRODUCTION TEST i Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 6, 1998 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF IWATER-BBL i CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 'B' 12625' 6997' Top Kuparuk A3 12690' 7056' Top Kuparuk A2 12709' 7073' 31. List of Attachments Summary of Daily Drilling Reports, Surveys Signed T.~re~Res~j~~~~~ Drilling Engineering Supervis°r Date ~//~tT/~/~ MPL-40 98-10 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS G£NE,AL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). I'rEM 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'. RElieVED jUL 3 ! 1998 Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 22:39, 17 Jun 98 Page 1 The analysis is from - 03:00, 02 Mar 98 - to - 03:00, 02 Mar 98 Programs in Result Table: MPL-40 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPL-40 Event 03:00, 02 Mar 98 03:00, 02 Mar 98 0 hr 0 min Obtained leak off 13.2 Hole Size MDR 8-1/2 Progress Report Facility M Pt L Pad Well MPL-40 Rig Nabors ~fl 7,~~' Page 1 Date 17 June 98 Date/Time 21 Feb 98 22 Feb 98 23 Feb 98 24 Feb 98 25 Feb 98 26 Feb 98 27 Feb 98 20:30-01:00 01:00-01:30 01:30-06:00 06:00-06:15 06:15-18:00 18:00-18:15 18:15-22:00 22:00-02:00 02:00-05:30 05:30-06:00 06:00-06:30 06:30-10:30 10:30-12:00 12:00-15:00 15:00-15:30 15:30-16:30 16:30-18:30 18:30-18:45 18:45-06:00 06:00-06:15 06:15-14:00 14:00-14:30 14:30-15:00 15:00-16:00 16:00-18:00 18:00-18:15 18:15-04:30 04:30-06:00 06:00-06:15 06:15-06:30 06:30-08:30 08:30-09:00 09:00-10:00 10:00-14:00 14:00-18:00 18:00-18:15 18:15-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:15 06:15-06:30 06:30-18:00 18:00-18:15 18:15-22:30 22:30-00:30 00:30-06:00 06:00-07:30 07:30-10:00 10:00-12:30 12:30-12:45 12:45-15:30 15:30-18:30 18:30-20:00 Duration 4-1/2 hr 1/2 hr 4-1/2 hr 1/4 hr 11-3/4 hr 1/4 hr 3-3/4 hr 4hr 3-1/2 hr 1/2 hr 1/2 hr 4hr 1-1/2 hr 3hr 1/2 hr lhr 2hr 1/4 hr 11-1/4 hr 1/4 hr 7-3/4 hr 1/2 hr 1/2 hr lhr 2hr 1/4 hr 10-1/4 hr 1-1/2 hr 1/4 hr 1/4 hr 2hr 1/2 hr lhr 4hr 4hr 1/4 hr 8-3/4 hr 1-1/2 hr lhr 1/2 hr 1/4hr 1/4 hr 11-1/2 hr 1/4 hr 4-1/4 hr 2hr 5-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1/4 hr 2-3/4 hr 3hr 1-1/2 hr Activity Rigged down Lines / Cables Held safety meeting Rig moved 30.00 % Held safety meeting Rig moved 80.00 % Held safety meeting Rig moved 100.00 % Rigged up Divertor Racked back drill pipe Held safety meeting Held safety meeting Racked back drill pipe Tested Divertor Made up BHA no. 1 Tested Standpipe manifold Drilled to 267.0 ft Made up BHA no. 1 Held safety meeting Drilled to 1279.0 ft Held safety meeting Drilled to 2589.0 ft Circulated at 2589.0 ft Pulled out of hole to 1000.0 fi R.I.H. to 2589.0 fi Drilled to 2870.0 ft Held safety meeting Drilled to 4747.0 ft Circulated at 4747.0 ft Held safety meeting Rest hole at 4747.0 ft Pulled out of hole to 100.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 4747.0 ft Drilled to 5240.0 ft Held safety meeting Drilled to 6364.0 ft Circulated at 6364.0 ft Pulled out of hole to 4500.0 ft R.I.H. to 5500.0 ft Held safety meeting R.I.H. to 6364.0 ft Drilled to 7303.0 ft Held safety meeting Drilled to 7585.0 ft Circulated at 7585.0 ft Pulled out of hole to 2200.0 fi Pulled out of hole to 1000.0 fi R.I.H. to 7585.0 fi Circulated at 7585.0 ft Held safety meeting Pulled out of hole to 209.0 ft Pulled BHA Rigged up Casing handling equipment jUL Anchorage D Progress Report Facility M Pt L Pad Well MPL-40 Rig Nabors 4~8 $Z~ Page 2 Date 17 June 98 Date/Time 20:00-20:30 20:30-05:00 28 Feb 98 05:00-05:30 05:30-06:00 06:00-08:00 08:00-08:15 08:15-11:00 11:00-14:30 14:30-16:30 16:30-17:00 17:00-19:30 19:30-19:45 19:45-21:00 21:00-22:00 22:00-02:00 01 Mar98 02:00-03:00 03:00-06:00 06:00-06:15 06:15-08:00 08:00-08:30 08:30-11:30 11:30-13:00 13:00-14:30 14:30-17:00 17:00-18:00 18:00-19:00 19:00-19:15 19:15-21:00 21:00-22:00 22:00-01:00 02 Mar 98 01:00-02:00 02:00-03:00 03:00-06:00 06:00-06:15 06:15-18:00 18:00-18:15 18:15-00:30 03 Mar 98 00:30-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-00:30 04 Mar 98 00:30-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-16:30 16:30-18:00 Duration 1/2hr 8-1/2 hr 1/2 hr 1/2hr 2hr 1/4 hr 2-3/4 hr 3-1/2 hr 2hr 1/2 hr 2-1/2 hr 1/4 hr 1-1/4 hr 1 hr 4hr lhr 3hr 1/4 hr 1-3/4 hr 1/2 hr 3hr 1-1/2 hr 1-1/2 hr 2-1/2 hr lhr lhr 1/4 hr 1-3/4 hr lhr 3hr lhr lhr 3hr 1/4 hr 11-3/4 hr 1/4 hr 6-1/4 hr 1-1/2 hr 1-1/2 hr lhr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 6hr 1-1/2 hr lhr lhr 2hr 1/2 hr 1/2 hr 2hr 7-1/2 hr 1-1/2 hr Activity Held safety meeting Ran Casing to 7560.0 ft (9-5/8in OD) Rigged up Cement head Circulated at 7560.0 ft Circulated at 7560.0 ft Held safety meeting Mixed and pumped slurry - 417.000 bbl Circulated at 2139.0 ft Mixed and pumped slurry - 463.000 bbl Rigged down Cement head Serviced Drillfloor / Derrick Held safety meeting Rigged down Divertor Installed Casing head Rigged up BOP stack Installed BOP test plug assembly Tested BOP stack Held safety meeting Tested BOP stack Retrieved BOP test plug assembly Made up BHA no. 3 R.I.H. to 2139.0 ft Drilled installed equipment - DV collar R.I.H. to 5000.0 ft Held drill (Stripping) Held drill (Kick (well kill)) Held safety meeting R.I.H. to 7475.0 ft Tested Casing Drilled installed equipment - Landing collar Circulated at 7605.0 ft Performed formation integrity test Drilled to 7976.0 ft Held safety meeting Drilled to 9478.0 ft Held safety meeting Drilled to 10503.0 ft Circulated at 10503.0 ft Pulled out of hole to 7500.0 ft Serviced Top drive R.I.H. to 10503.0 ft Held safety meeting Drilled to 11814.0 ft Held safety meeting Drilled to 12379.0 ft Circulated at 12379.0 ft Pulled out of hole to 10500.0 ft R.I.H. to 12379.0 ft Drilled to 12567.0 ft Held safety meeting Drilled to 12575.0 ft Repaired Kill manifold Drilled to 13125.0 ft Circulated at 13125.0 ft jUL ! 998 Alaska Oi! & Oas Cons. (;om Anchoras,3 -fiiSSlOr~ Facility M Pt L Pad Progress Report Well MPL-40 Rig Nabors ~ ~, ~ Page 3 Date 17 June 98 Date/Time 05 Mar 98 06 Mar 98 18:00-18:30 18:30-21:00 21:00-22:00 22:00-00:00 00:00-02:00 02:00-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-11:30 11:30-13:00 13:00-14:30 14:30-21:00 21:00-21:30 21:30-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-10:30 10:30-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-23:00 23:00-06:00 Duration 1/2 hr 2-1/2 hr lhr 2hr 2hr 4hr 1/2 hr lhr 3hr lhr 1-1/2 hr 1-1/2 hr 6-1/2 hr 1/2 hr 4-1/2 hr 4hr 1/2 hr 1-1/2 hr 2hr 1/2 hr 7-1/2 hr 1/2 hr 1/2 hr 3hr lhr 7hr Activity Held safety meeting Pulled out of hole to 7560.0 ft Serviced Block line R.I.H. to 13125.0 ft Circulated at 13125.0 ft Pulled out of hole to 9000.0 ft Held safety meeting Pulled out of hole to 1000.0 ft Pulled BHA Installed BOP test plug assembly Tested Top ram Rigged up Casing handling equipment Ran Casing to 7560.0 ft (7in OD) Circulated at 7560.0 ft Ran Casing to 13105.0 ft (7in OD) Circulated at 13105.0 ft Held safety meeting Circulated at 13040.0 ft Mixed and pumped slurry - 51.000 bbl Tested Casing Rigged down BOP stack Held safety meeting Rigged up Drillfloor / Derrick Installed Xmas tree Freeze protect well - 75.000 bbl of Diesel Laid down 12000.0 ft of 5in OD drill pipe Progress Report Facility M Pt L Pad Well MPL-40 Rig Nabors 4ES Page 1 Date 17 June 98 Date/Time 09 May 98 03:00-06:00 06:00-07:00 07:00-08:00 08:00-11:00 11:00-12:00 12:00-12:15 12:15-13:00 13:00-15:00 15:00-18:30 18:30-18:45 18:45-19:00 19:00-01:30 10 May 98 01:30-03:30 03:30-04:00 04:00-06:00 06:00-06:15 06:15-06:30 06:30-11:30 11:30-13:30 13:30-14:00 14:00-15:00 15:00-16:30 16:30-16:45 16:45-18:00 18:00-18:15 18:15-20:30 20:30-21:00 21:00-22:00 22:00-23:30 23:30-23:45 23:45-00:30 11 May 98 00:30-01:30 01:30-02:00 02:00-06:00 06:00-06:15 06:15-07:30 07:30-19:30 19:30-21:00 21:00-21:30 21:30-22:00 22:00-22:30 22:30-04:00 12 May 98 04:00-06:00 06:00-07:00 07:00-10:30 10:30-11:00 11:00-18:30 18:30-23:00 23:00-01:30 13 May 98 01:30-02:00 02:00-02:45 02:45-06:00 06:00-06:30 06:30-12:30 Duration 3 hr lhr lhr 3hr lhr 1/4 hr 3/4 hr 2hr 3-1/2 hr 1/4 hr 1/4 hr 6-1/2 hr 2hr 1/2 hr 2hr 1/4 hr 1/4 hr 5hr 2hr 1/2 hr lhr 1-1/2 hr 1/4 hr 1-1/4 hr 1/4 hr 2-1/4 hr 1/2 hr lhr 1-1/2 hr 1/4hr 3/4 hr lhr 1/2 hr 4hr 1/4hr 1-1/4 hr 12hr 1-1/2 hr 1/2 hr 1/2 hr 1/2hr 5-1/2 hr 2hr lhr 3-1/2 hr 1/2 hr 7-1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 3/4 hr 3-1/4 hr 1/2 hr 6hr Activity Installed High pressure lines Installed High pressure lines (cont...) Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Drillfloor / Derrick Monitor wellbore pressures Removed Xmas tree Installed BOP stack Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Installed Tubing handling equipment Ran Tubing to 2125.0 ft (4-1/2in OD) Circulated at 2125.0 ft Ran Tubing to 4512.0 ft (4-1/2in OD) Held safety meeting Serviced Drillfloor / Derrick Ran Tubing to 12948.0 ft (4-1/2in OD) Reverse circulated at 12948.0 ft Laid down 913.0 ft of Tubing Serviced Block line Rigged up Lubricator Held safety meeting Rigged up Lubricator Held safety meeting Perforated from 12690.0 ft to 12710.0 ft Conducted electric cable operations Rigged down Logging/braided cable equipment Rigged up High pressure lines Held safety meeting Tested High pressure lines Injectivity test - 304.000 bbl injected at 4800.0 psi FRAC job - 439.000 bbl injected at 5000.0 psi Monitor wellbore pressures Monitor wellbore pressures (cont...) FRAC job - 1447.000 bbl injected at 4795.0 psi Monitor wellbore pressures Reverse circulated at 12035.0 ft Flow check Reverse circulated at 12035.0 ft Ran Drillpipe to 12299.0 ft (3-1/2in OD) Reverse circulated at 12563.0 ft Monitor wellbore pressures Monitor wellbore pressures (cont...) Reverse circulated at 12563.0 ft Monitor wellbore pressures Reverse circulated at 12948.0 ft Monitor wellbore pressures Reverse circulated at 12948.0 ft Monitor wellbore pressures Laid down 939.0 ft of 3-1/2in OD drill pipe Laid down 3442.0 ft of Tubing Held safety meeting Laid down 12948.0 ft of Tubing Oil & Gas Cons. Corn: A..nchorase tiSSl0r~ Facility M Pt L Pad Progress Report Well MPL-40 Page 2 Rig Nabors 4ES Date 17 June 98 Date/Time 14 May 98 15 May 98 12:30-13:30 13:30-19:00 19:00-21:30 21:30-02:30 02:30-03:00 03:00-05:30 05:30-06:00 06:00-11:00 11:00-15:00 15:00-19:00 19:00-21:30 21:30-23:30 23:30-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-10:00 Duration lhr 5-1/2 hr 2-1/2 hr 5hr 1/2 hr 2-1/2 hr 1/2 hr 5hr 4hr 4hr 2-1/2 hr 2hr 3hr lhr lhr 1-1/2 hr 4hr Activity Tested Variable ram Ran Tubing to 6000.0 ft (2-7/8in OD) Reverse circulated at 6000.0 ft Ran Tubing to 12925.0 ft (2-7/8in OD) Laid down 238.0 ft of Tubing Reverse circulated at 12687.0 ft Flow check Pulled Tubing in stands to 0.0 ft Rigged up sub-surface equipment - ESP Ran Tubing in stands to 7000.0 ft Rigged up sub-surface equipment - Electric cable Ran Tubing in stands to 12665.0 ft Installed Tubing hanger Installed Xmas tree Tested Xmas tree Freeze protect well - 75.000 bbl of Diesel Freeze protect well - 75.000 bbl of Diesel Alaska Oil a Gas Cons. Co~ ..'z Milne Point Unit, Alaska TO: MPU TelexGroup FROM: Kirby Walker Well Name: IMPL-40 Main Category: IPERF Sub Category: IE-LINE Operation Date: 15/10/98 MPU FILE COPY Date: I May 10, 1998 Objective: To perforate the Kuparuk A sand from 12,690' - 12,710' using Atlas' 3-3/8' Ultrapack charges, 60 degree phase, 6 spf. ~ Sequence of Events: · 14:30 16:45 17:30 17:50 19:20 19:34 19:58 20:02 20:10 20:50 Atlas on location. Safety meeting in doghouse Pickup gun assembly RIH Stop at 12,500' to tie in short joints RIH to 12,810' - adjust counters Log on depth Fire guns - positive indication of guns fired POOH On surface with guns. RDMO Atlas Results: '~. Perforated from 12,690' to 12,710' using 3-3/8' guns, 6 spf, 60 I/I~Tiein log/date 5-8-98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing ,, '-,.- t_998 jul_ ~aska Oil & Gas Cons. Page I . ,~ -. MPU FILE COPY BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: FROM: DATE: RE: Xiuxu Ning Kirby Walker -.AIrily., 1998 L-40 (Kuparuk A) Injectivity Test, DataFRAC AND FRAC SERVICE CO'S.: Dowell, Peak, Nabors JOB SUMMARY The 90 BBL Injectivity Test was circulated down the tubing (12,035') at 8 BPM. ~With the crosslinked fluid 10 BBL from the tubing tail the rate was dropped to 4 BPM and the annular preventers were closed. Rate was then increased to max available (30 BPM) until the XL fluid was displaced 5 BBL into the formation. At which point the pumps were shutdown and ISIP recorded. It was decided from the Iow Near-Wellbbre- Friction (257 psi) not to pump a scour stage. A 250 BBL DataFRAC was' bullheaded at 25 BPM into the formation and underdisplaced by 10 BBLs. Pumps were shutdown and pressure monitored for about 30 minutes. Closure occurred in 3.84 minutes at 2,390 psi and leakoff was determined to be 0.0025 ft2/min. Anchorage decided to pump the schedule as planned, leakoff of 0.003 ft2/min. After waiting on the PCM to be repaired the job was able to be pumped. Screenout started 37.6 minutes after pad was on perfs and continued to rise until the end of the job. A total increase of around 1400 psi in Net pressure was seen. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final STP psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft 25 90 30 4375 2280 257 0.78 DATA FRAC Bbls ISIP Closure Closure Time Leakoff NWB friction, Treat grad, Pumped psi Pressure observed psi psi/ft 250 2521 2390 3.84 0.0025 103 0.80 Page 2 FRAC Sand Prop Lead-in Prop Tail-in Prop Liner Sand, Treesaver pumped, # behind pipe, Type /# Type /# M# rubber left Job was M# in hole? Pumped to 173,825 167,105 16/20 16/20 LTC / N/A N/A completion ChemFIow / 118,385ff 55,440 Ft of sand Estimated Final ISIP, psi ISIP Incr % PAD TSO, TSO, in Pipe sand top STP, over (pad/slurry) design, min Nolte psi DataFRAC Plot 522 12,167 4,581 3,809 1,288 20.4% 11.2 37.6 Operational problems - While priming up the pumps and other equipment a small water leak was noticed coming from one of the PCM tanks. The leak was contained enough for the PCM to mix one full tank of gel, enough fluid for. the Injectivity Test, DataFRAC, and one scour stage if needed. The PCM was then taken to Kuparuk for repair. - During 7 PPA stage pump #1 acqui.red a leak in the fuel line. NO fuel was spilt. Pump was taken off line and other pumps' rates were increased to compensate. Comments - The 2 different types of proppant made it quite difficult to control the fluids. Multiple tests were done on location with both types of proppant and samples of the fluid actually mixed for the job. The activator concentrations were determined for each type of,,proppant at each proppant concentration. Throughout the job samples were taken...all looked good. The'QA/QC on the fluids was.superbly done! TIME OPERATIONS SUMMARY 00:40 Pressure Test lines to 8,000 psi 01:30 DataFRAC 02:30 Shutdown - wait on PCM 06:10 FRAC PUMPING SUMMARY Page 3 ~ BPM I PS~GIPS~GI BBL BBL COMMENTS INJECTIVITY TEST DISPLACEMENT = 208.0 BBLS 00:44 10 19 1345 90 - Circulate Inj. Test to tubing tail YF140D 00:54 8 16 2420 216 90 Start Displacement seawater 01:05 4 706 1670 177 Slow rate: close annular rams 01:06 25 2198 3487 180 Increase Rate 01:08 30 2346 3839 251 Increase Rate 01:10 0 2260 1927 306 S/D ISIP- 2380 psi NWBF- 257 psi Grad. - 0.78 DATA FRAC 01:30 25 2304 3794 250 - Start DataFRAC 01:40 25 2238 4778 189 250 Displace DF w/seawater 01:48 - 2233 2535 439 S/D - Monitor Pressure~ ISIP - 2521 psi NWBF - 103 psi Grad. - 0.80 FRAC 06:10 25 2182 3628 275 - Start Pad 06:19 25 2043 4572 208 Pad on zone 06:21 25 2264 4860 255 275 Start 1 PPA (ChemFIow) 06:29 25 2376 4114 483 1 PPA on zone 06:32 25 2335 4009 52 530 Start 2 PPA . 06:33 25 2308 3963 83 58".2 Start 3 PPA 06:37 25 2281 3940 112 665 Start 4 PPA 06:40 25 2262 3903 738 2 PPA on zone 06:41 25 2259 3903 137 776 Start 5 PPA 06:42 25 2257 3926 790 3 PPAon zone 06:46 25 2209 4132 873 4 PPAon zone : 06:46 25 2202 4123 885 Switch to LTC 06:47 25 2202 4032 158 913 Start 6 PPA 06:50 25 2195 3931 984 5 PPAon zone 06:53 25 2152 3954 177 1071 Start 7 PPA 06:54 25 2147 3995 1093 LTC on zone 06:55 25 2149 4013 1121 6 PPA on zone - drop pump 1 07:00 25 2310 4215 158 1248 Start 8 PPA 07:02 25 2370 4302 1279 7 PPAon zone 07:07 25 2693 4796 1427 Start FLUSH 07:09 25 2718 4911 1456 8 PPAon zone 07:15 25 3441 4563 1614 S/D ISIP - 3809 psi JUL 5 i 1998 ~*Jaska 0i] & Gas Cons, Colllf".qisslor, Anchorage -. Page 4 FLUIDS PUMPED DOWNHO~I~ INJ TEST& DATA FRAC: 745 Bbls FRAC: 1447 Bbls 2192 Bbls ****TOTAL FLUIDS PUMPED DOVVN HOLE LOAD VOLUME GEL QUALITY CONTROL CHECK seawater seawater GEL GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.5 95 6.9 34 8.3 3:36 8.6 FLUID ADDITIVES J-877 (slurry gel - guar) Adomite Regain - run in PAD J-475 (encapsulated break'er) - L-10 (MgO crosslinker) F-75N (surfactant) - J-899 (activator) Alaska Oi} & '*'"" '~ ..... ~"'¢~' ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Milne Point Unit 04-Mar-98 17:00:00 Page 1 of 6 Well ..................... : MPL-40 Spud date ................ : 23-Feb-97 API number ............... : 50-029-22855-00 ~st survey date ......... : 04-Mar-98 Engineer ................. : Milt Cooper Total accepted surveys...: 195 MD of first survey ....... : 0.00 ft Rig: ..................... : Nabors 27E MD of last survey ........ : 13027.24 ft State: ................... : Alaska ORIGINAL BPXA PDC Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : MSL Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : KB above permanent ....... : ~F above permanent ....... : ,, ,, Vertical section origin- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 17.55 ft 50.60 ft 50.60 ft 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : n/a Departure (+E/W-) ........ : n/a Azimuth from rotary table to target: 255.36 degrees Geomagnetic data Magnetic model ........... : BGGM version 1997 Magnetic date ............ : 21-Mar-1998 Magnetic field strength..: 1145.72 HCNT Magnetic dec (+E/W-) ..... : 27.77 degrees Magnetic dip ............. : 80.74 degrees MWD survey Reference Criteria Reference G .............. : 1003.00 mGal Reference H .............. : 1145.00 HCNT Reference Dip ............ : 80.74 degrees Tolerance of G ........... : (+/-) 3.00 mGal Tolerance of H ........... : (+/-) 7.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections Magnetic dec (+E/W-) ..... : 27.78 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.78 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1998 Anadrill IDEAL ID5 ANADRILL SCHLUMBERGER Survey Report 4-Mar-98 17:00:00 Page 2 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.0 2 205.38 0.15 58.3 3 295.42 0.72 263.9 4 385.30 1.51 263.3 5 476.98 2.00 260.3 0.00 205.40 90.00 89.90 91.70 TVD depth (ft) 0.00 205.40 295.40 385.28 476.94 6 567.61 2.72 255.6 90.60 567.46 7 657.57 4.22 254.4 90.00 657.29 8 747.13 5.07 252.7 89.50 746.50 9 834.97 6.13 251.2 87.90 833.98 10 926.55 7.87 251.5 91.50 924.79 11 1021.20 9.54 255.2 94.70 1018.40 12 1113.70 11.84 257.3 92.50 1109.29 13 1209.55 13.47 257.6 95.80 1202.76 14 1299.77 15.54 253.1 90.30 1290.18 15 1395.36 16.64 252.3 95.60 1382.03 16 1486.37 17.38 251.5 91.00 1469.05 17 1580.91 19.01 252.8 94.50 1558.82 18 1673.75 21.12 254.7 92.90 1646.08 19 1767.38 21.58 255.6 93.60 1733.25 20 1860.79 21.07 256.0 93.40 1820.26 21 1955.55 23.65 254.1 94.80 1907.93 22 2047.93 26.47 254.7 92.30 1991.53 23 2144.63 29.53 255.3 96.70 2076.90 24 2238.85 32.19 255.1 94.20 2157.76 25 2330.91 32.49 254.9 92.10 2235.57 26 2424.81 35.00 254.4 93.90 2313.64 27 2518.42 37.67 254.5 93.60 2389.04 28 2611.94 40.55 255.1 93.50 2461.58 29 2705.37 42.51 256.1 93.50 2531.57 30 2799.13 44.25 256.1 93.70 2599.67 Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (deg) I00f) type 0.00 -0.26 0.19 1.92 4.71 8.44 13.88 21.13 29.69 40.81 55.13 72.28 93.25 115.85 142.32 168.89 198.35 230.20 264.28 298.24 334.30 373.38 418.78 467.09 516.36 568.51 623.96 682.93 744.91 809.26 0.00 0.00 0.14 0.23 0.14 -0.23 -0.06 -1.97 -0.47 -4.75 -1.27 -8.39 -2.69 -13.65 -4.75' -20.59 -7.42 -28.75 -10.98 -39.31 -15.04 -53.05 -19.09 -69.72 -23.64 -90.21 -29.42 -112.05 -37.30 -137.35 -45.58 -162.65 -54.61 -190.74 -63.50 -221.34 -72.23 -254.28 -80.56 -287.21 -89.90 -322.03 -100.40 -359.69 -112.14 -403.54 -124.48 -450.25 -137.23 -497.84 0.00 0.00 0.00 0.27 58.30 0.07 0.27 301.52 0.95 1.97 268.40 0.88 4.77 264.40 0.54 8.48 261.41 0.82 13.91 258.86 1.67 21.14 257.01 0.96 29.69 255.53 1.22 40.82 254.40 1.90 55.14 254.17 1.86 72.29 254.69 2.52 93.25 255.31 1.70 115.85 255.29 2.61 142.32 254.80 1.17 168.92 254.35 0.85 198.40 254.02 1.78 230.27 253.99 2.38 264.34 254.14 0.60 298.29 254.33 0.57 334.35 254.40 2.83 373.44 254.40 3.07 418.83 254.47 3.18 467.14 254.55 2.83 516.40 254.59 0.35 -151.05 -548.13 568.56 254.59 2.69 -165.91 -601.55 624.01 254.58 2.85 -181.36 -658.47 682.99 254.60 3.11 -196.77 -718.51 744.97 254.68 2.21 -212.23 -780.98 809.30 254.80 1.86 TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1998 Anadrill IDEAL ID5 OB 68R] _ -- ANADRILL SCHLUMBERGER Survey Report 4-Mar-98 17:00:00 Page 3 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 2893.81 46.33 256.6 32 2983.29 47.83 256.5 33 3079.06 49.05 256.4 34 3172.65 51.24 257.0 35 3266.37 53.84 256.5 36 3360.18 56.96 256.4 737 3455.44 59.48 255.9 38 3550.05 61.72 255.8 39 3643.14 64.00 255.5 40 3736.97 66.19 254.7 41 3831.22 68.60 254.7 42 3925.06 69.10 255.5 43 4017.59 69.40 255.3 44 4113.29 69.31 255.9 45 4206.67 69.36 255.2 46 4301.55 69.30 254.8 47 4394.64 69.64 254.9 48 4488.47 69.98 255.0 49 4582.52 70.10 254.7 50 4671.19 70.14 255.4 51 4770.66 70.06 256.0 52 4863.58 70.19 256.2 53 4959.20 69.57 255.7 54 5054.69 69.43 255.8 55 5147.44 69.41 255.3 94.70 89.50 95.80 93.60 93.70 93.80 95.20 94.70 93.00 93.90 94.20 93.90 92.50 95.70 93.40 94 · 90 93.00 93.90 94.00 88.70 99.50 92.90 95.60 95.50 92.70 56 5242.89 69.70 255.9 95.50 57 5336.03 69.77 255.5 93.10 58 5428.75 69.48 255.7 92.70 59 5522.54 69.54 255.4 93.80 60 5616.22 68.01 256.2 93.70 [ C)1998 Anadrill IDEAL ID5 OB 68R] TVD depth (ft) 2666.29 2727.24 2790.79 2850.77 2907.75 2961.01 3011.15 3057.63 3100.05 3139.59 3175.80 3209.68 3242.45 3276.19 3309.15 3342.65 3375.27 3407.68 3439.76 3469.93 3503.79 3535.38 3568.26 3601.71 3634.29 3667.65 3699.90 3732.17 3765.01 3798.93 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) I00f) type type 876.55 942.08 1013.74 1085.57 1159.92 1237.11 1318.02 1400.52 1483.27 1568.43 1655.38 1742.96 1829.46 1919.01 2006.40 2095.19 2182.28 2270.40 2358.75 2442.17 2535.72 2623.08 2712.84 2802.29 2889.08 2978.56 3065.89 3152.79 3240.66 3328.00 -228.11 -846.38 876.58 -243.35 -910.12 942.09 -260.15 -979.81 1013.75 -276.67 -1049.73 1085.58 -293.72 -1122.12 1159.92 -311.81 -1197.17 1237.11 -331.18 -1275.74 1318.02 -351.35 -1355.73 1400.52 -371.86 -1435.90 1483.27 -393.77 -1518.20 1568.43 -416.71 -1602.07 1655.38 -439.23 -1686.70 1742.96 -461.03 -1770.41 1829.46 -483.31 -1857.15 1919.01 -505.11 -1941.78 2006.40 -528.09 -2027.54 2095.19 -550.86 -2111.61 2182.28 -573.74 -2196.72 2270.40 -596.83 -2282.00 2358.75 -618.35 -2362.59 2442.17 -641.46 -2453.25 -662.45 -2538.06 -684.24 -2625.14 -706.26 -2711.83 -727.91 -2795.87 254.92 2.23 MWD 255.03 1.68 MWD 255.13 1.28 MWD 255.23 2.39 MWD 255.33 2.81 MWD 255.40 3.33 MWD 255.45 2.68 MWD 255.47 2.37 MWD 255.48 2.47 MWD 255.46 2.46 MWD 255.42 2.56 MWD 255.40 0.96 MWD 255.40 0.38 MWD 255.41 0.59 MWD 255.42 0.70 MWD 255.40 0.40 MWD 255.38 0.38 MWD 255.36 0.38 MWD 255.34 0.33 MWD 255.33 0.74 MWD 2535.72 255.35 0.57 2623.08 255.37 0.25 2712.84 255.39 0.81 2802.29 255.40 0.18 2889.08 255.41 0.51 -750.16 -2882.55 2978.56 -771.74 -2967.18 3065.90 -793.35 -3051.35 3152.79 -815.27 -3136.43 3240.66 -836.70 -3221.10 3328.00 MWD MWD MWD MWD MWD 255.41 0.66 MWD 255.42 0.41 MWD 255.43 0.37 MWD 255.43 0.31 MWD 255.44 1.82 MWD Ga~ Cons. Commissior'~ 'Alaska Oi~ & "' ' Anchorage 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 4-Mar-98 17:00:00 Page 4 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) I00f) type type 61 5710.06 67.86 256.5 93.90 3834.20 62 5803.09 67.31 257.4 93.00 3869.67 63 5897.24 68.05 256.5 94.10 3905.40 64 5991.67 69.39 256.0 94.50 3939.70 65 6082.07 68.64 256.7 90.40 3972.07 66 6176.90 68.86 257.1 94.80 4006.43 } 67 6271.31 69.06 256.6 94.40 4040.32 68 6363.85 68.81 256.4 92.50 4073.57 69 6456.67 68.61 257.0 92.90 4107.30 70 6551.86 67.93 257.5 95.20 4142.55 3415.00 -8 3500.94 -8 3587.96 -8 3676.00 -9 3760.39 -9 3848.71 -9 3936.79 -9 4023.09 -9 4109.63 -10 4198.01 -10 71 6647.03 67.80 257.5 95.10 4178.38 4286.04 -10 72 6740.45 68.11 257.3 93.40 4213.44 4372.56 -10 73 6834.01 67.97 257.5 93.60 4248.44 4459.31 -10 74 6927.74 67.83 257.7 93.70 4283.69 4546.06 -11 75 7021.52 67.65 257.5 93.80 4319.23 4632.81 -11 76 7113.75 68.67 256.4 92.30 4353.56 4718.44 -11 77 7209.80 69.05 256.1 96.00 4388.18 4807.97 -11 78 7303.29 68.68 255.8 93.50 4421.90 4895.18 -11 79 7398.43 68.36 255.8 95.10 4456.72 4983.67 -12 80 7492.07 69.28 255.1 93.70 4490.57 5071.04 -12 81 7698.42 68.00 253.4 206.30 4565.72 5263.12 -12 ,82 7796.29 66.99 252.5 97.90 4603.19 5353.48 -13 ' 83 7887.03 66.35 251.3 90.70 4639.11 5436.61 -13 84 7978.85 66.80 251.9 91.90 4675.65 5520.76 -13 85 8072.69 69.43 251.9 93.80 4710.61 5607.63 -13 86 8166.21 69.26 253.0 93.50 4743.59 5695.01 -14 87 8262.71 69.59 252.4 96.50 4777.50 5785.25 -14 88 8357.74 68.70 253.6 95.00 4811.32 5873.95 -14 89 8452.46 69.81 256.4 94.80 4844.91 5962.59 -14 90 8547.65 68.66 256.2 95.10 4878.62 6051.50 -15 57.24 -3305.67 3415.01 255.46 76.65 -3389.42 3500.95 255.50 96.31 -3474.22 3587.98 255.53 17.24 -3559.75 3676.02 255.55 37.16 -3641.77 3760.42 255.57 57.19 -3727.82 3848.75 255.60 77.23 -3813.62 3936.83 255.63 97.38 -3897.55 4023.14 255.65 17.29 -3981.79 4109.69 255.67 36.81 -4068.04 4198.09 255.70 55.88 -4154.04 4286.14 255.74 74.76 -4238.53 4372.67 255.77 93.70 -4323.25 4459.45 255.80 12.34 -4408.04 4546.22 255.84 30.98 -4492.82 4632.99 255.87 50.33 -4576.28 4718.65 255.89 71.61 -4663.26 4808.18 255.90 92.79 -4747.86 4895.40 255.90 14.49 -4833.65 4983.89 255.90 36.44 -4918.22 5071.26 255.89 88.58 -5103.12 5263.30 255.83 15.10 -5189.59 5353.63 255.78 40.97 -5268.75 5436.72 255.72 67.58 -5348.77 5520.83 255.66 94.62 -5431.49 5607.68 255.60 21.01 -5514.91 5695.04 255.55 47.87 -5601.17 5785.27 255.51 73.83 -5686.06 5873.96 255.47 96.76 -5771.68 5962.60 255.46 17.82 -5858.07 6051.51 255.47 0.34 1.07 1.18 1.50 1.10 0.46 0.54 0.34 0.64 0.87 0.14 0.39 0.25 0.25 0.28 1.56 0.49 0.50 0.34 1.20 0.99 1.34 1.40 0.77 2.80 1.12 0.68 1.51 3.00 1.23 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis . 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1998 Anadrill IDEAL ID5 OB 68R] -- -- ANADRILL SCHLUMBERGER Survey Report 4-Mar-98 17:00:00 Page 5 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 91 8641.17 68.05 255.9 92 8733.94 68.16 256.2 93 8825.77 68.98 256.7 94 8921.42 68.06 257.2 95 9016.11 67.90 256.0 96 9110.95 68.95 257.3 · ,,~ 97 9204.75 69.08 256.2 98 9293.54 69.75 256.4 99 9389.22 68.95 255.5 100 9481.96 69.11 255.4 t01 9576.27 69.84 255.9 102 9666.59 69.21 255.3 103 9760.88 68.21 254.4 104 9853.76 68.20 254.0 105 9947.08 69.02 254.2 106 10037.75 69.66 253.9 107 10129.83 71.44 255.0 108 10226.83 71.01 255.0 109 10321.51 70.57 254.7 110 10417.75 70.14 254.2 111 10509.43 69.65 254.2 ,112 10603.06 68.40 253.3 .]!!113 10696.42 65.54 253.0 114 10790.11 63.98 251.3 115 10884.25 62.70 252.0 116 10977.70 60.68 253.5 117 11071.89 58.78 253.4 118 11165.20 57.12 253.9 119 11260.01 54.95 254.9 120 11350.23 52.57 255.2 93.60 92.70 91.90 95.60 94.70 94.90 93.80 88.70 95.70 92.80 94.30 90.30 94.30 92.90 93.30 90.60 92.10 97.00 94.70 96.20 91.70 93.70 93.30 93.70 94.10 93.50 94.20 93.30 94.80 90.20 TVD depth (ft) 4913.15 4947.72 4981.29 5016.30 5051.81 5086.70 5120.30 5151.48 5185.23 5218.44 5251.51 5283.09 5317.33 5351.83 5385.85 5417.82 5448.49 5479.71 5510.87 5543.21 5574.73 5608.27 5644.77 5684.72 5726.94 5771.28 5818.77 5868.28 5921.24 5974.56 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 6138.49 -1538 6224.50 -1559 6310.03 -1,579 6398.96 -1599 6486.72 -1620 .80 -5942.51 6138.51 255.48 .53 -6025.98 6224.52 255.49 .57 -6109.15 6310.05 255.50 .66 -6195.81 6398.98 255.52 .01 -6281.21 6486.76 255.54 6574.95 -1640 6662.50 -1660 6745.53 -1680 6835.07 -1701 6921.72 -1723 .38 -6367.07 6574.99 255.55 .45 -6452.32 6662.54 255.57 .12 -6532.99 6745.57 255.58 .86 -6619.86 6835.12 255.58 .63 -6703.74 6921.77 255.58 7010.04 -1745 7094.63 -1766 7182.49 -1789 7268.73 -1813 7355.58 -1836 .51 -6789.29 7010.09 255.58 .55 -6871.23 7094.68 255.58 .51 -6956.04 7182.54 255.57 .00 -7039.04 7268.77 255.56 .79 -7122.59 7355.62 255.54 7440.33 -1860 7527.16 -1883 7619.00 -1907 7708.42 -1930 7799.01 -1954 .09 -7204.10 7440.36 255.52 .37 -7287.76 7527.19 255.51 .14 -7376.47 7619.02 255.50 .51 -7462.79 7708.44 255.50 .79 -7550.07 7799.03 255.48 7885.10 -1978 7972.56 -2002 8058.35 -2027 8142.96 -2053 8226.88 -2080 .24 -7632.93 7885.12 255.47 .72 -7716.92 7972.57 255.45 .60 -7799.09 8058.35 255.43 .57 -7879.76 8142.96 255.39 .05 -7959.58 8226.88 255.35 8309.10 -2104 8390.41 -2127 8469.45 -2149 8548.06 -2171 8620.80 -2189 .47 -8038.19 8309.10 255.33 .64 -8116.17 8390.41 255.31 .91 -8192.05 8469.46 255.30 .06 -8267.77 8548.07 255.29 .83 -8338.05 8620.81 255.28 0.72 0.32 1.03 1.08 1.19 1.69 1.10 0.78 1.21 0.20 0.92 0.93 1.38 0.40 0.90 0.77 2.24 0.44 0.55 0.66 0.53 1.61 3.08 2.34 1.51 2.58 2.02 1.84 2.45 2.65 MWD MWD M -- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M -- MWD MWD MWD MWD MWD MWD MWD 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 5-axis 6-axis [(c)1998 Anadrill IDEAL ID5 OB 68R] -- -- ANADRILL SCHLUMBERGER Survey Report 4-Mar-98 17:00:00 Page 6 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - {ft) (deg) (deg) (ft) 121 11445.00 49.67 255.8 94.80 122 11538.70 46.41 255.8 93.70 123 11632.64 43.56 255.9 93.90 124 11726.12 41.23 255.2 93.50 125 11821.03 38.50 254.9 94.90 TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 126 11915.83 34.98 255.7 94. 27 12008.94 32.13 253.6 93. 128 12103.89 31.49 253.4 95. 129 12196.80 30.38 253.7 92. 130 12293.22 28.89 253.6 96. 6034.06 8694.59 -2208.31 -8409.49 8694.60 255.29 6096.70 8764.26 -2225.40 -8477.02 8764.26 255.29 6163.10 8830.63 -2241.63 -8541.38 8830.63 255.29 6232.15 8893.66 -2257.35 -8602.43 8893.67 255.30 6304.98 8954.49 -2273.03 -8661.19 8954.49 255.30 131 12383.07 27.96 253.3 89. 132 12478.59 27.17 252.7 95. 133 12572.32 26.76 253.5 93. 134 12666.86 25.90 253.1 94. 135 12759.93 25.03 255.2 93. 80 6380.94 9011.18 -2287.44 -8716.03 10 6458.52 9062.63 -2301.02 -8765.65 00 6539.25 9112.68 -2315.24 -8813.66 90 6618.94 9160.41 -2328.77 -8859.46 40 6702.72 9208.05 -2342.19 -8905.20 136 12854.81 24.26 254.4 94. 137 12947.84 23.38 253.3 93. 138 13037.24 22.18 253.6 89. 90 6781.78 9250.82 -2354.37 -8946.22 50 6866.44 9294.97 -2367.29 -8988.48 70 6949.96 9337.43 -2379.64 -9029.13 60 7034.74 9379.36 -2391.70 -9069.32 00 7118.71 9419.33 -2402.63 -9107.78 The 139 final survey is a 13125.00 22.18 90 7204.96 9458.90 -2413.00 -9145.97 00 7290.04 9496.45 -2423.44 -9182.05 40 7372.47 9531.04 -2433.30 -9215.23 projection to total depth. 253.6 87.80 7453.77 [(c)1998 Anadrill IDEAL ID5 OB 68R] -- -- 9564.17 -2442.66 -9247.02 9011.19 255.29 9062.63 255.29 9112.68 255.28 9160.42 255.27 9208.06 255.26 9250.83 255.26 9294.99 255.25 9337.45 255.24 9379.38 255.23 9419.36 255.22 3.10 3.48 3.04 2.54 2.88 3.75 3.30 0.68 1.21 1.55 1.05 0.88 0.58 0.93 1.35 9458.93 255.22 0.88 9496.48 255.21 1.06 9531.07 255.21 1.35 9564.21 255.20 0.00 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 11-May-98 iWell Name Services Bluelines R/F Sepia Film :!MPL-40 CCL PERF RECORD 1 1 MPL-40 GR / CCL DEPTH DET. 1 I Received byf~ Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. Well Compliance Report File on Left side of folder 198-010-0 MD 13125 MILNE_~PoiNT ~iT' ......... ~[40 .......... 5'0'[' 02912~855[00 .......... B'~ E~LORATION TVD 07454 ~ ~bmpletion Date: 5FF0/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D L ADN-MD L ADN-TVD b CCL/?ERF CF-~AL 12356-12810 O CH 5 5/11/98 5/14/98 L CDR-MD ~AL 4748-13125 OH 8/19/98 8/20/98 L CDR-TVD 6~qAL 3500-7400 OH 8/19/98 8/20/98 L GR/CCL ~I~AL 7450-12960 ~'/~/~ CH 5 5/11/98 5/14/98 ~L 4748-13125 OH 8/19/98 8/20/98 T ~AL 3500-7400 OH 8/19/98 8/20/98 T T 8591 ~ SCHLUM GR/CCL/PDC CH 8/4/98 8/6/98 T 8620 ~/ SCHLUM CDR/ADN OH 8/18/98 8/20/98 Daily Well Ops _~/~-~ Are Dry Ditch Samples Required? ye~And Rec-~i~d? ~y-~ no Was thewell cored? yes ~_. Analysis Descri ~on e . Comments: Monday, May 01, 2000 Page 1 of 1 MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE' May 9, 1998 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor awpkeife.doc FROM: Chuck Scheve, ~ SUBJECT: Petroleum Inspector BOPE Test Nabors 4ES MPU L-40 PTD # 98-10 Saturday May 9~.1998: I traveled to BPX's MPU L-40 Well being completed by Nabors Rig 4ES and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows, the test lasted 2.5 hours with no failures. The Kelly valves were not tested today because it will not be used during completion of this well. The testing went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. S..ummary: i witnessed the initial BOPE test on Nabors Rig 4ES completing Well MPU L-40 Nabors 4ES, 5/9198, Test time 2.5 hours, 0 failures Attachment: awpkeife.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Nabors Rig No. 4ES PTD # 98-10 BPX Rep.: L-40 Rig Rep.: Set @ Location: Sec. X Weekly Other DATE: 5/9/98 Rig Ph.# 659-4154 David Oriall Gene Sweat 8 T. 13N R. IOE Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign N/A Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/3000 1 250/5,000 I 250/5,000 I 250/5,000 2 250/5,000 f 250/5,000 N/A N/A P/F P P P P P P N/A MUD SYSTEM: Visual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 2 250/5,000 P 1 250/5,000 P CHOKE MANIFOLD: No. Valves 11 I No. Flanges 22 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5,000 P 250/5,000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3000 1800 minutes 32 sec. minutes 15 sec. OK Remote: OK 4(~1900 Psi Psig. Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Weli File c- Open/Rig c- Database c - Tdp Rpt File c- Inspector F1-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: VV'[tnessed By: awpkeife Chuck Scheve U~/UO/~O Memo To: Blair Wondzell Subject: IVlilne Point Unit MPL -40 CC: From= Date: Paul Prince, Kathy Campo~"~ j 8 May 1998 MPU L-40 (Pe~rnit No. 98-010), Mr. Wondzell, In order to provide you an update for completion plans for MP L-40, I've attached a brief summary of our the proposed program, Nabors 4ES is moving to L-40 this weekend. We will forward the final completion forms as soon as the production tests are complete. if additional information is needed, give me a call 907-564-5376 or pager 275- 8310. ATTACHMENTS: Summary of Completion Plans (3 pages) Copy of Permit (1 Page) "--'-- "' ' ' OriO. KD I':lov. = 50.6' ~N '~'~ ~ ~,,~--~, OlW MPU L-40 o~,.~-~ ,,.~- ~j:;IShead: f 1' ,5/91 FMC~ Oea. 5a w! -. FiT To Ttw). Spoel -- 33.o' (FI 27~ 7 ,t1~" F/VIC 1~. Hng., 3' LH -1- -- ~cmn ~ am:! ~,?/~ b~m~ 2.5" b"lW J · I..F DPV pro~k~ I ' Max, halo ~ - 71 ¢l~13. ~ ,,, .. . . :. , , ' '"" C,m31CO 2 7/B" x 1' ~' 27,,~ XN ~p, ple ~ 513, GPMTAR 1 T~m ~ sep~ G~T8 ~l ~lon Stim~ll,I;on Summ~ I~ hp ~tor. ~ v. I a0 J ' J Su~m=w _ I ~1~'; ~ 1; ,~9~-1~7~0' 7( ~'-~7~ DATE R~, ~ ' ~MM~ ~_ILN~ POl~ .._ BP EXPLORA~ON (AK) OBJECTIVE: It is requested that Nabom 4ES run the initial completion for MPU L-40. It is proposed to wireline conveyed perforate the Kuparuk "A" sand and then perform an "A" sand hydraulic fracture stimulation. The first 60,000 lbs of proppant will be 20/40 Carbolite, the second 52,000 lbs will be a mixture of 16/20 Carbolite and 16/30 Chemflow at a ratio of 1:1, and the last.90,000 lbs will be -16/20 LTC. YF140D cross-linked gel will be used throughout the treatment. A GC 1700 ESP completion will then be installed along'with a Cavin's De-sander.. Costs for this work should be charged against the. completion AFE # 347122. .. SCOPE: 1: MIRU N-4ES. NDTree. NU BOP_ 2. PU 4-1/2" IBT modh'ied, open-ended, packerless frac string. Run to depth 12,630' MD. 3. PU AWS lubricator/Electric line gun string (3-318" big hole OMNIKONE, 60 degree phasing, 6 sP0. Perforate zone. of interest. A marked line GR-CCL is required, either with the perforating run or prior to the perforating gun run. 4. Fmc well as per program. 5. Reverse out excess proppant from 4-1/2' fmc stdng in the event of a screen out. 6. Kill well. Retrieve and lay down 4-1/2' frac string. 7. PU 2 7/8" tbg w/~0 joints below the 7" csg scraper and space a 2,d scraper out at 6000; Cleanout well to PBTD. Rack back 2 7/8"tbg. Confirm step 7 with SSD pdor to pu 2 7/8". 8. Run GC 1700 ESP on 2-7/8" tubing with De-sander. Set the PHD at 12,300" MD. Set one GLM 20' above ESP and one GLM at +/- 120' MD. 9. RDMO N-4ES. BACKGROUND' MPU L-40 was drilled and cased in March 1997,'by Nabom 27E. The well was left unperforated and filled with seawater and an 8[; bbl diesel cap. The well is currently 380 psi ,assuming a reservoir pressure of 3300 psi at 7060' TVD(9.0 EMW). Use 9.3 ppg completion fluid for 100 psi overbalance hyrostatic pressure : POINTS OF CONTACT: Operations Drilling Superintendent Operations Drilling Engineer Drilling Engineering Supervisor Centriliff Engineer Production Lead Engineer:. Well Ops. Superintendent: Production Engineer: Paul Pdnce Omar Nut"" Brent Reeves Karen Norrell Bill Hill J. Hendrix Xiuxu Ning office 564-5589 564-5627 564-5376 564-4254 564-4924 659-6330 564-5696 Home 345-6768 349-4547 345-1548 345-8065 345-7469 Pa_q~r 275-75O3 275-4753 275-8310 659-6390 Current Well Status: · GENERAL WELL INFORMATION: APl Number: 50-029-22855 Permit # 98-010 Well Type: Kuparuk "A" Sand Producer H2S Present: No Original KB Elev: 50.6' Original GL Elev:' 17.55' BARRIERS - A TWC and unperforated casing will be the two barriers for the NU-ND operation CASING and WELLHEAD INFORMATIQ. N: Note: ID of the 7" hanger is 6.151" Drift 9 518" is 8.679" Drift Production Casinq Interval ' Drift ID Burst 7" 26 # L-80 MBTC 0-12,958'MD 6.151~ 7240 9 5/8"40#L-80 8.679" 7430 Wellhead: 11" x 7-1/16" 5M FMC Gert 5A Tree: 2-9/16" Carbon ... Collapse Tension 5410 604x1000 # 3090 916x1000 # ,-. EX_!S!ILNG co PL~ None. Well is unperforated with 7" casing. BH_P e~rJ.d._B._HT I~!~ FORMATION: BHP: Estimated 3300 psi at 7056' -i-VD. BHT: Estimated at 170°F DIRECTIONAL INFORMAT_/ON: KOP: 300' MD Max angle: 71° @ 10.130' MD Max DLS.' 3-3° at 3360' MD Ar~gle thru perfs: 28° . ; Azimuth 255° Departure: 9565" PROPOSED PERFO,I~ATION INFORMA_TIO__N: ! ~- Measured Depth Kuparuk "A" sands . ~ 12,690'-12,71.0' (20) Initial depth reference: LW~ completed 3-4-98. PERFORATING G_U.N SPECIFICATIONS: 3-3/8" big hole OMNIKONE, 60 degree phasing, 6 spf .. True Vertical Depth 7,056'- 7,074 (18') PROPQSED_COMPLETION 2-7/8" 6.5 ppf, L-80 EUE 8 rd 123 GC1700 1:5 152 HP 2325 volt/40 amp Tandom Gas Seperator GSB3 UT/IT AFLAS/HSN Seal · 2 Cable Cavins Desander assembly '~ Run 10 joints of sand trap (bull plugged 2-7/8" tubing) below the desander. - Set PHD at 12,300' MD. · Immediately above the ESP, install the following componentry: 10' 2-7/8" pup, 2-7/8' XN nipple, 10' 2-7/8" pup, and 2-7/8' KBMM GLM. in addition, the upper 2-7/8" KBMM GLM should also be run as per normal. Note: Run in the hole slowly to avoid damaging the packer sub. If the tubing appears t:~lD, ~,, ~ E I V ~ ~]~ floating, reduce the rate of running. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Fcbruars.' 5, 1998 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 ae~ Milne Point Unit MPL-40 BP Exploration (Alaska), Inc. Permit No. 98-010 Sur. Loc. 3142'NSL, 5018'WEL, Sec. 08, T13N, R10E, UM Btmnhole Loc. 711'NSL, 3485'WEL, Sec. 12, T13N, R09E, UM Dear Mr. Alvord: Encloscd is the approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission max, witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North David W.(~(0,hnston ~ -- Chaimaan BY ORDER OF THE COMMISSION dlffEnclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALA-,u~,~ OIL AND GAS CONSERVATIOI,~--~;;OMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oili [] Re-Entry [] Deepen [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 50.2' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation,,f,,~ Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 AD~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3142' NSL, 5018' WEL, SEC. 8, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 764' NSL, 3644' WEL, SEC. 12, T13N, R9E, UM MPL-40 At total depth 9. Approximate spud date Amount $200,000.00 711' NSL, 3485' WEL, SEC. 12, T13N, R9E, UM 02/10/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025514, 711'I No Close Approach 1920 13071' MD / 7360' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e} (2)} Kick Off Depth 300' Maximum Hole Angle 69.17° Maximum surface 2834 psig, At total depth ('I-VD) 7100'/3544 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 7329' 31' 31' 7360' 4415' 1643 sx PF 'E', 670 sx Class 'G' 8-1/2" 7" 29# L-80 Mod-Btrc 13041' 30' 30' 13071' 7360' 231 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Surface Conductor Intermediate Production Liner ,i~8~ 0i! ~78¢~ C008' Perforation depth: measuredORIGINAL true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Narne/Nurnben Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoarnor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~~- ~ d ~____~¢'~ Title Senior Drilling Engineer Date Commission Use Only Permit Number I APl Number Approval Date See cover letter //~-,,2<c:::)I 50- c::, ~_'~- 2_ ~-- ~' ,.¢"..5'" c~ -.~" ,~ ~2 for other requirements Conditions of Approval: Samples Required []Yes J~No Mud Log Required []Yes [] No Hydrogen Sulfide Measures []Yes 'J~ No Directional Survey Required ~Yes I--I No Required Working Pressure for DOPE []2M; []3M; []5M; []10M; [] 15M Other: "7-~-~7- f~ ~.~5~; by order of Approved By .. i,':,', r,~! Siflr~¢,,~ ~V Commissioner the commission Dat~..,~.'-'~/ (___~ Form 10-401 Rev. 12-01-85 David W. Johnston Submit In Triplicate Shared.Services Drilling Contact: Lance Spencer 564-5042 I Well Name: IMP L-40 I Well Plan Summary I Type of Well (producer or injector): I Kuparuk Producer ISurface Location: 3142' NSL, 5018' WEL, Sec. 08, T13N ,R10E, UM., AK Target TKUA3 764' NSL, 3644' WEL, Sec. 12, T13N, R9E, UM., AK Bottom Hole Location: 711' NSL, 3485' WEL, Sec. 12, T13N, RgE, UM., AK I AFE Number: I 337122 I Estimated Start Date: Feb 98 I MD: 113,071 I Well Design: Ultra Slim Hole Long String Formation Markers: I Rig: I Nabors 27-E Operating days to complete: 115 I TVD: 17,360' Bkb I IKBE: I50-2' I 9-5/8", 40# Surface X 7", 26# Formation Tops MD TVD (bkb) EMW Formation Pressure Base Permafrost 1890 1850 8.4 ppg 808 psi NA Top Schrader Bluff 6052 3950 8.4 ppg 1725 psi OB Base Schrader Bluff 6797 4215 8.4 ppg 1841 psi Top HRZ 11974 6420 8.8 ppg 2938 psi Base HRZ 12077 6505 8.8 ppg 2977 psi TKLB(MK-19) 12178 6590 9.2 ppg 3153 psi TKUD 12367 6750 9.2 ppg 3229 psi TKUC/B 12563 6920 9.6 ppg 3455 psi TKUA3/Target 12655 7000 9.6 ppg 3494 psi TKUA2 12679 7020 9.6 ppg 3504 psi TKUA1 12717 7057 9.6 ppg 3523 psi Miluveach 12771 7100 9.6 ppg 3544 psi Total Depth 13071_+ 7360+ 9.6 ppg 3674 psi · *These are estimated maximum pressures and the actual pressures may be lower. ~as,ng/, uo,ng ~,roc. ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/'rVD MD/I'VD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 7329 31/31 7360/4415 8-1/2" 7" 29# L-80 Mod. 13041 30/30 13071/7360 btm The internal field pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _.+ 7,100 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7,100 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,544 psi is 2,834 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. MP L-40 (L-98 A) Drilling Permit ,, 1 1/14/98 Cementinq Program: Halliburton Cementing Services Hole Casing Interval Volume~ Spacer Type of Cement Properties~ Cate~lory Size/Depth Surface Lead~ Lead Lead Lead First Stage 9-5/8" @ 2090-5552' 650 sx 70 bbls Permafrost "E" Den 12.0 ppg 7,360' 251 bbls Fresh water Yield 2.17 ft 3/sx Water 11.63 gps TT 4.0 hrs 5552-7360' Tail5 Tai~l Tail 670 sx Premium Class "G" w/ Den 15.8 ppg 137 bbls 0.2 %Halad 344, 0.2% CFR-3 Yield 1.15 ft 3/sx 0.15 #/sk Flocele Water 4.9 gps TT 4.0 hrs ....... §'~;~'A'a ....................... §¥~ii~' ...................................... E'~;;a~ ............ i"~'~a ..................... i3'~a ...................................... E'&';~a ........................................................ Stage collar° @ 0-1890' 993 sx 75 bbls Permafrost "E" Same as above 2,098' 1890-2090' 384 bbls Fresh water Production 7" @ 11,563'- Lead" Lead Lead Den 15.0 ppg First Stage 13,071' 13,071' 231 sx 20 bbls. Premium Class "G" w/ Yield 1.15 ft 3/sx 47 bbls Fresh Water 0.2% CFR-3 + 0.01% Water 5.0 gps 70 bbls +0.45% Halad 344 TT 3.5-4.5 hrs @ 140° F NSCI FL 50 cc/30 min @140° F 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and muds to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,090'MD_+ 4. The surface hole First Stage LEAD Cement Volume. Interval from 2,090-5,552' md. The estimated first stage lead cement volume from 2,090-5,552' md and is equivalent to the annular volume calculated from the 9-5/8" ES Cementer at 2,090' md which is 200 ft md below Base of the Permafrost at 1,890' md (1,850 TVD bkb) to 5,552' md which is 500' above the NA top plus 30% Excess. 5. The surface hole First Stage TAIL Cement Volume covers the interval from 5,552-7,360' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the 5,552' (500' md above tt~e NA top) to surface TD at 7,360' md (4,415' TVD bkb) plus 30% open hole excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-2,090' md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 2,090' MD (2,032' TVDbkb) to surface. From 1,850' to sudace include 250% open hole excess and from 1,890-2,090' use 30% open hole excess. 7. The estimated Well head stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the well head. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. If the Schrader Bluff is productive install one(l) Bow Spring Centralizers per joint from 6,052-6,797 of 9-5/8" casing to cover the top of the NA to Base OB. 10. The production hole will be cemented in a single stage. The Cement Volume covers the interval from 11,563-13,071' md. The estimated first stage tail cement volume is equivalent to the annular volume calculated from 11,163' which is ' 30;o open hole excess and the shoe joint volume. The 1000'+ above the Kuparuk C Sand to TD at 13,071 plus °' estimated shoe joint volume is equivalent to the capacity of 80'md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install TWO per joint for the first 10 joints and ONE per joint from to 240' above any potential hydrocarbon bearing sands. 12. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing. 13. Install two 7" marker joints and position three joints above the Kuparuk C sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no__[t necessary. MP L-40 (L-98 A) Drilling Permit RECEIVED F' ' Alaska Oil & Gas ~ons. L~Uiiti'![llss[O[~' Anchorage 2 ORIGINAL 1/14/98 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. M10 Power Plus MWD Directional from top to bottom of surface hole.. 2. LWD (CDR/GR/ROP) from TOP Schrader Bluff to TD of surface hole. 3. DWOB/DTOQ from top to bottom of surface hole. Intermediate N/A 1. M10 Power Plus MWD Directional 2. LWD (CDR/AND/GR/ROP) (Real Time) 3. DWOB/DTOQ N/A Mud Logging Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. Final Production 8-1/2" Cased Hole Logs: 12-1/4" and 8-1/2" Hole M10 PowerPlus IWOB: GR: CDR: ADN: ROP: Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point gel gel Loss % 8.6-9.6 50-150 15-35 8-15 10-30 9-10 8-15 <9 Production Mud Properties to Change LSND Freshwater Seawater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-9.9 35-45 6-20 3-10 7-20 8.5-9.5 6-12 8-10 for <6 ~ <4 Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. Directional: KOP1 300' Start Variable @ 1.5°- 2.5 °/100 and Az 255.36°. EOB @ 3790' md. 69.17° from 3,790-10,559' Tangent Hole Angle Final Build Section Maximum Hole Angle Close Approach Wells Survey Program Start Final Drop 10,559 @ 2.5°/100 to 30° incl. and 255.36 Az o EOD 12,456' md 69.17° from 3,790-10,559' All wells may remain flowing while drilling L-40 and no shut-ins are required. 1. Surface to 7,360' MWD surveys. 2. 7,3.6.0,,TD .......... MW.D S.~.rveYs~ Disposal: No "Drilling Wastes" will be injected or disposed into L-40 while drilling this well. MP L-40 (L-98 A) Drilling Permit 3 1/14/98 Cuttinqs Handlinq: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Objective: MPL-40 is planned as a S-Shaped high angle, 69.17°; medium departure, 9,597'; Kuparuk River A Sand producer which will be drilled to a measured depth 13,074'. The S-shaped well profile with a final angle of 30°, will intersect the target objectives in the Kuparuk and provide optimum inclination for fracture stimulation. The surface casing will be deep set below the Schrader Bluff at 7,360'md (4,415' TVD bkb) to isolate the Ugnu and Schraber Bluff from the Kuparuk interval which should be normally pressured. Geolo_cly The primary targets are the Kupauuk A3, A2 and A1 sands but has some potential in the Kuparuk B and C sands.. The target location is northwest of well MP L-39 in the same fault block. L-40 appears to be up-dip structurally of L-39, but this location is near the edge of the seismic data. In the success case, L-40 will be supported by L-39: however, if L-40 comes in structurally deeper than L-39, then L-40 will become the injector. Well L-39 has not been completed. The deepest known oil in the area is at the L-39 location at a depth of 7,036 tvd ss. No oil-water contact is expected at the L-40 location. The HRZ interval in some nearby wells is missing. In other nearby wells the HRZ was thin or truncated. In this well a full section is assumed, but the zone my be truncated. The vertical margin of uncertainty is approximately 100+ ft TVDbkb associated with the Kuparuk targets due to seismic time conversion. Reserves associated with this producer are estimated at 5.4 MMSTB OIP (primary and secondary) for assuming an OWC of 7,045' tvdss. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be normal (9.6 ppg EMW) or partially depleted. This well will not be affected by Kuparuk injection. The deep set surface casing design is recommended to alleviate potential problems of differential sticking and lost circulation in the Ugnu and Schrader Bluff while drilling the Kuparuk. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. Lost circulation and stuck pipe have occurred but not recently and are not expected. Close Approaches There are no close approaches associated with the drilling of MP L-40, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Injection There has been no production of injection into this fault block and formation pressures are expected to be normal at a maximum of 9.6 PP9 EMW pore pressure in the Kuparuk while drilling L-40. Annular Iniection Currently annular injection is not permitted on L-Pad. Lost Circulation: Lost circulation is most prevalent while running casing and cementing in the surface and production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. This problem should be alleviated because of the deep set surface casing design. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. MP L-40 (L-98 A) Drilling Permit 4 1/14/98 Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on L-Pad. Excessive amounts of reaming have been required to condition the hole prior to running the surface casing. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9-5/8" casing has been stuck. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher mud's weights needed to keep the HRZ and Kuparuk formations in balance. Since there is the possibility that the HRZ will be truncated or absent there is a potential for stuck pipe the transition interval from Colville(SeeBee) to Kulubik. Shale instability in the Miluveach may result in tight hole or packing off so preventative measures must be taken to alleviate this risk. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurrence and has often causes difficulties so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK B/C SAND KUPARUK A1 SAND 6,920' TVDss 3,455 PSI 7,057' TVDss 3,523 PSI 9.6 PPG EMW 9.6 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at ± 7,100 TYDbkb. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.7,100' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,544 psi is 2,834 psi. The maximum expected pore pressure for this well is 9.6 ppg EMW (3,544 psi @ 2,834' TVDbkb). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point L-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on L Pad. MP L-40 (L-98 A) Drilling Permit 5 1/14/98 MP L-40 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD to top of Schrader NA and then (GR/DIR/CDR/DWOB/DTOQ) from top of Schrader NA to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2,090' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP. 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 250' of production rat hole between the base of the Kuparuk A sand and PBTD before running the 7" casing. 11. Run 7" casing. 12. Perform Single Stage Cement Job. Complete the production casing cementing check list. 13. Displace cement with 8.6 ppg filtered sea water and enough diesel to cover from the base of permafrost to surface (+-2200' MD). Test casing to 3500 psig. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. 14. 15. 16. MP L-40 (L-98 A) Drilling Permit 6 1/14/98 Aoadrlll 8chlumbe~er ........ i'". ! .:-: t.~..2'a:: 2 £-:~ .......... 1111 East 80th Avenue Anchorage, AK 99518 [907) 349-451Z Fax 344-2160 DIRECTI0~A~ WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPL-40 {PO%) Field ........ : Milne Point Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.49646908 N Surface Long.: 149.63313885 W L~al Description ~h~rface ...... ; 3142 FSL 5038 FEb SOB T13N RIOE U~ Target ....... : 764 FSL 3644 FEL $12 T13N R09E UM ~Hb .......... : 711 FSL 3~45 FEL $12 ~L3~ R09E ~ LOCATION8 - ALASKA Zone: 4 X-Coord Y-Coord 544863,88 6031332,31 535795.00 6028905.00 535594.35 6028851.50 PROPOSED ~ELL DROF[LE STATION MEASURED INCLN DIRECTION VERTICAL-DEE~I~S IDE~TIFrCATION DEPTH ANGLE AZI~TUH ~ O.OD O.O0 O.OO O.UO -50.20 KOP / BUILD 1/lOD 300.00 O.0D 255.36 300.00 249.80 ~OD.0B 3.00 255.36 BU~ 1.5/~00 500.OD 2.80 255.36 499.96 ii9.76 600.00 3.50 255.36 599.84 549.64 ~ECTZON DEPART O.DO -0-00 0.87 3.49 8-29 Prepared ..... : 33 Jan L998 Vert sect az.: 255.36 KB elevation.: 50.20 [t ~aqnet£c Dcln: +28.040 Scale Factor,: 0.99990229 Convergence..~ +0.34581153 ANADRILL AKA-DPC APPROVED {:OR IPE'RM. ITT NG ONLY CDORDII~TE~- FRO~ W~LLHEAD X Y FAC~ 100 0.00 N 0.00 E 544863.88 6031332.31 105L 0.00 O.00 N O.0O E 544863.88 6031332.31 3fiSL 0.00 0.22 S 0.84 W 54~863,04 6~31332.08 LOSL 3.00 0.88 S 3.38 W '544860.51 6031331.41 105L L.0O 2.09 S 8.02 ~ 544855.87 6033330.17 105A 1,50 700.DO 5.00 255.36 800.00 6.50 25S.36 900.00 8.00 255.36 1000.00 9.50 255.36 LlOO.OO Ll. O0 255.36 699.56 649.36 799.06 748.86 898.26 848.06 997.09 946.89 1095.49 1045.29 15.70 25.72 38.3~ $3.55 71.34 3,97 S 15,19 W 544848_72 6031328.25 105L 1.50 6.50 $ 24.88 W 544839.0~ 6033325,66 ~S 1.50 9.69 S 37.09 ~ 544826.85 6031322.40 HS 1.50 13.53 S 51.8I W 544832.16 6031318.47 HS 1.50 18.03 S 69.03 W 544794.97 603~313.87 ~S 1,50 120O,O0 32.50 255.36 1193.39 1143.19 91.71 LS00,0O i4.00 255,36 1290.73 1240.53 114.63 23.18 S 88.73 W 544775.30 6031308.60 ~S 1.50 28.97 D 110,90 W 5~{753.16 6031302.68 HS L.50 (Anadri~l (c}98 ~PL4OP0~ 3,2b.5 11:20 AM D) 8TATIO~ [DE~TIFIC~TEON Eked 1.5/100 BUrLD BAS~ PHRMA[~{OST ~UrLD 2.5'/100 ~BPTH 3~00.00 1500.00 1600.00 i700.00 1BO0~O0 INCL~ DIRECT[ON VE~TICAL-D~PTH~ A~GLE ASIMUTH TVD SUB-SEA 15.50 255.36 ~87,43 133~.23 17.00 255.36 3483,43 3433.23 18.50 ~55.36 ~57E.67 ~528.~7 20,00 255.36 1673.07 1622.87 21.50 255.36 1766.58 1716.38 SECTION D~PART 140.08 16~.07 198.55 231.52 266.95 1546.99 22.20 255.36 1810.20 1760.00 284.44 1890.20 22.20 255.36 1850.2~ 1~00.00 380.77 1955.80 22.2~ 255.36 1870.20 1~20.00 30B.93 2OO0_O0 24.4i 255.~6 ]951.2D ~901,00 343.83 2100.00 26.91 255.36 204~.33 1991.13 387.~3 OOORDINATE~-FROM ALASKA Zone 4 WELLHEAD X Y 35.40 $ 135.5~ ~ 544728.57 6031296.09 42.47 S 162.65 W 544701.54 6031288.86 50.18 S 592.1I W 5~672.10 6031280.98 58.51 $ 22~.0~ W 5~46~0.25 6011272.46 67.46 ~ 258.~$ W 544606.03 6031263.30 2200.00 2300.00 2400.00 2500.00 2600.00 FAC~ 1DO 1.50 1.50 1.50 1.50 1,50 71,~B $ 275.21 W 544589.14 603125B.?? ~E 3.50 76.01 S 291.00 W 5~573.37 6031254.55 BS 0.00 78.07 $ 298,90 W 544565.~$ 6031252.44 ~9 O.O0 86-89 S 332.67 W 544531.7~ 6031243,~2 HS 2.50 97,83 S 374.56 ~ 544489.95 6031232.23 tLS 2.50 29.43 255.36 2129.49 2079.29 434.32 109.76 31.9i 255.36 2215.50 2165,30 485.31 122.65 34.41 2~5.36 2299-21 2249.O1 540.00 136.47 36-9~ 255.36 2380.4~ 2330.25 598,29 151.20 39.45 255.36 2459.07 240S.87 660,07 166.81 2700.00 41,91 255.36 253{.93 2484.73 2BO0.O0 44.~1 255,36 2607.87 2557.67 2908.~8 46.91 255.36 2677.75 ~627.55 3000.D0 49,41 255.~6 274~.45 2694.25 3100.00 51.91 255.36 2807,84 2757.64 725.25 793.62 865.14 939.63 1016.97 1~3.28 2~0.$6 237.46 2~7.00 3200.00 54.4l 255.36 2867.79 2517.59 1096.99 277.23 3~00.00 56.91 255.36 292~,20 287~,00 1179.56 298.09 340~.00 59.41 255.36 2976.95 2926-75 1264.50 319.56 3500-00 61.91 255,36 3025.94 2975-74 1351.67 341,~9 3600.00 64.41 255.36 3071.09 3020.89 1440,89 364.1~ 3700.00 66.91 255,36 3~12.30 3062.10 1531.99 387.16 END 2.5/100 BUILD 3790.48 69.Z7 255.36 3146.14 3095.94 1615.90 %08.37 _~ PT ~926.88 69,17 255.36 3550.20 3500.00 2678.04 676.79 (Anadri~l (c) 98 MPL40P~4 3.2b.5 11:20 Ab] P) 420.22 W 544444.37 6031220.03 HS 2.50 469.55 W 544~95,12 6031206,~5 Hg 2.50 522.47 W 544342.29 6031192-71 H~ 2.50 57~.87 ~ 544~5.99 6031177.64 HS 2.50 · 638,65 W 544226.31 6031161.66 ~$ 2.50 I 70~.68 ~ 544163.38 6031144.82 }LS 2.50 767.86 ~ 544~97.32 6~31127.14 ~$ 2.50, 837.06 w 54402~,24 603/308.65 ~S 2.50 909.13 W 543956,29 6031089,39 HS 2.50i 98~.96 W 54388~.59 603106~.~0 I-IS 2.50; Z 1061,38 W 5~3804.29 6031048.75 ES 2.50 1145.27 W 543724,54 6031027,36 ~S 2.50 1223.~6 W 543642.49 6031005.40 }tS 2.50 1307.79 ~ 543558.3~ 6~309~2.87 ~S 2.50 3394./2 W 543472,I2 6030959.8O ES 2.50 1482.26 W 543384.12 6030936.25 ~S 2.50 5563.45 W 543303.07 6030914.56 HS 2.50 2591,L2 W 5~2277.~5 6030639.9~ ~S O.O0 NPL-40 (P04} 13 Jan 1998 Pa~e 5 ~TATI ON' MEAS~3 RE D INCLN IDENTIFICATION D~P'Ir~ ANGLE NA 6051.86 69.17 OA 6473.72 69.17 OB 6698.72 69.17 ]~ OB 6797.15 69.17 9-5/$' CASING POINT 7359.64 69.L7 DIRECTION VERTICAL-DEPTHS SECTION ASIMUTH TV/} SUB-SEA DEPART 255.36 3950.20 3900.00 3729.50 255.36 4L00.20 4050.00 4123.8e 255.36 {180.20 ~130.00 4334.09 255.36 4215,20 4165.00 4426.09 255.36 4415,20 4365,00 4951,$2 DROP 2,5/[00 10558.97 69.17 106~0.00 68.~5 10700.00 65,65 ~0800.00 63.15 10900.00 60.65 255.36 5552.77 5~0~.57 7942.09 255.36 5567,78 5517,50 7980.30 255-36 5606.94 5556,74 80~2.27 255.36 5650.15 5599.95 8~62.~5 255.36 5697.25 5647.05 8250.65 ~1000.00 58,15 11100.O0 55.65 11200.00 53.15 11300,00 50.65 Li400.O0 48.15 255.36 5748.15 5697.95 8336.7/ 255.36 5~02.77 5752.57 ~420.~7 255.36 5869.98 5~10.78 ~50L.~7 255.36 5922,68 5572.48 85~0,46 255.36 5987.76 5937.56 8656.37 11500.00 45.65 11600.00 43.15 11700.00 40.65 llBO0.O0 38.t5 11900.00 35,65 255-36 6056.09 6~0~.89 8729.58 255-36 6527.53 6077.33 9799.34 255.36 6201.96 6/51.76 8866.1[ 255-36 6279.2~ 6229.03 8929.57 255.~6 635g.~D 6309.00 89~9.61 END 2-5/LD0 DROP TOP HRZ BASE ERZ DROP 11974.22 33.~9 11974,22 33.79 12076.50 33.79 12076.50 33.79 12100.00 33.56 255.36 6420.20 6370.00 9031.87 255-36 6420.20 6370.00 9031.87 255.36 6505.20 6455.00 908~.76 255.36 6505.2~ 6455.00 9088.76 255.36 6524.76 6474.56 9101.79 MK-19 12178.17 32.77 12200.00 32.56 12300.00 31,56 255,36 6590.20 6540.00 9144.55 255.36 6608.57 6558.37 9156.33 255.36 6693,33 66~3-~3 9209.41 (Anadrill (c)~B ~4PL4DPDi 3.2b.5 ll:2U A~ P} COORDrNATES~FROM ALASKA Zone 4 ~E~ X Y 942.51 S 3608.44 W 54126L.54 6038368.13 1042.15 S 3989.94 W 5~0880.69 6030266.20 1095.38 ~ 4193.&1 ~ 540677.~7 60302~.83 5118.55 S 1251.~1 S 4282.42 W 540588.70 603018B.05 ItS 4791.09 W 540080.90 6030052.13 MS ~OOL FAC~ 100 O.O0 0.00 0.00 0.00 0.00 2007.10 S 7684.29 W 537192.60 6029279.07 L~ O.O0 2016.76 ~ 7721.26 ~ 537155.69 6029269.19 X~ 2,5~ 2040.00 S 7810.25 W 537066.85 6029245.41 LS 2. 2062.79 S 7897.50 W 536979.75 6029222.10 LS 2. 20~5.08 S 7982.83 W 53689~.56 6029599.30 L~ 2.5( 2106.83 S 8066.1l W 536811.43 6029177.85 LS 2.5( 2128.~ S 8147.15 W 53673O.52 6029~55.39 L$ 2.50 2148.54 8 8225.81 W 536651,99 6029134.30 LS 2.50 2168.43 S 8301.94 W 536575.99 60291i4.04 L~ 2.50 2187.61 S 8375.3~ W 536502.67 6029094.41 L$ 2.50 2206.06 S ~446.03 W 536432.15 6029075.53 LS 2.50 2223.74 S 85~3-71 ~ 53636~.58 ~029057~45 L~ 2.50 2240.62 S 8575.32 W 53~300.08 60290~0.19 LS 2.50 2256.65 S 8639.72 W 53623g.78 6029023.78 LS 2.50 2271.83 S 8697.81 W 536180,80 6029008.26 LS 2.50 2282.51 S 8738.70 W 536139.97 6028997.33 H$ 2.50 2282.51 S 8738.70 N 536139.97 6028997.33 ~S 2.50 2296.88 S $793°74 ~ 536085.03 6025982.63 L~ 0.00 2296.8~ S 8793.74 W 536085.~3 6~28982.63 LS ~.~0 2308.18 S 8806.35 W 536072.44 6028979.26 LS 2310,98 $ 8847.72 W 536031.13 6028968.20 LS 1.00 2313.96 S 8859.12 W 536DL9.75 6028965.16 LS 2327.37 S 8920.47 W 535968,49 6028951.43 LS L.O0 MPL-40 (PO4) lB Jan 1998 Page STATIO~ ~f~AS~3RED I~CL19 DIRECT/ON VERTICAL-DEPTHS S~CTIO~ COORDINATES-PROM ALASKA Zone 4 TOOL Db/ IDBNTIFICATION DEPTI4 ANG~,~ AZIMUT~ TVD SUB-S~A DEPART ~ELL4{EAD X Y FAC~ 100 TKUD 12366.51 30,89 255,36 6750.20 6700.00 9243.88 2336.09 ~ S94~.$3 W 535935.19 6028942.52 LS l.OO 12~00,00 30.56 255.36 6778.99 672S.7~ 9261.00 23~0.41 S 8960.39 W 535918,66 6028938.10 LS 1.00 ED l/lO0 DROP [2455,59 30.00 255.36 6826.99 6776,79 ~289,02 23~7.49 8 8987.50 W 535891.59 6028930,85 KS 1.00 Ti~3JC/B 12563.21 3O.0~ 255.36 6920,2~ 6878.00 9342.83 2361,09 S 9839.57 W 535939~61 60259~6.94 HS 0.0~ TXIJA 12649.81 30.OU 25S.36 6995,20 6945.00 9386.13 2372.03 S 9081.46 W 535797~79 60289D5.75 ~ O,O0 TARGET 12655,59 30.00 TKA3 ~2655.59 38.00 TKA2 12678.6S 30.00 TI{A1 12713.32 30.DO T~I~V 12771.06 30.00 ~D/7" CASING k~:~C)Ii'~'/' 13071.06 30.00 255.36 7000.20 6950,00 9389.02 2372.76 S 90~4.~6 W 5357~5,00 6028905.00 ~S 0.00 255.36 7000.20 6950,00 9389.02 2372,76 S 9084.26 W 535795.00 6028905,00 RS 0.00 255.36 7020,2D 6970.00 9400.57 2375,68 $ 9095-43 N 53~753o85 60~$902.01 HS 0.00 255,36 7050.20 7000.00 94L7.89 2380.06 $ 9Z22.i9 N 535767.~2 6028897.54 255.36 7100.20 7D$O.0O 9446.76 23~7.35 $ 9~40.12 W 535739.23 255.36 7360.01 7309.81 8596.76 2425,2~ ~ 9285.25 (Anadrill {c)98 MPL40PO{ 3.2b.5 1~:20 AM P) il SHAREd 'S"E'R'V'Z'cES B Z"LLT_N' ...... ' ' i i i ill i iii i i ANADRiLL AKA~DPC ~ FOR IPE MtTTtNG 1 ONLY : ii ii ii i ii i 4nadri ]7 Sch]umberger i i ii iii NPL-40 (P04) VERTICAL SECTION VIE Sect~o~ at: 255,36 TVD SCale ' 1 i~h = 1400 feet gep Scale.' 1 inch : ~400 feet - "A- 1' ..... rll~"".__.A[~ ;,,.~--~ ' il -. [uraw~ ' ]j dan tusu I J C ~ -- ii i i ii ........... Marker Identification MD BKB SECTN INet Al KB 0 0 0 0.( BI KO9 / BUILD 1/~00 300 300 -0 C} B~ILD t.5/[O0 50~ ~0 3 2.( ..... ,, D) ENO t.a/J00 BUILd t~7 iSJ0 284 22. E) BUILd 2.5/t00 ~9~2 ~870 309 22.~ B ..... ~,Fa~¢-~ F) END 2.5/100 BUILD 3190 3~46 ~616 -- . BJ ~ 4927 3550 2678 m~9-5/8 CASING PDZ~T 7960 4415 4~2 69. I~ ~OP 2.5/~e0 ~0559 5553 7942 __ ~ d) END ~.5/JO0 BROP t1B74 5420 9032 33.l ~ ...... K) DRDP ~/100 ~076 6505 9~B~ L~ END ~/~0~ DRDP ~2456 6B27 9289 30.( ~ ~) TARGET ~2656 7000 9~9 ~.( ~ , ,, N) Ta/7" CASZN~ PO~T ~307~ 7~0 g597 30.( ~ - ~ '~- .......... ~=m~: ...........................---~z= :~,=:.,==.:;- ;;- - . ......... , , 0 700 1400 2100 2800 3500 42.00 4900 5600 6300 7000 7700 8400 g:to0 9800 10500 ] 1200 11900 I ii i i i . ii ii Jll LN i7 ]7 17 17 7g )0 S,e, ct ion Oepa,rture T , ' , SHARED SERV.,ZdES 'DRZ LZN6'. '- , ~ ' - .............. ~ ~-~ IVlh'L-~U t~UR) ,VERTI, CAL SECTIO, N VIEW , )~ ' Section at,: 255,36 'TVD Scale.: ~_~-f¢ ~ r ..... . Der Sca]e.; ~ ~nch = ~00 feet Drawn ..... : J3 dan ~,~98 ) _ ~ . , Marker Identification ND BKB SECTN INCLN A) DRoP ~/t00 ~2076 6505 9089 33.79 B] END ~/~00 DROP 12456 6827 9289 30.00 C) TARGET ~2656 7000 g38g 30,00 ) ~Kuo-~ . L _ ~ ..... D) TO/7" CASING POINT 13071 7360 9597 30.00 ~ , ~ AKA-DPC i ] 'AN, kDR~LL i .... ~ ' _. ~ ~~ PER ~T' ~ ,__~.~ -~ ..... --~ ~ ~~ -'~ :. . · ... ' D : ~ , , um~r~)i ~'NPL,~OP04 9.%.S ~:~.5 mAN O) 9H O0 9050 9~00 9150 9200 9;>50 ' g300 9350 gaO0 9450 0500 9550 91500 9650 9700 : S~c_t i_o n Departure .... 80 J J n/ Z .... SHARED SE'R'V-T . I ! m I ! I Ii 7-- i , .... ~,- .......... . ......... ...... A) KB 0 0 N 0 BI KOP / BUIL~] t/lO0 300 0 ~ 0 C] BUILD 1.5/I00 500 ! S 3 D] END 1.5/100 BUILD 1847 72 S 275 E) BUILD 2.5/100 1912 78 S ~9 F) END 2.5/~00 BUILD 3790 408 S 1563 ~] PO~ZBLE ~SIN~ PT 4927 677 S ~591 H) 9-5/8' CASIN6 POINT 7~0 ~251 S 4791 I) D~P 2.5/~00 ~0559 2007 S 768~ J) END 2.5/i00 2ROP 11974 2289 S 8739 K) DROP 1/~00 I~076 2~7 S 8794 L] END 1/]00 ~OP 12455 2347 S 8988 HI TARGET 126~ 2373 S ~84 NJ TD/7" CASING ~INt ~307~ 2425 S g285 DRILLING I im i i ANADRILL AKA-DPC I APPROVED FOR PERMITTING ONLY j ...... ~.LAN # ii i i i i mi ii _ i ~nadrY 77 SchYumDerger __ ! mi iim 1 ............... '~- ............... I'~ ............ MPL-40 (PO4) PLAN VIEW L . i .. i CLOSURE ~ 9597 feet at Azimuth 255,36 DECLIIIAIION,' +28.040 (E) SCALE ' ! inch: 1200 feet D~A~N · 13 Jan ~998 10200 9600 9000 8400 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 tBO0 1200 600 0 600 <- WESf ' EASI -> Ir-) g8 ~_40~o4 ~.2[1 i~ ~ ~: ~4 ~ P~ ................................... DATE I I CHECK NO. J I VENDOR Ai ARAA~T i A · C~O I DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 010598 Cg. Oi[a~¥b: I00.00 i00. O0 HANDLING INST' s./h kathy campoaaoT- x 5122 THE A~ACHED CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. I[I~ I · WELL PERMIT CHECKLIST COMPANY z~.,/~ WELL NAME.//~ - ~/'~ PROGRAM: exp [] dev,,~redrll [] serv [] wellbore seg FJ ann. disposal para req [] FIELD & POOL ~_~".2....C/,~ ~, INIT CLASS C"~//.-"' / - ,~., ~/ GEOL AREA ~ ?~__) UNIT# /,//~/'~::> ON/OFF SHORE ~,.~ ADMINISTRATION A R /,~T 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located 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 ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... C N ~ N '~ N '~ N '~ N '~ N '~ N '~ N h N '~ N N N N ENGINEERING APPR~,¢~,~. D.._~.~I 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. CMT 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 ................ N 26. BOPE press rating appropriate; test to ~ c:;, psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... ~ ~-~~ 2@. Is presence of H2S gas probable ................. GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures ..... Y 31. Data presented on potential overpressure zones ....... Y/~ 32. Seismic analysis of shallow gas zones ............. ~ N .... 33. Seabed condition survey (if off-shore) ............ // Y N ' 34. Contact name/phone for we,eklyj~rogress reDo, rts .... /,f . Y N lexp~oratory omy] REMARKS GEOLOGY: ENGINEERING: COMMISSION: JDH ~ RNC ,~¢E~ - co Comments/Instructions: © © HOW/lit - A:\FORMS\cheklist rev 09/97 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 * ....... SCHLUMiBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : MPL-40 FIELD NAIVE : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API AFgM~ER : 500292285500 REFERENCE NO : 98160 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/14 ORIGIN : FLIC REEL NAME .. 98160 CONTINUATION # : PREVIOUS REEL : COM~IENT : B.P. EXPLORATION, MILNE POINT MPL-40, API #50-029-22855-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/14 ORIGIN : FLIC TAPE NAME : 98160 CONTINI]ATION # : 1 PREVIOUS TAPE : COMMENT : B.P. EXPLORATION, MILNE POINT MPL-40, API #50-029-22855-00 TAPE HEADER MILNE POINT MWD/MAO LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL : FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN1 98375 P WILSON M COOPER WELL CASING RECORD 1 ST STRING 2ND STRING MPL-40 500292285500 BP EXPLORATION SCHLUMBERGER WELL SERVICES 14-AUG-98 BIT RUN 2 BIT RUN 3 8 13N iOE 3142 5018 50.60 50.60 17.55 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 24.000 20.000 112.0 12.250 9.675 7560.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 3RD STRING 8. 500 PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATED ADN AND CDR LWD DATA AQUIRED ON BP EXPLORATION'S MPL-40 WELL. THE DATA WAS AQUIRED IN TWO BIT RUNS FROM 25-FEB-98 TO 05-MAR-98. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/08/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: O. 5000 FILE S~Y LDWG TOOL CODE CDR ADN $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (M~ASURED DEPTH) START DEPTH STOP DEPTH 4676.0 13124.0 7548.0 13072.0 BASELINE DEPTH 88888.0 12988.0 12982.0 12968.0 12964.0 12960.5 12954.0 12943.5 12931.5 12916.5 12908.0 12903.5 12882.0 12849.5 12837.0 12818.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... CDR ADN 88887.5 12987.5 12983.5 12967.5 12963.0 12960.5 12954.5 12945.5 12932.5 12916.0 12909.0 12904.5 12881.5 12850.5 12837.5 12818.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12813.0 12813.5 12806.0 12806.5 12797.0 12796.0 12779.0 12779.5 12764.5 12764.5 12757.0 12757.5 12752.0 12753.0 12739.5 12739.5 12731.0 12731.5 12729.0 12729.0 12723.0 12723.0 12712.0 12712.0 12709.0 12709.0 12697.0 12696.5 12689.0 12689.0 12678.5 12677.0 12676.5 12674.5 12673.5 12671.5 12664.5 12665.5 12660.5 12660.0 12644.0 12643.5 12640.0 12639.5 12633.5 12633.5 12626.5 12626.0 12619.0 12618.5 12614.0 12612.5 12607.0 12607.5 12599.0 12599.0 12586.5 12585.0 12583.5 12583.0 12575.5 12575.0 12567.5 12566.0 12560.5 12559.0 12546.5 12545.5 12527.5 12526.0 12516.5 12515.0 12512.5 12510.5 12505.5 12505.5 12504.0 12502.5 12502.0 12501.0 12496.5 12494.5 12488.0 12485.5 12483.5 12482.0 12464.5 12462.5 12461.0 12458.0 12440.0 12438.0 12433.5 12430.5 12419.0 12416.5 12412.0 12410.5 12407.5 12405.5 12390.5 12388.5 12386.0 12382.0 12378.0 12376.0 12370.5 12369.5 12366.5 12365.0 17-AUG-1998 12:07 PAGE LIS Tape Verification Listing Schlumberger Alaska Computing Center 12363.0 12355.5 12341.0 12327.0 12320.0 12305.0 12301.5 12296.0 12284.5 12279.5 12271.0 12261.0 12258.0 12252.5 12248.5 12231.5 12226.0 12189.0 12177 5 12166 0 12162 5 12147 5 12137 5 12135 0 12115 5 12107 0 12094 5 12088 5 12080 5 12076.5 12069.0 12061.5 12060.0 12056.5 12054.0 12042.0 12037.0 12032.0 12022.5 12013.0 12007.0 12000.0 11992.5 11984.0 11979.0 11964.5 11961.5 11942.0 11938.0 11929.0 11922.5 11918.5 11916.5 11909.5 11897.0 12361.5 12352.5 12338.5 12324.5 12320.5 12302.0 12299.5 12293.0 12282.0 12277.0 12268 5 12258 0 12255 5 12251 5 12245 5 12228 0 12223 5 12185 0 12175 5 12163 0 12158.5 12144.0 12136.5 12132.5 12112.0 12103.5 12091.0 12085.5 12077.0 12074.0 12068.0 12060.5 12058.5 12052.5 12051.0 12039.5 12034.5 12029.0 12020.0 12010.0 12004.5 11996.0 11991.5 11982.5 11973.5 11963.5 11959.5 11938.5 11935.0 11926.0 11918.0 11915.0 11912.0 11904.5 11894.0 17-AUG-1998 12: 07 PAGE LIS Tape Verification Listing Schlumberger Alaska Computing Center 11888.5 11875.5 11868.0 11866.0 11845.5 11823.5 11817.0 11804 0 11770 0 11760 5 11757 0 11749 0 11723 5 11718 0 11706 5 11702 5 11689 5 11680.0 11676.0 11666.5 11635.0 11623.5 11617.5 11586.0 11572.5 11557.5 11553.0 11548.0 11542.0 11528.5 11507.0 11476.0 11461.5 11451.5 11438.5 11409.0 11377.0 11368.0 11353.0 11341.5 11320.5 11306.5 11293 0 11282 5 11275 0 11251 5 11233 5 11218 5 11199 5 11195.0 11184.0 11179.5 11170.5 11158.0 11153.5 11886.5 11873.0 11866.0 11862.5 11843.0 11820.5 11812.5 11802.0 11768.0 11758.0 11755.5 11746.0 11719.0 11714.5 11704.0 11700.5 11686.5 11678.0 11672.5 11663.0 11633 5 11620 5 11612 0 11582 5 11572 0 11558 0 11552 5 11545 5 11540 5 11527 0 11505.5 11474.0 11458.5 11449.5 11438.5 11407.5 11372.5 11364.5 11349.0 11338.0 11317.5 11305.0 11294.0 11283.5 11274.0 11249.0 11231.0 11217.5 11197.5 11194.5 11185.5 11180.5 11171.0 11156.5 11149.0 17-AUG-1998 12:07 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: 11151.0 11133.5 11127.5 11112.0 11109.5 11101.5 11089.0 11075.5 11048.5 11002.0 10994.5 10984.5 10976.0 10967.0 $ MERGED DATA SOURCE LDWG TOOL CODE CDR CDR $ REMARKS: 11147.5 11134.5 11129.5 11112.5 11107.5 11101.0 11089 0 11077 5 11048 5 11000 5 10993 0 10981 0 10972 5 10962 5 BIT RUN NO. MERGE TOP MERGE BASE 1 4676.0 7520.0 2 7520.0 13072.0 The depth adjustments shown above reflect the MWD GR to the GR?CCL logged by WA on 3-AUG-98. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/PEL/PER. The LDWG outputs of CALA and CALS are HDIA and VDIA respectively. THE CORRELATIONS SHOWN ABOVE WERE APPLIED AFTER A +15' BLOCK SHIFT. ALL SHIFTS MADEARENOT DISPLAYED IN THIS HEADER BECAUSE THEIR NUMBER EXCEEDS THE HEADER BUFFER SIZE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12: 07 PAGE TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD Ot~4M O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~M O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHMM O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~4M O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALA MWD IN O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CRATMWD O0 000 O0 0 1 1 1 4 68 0000000000 TRPMMWD RPM O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13124.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD -999.250 GR.MWD RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD DRHO.MWD -999.250 PEF.MWD -999.250 DCAL.MWD -999.250 CALS.MWD CALA.MWD -999.250 NPHI.MWD -999.250 CRAT.MWD -999.250 TRPM.MWD -999.250 -999.250 -999.250 -999.250 15.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: DEPT. 4677.000 FET.MWD VRA.MWD -999.250 VRP.MWD RHO1.MWD -999.250 RHO2.MWD DRHO.MWD -999.250 PEF.MWD CALA.MWD -999.250 NPHI.MWD -999.250 RA.MWD -999.250 ROP.MWD -999.250 RHO3.MWD -999.250 DCAL.MWD -999.250 CRAT.MWD -999.250 RP.MWD -999.250 GR.MWD -999.250 RHO4.MWD -999.250 CALS.MWD -999.250 TRPM.MWD -999.250 71.038 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/14 , MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUM~Lau~Y VENDOR TOOL CODE START DEPTH CDR 4676.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 7584.0 05-M~-98 5 68R _ 5.OB MEMORY 13125.0 4676.0 13125.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 0.0 71.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR COMP. DUAL RESISTIVITY ADN AZI DENSITY $ TOOL NUMBER ........... CDR8044 ADNll9 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) 9. 675 7560.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 1000 FLUID LOSS (C3): RESISTIVITY (OHi~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 3.310 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.330 MUD CAKE AT (MT): 4.120 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) TOOL STANDOFF (IN) EWR FREQUENCY (HZ) 20000 REMARKS: ******** 12.25 inch Surface Hole ************ MWD Run 002 CDR 8044 v4.1 Gamma Ray is corrected for hole size and mud weight Ail data is from down hole recorded memory ********* 8.5 inch Production Hole ********** MWD Run 003 CDR 7027 vS.0 ADN 119 vS.0 sources: NSRO33/GSR2066 TNPH corrected for hole size, hyrogen index, mud salinity, and temperature. THIS FILE CONTTAINS THE RAW DATA FOR BIT RUN #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 255 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 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFi~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT TVDE LW1 FT ROP5 LW1 F/HR TABR LW1 A TR LW1 OHM~ PSR LW1 OHM~ GR LW1 GAPI O0 000 O0 0 2 1 1 4 O0 000 O0 0 2 1 1 4 O0 000 O0 0 2 1 1 4 O0 000 O0 0 2 1 1 4 O0 000 O0 0 2 1 1 4 O0 000 O0 0 2 1 1 4 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 4676. 000 TVDE.LW1 3495.208 ROPS.LW1 -999.250 TABR.LW1 A TR . LW1 2. 215 P SR . LW1 2. 315 GR. LW1 71. 038 DEPT. 7584. 000 TVDE. LWI 4523 . 092 ROPS. LW! 178. 328 TABR. LW1 ATR. LW1 2. 704 PSR. LW1 2. 860 GR. LW1 147. 411 0.000 1781.984 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center · 17-AUG-1998 12:07 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE · 98/08/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~BER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~9~ARY VENDOR TOOL CODE START DEPTH CDR 7448.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13124.0 05-MAR-98 5 68R _ 5. OB MEMORY 13125.0 4676.0 13125.0 0.0 71.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR COMP. DUAL RESISTIVITY ADN AZI DENSITY $ TOOL NUFiBER ........... CDR8044 ADNll9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: 12 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) .. DRILLERS CASING DEPTH (FT) : 9. 675 7560.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 1000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 3.310 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 330 MUD CAKE AT (MT): 4.120 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ******** 12.25 inch Surface Hole ************ MWD Run 002 CDR 8044 v4.1 Gamma Ray is corrected for hole size and mud weight Ail data is from down hole recorded memory ********* 8.5 inch Production Hole ********** MWD Run 003 CDR 7027 vS.0 ADN 119 vS.0 sources: NSRO33/GSR2066 TNPH corrected for hole size, hyrogen index, mud salinity, and temperature. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 124 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: 13 TYPE REPR CODE VALUE 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 8 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 NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 TVDE LW2 FT O0 000 O0 0 3 1 1 4 68 0000000000 ROP5 LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 TABR LW2 O0 000 O0 0 $ 1 1 4 68 0000000000 ATR LW2 OH~M O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OH~M O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 TABD LW2 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 UB LW2 O0 000 O0 0 3 1 1 4 68 0000000000 DCAL LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 TNRA LW2 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM O0 000 O0 0 3 1 ! 4 68 0000000000 VDIA LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 HDIA LW2 IN O0 000 O0 0 3 1 i 4 68 0000000000 DPHB LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 DPHU LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 DPHL LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 DPHR LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE 14 ** DATA ** DEPT. 7448 ATR. LW2 3 DRHB . LW2 - 0 PEB. LW2 12 ROBB. LW2 2 UB . LW2 37 VDIA . LW2 7. DPHL. LW2 - 20. DEPT. 13124. ATR. LW2 2. DRHB. LW2 0. PEB . LW2 3. ROBB . LW2 2. UB . LW2 8. VDIA . LW2 8. DPHL. LW2 10. 500 TVDE. LW2 4514. 767 ROPS. LW2 -999. 250 TABR. LW2 233 PSR. LW2 3 . 089 GR. LW2 73 . 170 TABD. LW2 440 DRHL.LW2 -0.440 DRHU. LW2 -0.440 DRHR.LW2 659 PEL. LW2 12. 659 PEU. LW2 12. 659 PER. LW2 992 ROBL. LW2 2. 992 ROBU. LW2 2. 992 ROBR. LW2 609 DCAL. LW2 O. 360 ~. LW2 28.846 RPM. LW2 601 HDIA. LW2 8. 201 DPHB. LW2 -20. 706 DPHU. LW2 706 DPHR.LW2 -20. 706 TNPH.LW2 55.578 500 TVDE.LW2 7453.275 ROPS.LW2 120.907 TABR.LW2 206 PSR. LW2 1 . 969 GR. LW2 98. 543 TABD. LW2 078 DRHL.LW2 O. 063 DRHU. LW2 O. 057 DRHR.LW2 359 PEL. LW2 3. 224 PEU. LW2 3.209 PER. LW2 495 ROBL. LW2 2. 485 ROBU. LW2 2. 516 ROBR. LW2 420 DCAL. LW2 O. 230 TNRA. LW2 22.886 RPM. LW2 735 HDIA.LW2 8. 828 DPHB.LW2 9. 416 DPHU. LW2 013 DPHR. LW2 7. 985 TNPH. LW2 38.198 O. 000 0. 000 -0. 440 12. 659 2. 992 O. 000 -20. 706 1739. 969 3979.906 O. 082 3. 124 2. 518 15. 000 8. 121 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/08/14 ORIGIN : FLIC TAPE NAME : 98160 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · B.P. EXPLORATION, MILNE POINT MPL-40, API #50-029-22855-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-AUG-1998 12:07 PAGE: 15 **** REEL TRAILER **** SERVICE NAME .. EDIT DATE : 98/08/14 ORIGIN : FLIC REEL NAME : 98160 CONTINUATION # : PREVIOUS REEL : COR~IENT : B.P. EXPLORATION, MILNE POINT MPL-40, API #50-029-22855-00 *******.~.~********************,~ * ~ COMP~ING C~ * ****************************** * ...... ~STE~ AT~S LOG - - - * * ....... PROCESS~ BY ....... * * ....... SCHL~ERGER ....... * ****************************** COMPANY NAME : BP EXPLORATION (ALASKA) WELL ~AME : MPL-40 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292285500 REFERENCE NO : 98399 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/08/ 3 ORIGIN : FLIC REEL NAME : 98399 CONTINUATION # : PREVIOUS REEL : COf4~iENT : BP EXPLORATION, MILNE POINT, MPL-40, API #50-029-22855-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/ 3 ORIGIN : FLIC TAPE NAME : 98399 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT, MPL-40, API #50-029-22855-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPL-40 API NUMBER: 500292285500 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: WESTERN ATLAS TAPE CREATION DATE: 3-AUG-98 JOB AUgM~ER: 98399 LOGGING ENGINEER: RECK OPERATOR WITNESS: K WALKER SURFACE LOCATION SECTION: 8 TOWNSHIP: 13N RANGE: 10E FNL: FSL: 3142 FEL: 5018 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 50.60 DERRICK FLOOR: 50.60 GROUND LEVEL: 17.55 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 1ST STRING 9. 675 7560.0 40. O0 2ND STRING 7. 000 13040.0 26. O0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(M~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GR ....... REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE GR/CCL DATA AQUIRED ON BP EXPLORATION'S MPL-40 WELL. THIS LOG IS THE PDC FOR THIS WELL. THIS IS A WESTERN ATLAS LOG PROCESSED BY SCHLUMBERGER. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~iBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUM~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH GR 12960.0 7450.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GR ....... ~KS: THIS FILE CONTAINS CASED HOLE GR/CCL MAIN PASS DATA. THIS IS THE PDC PASS. LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: $ 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 O. 5 9 65 FT 11 66 64 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 NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELE~ CODE (HEX) DEPT FT 194605 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 194605 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 194605 O0 000 O0 0 1 1 1 4 68 0000000000 TEND GR LBF 194605 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12960.000 CCL.GR 0.000 GRCH. GR 63.360 TEND.GR DEPT. 7450. 000 CCL. GR 80. 340 GRCH. GR 26. 560 TEND. GR 943.687 -33.468 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: **** FILE TRAILER **** FILE NAIVE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~iE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE19IIMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GR 12960.0 12705.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GR ..................... $ REMARKS: THIS FILE CONTAINS CASED HOLE GR/CCL REPEAT PASS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: 5 ** 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 O. 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 NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 194605 O0 000 O0 0 2 1 1 4 68 0000000000 CCL GR V 194605 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH GR GAPI 194605 O0 000 O0 0 2 1 1 4 68 0000000000 TEND GR LBF 194605 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12960.000 CCL.GR 0.000 GRCH. GR 60.126 TEND.GR DEPT. 12705.000 CCL.GR 163.800 GRCH. GR 54.654 TEND. GR 1340.729 -15. 047 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/ 3 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 INCREM~2Fr: O. 2500 FILE SUM~U~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 13000.0 7442.3 GR 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CCL COLLAR LOCATER $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 08-MAY-98 JO01 VER1.1 12958.0 12961.0 7450.0 12960.0 TOOL NUM~ER ........... GR 8262XA PCM 8250EA LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 13040.0 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) : SEAWATER/DIESEL NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG WAS RUN ON MARKED LINE FOR PRIMARY DEPTH CONTROL FILM SPLICE AT 12620' DUE TO PLOTTER RUNNING OUT OF FILM THIS FILE CONTAINS THE RAW DATA FOR THE MAIN PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger -Alaska Computing Center 3-AUG-1998 15:36 PAGE: 8 TYPE REPR CODE VALUE 8 68 0.25 9 65 FT 11 66 51 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 NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 194605 O0 000 O0 0 3 1 1 4 68 0000000000 CCL GR V 194605 O0 000 O0 0 3 1 1 4 68 0000000000 GR GR GAPI 194605 O0 000 O0 0 3 1 1 4 68 0000000000 TEN GR LBF 194605 O0 000 O0 0 3 1 1 4 68 0000000000 SPD GR F/HR 194605 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 13000.000 CCL.GR SPD.GR 0.000 DEPT. 7442.500 CCL.GR SPD.GR 0.000 200.000 GR.GR 103.740 GR. GR 0.000 TEN. GR 0.000 TEN. GR 0.000 -500.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 98/08/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INC~: 0.2500 FILE SU~94ARY VENDOR TOOL CODE START DEPTH GR 12987.0 $ 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMFiA RAY CCL COLLAR LOCATER $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 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) : STOP DEPTH .......... 12699.3 08 -MAY-98 JO01 VER1.1 12958.0 12961.0 7450.0 12960.0 TOOL NUMBER GR 8262XA PCM 8250EA 13040.0 SEAWATER/DIESEL LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: 10 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): 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: LOG WAS RUN ON MARKED LINE FOR PRIMARY DEPTH CONTROL FILM SPLICE AT 12620' DUE TO PLOTTER RUNNING OUT OF FILM THIS FILE CONTAINS THE RAW 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 20 4 66 1 5 66 6 73 7 65 8 68 0.25 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-AUG-1998 15:36 PAGE: 11 ** SET TYPE- CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194605 O0 000 O0 0 4 1 1 4 68 0000000000 CCL GR V 194605 O0 000 O0 0 4 1 1 4 68 0000000000 GR GR GAPI 194605 O0 000 O0 0 4 1 1 4 68 0000000000 TEN GR LBF 194605 O0 000 O0 0 4 1 1 4 68 0000000000 SPD GR F/HR 194605 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12987.000 SPD.GR 0.000 DEPT. 12699.250 SPD.GR 0.000 CCL.GR 200.000 GR.GR 0.000 TEN. GR CCL.GR 84.630 GR. GR 0.000 TEN. GR 0.000 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO! DATE : 98/08/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/08/ 3 ORIGIN · FLIC TAPE NAME : 98399 CONTINUATION # : 1 PREVIOUS TAPE : COMFiENT : BP EXPLORATION, MILNE POINT, MPL-40, API #50-029-22855-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/08/ 3 ORIGIN : FLIC REEL NAME : 98399 CONTINUATION # : PREVIOUS REEL : CO~4ENT : BP EXPLORATION, MILNE POINT, MPL-40, API #50-029-22855-00
