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Home My WebLink About196-0681. 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 8,640 feet 8,398 feet true vertical 7,195 feet 8,514 feet Effective Depth measured 8,563 feet 8,372 feet true vertical 7,177 feet 6,992 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5# / L-80 / EUE 8rd 8,064' 6,747' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# / L-80 / NSCT 8,404' 7,016' Packers and SSSV (type, measured and true vertical depth)HES 7" x 4-1/2" 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: 323-316 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 174 Gas-Mcf MD 110' 0 Size 110' 3,497' 1521 42022 0 00 367 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-068 50-029-22670-00-00 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: ADL0028232 & ADL0375133 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT K-05 Plugs Junk measured LengthCasing Conductor 8,587' 3,823'Surface Production 20" 9-5/8" 7" 110' 3,787'5,750psi 7,240psi8,620' 7,180' Burst N/A Collapse N/A 3,090psi 5,410psi 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 3:27 pm, Aug 08, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.08.08 15:05:41 - 08'00' Taylor Wellman (2143) RBDMS JSB 081523 WCB 4-8-2024 DSR-8/14/23 _____________________________________________________________________________________ Revised By: TDF 8/8/2023 Milne Point Unit Well: MP K-05 Last Completed: 7/9/2023 PTD: 196-068 SCHEMATIC TD =8,640’ (MD) / TD = 7,195’(TVD) 20” KBE= 62.4’ 7” 7” Howco ES Cementer @ 5,577’ 9-5/8” Min ID = 2.205” @7,913’ MD KUP C Sands Tag fill @ 8,494’ WLM, ~8,514’ MD 11/17/1998 PBTD =8,536’(MD) /PBTD = 7,177’(TVD) KUP B Sands 15 1 2 3 4& 5 13 14 16 17 18 6, 7 &8 9&10 11 &12 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 91.1 / NT80LHE N/A Surface 110' N/A 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 3,823’ 0.0758 7" Production 26 / L-80 / BTC 6.276 Surface 8,620’ 0.0383 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,064’ 0.0058 4-1/2” Tubing 12.6 / L-80 / NSCT 3.958 8,372 8,404 0.0152 JEWELRY DETAIL No Top (MD) Item 1 158’ GLM 2: 2-7/8 X 1'' Side pocket, w/DSOV & BK Latch 2 7,791’ GLM 1: 2-7/8 X 1'' Side pocket,W/DSOV & BK Latch 3 7,912’ 2-7/8” HES XN Nipple:Min ID= 2.205” 4 7,962.8’ Discharge Head: DSCHG B/O PMP 513 5 7,963’ Zenith Ported Sub: HEAD S/A 513/538 PX PRESS PORT 513/538P PMP 6 7,964’ Pump #1: PMP 538PMSXD 066 7 7,980’ Pump #2: PMP 538PMSXD 093 8 8,002’ Pump #3: PMP 538PMSXD 20 9 8,012’ Gas Separator: 538GM2T HV E V X MT HS FER STD PN 10 8,017’ Intake: GPXARCINT FER H6 11 8,018’ Upper Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 12 8,025’ Lower Seal: GSB3DB FER HL SSCV H6 SB/SB CL-5E 13 8,032’ Motor: 562XP 450 Hp / 3135V / 88A / 18R 14 8,059’ Zenith Motor Gauge & Centralizer: Bottom @ 8,064’ 15 8,372’ HES 7” x 4-1/2” 23-32# Perma-Series Packer 16 8,381’ 4-1/2” X Nipple 17 8,398’ 4-1/2” XN Nipple w/ Plug Installed, ID= 3.95” 18 8,403’ 4-1/2” WLEG, ID= 4.00 –Bottom @ 8,404 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. C Sands 8,302’ 8,358’ 6,937’ 6,981’ 56 8/11/1996 Open Kup. B Sands 8,390’ 8,430’ 7,006’ 7,036’ 40 8/11/1996 Open Ref Log: Atlas GR/ CCL 8/10/1996 – 4-1/2” gun diameter/ 5 SPF OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I in 30” hole 9-5/8" 779 sx PF ‘E’, 736 sx ‘G’, 250 sx PF ‘C’ in a 12-1/4” hole 7” 220 sx Class ‘G’ in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 1,500’ Max Hole Angle = 38 to 42 deg. f/ 2,800’ to 7,750’ Max Hole Angle through perforations = 40 deg. DLS 4.5°/100’ @ 2,300’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8Rd. on bottom, 2-1/2” CIW BPV profile GENERAL WELL INFO API: 50-029-22670-00 Orig. Drilling by Nabors 27E - 4/19/1996 Orig. Completion by Nabors 4ES - 8/12/1996 ESP RWO w/ Nabors 4ES – 11/18/1998 ESP RWO and set isolation packer w/ Nabors 4ES – 1/22/2002 ESP RWO and open isolation packer w/ Nabors 4ES – 12/01/2004 ESP RWO w/ Nabors 3S – 1/10/2009 ESP RWO w/ Doyon 16 – 12/31/2013 ESP Swap w/ ASR#1 – 7/9/2023 Well Name Rig API Number Well Permit Number Start Date End Date MP K-05 Wellhead 50-029-22670-00-00 196-068 6/29/2023 7/9/2023 6/30/2023 - Friday No operations to report. 6/28/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/29/2023 - Thursday Set 2 1/2 BPV in well after kill, bled void N/D TREE/ADAPTER SET cts plug and teseted 500 low 5000 high 5/10 min checked lift threads. Plugged CL ports S/B for R/U and BOPE test. No operations to report. No operations to report. 7/1/2023 - Saturday No operations to report. 7/4/2023 - Tuesday 7/2/2023 - Sunday No operations to report. 7/3/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP K-05 Wellhead 50-029-22670-00-00 196-068 6/29/2023 7/9/2023 7/7/2023 - Friday Continue L/D ESP BHA. Swap floor equipment to run 3-1/2" Work String.M/U Baker 7" Test Packer, install wiper rubber. Trip in hole at 70fpm to 2,537'. P/U 28k S/O 24k. Crew change, shut down and check equipment.Cont RIH w/ 7" Baker Test Packer from 2,539' to 8,105'. Screw in w/ quill, M/U Kelly Hose, line up to pump. P/U 86K - S/O 49K.Set packer as per Baker Rep 1 turn to the left and set 20k down to ensure packer set. Packer COE @ 8,088.12' MD. Fill Backside with 67BBLS. Close Annular. Pressure test to 2,000psi - good, charted test. Bleed pressure off backside to 0psi. Lower Annular pressure to 550psi, Strip OOH to unseat Packer well went on a vac monitored for 10min till was static. Opened Annular.Turned the pipe to the right 3 times to move the packer into running position, slacked off to ensure packer was in the correct position. BD surface lines and RD swivel.POOH w/ Test Packer. F/8,088' T/ 5,502'.Cont'd POOH w/ Test Packer. F/5,502' to surface. LD packer. 7/5/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Rig was Accepted at 18:00.PU RU testing equip.Test BOPE as per sundry. 250psi low. 2500psi high all charted 5min tests. AOGCC rep Sean Sullivan waived witness.Test BOPE as per sundry. 250psi low. 2500psi high all charted 5min tests. AOGCC rep Sean Sullivan waived witness. Noticed water coming out of the weep hole on blind rams functioned and still had a leak. Blind ram weep holes held in the open position. Cont'd test 3.5'' mandrel and choke valves. SIMOPS spotted in ESP Spool unit and gen set into place.Hung ESP sheave and elephant trunk. BD all surface lines and stack to prepare for while waiting on Yellow jacket Rep to come out and service the blind rams. 7/6/2023 - Thursday Continue testing BOPE. Inspect Accumulator, Change pressure settings, redo draw down test. Continue working on various projects awaiting Yellow Jacket BOP specialist.Change out Blind Ram Seals, reassemble Blind Ram. Test Blind Rams against blinds and C2. 250psi low, 2500psi high.Pump 30BBLS down IA - 3 BPM @ 100psi. IA on slight vac. Blow down lines and stack. Pull CTS Plug and BPV. M/U Landing Joint w/ Kelly Hose attached. BOLDS. Unseat TBG Hanger @ 60K, P/U weight 64K. Break out and lay down Hanger. Attach ESP Cable to rope.POOH w/ 2-7/8" ESP Completion F/ 8,050' to 2,400'. Crew change, shut down equipment and check fluids. 73 BBLS pumped for hole fill during tour.POOH w/ 2-7/8" ESP Completion F/ 2,400' T/ ESP pump assy, pumping double displacement every 15 jts. Make service breaks on Baker Packer. Lower Sheave and route ESP Cable through, re-hang Sheave. Load 2-7/8", 6.5#,L, EUE R2 Tubing in Pipe Shed. Tally Joints. Load Jewelry in Shed. Load ESP Pumps and Motors.Offload 200bbls of 8.4ppg source water to pits. PU upper and lower Tandem Seal assemblies. Fill assemblies with oil and connect Pot Head.Tie in MLE to Motor. MU Intake Gas Seperator, 3 Pumps, Ported Sub & Discharge Head, MU JT#1 Ported Sub stacked out in Hanger Bowl. Rotated ported sub, ran in JT#1. Clear floor of Baker install equipment. Final tests on ESP passed.RIH w/ 2-7/8" ESP completion. Install XN-Nipple between JTS 1&2. GLM#1 w/ DMY VLV between JTS 4&5. T/ 5,041'MD.Cont. RIH w/ 2-7/8" ESP Completion F/ 5,041MD T/ 6,799'MD testing ESP Cable every 1000' 7/8/2023 - Saturday Well Name Rig API Number Well Permit Number Start Date End Date MP K-05 Wellhead 50-029-22670-00-00 196-068 6/29/2023 7/9/2023 Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. No operations to report. 7/11/2023 - Tuesday 7/9/2023 - Sunday Continue RIH w/ 2-7/8" ESP Completion from 6,799'MD to 8,037.89'MD while pumping double displacement and testing every 1000'. Clamp cable every other joint. Total Clamp count: 7 Protectolizers, 2 Flat Guards, 137 OTC Clamps.Make up Landing Joint / Tubing Hanger, connect ESP Cable to Penetrator and test - good. FINAL PUW 68K, SOW 45K. Land hanger w/ base of ESP at 8,064.19, RILDS. Install BPV.Blow down surface lines. Rig down. Swap to Well K-30 at 12:00. WELLHEAD: Completion. MU LJ w/ 2 7/8 LH ACME to tbg hgr, MU to comp. string. Centralift install ESP penitrator and splice cable. Land hgr into profile 16.15' RKB, RILDS and B/O LJ. Set 2.5 Bpv. ASR RD. BOP stack off, clean hgr void, install seal subs and R46 gasket. PU tree/adapter and land onto tbg spool. Torque to spec and test 500/5000 5/10 min (PASS). Pull Bpv with T bar and install tree cap, all valves closed. 7/10/2023 - Monday Continue RIH w/ 2-7/8" ESP Completion from 6,799'MD to 8,037.89'MD while pumping double displacement and testing every 1000'. Clamp cable every other joint. Total Clamp count: 7 Protectolizers, 2 Flat Guards, 137 OTC Clamps.Make up Landing Joint / Tubing Hanger, connect ESP Cable to Penetrator and test - good. FINAL PUW 68K, SOW 45K. Land hanger w/ base of ESP at 8,064.19, RILDS. Install BPV.Blow down surface lines. Rig down 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: 07/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230711 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 22-06 50133205500000 205054 7/6/2023 YELLOW JACKET CBL KBU 22-06 50133205500000 205054 7/2/2023 YELLOW JACKET CBL/PERF KBU 33-06X 50133205290000 203183 6/14/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/29/2023 YELLOW JACKET GPT/PERF KBU 33-06X 50133205290000 203183 6/13/2023 YELLOW JACKET PERF KU 12-17 50133205770000 208089 6/14/2023 YELLOW JACKET PERF MP F-89 50029232680000 205090 7/6/2023 READ Caliper Survey MP K-05 50029226700000 196068 5/30/2023 READ Caliper Survey MPU E-23 50029225700000 195094 6/23/2023 YELLOW JACKET CUT MPU L-43 50029231900000 203224 6/27/2023 YELLOW JACKET PERF PAXTON 12 50133207100000 223014 6/28/2023 YELLOW JACKET PERF Please include current contact information if different from above. T37830 T37830 T37831 T37831 T37831 T37832 T37833 T37834 T37835 T37836 T37837 MP K-05 50029226700000 196068 5/30/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.11 14:54:56 -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): 8,640'8,514' 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" 3,787' 8,587' Perforation Depth MD (ft): MD N/A 5,750psi 7,240psi 3,497' 7,180' 3,823' 8,620' Length Size Proposed Pools: 110' 110' TVD Burst PRESENT WELL CONDITION SUMMARY 7,195' 8,563' 7,177' 1,902 8,398' 110' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0028232 196-068 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22670-00-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT K-05 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5#/L-80/EUE & 12.6#/L-80/NSCT 8,050' and 8,404' 6/15/2023 HES 7" x 4-1/2" and N/A 8,372' MD/6,992' TVD and N/A See Schematic See Schematic 2-7/8" & 4-1/2" 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 todd.sidoti@hilcorp.com 777-8443 Todd Sidoti Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:19 am, May 31, 2023 323-316 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.05.31 06:57:20 - 08'00' Taylor Wellman (2143) 10-407 MGR28JUN23 ADL0375133, 1,902 SFD 6/8/2023 BOPE pressure test to 2500 psi. MGR28JUN23 DSR-5/31/23 SFD JLC 6/28/2023 06/28/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.28 15:34:42 -05'00' RBDMS JSB 062823 RWO – ESP Swap Well: MPU K-05 Date: 28 Apr 2023 Well Name: MPU K-05 API Number: 50-029-22670-00-00 Current Status: Producer [ESP Failed] Pad: K-Pad Estimated Start Date: June 15th, 2023 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-068 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Scott Pessetto (907) 564-4373 (O) (801) 222-2203 (M) Current Bottom Hole Pressure: 2,602 psi @ 7,000’ TVD (SBHP measured 5/11/2017) 7.15 PPGE Max. Predicted Surf Pressure: 1,902 psi (Using 0.1 psi/ft gas gradient) Max Inclination: 42° @ 4914’ MD Brief Well Summary: MPK-05 is a Kuparuk producer producing from the B/C sands. The current ESP in MPK-05 was installed in 2013. The ESP has failed and is need of replacement. Notes Regarding Wellbore Condition x Well requires an 8 year MIT. Objective: Replace failed ESP with new assembly and return well to production. Pre-Rig Procedure (No sundry required): Slickline Pumping & Well Support 1. MIRU SL and PT PCE to 250 psi low / 1500 psi high. 2. Run memory caliper from top of ESP to surface. 3. Pull dummy valve from deep station. 4. Pull orifice and dummy off top station. 5. RDMO SL. 6. Clear and level pad area in front of well. Spot rig mats and containment. 7. RD well house and flowlines. Clear and level area around well. 8. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 9. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 10. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 11. RD Little Red Services and reverse out skid. 12. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 13. NU BOPE house. Spot mud boat. Well requires an 8 year MIT. RWO – ESP Swap Well: MPU K-05 Date: 28 Apr 2023 Brief RWO Procedure: 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with ppg produced water prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi 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. 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 rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 5. Call out vendor for ESP pull. 6. RU Spooler to pull ESP cable. 7. MU landing joint or spear and PU on the tubing hanger. a. P/U weight was was 45,000# and S/O was 37,000#. 8. Recover the tubing hanger. 9. POOH and lay down the 2-7/8” tubing. Number all joints a. Keep all tubulars for future rig workovers. b. Tubing caliper will be run, and bad joints will be identified prior to the RWO. c. Keep XN nipple and GLMs for future use. d. Keep ported discharge head and centralizer for future use. e. Note any sand or scale inside or on the outside of the ESP on the morning report. f. Look for over-torqued connections from previous tubing runs. g. Recover the following amount of clamps/guards from the completion: i. 132 cross collar (Cannon) clamps ii. 3 SS bands on discharge gauge iii. 4 flat guards iv. 5 pump protectolizers v. 1 motor protectolizer 10. Lay Down ESP. 11. RIH with 7” test packer assembly on 3-1/2” WS to 7,800’. 12. Test casing to 2,000 psi for 30 minutes charted. POOH with test packer. 13. PU new ESP and RIH on 2-7/8” tubing, making electrical checks every 2,000 feet. a. Set base of ESP assembly at ± 8,050’ MD. b. 1 joint of 2-7/8” Tubing c. 2-7/8” XN d. 1 joint of 2-7/8” Tubing Lubricate BPV is risk of trapped pressure below.-mgr RWO – ESP Swap Well: MPU K-05 Date: 28 Apr 2023 e. 2-7/8” GLM w/ DV installed f. 2-7/8” Tubing g. 2-7/8” GLM w/ OV installed at ± 125’ MD. h. 2-7/8” Tubing 14. Land tubing hanger and space out. RILDS. Lay down landing joint. Note PU and SO weights on tally. 15. Set BPV. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By: TDF 12/6/2018 SCHEMATIC Milne Point Unit Well: MP K-05 Last Completed: 12/31/2013 PTD: 196-068 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 91.1 / NT80LHE N/A Surface 110'N/A 9-5/8"Surface 40 / L-80 / BTC 8.835 Surface 3,823’0.0758 7"Production 26 / L-80 / BTC 6.276 Surface 8,620’0.0383 TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 8,050’0.0058 4-1/2”Tubing 12.6 / L-80 / NSCT 3.958 8,372 8,404 0.0152 JEWELRY DETAIL No Top (MD)Item 1 142’GLM ST 2: Camco 2-7/8” x 1”, KBMM-2 w/ DSOV 2 7,786’GLM ST 1: Camco 2-7/8” x 1”, KBMM-2 w/ DGLV 3 7,937’2-7/8” HES XN Nip,Min ID= 2.205” 4 7,980’’WellLift Discharge Gauge Unit 5 7,984’Discharge Head: GPHVDIS 6 7,985’Upper Pump: 137-P17 ArmorX 7 8,004’Lower Pump: 18-P75 ArmorX 8 8,011’Gas Separator: GRSFTXAR H6 9 8,016’Upper Tandem Seal: GSB3DBUT SB/SB PFSA 10 8,023’Lower Tandem Seal: GSB3DBLT SB/SB PFSA 11 8,030’Motor: MSP-1 – HP 210 / 2,380V / 53A 12 8,046’PumpMate w/6 fin centralizer –Bottom @ 8,050’ 13 8,372’HES 7” x 4-1/2” 23-32# Perma-Series Packer 14 8,381’4-1/2” X Nipple 15 8,398’4-1/2” XN Nipple w/ Plug Installed, ID= 3.95” 16 8,403’4-1/2” WLEG, ID= 4.00 –Bottom @ 8,404 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Kup. C Sands 8,302’8,358’6,937’6,981’56 8/11/1996 Open Kup. B Sands 8,390’8,430’7,006’7,036’40 8/11/1996 Open Ref Log: Atlas GR/ CCL 8/10/1996 – 4-1/2” gun diameter/ 5 SPF OPEN HOLE / CEMENT DETAIL 20"250 sx of Arcticset I in 30” hole 9-5/8"779 sx PF ‘E’, 736 sx ‘G’, 250 sx PF ‘C’ in a 12-1/4” hole 7”220 sx Class ‘G’ in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 1,500’ Max Hole Angle = 38 to 42 deg. f/ 2,800’ to 7,750’ Max Hole Angle through perforations = 40 deg. DLS 4.5°/100’ @ 2,300’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8Rd. on bottom, 2-1/2” CIW BPV profile GENERAL WELL INFO API: 50-029-22670-00 Orig. Drilling by Nabors 27E - 4/19/1996 Orig. Completion by Nabors 4ES - 8/12/1996 ESP RWO w/ Nabors 4ES – 11/18/1998 ESP RWO and set isolation packer w/ Nabors 4ES – 1/22/2002 ESP RWO and open isolation packer w/ Nabors 4ES – 12/01/2004 ESP RWO w/ Nabors 3S – 1/10/2009 ESP RWO w/ Doyon 16 – 12/31/2013 _____________________________________________________________________________________ Revised By: TDF 12/6/2018 PROPOSED SCHEMATIC Milne Point Unit Well: MP K-05 Last Completed: 12/31/2013 PTD: 196-068 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20"Conductor 91.1 / NT80LHE N/A Surface 110'N/A 9-5/8"Surface 40 / L-80 / BTC 8.835 Surface 3,823’0.0758 7"Production 26 / L-80 / BTC 6.276 Surface 8,620’0.0383 TUBING DETAIL 2-7/8"Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ~8,050’0.0058 4-1/2”Tubing 12.6 / L-80 / NSCT 3.958 8,372 8,404 0.0152 JEWELRY DETAIL No Top (MD)Item 1 ~142’GLM ST 2: Camco 2-7/8” x 1”, KBMM-2 w/ DSOV 2 ~7,786’GLM ST 1: Camco 2-7/8” x 1”, KBMM-2 w/ DGLV 3 ~7,937’2-7/8” HES XN Nip, Min ID= 2.205” 4 ~7,980’’Discharge Gauge 5 ~7,984’Discharge Head 6 ~7,985’Upper Pump 7 ~8,004’Lower Pump 8 ~8,011’Gas Separator 9 ~8,016’Upper Seal 10 ~8,023’Lower Seal 11 ~8,030’Motor 12 ~8,046’Centralizer 13 8,372’HES 7” x 4-1/2” 23-32# Perma-Series Packer 14 8,381’4-1/2” X Nipple 15 8,398’4-1/2” XN Nipple w/ Plug Installed, ID= 3.95” 16 8,403’4-1/2” WLEG, ID= 4.00 –Bottom @ 8,404 PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date Status Kup. C Sands 8,302’8,358’6,937’6,981’56 8/11/1996 Open Kup. B Sands 8,390’8,430’7,006’7,036’40 8/11/1996 Open Ref Log: Atlas GR/ CCL 8/10/1996 – 4-1/2” gun diameter/ 5 SPF OPEN HOLE / CEMENT DETAIL 20"250 sx of Arcticset I in 30” hole 9-5/8"779 sx PF ‘E’, 736 sx ‘G’, 250 sx PF ‘C’ in a 12-1/4” hole 7”220 sx Class ‘G’ in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 1,500’ Max Hole Angle = 38 to 42 deg. f/ 2,800’ to 7,750’ Max Hole Angle through perforations = 40 deg. DLS 4.5°/100’ @ 2,300’ TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr., 3” LH Acme on top and 2-7/8” EUE 8Rd. on bottom, 2-1/2” CIW BPV profile GENERAL WELL INFO API: 50-029-22670-00 Orig. Drilling by Nabors 27E - 4/19/1996 Orig. Completion by Nabors 4ES - 8/12/1996 ESP RWO w/ Nabors 4ES – 11/18/1998 ESP RWO and set isolation packer w/ Nabors 4ES – 1/22/2002 ESP RWO and open isolation packer w/ Nabors 4ES – 12/01/2004 ESP RWO w/ Nabors 3S – 1/10/2009 ESP RWO w/ Doyon 16 – 12/31/2013 Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned b~ildred Daretha Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Isl STATE OF ALASKA RECEIVED A�. .,dKA OIL AND GAS CONSERVATION CO�v��AISSION JAN 2 2 2014 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AOGCC ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well 0 Alter Casing ®Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other 0 Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic • 196-068 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 • 50-029-22670-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 375133&028232 ' + MPK-05 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): - Milne Point Unit/Kuparuk River Oil 11. Present well condition summary: Total depth: measured .. 8640' feet Plugs:(measured) None feet true vertical 7195' feet Junk:(measured) None feet Effective depth: measured 8536' feet Packer: (measured) 8372' feet true vertical 7117' feet Packer: (true vertical) 6992' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 38'- 110' 38'- 110' Surface 3787' 9-5/8" 36'-3823' 36'-3497' 5750 3090 Intermediate Production 8587' 7" 33'-8620' 33'-7180' 7240 5410 Liner SatItifo JUL 1 6 2014 Perforation Depth: Measured Depth: 8302'-8430' feet True Vertical Depth: 6937'-7037' feet Tubing(size,grade,measured and true vertical depth): 2-7/8 ,6.5#; L-80; 8050'; 6735'; 4-1/2", 12.6# L-80 8372'-8404' 6992'-7017' Packers and SSSV(type,measured and true vertical depth): 7"23-32#Perma-Series Packer 8372' 6992' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: RBDM MAY 16 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 760 0 Subsequent to operation: 113 24 1365 220 189 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: • 0 Exploratory 0 Stratigraphic ®Development 0 Service ®Daily Report of Well Operations 0 Well Schematic Diagram 16. Well Status after work: • ®Oil 0 Gas 0 WDSPL 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Abby Warren,564-5720 Email:Abigail.Warren@bp.com N/A Printed Name: Joe Lastufka(\ Title: Drilling Technologist ( Signature: hone: 564-4091 Date: 1// .,1/14' Form 10-404 Revised 10/2012VG /Z g/`q �� Submit Original Only North America-ALASKA-BP Page 1 of 7 Operation Summary Report Common Well Name:MPK-05 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2013 End Date:12/31/2013 X4-00YCT-E:(1,800,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/6/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292267000 Active datum:ORIG KELLY BUSHING @46.60usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/26/2013 06:00 - 00:00 18.00 MOB P PRE PREPARE TO MOVE OFF MPL TOWARDS MPK -09:00 HRS PULL OFF MPL-43.WSL AND TOOLPUSHER PRESENT. -10:00-12:00 HRS REMOVE BOPE STACK -12:00-16:00 INSTALL BOOSTER WHEELS. -16:00 HRS PJSM RIG MOVE.DDI HSE REPRESENTATIVE PRESENT. -19:00 HRS RIG OFF MPL PAD. -21:30 HRS RIG AT MILNE SPINE ROAD. -23:30 HRS RIG AT MPU TURN OFF FOR CREW CHANGE. 12/27/2013 00:00 - 01:00 1.00 MOB P PRE MOVE RIG FROM MPU TOWARDS MPK. 01:00 - 04:00 3.00 MOB P PRE MOVE RIG FROM MPK ACCESS ROAD TO MPK-PAD. 04:00 - 05:30 1.50 MOB P PRE MOVE RIG ONTO MPK-PAD. 05:30 - 07:00 1.50 MOB P PRE PJSM,REMOVE BOOSTER WHEELS -REMOVE BOOSTER WHEELS F/FRONT AND REAR. -LOAD BOP STACK INTO CELLAR. 07:00 - 08:30 1.50 MOB P PRE PJSM,RAISE DERRICK. -LEVEL AROUND CELLAR. -LAY MATS FOR RIG. 08:30 - 10:00 1.50 MOB P PRE PJSM,BACK RIG OVER MPK-05. -WSL AND PAD OPS PRESENT. 10:00 - 12:00 2.00 RIGU P PRE RIG UP. -SPOT CUTTING BOX. -SPOT RIG COMPONENTS. 12:00 - 15:30 3.50 RIGU P , PRE R/U KILL MANIFOLD IN CELLAR. -T-HARD LINE TO BOTH FLOW BACK TANKS. -SPOT SLOP TANK. BRING ON 8.5 PPG SEAWATER INTO PITS. -BRIDLE DOWN TOP DRIVE. ACCEPT DOYON 16 RIG AT 12:00 HRS ON 12/27/2013. 15:30 - 22:00 6.50 RIGU P PRE PJSM,CONTINUE TO R/U KILL MANIFOLD AND CIRCULATE OUT LINES TO HARD LINES. -R/U OA TO BLEED TRAILER. -CLEAR LINES WITH STEAM AND AIR. -FLUID PACK WITH DIESEL TO TEST. -ATTEMPT TO TEST LINES.UNABLE DUE TO FAULTY HOSE ON FLOW BACK TANK -BLOW DOWN LINES TO REMOVE FAULTY HOSE AND REPLACE WITH NEW HOSE. -FLUD PACK LINES AND RETEST. -TEST HARD LINES TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. 22:00 - 22:30 0.50 RIGU P PRE H2S RIG EVACUATION DRILL. -AAR WITH WSL AND ALL PERSONAL ON LOCATION. -DISCUSSED WITH CREW SAFE AREAS AND PROPER STORAGE OF WINTER GEAR NEAR EGRESS. 22:30 - 00:00 1.50 BOPSUR P PRE PJSM,P/U WELL SUPPORT LUBRICATOR. -TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. Printed 1/13/2014 11:08:11AM North America-ALASKA-BP Page 2 of 7 Operation Summary Report Common Well Name:MPK-05 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2013 End Date:12/31/2013 X4-00YCT-E:(1,800,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/6/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292267000 Active datum:ORIG KELLY BUSHING©46.6ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/28/2013 00:00 - 00:30 0.50 BOPSUR P PRE SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. PJSM,PULL BPV WITH WELL SUPPORT. -PULL BPV. L/D LUBRICATOR. 00:30 - 04:00 3.50 BOPSUR P PRE PJSM,WELL KILL WITH 8.5 PPG SEAWATER. -REVIEW DDI WELL KILL S.O.P. -BRIDGING DOCUMENT. -DISCUSSED INDIVIDUAL ROLLS AND RESPONSIBILITIES. -WSLAND TOOL PUSHER PRESENT FOR OPERATION. SITP=650 PSI, SICP=900 PSI,OA=16 PSI. KWF=8.5 PPG HEATED 120 DEG.SEAWATER. -WSL/TOOL PUSHER VERIFY VALVE ALIGNMENT. -BLEED GAS FROM THE IA.FROM 900 PSI TO 150 PSI IN 15 MINUTES.SITP=550 PSI. -NO FLUID RETURNS. PUMP 47 BBLS KWF DOWN THE TUBING UP THE IA THROUGH THE CHOKE OUT TO THE FLOW BACK TANK. -ICP:3 BPM=560 PSI. -FCP:5 BPM=80 PSI. -NO FLUID RETURNS TO SURFACE AFTER 47 BBLS PUMPED. -BULL HEAD ON THE FLY:17 BBLS KWF,3 BPM=90 PSI. PUMP 428 BBLS KWF DOWN THE TUBING UP THE IA THROUGH THE CHOKE OUT TO THE FLOW BACK TANK. -ICP:3 BPM=770 PSI. -FCP:5 BPM=1080 PSI. -PUMPED TOTAL 558 BBLS 8.5 SEAWATER PUMPED. -NO SEAWATER TO SURFACE. -OBSERVED 210 BBLS CRUDE AT FLOWBACK TANK. LOST 348 BBLS KWF TO THE FORMATION. 04:00 - 06:30 2.50 BOPSUR P PRE MONITOR WELL FOR 30 MIN. -TBG ON A VAC,IA=8 PSI. -TBG AND IA VERIFIED ON A MINUET VACUUM. 06:30 - 07:00 0.50 BOPSUR P PRE BLOW DOWN SURFACE LINE R/U SECONDARY KILL LINE TO THE IA. 07:00 - 08:30 1.50 BOPSUR P PRE PJSM,SET TWC. -R/U AND TEST WELL SUPPORT LUBRICATOR. -TEST TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES. -SET TWC.L/D LUBRICATOR. 08:30 - 09:30 1.00 BOPSUR P PRE TEST TWC. -PERFORM ROLLING TEST F/BELOW. -500 PSI AT 8 BPM,5 CHARTED MIN.. -45 BBLS PUMPED. -TEST F/ABOVE 250/3,500 PSI F/5 CHARTED MIN. Printed 1/13/2014 11:08:11AM North America-ALASKA-BP Page 3 of 7 Operation Summary Report Common Well Name:MPK-05 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2013 End Date:12/31/2013 X4-00YCT-E:(1,800,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/6/1996 12:00:OOAM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292267000 Active datum:ORIG KELLY BUSHING @46.60usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 11:30 2.00 BOPSUR P PRE PJSM,N/D AND N/U BOPE -FMC REP BLEED THE TBG HANGER VOID. -N/D THE 2-9/16"ADAPTOR FLANGE AND TREE. -INSPECT HANGER THREADS -3"L.H.ACME HANGER'XO'MAKE-UP IS 6 TURNS TO LEFT. 11:30 - 18:00 6.50 BOPSUR P PRE PJSM,N/U 13-5/8",5M, 4 PREVENTER BOPE. -N/U ON TOP OF 7-1/16"TBG SPOOL,(1) 7-1/16"BY 13-5/8",5M DSA. -THEN A 13-5/8",5M FLANGE BY FLANGE SPACER SPOOL. -CONNECT ACCUMULATOR LINES,CHOKE AND KILL LINES. -R/U MOUSE HOLE,RISER AND TURNBUCKELS. -PERFORM CROWN INSPECTION. -PERFORM API-53 ACCUMULATOR TEST. 18:00 - 20:00 2.00 BOPSUR P PRE R/U 2-7/8"AND 4"BOPE TEST EQUIPMENT. 20:00 - 00:00 4.00 BOPSUR P PRE PJSM,TEST FOUR PREVENTER 13-5/8"BOP AND RELATED EQUIPMENT. -TEST BOP ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES. TEST ANNULAR WITH 2-7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8" AND 4"TEST JOINT TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST WITH FRESH WATER. BOB NOBLE OF AOGCC WAIVE STATES RIGHT OF WITNESS TO BOPE TEST. CONTINUAL HOLE FILL=20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=782 BBLS 8.5 PPG SEAWATER. CUMULATIVE FLUID LOSS=782 BBLS BBLS 8.5 PPG SEAWATER. 12/29/2013 00:00 - 00:30 0.50 WHSUR P DECOMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. CONTINUE TO TEST BOPE TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. 00:30 - 01:30 1.00 WHSUR P DECOMP BLOW DOWN LINES. -R/D TEST EQUIPMENT. FLUSH OUT BOPE. 01:30 - 02:00 0.50 WHSUR P DECOMP R/U BAILS. -M/U LANDING JOINT AND UD TO SHED. Printed 1/13/2014 11:08:11AM North America-ALASKA-BP Page 4 of 7 Operation Summary Report Common Wet Name MPK-05 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2013 End Date:12/31/2013 X4-00YCT-E:(1,800,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/6/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. l UWI:500292267000 Active datum:ORIG KELLY BUSHING©46.60usft(above Mean Sea Level) Date From-To Hrs Task i Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:00 2.00 BOPSUR P DECOMP PJSM,R/U WELL SUPPORT LUBRICATOR. -P/U PORTED LUBRICATOR EXTENSION AND 4.5"IBT X 3"LH ACME. -TEST LUBRICATOR AND TOOLS TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -PULL TWC.TUBING ON A VAC. -L/D PORTED LUBRICATOR EXTENSION. -L/D LUBRICATOR AND TOOLS. 04:00 - 04:30 0.50 BOPSUR P DECOMP R/U ESP SHEAVE. -P/U LANDING JOINT. 04:30 - 05:00 0.50 PULL P DECOMP PJSM,PULL TUBING HANGER. -M/U LANDING JOINT TO TOP DRIVE. -FMC REP BOLDS. -PULL HANGER TO FLOOR. -PUW=106K,SOW=86K. 05:00 - 05:30 0.50 KILLW P DECOMP BULL HEAD 47 BBLS KWF DOWN THE TBG AT 3BPM/180 PSI. 05:30 - 06:30 1.00 PULL P DECOMP MONITOR WELL -L/D LANDING JOINT. L/D TBG HANGER AND SEND TO FMC FOR REDRESS. -BLOWN DOWN TOP DRIVE AND CHOKE. -TBG AND IA ON A VACUUM. 06.30 07:00 0.50 PULL P DECOMP PJSM,R/U TO PULL 2-7/8"ESP ASSEMBLY. -HANG ESP SHEAVE AND CABLE TRUNK IN DERRICK. 07:00 - 08:30 1.50 PULL P DECOMP PULL ESP COMPLETION F/8173'T/7865'MD -PUW/70K,SOW/66K INCLUDES 40K TOP DRIVE WT. -DROP TUBING RABBIT OD=1-7/8". SNAKE CABLE OVER SHEAVE IN DERRICK TO SPOOLING UNIT. 08:30 - 16:00 7.50 PULL P DECOMP PULL 2-7/8"6.5#,L-80 EUE,8 RD TBG COMPLETION. -F/7865'T/ESP ASSEMBLY. -MAINTAIN 20 BPH CONTINUOUS HOLE FILL WITH NO RETURNS. -REPLACE JOINT#187. -BREAK OUT AND INSPECT JOINT#176,229, 232 AND 245. -ALL TUBING LOOKS GOOD. -NO HOLES FOUND IN TUBING. -RECOVER TUBING RABBIT AT THE'XN' NIPPLE. Printed 1/13/2014 11:08:11 AM • North America-ALASKA-BP Page 5 of 7 Operation Summary Report Common Well Name:MPK-05 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2013 End Date:12/31/2013 X4-00YCT-E:(1,800,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/6/1996 12:00:00AM Rig Release: Rig Contractor DOYON DRILLING INC. UWI:500292267000 Active datum:ORIG KELLY BUSHING @46.60usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 18:30 2.50 PULL P DECOMP PJSM,PULL AND LID ESP MOTOR AND PUMPS ASSEMBLY. -DRAIN AND INSPECT DURING ASSEMBLY BREAK DOWN. IDENTIFIED TWO HOLES IN UPPER PUMP HOUSING. -THE 2"BY 2"RUBBER FISH LOST IN WELL WAS RECOVERED AT THE DISCHARGE HEAD. -UPPER SEAL ASSEMBLY HAD WASH-OUT IN THE BODY. -THE CONTROL LINE WAS PARTED ON THE WELLLIFT GUAGE SENSOR,NO LOST PARTS. RECOVERED:LASSLE CLAMPS=134,FLAT GAURDS=3,PROTECTOLIZERS=5,SS BANDS=4. 18:30 - 20:30 2.00 PULL P DECOMP R/D ESP TRUNK. -C/O ESP SPOOLS. -CLEAN AND CLEAR RIG FLOOR. STRING NEW ESP CABLE TO RIG FLOOR. 20:30 - 00:00 3.50 PULL P DECOMP CENTRILIFT REP TO PERFROM ESP SPLICE AT RIG FLOOR. CONTINUAL HOLE FILL=20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=450 BBLS 8.5 PPG SEAWATER. CUMULATIVE FLUID LOSS=1232 BBLS BBLS 8.5 PPG SEAWATER. 12/30/2013 00:00 - 00:30 0.50 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. SERVICE AND INSPECT RIG FLOOR EQUIPMENT AND TOOLS. 00:30 - 05:00 4.50 RUNCOM P RUNCMP PJSM,CONTINUE ESP SERVICE MOTOR AND PUMP ASSEMBLY. -INSTALL CONTROL LINE FROM SENSOR TO GAUGE UNIT. INSTALL POTHEAD MOTOR LEAD. 05:00 - 12:00 7.00 RUNCOM P RUNCMP RIH WITH 2 7/8"6.5#EUE 8 RD TUBING ESP COMPLETION FROM DERRICK. -TUBING TORQUE=2300 FT/LBS. -USE BEST-O-LIFE 2000 PIPE DOPE ON EVERY CONNECTION. -CHECK ESP CABLE CONDUCTIVITY EVERY 2000'. -PUMP 5 BBLS TO FLUSH THROUGH PUMP AT 1 BPM. -T/6404'MD,PUW/85K,SOW/77K (INCLUDES 40K TOPDRIVE WT.) -20 BPH HOLE FILL W/8.5#SEAWATER AND NO RETURNS. 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM,SERVICE RIG FLOOR EQUIPMENT. PERFORM PRE-TOUR CHECKS. Printed 1/13/2014 11:08:11AM North America-ALASKA-BP Page 6 of 7 Operation Summary Report Common Well Name:MPK-05 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2013 End Date:12/31/2013 X4-OOYCT-E:(1,800,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/6/1996 12:00:00AM Rig Release: �UWI:500292267000 Rig Contractor:DOYON DRILLING INC. Active datum:ORIG KELLY BUSHING(!'�46.60usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 14:00 1.50 RUNCOM P RUNCMP CONTINUE RUN ESP COMPLETION. -F/6404'MD T/8028'MD. -.ON 2-7/8"TBG F/DERRICK. -PUW/85K,SOW/77K(INCLUDES 40K TOPDRIVE WT.) -TUBING TORQUE=2300 FT/LBS. -USE BEST-O-LIFE 2000 PIPE DOPE ON EVERY CONNECTION. -CHECK ESP CABLE CONDUCTIVITY EVERY 2000'. -PUMP 5 BBLS TO FLUSH THROUGH PUMP AT 1 BPM. 14:00 - 15:00 1.00 RUNCOM P RUNCMP P/U LANDING JOINT W/FOSV -M/U 10 FT PUP. -SCREW INTO HANGER W/3"L.H.ACME. -FMC REP INSTALL PENETRATOR. -PUW/99K,SOW/86K(INCLUDES 40K TOPDRIVE WT.) 15:00 - 16:30 1.50 RUNCOM P RUNCMP CENTRILIFT REP TERMINATE ESP CABLE WITH LOWER CONNECTOR. -CHECK CONDUCTIVITY AT HANGER PRIOR TO LANDING. -FMC REP INSTALL TWC. -R/D ESP SHEAVE. 16:30 - 17:00 0.50 RUNCOM P RUNCMP LAND HANGER W/TWC INSTALLED. -FMC RILDS. -UD LANDING JOINT. 17:00 - 17:30 0.50 RUNCOM P RUNCMP ATTEMPT TO TEST BELOW TWC AT 6.5 BPM. -100 BBLS PUMPED WITH NO PRESSURE. 17:30 19:00 1.50 RUNCOM P RUNCMP TEST TWC FROM ABOVE. -TEST TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. 19:00 - 19:30 0.50 RUNCOM P RUNCMP B/D CHOKE,KILL AND SURFACE LINES. -CONTINUE TO FILL IAAT 20 BPH. 19:30 - 22:00 2.50 BOPSUR P RUNCMP N/D BOPE,MOUSE HOLE,RISER, TURNBUCKELS,KILL LINE AND DSA. i 22:00 - 23:00 1.00 RUNCOM P RUNCMP CENTRILIFT PERFORM FINAL CONDUCTIVITY TEST. -BHP=2642 PSI,DISCHARGE HEAD PRESSURE=2621 PSI,BHT=108°F. -FMC CLEAN HANGER AND INSTALL SLIDE (SLEEVE. _ 23.00 - 00:00 1.00 WHSUR P RUNCMP N/U TUBING ADAPTER. CONTINUAL HOLE FILL=20 BPH WITH KWF. NO RETURNS. 24 HOUR FLUID LOSS=582 BBLS 8.5 PPG SEAWATER. CUMULATIVE FLUID LOSS=1814 BBLS BBLS 8.5 PPG SEAWATER. 12/31/2013 00:00 - 00:30 0.50 WHSUB P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. CHECK CROWN-O-MATIC. CONTINUE TO N/U TUBING ADAPTER. 00:30 - 02:30 2.00 WHSUR P RUNCMP FMC PRESSURE TEST ADAPTER FLANGE TO 250 PSI LOW,5000 PSI HIGH FOR 5 CHARTED MINUTES EACH. 02:30 - 06:00 3.50 WHSUR P RUNCMP PJSM,N/U TREE. -ALIGN TREE USING PREVIOUS MARKING. -TEST TREE TO 250 PSI LOW,.5000 PSI HIGH FOR 5 CHARTED MINUTES. Printed 1/13/2014 11:08.11AM • North America-ALASKA-BP Page 7 of 7 Operation Summary Report Common Well Name:MPK-05 AFE No Event Type:WORKOVER(WO) Start Date:12/26/2013 End Date:12/31/2013 X4-00YCT-E:(1,800,000.00) Project:Milne Point Site:M Pt K Pad Rig Name/No.:DOYON 16 Spud Date/Time:4/6/1996 12:00:00AM Rig Release: Rig Contractor:DOYON DRILLING INC. UWI:500292267000 Active datum:ORIG KELLY BUSHING @46.60usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 07:00 1.00 WHSUR P RUNCMP PJSM,M/U WELL SUPPORT LUBRICATOR TEST,250/3500 PSI,5 MIN,CHART 07:00 - 07:30 0.50 WHSUR P RUNCMP PULL TWC,C/O RUNNING TOOL -M/U LUBRICATOR 07:30 - 08:30 1.00 WHSUR P RUNCMP TEST LUBRICATOR,250/3500 PSI,5 MIN, CHART -INSTALL BPV 08:30 - 12:00 3.50 WHSUR P RUNCMP PJSM WITH LITTLE RED SERV -R/U AND PT LINES,250/3500 PSI,5 MIN -LRS PUMP DEAD CRUDE FREEZE PROTECT TO 2500'TVD -15 BBLS CRUDE DOWN TUBING,75 BBLS 'DOWN IA RIG RELEASED 12/31/2013 AT 12:00 FROM MPK-05 I LOSSES FOR 12 HOUR TOUR=110 BBLS Printed 1/13/2014 11:08:11AM Tree: Cameron 2 9/16"5' MPK-05 KB Elev.=61.00 Wellhead: 11" x 7 1/16". MC GL Elev.=27.60 Gen 5A,w/2 7/8"FMC tbg.hng., 3"LH acme on top and 2 7/8"EUE 8 rd on bottom,2.5"CIW BPV profile • 140' RKB Camco 2-7/8"x 1" 142' KOP @ 1500' KBMM-2 GLM Max,hole angle:38°to 42° 414. f/2800'to 7750' Hole angle across perforations=40° DLS.4.5°/100'@ 2300' 9 5/8",40 ppf,L-80 Btrc. 3823' 2-7/8"6.5#,EUE 8rd,L-80 tubing (drift ID=2.441",Cap.=.00579 7"26 ppf,L-80,Btrc.production casing (drift ID=6.151",cap.=0.0383 bpf) 7 Howco'ES'Cementer 5577' Camco 2-7/8"x 1" 7785' KBMM-2 GLM 20'x 7",26 ppf short joint. 7960' 2-7/8"XN nipple 7936' (ID 2.25") WeIILift Discharge Gauge Unit 7979' Mid-peri TVD=6986' Mid-pert MD=8366' II I Tandem Pump PBTD TVD=7124' 137P17 ARMX 7984' PBTD=8536' I 18P75 ARMX GasMaster Coated INT 8010' Tandem Seal Section mit- 1 GSB3DBUT/LT SB/SB PFSA 8015' MIMS Stimulation Summary MSP-1 Motor/210hp/2380v 8029' 53Amp not applicable NM 1 INS PumpMate w/6 fin Centralizer 8050' Perforation Summary Ref log:Atlas GR/CCL 8/10/96 8,372' SIZE SPF INTERVAL (TVD) — g g Halliburton 7"23-32#Perma-Series Packer J(u_paruk C sands 4 1/2"12.6#Halliburton X Nipple 8,381' 4.5 5 8302'-8358' 6937'-6981' ID 3.813" Kuparuk B sands 4 1/2"12.6#Halliburton XN Nipple -- ID 3.813" 8,398' 4.5 5 8390'-8430' 7006'-7036' WLEG 8,404' Slickline tag @ 8,494' 11/17/98 PBTD(7"landing collar) 8536' A \7" csg.shoe 8620' DATE REV.BY COMMENTS MILNE POINT UNIT 04/20/96 JBF rilled and ased b Nabors 27E 08/12/96 M.LinderCompletion abors -ES WELL MPK-05 11/18/98 MDO ESP RWO/Calvins trap Nabors 4-es 1/22/02 B.Hasebe ESP RWO/Isolation Packer Nabors 4ES API NO: 50-029-22670 12/1/04 Lee Hulme ESP RWO/Open Isolation Pkr Nabors 4ES 1/10/09 REH ESP RWO Nabors 3S 12/31/13 MSS ESP RWO 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 LANNE FEB J 7 1012 06 Mr. Tom Maunder (4 6 5 Alaska Oil and Gas Conservation Commission I 0 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -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 • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPK 10/29/2011 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 MPK -02 1960810 50029226750000 02 NA 0.2 NA 5.1 9/5/2011 -)• MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27 /2011 MPK -09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24 /2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27 /2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10 /29 /2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27 /2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK-30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK -33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24 /2011 MPK -34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25 /2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK -38 1960300 50029226490000 32 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 _ 1.7 NA 1.7 NA 13.6 9/16/2011 STATE OF ALASKA " ALASKAOAND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 15 Exploratory p . 196 -0680 3. Address: P.O. Box 196612 Stratigraphic Service p 6. API Number: Anchorage, AK 99519 - 6612 .. 50- 029 - 22670 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028232. . MPK -05 10. Field /Pool(s): MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 8640 feet Plugs (measured) None feet true vertical 7194.61 feet Junk (measured) None feet Effective Depth measured 8536 feet Packer (measured) 8372 feet true vertical 7116.79 feet (true vertical) 7443 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 33 - 110 33 - 110 Surface 3791' 9- 5/8 "40# L -80 32 - 3823 32 - 3497 5750 3090 Production 8589' 7" 26# L -80 31 - 8620 31 - 7180 7240 5410 Production Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ AJ 8 1 F C n `j, 7 D '; -:- True Vertical depth: _ _ - Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 30 - 8173 30 - 6834 4 -1/2" 12.6# L -80 8372 - 8404 6992 - 7017 Packers and SSSV (type, measured and true vertical depth) 7" 23 -32# Perma Series Packer 8372 7443 RECEIVED 12. Stimulation or cement squeeze summary: SEP 0 2011 Intervals treated (measured): Nosh Gil & Gas Cons. Commission Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 65 19 1273 187 Subsequent to operation: 65 14 1170 184 14. Attachments: 15. Well Class after work: 1 Copies of Logs and Surveys Run Exploratory Development Ell . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ., El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Name Joe Lastuko„ Title Petrotechnical Data Technologist Signatu VIIIIIV ( Phone 564 -4091 Date 9/9/2011 NE RBDMS SEP 12 2O11c 7.1-1./t Form 10 -404 Revised 10/2010 94 ii Original Only !''�( i/ MPK -05 196 -068 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPK -05 8/10/96 PER 8,302. 8,358. 6,937.31 6,981.09 MPK -05 8/10/96 PER 8,390. 8,430. 7,005.84 7,036.54 MPK -05 1/21/02 BPS 8,375. 8,379. 6,994.26 6,997.35 MPK -05 11/30/04 BPP 8,390. 8,430. 7,005.84 7,036.54 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • • MPK -05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY { ay { '`t?3�:� �„�:�.F.., 's- "4^�;? fv�',: �:�,'�F,�:p:+'a" `� "'�,?;:�� ;+;, ..'La✓ x:.: ,.�Nrti,a^ o-*- !'IIM;YS'T,^ � �!i 11Aw' f'�v: nA�.�s ,�,./t'r✓.' " �$.'L�.� ?`T .��:" ��,'7?�'S {,W .`. ..:j Y>�t''� 'r�%.. P. .:. '„ aM _ vv ... nn....ia:' , i ti v g:: x:.. ..,.: > . 1 8/19/2011 T /I /0= 200/280/0 Acid Job Pumped 10 bbls crude down tubing to verify injectivity. :Pumped 20 bbls 10% DAD acid, 3 bbls 60/40 meth, 30 bbls crude down tubing. Notify Pad Op. to let acid soak for 60 min's prior to begining flow back. FWHP= 60/280/0 SV,WV,SSV Shut. MV,IA,OA Open s 3 3 3 FLUIDS PUMPED BBLS 40 CRUDE / 20 10% DAD ACID ✓ 3 60/40 METH 63 TOTAL ' Tree: Cameron 2 9116" 5M M P K - 0 5 Wellhead: 11" x 7 1/16" 5M FMC lev. =61.00 GL Elev. =27.60 Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8 rd on bottom, 2.5" CIW BPV profile ` ,, 1 1 40' RKB A* 4:7, s j Camco 2 -7/8" x 1" 141' KOP @ 1500' 6 KBMM -2 GLM Max, hole angle: 38° to 42° f/ 2800' to 7750' Hole angle across perforations = 40° DLS . 4.5° / 100' @ 2300' 9 5/8 ", 40 ppf, L -80 Btrc. I 3823 ' 1 2 -7/8" 6.5 #, EUE 8rd, L -80 tubing (drift ID = 2.441", Cap. = .00579 7" 26 ppf, L -80, Btrc. production casing 1 (drift ID = 6.151", cap. = 0.0383 bpf) � '� 7" Howco 'ES' Cementer 5577' Camco 2 -7/8" x 1" 7911' ,1r KBMM -2 GLM 20' x 7 ", 26 ppf short joint. I 7960' I '', f 2 -7/8" XN nipple t 1 (ID 2.25 ") 8054' ,4 WeIlLift Discharge Gauge Unit 8095' Mid -perf TVD = 6986' Mid -pert MD = 8366' f p i Tandem Pump PBTD TVD = 7124' 18 -P75 SXD 8101' 't PBTD = 8536' 119 -P23 SXD sr GasMaster Coated INT 8125' ;' Tandem Seal Section GSB3DBUT /LT SB /SB PFSA 8130' Stimulation Summary KME -1 Motor /225hp/2145v 8144' not applicable 69Amp II PumpMate w/6 fin Centralizer 8169' r Perforation Summary _ Ref log: Atlas GR/ CCL 8/10/96 SIZE SPF INTERVAL (TVD) — I 8,372' g g Halliburton 7" 23 -32# Perma- Series Packer Kupar C sands 4 1/2" 12.6# Halliburton X Nipple I g 381 4.5 5 8302' -8358' 6937' -6981' ID 3.813" Kt nantk R sands 4 1/2" 12.6# Halliburton XN Nipple — O ID 3.813" 8,398` 4.5 5 8390' -8430' 7006-7036' — WLEG 8,404' Slickline tag @ 8,494' 11/ 17/98 PBTD (7" landing collar) 8536' 7" csg. shoe 8620' DATE REV. BY COMMENTS MILNE POINT UNIT 04 / 20 / 96 JBF Drilled and Cased by N ors 27E 08/12/96 M. Linder Completion Nabors 4- WELL MPK -05 11/18/98 MDO ESP RWO / Calvins trap Nabors 4 -es 1/22/02 B. Hasebe ESP RWO / Isolation Packer Nabors 4ES API NO: 50- 029 -22670 12/1/04 Lee Hulme ESP RWO / Open Isolation Pkr Nabors 4E. 1/10/09 REH ESP RWO Nabors 3S BP EXPLORATION (AK) STATE OF ALASKA A~ OIL AND GAS CONSERVATION CO SION ~'E'-~ REPORT OF SUNDRY WELL OPE~TIONS ~~' ~E& 1. Operations Performed: ^ Abandon ®Repair Well ~ ~ ~5~5 ~ '`~~~ rir,~Su~pended Well ^ Plug Perforations ^ Stimulate . ^ Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver , b ®Otit~/'~ , + ~/~''~iQ~ ^ Change Approved Program ^ Operation Shutdown Change Out ESP ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 196-068 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22670-00-00 - 7. KB Elevation (ft): 61 90' - 9. Well Name and Number: . MPK-05- 8. Property Designation: 10. Field /Pool(s): ADL 028232 , Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8640 feet true vertical 7195 ' feet Plugs (measured) N/A Effective depth: measured 8536 feet Junk (measured) N/A true vertical 7117 feet Casing Length Size MD ,,TVD _ Burst Collapse Structural Conductor 72' 20" 110' 110' Surface 3787' 9-5/8" 3823' 3497' 5750 3090 Intermediate Production 8587' 7" 8620' 7180' 7240 5410 Liner ~~aa Perforation Depth MD (ft): 8302' - 8430' Perforation Depth TVD (ft): 6937' - 7037' 2-7/8", 6.5# L-80 8173' Tubing Size (size, grade, and measured depth): a-1/2", 12.6# L-80 8372' -8404' Packers and SSSV (type and measured depth): 7" 23-32 Perma-Series Packer 8372' 12. Stimulation or cement squeeze summary: 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: 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 ^ G1NJ ^ 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 Howard West, 564-5471 N/q Printed me Sondra Stewman Title Drilling Technologist Prepared By Nama/Number Si ture ' Phone 564-4750 Dat ~ '~ - Sondra Stewman 564-4750 Form t0-404 Revised 04/2006 ~ ~ d Submit Original Only ," Tree: Cameron 2 9/16" 5 Wellhead: ti" x 7 1/16" C Gen 5A, w/ 2 7/8" FMC tbg. hng., 3" LH acme on top and 2 7/8" EUE 8 rd'on bottom, 2.5" CIW BPV profile 140' RKB KOP @ 1500' Max, hole angle: 38° to 42° f/ 2800' to 7750' Hole angle across perforations = 40° DLS . 4.5° 1100' @ 2300' 9 5/8", 40 ppf, L-80 Btrc. 3823' 2-7/8" 6.5#, EUE 8rd, L-80 tubing (drift ID = 2.441", Cap. _ .00579 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151 ", cap. = 0.0383 bpf ) 20' x 7", 26 ppf short joint. Mid-pert TVD = 6986' Mid-pert MD = 8366' PBTD TVD = 7124' PBTD = 8536' Stimulation Summary not applicable PumpMate w/6 fin Centralizer 8169` Perforation Summary Ref log: Atlas GR/ CCL 8/10/96 MPK-05 7960' SIZE SPF INTERVAL (TVD) 4.5 5 8302'-8358' 6937'-6981' 4.5 5 8390'-8430' 7006'-7036' • KB Elev.=61.00 GL Elev.=27.60 Camco 2-7/8" x 1" 141' KBMM-2 GLM 7" Howco'ES' Cementer 5577' Camco 2-7/8" x 1" 7911' KBMM-2 GLM 2-7/8" XN nipple 8054` (ID 2.25") WeIILift Discharge Gauge Unit 8095` Tandem Pump 18-P75 SXD 8101 ` 119-P23 SXD GasMaster Coated INT 8125' Tandem Seal Section ` GSB3DBUT/LT SB/SB PFSA 8130 KME-1 Motor/225hp/2145v 8144' 69Amp 8,372` Halliburton 7" 23-32# Perma-Series Packer 4 1/2" 12.6# Halliburton X Nipple $ 381 ID 3.813" 4 1/2" 12.6# Halliburton XN Nipple " 8 398` ID 3.813 WLEG 8,404` Slickline tag @ 8,494' 11/ 17/98 PBTD (7" landing collar) 8536' 7" csg. shoe 8620' DATE REV. BY COMMENTS 04 / 20 / 96 0 12/ JBF M. Lin r Drilled and Cased by N ors 27E Com letion Nabors 4-~~ 11/18/98 1/22/02 MDO B. Hasebe ESP RWO / Calvins trap Nabors 4-es ESP RWO /Isolation Packer Nabors 4ES 12/1/04 Lee Hulme ESP RWO /Open Isolation Pkr Nabors 4 1/10/09 REH ESP RWO Nabors 3S MILNE POINT UNIT WELL MPK-05 API NO: 50-029-22670 BP EXPLORATION • • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPK-05 Common Well Name: MPK-05 Spud Date: 4/6/1996 Event Name: WORKOVER Start: 12/31/2008 End: 1/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/12/2009 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task Code NPT Phase '', Description of Operations 1/6/2009 00:00 - 03:30 3.50 RIGD P PRE Rlg released from MPF-81 ~ 00:00. Scope down and lower derrick. Disconnect pit and pipe shed modules. Prepare for rig move. 03:30 - 04:00 0.50 RIGD P PRE Hold PJSM with Peak drivers and rig crew. Discussed cold weather, good communication, staying in clear line of site of drivers, and loader operator. 04:00 - 06:00 2.00 RIGD P PRE BP WSL and Pad Operator observe pulling off of well. Line up rig components on edge of pad and notify MPU security of rig move. 06:00 - 10:00 4.00 MOB P PRE Move off MPF-Pad 07:00 hrs and arrive on MPK-Pad with Rig and Camp components at 10:00 hrs. 10:00 - 14:00 4.00 RIGU P PRE Spot Camp components. Spot Carrier over Well, observed by BP /WSL and NAD Toolpusher. At 13:45 hours, notifed AOGCC of upcoming ROPE test. Lou Grimaldi with AOGCC requested we call him 1/7/2009 in the morning. 14;00 - 19:00 5.00 RIGU P PRE Spot Pipe Shed, Pits and Rig components. Temp -35 Deg F. Scope up Derrick. 19:00 - 21:00 2.00 RIGU P PRE RU units, steam, stairs and handrails. Spot up-right tank per Pad operator instructions, to allow access to flow line buildings. Temp -35 Deg F. Accepted Riq at 21:00 hours on 1/6/2009. 21:00 - 00:00 3.00 KILL P DECOMP R/U kill manifold and hook up hard line to Tiger Tank and Choke. Install second annulus valve. 1/7/2009 00:00 - 01:00 1.00 WHSUR P DECOMP PU / MU lubricator and test with diesel to 500 psi. Well support tech ull BPV. WHP's, TBG = 1,350 psi, IA = 1,525 psi, OA = 0. 01:00 - 03:00 2.00 WHSUR P DECOMP Test surface lines to 3,000 psi. Test downstream of choke to Tiger tank to 500 psi. 03:00 - 03:30 0.50 KILL P DECOMP Well Kill meeting with crew, LRS and Vac truck drivers. 03:30 - 07:00 3.50 KILL P DECOMP Bleed IA down from 1,360 psi to 60 psi tubing at 1,020 psi. Pump 46 bbls 130 Deg 8.45 ppg seawater down tubing at 3 BPM with no fluid returns. Bull-head 20 bbls seawater down the tubing into the formation at 3 BPM / 90 psi. Pump 52 bbls seawater down the tubing through the choke to Tiger tank at 4 BPM / 80 psi with no returns. Stop and line up to bullhead down the IA due to no returns on surface. Bullhead a total of 365 bbls of heated seawater down the IA at 4 bpm with 70 psi of pump pressure (friction) and 20 psi on the Tubing. Swap to pump down the Tubing and bullhead a tubing volume of 48 bbls at a rate of 4 bpm with 80 psi of pump pressure (friction) and 30 psi on the IA. 07:00 - 07:30 0.50 KILL P DECOMP Shut the well in and monitor for 30 mins. Both the Tubing and IA are on a vacuum. 07:30 - 08:00 0.50 KILL P DECOMP Blow down lines and RD Kill Manifold. Check the well again and the Tubing is still on a vacuum but the IA is not. Put a gauge on it and it is showing 30 psi. 08:00 - 09:00 1.00 KILL P DECOMP Rig back up to the IA and bullhead 50 bbls of seawater at 4 bpm with 80 psi pump pressure. Discuss plan forward with Anchorage Engineering. Plan on re-killing the well if the IA is not on a vac after another 30 minute monitor. 09:00 - 09:30 0.50 KILL P DECOMP Monitor the well for 30 minutes. The IA is still showing 30 psi of pressure and the Tubing is still on a vacuum. 09:30 - 13:30 4.00 KILL P DECOMP Call CH2M Hill for another vac truck and they don't have any available. Wait on the vac truck that is round tripping for more Printed: 1/26/2009 11:05:00 AM • BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: MPK-05 Common Well Name: MPK-05 Spud Date: 4/6/1996 Event Name: WORKOVER Start: 12/31/2008 End: 1/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/12/2009 Rig Name: NABOBS 3S Rig Number: Date .From - To Hours Task Code NPT Phase Description of Operations 1/7/2009 09:30 - 13:30 4.00 KILL P DECOMP seawater to arrive back on location. 13:30 - 14:00 0.50 KILL P DECOMP Hold pre-kill safety meeting with crew and CH2M Hill vac truck driver. 14:00 - 15:00 1.00 KILL P DECOMP Fill the upright with seawater. RU Little Red to the IA. Line up the Kill Manifold to pump down the Tubing with the Rig Pump. 15:00 - 16:30 1.50 KILL P DECOMP Bullhead down the Tubing and IA simultaneously with the Rig Pump at 1 bpm / 20 psi (friction) down the Tubing and Little Red at 4 bpm / 0 psi down the IA. The Tubing on such a strong vac that it is actually taking it at 2-3 bpm. Pumped a total of 300 bbls down the IA and 160 bbls down the Tubing for a total of 460 bbls into the well. 16:30 - 18:00 1.50 KILL P DECOMP Monitor the well for 30 minutes. Hold discussion with the crew and BP Workover Operations Superintendent on 2008 results and 2009 plan. The Tubing is on a vacuum and the IA showing 90 psi. Bleed the pressure off the IA to 0 psi and monitor for an additional 30 minutes. The Tubing is on a vacuum and the 18:00 - 19:30 1.50 WHSUR P DECOMP PU T-bar and set 2-1/2" T e "H" TWC with FMC re .Test from above to 3,500 psi for 10 charted minutes. Witnessed by BP /WSL. FMC tech bleed adapter flange void to 0 psi. 19:30 - 21:00 1.50 WHSUR P DECOMP Blow down and R/D Kill manifold and lines, ND tree, FMC tech inspect hanger. 21:00 - 00:00 3.00 BOPSU P DECOMP PU BOPE from shipping cradle and NU 7-1/16" X 13-5/8" DSA. LRS maintain -20 bph fill rate into the IA. 1/8/2009 00:00 - 03:00 3.00 BOPSU P DECOMP N/U 13-5/8" BOPE with 2-7/8"x5" VBR. Connect Koomey lines, choke line, kill line. 03:00 - 04:00 1.00 BOPSU P DECOMP Function test BOPE. 04:00 - 09:30 5.50 BOPSU P DECOMP Test ROPE 250 psi low / 3,500 psi high. Test with 2-7/8" test joint against TWC. Test witnessed by BP WSL, NAD Toolpusher. Use LRS to gravity feed backside durino test at 20 BPH. Witness of test waived by Lou Grimaldi with AOGCC. 09:30 - 10:30 1.00 BOPSU P DECOMP Blow down and rig down all lines and test equipment. Drain the BOP Stack. 10:30 - 12:30 2.00 WHSUR P DECOMP Find ice plug in Choke line and work on thawing it out. Thaw out ice plug in line from Choke Manifold to the Pits. Continue feeding Well at 20 bbls per hour with Little Red down the IA. 12:30 - 14:30 2.00 WHSUR P DECOMP PU Opso Lopso and Pump In Sub with Well Support Techs. PUMU Lubricator and Polished Rod to Opso Lopso. Fill with diesel and pressure test to 500 psi - OK. Pull 2-1/2" Type "H" TWC. The Tubing is on a vacuum. LD Lubricator and Opso Lopso. 14:30 - 17:00 2.50 WHSUR P DECOMP Slip and cut drilling line. 17:00 - 18:00 1.00 PULL P DECOMP PUMU 3-1/2" IF Landing Joint with TIW Valve, Circulating Hose and 3" L.H. Acme XO. Screw into the Hanger with 8 turns. BOLDS with FMC rep. 18:00 - 18:30 0.50 PULL P DECOMP PJSM, crew change and perform pre-tour checks. 18:30 - 19:00 0.50 PULL P DECOMP Pull hanger off seat at 75 K, tubing and IA on a Vacuum., pump 60 bbls heated seawater down the tubing 4 bpm / 40 psi, observe well for 15 minutes. 19:00 - 20:00 1.00 PULL P DECOMP BO / LD tubing hanger and landing joint, blow down lines. 20:00 - 21:00 1.00 PULL P DECOMP R/U floor to pull 2-7/8" ESP completion. 21:00 - 00:00 3.00 PULL P DECOMP POH stand in Derrick with 2-7/8" ESP com letion PUW= 70 K, 50 stands out at 00:00 hours. Feed Well with charge pump at Printed: 1/26/2009 11:05:00 AM • s BP EXPLORATION Page 3 of 4 '~i Operations Summary Report Legal Well Name: MPK-05 Common Well Name: MPK-05 Spud Date: 4/6/1996 Event Name: WORKOVER Start: 12/31/2008 End: 1/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/12/2009 Rig Name: NABOBS 3S Rig Number: Date From - To !Hours Task Code NPT Phase Description of Operations i 1/8/2009 21:00 - 00:00 3.00 PULL P DECOMP -20 bph. 20 mph wind, -55 WC. 1/9/2009 00:00 - 07:30 7.50 PULL P DECOMP Continue POH from 50 stands (5,000'MD) with 2-7/8" ESP conpletion, Feed Well with charge pump at -20 bph. Stop at 2,005' MD and pump 26 bbls down tubing, pull 4 more stands to 1,740' MD and pump 10 bbls down tubing, tubing on a vacuum. Continue feed Well with charge pump at -20 bph seawater. 116 stands out at 06:00 hours. Break out and lay down 2.205" ID XN Nipple to be replaced by new 2.250" (D one. 07:30 - 10:30 3.00 PULL P DECOMP On surface with ESP Assembly. Drain, break out and lay down ESP Components with Centrilift rep. 10:30 - 11:30 1.00 PULL P DECOMP Clear and clean the Rig Floor of all unnecessary equipment. RD Elephant Trunk. 11:30 - 12:00 0.50 PULL P DECOMP Service the Rig. Slickline PE arrives on location to service the GLMs. 12:00 - 17:00 5.00 BUNCO RUNCMP PU / MU and service ESP pump and motor assembly with ..1/10/2009 17:00 - 18:30 18:30 - 00:00 00:00 - 02:00 02:00 - 10:00 1.50 5.50 2.00 8.00 BUNCO BUNCO BUNCO BUNCO SFAL SFAL SFAL RUNCMP RUNCMP RUNCMP RUNCMP MPU mechanic work on Gen-set to ESP cable Spooler unit. Found damaged armor on ESP cable. Back cable over sheave. Centrilift rep makes new motor lead splice, and cable splice. Continue to feed Well with charge pump at -20 bph. Run ESP cable over sheave in Derrick and make up motor lead on ESP. Feed Well with charge pump at - 20 bph. RIH with ESP completion assembly on 2-7/8", 6.5#, L-80, EUE 8rd tubin from Derrick. Check conductivity of cable, fill and flush pump with seawater every -2,000' MD. 1.50 bpm / 1,080 psi. Tbg and IA on a vacuum. 50 stands run at 05:30 hours. 10:00 - 14:30 4.50 BUNCO RUNCMP Stop with 118 stands in the hole. Perform reel to reel splice with Centrilift rep. 14:30 - 15:30 1.00 BUNCO RUNCMP Resume RIH with ESP Assembly on 2-7/8" Tubing from the Derrick. Ran a total of 254 Joints of Tubing, 2 ea GLMs, 1 XN Nipple, 134 LaSalle Clamps, 5 Protectolizers and 3 Flat Guards. 3 SS bands on ESP assembly and (1) on 10 ft pup below the hanger pup. 15:30 - 16:30 1.00 BUNCO RUNCMP Stab Headpin and perform final flush of ESP down the Tubing at a rate of 1.6 bpm / 1,080 psi. RD 2-7/8" Handling Equipment. RU 3-1/2" Handling Equipment. Clear and clean Rig Floor. 16:30 - 17:00 0.50 BUNCO RUNCMP PU 3-1/2" Landin Joint. PUMU Han er with FMC re and orient. Establish final PUW = 74K ,SOW = 52K. Install Penetrator with FMC rep and Centrilift rep. 17:00 - 19:00 2.00 BUNCO RUNCMP Perform surface Penetrator splice with Centrilift rep. 19:00 - 19:30 0.50 BUNCO RUNCMP Land tubing hanger (8,173' MD), FMC Wellhead tech RILDS. 19:30 - 20:30 1.00 BUNCO RUNCMP D rod TWC 2-1/2" t e "H" with FMC Wellhea t . T t TWC from above to 3,500 psi for 10 charted minutes. 20:30 - 22:30 2.00 BOPSU P RUNCMP Suck out BOP stack, N/D Choke and kill lines, flow nipple and accumulator hoses. 22:30 - 23:30 1.00 BOPSU P RUNCMP Make up new adaptor flange to tree in cellar. Ambient Temp was -43 Deg F at 23:00 hours. 23:30 - 00:00 0.50 BOPSU N WAIT RUNCMP Abort making critical lift during N / D BOP stack to lay over in shipping cradle due to ambient Temp below -40 Deg F. Bridge crane rails extend outside the substructure. Printed: 1/26/2009 11:05:00 AM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPK-05 Common Well. Name: MPK-05 Spud Date: 4/6/1996 Event Name: WORKOVER Start: 12/31/2008 End: 1/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/12/2009 Rig Name: NABOBS 3S Rig Number: ti ti D f O F ' ~ N ons escrip on o pera rom - To Hours Task Code PT ~ Phase Date 1/11/2009 00:00 - 02:30 2.50 BOPSU N WAIT RUNCMP Wait on weather to making critical lift. Ambient Temp -42 Deg F. Clean Rig. 02:30 - 03:30 1.00 BOPSU P RUNCMP ND BOP stack and lay over into shipping cradle. Ambient Temp -36 Deg F. 03:30 - 05:30 2.00 WHSUR P RUNCMP Remove 7-1/16" X 13-5/8" DSA, NU 2-9/16" production tree. 05:30 - 06:00 0.50 WHSUR P RUNCMP Test adapter void to 5,000 psi for 30 minutes. Test tree to 5,000 psi for 5 charted minutes. Witnessed by BP / WSL. Cenrilift Rep checked continuity of ESP. Good test. Phase to phase = 2.8 Ohms ,phase to ground = 800 Mega Ohms , Pressure at intake = 1,625 psi ,pressure at discharge = 1607.9 psi ,Temp at intake = 148 degF ,Temp at motor = 149 degF. 06:00 - 06:30 0.50 WHSUR P RUNCMP Pre-tour checks and service the Rig. 06:30 - 09:00 2.50 WHSUR P RUNCMP PU Lubricator with Well Support Techs. Pressure test to 500 psi with diesel -good. Pull 2-1/2" Type "H" TWC. Set 2-1/2" Type "H" BPV. LD Lubricator. Secure the Tree and Cellar. 09:00 - 00:00 15.00 RIGD N WAIT RUNCMP Wait on weather to commence rigging down. Ambient temperature at -40 degF. At 1500 hrs, the ambient temperature is at -45 degF. Too cold for the hydraulic system utilized in lowering the Derrick. Suspend rig down operations to maintain steam and heat throughout the Rig. Perform cleaning and housekeeping around the Rig. Work on procedures. AT 21:00 hrs Well support techs shot fluid level at -2,400 ft, IA pressure = 100 psi. 1/12/2009 00:00 - 06:00 6.00 RIGD WAIT RUNCMP Wait on weather to commence rigging down. Ambient temperature at -40 degF. At 0000 hrs, the ambient temperature is at -40 degF. Too cold for the hydraulic system utilized in lowering the Derrick. Suspend rig down operations to maintain steam and heat throughout the Rig. Perform cleaning and housekeeping around the Rig. Work on procedures. Held Rig Evacuaton drill. IA = 175 psi at 05:00 hrs. Ambient temperature, -28 degF at 05:30 hrs. R. i~_ released at 0600 hrs 1/12/2009. Printed: 1/26/2009 11:05:00 AM - STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: :irk. re~~~::.~~cl~.~.~i,~u do~:.an cc. r;.~tii?on.5a ~'~Gi~rska.guv I~oi~.fec,ke:~steirr~ala;~€t.~.t~ov Contractor: Nabors Rig No.: 3S DATE: 1/8/2009 Rig Rep.: G.Sweatt/J. Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. Hoffman/D.Rhodes Field/Unit & Well No.: MP K-05 PTD # 1960680 Operation: Drlg: Test: Initial: x Test Pressure: Rams: 250/3500 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 5/85000 Pipe Rams 1 2 7/8 X 5 Workover: x Weekly: Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/3500 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 0 NA P Lower Kelly 0 NA P Ball Type 1 P Inside BOP 1 P Test Result P P Lower Pipe Rams 0 NA Blind Rams 1 Blind/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 CHOKE MANIFOLD: Quantity Test F No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3050 P Pressure After Closure 1700 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 38sec P Trip Tank P P Full Pressure Attained 3 min 26 sec P ~ Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): ZOOOpsi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 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: "irr:.~ eg~ ~%~iesX;~.4 uv Remarks: Tested against 2 waV check, tested w/2 7/8" test Int. 24 HOUR NOTICE GIVEN YES X NO Date 01/06/09 Time 1340 hrs est start 0400 hrs Finish Waived By Lou Grimaldi Witness D. Rhodes/ J. Fritts ~~ ~ ~ ~,~ BOP Test (for rigs) BFL 11/14/07 Nabors 3s BOP Test MP K-05 1-8-2009.x1s ) STATE OF ALASKA ) ALAS. . OIL AND GAS CONSERVATION COMM. JION REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 61.9 KB 8. Property Designation: ADL-028232 11. Present Well Condition Summary: Total Depth measured 8640 true vertical 7194.61 Effective Depth measured 8536 true vertical 7116.79 Casing Conductor Surface Production Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ~¡ Stratigraphic 0 REC,EI\/FO DEC 2 2 2005 Stimulate 0 Other 0 Waiver 0 TA-Iª~~c&.~s Cons. l,ûmrms::m:m Re-enter Suspended wellIDjchorage 5. Permit to Drill Number: Exploratory D 196-0680 Service 0 6. API Number: 50-029-22670-00-00 9. Well Name and Number: MPK-05 10. Field/Pool(s): MILNE POINT Field/ KUPARUK RIVER OIL Pool feet feet Plugs (measured) Junk (measured) None None feet feet Length Size MD TVD Burst Collapse 78 20" 91.1 # NT80LHE 38 - 11 6 38...:-.11q 1490 470 3787 9-5/8" 40# L-80 36 - 3823 36 - 3497.27 5750 3090 8587 7" 26# L-80 33 - 8620 33 - 7179.66 7240 5410 Perforation depth: Measured depth: 8302 - 8358 True Vertical depth: 6937.31 - 6981.09 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8390 - 8430 5(;Þ\NNE[v DEC 2 {) 2005 7005.84 - 7036.54 2-7/8" 6.5# Pump Equipment 4-1/2" 12.6# L-80 20 - 8095 8095 - 8166 8372 - 8404 L-80 4-1/2" HES 23-32# Perm a-Series Packer 8372 Treatment descriptions including volumes used and final pressure: RBDMS BFl DEC 2 2 2005 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 479 500 x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 201 435 0 190 531 0 15. Well Class after oroposed work: Exploratory r Development M 16. Well Status after proposed work: Oil P' Gas r WAG r GINJ 0 Tubing pressure 241 209 Service r WINJ r WDSPL [J 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Title Data Mgmt Engr ~! ¡ ~hone 564-4424 . '..., . !\L Contact Sharmaine Vestal Printed Name Sharmaine Vestal Form 10-404 Revised 04/2004 Sundry Number or N/A if C.O. Exempt: N/A Date 12/21/2005 Submit Original Only BBLS 53 Crude 11 Acid 3 MeOH 67 TOTAL FLUIDS PUMPED 'ACTIVITYDATEq:' . ....;:~~n::::~4t~·~4~MAt:ly·:.::',·:: : , . 11/28/2005IT/I/0=225/260/440 Acid Treatment. Pumped 10 bbls crude, 11 bbls 7.5 0/0 ! DAD HCL ACID, 3 bbls meoh, and 43 bbls crude down tbg. Final IWHP=175/200/0 ..."..w:,,·,·.w.w,·...·,""n..,w,w.w.·,"'·..."'...'......."',·....."''''·'''·...'.·,....""..."'...w"'....-.-.,,,,,...·."w....,....w.·,w.'.,..'.'.,·,·.w,·.·."'.w,...','.·,."w",w,w,.......,"'.............,....,·,.',,,,·,,,"",·"",,·"'''''.,...,.'.....,.""...." ,W·.',·,·' .."",','."".'.'.,,,.'.',' '.',w.·,·,',.'.·,·.'.·,·"",·,"".·,','.',·,'''''.·,·.'.',·,..,.,·,'.w,,,",,,',',,,,",,,,·,,,,",,,<,.,,,,,.,.,,,,.,,,,,·,,,·,.,·,,.w.,'.,·"'.·.·"·""",...""......·,'.w...w.".........."',,,.......''''.......,,.-. MPK-05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ) ) -.. RECEIVED ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COfv..\11ISSION DEC 2 1 2004 REPORT OF SUNDRY WELL OPERATIOAW&OU&GasCons.Commissior Anchorage 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): 61.90' 8. Property Designation: ADL 028232 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 0 Plug Perforations 0 Stimulate 181 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Change Out ESP 181 Other 0 Time Extension 8640 7195 8536 7117 72' 3787' 8587' 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 196-068 6. API Number: 50-029-22670-00-00 9. Well Name and Number: MPK-05 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" 110' 110' 9-5/8" 3823' 3497' 5750 3090 7" 8620' 7180' 7240 5410 G 2 7 2004 8302' - 8430' 6937' - 7037' 2-7/8", 6.5# Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# Packers and SSSV (type and measured depth): 7" 23-32 Perma-Series Packer at 8372' 12. Stimulation or cement squeeze summary: I ntervals treated (measured): L-80 L-80 8166' 8372' - 8408' Treatment description including volumes used and final pressure: RBDMS 8FL DEt ~ 9- 7004 13. Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure 81 11 363 1273 15. Well Class after proposed work: 0 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 Oil-Bbl Prior to well operation: 243 Subsequent to operation: 445 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Tubinq Pressure Title Technical Assistant ./~ ,- ~ .~" ~nature ~-(,j.-.- ~ Form 10-404 Revised 04/2004 - Phone l Z .-/--/. j Prepared By Name/Number: Date.. - â) l../"-~ondra Stewman, 564-4750 Submit Original Only \. I , ,.' f ! ,"".<."", '; ¡- - -- ---~'-_c._-"'~- \- :::~~e~~;ï I ¿; ~':,' ~ ~ ~ ;16~: I blVl~'FMC I ~ Gen 5A, w/2 7/8" FMC tbg. hng., 3" LHacme on top and 2 7/8" EUE ; 8 rdon bottom, 2.5" C¡W BPV ~ profile 114°' RKB I j KOP @ 1500' Max, hole angle: 38° to 42° fl 2800' to 7750' Hole angle across perforations = 40c- OLS . 4.50 1100' @ 2300' I 3823' 1 i Btrc. 2-7/8"6.5#, EUE 8rd, l-80 tubing (drift 10 = 2.441", Cap. = .00579 7" 26ppf, L-80, Btrc. production casing (drift ID=6.151", cap. = 0.0383 bpf) 20' x 7", 26 ppf short joint. 7960' Mid-perf TVD = 6986' Mid-perf MD = 8366' PBTD TVD = 7124' PBTD = 8536' Stimulation Summary not applicable Pertöration - Summary Ref log: Atlas GRI CCl 8/10/96 SIZE SPF INTERVAL Kuparuk C sands 8302'.8358' Kuparuk B sands 8390' -8430' (TVD) 4.5 5 6937'-6981 ' 4.5 5 7006'.7036' - ._---.,~.~ - ....,.",...................."""'''''''''''''"--=-''''""..,...,.,..., ""'''''''''''''''''''"'1 iV1PK-05 ) KB Eiev.=6i.üG GL Elev.=27.60 ::ES: ::8: -- A I~ Cameo 2-7/8" x 1" KBMM GLM 140' I ] 7" Howeo 'ES' Cementer ! 5571' I . I 7910' I Cameo 2-7/8" x 1" KBMM GLM 2-7/8" XN nipple (ID 2.205") I 8053' I. Tandem Pump, 74 Stg. I I GC2900 & 82 Stg. GC2900 8095' ; Model- GPMT AR 1:1 "- Tandem Gas Separator I 8128' I GRSFTX AR H6 (400 Series) Intake = 6798' TVD Tandem Seal Section I ' GSB3 DB UT/L T IL H6 PFS Aflas/HSN 8133 I 18147' I. PumpMate w/6 fin Centralizer 1 8166' I . Motor, 228 HP, 2305 volt, 60 amp, Model KMH I 8,372' I Halliburton 7" 23-32# Perma-Series Packer 41/2" 12.6# Halliburton X Nipple I 8,381' I 103.813" 4 1/2" 12.6# Halliburton XN Nipple 8,398' 103.813" WLEG 8,404' Slickline tag @ 8,494' 111 17/98 PBTO (7" landing collar) ~ 7" csg. shoe 8536' 8620' 041 20 1 96 08/12/96 11/18/98 1/22/02 1 2/1/04 BY COMMENTS JBF Drilled and Cased by Nßbors 27E M. Linder Completion Nabors 4-ES MOO ESP RWO I Calvins trap Nabors 4-es B. Hasebe ESP RWO 1 Isolation Packer Nabors 4ES MILNE POINT UNIT WELL MPK-05 API NO: 50-029-22670 Lee Hulme ESP RWO I Open Isolation Pkr Nabors 4ES BP EXPLORATION (AK) ) ) Page 10f 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPK-05 MPK-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/28/2004 Rig Release: 12/1/2004 Rig Number: 4ES Spud Date: 4/6/1996 End: 12/1/2004 Date From-To Hours Task. Còde NPT Phase 11/28/2004 06:00 - 07:30 1.50 RIGD P PRE Rig down from MPF-83i. Scope and lower Derrick. 07:30 - 10:30 3.00 RIGD P PRE Pull Sub Base off of MPF-83i. Clear and Clean Location. Load Rig Mats. 10:30 - 14:30 4,00 MOB P PRE Move Rig and support equipment from MPF-Pad to MPK-Pad. Phase 2 weather conditions. 14:30 - 16:00 1.50 RIGU P PRE Move Sub Base over MPK-05 Well. Spot and rig up Pipe shed, Pits, and Camp. Raise and scope Derrick, Accept Rig at 16:00 hrs. 16:00 - 20:00 4.00 KILL P DECOMP Spot Tiger Tank and lay Line. Hook up Lines to Production Tree. Sea Water delayed due to Phase 2 weather. 20:00 - 21 :00 1.00 KILL P DECOMP Receive first load of Sea Water. Pick-up Lubricator and pull BPV. Lay down same. Tbg = 410 Annu = 520 psi. Bleed Gas to Tiger Tank. 21 :00 - 23:00 2.00 KILL P DECOMP Second load of Sea Water arrives on location. PJSM for Well Kill with all. Test lines to 3,500 psi. 23:00 - 00:00 1.00 KILL P DECOMP Begin Killing Well with 120 deg Sea Water. 11/29/2004 00:00 - 02:00 2.00 KILL P DECOMP Finish Well Kill Operations. Monitor. Well dead. 02:00 - 03:00 1.00 WHSUR P DECOMP Set and test TWC. 03:00 - 04:30 1.50 WHSUR P DECOMP Nipple down Production Tree. 04:30 - 06:30 2.00 BOPSUR P DECOMP Nipple up BOP Stack. 06:30 - 10:00 3.50 BOPSUR P DECOMP Test BOPE per BP/AOGCC requirements at 250/3,500 psi. State's right to witness test waived...no reply from the State Inspector after the 24 hr notice or the 4 hour notice for the test. 10:00 - 11 :00 1.00 BOPSUR P DECOMP Pick-up Lubricator and pull TWC. Lay down same. 11 :00 - 12:00 1.00 PULL P DECOMP Pick-up Landing Jt. BOLDS. Pull Tubing Hanger to Floor (68K) with no problems. Lay down same. 12:00 - 13:00 1.00 PULL P DECOMP Finish rigging up to pull 2/8" Tbg and ESP completion, 13:00 - 18:30 5,50 PULL P DECOMP TOH 2 7/8" Tbg and ESP Assy. SIB 84 Stands, UD 2 jts. Recover 3 Flat Guards, 5 Protectolizers, 133 LaSalle Clamps. 18:30 - 21 :00 2.50 PULL P DECOMP Breakout, checkout, and UD ESP components. 21 :00 - 22:30 1.50 PULL P DECOMP Clear and clean rig floor. Set up to run 2-7/8" tubing. 22:30 - 00:00 1.50 PULL P DECOMP RIH wi Baker GS Spear on 2-7/8" tubing from Derrick to latch into and pull XXN plug @ 8,398' in tailpipe below HES Packer @ 8,372'. 11/30/2004 00:00 - 02:30 2.50 PULL P DECOMP Continue TIH wi Baker Spear. P/U 11 jts 2-7/8" from Pipe Shed. M/U Kelly. 02:30 - 03:30 1.00 PULL P DECOMP Break circulation and circ bottoms up to clear gas from fluid. 03:30 - 04:30 1.00 PULL P DECOMP Work Spear down onto Packer. See Packer @ 8372', work slowly into Tailpipe and stack out on XXN @ 8398'. Work into XXN plug and P/U 3 times to verify. Work back down and SID pump. P/U and see that spear is engaged. Work jars 4-times and pull free of the packer with XXN plug. 04:30 - 05:00 0.50 PULL P DECOMP P/U Kelly, park above packer, and monitor well. 05:00 - 09:30 4.50 PULL P DECOMP TOH wi XXN plug and UD 11 jts 2-7/8", SIB 84 stands. BHA to surface. 09:30 - 10:00 0.50 PULL P DECOMP Lay down recovered XX Plug and BHA. 10:00 - 14:00 4.00 RUNCOrvP RUNCMP Pick-up and service ESP Assembly. 114:00 - 20:00 6.00 RUNCOrvP RUNCMP TIH with ESP Assy and 2 7/8" Tubing.Test cable every 2000'. Pump thru ESP @ 1 1/2 BPM, 100 psi. every 2000', Used 3 Flat Guards, 8 Protectolizers, 134 LaSalle Clamps. 20:00 - 23:00 3.00 RUNCOfvP RUNCMP M/U landing jt & hanger. Install penetrator. Make field splice in cable. Test same. 23:00 - 00:00 1.00 RUNCOfvP RUNCMP Land tubing hanger. P/U 65K, S/O 50K. RILDS. UD hanger. Printed: 12/6/2004 10:55:10 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPK-05 MPK-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Spud Date: 4/6/1996 Start: 11/28/2004 End: 12/1/2004 Rig Release: 12/1/2004 Rig Number: 4ES HóursTask.Code NPT Phase. DescriptioRpf.Qperations 11/30/2004 23:00 - 00:00 12/1/2004 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 1.00 RUNCOtvP 1.50 BOPSUR P 1.50 WHSUR P 1,00 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP Test connection. Set TWC & test same. NID BOPE. N/U & test X-mas tree & hanger void to 5000 psi. Perform final test on cable. P/U lubricator & pull TWC. Install BPV. LID lubricator. Secure well. clear & clean cellar, Release rig @ 0600 hrs. 04:00 - 06:00 2.00 WHSUR P RUNCMP Printed: 12/6/2004 10:55:10 AM STATE OF ALASKA ALASKA L~L AND GAS CONSERVATION COMMI~:SlON 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 = 62.4' [] 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 3731' NSL, 2133' WEL, SEC. 3, T12N, R11E MPK-05 At top of productive interval 9. Permit Number / Approval No. 196-068 2179' NSL, 3926' WEL, SEC. 33, T13N, R11E 10. APl Number At effective depth 50-029-22670-00 2329' NSL, 3971' WEL, SEC. 33, T13N, R11E 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 2396' NSL, 3990' WEL, SEC. 33, T13N, R11 E Sands 12. Present well condition summary Total depth: measured 8640 feet Plugs (measured) true vertical 7195 feet Effective depth: measured 8536 feet Junk (measured) true vertical 7117 feet Casing Length Size Cemented M D 'FVD Structural Conductor 72' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 3787' 9-5/8" 779 sx PF 'E', 736 sx 'G', 250 sx PF 3823' 3497' Intermediate Production 8587' 7" 220 sx Class 'G' 8620' 7180' Liner Perforation depth: measured 8302'- 8358', 8390'- 8430' true vertical 6937' - 6981 ', 7006' - 7036' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd tubing to 8160', 4-1/2", 12.6#, L-80 tubing from 8372' to 8404' (Plug Installed at 8398') Packers and SSSV (type and measured depth) Haliburton 7", 23-32 Perma-Series Packer at 8372' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ^laska 0il & Gas Cmos. Commission 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 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 certi~~ct to the best of my knowledge Signed s o n di'a-~w m an__~_/~~.-~F , Prepared By Name/Numbec Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 f j'A ,~r-z~ I ~'~'' !~U''' A ~' Submit In Duplicate -- Legal Well Name: MPK-05 Common Well Name: MPK-05 Spud Date: 4/6/1996 Event Name: WORKOVER Sta~: 1/18/2002 End: 1/22/2002 Contractor Name: NABORS Rig Release: 1/22/2002 Rig Name: NABORS 4ES Rig Number: - Date ~Rom -To ~ours Activi~ C~;N:PT ~Phase ~ :Description of Operations }:;:~,:;~:~; 1/18/2002 12:00 - 23:59 11.98 MOB N WAIT PRE WAIT ON WEATHER 1/19/2002 00:00- 13:00 13.00 MOB N WAIT PRE WAIT ON W~THER 13:00 - 00:00 11.00 MOB P PRE MI/RU 1/20/2002 00:00 - 01:00 1.00 RIGU P PRE ~ISE AND SCOPE DERRICK. 01:00 - 03:00 2.00 RIGU P DECOMP RIG UP HCR VALVE AND LINES. HOLD SAFE~ AND PRE-JOB MEETING. 03:00 - 04:00 1.00 WHSUR P DECOMP MAKE UP LUBRICATOR AND PULL BPV. TBG = 300 PSI. ANNU = 550 PSI. 04:00 - 04:30 0.50 KILL P DECOMP TEST LINES TO 3,500 PSI. 04:30 - 06:00 1.50 KILL P DECOMP CIRCU~TE WELL WITH 8.5C/GAL SEA WATER. CREW CHANGE. 06:00 - 09:00 3.00 KILL P DECOMP CONTINUE TO CIRCU~TE WELL. MONITOR WELL. WELL D~D. 09:00 - 09:30 0.50 WHSURI P DECOMP INSTALL AND TEST ~C. 09:30 - 10:30 1.00 WHSUR P DECOMP REMOVE X-MASS TREE. 10:30- 13:30 3.00 BOPSUF P DECOMP INSTALL DOPE. 13:30 - 17:00 3.50 BOPSUF,P DECOMP PERFORM DOPE TEST TO BP AND AOGCC REQUIREMENT. STATE WITNESSED TEST. 17:00 - 18:00 1.00 WHSUR P DECOMP PICK UP LUBRICATOR AND PULL ~C. 18:00 - 20:00 2.00 PULL P DECOMP RIG UP FLOOR TO PULL ESP COMPLETION. BOLDS. PULL HANGER TO FLOOR. 76K. 20:00 - 00:00 4.00 PULL P DECOMP START POOH WITH 2 7/8" TBG AND ESP ASSY. 1/21/2002 00:00 - 01:30 1.50 PULL P DECOMP FINISH POOH WITH TBG AND ESP ASSY. 01:30 - 03:30 2.00 PULL 3 DECOMP LD ESP ASSY AND DE-SANDER ASSY. 03:30 - 06:00 2.50 RUNCO~ COMP PJSM. BEGIN RU SCHLUMBERGER E-LINE UNIT. CREW CHANGE. 06:00 - 07:00 1.00 RUNCO~ COMP MAKE UP TOOL STRING AND 6.00" G~JB. 07:00 - 10:00 3.00 RUNCO~ COMP RIH WITH G~JB TO A DEPTH OF 8,420-FT. POOH. LD G~JB. 10:00 - 12:00 2.00 RUNCO~ COMP MAKE UP HALLIBURTON BWD PKR AND TAILPIPE ASSY. 12:00 - 15:30 3.50~ RUNCO~P COMP RIH WITH PKR. SETAT 8,375-FT ELMD. TIE-IN LOG = AT~S G~CCL DATED 08/10/1996. 15:30 - 16:30 1.00 RUNCO~ P COMP RD SCHLUMBERGER. CL~R RIG FLOOR. 16:30 - 18:00 1.50 RUNCOEP COMP PU AND BEGIN SERVICE ESP ASSY AND PUMPMATE.. CREW CHANGE 18:00 - 20:00 2.00 RUNCO~ P COMP COMPLETE SERVICE OF ESP ASSY AND PUMPMATE. 20:00 - 00:00 4.00 RUNCO~ COMP START RIH WITH ESP ASSY AND 2 7/8" TBG. 1/22/2002 00:00 - 00:30 0.50 RUNCO~ COMP RIH WITH ESP ASSY AND 2 7/8" TBG. 00:30 - 05:30 5.00 RUNCO~ WAIT COMP ESP CABLE WAS MIS~BLED AND HAD TO GET ADDITIONAL SPOOL OF ESP CABLE TO LOCATION AND MAKE SPLICE. 05:30 - 06:30 1.00 RUNCO~ COMP 06:30 - 09:30 3.00 RUNCO~ COMP MU HANGER & SPLICE ESP CONNECTOR & ~ND HANGER & RILDS 09:30 - 11:00 1.50 BOPSUF 3 COMP 11:00-14:00 3.00 WHSUR ~ COMP ~ NIPPLE UP TREE & TEST TO 5000 PSI. PULL~C&SET BPV & SECURE TREE AR~ & CEL~R. RIG REL~SED ~ 1400 HRS. 1/22/02 ,= Printed: 1/29/2002 8:17:57AM STATE OF ALASKA .... ALASKA O,,_ AND GAS CONSERVATION COM~¥,,$SION REPORT OF SUNDRY WELL OPERATIONS ,. Operations performed: ~lOperation Shutdown ~]Stimulate l--] Plugging I~ Perforate ¢~,~¢~:;u¢.~ r.,~-.. ,..¢;r'~ .... '~'~' '::?"-:' L'.'i~iT~;.' ,~; .............. I [~ Pull Tubing I~Alter Casing []Repair Well [~ Other Change Out ESP /~.!~r~.~,.!~.,_~.¢,,~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 t5. Type of well: [] Development [] Exploratory [] Stratigraphic I~ Service 4. Location of well at surface 3731' NSL, 2133' WEL, SEC. 3, T12N, R11E At top of productive interval 2179' NSL, 3926' WEL, SEC. 33, T13N, R11E At effective depth 2329' NSL, 3971' WEL, SEC. 33, T13N, R11E At total depth 2396' NSL, 3990' WEL, SEC. 33, T13N, R11E 6. Datum Elevation (DF or KB) KBE = 62.4' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-05 9. Permit Number / Approval No. 96-68 10. APl Number 50-029-22670 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8640 feet true vertical 7195 feet Effective depth: measured 8536 feet true vertical 7117 feet Casing Size Structural Conductor 72' 20" Surface 3787' 9-5/8" Intermediate Production 8587' 7" Liner Plugs (measured) Junk (measured) Length Cemented MD TVD 250 sx Arcticset I (Approx.) 779 sx PF 'E', 736 sx 'G', 250 sx PF 110' 110' 3823' 3497' 220 sx Class 'G' 8620' 7180' Perforation depth: measured 8302' - 8358', 8390' - 8430' true vertical 6937' - 6981 ', 7006' - 7036' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd tubing assembly to 8357' (Cavins safety sub at 8159', Cavins desander unit at 8164' and a bull plug at 8357') Packers and SSSV (type and measured depth) Cavins desander unit with ESP packer at 8164' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: 15. Attachments E~ Copies of Logs and Surveys run [~ Daily Report of Well Operations Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure I16. Status of well classifications as: [] Oil [] Gas I-q Suspended Service 17. I hereby certify that the f~,egoing is true and correct to the best of my knowledge Signed d.~.,~ ~ Terrie Hubble Title Technical Assistant III Prepared By Name/Number: Date ~)~' ¢~-~3- Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Du Progress Report Facility M Pt K Pad Well MPK-05 Page 1 Rig ~ )[0~Of~ t.~._N Date 10 February 99 Date/Time 15 Nov 98 16 Nov 98 17 Nov 98 18 Nov 98 07:00-09:00 09:00-10:30 10:30-15:30 15:30-16:30 16:30-18:00 18:00-18:15 18:15-19:00 19:00-20:30 20:30-21:00 21:00-21:30 21:30-22:00 22:00-22:30 22:30-23:00 23:00-01:00 01:00-01:15 01:15-01:30 01:30-02:00 02:00-03:30 03:30-05:00 05:00-06:00 06:00-06:15 06:15-07:00 07:00-08:00 08:00-09:00 09:00-17:00 17:00-18:00 18:00-18:15 18:15-18:30 18:30-19:30 19:30-20:30 20:30-22:00 22:00-23:30 23:30-00:00 00:00-01:30 01:30-02:30 02:30-06:00 06:00-11:30 11:30-12:30 12:30-13:30 13:30-16:00 16:00-16:30 16:30-18:00 18:00-18:15 18:15-19:00 19:00-23:30 23:30-00:00 00:00-01:30 01:30-02:00 02:00-03:00 03:00-03:30 03:30-04:00 04:00-04:15 04:15-04:30 04:30-04:45 Duration 2hr 1-1/2 hr 5hr lhr 1-1/2 hr 1/4 hr 3/4 hr 1-1/2 hr 1/2 hr 1/2hr 1/2 hr 1/2 hr 1/2 hr 2hr 1/4 hr 1/4 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 1/4 hr 3/4 hr lhr lhr 8hr lhr 1/4 hr 1/4 hr lhr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr lhr 3-1/2 hr 5-1/2 hr lhr lhr 2-1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 3/4 hr 4-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr Activity Rigged down Fluid system Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Fluid system Serviced Block line Held safety meeting Rigged up Drillfloor / Derrick Installed High pressure lines Retrieved Hanger plug Tested High pressure lines Bleed down well Circulated closed in well at 8070.0 ft Bullhead well Circulated closed in well at 8070.0 ft Monitor wellbore pressures Installed Hanger plug Removed Xmas tree Installed BOP stack Tested All functions Retrieved Hanger plug Held safety meeting Retrieved Tubing hanger Circulated at 7071.0 ft Circulated at 7071.0 ft Pulled Tubing in stands to 64.0 ft Rigged down sub-surface equipment - Electrical submersible pumps Held safety meeting Rigged down sub-surface equipment - Electrical submersible pumps Made up BHA no. 1 Rig waited: Orders Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rig waited: Equipment Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations (cont...) Rigged down Logging/braided cable equipment Serviced Block line Rigged up Completion string handling equipment Serviced Completion equipment Serviced Electrical submersible pumps Held safety meeting Serviced Electrical submersible pumps Ran Tubing in stands to 8330.0 ft Installed Tubing hanger Serviced Electric cable Ran Tubing on landing string to 8357.0 ft Removed BOP stack Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Tested High pressure lines Facility M Pt K Pad Progress Report Well MPK-05 Rig (null) Page Date 2 10 February 99 Date/Time 04:45-05:00 05:00-06:00 Duration 1/4 hr lhr Activity Freeze protect well - 14.000 bbl of Diesel Rigged down High pressure lines PERMIT 96-068 96-068 96-068 96-068 96-068 96-068 96-068 96-068 96-068 96-068 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS SBL/GR/CCL 7386 CDR-MD CDR- TVD CDN-MD CDN-TVD 7445 ~SEPIA ~T~SBT/GR MARKED LINE ,~/~3820-8630 ~L~3500-7190 ~-480-8570 ~'3500-7140 ~T~3714-8640 CDR/CDN GR/CCL-PERF RCD ~8200-8500 GR/CCL ~30 - 8569 7496 ~R/CCL Page: 1 Date: 07/21/98 RUN RECVD 1 05/01/96 1 08/16/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 1,2 09/05/96 FINAL 09/06/96 FINAL 09/06/96 1 10/16/96 T 10-407 ~CoMPLETION DATE i?////~/~' DAILY WELL OPS R ~//~ /[~ / TO ~/~ /~/ Are dry ditch samples required? yes ~_And received? Was the well cored? yes ~_~alysis & description received? Are well tests required? yes --m~Received? Well is in compliance Initial COMMENTS STATE OF ALASKA ~: ALASK~ OIL AND GAS CONSERVATION CC,~viMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 96-68 .., 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22670 4. Location of well at surface i~ '~i: ;:?. ~!i'~''I ~ , ~~ 9. UnitMilneOrpointLeaSeunitName 3731' NSL, 2133' WEL, SEC. 3, T12N, R11E ~ ~ !L:..i:i At top of productive interval ! ~._J/~_/~` ............ i 10. Well Number 2179' NSL, 3926' WEL, SEC. 33, T13N, R11E ! ~,';-,~-i~:iF!'? i MPK-05 At total depth~. ~/~_ ..~_ ....! 11. Field and Pool 2396' NSL, 3990' WEL, SEC. 33, T13N, R11E '~ .................. '.-~--~ Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 62.4'I ADL 028232 12. Date Spudded04/06/96 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' Water depth' if OffshOre } 16' NO' Of cOmpletiOns04/16/96 08/11/96 N/A MSLI One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 8640 7195 F~ 8536 7117 F~ (~Yes []No I N/A MD! 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR/CCL, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE VVT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NT8OLHE 38' 110' 30" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 3823' 12-1/4" 779 sx PF 'E', 736 sx 'G', 250 sx PF 'C' 7" 26# L-80 33' 8620' 8-1/2" 220 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 2-7/8", 6.5#, L-80 8152' N/A MD TVD MD TVD 8302'-8358' 6937'-6981' 8390'-8430' 7006'-7036' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ORIGINAL i27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) August 12, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing Pressure CALCULATED , OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (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. JAN 0 5 ~997 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. ' Geologic Marke, o 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top KC1 8291' 6867' Top Kuparuk 'B' 8349' 6912' Top Kuparuk B6 8423' 6969' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the fore, going is true and cc rrect to the best of my knowledge s, ned 'l'imSchofield ~ Title Senior Drilling Engineer Date i~- ~i cz'., -/// Prepared By Name/Number: Kathy CampoJmor,' 564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-05 Rig Name: N-27E AFE: 33701 9 Accept Date: 04/06/96 Spud Date: 04/06/96 Release Date: 04/1 9/96 Apr 6 1996 (1) Rig moved 100 %. Nabors rig #27E accepted 04/06/96 @ 0100 hrs. RU drillfloor/derrick. RU divertor. Apr 7 1996 (2) MU BHA #1. Tested divertor. Held safety meeting. Drilled to 1950 ft. Apr 8 1996 (3) Drilled to 1960 ft. Circulated at 1960 ft. POOH to 1100 ft. RIH to 1960 ft. Drilled to 2552 ft. Flow check. Fill pits with water based mud. Circulated at 2520 ft. POOH to 1470 ft. Fill pits with water based mud. Circulated at 1470 ft. RIH to 2040 ft. Circulated at 2040 ft. RIH to 2420 ft. Washed to 2552 ft. Drilled to 2836 ft. Repaired mud pumps. Drilled to 3290 ft. Apr 9 1996 (4) Drilled to 3840 ft. Circulated at 3840 ft. POOH to 1100 ft. RIH to 3840 ft. Circulated at 3840 ft. Pulled BHA. RU casing handling equipment. Ran casing to 2649 ft (9.625"). Washed to 2649 ft. Ran casing to 2780 ft (9.625 in OD). Circulated at 2790 ft. Apr 10 1996 (5) Circulated at 2790 ft. Ran casing to 3823 ft (9.625 in OD). Circulated at 3823 ft. Mixed and pumped slurry - 452 bbl. Displaced slurry - 284 bbl. RD cement unit. Mixed and pumped slurry - 42 bbl. RD divertor. Installed wellhead integral components. RU BOP stack. Tested BOP stack. Apr 11 1996 (6) Tested BOP stack. Installed bore protector. MU BHA #2. RIH to 1100 ft. Serviced block line. RIH to 3300 ft. Tested casing. Held drill (stripping). RIH to 3739 ft. Drilled installed equipment - float collar. Performed formation integrity test, 12.5 ppg EMW. Drilled to 4760 ft. Apr 12 1996 (7 ) Drilled to 5328 ft. Circulated at 5328 ft. POOH to 3800 ft. RIH to 5328 ft. Drilled to 6998 ff. Page Apr 13 1996 (8) Circulated at 6998 ft. POOH to 5328 ft. RIH to 6998 ft. Drilled to 8135 ft. Circulated at 8135 ft. Apr 14 1996 (9) Circulated at 8135 ft. POOH to 7670 ft. Fill pits with water based mud. Circulated at 7670 ft. Circulated at 7670 ft. Circulated at 7670 ft. Flow check. Pulled BHA. MU BHA #3. RIH to 600 ft. Apr 15 1996 (10) RIH to 7618 ft. Circulated at 7618 ft. RIH to 7997 ft. Circulated at 7997 ft. Washed to 8132 ft. Drilled to 8511 ff. Apr 16 1996 (11) Drilled to 8577 ft. Circulated at 8577 ft. Pulled BHA. Ran electric logs. MU BHA #4. RIH to 8415 ft. Washed to 8550 ft. Circulated at 8550 ft. Apr 17 1996 (12) Circulated at 8550 ft. LD 465 ft of 5 in OD drillpipe. Logged hole with LWD: DIR/FE/DD from 8067 ft to 8577 ft. Drilled to 8640 ft. Circulated at 8640 ft. Circulated at 8640 ft. LD 7790 ft of 5 in OD drillpipe. Pulled BHA. Removed bore protector. Worked on BOP - Bottom ram. RU casing handling equipment. Held safety meeting. Apr 18 1996 (13) Ran casing to 3808 ft (7 in OD). Circulated at 3808 ft. Ran casing to 8620 ft (7 in OD). RU high pressure lines. Circulated at 8120 ft. Mixed and pumped slurry- 55 bbl. Displaced slurry- 326 bbl. Wait on cement. Apr 19 1996 (14) Wait on cement. Tested casing. Held safety meeting. Circulated at 5580 ft. Mixed and pumped slurry - 25.5 bbl. Displaced slurry - 213 bbl. Tested casing. RD casing handling equipment. Installed seal assembly. Tested seal assembly. RD BOP stack. Installed adapter spool. Installed Xmas tree. Tested adapter spool. Tested all tree valves. Installed hanger plug. Freeze protect well - 60 bbl of Diesel. Nabors rig #27E released 04/19/96 @ 1000 hrs. Page 2 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-05 Rig Name: N-4ES AFE: 33701 9 Accept Date: 08/08/96 Spud Date: Release Date: 08/1 1/96 Aug 9 1996 ND flange & NU BOP's. Test BOP's. Test waived by Lou Grimmaldi w/AOGCC. RD test jt & pull test plug, set wear bushing, RILDS. MU BHA #1 & RIH f/shed on 3-1/2" drillpipe to cement tag @ 5541' Cir¢ diesel cap to tiger tank. Drilling on cement & ES cementing tool 5541'-5574'. Tag ES @ 5567'. Circ biozan sweep. Cont to PU 3-1/2" drillpipe t/8530', tag cement. Drilling cement 8530'-8560'. Pump biozan sweep &circ out drilling mud. POOH with BHA #1. Rig accepted @ 0600 hrs, 08/08/96. Aug 10 1996 Cont TOH & LD BHA #1. Strap & MU BHA #2 & RIH & tag fill @ 8558'. Mix & perform casing wash & circ & filter brine. POOH, LD drillpipe. Cut drilling line. Cont TOH, LD BHA #2. ND flow nipple & NU perf flange. Aug 11 1996 RIH with GR/CCL & log 8574' to surface. RIH with #1,4-1/2" gun @ 5 spf. Perf 8410'- 8430'. MU gun #2. RIH & perf 8390'-8410'. POOH. MU gun #3. RIH & perf 8338'- 8358'. POOH. MU gun #4 & perf 8318'-8338'. POOH. MU gun #5. RIH & misfire POOH & repair short in head. MU gun #6. RIH & perf 8302'-8318'. POOH. ND shooting flange & NU riser, pull wear ring & set test plug. Test 2-7/8" rams. Rig floor to run 2-7/8" tubing & ESP assy. MU ESP assy & service. RIH with ESP assy, PU 2-7/8" from shed. Aug 12 1996 Cont to RIH with ESP completion & MU hanger & landing jr. Make splice at hanger. Land tubing, RILDS. Back out landing jr, install 2-way check. ND riser & flowline & BOP's. NU adapter flange & tree & test same. Pull check & set BPV. Secure well head & make final check on ESP readings, OK. Rig released 08/11/96 @ 1800 hrs. NOTE: No freeze protect because the weather conditions were such that there were no freezing concerns and because the well was quickly placed on production. jAN 0 3 1997 Alaska 0il & Gas Cons. Commission Anchorage Page PAGE ********* ANADRILL ********~* ********* SCHLUMBERGER ************************************************** COMP~4Y BP WELL NAME MF'I(-5 LOCATION ! MID4E PT LOCATION 2 ALASRA MACq4ETIC DECLINATION 27~78 GRID CONVERG~.CE ANGLE 0,00 [~TE: AP1 NUMBER -n, AFE NUMBER 38701? JOB NUMBER 37858 WELL HEAD LOCATION: LAT(N/-S) 0~00 AZIMUIM FR~ ~TAR¥ TABLE TO TARGET IS TIE IN ~}INT(TIP) MEASURED DE~%H 112,00 TRUE VERT DE~TH INCLINATION 0 AZI~H 0 LA~I~DE(N/-S) 0,00 D£P(E/-W) 0,00 .341,83 M~A~R~D I~BRVAL VERTICAL DEPT~ DEI:~T~ i!2,~} 0,0 112,00 i35,94 23,9 135,94 216.69 60,8 2i6.68 307,88 91.2 307.86 7~.6.76 ~,? 396.73 487 ~4 577.23 669.05 759.~ 850,70 944.35 1039,71 11~,72 !228,64 1~3,29 i415,38 1510,16 1605.02 1698.94 1794.78 1986,23 2079,53 2265,43 Z"~i,O0 2454,.~ 2645,76 ~39,61 2&~,70 2927,44 3022.81 3117,56 321!.!i 3308,34 3403,26 ~97.10 2591.75 90,6 487.31 59,9 577.20 91,6 &59.01 90,2 759,25 91.4 850.65 93,7 9-44..,29 95,4 ~" ' 94,0 11~.65 94,9 I;~ ~ 94.4 I3~.19 ~'~,~,i!4i5.27 94.8 i510.0i 94.8 i604.73 93.9 1696.32 94.5 18&6.~ 96,9 1980.54 93,3 2070.19 94,4 2159.13 91,6 2~43.13 95.6 2528.93 921.9 2412,37 95.7 2495.97 95.2 2~6.67 _ ~654.~ 94.1 2729,67 93,7 280~.vo 95.4 2876.64 94.8 2949.71 ,~.; 302i,72 97,2 2~95,92 94,9 3169.50 93,6 3243,57 94.4 3317.69 94.6 339!.50 ANA~!LL SURVE~ C~LCULATiONS CIRCULAR ARC T~'.GET STATION -AZ!ML~H LATITUDE SECTi[~4 INCLN, N/-S ft deq deg ft 0,00 O.(E) 0.(~ 0.00 '0.02 0,72 63,~ 0,2! 0,99 62.69 0,62 0.52 0,95 57.79 0,83 0,42 48.09 !,99 !.21 0.38 16.59' 2.5! 1.86 0.~. 21.12 3.28 2.87 0.87 !i.99 4.45 .,~5.16 5.29 3,70 0,2~. ~n 4,09 0,44 275.98 5.5! 4.49 0.79 275.i7 5.60 4.90 0.70 266.52 5.62 5.~ 0.82 279.98 5.7i A.14 ~,07 ~a~ ,~ _ ~,,~ 6.02 6,.~. 1.05 274.27 8.t8 !,i6 [~4.68 7.i9 !1,t5 2.47 349,58 i0.07 15.92 3,5! 0.45 14.98 23,20 5.90 1,38 22.68 35.27 9.t9 555.94 35.25 52.32 12.0! 350,65 52,49 74,42 !4,58 ~7,87 74,37 !00,t6 17,57 345,54 9~.50 131,56 21,55 ~1.51 129.59 167.92 ~.47 340,2~ 143.94 ~;¢~.99 26.78 340.60 2~3.62 253.06 27.82 340.52 244.26 299.66 30.47 ~0,15 288.16 349,70 33,04 ~L~,43 335,14 402.64 .35,73 ~9.67 4~.93 37,61 340,39 437,72 517.24 39,14 340.79 492.73 577.91 29.88, 341.55 550.t6 6[~.25 39.23 .341.04 &37.32 697.~ 40.07 341.72 ~63,68 7¢~.76 40,45 341.71 723.54 820.71 37.69 342.03 780.51 878,33 37,87 93A o~ 38,65 342.62 891.~ MF'K-5 D~PA~U~E DISPLACEMENT at AZIMUTH DiS E/-W Oe_.cu' ft ft ~eo lOOft O.(K~ 0.~, 0,00 0,00 0.13 0,!5 63,32 1,2i 1,36 .~,.~% 0,33 2.55 2.90 61.56 0.10 3.42 3.95 59.74 3,75 4,51 56.25 0,2~ 4,02 5,19 50,84 0,31 4.36 A ..2~ 44,41 0,26 4.25 6.79 38.79 0.89 3.66 6.61 33.60 ~,6,_, A '~,". 25.40 0.38 t.43 ~ mn ,,..,,u 14,24 0.19 5,71 1,'~ -1,35 6,17 347.41 0,27 -3,08. 7,00 ~3,94 0,17 -4.3i 8,39 329.05 1,22 -5.(Y~ 11,28 .3~,!8 1,45 -5,44 !5:93 340,05 1,24 -5.5~ 23,29 346,65 2,.% -5.72 35,71 350,78 3.51 -7,&5 53,07 351.49 3.15 -12.06 ~,..~4. 350,79. 2.73 -i8,04 101,12 7".49,72 3,28 -27,05 lo%.38 346.21 4.25 -38,98 1S8.51 346.63 4,53 -52.99 210.41 345.41 -67.26 253.36 344.61 1.12 -62.95 299.&5 343.94 -t00,26 349,82 343,34 2.73 -118,77 402,70 342,85 2,87 -138,(E~ 455.96 342,50 2.26 -157.37 517,26 342,29 1.45 -176.95 577.'.-Fz ~2.17 0.92 -t96,30 655.26 342,09 0.76 -215.5-5 697.94 342,03 1,Ol -235.07 760.77 342.00 0.3~ -253.72 820.72 341.99 2.70 -Z~l.30 878.33 342,01 0,28 -28~.68 936.94 342.04 0.83 -306,69 996,43 342.07 0,64 PAGFj NO, ~ASURI~i) INTB~:VAL VEA%ICAL Dk'Fq~H DEP?H 3774,39 ~,0 3459.~ 3~76,56 102,2 352~.96 ~969,53 93,0 ~11,57 4~3.97 94~4 3685.~ 4!56,95 93.0 3756.96 4252.41 4347.29 4442.[~' 4536.62 46.31.07 4722.88 46t9.51 4914.10 5010.13 5104.85 51~.49 5294.51 53i~.26 5484.58 5580.54 5675.17 5771.27 5647.01 5960.04 6!47.92 6241.73 6324.62 6429.59 6523.64 6615.91 6710.75 6806.46 6.901.M, 6995.86 7087.93 7163.3 7275.06 7371.18 7464.75 95.5 3834.~ 94.9 3909.10 95,1 3963.57 94,2 4056.56 94.5 4128.63 92.8 4198.79 95,6 4270,53 94.6 4~n8 a~ 96.0 4411.90 94,7 4482.09 95,0 46'23,95 95.8 46.95,51 94,3 4765,85 96,0 4637.45 94.6 4907.%' 96.1 4979.62 95.7 5051.06 93,0 5120.~) 94,3 5191.26 93.6 5261.8~ 93.8 5332.16 92.9 5402.23 95.0 5474.!0 94,0 5545,35 92.3 5615.24 94.6 5687.I5 95.7 5759.87 95.3 5832.44 94.1 5904.37 92.1 5975,62 95.4 .~50.36 91.7 6122.65 96.1 6198.37 93.6 6272.(~ ************* ~DRILL SURVEY CALCULATIONS ********:***** CiRCUkAR ARC TARGET STATION AZIMUTH ~TITUDB S~TIFjN it~.LN. N/-S ft Oeg Oeo ft 1052,14 39,33 ~2,5~ 100t.21 1116.47 36.75 343.87 1062.60 1174._~ 38,56 341.92 1116.30 !233,11 36,12 342,00 1174,00 12'.~.27 37.74 341,81 !228.34 1348,79 37,86 342,62 1284,06 1407,27 38,~ ~9,96 1~39,~ 14~,38 28.66 339.62 1394.96 1525,84 39.82 ~-6,76 1450,26 1586..~ 40.71 255.78 15~..16 !647.03 41.07 336.14 1561.64 1710.06 41.73 236.73 1620.03 1773.27 42.25 ~9.35 1679.1i .1837.84 42,~? 341,54 17~.97 190!.44 42,08 .34,3,74 1600.68 t964,~' 4i.40 344,37 1661,26 2027.21 41,46 ~4.19 192i.78 2090.79 41,.53 ~' ~ ~' o4~.o~ 1982 o~ ~lb~,~/ 41.71 344.59 2043,4t 2217,41. 41.77 ~.~ ~ 2104,6A. ~80,45 41.~3 344.13 2165.46. 2344,46 41.79 344.3! 2217.!1 2408,16 41.66 ~2,8~ 22&~,24 2469.94 41.57 342.49 2347.22 2532.32 4i,32 343.~ 2594.!0 41,28 343,25 2466.,01 2655,~ 41,16 ~2,93 ~25,16 2716.86. 40.~0 342,86 2563.44 2776,92 40,74 ~4,01 2642.95 2840,27 40,74 342,90 270i,78 ~90rj,51 40,79 343,~- 27s9,40 2962.35 40.60 341,10 2818,24 .3024.57 40,50 [442,87 2877,41 ~86.40 .40.37 342.40 29~.,42 3147.(¢J 39.86 ~1.19 2'~74.0Q 3205,31 38,74 342,47 3049,40 32_,.'!,4.5938,11 .341,77 3105,62 3321,06 37.9! 239,44 3159.09 ~0.13 38.13 286.69 3214.03 3437.57 37.?3 ~ ~ · . ~7,0_ 3267.09 DEPARTL~ DISP!~CBMEN? at ~/-W ft ft -323,42 1052,15 -~2,04 1!16,49 -359,12 1174,55 -377.26 1~3.13 -~5,0t 1290.29 AZIML~H Oeo 342.10 342,16 342,20 342,!7 -412,88 1~6,81 342,16 -431,65 1407,30 342,14 -452,08 1466,39 342.04 -474.24 1525.84 341.89 -498.81 t586.60 34!.68 -522.56 1647.07 341.47 -547.62 1710.14 2441.32 -570.45 !773.37 341.24 -592.07 1837.95 2441.21 -611.05 i901.53 34!.26 %26.35 1964,46 2441.35 -645.39 ~' ~ % ~O~7,c~ 341,44 -~.2,92 2090,83 34. i,51 -680.01 2153,59 34i.59 -697.50 2217,42 5441.67 -715.02 2280.45 34!.73 -732.~ 2344.46 [441.~b -750.47 2406.16 341.84 -768.88 246_9.94 341,86 -787.28 2532,~c~ 341,89 -805,08 2594,10 ~441,92 -823,04 2655,90 341,95 -840,97 ~716,87 341,97 -858,66 2778.93 342,00 -876.14 2640.29 342.03 -693,77 2900.54 342.05 -912,79 2962,37 :442.05 -932,03 3024,59 342,05 -950.46 3066.42 -969,41 3147,03 342,06 -987,60 3205,33 ~442,05 -1005,80 3264,62 342,06 -1024,55 2821,06 ~442,03 -1046.56 3380.14 341,96 -1069.12 3437.57 DLS deo/ lOOft 0.i0 1,02 0.47 ^,42v 0,54 1.77 0.48 2.28 1.16 0,46 1,92 0.71 1,54 !.57 0,85 0,14 0.55 0,67 0,36 0.i3 i.03 0,27 0.58 0,06 0,27 0,28 0.8'; 0,77 0,14 1.37 1.21 0,35 0.99 1,50 0,80 1,56 0,24 MEA~REI) IN?ERVAL VERT!C~L DEPTH DEPTH ft ft 7559,65 94,9 63~.,65 7654,17 94j 7749,07 94,9 7844,47 95.4 79~.,69 92,2 6644,~ 8032.30 95,6 6721,14 8W6,_%4 64,2 6772,86 6190,69 94,2 ~.46,63 8283,81 93,1 69Z~,97 6274,U 91.t 6994,16 8469,3Z 94,4 70~.,47 8568,53 99,2 7141.18 8596,17 27,6 7161,85 SURLY F$~]JECTED TO TD ~440,~ 43,6 7194,61 ************* ANAi$:iLL ~UR~Y CALC:JLAT!ONS ************* CIRCULAR ARC METHOD******** TARGET STATION AZIMIffH LATITUDE SECTION INCD4~ N/-S E/-W ft de~ ~eq ft ft 3496.04 [~.,46 3~6,96 3~1,1! -1092,04 [,554,66 38,61 2~6,14 3335,13 -1115,48 2613,~ 38,13 32-.5.,41 3429,05 -t1[~,18 3671,~ 37,24 335,16 3482,23 -1163,09 3726,31 $5,6t 3._q5.05 3532.49 -1186,4i DEPAETURE DI~'LACEMENT at ft 3496,04 3554,6~ ~.13,33 3671,2.4 3726,40 AZIMUTH 341,~0 341.71 ~1,62 341,53 341,44 DLS ~eq/ lOOft 0.~7 0,56 0,54 i,23 0.68 3762,72 36,27 ~5,~ 3564,03 -1210,25 37~2,85 341,34 2~20,59 36,49 335,68 3618.70 -1226,06 3620,76 341.28 0,49 3~76,23 36.32 .~.7,61 3670,00 -1248,22 3~76,46 341,22 1,23 ~32,28 37,78 341,96 3722,63 -1267,~. ~32.52 341,20 3~22 3989,05 ~,36 342,48 3~6,69 -1284,89 ~89,28 341,21 1,78 4049,76 40,72. 343,99. o~,~,~,~ -!302~40 41t5,02 41,57 343,~ 3697,59 -1320,49 41~,35 41,63 344.02 3915,22 -1~5.56 .4050,00 4115,20 4133,53 4162.45 41.63 3~4.02 5-6'43.2i -1333.58 ~1,24 341,28 341,30 341,31 y~ 41oz,61 !,7..4 O 0:47 0.06 F MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston,.. Chairman THRU: DATE: April 10, 1996 Blair Wondzell, P. I. Superviso.~ FROM: Bobby Foster, ~ SUBJECT: Petroleum Inspector~ . ~^ FILE NO: GWQIDJDD.doc Surface Casing Cmt. BPX - MPU - Well K-5 PTD # 96-0068 Kuparuk River Field Wednesday, April 10, 1996: After arriving on the North Slope this date, I traveled to BPX's MPK-5 to follow up on a report by Doug Amos concerning the surface cement job on the 9.625" surface casing. I arrived on location at 2:45 PM and met with Tom Anglen, SSD rep. and discussed the cement job. Tom said they lost partial returns while cementing the casing but BPX felt confident that the casing shoe had integrity. I went to the cellar and observed the casing to check for any bubbles of gas and found none. I then had the cement checked in the annuls of the 9.625" and 13.325" conductor and found hard cement approximately 5.5' down in [he casing. Tom and I talked about drilling out and doing a leakoff test. After talking to Tom about drilling out I called the AOGCC and spoke with David Norton and Jack Hartz. It was decided to that it was BPX's decision to make about drilling out. I told Tom what was discussed and he called his supervisor Randy Thomas and they decided to drill out. I stoodby until the float collar, casing shoe, and 10' of new formation was ddlled out. The well was circulated out the bit was pulled into the casing and the leakoff test was performed. The casing shoe was at 3517.9' TVD and the mud weight was 8.6 lb/gal. To obtain an equivalent mud weight of 12.5 lbs/gal, the casing was pressured up to 740 psig. and held for approximately 8 minutes during which time the pressure dropped to 640 psig. While the test was in progress I went to the cellar and checked for any bubbles in the cellar which would indicate gas migrating up around the 9.625" casing. I did not see any indications of gas bubbles or influx of an fluid. After completing the leakoff test I departed the location at 10:30PM and returned to The AOGCC office. While at the rig I ask Tom what well was being injected into and he said K-17. I ask him how much fluid had been disposed of down the well and he said approximately 8,000 bbls. so far. I checked the well and everything seemed to be normal. This well is 90' from K-5 at surface. All wells on this pad are supposed to be drilled on 15' spaceing. RECEIVED ,~PR 1 1 1996 Al~ska Oil & Gas Cons. Commission Anchorage .e K-Pad Wells. hase 1 ,~ Location Check J. Cotton 2/2/96 ,~/ell Line Grid Azimuth: 157037'00'' NAD 27 ASP ZONE 4 SF= 0.99990812 SCALE: 1 "=200' Note: Bearing and distanoe, are ASP grid. Well K-2 / X=584512,2564 Y=6005935,7546 Well K-4 Well K-1 ~ K. X=584410.5535 Of Y=8005895,8703 Well K-$ Well K-7 Well K-11 / Well K-1 Well K-1 Well K-17 Well K-lg ~_.~ Well K-21 ~ · Well K-25 Well K-27 Well K-29 Well K-$1 Well K-33' Well K-$5 Well K-37' Well Well K-6 Well K-8 roll K-10~~' Well K-12 Well K-14 Well K-18 -~f~ Well K-I~:~'~i roil K-20 ~:~_ K-22 ~?~' Well K-24 Well K-2B : We[l K.28' k-~ Well K-30 {~'~ Well K-82 K-J~13 Well K-34 Well K-36 .~' Well K-3 .~,eil K-40 / K-C= Well K-42 Well K-44 X=584~2.1 Y=8005844,S 144 Well K-41 K-I Well K.43 X=584530,4949 Y=6005802.6501 . . ~HI-I'II~IC[ SSDIA~SS GS~IblHS N[':J:.~I;, :2,0 96, 2, t 83_-I HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: ~.~,~, ~ D~.SC~I~TION -c/~ ~ M~-0~ ~:~ 7~ ~ ~ ~D~ TA~+~IS ECC No. Run # 1 6653.01 Run # 1 6774.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ) , '. r FA/~[ to (907) 563-7803 Received byi~_~~~[~ Date: Attn. ALAS~ OIn + SAS cONSERVATiON 3001 poRCUPINE DRIVE ANCI{ORAGE AK, 99501. RECEIVED S£P 0 6 '1995 ~J(a o]i ~ (,Ja~ ~,,.~~:1 ~996 Transmittal of Data RE: sent by: HAND CAR~Y Dear sir/Madam, Enclosed, please find the data as described belOW: ~ DESCRIPTION wELL 1 GR/CCL FINAL BL+RF 1 pFC/PERF FINAL BL+RF 1 GR/cCL FINAL BL+RF please sign and return to: Attn. Rodne¥ D. paulSOn Western Atlas Logging services 5600 B street suite 201 Anchorage, AK 99518 FAX to (907). 563-7803 . Received by: ... Date ECC No. 6653.01 6766.00 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 30, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Job # 96165 was sent to: I~R-/~''~ C.~ L.... C CDN, CDR/CDN TVDfor well MPK-05 BP Exploration (Alaska)Inc. Petrotechnical Data Center, MB3-3 900 E. Benson BIvd, ..... Anchorage, Alaska 99519-8612 OH LIS Tape Bluelines each Film-each .. ! State of Alaska AlaSka Oil & Gas Conservation Comm. Attn: Larry Grant 3001 'Porcupine Drive Anchorage,.Alaska 99501 1 OH LIS Tape ~ 1 Blueline each 1 RF Sepia each ~.--' ...-- · OXY USA, Inc Attn: Dadene Fairly P.O. Box 50250 Midland, Texas 79710 I OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 467 .NOTE: NO DEPTH SHIFT PER MATT LINDER PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Couder: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RECEIVED Date Delivered: S EP 0 5 1.q§6 Received By: ,~daska Oil & Gas Cons, Commission A~chorage HOWARD OKIJ~ND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A/<, 99501. Date: 8 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS ECC No. Run # 1 6630.00 Run $ 1 6653.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 'B Street ~- . -.- ..... ;:' .- ': Suite 9.01 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by ~ ~_%~ ,-~3~ ~aue: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 SBT FINAL BL+RF~/ ECC No. Run # 1 6653.00 1 SBT FINAL BL+RF~/ Run # 1 1 SBT FINAL BL+RF~' Run 1 PLS FINAL BL+RF /Run 1 PFC/PERF FINAL BL+RF,/Run 6657.00 6658.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Anchorage, AK 99518 ~:_(907) 563-7803 Received by: Date~; ' MEMORANDUM TO: THRU: Statu of Alaska Alaska Oil and Gas Conservation Commission David Jo,.q~n, Chairmafr Blair Wondzell,~, P. I. Superviso~~'('~'~ FROM: Bobby Foster, ',,z, ""' SUBJECT: Petroleum Inspector DATE: April i0, 1996 FILE NO: GWQIDJDD.doc Surface Casing Cmt. BPX - MPU - Welt K-5 PTD # 96-0068 Kuparuk River Field Wednesday, April 10, 1996: After arriving on the North Slope this date, I traveled to BPX's MPK-5 to follow up on a report by Doug Amos concerning the surface cement job on the 9.625" surface casing. i arrived on location at 2:45 PM and met with Tom Anglen, SSD rep. and discussed the cement job. Tom said they lost partial returns while cementing the casing but BPX felt confident that the casing shoe had integrity, i went to the cellar and observed the casing to check for any bubbles of gas and found none. i then had the cement checked in the annuls of the 9.625" and 13.325" conductor and found hard cement approximately 5.5' down in the casing. Tom and ! talked about drilling out and doing a ieakoff test. After talking to Tom about drilling out I called the AOGCC and spoke with David Norton and Jack Hartz. It was decided to that it was BPX's decision to make about drilling out. I told Tom what was discussed and he called his supervisor Randy Thomas and they decided to drill out. ! stoodby until the float collar, casing shoe, and 10' of new formation was drilled out. The well was circulated out the bit was pulled into the casing and the leakoff test was performed. The casing shoe was at 3517.9' TVD and the mud weight was 8.6 lb/gal. To obtain an equivalent mud weight of 12.5 tbs/gal, the casing was pressured up to 740 psig. and held for approximately 8 minutes during which time the pressure dropped to 640 psig. While the test was in progress I went to the cellar and checked for any bubbles in the cellar which would indicate gas migrating up around the 9.625' casing. I did not see any indications of gas bubbles or influx of an fluid. After completing the leakoff test I departed the location at IO:30PM and returned to The AOGCC office. While at the rig ! ask Tom what well was being injected into and he said K-17. I ask him how much fluid had been disposed of down the well and he said approximately 8,000 bbls. so far. I checked the well and everything seemed to be normal. This well is 90' from K-5 at surface. Ali wells on this pad are supposed to be drilled on 15' spaceing. FridaY,,. April 12, 1996: ! returned to the location this date and checked the ceiler on well K-5 and K-17, the well being injected into, to see if any bubbles were visiable in the ceiler or if any other problems had occured. I spoke with Tom Anglen, BPX rep., and he said everything was going OK. Tom ~lso informed me that they were going to run a surface casing cement bond log on this well after the well was drilled to TD. Sunday,, Apdt 14., 1996: ! was in the Milne Point field on another matter and i went by K-5 and K-17 and checked the ce!lets on both wells and ever/thing seemed normal, i spoke with the Nabors toolpusher and he told me that they had lost circulation while drilling ahead but had regained it and were now drilling ahead. MEMORANDUM State of Alaska TO: THRU: Alaska Oil and Gas Conservation Commission David John~~, Chairman--- Blair Wondzeli~ ~,,~ P. I. Supervisor~(~) FROM: D o u g Am os,"--~ ~J~ ~ SUBJECT: Petroleum Inspector DATE: April 9, 1996 FILE NO: gwqhidd.doc Surface Cement Job BPX MPU K-5 Kuparuk Rv. Field PTD No. 96-0068 Tuesday, April 9, 1996: i contacted Tom Anglend, BPX MPU representative, to inquire about the surface casing cement job, on the new MPU K-5 well being drilled by Nabors 27E. I collected the following information pertaining to the cement job: · The 9 5/8" casing became stuck and lost circulation was encountered at approximately 2,600'. From 2,600' to 3,400' every third joint of casing had to be broken and the hole circulated. From 3,400' to TD @ 3,823' every joint of casing was broken and the hole circulated. · Lost circulation was encountered from the start of the cement job. Because they were injecting out of the pits while pumping cement an accurate volume of lost circulation could not be established. Tom estimated that they were loosing around 37 percent. Surface returns consisted of contaminated mud. · Volume of cement pumped was 301 bbl's (779 sacks) of Type E Permafrost cement and 1 51 bbl's (736 sacks) of Class G cement. The hole volume at gauge would have been 320 bbl's (3,823 X .0836 bbl/ft). · According to Tom, other than the top cement job no other remedial work was planned. Summary: Due to the lack of cement returns to surface, I collected information pertaining to the surface casing cement job on BPX MPU Well K- 5. MEMORANDUM TO: THRU: FROM: 27E David Jo~n, Chairma~ Blair Wondzell ) P. I. Supervisor/;~/~'' Doug A m os,~g/~-~..~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 6, 1996 FILE NO: ewqhdfdd.doc SUBJECT: Diverter Inspection Nabors BPX MPU K-5 Kuparuk Rv. Field PTD No. 96-0068 Saturday, April 6, 1996: I traveled to BPX MPU K-5 well to inspect the Diverter System. Due to work schedule conflicts I was unable to witness the diverter function test. I found the location well organized-and the Diverter System in compliance, with the exception of the lack of warning signs at the terminus of the vent lines. ! brought this deficiency to the attention of BPX representative, Tom Anglend and the signs were put in place. An AOGCC Diverter Inspection Form with Location Schematic is attached for reference. SUMMARY: ! conducted a Diverter System inspection at BPX MPU K-5 well on Nabors Rig 27E. Attachment: EWQHDFDD.XLS Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Development Nabor Alaska Drilling Rig No. 27E PTD # BP Exploration Oper. Rep.: BPX MPU K-5 Rig Rep.: T. l0 N. R. ll E. Merdian Umiat X Exploratory: 96-0068 Rig Ph. # Tom Anglend Brian Busby 659-4373 TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK Reserve Pit: N/A Well Sign: OK (Gen.) Drlg. Rig: OK Flare Pit: N/A DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: Valve(s) Auto & Simultaneous: Vent Line(s) Size: Vent Line(s) Length: Line(s) Bifurcated: Line(s) Down Wind: Line(s) Anchored: Turns Targeted / Long Radius: 20 in. ~es Yes 10 Yes Yes Yes Yes in, ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure: Systems Pressure Attained: Nitrogen Bottles: Not Witnessed min. min. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: GAS DETECTORS: Methane Hydrogen Sulfide: Light Alarm Not Witnessed Light Alarm Not Witnessed psig psig sec, sec. psig DIVERTER SCHEMATIC Existing Well Heads 10" Vent Line Pipe' Shed Sub Base , ~-Motors & Pits "-- 20" Annular & 10" Hydrualic Knife Valve ~10 Manual Knife Valves Rig Shop ! Rig Camp i Pad Access 4 Prevailing Winds Distribution orig. - Well File c - Oper/Rep c - Database ¢ - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.: Doug Amos F1-022 EWQHDFDD.XLS ALA$1~A OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 4, 1996 Tim Schofield, Senior Drlg Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Milne Point Unit M~PK-05 BP Exploration (Alaska) Inc. Permit No' 96-68 Sur. Loc. 3732'NSL, 2133'WEL, Sec. 3, T12N, RILE, UM Btmhole Loc. 2341'NSL, 3934'WEL, Sec. 33, T13N, R11E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the 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 perrrfitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnston Chairman BY ORDER OF TIlE COMMISSION dlf/Enclomres cc: Department offish & Game, Habitat Section w/o encL Department of Environmental Conservation w/o encL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill [-Illb. Type of well. Exploratoryl-i Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska)/nc Plan RTE = 61.9 feet Mi/ne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612. Anchorac/e. Alaska 99519-6612 ADL 028232 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 3732' NSL, 2133' WEL, SEC. 3, T12N, R11E Mi/ne Point Unit At top of productive interval !8. Well number Number 2199' NSL, 3888' WEL, SEC. 33, T13N, R11E MPK-05 2S100302630-277 At total depth 9. Approximate spud date Amount 2341' NSL, 3934' WEL, SEC. 33, T13N, R11E 05/13/96 $200,000.00 .12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandmVD) property line ADL 028231, 1346 feet MPK-09, 37' @ 1750'TVO feet 2560 8600' MD / 7190' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2000 feet Maximum hole angle42, z~ o Maximum surface 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) · 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3764' 31' 31' 3795' 3500' 650 sx PF 'E', 736 sx 'G', 250 sx PF ~.' 8-1/2" 7" 26# L-80 Mod B 8570' 30' 30' 8600' 7190' 320 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor l~ 'L% ?~ ~ i ~:. ~ ~ F~ Surface ~-',~: ii.,, k~ ~' ~ '-' ~-~ Intermediate Production ¢~¢~/~.~ 9 o Liner Perforation depth: measured ,~. ........ true vertical A',&$;''-? ..... ~:" ...... 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportD 20 AAC 25.050 requirements[] 21' I hereby C~' tha~hce~is true and c°rrect t° the best °f mY kn°wledge "i~'°-Y¥ ~'°"+°" 'c'~"~'°''-u'csf/°''Signed ~'~ '. Title Senior D#llin, Engineer~"t" ,~.h+ e. 5/~"o.'"Date / Commission Use Only Permit l~u~b IAPI number ' IApproval date See cover letter C/~ ~r~ 150' 0 ~ c~_ ~,,~ ~)~0 [ ~.'..oZ_ff..-~, for other requirements Conditions of approval Samples required [] Yes [] No Mud log required [] Yes I-: q~o Hydrogen sulfide measures [] Yes I~ No Directional survey requirea I~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; J~5M; []10M; []15M; Other: Original Signed By by order of Approved by David W. ,lnhnst0n Commissioner tne commission Date7[~/~ Form 10-401 Rev. 12-1-85 Submit in l riplicate l Well Name: J MPK-5 Well Plan Summary I Type of Well (producer o.r injector): I Kuparuk Producer Surface Location: 3732' FSL 2133' FEL Sec 3 T12N R11E UM., AK. Target. Location: 2199' FSL 3888' FEL Sec 33 T13N R11E UM., AK. Bottom Hole Location: 2341' FSL 3934'FEL Sec 33 T13N R11E UM., AK. Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: 1337011 I I Rig: I Nabors 27E I I MD' IS600' I I TVD' 17190' BKB I IKBE: I61' I IWell Design (conventional, slimhole, etc.): IUltra Slimhole, 7" Longstring Formation Markers Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1815 1811 n/a NA (Top Schrader) 5228 4581 1905 psig / 8.0 ppg OA 1955 psig / 8.0 PPg Base Schrader Bluff 551 3 4796 1995 psig / 8.0 ppg Top HRZ 7627 , 6391 n/a Base HRZ n/a Kupark D Shale 8124 6781 n/a Kuparuk C 8300 6931 .. 3650 psig / 10 ppg TKA 3669 psi[//10 ppg Total Depth 8600 , 7191 n/a Casincj/Tu )ing Program' Hol~ ~sg/ - Wt/Ft 'Grade Conn Length Top Btm Size Tbg, O.D. MD/TVD MD/TVD 30" 20" 91.1# NT80LHE weld 80 32' 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3764 31' 3795/3500 , 8 1/2" 7" 26# L-80 Mod B 8570 30' 8600/7190 N/A (tbg) 2-7/8" 6.5# L-80 EUE 8094 29' 8123/6781 8rd Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. The Modified Buttress 7" 26# will be run on bottom. Logging Program: I Open Hole Logs: Surface Schrader Bluff Final Mud Logs: MWD No additional logs required - Res/Gr from LWD tools LWD GR/Resistivity/SFC CSG to TD Neutron/Density over Kuparuk intervals Mud logs and samples are not required for K Pad wells API # 50-029-22XXX March 27, 1996 Mud Program: Special design considerations Hydrates LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per the updated pad data sheet are encouraged. We will have hydrates on K Pad. We will have our mud weight to 11.0 PPG by 2000 feet. We will weight up in 0.5 ppg increments if necessary. We will use the coldest mix water available to minimize warming in the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to 450 to 600 GPM when hydrates are present to keep mud temperatures to a minimum. We will control drilling rate and keep mud viscosity at 100 sec/qt to keep the hole clean. Surface Mud Properties: I Spud Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 to to to to to to to 11.0 - 11.5 100 35 15 30 10 15 Production Mud Properties: I LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.5 50 20 10 20 9.5 z~-6' Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KO P: 12000' Maximum Hole Angle: Maximum Dog Le~l: Inclination in target: Close Approach Well: 42.71 degrees < 4 degrees 20 Degrees MPK-9 is 37 feet @ 1750 feet TVD MPK-9 is the closet well currently planned to drill after MPK-05, at 61 feet. MPK-09 will be drilled but not on production when MPK-05 is drilled, so the well can be considered shut in for the drilling of MPK-05. This wellplan will allow MPKo5 to be drilled as per BP's close approach guidelines. The well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. AP1 # 50-029-22XXX March 27, 1996 Disposal: Cuffings Handling: 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. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Request for AOGCC Approval Disposal of Drilling Wastes (20AAC25.254) 1. Approval is requested for Annular Pumping for K 5 well, and any well on the pad/drillsite previously permitted for disposal activities by AGOCC. 2. The Base of the Permafrost for all wells located in the Milne Point Unit is 1750 feet. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. 3. The receiving zone to which the fluids will migrate is identified as the Prince Creek geological formation at 2500 - 3300' TVD..The confining layer is the Sagavanirktok Shale defined by logs at 2500' TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7-24-95. 4. There are no wells on Milne Point K Pad. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The drilling wastes to be disposed of during this operations can be defined as drilling mud, cement contaminated drilling mud, and drill cuttings; rig wash fluid (inclusive of rig boiler blow down, and mud and cement rinse water of associated rig equipment, completion fluids (seawater and brine), formation fluids, reserve pit fluids, and drill rig domestic waste water. (Note: if you plan to dispose of fluids OTHER than those outlined above you must list them on the request) The maximum volume to be disposed of in the annulus is 35,000 bbls. Fluid densities will range from 8.3 to 13.0 ppg. Any deviation from this program must be detailed separately. 6. The 9.625" surface casing shoe will set at 3908'md 3701('tvd) and cemented with 768 "E" and 250 "G" sacks cement. This depth is below the base of the permafrost (1750' TVD) and into the top of the Prince Creek formation which has a long. established history of annular pumping at Milne Point. The break down pressure of the Prince Creek formation is 13 to13.5 ppg equivalent mud weight. 7. The burst rating (80%) for the 9.625" 40# 'surface casing is 4600 psi. The collapse rating (80%) for the7" 26# 'intermediate/production casing is 4325 psi. 8. The Maximum Allowable Surface Pressure while annular pumping is the lesser of 2000 psi or the calculated pressure according to the following equation: MASP (psi) = (Max Breakdown ppg-8.3 ppg) X 0.052 X Surf Csg Shoe TVD MASP (psi) = 855 psi 9. The maximum pressure imposed at the surface casing shoe is calculated according to the following equation: Max Press @ Surf Csg Shoe (psi) = .052 x Max Breakdown ppg x Surf Csg Shoe TVD Max Prss at Surf Csg Shoe =2457 psi This pressure is less than the 80% burst and collapse casing pressures calculated in #7. 10. Additional data supplied as needed. . DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL P'REV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point MPK-17 0 35,000 2/16/96 - 2/16/97 ,, Milne Point MPK-25 0 35,000 2/15/96 - 2/15/97 Milne Point MPK-38 0 35,000 2/15/96 - 2/15/97 'Milne 'Point MPK-18 0 35,000 3/7/96 - 3~/97 Milne Point MPK-9 0 35,000 Requested Miine Point MPK-10 0 35,000 3/13/96 - 3/13/97 Milne Point MPK-37 0 35,000 3/13/96 - 3/13/97 FREEZE PROTECTION- Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. AP1 # 50-029-22XXX March 27, 1996 DRILLING HAZARDS AND RISKS: See both the NEW Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on the Cascade wells, and review recent wells drilled on E Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. Hydrates We will have hydrates on K Pad. We will have our mud weight to 11.0 PPG by 2000 feet. We will weight up in 0.5 ppg increments if necessary. We will use the coldest mix water available to minimize warming in the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to 450 to 600 GPM when hydrates are present to keep mud temperatures to a minimum. We will control drilling rate and keep mud viscosity at 100 sec/qt to keep the hole clean. The MPU PE group will be perforating, and cleaning out wells shortly after the dg ddlls and completes them. This will make the near dg area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells on F Pad have lost varying amounts of mud (from 70 to 1000 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 and MPK- 17 were stuck coming out on the short tdp at surface casing point. In the MPK-17 well, proir to the stuck pipe incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed around the BHA at 2300 feet. Subsequent fishing operations were successful and a very expensive BHA was recovered. The interval was the first report of hydrates being present in the well so we had a 11.3 ppg mud weight, but our vis was only 66 sec/qt (26 cp). The Sand/Coal that hydrates were present in probably provided a ledge for the gravel to accumulate in, and fell into the hole when we were tripping out for casing. Future wells should have higher viscosity ( 150 sec/qt )for hole cleaning Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 35 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (10 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 10 ppg EMW (3646 psi @ 7011' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. We will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. API # 50-029-22XXX March 27, 1996 MP K-5 Proposed Summary of Operations I , . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5A Wellhead on the conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. Prior to spud, discuss hydrates drilling with Nabors 22E toolpushers and company representatives J. C. Pyron and D. Montjoy. NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. Drill 12-1/4" surface hole to 3795' md (3500' tvd). Use extreme caution while drilling through the known hydrate interval down to 3100 feet. Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. Follow Pad Data Sheet short trip guidelines. Drill 8-1/2" hole to TD at 8600' MD (7191' TVD). (Note: This hole section will be logged with LWD Triple Combo (GR/Res/Neu/Dens). Use due caution while drilling with shallow set surface casing for both stuck pipe and well control issues. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing with I stage cement program. Test casing to 3500 psi and freeze protect wellbore to 100' TVD by displacing with air. Closely monitor casing running loads for drag. Make sure there is a circulating head for the topdrive before starting to run casing. ND BOPE and NU dry hole tree. Release rig to MPK-38 Note: This well will be ROPE perforated, and cleaned out with a completion rig and prior to running the ESP completion. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 3.5" DP and 6" bit, clean out to PBTD. TOOH. PU and RIH with ROPE perforating string (procedure to be distributed later with perforation intervals). PU and RIH with 2-7/8" EUE 8rd tubing with Electric Submersible Pump (ESP) completion. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. POST . . . . RIG WORK Complete the' handover form and turn it and the well files over to production. Turn over the well files along with the handover form. A SBT/GR/CCL is not required on this well. An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. The rig will not complete this well. PEs will perforate and clean out this well with a pulling unit. AP1 # 50-029-22XXX March 27, 1996 MPK-5 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE' 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 650 THICKENING TIME: Greater than 4 hrs at 50© F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaCI2 WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk APPROX #SACKS: 736 THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 TOP JOB CEMENT TYPE: Type C Permafrost ADDITIVES: Retarder WEIGHT: 15.6 ppg YIELD: 0.95 cu ft/sk. MIX WATER: 3.75 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 TURBULATOR centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. 1 TURBULATOR centralizer per joint of 9-5/8" casing from 2000 to 2500 feet. OTHER CONSIDERATIONS: This well is being drilled after MPK-25 was suspended following problems with the surface casing job. We cannot overstress the importance of getting a sucessful cement job on the well. There are changes to the spacer, cement volumes and centralizer program on this well. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. Casing has been stuck while the rig was shut down filling only 5 joints. API CEMENT VOLUME: 1. The Tail Slurry volume is increased to 623 sacks is calculated to cover the 9-5/8" to 1800 feet with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry surface with 150% excess. 3. 80'md 9-5/8", 40# capacity for float joints is 6 BBL. 4. Top Job PF "C" Cement Volume is 250 sacks. # 50-029-22XXX Il CEMENT MPK-5 PRODUCTION CASING PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK and SCHRADER BLUFF: CIRC. TEMP: 115° F BHST 120 deg F at 7040' TVDSS. SPACER: 50 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3; 15#/SK Silicalite, 0.8% Halad 344, and HR5 as required WEIGHT: 13.1 ppg APPROX # SACKS: 320 FLUID LOSS: < 40cc/30 min @ 115° F YIELD: 2.05 cu ft/sk MIX WATER: 11 gal/sk THICKENING TIME: 4:14 hrs @ 114° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7"x 8-1/4" Straight Blade Rigid Centralizers--two per joint on the bottom 17 joints of 7" Casing (57 total). This will cover 200' above the C Sand. 2. 7"x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6900' - 6100' to cover the Schrader Bluffs Sands (25Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4" Straight Blade Rigid Centralizers needed is 82. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10 bpm. Batch mixing is not necessary. We will have displaced cement to above the Schrader Bluff top with this single stage, therefore we will need to run a CBL no sooner than 2 weeks after cementing. SHALLOW SET SURFACE CASING AT K PAD All the initial K Pad wells will be designed to have the surface casing shoe set above the Schrader Bluff sands. This gives greater flexibility for back-up targets in the Schrader Bluff and also gives significant savings in the costs of 9 5/8" casing and cuttings disposal. The savings will vary from well to well, but should result in average reductions in well costs of around $100,000. This cost saving comes with a number of disadvantages which the rig team will have to overcome in order to achieve the benefit. These disadvantages come from having the relatively Iow pressured Schrader Bluff formation open when drilling the production section and running 7" casing. Past experience has shown that differential sticking can be a problem across the Schrader Bluff unless certain procedures are followed. The most likely time for differential sticking to occur is when running casing. The following' recommended practices are based on lessons learnt at Milne Point. 1. Add Barafibre/Baracarb while drilling the Schrader Bluff sands. 2. Spot a Barafibre/Baracarb pill across the Schrader Bluff when pulling out of hole to run 7" casing. 3. Minimize the time that the 7" casing is stationary in open hole by using auto-fill float equipment and/or by filling the casing every joint. If a top drive is available, use a Franks Casing valve or equivalent, to fill the casing while running it in'hole. NOTE - N22E got stuck on J-16 in 1995 when filling casing every 5th joint. NOTE - Our standard float equipment can be used as auto-fill equipment by asking Halliburton to leave the auto:fill tabs in place. The tabs pump out at 3 BPM, so circulation rates should be kept to 2 BPM when circulating at the shoe. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Top with 30% excess. AP1 # 50-029-22XXX March 27, 1996 MPK-5 Cement Calculator Milne Point Cement and centralizer Calculations Well MPK-5 Surface (1 Stage) Cement Job cement Type E G Hole Size 12.25 Yeild (cfs) 2.17 1.15 Casing Size 9.625 Weight (ppg) 1 2 15.8 BPF 0.0558 ,BPF +,30% 0.0725 BPF + 150% 0.1395 'Depth BBLS 'Cu. Ftl Sacks Top of Cemenl Shoe Depth ~ Calculated G Tail Volume 1995 150.7 846 736 1800 E Lead Volume 1800 251.0 1409 650 Surface ,,, Total E 650 Total G 736 9-5/8" Bows I 0 Production. 1-Stage Cement Job I Cement Yield Hole Size 8.5 . Silicalite Slurry 2.05 Casing size I 7 BPF , I 0.0226 BPF + 30% I 0.0294 'Top of Cemenl Stage I J iVD ' ' BBLS Cu. Ft. Sacks Calculated NA Top Seabee Top }~m~l~q .u. ru centralizers ~ 23 Across the Kuparuk .. Centralizers ~ 28 Across the Schrader Bluff · , Total G ST1 I ' 320 Total ST Bladet , 52 Page 1 S?X - SHaped Sepvic_ , DpikLin9 il ~ / ",, ALo. sko. S o, :e P o. Zone4 , ii i i /; / i HALLIBURTON ii FiiLne : HPK k L....xL.../ / MPI<-5 Est h'IPK-5 (c)GK) Wp1 Ppe[imlno. ry s/aox96 CRITICAL PDINT DATA TIE ~N K~p / START ~ BUILD ~_ MD Inc Azl. ~ N/S E/W 0 O.OO 341.85 0 0 N 0 E 1CO0 D.OD 341.~5 10(X) 0 N 0 E HBRIZFINTAL VIEW (TRUE NORTH) SCALE 500 Ft;, / DIVISION ¢'~SURVEY REP WELLHEAD 1,00/100 Fi START P~ BUILD 1300 3.00 341,85 1300 7 N 2 ~ 1,50/100 Ft ST/~RT OF BUILD 1600 7.50 341.1~5 1590 34 N ~ 2.O0/lOO ?t END EF BUILD ~_7~ lO.OD 341.85 17~ ~ N 17 B~se 1815 10.03 34t.85 18t I 67 N ~ Pe~ mM'm os$ START ~ Ig25 lO.DO 341.85 1919 85 N 28 CCRVE ~ P,50/IOD F~ END EF CURVE 3166 41.02 341,85 30c-c~ 586 N IgB NA Se, rids 5~2'8 41.02 341.85 4581 1872 N 614 3~se Schr(~der 55~3 41.02 341.85 4796 L:~]50 N 672 TH2Z 7627 4%02 34L85 6391 33{:)9 N ~105 START C?- 7749 4~.0~ 341.85 6483 3445 N t130 CURVE ~ P.00/109 ?-~ TKUD 8!~4 33.53 34L85 6781 3660 N ~L:~30 To~ge~ 8300 30.03 34t,85 6931 3748 N 1229 TKUSI 8393 30.00 341,85 701! 3792 N !243 VERTICAL VIEW SCALE 500 ?~, / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REP WELLHEAD o o 500l 1000 1300 J 0 15004 8 1599 / 1722/ 35 0,00 @ 0 MD TIE IN 0,00 ~ 1000 MD KOP / START [}- BUILD e 1,00/100 1,00 @ l iO0 MD 2,00 ~ 1200 MD 3,00 ~ 1300 MD START BF- BUILD @ 1,50/100 ?t 4,50 @ 1400 MD 6,00 ~e 1500 MD 7,50 @ 1600 MD START BF BUILD e 2,00/100 ?t 10,00 ~ 1725 MD END BF BUILD .ooo 181i !919 2000-- 2500-- 3500-- 4000I 4500I 4581 4796 5000-- 5500-- 6000-- 6391 6~-- 6781 7191 7500 54 70 89 -500 VERTICAL SECTION PLANE'. 341,85 iO.OO @ 1815 MD Base Permafrost !0.00 ~ ~925 MI) START BF CURVE ~ 2.50/100 !2.50 ~ 2025 MD !5,oo e ems MD 17.50 8 2885 MD 20.00 ~ ~3~5 MB 88,50 e ~4~5 MD ~ ~0 ~ ~0 500 0 SOO 7,50 e 86R5 MD 32,50 ~ 2825 MD i i I T~ ~ ~ NS EW ~id X ~id Y I 3750 e 3025 MB ' 02 ~ 3~66 MD ENB ~ CURVE T~ 6~ 37~ N ~ W ~1~ I I ~% 9 5/8 in ~D, ~ 3Z~ MD, 35~ TVD I g 5/8 in 37~ 41.~ ~t.~ ~ 9Z9 N ~ ~ Z in ~ ~.~ ~1.~ 7191 ~t N 1276 W I 1,02 ~ 5228 MD ~ Sands 1970 % 4~,02 ~ 55~3 ND ~ose Sc~de¢ .... . ....... , .... l.O~ ~ 76~7 N~ T~Z 3545 % 41,~ ~ 7749 HD START ~ CURVE ~ 8,00/~00 3625 3625 ~ 37,02 ~ 7949 NB ~33,53 ~ 8124 H~ TKUD k 30,00 ~ 8300 H~ 3945 k 30,00 e 8393 H~ TK~I 3991 ~ ~d59~ ~MD, 7191 TVD 4095 I 0 500 1000 15OO 2~0 2~0 3~0 3~0 4~ 4~0 5~0 v Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 3/20/96 Wellpath ID: MPK-5 (96K) Wpl Measured Incl Drift Subsea TVD Course T 0 T A L Depth Dir. Depth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 2725.00 30.00 341.85 2605.97 2666.97 I00.00 343.29N 112.55W 6006207.96 584304.59 361.27@341.85 361.27 2825.00 32.50 341.85 2691.45 2752.45 I00.00 392.58N 128.71W 6006257.06 584287.87 413.14@341.85 413.14 2925.00 35.00 341.85 2774.59 2835.59 100.00 445.37N 146.02W 6006309.65 584269.97 468.6~@341.85 468.69 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 30.0 342.55N 114.8CRV 15.48 7.42 71.85 5.39 BPHM-PBD 2.50 32.5 391.67N 131.4~N 17.33 7.73 71.85 5.82 BPHM-PBD 2.50 35.0 444.26N 149.3~N 19.33 8.05 71.85 6.28 BPHM-PBD 3025.00 37.50 341.85 2855.23 2916.23 100.00 501.55N 164.44W 6006365.61 584250.91 527.82@341.85 527.82 3125.00 40.00 341.85 2933.21 2994.21 100.00 561.02N 183.95W 6006424.86 584230.74 590.41@341.85 590.41 END OF CURVE 3165.89 41.02 341.85 2964.30 3025.30 40.89 586.26N 192.22W 6006450.00 584222.18 616.97@341.85 616.97 2.50 -0.00 2.50 -0.00 2.50 -0.00 2.50 37.5 500.23N 168.4~N 21.48 8.38 71.85 6.78 BPHM-PBD 2.50 40.0 559.45 N 188.73W 23.78 8.71 71.85 7.31 BPHM-PBD 2.50 41.0 584.59N 197.32W 24.74 8.85 71.85 7.54 BPHM-PBD CASING POINT OD = 9 5/8 in, ID = 8.84 in, Weight = 40.00 lb/ft. 3795.08 41.02 341.85 3439.00 3500.00 629.20 978.68N 320.9CVV 6006840.90 584089.10 1029.94@341.85 1029.94 0.00 NA Sands 5227.91 41.02 341.85 4520.00 4581.00 1432.82 1872.29N 613.92W 6007731.08 583786.07 1970.38@341.85 1970.38 0.00 Base Schrader 5512.88 41.02 341.85 4735.00 4796.00 284.97 2050.02N 672.2CW 6007908.13 583725.80 2157.42@341.85 2157.42 0.00 0.00 0.00 0.00 0.00 41.0 978.68N 320.9CW 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 41.0 1865.35N 635.09¢/ 74.62 19.88 71.85 16.58 BPHM-PBD 0.00 41.0 2042.36N 695.5~'W 81.57 21.45 71.85 17.93 BPHM-PBD THRZ 7626.99 41.02 341.85 6330.00 6391.00 2114.11 3368.54N 1104.55W 6009221.61 583278.76 3545.02@341.85 3545.02 0.00 START OF CURVE @ 2.00deg/100 ~ 7749.04 41.02 341.85 6422.09 6483.09 122.06 3444.67N 1129.52W 6009297.44 583252.95 3625.13@341.85 3625.13 0.00 7849.04 39.02 341.85 6498.66 6559.66 100.00 3505.77N 1149.55W 6009358.32 583232.24 3689.43@341.85 3689.43 -2.00 7949.04 37.02 341.85 6577.44 6638.44 100.00 3564.30N 1168.74W 6009416.62 583212.40 3751.03@341.85 3751.03 -2.00 8049.04 35.02 341.85 6658.31 6719.31 100.00 3620.18N l187.0e'W 6009472.29 583193.45 3809.83@341.85 3809.83 -2.00 TKUD 8123.70 33.53 341.85 6720.00 6781.00 74.66 3660.13N 1200.1ON 6009512.09 583179.91 3851.88@341.85 3851.88 -2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 41.0 3355.47N 1144.41W 133.22 33.22 71.85 28.13 BPHM-PBD 0.00 41.0 3431.29N 1170.33W 136.20 33.91 71.85 28.73 BPHM-PBD 2.00 43.0 3492.16N 1191.08W 138.54 34.67 71.85 28.94 BPHM-PBD 2.00 45.0 3550.47N 1210.93W 140.76 35.42 71.85 29.12 BPHM-PBD 2.00 47.0 3606.15 N 1229.84W 142.88 36.16 71.85 29.28 BPHM-PBD 2.00 48.5 3645.97N 1243.35W 144.39 36.70 71.85 29.37 BPHM-PBD 8149.04 33.02 341.85 6741.19 6802.19 25.34 3673.34N 1204.5CW 6009525.25 583175.43 3865.78@341.85 3865.78 -2.00 8249.04 31.02 341.85 6825.97 6886.97 100.00 3723.73N 1221.01W 6009575.44 583158.36 3918.8¢@341.85 3918.80 -2.00 Target 8300.15 30.00 341.85 6870.00 6931.00 51.11 3748.39N 1229.1CW 6009600.00 583150.00 3944.75@341.85 3944.75 -2.00 0.00 0.00 0.00 2.00 49.0 3659.14N 1247.82W 144.90 36.89 71.85 29.40 BPHM-PBD 2.00 51.0 3709.36N 1264.82W 146.78 37.59 71.85 . 29.50 BPHM-PBD 2.00 52.0 3733.94N 1273.13W 147.72 37.95 71.85 29.54 BPHM-PBD TKUC1 8392.53 30.00 341.85 6950.00 7011.00 92.38 3792.27N 1243.4~V 6009643.73 583135.13 3990.94@341.85 3990.94 0.00 CASING POINT OD = 7in, ID = 6.28in, Weight= 26.001b/~. 8600.00 30.00 341.85 7129.67 7190.67 207.47 3890.85N 1275.8CW 6009741.92 583101.72 4094.68@341.85 4094.68 0.00 8600.15 30.00 341.85 7129.81 7190.81 0.15 3890.92N 1275.82W 6009742.00 583101.69 4094.75@341.85 4094.75 0.00 0.00 0.00 0.00 0.00 52.0 3777.70N 1287.9zgvV 149.40 38.42 71.85 29.83 BPHM-PBD 0.00 52.0 3890.85N 1275.8Ohr 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 52.0 3876.04N 1321.22W 153.19 39.48 71.85 30.49 BPHM-PBD S?X- SSe~ed Sepvi~._~ D~i/Un9 ii A[¢sk¢ S~ce Plane', Zone4 ~?~-5 (96K> Wp~ Ppekiminapy ~ ~ Tm avdti n 9 Cy[i n dem- Nora md Plan e ReFepence We[[ - MPK-5 (96K) Wpl MD: 0 - 8600 F~. ~n~e~vo[, 50 F~. a[[ D;~ec~ons usin~ BP Highslde Me~hod ~ L;nes ape ~he EXPECTED a~s~once Qpc[es ama ~he B.P. FLBWING/SHUT-~N condition 300 ,i ? :: :: ii a40 210 i/ :; / i HALLIBURTBN /..,.~ .2 / / \ / 3/20/96 2:00 pm 0 700 650 600 550 500 450 400 350 300 250 3O 6O 180 -: 120 Da%e Pto~ed Cheated By Checked By Appnoved By Da~e 3/20/96 Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.1 Page 1 Date: 3/20/96 Time: 2:00 pm Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-5 Est MPK-5 (96K) Wpl Preliminary N/S and F_JW are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 8600.15 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Flowing Shut-in Enter Well Safety Min. Safety Safety Shut-in Clear Spread MD TVD Dist Dist Zone MD MPK-17 MWD 66.0 79.1 1050 1050 15.8 2.6 MPK-17 Wp3 68.2 81.3 1050 1050 15.8 2.6 MPK-38 Wpl 243.1 256.2 1050 1050 15.8 2.6 MPK-37 Wpl 218.7 231.8 1050 1050 15.8 2.6 MPK-25 MWD 124.8 136.0 900 900 13.5 2.2 MPK-25 Wp2 128.0 141.2 1050 1050 15.8 2.6 MPK-18 Wpl 120.7 133.8 1050 1050 15.8 2.6 MPF-10 Wpl 92.7 105.8 1050 1050 15.8 2.6 MPK-09 (96 1.0 19.2 1450 1449 21.8 3.6 1550 Enter Exit Exit Close Danger Danger Shut-in Approach Zone Zone Zone Status MD MD MD 1750 OK OK OK OK OK OK OK OK SHUT-IN Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.1 Page 1 Date: 3/20/96 Time: 2:01 pm Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-5 Est MPK-5 (96K) Wpl Preliminary N/S and F_JW are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 8600.15 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Closest Points Slot Wellpath Distance MPK-17 As-Built MPK-17 MWD 88.25 97.08 MPK- 17 As-Built MPK- 17 Wp3 90.25 101.24 MPK-38 Est MPK-38 Wpl 264.67 480.74 MPK-37 Est MPK-37 Wpl 240.33 393.63 MPK-25 As-Built MPK-25 MWD 143.99 175.22 MPK-25 As-Built MPK-25 Wp2 149.74 180.02 MPK-18 Est MPK-18 Wpl 142.35 3491.80 MPK-10 Est MPF-10 Wpl 114.87 2819.74 MPK-9 Est MPK-09 (96F) Wp2 30.26 37.13 Direction Ref MD Ref TVD Sep Factor 152.28 1000.00 1000.00 13.9 151.79 1350.00 1349.78 12.3 157.94 0.00 0.00 56410.8 158.36 1350.00 1349.78 12.8 133.51 0.00 0.0C973078528.0 146.58 2350.00 2328.35 29.1 158.14 0.00 0.,-1879572480.0 159.51 2150.00 2138.33 28.2 158.41 850.00 850.00 25.8 161.93 1400.00 1399.65 21.3 157.56 0.00 0.00 54008.0 158.27 1550.00 1548.91 20.2 107.81 0.00 0.¢1870921728.0 121.31 6100.00 5238.96 17.5 83.65 0.00 0.¢1911816192.0 78.33 8350.00 6974.17 8.9 156.45 0.00 0.C1956118528.0 188.98 1750.00 1746.68 3.4 Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 1 Date: 3/20/96 Time: 1:32 pm Wellpath ID: MPK-5 (96K) Wpl Last Revision: 3/20/96 Survey Reference: WELLHEAD Reference World Coordinates: Lat. 70.25.33 N - Long. 149.18.43 W Reference GRID System: Alaska State Plane Zone: Alaska 4 Reference GRID Coordinates: (ft): 6005866.00 N 584421.00 E North Aligned To: TRUE NORTH Vertical Section Reference: WELLHEAD Closure Reference: WELLHEAD TVD Reference: WELLHEAD Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.2.1 Vertical Section Plane: 341.85 deg. BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-5 Est MPK-5 (96K) Wpl Preliminary Measured Incl Drift Subsea TVD Course T O T A L Depth Dir. DePth Length Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) (ft) GRID Coordinates Northing Easting (ft) (ft) TIE IN 0.00 0.00 0.00 -61.00 0.00 0.00 0.00N KOP / START OF BUILD @ 1.00 deg/100 ft 1000.00 0.00 0.00 939.00 1000.00 1000.00 0.00N 1100.00 1.00 341.85 1038.99 1099.99 100.00 0.83N 0.00E 6005866.00 584421.00 0.00E 6005866.00 584421.00 0.27W 6005866.83 584420.72 Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/lOOft) (dg/lOOft) (dg/lOOft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 0.0C@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.00 0.0C@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 3.17 0.87@341.85 0.87 1.00 0.00 1.00 1.0 0.83N 0.27N 3.38 0.00 0.00 0.00 MWD 3.17 0.00 1.41 BPHM-PBD 3.38 71.85 1.56 BPHM-PBD 1200.00 2.00 341.85 1138.96 1199.96 100.00 3.32N START OF BUILD @ 1.50 deg/100~ 1300.00 3.00 341.85 1238.86 1299.86 100.00 7.46N 1400.00 4.50 341.85 1338.65 1399.65 100.00 13.68N 1.09N 6005869.31 584419.87 2.45W 6005873.43 584418.47 4.48W 6005879.62 584416.36 3.4¢@341.85 3.49 1.00 0.00 1.00 2.0 3.32N 1.0OW 3.60 7.85@341.85 7.85 1.00 0.00 1.00 3.0 7.46N 2.45W 3.83 14.3~@341.85 14.39 1.50 0.00 1.50 4.5 13.67N 4.5CW 4.09 3.59 71.85 1.71 BPHM-PBD 3.81 71.85 1.87 BPHM-PBD 4.03 71.85 2.03 BPHM-PBD 1500.00 6.00 341.85 1438.22 1499.22 100.00 22.37N START OF BUILD @ 2.00deg/100~ 1600.00 7.50 341.85 1537.53 1598.53 100.00 33.54N 1700.00 9.50 341.85 1636.42 1697.42 100.00 47.58N 7.33W 6005888.29 584413.41 23.54@341.85 23.54 1.50 0.00 10.9~¥ 6005899.41 584409.63 35.3¢@341.85 35.30 1.50 0.00 15.6C~r 6005913.40 584404.86 50.08@341.85 50.08 2.00 0.00 1.50 6.0 22.36N 7.3TN 4.38 1.50 7.5 33.52N 11.0fiW 4.73 2.00 9.5 47.55N 15.72W 5.15 4.26 71.85 2.19 BPHM-PBD 4.49 71.85 2.37 BPHM-PBD 4.72 71.85 2.55 BPHM-PBD END OF BUILD 1725.00 10.00 341.85 1661.06 1722.06 25.00 51.61N Base Permafrost 1815.31 10.00 341.85 1750.00 1811.00 90.31 66.51N START OF CURVE @ 2.50 deg/100 ft 1925.00 10.00 341.85 1858.02 1919.02 109.69 84.61N 16.92rxV 6005917.41 584403.50 54.31@341.85 54.31 2.00 0.00 21.8CW 6005932.25 584398.45 69.9¢@341.85 69.99 0.00 0.00 27.74W 6005950.28 584392.31 89.04@341.85 89.04 0.00 0.00 2.00 10.0 51.56N 17.05W 0.00 10.0 66.45N 21.98W 0.00 10.0 84.53N 27.98W 5.27 5.71 6.28 4.78 71.85 2.60 BPHM-PBD 5.01 71.85 2.74 BPHM-PBD 5.30 71.85 2.92 BPHM-PBD 2025.00 12.50 341.85 1956.10 2017.10 100.00 103.15N 2125.00 15.00 341.85 2053.22 2114.22 100.00 125.73N 2225.00 17.50 341.85 2149.22 2210.22 100.00 152.32N 33.81W 6005968.75 584386.02 108.55@341.85 108.55 2.50 -0.00 41.22W 6005991.25 584378.37 132.31@341.85 132.31 2.50 -0.00 49.93W 6006017.73 584369.35 160.2¢@341.85 160.29 2.50 -0.00 2.50 12.5 103.04N 34.14W 2.50 15.0 125.58N 41.6fiW 2.50 17.5 152.12N 50.55W 6.92 7.68 8.59 5.54 71.85 3.14 BPHM-PBD 5.79 71.85 3.39 BPHM-PBD 6.04 71.85 3.66 BPHM-PBD 2325.00 20.00 341.85 2243.90 2304.90 100.00 182.86N 2425.00 22.50 341.85 2337.10 2398.10 100.00 217.30N 2525.00 25.00 341.85 2428.62 2489.62 100.00 255.56N 59.95W 6006048.15 584358.99 192.44@341.85 192.44 2.50 -0.00 71.24W 6006082.46 584347.31 228.68@341.85 228.68 2.50 -0.00 83.7¢W 6006120.58 584334.34 268.95@341.85 268.95 2.50 -0.00 2.50 20.0 182.59N 60.77W 9.65 2.50 22.5 216.94N 72.33W 10.87 2.50 25.0 255.10N 85.2CW 12.25 6.30 71.85 3.95 BPHM-PBD 6.56 71.85 4.27 BPHM-PBD 6.84 71.85 4.62 BPHM-PBD 2625.00 27.50 341.85 2518.30 2579.30 100.00 297.59N 97.57W 6006162.44 584320.08 313.17@341.85 313.17 2.50 -0.00 2.50 27.5 297.00N 99.3Ohr 13.79 7.13 71.85 4.99 BPHM-PBD WELL PERMIT CHECKLIST FIELD & POOL [] dev~ redrll [] aery [] PROGRAM: exp UNIT# ON/OFF SHORE wellbore seg [] ADMINISTRATION ENGINEERING 5. 6. 7. 8. 9. 10. 12. 13. REMARKS 1. Permit fee attached. ' ..... ~ N ~ 2. Lease number appropriate ................ ~ N UI'_ ~1 ~ ~ ~, ti (~ k ~ 3. Unique well name and number ............... (~- N '1 4. Well located in a defined pool ............. .~ N ~ ~ . f~ u~ .~,' ~ ~- ~ ~, Well located proper distance from drlg unit boundary.. ~ N Well located proper distance from other wells ...... ~ N Sufficient acreage available in drilling unit ...... N If deviated, is wellbore plat included ........ ~ ~ N Operator only affected party .............. ~ N Operator has appropriate bond in force ......... ~N Permit can be issued without conservation order ..... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ........ F~ N 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 abndnmnt been approved. 22. Adequate wellbore separation proposed. 23. If diverter required, is it adequate. 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~O~D~I) psig4.3W 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures..~~'~ 32. Seismic analysis of shall~ ........ .Y. .N. 33. Se~__off-shore) . . ..- .... .Y..N. DATE. 34. name/phone for weekly progress reports ..... Y N GEOLOGY: RPC ~, ENGINEERING: BEW JDN ~ TAB HOWlljb - A:~,FORMS\cheklist rev 11195 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. Logging Services -±Jape Subfile 2 is type: L_~ TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPK - 05 500292267000 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 19-SEP-96 6653.01 D. BARBA J. FOX 3 12N liE 3732 2133 61.00 27.60 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 3823.0 PRODUCTION STRING 7.000 8620.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ GRCH GR GRCH 1 1 10-AUG-96 WESTERN ATLAS LOGGING SERVICES REMARKS: GR/CCL: MARKED LINE. EQUIVALENT UNSHIFTED DEPTH 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 30.0 8565.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NIIMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPK - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 135 Tape File Start Depth = 25.000000 Tape File End Depth = 8570.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34183 datums Tape Subfile: 2 219 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE 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): START DEPTH STOP DEPTH 30.0 8577.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR PCM GR $ PULSE CODE MODULATOR GAMMA RAY 10-AUG-96 FSYS REV. J001 VER. 1.1 0637 10-AUG-96 8558.0 8574.0 30.0 8569.0 3600.0 YES TOOL NUMBER 8250EA/8248EA 8220XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 0.000 8620.0 0.0 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) : BRINE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZIR WINDOW (FT) : ~. 0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : MPK - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 683 Tape File Start Depth = 30.000000 Tape File End Depth = 8565.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 170706 datums Tape Subfile: 3 757 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 4 is type: LIS 96/ 9/~9 01 **** REEL TRAILER **** 96/ 9/~9 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 19 SEP 96 3:32p Elapsed execution time = 6.15 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... * ............................ * COMPANY NAME : B. P. EXPLORATION WELL NAME : MPK-05 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 50-029-22670-00 REFERENCE NO : 96165 RECEIVED SEP 05 1996 Alaska Oil & Gas Co~s, Corr~ission ~chorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09: ~ PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/28 ORIGIN : FLIC REEL NAME : 96165 CONTINUATION # : PREVIOUS REEL : COI~4ENT : BP EXPLORATION, MILNE POINT MPK-05, API # 50-029-22670-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/28 ORIGIN : FLIC TAPE NAME : 96165 CONTINUATION # : 1 PREVIOUS TAPE : CONk4ENT : BP EXPLORATION, MILNE POINT MPK-05, API# 50-029-22670-00 TAPE HEADER MILNE POINT ~WD/MAD LOSS 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 RUN 1 96165 RCR/JWPB ANSLEN WELL CASING RECORD 1ST STRING 2NDSTRING MPK-05 500292267000 B. P. Exploration SCHLUMBERGER WELL SERVICES 26-AUG-96 BIT RUN 2 96165 RCR/JWPB ANGLEN BIT RUN 3 3 12N liE 3732 2133 61.20 60.20 31. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3821.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ 3RD STRING PRODUCTION STRING Well drilled 10-APR through 17-APR-96 with CDR/CDN. Data was collected in a two bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/28 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: 0.5000 FILE SUF~rlARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 3715.0 8639.5 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (M~ASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ No depth adjustments were made as per Matt Linder. This file also contains the Very Enhanced QRO resistivity with 2' average that was reprocessed at GeoQuest. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD BIT RUN NO. MERGE TOP MERGE BASE 1 3715.0 8134.5 2 8134.5 8639.5 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 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 NUAIB SAMP ELE~ CODE (HEX) DEPT FT 630365 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OP~4 630365 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OPi~ 630365 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OP~ 630365 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~I4 630365 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OPi~ 630365 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630365 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630365 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630365 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 630365 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO MWD G/C3 630365 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630365 O0 000 O0 0 1 1 1 4 68 0000000000 CALN MWD IN 630365 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI MWD PU-S 630365 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8639.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 31.034 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CAIxN. MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~u PAGE: DEPT. 3715.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN. MWD -999.250 NPHI.MWD -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRItO.MWD 51.800 -999.250 -999.250 -999.250 VRA . MWD FET.MWD PEF.MWD -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: No depth shifting done as per Matt Linder. MAD data aquired as wash down at beginning of bit run 2. $ START DEPTH STOP DEPTH 7996.0 8575.0 MAD RUNNO. MAD PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630365 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD 0HI~630365 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD OH~ 630365 O0 000 O0 0 2 1 1 4 68 0000000000 VRA MAD OH~ff4 630365 O0 000 O0 0 2 1 1 4 68 0000000000 VRP MAD OH~E4630365 O0 000 O0 0 2 1 1 4 68 0000000000 DER MAD Ot~4M 630365 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR 630365 O0 000 O0 0 2 1 1 4 68 0000000000 FET MAD HR 630365 O0 000 O0 0 2 1 1 4 68 0000000000 GR MAD GAPI 630365 O0 000 O0 0 2 1 1 4 68 0000000000 RHOBMAD G/C3 630365 O0 000 O0 0 2 1 1 4 68 0000000000 DRHOMAD G/C3 630365 O0 000 O0 0 2 1 1 4 68 0000000000 PEF MAD BN/E 630365 O0 000 O0 0 2 1 1 4 68 0000000000 CALNMAD IN 630365 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI MAD PU-S 630365 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8575.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 296.199 FET.MAD GR.MAD -999.250 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD CALN.MAD -999.250 NPHI.MAD -999.250 -999.250 -999.250 -999.250 LIS Tape Verm~ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: DEPT. 7996.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 FET.MAD GR.MAD -999.250 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD CALN. MAD -999.250 NPHI.MAD 50.500 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH MAD 7996.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH .......... 8575.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD ....... REMARKS: No depth shifting done as per Matt Linder. MAD data LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: aquired as wash down at beginning of 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 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630365 O0 000 O0 0 3 1 1 4 68 0000000000 RA MAD OPff4M630365 O0 000 O0 0 3 1 1 4 68 0000000000 RP MAD OH~M 630365 O0 000 O0 0 3 1 1 4 68 0000000000 VRA MAD OH~ 630365 O0 000 O0 0 3 1 1 4 68 0000000000 VRP MAD OH~4M 630365 O0 000 O0 0 3 1 1 4 68 0000000000 DER MAD OH~ 630365 O0 000 O0 0 3 1 1 4 68 0000000000 ROP MAD FPHR 630365 O0 000 O0 0 3 1 1 4 68 0000000000 FET MAD HR 630365 O0 000 O0 0 3 1 1 4 68 0000000000 GR MAD GAPI 630365 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB MAD G/C3 630365 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO MAD G/C3 630365 O0 000 O0 0 3 1 1 4 68 0000000000 PEF MAD BN/E 630365 O0 000 O0 0 3 1 1 4 68 0000000000 CALN MAD IN 630365 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI MAD PU-S 630365 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: ** DATA ** DEPT. 8575.000 RA.MAD VRP.MAD -999.250 DER.MAD GR.MAD -999.250 RHOB.MAD CALN. MAD -999.250 NPHI.MAD -999.250 RP.MAD -999.250 ROP.MAD -999.250 DRHO.MAD -999.250 -999.250 296.199 -999.250 VRA . MAD FET.MAD PEF.MAD -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE I~TJMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 3714.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TItlE): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 8134.5 17-APR-96 FAST 2.5-005B 4.1 MEMORY 8640.0 3714.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RES I STIVI TY/GR CDN DENS I TY/NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8640.0 85 42.3 TOOL NUMBER ........... RGS751 NDS055 8.500 3821.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S) : 52.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): 5.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT M~ASURED TEMPERATURE (MT)'. 2.810 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 410 MTrD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 1.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: **** RUN1 3840' - 8135' **** RES TO BIT: 64.30'; GR TO BIT: 74.72' DEN TO BIT: 119.52'; NEUT TO BIT: 126.50' **** RUN2 8575' - 8640' **** RES TO BIT: 11.39'; GR TO BIT: 21.81' DEN TO BIT: 66.68'; NEUT TO BIT: 73.66' WASP~DOWN INTERVAL 8070' - 8575' MAXIMUM DEVIATION 42.29 DEG AT 5010' $ LIS FORMAT DATA 80.0 80.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD ~ S~2.IP ELI~ CODE (HEX) DEPT FT 630365 O0 000 O0 0 4 1 1 4 68 0000000000 RA LW1 OH~ 630365 O0 000 O0 0 4 1 1 4 68 0000000000 RP LW1 0H~94 630365 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW1 OH~M 630365 O0 000 O0 0 4 1 1 4 68 0000000000 ROP LW1 FPHR 630365 O0 000 O0 0 4 1 1 4 68 0000000000 FET LW1 HR 630365 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW1 GAPI 630365 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LW1 G/C3 630365 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LW1 G/C3 630365 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LW1 BN/E 630365 O0 000 O0 0 4 1 1 4 68 0000000000 CALN LWI IN 630365 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI LW1 PU-S 630365 O0 000 O0 0 4 1 1 4 68 0000000000 * * DA TA * * DEPT. 8134. 500 RA. LW1 -999. 250 RP. LW1 -999. 250 DER. LW1 ROP.LW1 61.858 FET.LW1 -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO.LW1 -999.250 PEF.LW1 -999.250 CALN. LW1 -999.250 NPHI.LW1 DEPT. 3714.500 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 ROP.LW1 -999.250 FET.LW1 -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO.LW1 -999.250 PEF. LW1 -999.250 CALN. LW1 -999.250 NPHI.LW1 -999.250 -999.250 -999.250 -999.250 -999.250 52.600 LIS Tape Ver~. ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: 11 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION . O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NLTI4BER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 8501.0 8639.5 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~iE) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 17-APR-96 FAST 2.5-005B 4.0 MEMORY 8640.0 3714.5 8640.0 85 42.3 LIS Tape Ver~£ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 PAGE: 12 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY/GR CDN NEUTR ON~DENS I TY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : TOOL NUMBER RGS055 NDS055 8.500 3821.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S) : 52.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): 5.0 RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 810 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 410 MUD CAKE AT (MT): O. 000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 1.0 REMARKS: **** RUN1 3840' - 8135' **** RES TO BIT: 64.30'; GR TO BIT: 74.72' DEN TO BIT: 119.52'; NEUT TO BIT: 126.50' **** RUN2 8575' - 8640' **** RES TO BIT: 11.39'; GR TO BIT: 21.81' DEN TO BIT: 66.68'; NEUT TO BIT: 73.66' WASPZDOWN INTERVAL 8070' - 8575' MAXIMUM DEVIATION 42.29 DEG AT 5010' $ LIS FORMAT DATA 80.0 80.0 0.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Ver~£ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~ PAGE: 13 TYPE REPR CODE VALUE 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630365 O0 000 O0 0 5 1 1 4 68 0000000000 RA LW2 OH~4M 630365 O0 000 O0 0 5 1 1 4 68 0000000000 RP LW2 OPff4~630365 O0 000 O0 0 5 1 1 4 68 0000000000 DER LW2 OH~ 630365 O0 000 O0 0 5 1 1 4 68 0000000000 ROP LW2 FPHR 630365 O0 000 O0 0 5 1 1 4 68 0000000000 FET LW2 HR 630365 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW2 GAPI 630365 O0 000 O0 0 5 1 1 4 68 0000000000 RHOB LW2 G/C3 630365 O0 000 O0 0 5 1 1 4 68 0000000000 DRHO LW2 G/C3 630365 O0 000 O0 0 5 1 1 4 68 0000000000 PEF LW2 BN/E 630365 O0 000 O0 0 5 1 1 4 68 0000000000 CALNLW2 IN 630365 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI LW2 PU-S 630365 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 8639.500 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 ROP.LW2 31.034 FET. LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO.LW2 -999.250 PEF. LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 DEPT. 8501.000 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 ROP.LW2 -999.250 FET.LW2 -999.250 GR.LW2 -999.250 RHOB.LW2 DRHO. LW2 -999.250 PEF. LW2 -999.250 CALN. LW2 -999.250 NPHI. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 34.600 ** END OF DATA ** LIS Tape Ver~£ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 PAGE: 14 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SU~ViARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8070.0 8575.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~ORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CDR RES I STIVI TY/GR CDN NEUTRON/DENSITY 17-APR-96 FAST 2.5-005B 4.0 MEMORY 8640.0 3714.5 8640.0 85 42.3 TOOL NUMBER ........... RGS055 NDS055 LIS Tape Ver~£ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~0 PAGE: 15 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 3821.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.10 MUD VISCOSITY (S) : 52.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): 5.0 RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 810 MUD AT MAX CIRCULATIONG T~PERATURE : MUD FILTRATE AT (MT): 2. 410 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 1.0 REMARKS: **** RUN1 3840' - 8135' **** RES TO BIT: 64.30'; GR TO BIT: 74.72' DEN TO BIT: 119.52'; NEUT TO BIT: 126.50' **** RUN2 8575' - 8640' **** RES TO BIT: 11.39'; GR TO BIT: 21.81' DEN TO BIT: 66.68'; NEUT TO BIT: 73.66' WASI{DOWN INTERVAL 8070' - 8575' MAXIMUM DEVIATION 42.29 DEG AT 5010' $ LIS FORMAT DATA 80.0 80.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 LIS Tape Ver=£ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~0 PAGE: 16 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 630365 O0 000 O0 0 6 1 1 4 68 0000000000 RA MAi OHMM 630365 O0 000 O0 0 6 1 1 4 68 0000000000 RP MAi OH~M 630365 O0 000 O0 0 6 1 1 4 68 0000000000 DER MAi OHM~ 630365 O0 000 O0 0 6 1 1 4 68 0000000000 ROP MAi FPHR 630365 O0 000 O0 0 6 1 1 4 68 0000000000 FET MAi HR 630365 O0 000 O0 0 6 1 1 4 68 0000000000 GR MAi GAPI 630365 O0 000 O0 0 6 1 1 4 68 0000000000 RHOB MAi G/C3 630365 O0 000 O0 0 6 1 1 4 68 0000000000 DRHO MAi G/C3 630365 O0 000 O0 0 6 1 1 4 68 0000000000 PEF MAi BN/E 630365 O0 000 O0 0 6 1 1 4 68 0000000000 C ~ALNMAi IN 630365 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI MAi PU-S 630365 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 8575.000 RA.MA1 -999.250 RP.MA1 -999.250 DER.MAi ROP.MA1 296.199 FET.MA1 -999.250 GR.MA1 -999.250 RHOB.MA1 DRHO.MA1 -999.250 PEF.MA1 -999.250 CALN.MA1 -999.250 NPHI.MA1 DEPT. 8070.000 RA.MA1 -999.250 RP.MA1 -999.250 DER.MAI ROP.MA1 -999.250 FET.MA1 0.061 GR.MA1 -999.250 RHOB.MA1 DRHO.MA1 -999.250 PEF.MA1 -999.250 CALN. MA1 -999.250 NPHI.MA1 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Ver=£ication Listing Schlumberger Alaska Computing Center 28-AUG-1996 09:~d PAGE: 17 ** * * FILE TRAILER * * * * FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/08/28 ORIGIN : FLIC TAPE NAME : 96165 CONTINUATION # : 1 PREVIOUS TAPE : CO~ENT .. BP EXPLORATION, MILNE POINT MPK-05, API# 50-029-22670-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/08/28 ORIGIN .. FLIC REEL NAME : 96165 CONTINUATION # : PREVIOUS REEL : COhErENT : BP EXPLORATION, MILNE POINT MPK-05, API# 50-029-22670-00 WESTERN ATLAS 10' 3827' Logging Services Tape Su~file' 2 is type: ~IS TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MPK-05 500292267600 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 07 -AUG- 96 6653.00 B. ESARY T. ANGLEN 3 12N 11E 3732 2133 61.00 27.67 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 20.000 80.0 91.10 12.250 9.625 3823.0 40.00 8.500 8575.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS GR GRCH 1 1 15-APR-96 WESTERN ATLAS LOGGING SERVICES ......... EQUIVALENT UNSHIFTED DEPTH ......... PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: SBT/GR - Marked Line. LOG TIED INTO: WIRELINE MARKS. *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** SHIFT PROCEDURE AS FOLLOWS: 1) SECOND PASS GAMMA RAY DEPTH MATCHED TO FIRST PASS GAMMA RAY. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10.0 3790 . 0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... PASS i (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPK - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F i Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 4 4 30 995 99 1 * DATA RECORD (TYPES 0) Total Data Records: 60 1022 BYTES * Tape File Start Depth = 10.000000 Tape File End Depth = 3795.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15143 datums Tape Subfile: 2 152 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 3570.0 3760.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: i ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH GRCH 3573.5 3575.0 3574.0 3575.5 3590.0 3590.5 3595.0 3595.5 3663.5 3665.0 3664.0 3665.5 3665.0 3666.0 3676.0 3676,5 3682.5 3683.0 3683.0 3684.0 3752.0 3753.0 3753.5 3754.5 REMARKS: PASS 2 (REPEAT PASS). / ? ?MATCH2A. OUT $ CN : BP EXPLORATION WN : MPK - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 66 1 GAPI 4 * DATA RECORD (TYPE~ 0) Total Data Records: 1022 BYTES * mmmmmmm 30 995 99 Tape File Start Depth = 3565.000000 Tape File End Depth = 3765.000000 Tape File Level Spacin~ = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 803 datums 47 records... 62 bytes 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3' RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10.0 $ 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 CCL GR ACOM SBT VDL CENT $ STOP DEPTH 3795.0 CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER 15-APR-96 FSYS REV. J001 VER. 1.1 1839 15-APR-96 8575.0 3835.0 10.0 3827.0 1200.0 YES TOOL NUMBER 2330NA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): 0.000 3823.0 0.0 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): MUD 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX- · MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELiNE COUNT RA ~ NORMALIZATION IN OIL ZON= TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1 (MAIN PASS) $ CN : BP EXPLORATION WN : MPK - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves'. Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 1 1 F/MN 1 LB 4- 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 303 Tape File Start Depth = 10.000000 Tape File End Depth = 3795.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 90849 datums Tape Subfile-. 4 379 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3570.0 $ 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): STOP DEPTH 3766.0 15-APR-96 FSYS REV. J001 VER. 1.1 1601 15-APR-96 8575.0 3835.0 10.0 3827.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ CASING CO~ LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB- CENTROLLER TOOL NUMBER 2330NA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 3823.0 0.0 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): MUD 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUEL~NE COUNT RATE NORMALIZATION IN OIL ZON~ TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0,0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2 (REPEAT PASS) $ CN : BP EXPLORATION WN : MPK - 05 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPES 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 1 I F/MN 1 LB 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 16 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 16 Tape File Start Depth = 3570.000000 Tape File End Depth = 3765.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4709 datums Tape Subfile: 5 Minimum record length: Maximum record length: 92 records... 62 bytes 1006 bytes Tape Subfile 6 is type: LIS O1 **** REEL TRAILER **** 96/ 8/ 8 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 8 AUG 96 11:37a Elapsed execution time = 10.49 seconds. SYSTEM RETURN CODE = 0