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Home My WebLink About201-223RECEIVED By Meredith Guhl at 2:16 pm, Mar 02, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas[-] SPLUG ❑ Other ❑ Abandoned 0 Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 0 1b. Well Class: Development 0 Exploratory ] Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp North Slope, LLC 6. Date Comp., Susp., or Aband.: 2/22/2022 14. Permit to Drill Number / Sundry: 201-223 / 321-595 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 1/3/2002 15. API Number: 50-029-23055-00-00 4a. Location of Well (Governmental Section): Surface: 2420' FSL, 3559' C\�AN , Sec. 34, T12N, R11E, UM, AK Top of Productive Interval: FEL DLB 2544' FSL, 1802' FEL, Sec. 34, T12N, R11 E, UM, AK Total Depth: 2546' FSL, 1799' FEL, Sec. 34, T12N, R11 E, UM, AK 8. Date TD Reached: 1/9/2002 16. Well Name and Number: PBU L-106 9. Ref Elevations: KB: 79.22' GL: 50.4' BF: 17. Field / Pool(s): Prudhoe Bay Field / Borealis Oil Pool 10. Plug Back Depth MD/TVD: 6,938' / 6,584' 18. Property Designation: ADL 028239 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 583357 y- 5978143 Zone-4 TPI: x- 585112 y- 5978287 Zone-4 Total Depth: x- 585115 y- 5978290 Zone-4 11. Total Depth MD/TVD: 7,455' / 7,101' 19. DNR Approval Number: 00-001 12. SSSV Depth MD/TVD: None 20. Thickness of Permafrost MD/TVD: 1900' (Approx.) 5. Directional or Inclination Survey: Yes❑ (attached) No 0 Submit electronic information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD, GR, RES, DEN, NEU, Dipole Sonic, MDT, CCL, RIFT, USIT 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5 H-40 29' 109, 29' 109, 42" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 28' 2,726' 28' 2,653' 9-7/8" 359 sx AS Lite, 134 sx Class 'G' 5-1/2" 1 15.5# / 9.2# L-80 26' 7,444' 26' 7,090' 6-3/4" 217 sx Class 'G' x3-1/2" 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Abandonded 2/22/2022 MDG 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2" 9.2# L-80 6684' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes E] No E Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6,938' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period Oil-BbI: Gas-MCF: Water-BbI: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate Oil-BbI: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Sr Pet EngMGR09MAR2022 Sr Pet Geo DLB 04-26-2022 ISr Res Eng XV Form 10-407 Revised 3/2020 RBMDS 03/02/2022 MDG Submit within 30 days of Completion, Suspension, or Abandonment 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6930' 6576' information, including reports, per 20 AAC 25.071. Schrader Bluff M 4192' 3981' Schrader Bluff N 4467' 4227' Schrader Bluff O 4640' 4381' Base Schrader / Colville 5056' 4760' CM1 5969' 5621' H RZ 6568' 6214' Kalubik 6795' 6441' Kuparuk D 6914' 6560' Kuparuk C 6930' 6576' LCU / Kuparuk B 7102' 6748' Kuparuk A 7235' 6881' Miluveach 7313' 6959' Formation at total depth: Miluveach 7313' 6959' 31. List of Attachments: Summary of Pre -Rig Work, Daily Drilling Reports, Wellbore Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolociical report, reduction or well test results er 20 AAC 25.070. 32. 1 hereby certify that the foreqoinq is true and correct to the best of my knowledqe. Authorized Name: Monty M ers Contact Name: Joe Lastufka Authorized Title: Drilling Manager Contact Email: ose h.lastufka hilcor .com Authorized Monty M Diglt`^IyeigntyMMyen,c=US rs Contact Phone: 777-8400 -Mon Y M MYe,s, c= s oN =H .sp Alaska, LLC, ou=Technical 3. 2. 2 0 2 2 Signature w/Date: Services -AK Drilling, Myers Reon am"d.. Dade2022.03,0207:0806-9'00' INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Daily Report of Well Operations PBU L-106A ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL*** (CTD) CHANGE OUT FUEL PUMP ON UNIT WHILE SPINE ROAD IS CLOSED (Vehicle extraction). RIG TO MOVE SOME EQUIPMENT FROM IN FRONT OF WELL BEFORE WE MISU. 2/11/2022 ***JOB IN PROGRESS, CONTINUED ON 2/12/22 WSR*** 2/12/2022 LRS 70 Weather Standby ***CONTINUED FROM 2/11/22 WSR*** (CTD) POLLARD UNIT #60 COLD WEATHER STANDBY 2/12/2022 ***CONTINUED ON 12/13/22 WSR*** ***CONTINUED FROM 2/12/22 WSR*** (CTD) SET 3-1/2" X CATCHER SUB AT 6,712' SLM / 6736' MD. MADE THREE ATTEMPTS TO PULL INT-DGLV AT ST #1 (6,606' MD, Kept slipping off). BLED IA FROM 1400 PSI TO 1000 PSI TO CONFIRM INT-DGLV STILL IN POCKET. PULL INT-OGLV FROM ST #3 (3,663' MD). THUNDERBIRD CURRENTLY LOADING IA. 2/13/2022 ***JOB IN PROGRESS, CONTINUED ON 2/14/22 WSR*** T/I/O= 1850/1650/500 Assist SL (Load IA & TBG) Road to location. Rig up 2/13/2022 ***Job Continued on 02/14/2022*** 2/13/2022 LRS 70 Weather Standby ***Job Continued from 02/13/2022*** Assist SL (Load IA & TBG) Pumped 50 bbls DSL to load IA. Pumped 70 BBLs DSL to Load TBG. MIT-T ***PASSED*** to 4615 psi. Pumped 1 bbl DSL to achieve max applied PSI of 4750 psi. 1st 15 min TBG lost 125 psi. 2nd 15 min TBG lost 10 PSI. total loss of 135 psi. Bled back 0.7 bbls DSL. MIT -IA ***PASSED*** to 4626 psi. Pumped 3BBLS down IA to acheive M.A.P.of 4700 psi. 1 st 15 min IA lost 45 psi, 2nd 15 min IA lost 25 psi, 3rd 15 min IA lost 19 2/14/2022 psi Bled 3BBLS back from IA to 300 psi FWHP=2000/300/500 ***CONTINUED FROM 2/13/22 WSR*** (CTD) TB LOADED IA W/ 50 BBLS OF DIESEL. SET INT-DGLV AT ST #3 (3,663' MD). PULL EMPTY 3-1/2" X-CATCHER SUB FROM 6,712' SLM / 6,736' MD. THUNDERBIRD LOADED TUBING W/ 70 BBLS OF DIESEL. SET 3-1/2" XX PLUG IN X-NIPPLE AT 6,712' SLM / 6,736' MD. TB PERFORMED SUCCESSFUL MIT-T TO 4615 PSI (Bled back to 2000 psi). TB PERFORMED SUCCESSFUL MIT -IA TO 4626 PSI (2000 psi left on tbg during test). EQUALIZE & PULL 3-1/2" XX PLUG BODY FROM 6,712' SLM / 6,736' MD. DRIFT TO 6,942' SLM W/ 2.74" x 20' DUMMY WHIPSTOCK (Worked to 6,946' and - 4' scrape up the side). TAG HARD BOTTOM AT 6,985' MD W/ 2.50" S-BLR (Sample of frac sand & paraffin). 2/14/2022 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** T/I/O = 900/550/475. Remove 3-1/8" flow cross kill port flange. Install CTD kill line assembly, torque to API spec.PT tree assembly to 500 psi low/5000 psi high (pass). 2/15/2022 RDMO. Remove tree cap assembly & install tapped blind flange, torque to API spec. PT tree assembly to 500 psi low/5000 psi high. PT SV to 3500 psi to verify valve will meet 2/16/2022 BOP test criteria (Pass) Hilcorp Energy Company Composite Report Well Name: PBW L-106A Field: Prudhoe Bay West County/State: , Alaska API #: 50-029-23055-01-00 ctivity Date Ops Sum 2/1512022 Rig released from L-116A, continue troubleshooting Eline continuity issue. MU BHI Upper MWD to coil and test. Tool is functioning properly with no issues, LID tools. Continue WOW for pad prep, continue maintenance, housekeeping and painting Continue WOW for pad prep, continue maintenance, housekeeping and painting. Work on replacing Pump #1 pulsation dampener. Monthly service of shaker. Service Choke "B". Service HP filters and suction screens. Service both IDS and ODS tugger winches. 2/16/2022 Continue rig maintenance and repair while waiting on pad prep for next well. Complete changing pulsation dampener on Pump #1. Wrap coil reel in visqueen. Continue painting and cleaning. Complete pad prep. Complete well handover with Pad Operator. End wait time and begin rig move at 22:00 on 2/16/2022. Move rig modules and spot. Begin spotting pit module. Generator on pit module shut down. Trouble shoot. Generator repaired on pit module. Spot pit module and set down. LOTO L-105 and L-108. 2/17/2022 Accept Rig over L-106A at 05:00 on 2/17/2022. Begin RU checklists. Begin bringing on fluid. NU MPD line. NU Second Swab for additional height. NU BOPE. Measure BOPE and RKB for pressure deployment. Secure stack. Test rig H2S and LEL alarms. Rig up flowback tank and pressure test line. Onboard 290 bbls PowerPro. Complete RU checklist. MU and PU testjoint. Flush and fill all lines with fresh H2O. Flush Choke B and remove solids. Shell test BOPE. Begin BOPE test. Test witness was waived by AOGCC representative Guy Cook. Complete Test 1: IRV, Pack -off, C7, C9, C10 and C11 Pass. Complete Test 2: B/S, R2, B2, C15 Test 3 found Annular not holding any pressure. Cycle and increase pressure. Still not holding. Complete test 4,5,6 and Accumulator draw down test. Complete test 7 and 8. 2/18/2022 Open Annular and find significant cement from previous well. Clean and replace annular. Open all ram doors to inspect for cement. Proactively replace Blind/Shear ram inserts Continue removing cement from BOP ram cavities. Finish cleaning all BOP ram cavities. Replace door seals and close ram doors. RD Micro motion lines and clean residual cement. Inspect circulating lines with borescope and find additional cement. Begin RD circulating lines from BOP stack. 2/19/2022 Finish Out MM clean and clear. Pull choke and kill lines. Inspect test valves. Break apart and clean/clear cement MM and lines Fluid pack all lines and BOP stack with fresh water. Pump 30 bbl citric stage and flush with fresh water Grease and service all valves Stab on with injector and fluid pack all lines for shell test. 2/20/2022 Reverse circulate coil to flush. Line up to pressure test breaks on SR manifold. 3" connection on R6 line leaked. Replace gasket. Pressure test Cement manifold breaks to 4500#. No leaks. Isolate 5K side of manifold. Bring pressure up to 7000#. No Leaks. Prepare for shell test. Perform shell test against C-13 / C14 to 4000#. Drip coming from door seal on 2" upper pipe /slip and grease zirc. Bleed down and remove injector. Vac out stack. Remove drillers side 2" upper Pipe/ Slip ram. Clean door seal area. Reinstall. Shell test. No Leaks Test BOPE to 250 PSI low, 3500 psi high for a charted 5 min. each. Test with 2.0" and 2-3/8" Testjoints. Initial test waived by Guy Cook, Re -test waived by Matt Herrera. Test #1: IRV, Stripper, C7, C9, C10, C-11 Pass. Test #2: Blind/ Shear, R2, BL2, C15 Pass -Test #3: Annular (2"), TIW#2, B1, B4 - Pass. Test #4: Upper 2" Pipe/ Slip, TIW#1, B2, B3 - Pass. Test #5: Lower 2" Pipe/Slips, C5, C6, C8 and TV2. Test #6: Choke A and Choke C. Draw Down Test on Accumulator. Test #7: Upper Pipe Rams, C1, C4, TV 1. Test #8: 2 3/8" Pipe/Slips, C2, C3. Clear and clean rig floor. RD BOP test equipment. Test and chart PDL's to 3500 psi Re -torque all tree bolts. Install BHI floats and pressure test. Bleed off tree above master valve to ensure master is holding. PT BHI floats and pack off. Master is leaking. Call for Worley grease crew to service valve. Master holding. Deploy BHA#1: 2.75" Nozzle BHA. 2/21/2022 Worley greased master valve. Makeup BHA#1 with 2.75" Nozzle (7/8" Ball on seat). Bleed IA / CA while loading coil. Loaded coil with 10 bbls Meth. Pressure up well to 900#. Open master. Rih attempting to hold 900#. Pushing fluid away. Close choke and continue in hole. Log CCL log from 6800'. Log 20' pup above setting depth. -13' correction. to PDC log Rih and drift to 6960' MD. Did not tag. Circulate wellbore over to 1 %slick KCL. Continue circulating 1 % Slick KCL. Pump 10 bbls of HiVis. Chase with 8.8 ppg used PowerPro. Once mud 75% around. On 100% losses. Discuss with engineer. Regain returns. POOH OOH. Secure well and bleed down. LID nozzle BHA MU and pressure deploy NS packer whipstock. Test and confirm all tools and gyro working. Verify orientation and TF RIH to log, correct and set whipstock. Pump .35 bpm RIH and losess - 15 bph. Take survey @ 6151'. Log down for tie-in log from 6855' @ 5fpm. Correct -15'. Continue logging down to see RA tag near whipstock setting depth. Confirm on depth. Take final gyro survey before RIH through perfs WT CK = 33k puw. RIH to set whipstock. On depth at 6949.21'. PUH to get weight back @ 6949.05'. TOWS = 6938'iclose EDC and pressure up to set WS. 149 degree TF. See shear @ 3700 psi with WOB Set 6k down to confirm WS set. Pull up hole and pump IN 1.5 bpm, Out .3 bpm. Call Foreman and discuss options. Decide to swap well to Slick 1 % KCL. Pump Slick 1 % KCL. In 1.5 bpm, Out .5 bpm. At 55 bbls pumped returns 1:1. Recover 8,8ppg used PowerPro. POOH. In Rate = 1.56 bpm, Out Rate = 1.53 bpm 150 psi WHIP. OOH. Begin PUD whipstock setting BHA. 2/22/2022 Pressure un-deploy BHA#2. Break down tools. Install night cap and get pits prepared for Polyswell Polyswell spotting. Perform injectivity test with 1 % Slick KCL. 3bpm @ 550 psi. PJSM with everybody involved. Pull MP#1 suction screen and bypass HP screens. Mix 10 bbls of 3%KCL, Duovis Pill. Dump Polyswell on fly. Chase with freshwater. Place Poly swell at 3 bpm @ 550 Psi. On volume could see indication of Polyswell hitting perfs. Built to 700 psi at 8 bbls pushed into perfs. Shut pump down pump. Let Polyswell Hydrate for 1 hr. Attempt to build some squeeze pressure. No luck. 500 psi pumping away. Let soak for additional 30 min. No Luck. Setup to go mill window. Makeup and rih with window milling BHA. Log tie in from 6840' to 6892.77' -13.5' correction. Close EDC. Mill. Free Spin: 3022 psi @ 2.04 bpm. Rate in: 2.04 bpm, Rate out: 2.02 bpm. MW in: 8.4 ppg, MW out: 8.4 ppg. Dry tag @ 6940 md. Mill window f/6939.8' t/6945.81. Rate In = 1.9 bpm Rate Out = 1.8 bpm. 4000 psi circ pressure. Mill 10' of rathole f/ 6945.8' t/6955'j Make 5 reaming passes through window without issue. Dry drift window twice clean. Geo confirms formation sand in bottoms up sample. POOH to LID window mill and troubleshoot BHI. Losses over night - 8 bph. OOH - Begin pressure un- deploy window milling BHA. TREE= 3-1/8" CIWFLS V1ELLHEAD= 11" FMC ACTUATOR= BAKER INITIAL KB_ ELE 79.22' BF_ ELEV = 52.80' KOP = 1128' Max Angle = 2e @ 4519' Datum MD= 7034' DatumTVD= 6600' SS 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 1--1 2726' Minimum ID = 2.812" @ 2216' 3-1/2" CAMCO SSSVN L-1 06 3-1/2" TBG,�—EM656=5-9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 5-1/2" CSG, 15.5#, L-80 BTC, 6667' .0232 bpf, ID = 4.950" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 1" @6930' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I O NS z I SHOT I SQZ 2-12" 1 6 1 6930 - 6994 1 O/C 1 02/20/02 PBTD 7377' - 3-1/2" CSG, 9.2#, L-80, NSCT, 7444' .0232 bpf, ID = 2.992" X SAFETY NOTES: 2215' 1--� 3-1/2- CAMCO BP-6i SSSV N, ID = 2.812" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3663 3501 25 KBG2-9 DMY INT 0 02/14/22 2 6521 6167 3 KBG2-9 DMY INT 0 02/07/04 1 6606 6251 2 KBG2-9 DMY INT 0 01/17/02 6661' 3-1/2" BKR CND SLD SLV, ID = 2.812" 6665' BKR LOC SEAL ASSY, ID = 2.990" 6668' BKRSEAL RECEPTACLE ID = 4.00 6684' 3-1/2" BKR SEAL ASSY, ID = 2990" 6687' 4.75" X 3-1/2" XO, 6736' I--� 3-1/2" HES X NIP, ID = 2.813" 6758' I--� 3-1/2" HES X NIP, ID = 2.813" 6887- 20' PUP JT W / RA TAG 6938' — 3-1/2" NS PKR WHIPSTOCK 7114' 20' PUP JT W / RA TAG 7338'elm 3-1/2" HES M CIBP(SETON01/15/02) DATE I REV BY COMMENTS DATE REV BY COMMENTS 01/17/02 ORIGINAL COMPLETION 06/12/14 DU/JMD TREE C/O (06/06/14 02/01/02 CH/TP CORRECTIONS 03/1920 CJN/JMD GLV C/O 03/1720 0221/02 CWS/TLH ADD PERFS 022122 JKC/JMD GLV C/O 02/1422 0228/01 DAC/KK PERF DEPTH CORRECTION 022822 JNUJMD SET NS PKR WHIPSTOCK 10/14/07 KSB/SV GLV C/O 10/08/07 0423/13 JO/JMD GLV TVD CORRECTION BOREALIS UNIT WELL: L-106 PERMIT No: 2012230 API No: 50-029-23055 SEC 34, T12N, R11 E 2419' NSL & 3559' WEL Hilcorp North Slope, LLC STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Samantha Carlisle at 3:13 pm, Nov 18, 2021 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ■ • Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: Hllcorp North Slope, LLC 4. Current Well Class: 5. Permit to Drill Number: 201-223 ' Exploratory ❑ Develop • Stratigraphic ❑ Service ❑ 3. Address: 3800 Centerpoint Dr, Suite 1400, 6. API Number: 50-029-23055-00-00 Anchorage, AK 99503 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in thes pool? PBU L-106 Will planned perforations require a spacing exception? Yes ❑ No ■ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 028239 PRUDHOE BAY, BOREALIS OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7455 7101 7338 6984 2983 7338 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 29 - 109 29 - 109 1490 470 Surface 2698 7-5/8" 28 - 2726 28 - 2653 6890 4790 Intermediate Production 7418 5-1/2" x 3-1/2" 26 - 7444 26 - 7090 7000 / 10160 4990 / 10530 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6930 - 6994 6576 - 6640 3-1 /2" 9.2# L-80 24 - 6684 Packers and SSSV Type: No Packer Packers and SSSV MD (ft) and TVD (ft): No Packer No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Strastigraphic ❑ Development ■ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 1, 2022 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0' GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Monty M DN:cn=MontyMMyers,c- ers Contact Name: Trevor Hyatt DN: cn=Monty M Myers, c=US, Authorized Name and-Hilcorp Alaska, LLC,—Technical services - AI( Drilling, Digital Signature with Date: Monty Myers Myers Reason: m,il=,lama@pilvm.thistlocumen Contact Email: trevor.hyatt@hilcorp.com Contact Phone:777-8396 Authorized Title: Drilling Manager 11 . 18 .2 0 21 AOGCC USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I 321-595 Plug Integrity ❑ BOP Test d Mechanical Integrity Test ❑ Location Clearance ❑ Other: ROPE test to 3500 psi. Variance to 20 AAC 25.112(i) approved for alternate plug placement. Fully cemented production liner. RBDMS HEW 12/1/2021 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required: 10-407 Digitally signed by JessieL. Jessie L. Chmielowski APPROVED BY Approved By: Date: COMMISSIONER Date: Chmielowski Date:2021.11.3011:26:37 THEAOGCC 11�30�21 ' Comm.dts 11/30/2021TC-m- I Sr Pet EneGR26Nov21 I Sr Pet Geo SFD 11/19/2021 1 Sr Res Eng DSR-11/18/21 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: November 18, 2021 Hilcorp Re: PBU L-106 Sundry Request Sundry approval is requested to set a whipstock in L-106 as part of the drilling and completion of the proposed L-106A CTD lateral. Proposed plan for L-106A Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. See L-106A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. The rig will set a 3-1/2" whipstock. A 2.80" window + 10' of formation out of the 3-1/2" casing. The well will kick off drilling and land in the Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 2-3/8" L-80 solid liner and cemented in place. The well will be selectively perforated post rig (see future L-106A Perf Sundry). This completion will completely isolate and abandon the parent Kuparuk perfs. This Sundry covers plugging the existing Kuparuk perforations via the liner cement iob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre -Rig Work - (Estimated to start in January 2022): 1. Slickline: Dummy WS drift, MIT support a. Drift past whipstock setting location 2. Fullbore: MIT -IA to 4,500 psi and MIT-T to 4,500 psi 3. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: • Reference PBU L-106A PTD submitted in concert with this request for full details. • General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,983 psi 2. Set Whipstock ~ 6,938'MD 3. Mill Window Sundry 321-595 4. Drill Build and Lateral 5. Run and Cement Liner* PTD 221-101 6. Freeze Protect and RDMO 7. Set LTP* (if needed) and perforate post rig (see future L-106A Perf Sundry) * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 TRH= 3-118" CIWFLS WELLHEAD = 11" FMC ACTLOJOR= BAKERC NFI1AL KB_ ELE 79.27 BF. ELEV = 52.80' KOP = 1128' Max Angle = 28' Q 4519' Datum MD = 7034' Datum TV D = 6600' SS 7-518" CSG, 29.7#, L-80, C = 6.875" 1--� 2726' Minimum ID = 2.812" @ 2215' 3-1/2" CAMCO SSSVN 3-112" TBG, 9.2#, L-8D IST--M, fi665' .0087 bpf, ID=2.992" 112" CSG, 15_5#, L-80 BTC, fififiT .0232 bpf, U = 4.95T PERFORATION SLt:vMRY REF LOG: ANGLEAT TOP PERF: 1' ( 6930' Note- Refer to Production ❑B for historical pert data SIZE SPF NTERVAL Opn/Sgz I SHOT SOZ 2-112" 1 6 1 6930 - 6994 O 1 02120102 PBTD 737T 3-112" CSG, 9.2#, L-80, NSCT, 74dW .0232 bpf, ID = 2.992" L-106 SAFM NOTES: 2215' 1-13-112" CAMCO BP-6i SSSVN, U= 2.812" :NsF-Y>A. Z ■sri 1��► I�' Ca n14-� ST MD TV❑ DEV TYPE VLV LATCH PORT DATE 3 W63 3501 25 KBG2-9 SO INT 20 05/01/08 2 6521 6167 3 KBG2-9 WY INT 0 02/07104 1 660E 6251 2 KBG2-9 DIVY INT 0 01/17102 6661' 1--1 3-112" BKR CMD SLID SLV , ID = 2.812" 666�-1BKR LOG SEAL ASSY, Q= 2.990" 6668' BKRSEAL RE=ACLE, D = 4.00 6684' 3-112' BKR SEAL ASSY , 1)= 2.99T 6687' 4.75" X 3-112" XO, D = 2.992" 6736' 1-13-112" HES X NIP, ID = 2.813" 67W I--13-112" HES X NIP, ID = 2.813" 688T 1-129 PUP JT W 1 RA TAG 7114 —129 PUP JT W 1 RA TAG 'elm3-112" HES MCEP{SETON 01115102] ❑ATE REV BY COM4 34TS DATE REV BY ODU ENT-S 01/17/02 ORIGINAL COMPLETION 06112/14 DLVJMD TREE CIO (06/06114) 02/01/02 CWTP ooRRE)CTIONS 02/21/02 CAW LH ADD PERFS 02/28/01 DACJKK PELF DEPTH CORRECTION 10/14/07 KSBISV GLV C!O 10/08/07 1041231131 JOIJIVID I GLV TVDCORRECTION BOREALIS UNT WEL L-106 PERMTf No- '2012230 API No: 50-029-23055 SI-C: 34, T12N, R11 E 2419' NSL & 3559' WEL BP Exploration (Alaska) TREE _ WELLHEAD = 11' FMC ACTUATOR = RVrrIAL KB_ ELEI 79-22' BF. ELEV = 52.8D' KOP = 1128' Max Argk = .0 Datum MD = Dakrn TVD = 660D' SS SAFETY NOTES: PROPOSED L-10 REV 'I 7-518" CSG, 29.7#, L-80, U = 6.875" I--1 2726' Minimum ID = 2.812" tx@ 2216' 3-1/2" CAMC❑ SSSVN 3-112" TBG, 9.2#, L-80, 6T-M 6665' — .0087 bpf, D= 2.992" 5-112- CSG, 15.5#, L-80 BTC, 6667' .0232bpf, D=4.950" TOP OF LNR 691W 3-1/2" MONOBORE WHIPSTOCK L! !J 3-112' CSG, 9.2#, L-80, NSCT, .0232 bpf, D = 2.992' L_�938' 38' PERFORATION SUMMARY REF LOG - ANGLE AT TOP PERF: —° @ NDte_ Referto Production DB for Nstarical perrdata SIZE SPF I INTERVAL I ODrbfSaz I SHOT SQZ PBTD LNR, 6.5#, L-80 HYD511, . bpf, ID X 2215' 1--1 3-1 /2" CAMCD BP-6i SSSV K ID = 2.812" GAS LIFT MANDRELS ST MD TV DEV TYFE VLV LATCH PORT DATE 3 3663 3501 25 KBG2-91 SO INT 20 0510V 2 6521 6167 3 KBG2-9 DMY INT 0 02/07/04 1 6606 6251 2 KBG2-9 DW INT 0 01/17/02 6661' 3-1/2" BKR CMD SLD SLV, ID = 2.812" 6665' BKR LOC SEAL ASSY, ID = 2.990" 6668' BKRSEAL RECEPTACLE, ID = 4.00 6684' 3-112" BKR SEAL ASSY, 66$T 4.75" X 3-1/2" 6736' 3-112' HES X NIP, ID = 2.813' 67sr M3-1/2" HES X NIP, 10=2.813" 6910' 2.70- DEPLOYMENT SLEEVE, ID = 6387' H20' PUP JT W 1 RA TAG DATE . REV BY COMMENTS DATE REV BY COMMENTS 011171021 ORIGINAL COMPLETION / 1 CTD ST L406A 01/29/20 JMD BUILTPROPOSED 11/15/21 TH/JMD BUILT PROPOSED REV 1 BOREALIS UNIT WELL: L-106A PERMIT No: API No- 50-D29 23D55-D1 SEC 34, T12N, R11E 2419' NSL 8 3559' WEL BP Exploration (Alaska) am CDR2-AC BOP Schematic Date Quick Test Sub to Otis 1.1 ft 4-- Top of 7" Otis k 0.0 ft CDR2 Rig's Drip Pan Distances from top of riser Fill Line from HF2 Excluding quick -test sub Normally Disconn cted �- 3" HP hose to Micromotior Top of Annular 2.75 ft o0 C L Annular 3.40 ft Bottom Annular 4.75 ft CIL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B Kill Line CL 2-3/8" Pipe / Slip 9.54 ft f Ci_ 2.0" Pipe / Slips 10.40 ft Flow Tee 0 Master LDS LDS Ii --------r Ground Level Hydril 7 1116" Annular ir�nuriw�z 3" LP hose open ended to Flowline B3 B4 Choke Line TV1 TV2 T1 T2 Master I_1 OA PTD: 2012230 E-Set: 35229 David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 11 Anchorage, AK 99503 Hileorp North Slope, LLC Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Date: 06/ 14/ 2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: RECEIVED By Abby Bell at 3:24 pm, Jun 14, 2021 FTP Folder Contents: Log Print Files and LAS Data Files: Well API PTD # Log Date Log Type Log Vendor 09-05B 500292021502 219001 5/7/2021 SCMT SCHLUMBERGER 13-19 500292069000 181180 5/4/2021 SCMT SCHLUMBERGER C-29B 500292147202 214049 1/26/2021 SCMT SCHLUMBERGER E-17A 500292047001 204204 4/28/2021 SCMT SCHLUMBERGER E-34A 500292243701 214096 5/3/2021 SCMT SCHLUMBERGER L-106 500292305500 201223 6/5/2021 PPROF SCHLUMBERGER V-109 500292312000 202202 6/11/2021 PPROF SCHLUMBERGER Z-34 500292346900 212061 5/22/2021 SCMT SCHLUMBERGER Z-35 500292288400 198093 5/23/2021 SCMT SCHLUMBERGER Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: ,c9�� 06/14/2021 Reviewed By: Safety Valve & Well Pressures Test Report P.1.Suprv375—C l`zLit3 Comm Pad: PBU_L InspDt: 11/30/2013 Inspected by Jeff Turkington Interval InspNo sysJAT131130151516 Related Insp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Dave Kindred Reason 180-Day Src: Inspector _Well Data Pilots SS SSSV Shutln Dt Well T e Well Pressures Gas Lit .Waiver Comments Well Permit Separ Set UP Test Test Test Date SI Oil,WAG,GINJ, Inner Outer Tubing Nnmher Nnmh#r PSI PSI Trin Cnde Cnde Cnde GAS-CYCLF- SI PSI PSI PSI Yes/No Yes/No L-100 L-101 1980550 1980320 154 154 125 125 117, 122 ' P P P . P 1-011, I -OIL 280 280 — - L-102 2020360 154 125 117- P P 1-OIL 300 L-104 2012380 154 125 97 - P P. 1-OIL _ 286 L-105 2020580 2000 1900 - P P 8 / WAGIN 2875 MI well. L-106 2012230 154 125 113 - P P . I -OIL 285 _ L-107 2011510 154 125 123 P P 1-OIL 285 1_109 L-114A L-118 L-121A L-122 L-201 L 202 2012010 2051120 2011870 2030390 2030510 1 2040460 2041960 154 154 154 154 154 154 2000 125 125 125 125 125 125 1853 127 119 - 119 124 1 120 ' 118 P P P P P P P - P - P- P • P. P. P 4 P WAGIN 1-011, 1-OIL 1-0IL, 1-OIL 1-0IL _ 3000 306 280 290 — �— 280—� 300 �— _— i MI well. — _ Wing valve leaked, used lateral to test SSV DP. Comments Performance OudQ 4 -�x e� +,' hold - - - - Wells Components Failures Failure Rate �regst�re d �t�.eNh 14 30- — -2 6.67% -- ejck't, — Sys-v SCOtAE® OCT 2. 7 2014 Friday, December 06, 2013 Page 1 of 1 Scan THIS copy, please discard/delete any duplicates 9 0 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 iv 9 W PC O C T 0 5 2009 Alaska Gil & Gas Cons. Commission Anchorage Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, ' 1 0& Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • 9 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) L pad nato B/13/2009 Well Name PTO # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na gal L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need Top Job? I NA L-103 2021390 150029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/612009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 150029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 150029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 150029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 150029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 150029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 plate blockina conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 1 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 1500292327700001 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 1500292330900001 NA 1.8 NA 17 6/27/2009 a1l`rhhunhepgop Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall 1nh a NO. e.s '4.c1f1 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite t00 Anchorage, AK 99501 04/27/09 F-45A AP3O-00033 RST GRAVEL PACK LOG 04/17/09 1 1 P2-07 AVYO-00023 PRODUCTION PROFILE _ a 04/05/09 1 1 11-12 AYOO-00019 USIT 1— — 04/19/09 1 1 X-05 AYTO-00010 USIT Aj `6 04/03/09 1 1 X-01 AZ413-00012 PRODUCTION PROFILE — 03/18/09 1 1 Z-21A AP3O-00022 RST —101 02/24/09 1 1 E-34L1 AYTU-00010 OH LDWG EDIT (IFLEX) 02/08/09 1 1 L-106 22026 OH LDWG EDIT (REDO) 03 1 01/10/02 1 MPF-96 09AKA0039 OH MWD/LWD EDIT 02/23/09 2 1 F-19A 40018664 OH MWD/LWD EDIT — 02/14/09 2 1 F-18A 09AKA0034 OH MWD/LWD EDIT 03/16/09 2 1 06-23C 12066550 JMCNL 09/14/08 1 1 1 03-14B BIJJ-00005 MCNL 03/30/09 1 1 11-18 BOCV-00006 RST 1 03/02/09 1 1 07-208 AWJB-ON28 MCNL 02/27/09 1 1 MPB-22A AXBD-00005 CH EDIT PDC-GR (CBL) 12/23/08 1 07-29D AXBD-00016 MCNL (S 03/17/09 1 1 09-33A AWJI-00019 MCNL — — 04/01/09 1 1 nI GAC= AV I.9-11 C - _-___-_-_._._�.-��-.�..��.. . �• v�-,-„-v +-v ,1r•v1-1�V V,\G VVr1 GNVfI IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 0 RE: L-106 (PTD#2012230) sustab casing pressure Page 1 of 1 0 Regg, James B (DOA) From: NSU, ADW Well integrity Engineer [NSUADWWelllnte rit En Ineer BP.com l �'10(dJ0 Sent: Monday, October 01, 2007 2:17 PM j To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 Weilpad Lead; GPB, GC2 OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Oakley, Ray (PRA); Robertson, Daniel B (Alaska) Cc: Lau, John, Jack Subject: RE: L-106 (PTD#2012230) sustained casing pressure Please note the corrections to the pressures below. Thank you - Jack L. Winslow Well Integrity Engineer alternate: Ryan Holt office - 659-5766 pager - 659-5100, 1242 r i etc fk-'+- C� 4tr'z From: NSU, ADW Well Integrity Engineer Sent: Monday, October 01, 2007 2:05 PM To: 'James Regg'; 'tom —ma under@ad min. state. ak.us'; 'Robert Fleckenstein'; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Oakley, Ray (PRA); Robertson, Daniel B (Alaska) Cc: NSU, ADW Well Integrity Engineer; Lau, John, Jack Subject: L-106 (PTD#2012230) sustained casing pressure 0 e6ly-ec,ee d 55CU S I L-106 has been found to have sustained casing pressure on the IA. The wellhead pressures were 31012040/380 on 09/21/07. DHD performed a subsequent TIFL which failed by flow to surface on 09/29/07. This well has been reclassified to Under Evaluation due to TxIA communication. The plan forward is as follows: 1. TIFL - FAILED 2. S: c/o OGLV in Sta#3 @ 3663' MD 3. D: Re-TIFL Thank you - Jack L. Winslow (for Anna Dune) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 10/1 /2007 0 TREE= 3-1/8"5MCIW WELLHEAD= 11"FMC ACTUATOR= NA KB. ELEV = 79.22' BF. ELEV = 52.80' KOP = 1128' Max Angle = 28 @ 4519' Datum MD= 7034' Datum TVD = 6600' SS 7-5/8" CSG, 29.7#, L-80, ID = 6.875" H 2726' Minimum ID = 2.812" @ 2215' 3-1/2" CAMCO SSSVN PERFORATION SUMMARY REF LOG: ANGLE ATTOP PERF: 1 @6930' Note: Refer to Production DB for historical pert data SIZE SPF I INTERVAL Opn/Sqz DATE 2-1/2" 6 6930 - 6994 O 02/20/02 112" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 6661' 5-1/2" CSG, 15.5#, L-80, BTC, ID=4.950" 666T 4.75" X 3-1 /2" CSG XO, ID = 3.000" 6688' PBTD (ELM) H 7338' -1/2" CSG, 9.2#, L-80, NSCT, ID = 2.992" H 7"4' L-106 SAFETY NOTES: 2215' H3-1/2"CAMCOBP-6iSSSVN, ID=2.812" GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCHI PORT DATE _LT 3 3663 3422 25 KBG2-9 SIO INTG 20 6521 6087 4 KBG2-9 DMY INTG - :02/07/042 /07/041 6606 6173 3 KBG2-9 DMY INTG - /17/02 6661'j-13-1/2" BKR CMD SLIDING SLV, ID = 2.81T 6665' BKR LOC SEAL ASSY, ID = 2.990" 6668' TOP OF BKR PBR, ID = 4.00" 6684' BTM OF 3-1/2" BKR SEAL ASSY, ID= 2.990" 6736' 3-1l2" HES X NIP, ID = 2.813" 6758' 3-1/2" HES X NIP, ID = 2.813" 6887' 20' UP PJT W / RA TAG 7114' I-120' PUP JT W / RATAG f 7338'elm 3-1/2"HESMCIBP(SETON01/15IO2) DATE REV BY COMMENTS DATE REV BY COMMENTS 01/17/02 ORIGINAL COMPLETION 02/07/04 GJB/TLP GLV GO 02/01/02 CWTP CORRECTIONS 02/21/02 CWS/tlh ADD PERFS 02/28/01 DA GKK PERF DEPTH CORRECTION 03/30/02 JB/KAK GLV CHANGEOUT 04/08/03 DRS/TP TV DIMD CORRECTIONS BOREALIS UNIT WELL: L-106 PERMIT No: 2012230 API No: 50-029-23055 SEC 34, T12N, Rl l E2419' NSL & 3559' WEL BP Exploration (Alaska) MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiclie\CwPgs_lmrts\Microfilm—Marker.doc ,)�d"Mm- 12-m61_( DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012230 Well Name/No. PRUDHOE BAY UN BORE L-106 Operator BP EXPLORATION (ALASKA) INC MD 7455 TVD 7101 i Completion Date 2/20/2002 --- Completion Status 1-OIL Current Status 1-OIL s'j'L 3 J-, �qw �_ API No. 50-029-23055-00-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D C C_1.0636 1,2 100 7442 Open 3/5/2002 Dipole Sonic Imager (DSI) �'tD C �j1.0636 lr dugmoni~Res shv 1,2 100 7442 Open 3/5/2002 IUD C LA-0637 iL�niRBSrstavity =_ 4 108 7455 Open 3/5/2002 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / NO Chips Received? `Y-`N--- Analysis Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? DY / N Formation Tops @ N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 04125102, Put on Line 1. Status of Well Classification of Service Well ® Oil ❑ Gas ❑ Suspended ❑ Abandoned ❑ Service 2. Name of Operator BP Exploration (Alaska) Inc. 7. Permit Number 201-223 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 8. API Number 50-029-23055-00 4. Location of well at surfaced 2419' NSL, 3559' WEL, SEC. 34, T12N, RI E, UM ' ' , At top of productive interval 2543' NSL, 1803' WEL, SEC. 34, T12N, R11 E, UM At total depth & h 2546' NSL, 1799' WEL, SEC. 34, T12N, R11 E, UM } -: 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number L-106 11 .Field and Pool Prudhoe Bay Field /Borealis Pool (Undefined) 5. Elevation in feet (indicate KB, DF, etc.) 6. KBE = 79.22' Lease Designation and Serial No. ADL 028239 12. Date Spudded 1/3/2002 13. Date T.D. Reached 1 1/9/2002 14. Date Comp., Susp., or Aband. 2/20/2002 15. Water depth, if offshore 1 N/A MSL 16. No. of Completions I One 17. Total Depth (MD+TVD) 118. 7455 7101 FTJ Plug Back Depth (MD+TVD) 7338 6984 FT 19. Directional Survey ® Yes ❑ No 120. Depth where SSSV set 21. (Nipple) 2213' MD Thickness of Permafrost 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, Dipole Sonic, MDT, CCL, RFT, USIT 23. CASING LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM 34" x 20" 91.5# H-40 Surface 109, 42" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 28' 2726' 9-7/8" 359 sx AS Lite 134 sx Class 'G' 5-1/2" 15.5# L-80 26' 6667' 6-3/4" 217 sx Class'G' 3-1/2" 9.2# 1 L-80 1 6667' 7444' 6-3/4" (Longstring Cemented with 5-1/2" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 6930' - 6994' 6576' - 6640' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.2#, L-80 6686' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 3660' Freeze Protect with 75 Bbls of Diesel 7338' Set Cast Iron Bridge Plug 27. PRODUCTION TEST Date First Production 04/15/02 Method of Operation (Flowing, gas lift, etc.) N/A Date of Test 4/15/2002 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 6339 GAS-MCF WATER-BBL 3329 -0- CHOKE SIZE 176 GAS -OIL RATIO 525 Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (CORR) 28. CORE DATA D rr, r Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core c0s. No core samples were taken. It; :y Form 10-407 Rev. 07-01-80 i Rom_ 1 Submit In Duplicate /"—, 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Schrader Bluff M 4192' 3981' Please see attached. Schrader Bluff N 4467' 4227' Schrader Bluff O 4640' 4381' Base Schrader / Top Colville 5056' 4760' i- r , Mudstone:'_,I..; _'. ,.•{?`, CM1 5969' 5621' Alaska Oil HRZ 6568' 6214' One fluid sample taken during the wireline RFT run. Interval tested: Kuparuk C, at 6939' MD. Kalubik 6795' 6441' Pressure and time data: 3036.9 psi reservoir pressure. First Kuparuk D 6914' 6560' fluid attempt at this depth, tool was open for 21 minutes, with final flowing pressure of 325 psi. Second attempt at this depth, Kuparuk C 6930' 6576' filled 2.75 gal. chamber in 5 minutes with final flowing pressure of 3036.2 psi. LCU / Kuparuk B 7102' 6748' Recovered 59 cu. ft. gas and 2.75 gal. oil and heavy mud: Kuparuk A 7235' 6881' TGLR (total gas:liquids ratio): 901 cu ft/bbl. Miluveach 7313' 6959' Oil gravity: 26.8 31. List of Attachments: Summary of Post Rig Work (Updated). Previously Submitted: Summary of Daily Drilling Reports, Surveys 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date V / L-106 201-223 Prepared By Name/Number., Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 Well: L-106 Rig Accept: 01/02/02 Field: Prudhoe Bay Unit Rig Spud: 01/03/02 API: 50-029-23055-00 Rig Release: 01/17/02 Permit: 201-223 Drilling Ria: Nabors 9ES POST -RIG WORK 02/08/02 PULL BPV, RAN 2.5 SWAGE W/TEMP.RECORDER (MRT) TO 7326' SLM, SET FOR 15 MINS - POH SLOWLY, THERMOMETER IS BROKEN IN MRT. SET SLIP STOP CATCHER SUB @ 6592' SLM, SET 1" BOTTOM LATCH DGLV IN GLM # 2 @ 65 13' SLM, PULLED SLIP STOP CATCHER SUB @ 6592' SLM. 02/09/02 MADE SEVERAL RUNS TO PBTD FOR TEMPERATURE WHICH IS 194 DEG F @ 7325' SLM 02/10/02 RIH WITH GR/ CCU PRES/ TEMP, TAGGED TD @ 7338', LOG STATIC BHP= 2865, BHT= 163.6, LOG, PRES/TEMP TD TO 2200', POOH/ RIH W SCMT-BB, LOGGED TD-5900', PRES UP WELL TO 4000#, LOGGED SAME W/ REPEAT OVER TOP OF CEMENT @ 6660', FIELD LOG INDICATES FAIR TO GOOD CEMENT THROUGHOUT, POOH, RD, POST JOB INSPECTION, LEFT WELL SI, NOTIFY DSO OF WELL STATUS AND DEPARTURE, MO 02/12/02 MIT IA TO 3000 PSI / PASSED 0/2900/300. 02/20/02 PERFORATE KUPARUK C SANDS FROM 6930' - 6994' W ITH 2.5" HSD 6 SPF 60 DEG PHASING, 2506 POWERFLOW EH= 0.6", PEN = 4.8". TOTAL SHOTS FIRED = 382. LOGGED STATIC BHPT AT 7333 FT AFTER PERFORATING, SBHP = 3169.0 PSI, SBHT = 163.9 DEGF. 02121 /02 SET 3 1/2 FRAC SLEEVE (2' LONG - 2.20 ID W/ 4 AVA SEALS) @ 2192' SLM ( CONTROL LINE HELD 5000 PSI BLED DOWN TO 50 PSI). 02/22/02 BLEED CONTROL LINE DOWN TO 50 PSI AND RDMO. PUMPED C3/C4 SAND FRAC WITH YF125LG SYSTEM AND 16/20 CARBOLITE PROP. SUFFERED INSTANTAEOUS NWB SCREENOUT TO 8360 PSI WITH 63 BBLS OF 6 PPGA STG (30.30) IN FORMATION. PUMPED TOTAL OF 44.70 16/20 CARBOLITE LEAVING 14.40 (23.6 BBLS) OF SAND IN CSG/TBG. EST. TOP OF SAND TO SURFACE. AVG TREATING PRESS = 5194 PSI, LOAD TO RECOVER = 470 BBLS. LOST ONE TREESAVER ELEMENT TO HOLE (1.25" X 2.992" X 0.25"). WELL NOT FREEZE PROTECTED, HEATERS ON TREE. 02/25/02 CTU #8 FCO. RIH WITH 1 3/4" JSN FOUND ICE AT 20', JET TO 83', NOT MAKING MUCH HEADWAY, POOH. RIH WITH 2" DOWN JET. JET DOWN TO FRAC SLEEVE AT 2215'. SEEING RESTRICTIONS AT EACH COLLAR, POSSIBLE FREEZING FROM THE OUTSIDE INWARD. JET THRU SLEEVE DOWN TO 2260'. GOOD SAND RETURNS. POOH. RIH WITH'G' FISHING TOOLS. LATCH FRAC SLEEVE. POOH. L-106, Post Drill & Complete Page 2 02/26/02 POOH WITH FRAC SLEEVE. MU AND RIH WITH 2.25" JSN. RIH JETTING TO 6940'. LOST CIRCULATION, TEMPERATELY UNABLE TO MOVE PIPE. SHUT IN AT CHOKE AND CONTINUE PUMP AT MINIMUM RATE. WELL HEAD PRESSURE SHOWING SOME POSITIVE PRESSURE. OPEN CHOKE TO TANK, GETTING SLIGHT TRICKLE FOR RETURNS, HELD +- 2K DOWN WEIGHT. SAW SOME WEIGHT GAIN ON COIL AFTER APPROX. 2.5 HRS, START PULLING UP HOLE, PULLING FREELY @ 5550' CTMD, GETTING GOOD RETURNS. RUN BACK IN HOLE TO 6800' AND JET OUT JEWELRY & GLM'S PULLING OUT AT 80%. FREEZE PROTECT TO 2500' W ITH MEOH. WELL LEFT SI. 03/14/02 INSTALL GENERIC GAS LIFT. ICE PLUG @ 704' SLM, UNABLE TO CONT. RIG DOWN. 03/17/02 PUMP .2 BBLS MEOH DOWN TUBING, PRESSURED UP TO 3000 PSI. 03/29/02 MIRU UNIT #3 RIH W/2.5"DOWN JET NOZ, TAG PLUG @786'. FINISH CLEANOUT TO 1372' JET MEOH OVER GLVS, POOH FP FL, RDMO. PAD OP NOTIFIED WELL LEFT SI READY FOR SL. 03/30/02 SET SSCS - PULL CA E INT FROM STA-3 & STA-2 - SET CA BK INT, 16/64" PORT, 1756# TRO IN STA-3 @ 3663' MD - SET CA DKO INT, 20/64" PORT, OGLV IN STA-2 @ 6521'MD - PULL SSCS. - WELL READY TO POP. 04/02/02 ATTEMPT TO BREAK HYDRATE PLUG IN TBG BY PUMPING DOWN IA. 10 BBLS OF METH AND 10 BBLSOF CRUDE PUMPED DOWN IA. 04/03/02 CLEAN HYDRATE ICE PLUG OUT OF WELL. BRIDGES FROM 440' - 550' &1127 - 1130'. PUMP 50 BBLS 180 DEG DIESEL DOWN I/A. FP TBG WITH 60/40 METH. TO 2500'. LEFT WELL SHUT IN. 04/11 /02 SBHPS (PETREDAT) TANDEM GAUGES W/ DUAL MRT GAUGES. 04/12/02 UNABLE TO DO SBHPS DUE TO FRAC SAND FOUND @ 6726' SLM RDMO ( WELL SHUT IN). NOTIFY DSO OF WELL STATUS. WILL ATTEMPT TO PUMP DOWN IA AND THEN FLOW WELL. HOT OIL IA WITH 142 BBLS OF 1900 F DIESEL TO POP WELL USING TEST SEPARATOR. 04/17/02 RUN TANDEM PETREDAT BHP GAUGES W/ DUAL MRT'S. TAG HIGH @ 6994' CORRECTED DEPTH. RUN SURVEY W/ REVISED STOPS. 04/18/02 CONTINUE RUNNING SBHPS W/ TANDEM PETREDAT GAUGES & DUAL MRT'S. RD. SECURED WELL. NOTIFIED DSO OF WELL STATUS. WELL TO BE POP. SCANNED JUL 1 6 2DD4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ® Oil ❑ Gas ❑ Suspended ❑ Abandoned ❑ Service 2. Name of Operator BP Exploration (Alaska) Inc. 7. Permit Number 201-223 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 8. API Number 50-029-23055-00 4. Location of well at surface, - 2419' NSL, 3559' WEL, SEC. 34, T12N, R11 E UM JPrudhoe At top of productive interval: 2543' NSL, 1803' WEL, SEC. 34, T12N, R11 E UM t At total depth D 2546' NSL, 1799' WEL, SEC. 34, T12N, R11 E, UM . - 9. Unit or Lease Name Bay Unit 10. Well Number L-106 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 5. Elevation in feet (indicate KB, DF, etc.) 6. KBE = 79.22' Lease Designation and Serial No. ADL 028239 12. Date Spudded 1/3/2002 113. Date T.D. Reached 1/9/2002 14. Date Comp., Susp., or Aband. 2/20/2002 15. Water depth, if offshore N/A MSL 16. No. of Completions One 17. Total Depth (MD+TVD) 7455 7101 FT 18. Plug Back Depth (MD+TVD) 7338 6984 FT 119. Directional Survey ® Yes ❑ No 20. Depth where SSSV set 121. (Nipple) 2213' MD Thickness of Permafrost 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, Dipole Sonic, MDT, CCL, RFT, USIT 23. CASING LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM U., x 20" 91.5# H-40 Surface 109, 42" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 28' 2726' 9-7/8" 59 sx AS Lite 134 sx Class 'G' 5-1/2" 15.5# L-80 26' 6667' 6-3/4" 1217 sx Class'G' 3-1/2" 9.2# L-80 6667' 7444' 6-3/4" I(Lonastrina Cemented with 5-1/2" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 6930' - 6994' 6576' - 6640' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2", 9.2#, L-80 6686' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 3660' Freeze Protect with 75 Bbls of Diesel 7338' Set Cast Iron Bridge Plug 27. PRODUCTION TEST Date First Production Not on Production Yet Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas o w o . No core samples were taken. APR 5 2002 ANWON&GOOM-CoWnWim AnftW Submit Duplicate Form 10-407 Rev. 07-01-80 - a m R B O M S B F l APR 8 2002 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Schrader Bluff M 4192' 3981' Please see attached. Schrader Bluff N 4467' 4227' 'RECEIVED Schrader Bluff O 4640' 4381' APR 5 2002 Base Schrader / Top Colville 5056' 4760' i 01& 1i81M Mudstone Afthm CM 1 5969' 5621' HRZ 6568' 6214' One fluid sample taken during the wireline RFT run. Interval tested: Kuparuk C, at 6939' MD. Kalubik 6795' 6441' Pressure and time data: 3036.9 psi reservoir pressure. First Kuparuk D 6914' 6560' fluid attempt at this depth, tool was open for 21 minutes, with final flowing pressure of 325 psi. Second attempt at this depth, Kuparuk C 6930' 6576' filled 2.75 gal. chamber in 5 minutes with final flowing pressure of 3036.2 psi. LCU / Kuparuk B 7102' 6748' Recovered 59 cu. ft. gas and 2.75 gal. oil and heavy mud: Kuparuk A 7235' 6881' TGLR (total gas:liquids ratio): 901 cu ft/bbl. Miluveach 7313' 6959' Oil gravity: 26.8 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubbl fij& Title Technical Assistant Date o q' b5 d L-106 201-223 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 Woll- L-106 Toni- RFf Start: 1/10/2002 End: 1/1012002 4265.43 4186.2 2371.0 2370.2 ,_ 0.8 Y 1870.0 { 8 8.7 � 0.00 E gyp:.. 71y, "uMR. l Normal Pretest (built down) P Nb 2 1 4510 4509.95 1 2 4445 4545.02 4296.46 4217.2 2387.5 2386.6 0.9 1927.3 4.9 0.00 Normal Pretest (built down). Note: Depth of sample in ei P Nc 3 3 4657 4657.02 4396.53 4317.3 2442.7 2441.7 1.0 1908.2 1908.2 98.8 0.00 Normal Pretest P Oa 4 4 4725 4725.04 4457.68 4378.5 2475.5 2474.3 1.2 2012.3 28.4 0.00 94.90 Normal Pretest (built down) P Oba 5 5 4725 4726.02 4457.68 4378.5 2474.9 2478.3 3.4 1999.5 32.2 0.00 96.00 Normal Pretest (built down) P Oba 6 6 4725 4723.98 4457.68 4378.5 2473.3 2472.8 0.5 1934.0 1934.0 11.0 0.00 97.00 Normal Pretest P Oba 7 7 4778 4778.09 4505.54 4426.3 2500.7 2498.6 2.2 1958.1 1958.1 9.4 0.00 97.00 Unstable P Obb 8 8 4778 4777.86 4505.54 4426.3 2498.5 2498.4 0.2 1957.1 1957.1 9.8 0.00 97.00 Normal Pretest P Obb 9 9 4833 4832.96 4555.44 4476.2 2527.6 2526.6 1.0 -8.6 0.00 98.00 Dry test P Obc 10 10 4833 4831.88 4555.44 4476.2 2525.7 2523.8 1.9 1980.5 1980.5 1.2 0.00 98.00 Normal Pretest P Obc 11 11 4902 4902.04 4618.44 4539.2 2561.6 2559.7 1.9 1993.2 1993.2 583.2 0.00 98.00 Normal Pretest P Obd 12 12 4963 4962.92 4674.45 4595.2 2592.6 2590.6 2.0 -1.8 0.00 Dry test P C 1 13 13 4963 4960.91 4674.45 4595.2 2588.6 2588.0 0.6 -6.9 0.00 Dry test P 0: 14 15 6935 6935.09 6580.57 6501.3 3635.8 3623.3 12.5 3041.0 3041.0 0.6 0.00 148.00 Limited drawdown-not stable P C4 15 16 6939 6938.97 6584.57 6505.3 3623.6 3621.9 1.7 3036.9 3036.9 71.7 0.00 148.00 Normal Pretest P C4 16 17 6939 6938.97 6589.56 6510.3 3621.5 3619.6 1.9 3036.9 3036.9 77.9 0.00 149.00 Sample 1 - 2 3/4 gal. Did not fill chamber. F C4 17 18 6939 6938.90 6594.56 6515.3 3619.3 3616.3 2.9 3036.7 3036.7 43.1 0.00 150.00 Sample 1 - 2 3/4 gal. Filled chamber. P C4 18 19 6944 6943.98 6599.56 6520.3 3622.1 3620.6 1.5 3030.2 3030.2 36.5 0.00 150.00 Normal Pretest P C4 17 20 6949 6949.05 6612.56 6533.3 3624.2 3622.2 2.0 3030.8 3030.8 13.8 0.00 151.00 Normal Pretest P C4 18 21 6954 6954.08 6626.56 6547.3 3626.7 3624.7 1.9 3033.6 3033.6 110.9 0.00 151.00 Normal Pretest P C3D 18 22 6967 6966.93 6638.55 6559.3 3633.9 3630.6 3.3 3038.8 3038.8 59.9 0.00 151.00 Normal Pretest P C3C 19 23 6981 6981.05 6736.53 6657.3 3640.3 3636.9 3.4 3057.1 3057.1 6.1 0.00 152.00 Limited drawdown P C3B 20 26 6993 6993.16 6740.53 6661.3 3071.5 3071.5 0.00 152.00 Unrecognizable P C3B 21 7091 7091.00 6744.53 6665.3 0.00 Unrecognizable P C1X 22 7095 7095.00 6905.52 6826.3 0.00 Unrecognizable P CiX 23 7099 7099.00 0.00 Unrecognizable P C1X 24 7260 7260.00 0.00 Unrecognizable P A4 25 7260 7260.00 0.00 Attempted 1 gal fluid sample -Unsuccessful F A4 BP EXPI_©RATI N f Page of ` = Ea lea-Q>f Test umrr�aryy Legal Name: L-106 Common Name: L-106 Testate iest Tim- : ,`sure Test bepth �1MD H Test G$ith_{ND) ` AM W aria surs:F 5... c.Pres ; ek ©ff P CiF� I,a I..... EIVIW _ 1/6/2002 LOT 2,726.0 (ft) 2,654.0 (ft) 9.30 (ppg) 828 (psi) 2,110 (psi) 15.31 (ppg) Printed: 1/21/2002 9:54:26AM Legal Well Name: L-106 Common Well Name: L-106 1/2/2002 100:00 - 13:00 1 13.001 MOB I P I I PRE Spud Date: 1/3/2002 Start: 1/2/2002 End: Rig Release: 1/17/2002 Rig Number: 9-ES 13:00 - 18:30 1 5.501 DRILL I P I I SURF 18:30 - 22:00 3.50 DRILL I P I SURF 22:00 - 00:00 2.00 DRILL P SURF 1/3/2002 00:00 - 01:30 1.50 DRILL P I SURF 01:30 - 03:00 1.50 DRILL P SURF 03:00 - 03:30 0.50 DRILL P SURF 03:30 - 04:00 0.50 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 06:30 2.00 DRILL P SURF 06:30 - 08:00 1.50 DRILL P SURF 08:00 - 19:30 11.50 DRILL P SURF 19:30 - 20:30 1.00 DRILL P SURF 20:30 - 21:00 0.50 DRILL P SURF 21:00 - 22:30 1.50 DRILL P SURF 22:30 - 23:00 0.50 DRILL P SURF 23:00 - 23:30 0.50 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 1/4/2002 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 05:30 1 5.00 1 DRILL I P I I SURF 05:30 - 07:00 1.50 DRILL P SURF 07:00 - 09:30 2.50 DRILL P SURF 09:30 - 12:00 2.50 DRILL P SURF 12:00 - 12:30 0.50 DRILL P SURF 12:30 - 13:30 1.00 DRILL P SURF 13:30 - 14:30 1.00 DRILL P SURF 14:30 - 18:00 3.50 DRILL P SURF 18:00 - 19:30 1.50 DRILL P SURF 19:30 - 20:00 0.50 DRILL P SURF 20:00 - 21:30 1.50 DRILL P SURF 21:30 - 00:00 2.50 DRILL P SURF Commence rig do / move V201 to L106. Mast dn, pits off drill site. Prepare rig for move. Resume move in / rig up on L-106. Spot sub base, set pits, raise mast, raise pipe shed chute, bridle dn, rig up floor. Set mini camp. Begin take on water, mix spud mud. Load pipe shed dp / bha. ACCEPT NABORS RIG 9-ES THIS DATE 1/2/2002 1300 HRS Pick up 4" dp and stand back in mast. 27 stds. Make up hwdp , DCs, dretnl tools. Service top drv, make top drive connections during this time. PU 4" hwdp / bha#1, stand back in mast. Make up bit, dretnl assy, check motor setting, confirm and record data. Pre spud meeting all personnel. Function test diverter system. Witness waived AOGCC. Fill conductor, check for leaks. Function floor manifold. Spud well, drill ahead 9 7/8 hole dretnl, 107 - 273 ft. Poh one stand, add jars from mast, wash to btm, 30 ft fill. Resume drill 273 - 1761 ft. WOB 30, RPM 70, SPM 204, GPM 600, PRESS 2300, TQ 3000 Up 83, Dn 72, Rot 82 AST = 3 hrs, Art = 6.5 hrs Circ, pump wt pill, blow do top drv. Flow check, poh for bit trip to hwdp. Handle bha #1, break out bit #1, MU bit #2 Clear rig floor. Service top dry / blocks. Flow check, rih DCs, hwdp. Cont rih, tight at 1200 and 1400 ft. Work free. Wash 90 ft to btm, 16 ft fill. Flow check, resume drill ahead 9 7/8 hole 1761 - 2745 ft (TD as per geo ) WOB 35, RPM 70, SPM 204, GPM 600, PRESS 2300, TQ 2800 Up 102, Dn 93, Rot 90 AST = 1.2 hrs, ART = 1.9 hrs Clean hole for logs, circ sweep, pump wt pill Flow check, poh for logs. Lay do bha #2, lay out dretnl equip. Clear rig floor. PJSM, rig up Schlum wireline log equip. Calibrate, zero tools, load source. Rih wireline, PEX / Di -pole Sonic TD at 2746, 20" shoe at 107 ft. Log interval 2746 - 80 ft. Poh wireline. No losses / gains during E logs. Lay out wireline equip, release unit. Land csg hgr as dummy run, mark and record space out. Make up "Franks" circ tool, rig up up for 7 5/8 csg run. PJSM, Assemble shoe track, float equip, rih, test same, follow with Nrintea: 1/11/2UU1 U:41:4JAM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-106 L-106 DRILL+COMPLETE NABORS NABORS 9ES Spud Date: 1/3/2002 Start: 1/2/2002 End: Rig Release: 1/17/2002 Rig Number: 9-ES 1/4/2002 21:30 - 00:00 2.50 DRILL P SURF 1/5/2002 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 02:30 0.50 DRILL P SURF 02:30 - 05:00 2.50 DRILL P SURF 05:00 - 07:30 1 2.501 DRILL I P I I SURF 07:30 - 09:30 2.00 DRILL P SURF 09:30 - 12:00 2.50 DRILL P SURF 12:00 - 12:30 0.50 DRILL P SURF 12:30 - 16:00 3.50 DRILL P SURF 16:00 - 21:30 5.50 DRILL P SURF 21:30 - 22:00 0.50 DRILL P SURF 22:00 - 00:00 2.00 DRILL P SURF 1/6/2002 00:00 - 04:00 4.00 DRILL P SURF 04:00 - 06:00 2.00 DRILL P SURF 06:00 - 07:30 1.50 DRILL P SURF 07:30 - 08:00 0.50 DRILL P SURF 08:00 - 09:00 1.00 DRILL P SURF 09:00 - 09:30 0.50 DRILL P SURF 09:30 - 10:30 1.00 DRILL P SURF 10:30 - 11:00 0.50 DRILL P SURF 11:00 - 11:30 0.50 DRILL P SURF 11:30 -12:00 0.50 DRILL P SURF 12:00 - 00:00 1 12.001 DRILL I P I I PROD1 7 5/8, L80, 29.7#, BTC-Mod csg. Cont rih 7 5/8 csg, tight at 1950, 2250, 2600 ft. Pick up Idg jt, lay do "Franks" tool, make up cmt hd. Circ / cond mud. Recip csg entire period. Up 115, Dn 90. No losses gains. Cmt 7 5/8 csg as follows: Pump 5 bbl CW100, test lines to 3500 psi, pump remainder 5 bbls CW100. Pump 75 bbls Mudpush spacer. 10.2 ppg , drop btm plug. Pump lead slurry, 284 bbls 10.7 ppg "G', 5 bpm Pump tail slurry, 28 bbls 15.8 ppg "G", 7.5 bpm Drop top plug., commence displace 111 bbls, 7 - 8 bpm, with rig pump. Bump plug 0630 hrs, correct displacement with 1200 psi, hold 10 min, bleed, floats holding. FCP = 700 psi at 2 bpm, cmt returns = 100 bbls (60 contaminate, 40 dense) Recip csg to 0545 hrs. Lay do csg run equip / tools. Clear rig floor. Nipple do diverter system. Remove from sub. Install csg / tbg head, test same to 1000 psi. Test successful. No re -test. Nipple up bope, all related equip. Prepare and test bope as follows: Test rams, kill / choke lines, outlet valves, choke mnfld, standpipe to pumps 250 / 4500 psi Floor safety valves 250 / 4500 psi. Annuar 250 / 3500 psi Accumulator time / volume / press test. All tests successful, no re -test. Witness test waived by John Crisp AOGCC Lay out hwdp std with jars from mast. PU 4" dp from shed, stand ack in mast. Cont stand back 4" dp in mast. Assemble bha #3, rih same, shallow test MWD. Rih 4" dp from pipe shed to 2500 ft. Well kill drill, Co rep / tool pusher. Test csg 4500 psi / 30 min. Test successful. No press loss. Rih, wash 90 ft to cmt at 2616 dt. Circ. Commence drill out cmt / float equip. Drill guide shoe. Flow check. Drill rat hole / new formaton to 2765 ft. Flow check. Displace well bore fluids with 9.3 LSND. Pull in to shoe, perform LOT. Results = 828 psi surface press, 15.3 ppg EMW. Begin drill ahead 6 3/4 hole dretnl 2765 - 3740 ft. WOB 15, RPM 60, SPM 92, GPM 275, PRESS 1640 psi, TQ 2200 Up 102, Dn 8, Rot 94 Printed: 1/21/2002 9:41:43 AM Legal Well Name: L-106 Common Well Name: L-106 Spud Date: 1/3/2002 Event Name: DRILL+COMPLETE Start: 1/2/2002 End: Contractor Name: NABORS Rig Release: 1/17/2002 Rig Name: NABORS 9ES Rig Number: 9-ES Qate' ' . From To ours"Activtiy Cede 1�T F Phase Des+rnpttgn of Operatlort fl ry 1/6/2002 12:00 - 00:00 12.00 DRILL P PROD1 AST = 1.5 hrs, ART = 6.5 hrs 1/7/2002 00:00 - 09:00 9.00 DRILL P PROD1 Cont drill ahead 6 3/4 hole, 3740 - 4508 ft. Parameters normal. No losses gains. 09:00 - 10:00 1.00 DRILL P PROD1 Pump hi - vis sweep, shakers clean, cuttings returns normal. 10:00 - 13:00 3.00 DRILL P PROD1 Flow check, poh for bit. Intermittent swabbing various intervals. Hole fill thru dp / annulus. Drag normal. 13:00 - 14:30 1.50 DRILL P PROD1 Handle bha #3, break / grade bit, lay out dretnl tools, mud motor. 14:30 - 15:00 0.50 DRILL P PROD1 Clean / clear rig floor. 15:00 - 17:00 2.00 DRILL P PROD1 Flow check. Assemble bha #4, make up mud motor / dretnl tools, rih, shallow test MWD. 17:00 - 17:30 0.50 DRILL P PROD1 Rih 4" dp to 7 5/8 shoe. 17:30 - 18:00 0.50 DRILL P PROD1 Service top drive, blocks, crown. 18:00 - 19:00 1.00 DRILL P PROD1 Slip / cut drlg line. 19:00 - 21:30 2.50 DRILL P PROD1 Flow check, resume rih 4" dp, tight / take 30K wt various intervals 2960 - 3640. Wash / ream thru with slow rotation. 21:30 - 22:30 1.00 DRILL P PROD1 Precautionary wash 90 ft to btm. No fill. Take no wt. 22:30 - 00:00 1.50 DRILL P PROD1 Drill ahead 6 3/4 hole dretnl 4508 - 4607 ft. WOB 10, RPM 50, SPM 78, PRESS 1712, GPM 275, TQ 3000 AST = .5 hrs, ART = 7.75 hrs Up 130, Dn 97, Rot 109 1/8/2002 00:00 - 22:00 22.00 DRILL P PROD1 Drill 6 3/4" Directional Hole from 4607' to 6442'. 272 GPM @ 2040 psi. TQ = 6 K WOB = 5K - 15K, 60 RPM, P/U = 156K, S/O = 115K, ROT = 134K, AST = 1 Hr ART = 16.8 Hr 22:00 - 00:00 2.00 DRILL P PROD1 Circulate Hi - Vis sweep. Weight up mud to 10.3 ppg. Take SPR's. 1/9/2002 00:00 - 02:30 2.50 DRILL P PROD1 Wipe to shoe @ 2726'. Tight from 4300' up to 4238' - wiped again - clean. No other excessive drag. No swabbing. 02:30 - 03:30 1.00 DRILL P PROD1 Change out lower Top Drive valve. Service Top Drive. 03:30 - 05:30 2.00 DRILL P PROD1 RIH to 6350'. Wash to btm. @ 6442. No fill. No drag. 05:30 - 10:00 4.50 DRILL P PROD1 Drill from 6442' to 6908'. 272 GPM @ 2500 psi. Rotate all - 60 RPM. Lost Returns. 10:00 - 11:30 1.50 DRILL P PROD1 Slowed pumps. Rotate & reciprocate pipe. Regained returns. Mix & pump Barofiber.stage up pumps to drilling speed. 100 % returns. Total losses 35 bbls. 11:30 - 20:00 8.50 DRILL P PROD1 Drill fron 6908' to 7455' - TD per Geologist. Drilled @ 272 GPM - 2220 psi. TQ @ TD= 8.5K P/U = 180K, S/O = 124K, ROT = 149K. All Rotation - 10.55 Hrs. Well stable- no losses. 20:00 - 21:30 1.50 DRILL P PROD1 Circulate Hi-Vis sweep. Hole clean 21:30 - 22:30 1.00 DRILL P PROD1 Wipe hole up to 6034'. Max pull 25K over @ 7065'- wiped through again - no overpull. Ran back to 7393' - hole slick. 22:30 - 00:00 1.50 DRILL P PROD1 Wash last 60' to TD @ 7455'. No Fill. Circulate Hi-Vis Sweep. 1/10/2002 00:00 - 01:00 1.00 DRILL P PROM Spot slick pill for logging. Monitor well - OK. Pump slug. 01:00 - 03:30 2.50 DRILL P PROD1 POH w/ 4" DP. Hole in good condition - no excessive drag. 03:30 - 05:00 1.50 DRILL P PROD1 Stand back 4" HWDP. L/D DC's, MWD, Motor & B/O Bit. 05:00 - 00:00 19.00 EVAL P PROD1 PJSM. R/U SWS E-Line. Run #1 PEX/DSI - Aquired all logs. Run #2 RIFT: Had tool failure and aborted the run. Got all Printed: 1/21/2002 9:41:43AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/10/2002 105:00 - 00:00 L-106 L-106 DRILL+COMPLETE NABORS NABORS 9ES 19.001 EVAL I P Spud Date: 1/3/2002 Start: 1/2/2002 End: Rig Release: 1/17/2002 Rig Number: 9-ES PROD1 1/11/2002 00:00 - 00:30 0.50 DRILL I P PROD1 00:30 - 04:00 3.50 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 06:30 1.50 DRILL P PROD1 06:30 - 11:00 4.50 DRILL P PROD1 11:00 -19:30 1 8.501 DRILL IN I DPRB I PROD1 19:30 - 23:00 1 3.501 DRILL I P I I PROD1 23:00 - 00:00 1.00 DRILL P PROD1 1/12/2002 00:00 - 03:00 3.00 DRILL P PROD1 03:00 - 04:30 1.50 DRILL P PROD1 04:30 - 05:30 1.00 CASE P COMP 05:30 - 07:30 2.00 CASE P COMP 07:30 - 12:30 5.00 CASE P COMP 12:30 - 13:00 0.50 CASE P COMP 13:00 - 15:30 2.50 CASE P COMP 15:30 - 16:00 0.50 CASE P COMP 16:00 - 19:00 3.00 CASE P COMP 19:00 - 19:30 0.50 CASE P COMP 19:30 - 22:00 1 2.501 CASE I P I I COMP 22:00 - 00:00 1 2.001 CASE I P I I COMP I1/13/2002 I00:00 - 00:30 I 0.501 CASE I P I I COMP pressure data except for 3 points in Kuparuk. Recovered one 2 3/4 gal. successful fluid test in the Kuparuk C4 with one failed 1 gal. test in A sand. POH w/ RFT & R/D SWS E-Line. Only 10 bbls mud lost while logging - Hole stable. Pull Wear Bushing, set test plug & R/U BOP test equipment. Test BOPE 250/4500 psi, Annular 250/3500 psi. Witness of test waived by John Spaulding, AOGCC. Pull test plug, install wear bushing, R/D test equip. M/U BHA #5 - 6 3/4" Porcupine Hole Opener Assy. RIH to 6500'. Hole slick - no obstructions. Break circulation - minimal returns. String in Barofiber while rotating and reciprocating pipe. No success - returns still minimal. Pull 10 stands - unable to break circulation. Pull anoher 10 stands attempt circ - no success. Pull up into shoe - established full circulation with no losses. Stage into hole, CBU every 5 stands to 5415'. RIH to 6351' Break circulation. CBU. 100% Returns. RIH to 7377'. Establish full circulation with no losses and wash to TD @ 7455'. Pump HI-Vis sweep around. Well bore clean & Mud balanced @ 10.3 ppg. in and out. No losses pumping @ 272 GPM with 1280 psi. Spot casing pill & pump slug. POH - stand back 25 stands 4" DP. Hole in good condition. Continue POH UD 4" DP. Stand back 4" HWDP. UD BHA # 5. Pull wear bushing. Make dummy run w/ Landing it. & Hgr. Change to long bails, rig up to run Prod. Csg. Run 3.5" X5.5" Production string to 7 5/8" Shoe @2726'. Circulate 1.5 times Csg cap. 5 BPM @ 510 psi. No Losses. Cont. RIH w/ 5.5 " Csg.filling every it. to 5365' 115K P/U, 78K S/O - No displacement. Break circ. 1.5 BPM @ 500 psi. Loss rate = 1 BPM Cont. RIH filling every it. Loss rate 20 Bbls / Hr. M/U Landing Jt. & Hanger. P/U 174K, Dn. Wt. 94K. Land Hanger. M/U Cmt Head. Attempt to break circulation - no success. Attempt to reciprocate, pulled maximum allowable - 300K - no movement. String in Barofiber continue to pump and work pipe - no circ. or movement. Begin to batch mix cement. R/U lines to SWS/Dowell. Pump 5 bbls CW 100. Tset lines to 4000 psi. Pump 15 bbls CW 100. Drop bottom plug. Pump 40 bbis 11.3 ppg. MudPUSH XL. Pump 45.3 Bbls 15.8 ppg "G" tail slurry, all at 4.5 to 5 BPM.. Switch to rig pump, drop top wiper plug and displace with 165 bbls 8.5 ppg heated filtered seawater @ 5 bbm. Slowed down to 2 bpm 2 bbls prior to entering 3.5" tbg. continued pumping and bumped plug w/ 1950 psi. Held for 5 min., Bleed pres. Floats OK. No Returns during job. Observed steady pressure increase after cement rounded the shoe throughout complete displacement. Total Mud losses running pipe, attempting circulation and cementing were 660 bbls. R/D Cement head & lines. Break out landing Jt., UD same. Printed: 1/21/2002 9:41:43 AM I Legal Well Name: L-106 Common Well Name: L-106 Spud Date: 1/3/2002 Event Name: DRILL+COMPLETE Start: 1/2/2002 End: Contractor Name: NABORS Rig Release: 1/17/2002 Rig Name: NABORS 9ES Rig Number: 9-ES 1/13/2002 00:30 - 01:30 1.00 CASE P COMP M/U Pack -off on running tool. Run, install and test to 5000 psi. 01:30 - 13:30 12.00 CASE N CEMT COMP WOC in order to run cement evaluation log. Service rig while WOC. 13:30 - 15:00 1.50 CASE P COMP Compressive strength greater than 500 psi. Perform LOT on 5 1/2" X 7 5/8" annulus. Surface pres. = 800 psi w/ 9.7 ppg mud. = 15.4 EMW. Inject 45 bbls mud down annulus at 2.5 bbls/min @ 800 psi. Then pumped 45 bbls diesel down annulus for freeze protection. 15:00 - 16:30 1.50 CASE P COMP R/U test equip.. PJSM. Close Blind rams and attempt to test 3.5" X 5.5" csg. Leak @ 2100 psi. Pump 10 bbls. , shut down, pressure drops to 1400 psi. Bleed pres. Check all surface lines. Pres. up again to 1900 psi. - leak - pump 3 bbls, shut in, pressure again drops to 1400 psi. Bleed off pressure. 16:30 - 23:00 6.50 CASE N CEMT COMP Wait on SWS E-Line & HOWCO 2.72" CIPB. Service rig while waiting. 23:00 - 00:00 1.00 CASE N CEMT COMP R/U SWS E-Line. 1/14/2002 00:00 - 00:30 0.50 CASE N DFAL COMP R/U SWS E-Line 00:30 - 07:00 6.50 CASE N DFAL COMP M/U 3.5" COP on a -line, RIH. Could not pass through PBR X 3.5" XO. POH. Attach 2 collapsable centalizers and try again - no success. R/D SWS to make room for slick line. 07:00 - 00:00 17.00 CASE N DFAL COMP Wait on HES Slick Line unit R/U. Run 2.77" swadge. RIH - stopped at XO. POH. #2 Run - 2.75 LIB - Two impressions- more than 1 fish? #3 Run - Spear - No Recovery #4 Run - Spear - Recovered landing receptacle - Bottom Plug #5 Run - WL Spear - Recovered Top 3 sections of 5 of Top Plug + Brass locking ring from bottom plug landing receptacle. #6 Run - WL spear. No recovery. deemed XO now clear of 1/15/2002 00:00 - 05:00 5.00 CASE N DFAL COMP 05:00 - 06:00 1.00 RUNCOMP COMP 06:00 - 19:00 13.00 RUNCOMP COMP 19:00 - 20:00 1.00 RUNCOMP COMP 20:00 - 21:00 1.00 RUNCOMP COMP 21:00 - 22:30 1.50 RUNCOMP COMP 22:30 - 00:00 1.50 RUNCO COMP #7 Run - Run 2.5" Blind box Tagged up w/ fish @ 6691'. Drove Fish to to 7340' POH Recovered 1 Fin from bottom plug. Run #8 - Run 2.77" Swadge Guage w/ 2.80" solid centralizer to 7340' POH w/ 2.77 swadge. R/D HES Slick Line. R/U SWS E-Line. Run HES 3.5" Model " M " Cast Iron Bridge Plug. Set @ 4338". POH E- Line Test 3.5" X 5.5" Casing to 4500 psi - OK. R/D SWS. PJSM. M/U Hanger on landing jt. - make dummy run - strap out. Rig up to run tbg. Run 3.5" Completion string as per program.. Space out into tubing head. Reverse circulate corrosion inhibited filtered sea water. Land Hanger. R.I.L.D.S. Torque to 450 ft/lbs. B/O and UD landing A. Pressure tubing to 4500 psi for 30 minutes - OK. Bleed tubing to 2000 psi. Pressure up on annulus to 3500 psi - tbg pressure increased rapidly. Shut down pump. Tubing and annulus equalized @ 3420 psi. Check all surface equipment - OK. Bleed annulus - tubing bleeds down at same rate. Definite communication. Establish circulation - 1 bpm @ 250 psi down tubing and up annulus. RP appears to have sheared.. Blow down all lines to BOP stack. Drain BOP. Install TWC. Test from below to 2800 psi. Printed: 1/21/2002 9:41:43 AM Legal Well Name: L-106 Common Well Name: L-106 Event Name: DRILL+COMPLETE Contractor Name: NABORS Rig Name: NABORS 9ES 1 /16/2002 11 /17/2002 Spud Date: 1/3/2002 Start: 1/2/2002 End: Rig Release: 1 /17/2002 Rig Number: 9-ES 00:00 - 02:00 2.00 BOPSUF P COMP N/D & Secure BOPE 02:00 - 03:30 1.50 WHSUR P COMP N/U Adapter Flange & Tree. Test to 5000 psi. 03:30 - 04:30 1.00 WHSUR P COMP R/U DSM / Pull TWC / R/D DSM 04:30 - 10:00 5.50 RUNCOINN DFAL COMP R/U HES Slick Line. Make following runs: 1. Pull SSSV Dummy 2. Run Catcher sub & set @ 6566'. 10:00 - 12:30 2.50 RUNCOMN SFAL COMP HES Slick Line Unit Depth counter failed. Wait on parts from shop then repair. 12:30 - 20:30 8.00 RUNCOMN DFAL COMP Resume slick line work making the following runs: 3. Retrieve RP from #2 GLM @ 6521'. 4. Run dummy valve - attempt to set in #2 GLM - no success. 5. Run pocket brush - clean & polish valve seat in #2 GLM. 6. Run and install dummy valve in #2 GLM. 20:30 - 21:30 1.00 RUNCOhV DFAL COMP 21:30 - 00:00 2.50 RUNCOMKI DFAL COMP 00:00 - 02:00 2.00 RUNCOMKI DFAL COMP 02:00 - 03:30 1.50 CHEM P COMP 03:30 - 04:30 1.00 1 WHSUR P COMP 04:30 - 06:00 1.50 WHSUR P COMP Pressure tubing to 1500 psi. Pressure annulus to 4500 psi. for 30 minute test - OK Continue with HES Slick Line. Make following runs: 7. Retrieve Dummy valve from #2 GLM . 8. Retrieve Catcher Sub @ 6566'( incomplete) Retrieve Catcher sub @ 6566'. POH. R/D HES Slick Line. R/U Hot Oiler. Perssure test lines to 3000 psi. Pump 75 bbls diesel down annulus. Shut in and allow to U-Tube to Freeze protect to 3660'. Set BPV. Test from below to 1000 psi. R/D Hot Oiler, blow down all lines, clear cellar & secure well. RIG RELEASED @ 06:00 HRS. 1/17/2002. Printed: 1/21/2002 9:41:43AM Well: L-106 Field: Prudhoe Bay Unit API: 50-029-23055-00 Permit: 201-223 POST -RIG WORK Rig Accept: 01/02/02 Rig Spud: 01/03/02 Rig Release: 01/17/02 Drilling Rig: Nabors 9ES 02/08/02 PULL BPV, RAN 2.5 SWAGE W/TEMP.RECORDER (MRT) TO 7326' SLM, SET FOR 15 MINS - POH SLOWLY, THERMOMETER IS BROKEN IN MRT. SET SLIP STOP CATCHER SUB @ 6592' SLM, SET 1" BOTTOM LATCH DGLV IN GLM # 2 @ 65 13' SLM, PULLED SLIP STOP CATCHER SUB @ 6592' SLM. 02/09/02 MADE SEVERAL RUNS TO PBTD FOR TEMPERATURE WHICH IS 194 DEG F @ 7325' SLM 02/10/02 RIH WITH GR/ CCU PRES/ TEMP, TAGGED TD @ 7338', LOG STATIC BHP= 2865, BHT= 163.6, LOG, PRES/TEMP TD TO 2200', POOH/ RIH W SCMT-BB, LOGGED TD-5900', PRES UP WELL TO 4000#, LOGGED SAME W/ REPEAT OVER TOP OF CEMENT @ 6660', FIELD LOG INDICATES FAIR TO GOOD CEMENT THROUGHOUT, POOH, RD, POST JOB INSPECTION, LEFT WELL SI, NOTIFY DSO OF WELL STATUS AND DEPARTURE, MO 02/12/02 MIT IA TO 3000 PSI / PASSED 0/2900/300. 02/20/02 PERFORATE KUPARUK C SANDS FROM 6930' - 6994' WITH 2.5" HSD 6 SPF 60 DEG PHASING, 2506 POWERFLOW EH= 0.6", PEN = 4.8". TOTAL SHOTS FIRED = 382. LOGGED STATIC BHPT AT 7333 FT AFTER PERFORATING, SBHP = 3169.0 PSI, SBHT = 163.9 DEGF. 02/21/02 SET 3 1/2 FRAC SLEEVE (2' LONG - 2.20 ID W/ 4 AVA SEALS) @ 2192' SLM ( CONTROL LINE HELD 5000 PSI BLED DOWN TO 50 PSI). 02/22/02 BLEED CONTROL LINE DOWN TO 50 PSI AND RDMO. PUMPED C3/C4 SAND FRAC WITH YF125LG SYSTEM AND 16/20 CARBOLITE PROP. SUFFERED INSTANTAEOUS NWB SCREENOUT TO 8360 PSI WITH 63 BBLS OF 6 PPGA STG (30.3K#) IN FORMATION. PUMPED TOTAL OF 44.70 16/20 CARBOLITE LEAVING 14.40 (23.6 BBLS) OF SAND IN CSG/TBG. EST. TOP OF SAND TO SURFACE. AVG TREATING PRESS = 5194 PSI, LOAD TO RECOVER = 470 BBLS. LOST ONE TREESAVER ELEMENT TO HOLE (1.25" X 2.992" X 0.25"). WELL NOT FREEZE PROTECTED, HEATERS ON TREE. 02/25/02 CTU #8 FCO. RIH WITH 1 3/4" JSN FOUND ICE AT 20', JET TO 83', NOT MAKING MUCH HEADWAY, POOH. RIH WITH 2" DOWN JET. JET DOWN TO FRAC SLEEVE AT 2215'. SEEING RESTRICTIONS AT EACH COLLAR, POSSIBLE FREEZING FROM THE OUTSIDE INWARD. JET THRU SLEEVE DOWN TO 2260'. GOOD SAND RETURNS. POOH. RIH WITH'G' FISHING TOOLS. LATCH FRAC SLEEVE. POOH. L-106, Post Drill & Complete Page 2 02/26/02 POOH WITH FRAC SLEEVE. MU AND RIH WITH 2.25" JSN. RIH JETTING TO 6940'. LOST CIRCULATION, TEMPERATELY UNABLE TO MOVE PIPE. SHUT IN AT CHOKE AND CONTINUE PUMP AT MINIMUM RATE. WELL HEAD PRESSURE SHOWING SOME POSITIVE PRESSURE. OPEN CHOKE TO TANK, GETTING SLIGHT TRICKLE FOR RETURNS, HELD +- 2K DOWN WEIGHT. SAW SOME WEIGHT GAIN ON COIL AFTER APPROX. 2.5 FIRS, START PULLING UP HOLE, PULLING FREELY @ 5550' CTMD, GETTING GOOD RETURNS. RUN BACK IN HOLE TO 6800' AND JET OUT JEWELRY & GLM'S PULLING OUT AT 80%. FREEZE PROTECT TO 2500' WITH MEOH. WELL LEFT SI. 03/14/02 INSTALL GENERIC GAS LIFT. ICE PLUG @ 704' SLM, UNABLE TO CONT. RIG DOWN. 03/17/02 PUMP .2 BBLS MEOH DOWN TUBING, PRESSURED UP TO 3000 PSI. 03/29/02 MIRU UNIT #3 RIH W/2.5"DOWN JET NOZ, TAG PLUG @786'. FINISH CLEANOUT TO 1372, JET MEOH OVER GLVS, POOH FP FL, RDMO. PAD OP NOTIFIED WELL LEFT SI READY FOR SL. 03/30/02 SET SSCS - PULL CA E INT FROM STA-3 & STA-2 - SET CA BK INT, 16/64" PORT, 1756# TRO IN STA-3 @ 3663' MD - SET CA DKO INT, 20/64" PORT, OGLV IN STA-2 @ 6521'MD - PULL SSCS. - WELL READY TO POP. 04/02/02 ATTEMPT TO BREAK HYDRATE PLUG IN TBG BY PUMPING DOWN IA. 10 BBLS OF METH AND 10 BBLSOF CRUDE PUMPED DOWN IA. 04/03/02 CLEAN HYDRATE ICE PLUG OUT OF WELL. BRIDGES FROM 440' - 550' &1127 - 1130'. PUMP 50 BBLS 180 DEG DIESEL DOWN I/A. FP TBG WITH 60/40 METH. TO 2500'. LEFT WELL SHUT IN. ANADRILL SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Borealis, L-Pad Well...................... L-106 API number ................ 50-029-23055-00 Engineer .................. Franco COUNTY :................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Methodfor positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 50.40 ft KB above permanent.......: N/A DF above permanent.......: 79.22 ft ----- Vertical section origin ---------------- Latitude (+N/S-)......... 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point --------------- Latitude (+N/S-).........:-999.25 ft Departure (+E/W-)........:-999.25 ft Azimuth from rotary table to target: 345.00 degrees [(c)2002 Anadrill IDEAL ID6_1C_101 10-Jan-2002 01:55:38 Page 1 of 4 Spud date ................. 03-Jan-02 Last survey date.........: 10-Jan-02 Total accepted surveys...: 82 MD of first survey.......: 0.00 ft MD of last survey........: 7455.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date ............: 31-Dec-2001 Magnetic field strength..: 1149.07 HCNT Magnetic dec (+E/W-).....: 26.14 degrees Magnetic dip .............. 80.75 degrees ----- MWD survey Reference Criteria --------- Reference G..............: 1002.68 mGal Reference H..............: 1149.07 HCNT Reference Dip ............: 80.75 degrees Tolerance of G...........: (+/-) 2.50 mGal Tolerance of H...........: (+/-) 6.00 HCNT Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)..... : 26.14 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).... : 26.14 degrees (Total az corr = magnetic dec - grid conv) Sag applied (YIN)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 10-Jan-2002 01:-55:38 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Dis 1 Dis l Total At Azim DLS (deg/ Srvy tool Tool qual # depth angle angle length depth section +N/S- +E/W- dis 1 - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 109.65 0.21 285.86 109.65 109.65 0.10 0.05 -0.19 0.20 285.86 0.19 MWD Inc. Only 3 200.89 0.19 277.16 91.24 200.89 0.25 0.12 -0.50 0.52 283.33 0.04 MWD_IFR MSA 4 293.49 1.02 335.63 92.60 293.48 1.12 0.89 -1.00 1.34 311.74 1.01 MWD_IFR_MSA 5 386.93 2.54 334.97 93.44 386.88 3.98 3.52 -2.22 4.16 327.83 1.63 MWD_IFR_MSA 6 480.14 4.22 338.37 93.21 479.92 9.42 8.58 -4.35 9.62 333.10 1.81 MWD_IFR MSA 7 572.61 5.14 343.03 92.47 572.08 16.94 15.71 -6.82 17.12 336.54 1.08 MWD IFR_MSA 8 665.49 5.48 343.98 92.88 664.56 25.53 23.95 -9.26 25.68 338.87 0.38 MWD_IFR_MSA 9 754.56 5.64 346.39 89.07 753.21 34.16 32.29 -11.46 34.26 340.46 0.32 MWD_IFR_MSA 10 847.16 6.10 346.45 92.60 845.33 43.62 41.50 -13.68 43.69 341.75 0.50 MWD_IFR_MSA 11 941.06 6.79 353.06 93.90 938.64 54.11 51.86 -15.52 54.13 343.33 1.08 MWD_IFR_MSA 12 1034.89 7.82 3.70 93.83 1031.71 65.65 63.73 -15.78 65.66 346.09 1.81 MWD_IFR_MSA 13 1128.36 9.58 16.97 93.47 1124.11 78.27 77.52 -13.10 78.62 350.41 2.84 MWD_IFR_MSA 14 1221.90 10.40 22.37 93.54 1216.23 91.58 92.77 -7.62 93.09 355.31 1.33 MWD_IFR_MSA 15 1316.21 10.82 29.74 94.31 1308.93 104.64 108.33 0.02 108.33 0.01 1.51 MWD_IFR_MSA 16 1408.35 10.91 38.74 92.14 1399.43 115.94 122.64 9.76 123.03 4.55 1.84 MWD_IFR_MSA 17 1500.80 11.32 50.91 92.45 1490.15 124.82 135.19 22.28 137.02 9.36 2.57 MWD_IFR_MSA 18 1593.61 11.10 51.27 92.81 1581.19 132.13 146.52 36.32 150.96 13.92 0.25 MWD_IFR_MSA 19 1687.89 12.38 51.11 94.28 1673.50 139.88 158.55 51.27 166.63 17.92 1.36 MWD_IFR_MSA 20 1782.66 14.37 54.61 94.77 1765.70 148.09 171.74 68.76 184.99 21.82 2.27 MWD IFR_MSA 21 1877.52 16.04 60.30 94.86 1857.24 155.52 185.05 89.75 205.67 25.87 2.36 MWD_IFR_MSA 22 1970.91 16.26 68.20 93.39 1946.95 160.34 196.30 113.10 226.55 29.95 2.36 MWD_IFRMSA 23 2063.60 16.03 76.62 92.69 2036.00 161.51 204.08 137.60 246.14 33.99 2.54 MWD_IFR_MSA 24 2157.52 16.34 87.34 93.92 2126.22 158.32 207.70 163.42 264.28 38.20 3.19 MWD_IFR MSA 25 2249.84 17.69 92.09 92.32 2214.50 151.43 207.79 190.41 281.84 42.50 2.10 MWD_IFR_MSA 26 2342.30 19.53 92.85 92.46 2302.12 142.56 206.51 219.89 301.65 46.80 2.01 MWD IFR_MSA 27 2434.75 22.09 94.32 92.45 2388.53 132.07 204.43 252.66 325.01 51.02 2.83 MWD_IFR_MSA 28 2528.18 24.82 92.32 93.43 2474.24 120.42 202.31 289.78 353.41 55.08 3.04 MWD IFR_MSA 29 2622.13 25.57 90.58 93.95 2559.25 109.10 201.31 329.76 386.35 58.60 1.12 MWD IFR_MSA 30 2671.89 25.37 90.34 49.76 2604.17 103.40 201.14 351.16 404.68 60.20 0.45 MWD_IFR_MSA ((c)2002 Anadrill IDEAL ID6_1C_101 ANADRILL SCHLUMBERGER Survey Report 10-Jan-2002 01:55:38 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +NIS- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) ----- (deg) 100f) type type 31 2776.55 25.51 89.39 104.66 2698.68 91.86 201.24 396.11 444.30 63.07 0.41 MWD_IFR_MSA 32 2869.17 25.28 92.31 92.62 2782.36 81.02 200.66 435.82 479.79 65.28 1.37 MWD IFR_MSA 33 2962.09 25.34 96.19 92.92 2866.36 67.93 197.71 475.41 514.89 67.42 1.79 MWD_IFR_MSA 34 3055.06 25.54 93.49 92.97 2950.32 54.38 194.35 515.20 550.64 69.33 1.27 MWD_IFR_MSA 35 3149.10 25.15 94.16 94.04 3035.31 41.40 191.67 555.36 587.51 70.96 0.51 MWD_IFR MSA 36 3242.67 24.84 90.13 93.57 3120.12 29.74 190.18 594.85 624.51 72.27 1.85 MWD_IFR_MSA 37 3334.81 24.52 89.22 92.14 3203.85 19.99 190.39 633.32 661.32 73.27 0.54 MWD_IFR_MSA 38 3428.30 24.26 89.10 93.49 3288.99 10.55 190.96 671.92 698.53 74.13 0.28 MWD_IFR_MSA 39 3520.70 25.55 88.69 92.40 3372.80 1.21 191.71 710.83 736.23 74.91 1.41 MWD_IFR_MSA 40 3614.41 25.45 87.82 93.71 3457.38 -8.04 192.94 751.15 775.53 75.59 0.41 MWD_IFR_MSA 41 3708.75 25.29 93.58 94.34 3542.64 -18.96 192.45 791.52 814.58 76.33 2.62 MWD_IFR_MSA 42 3801.03 25.30 93.23 92.28 3626.07 -31.41 190.11 830.88 852.35 77.11 0.16 MWD_IFR_MSA 43 3897.28 24.83 90.45 96.25 3713.26 -43.23 188.80 871.63 891.84 77.78 1.32 MWD_IFR_MSA 44 3990.20 25.03 91.76 92.92 3797.52 -54.10 188.04 910.78 929.99 78.33 0.63 MWD_IFR_MSA 45 4084.22 24.79 95.34 94.02 3882.80 -66.69 185.59 950.29 968.25 78.95 1.62 MWD_IFR_MSA 46 4177.52 24.86 96.97 93.30 3967.48 -80.82 181.39 989.23 1005.73 79.61 0.74 MWD_IFR_MSA 47 4270.72 26.11 93.16 93.20 4051.61 -94.54 177.88 1029.16 1044.42 80.19 2.21 MWD IFR_MSA 48 4364.72 26.41 93.66 94.00 4135.91 -107.68 175.41 1070.68 1084.95 80.70 0.40 MWD_IFR MSA 49 4457.52 27.04 92.64 92.80 4218.80 -120.68 173.12 1112.35 1125.74 81.15 0.84 MWD_IFR_MSA 50 4518.70 27.69 93.72 61.18 4273.13 -129.45 171.56 1140.42 1153.26 81.44 1.34 MWD_IFR_MSA 51 4612.69 26.47 93.99 93.99 4356.82 -143.28 168.68 1183.11 1195.08 81.89 1.30 MWD_IFR_MSA 52 4705.93 25.86 92.99 93.24 4440.50 -156.32 166.18 1224.15 1235.38 82.27 0.81 MWD_IFR_MSA 53 4798.95 24.98 93.00 93.02 4524.52 -168.66 164.09 1264.02 1274.63 82.60 0.95 MWD_IFR_MSA 54 4892.40 23.72 92.48 93.45 4609.65 -180.40 162.24 1302.51 1312.57 82.90 1.37 MWD_IFR_MSA 55 4986.78 22.85 90.85 94.38 4696.34 -191.11 161.15 1339.80 1349.45 83.14 1.15 MWD_IFR MSA 56 5080.04 21.98 90.21 93.26 4782.56 -200,.63 160.82 1375.36 1384.73 83.33 0.97 MWD_IFR_MSA 57 5173.60 21.64 89.47 93.56 4869.42 -209.54 160.91 1410.12 1419.27 83.49 0.47 MWD_IFR_MSA 58 5266.51 20.54 88.80 92.91 4956.11 -217.70 161.41 1443.54 1452.54 83.62 1.21 MWD_IFR_MSA 59 5359.25 20.69 92.98 92.74 5042.91 -226.64 160.90 1476.17 1484.92 83.78 1.59 MWD_IFR_MSA 60 5452.36 20.01 92.61 93.11 5130.21 -236.54 159.32 1508.51 1516.90 83.97 0.74 MWD_IFR_MSA [(c)2002.Anadrill IDEAL ID6_1C_101 ANADRILL SCHLUMBERGER Survey Report 10-Jan-2002 01:55:38 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +NIS- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 61 -------- 5546.65 ------ 18.89 ------- 101.30 ----- 94.29 5219.14 -248.19 155.60 1539.60 1547.45 84.23 3.29 MWD IFR MSA 62 5640.11 19.14 100.43 93.46 5307.50 -261.47 149.86 1569.51 1576.65 84.55 0.40 MWD IFR_MSA 63 5733.73 18.35 98.57 93.62 5396.15 -273.95 144.88 1599.17 1605.72 84.82 1.06 MWD IFR MSA 64 5826.23 17.41 97.95 92.50 5484.18 -285.17 140.80 1627.28 1633.36 85.05 1.04 MWD_IFR_MSA 65 5919.60 16.09 97.92 93.37 5573.59 -295.66 137.08 1653.93 1659.60 85.26 1.41 MWD_IFR_MSA 66 6011.67 13.66 96.91 92.07 5662.57 -304.68 134.02 1677.36 1682.71 85.43 2.65 MWD_IFR_MSA, 67 6105.71 11.04 96.21 94.04 5754.42 -312.09 131.71 1697.34 1702.44 85.56 2.79 MWD IFR MSA 68 6199.37 8.26 96.27 93.66 5846.75 -317.77 130.00 1712.95 1717.87 85.66 2.97 MWD_IFR_MSA 69 6293.38 6.43 97.58 94.01 5939.98 -322.24 128.57 1724.88 1729.66 85.74 1.95 MWD_IFR_MSA 70 6387.05 5.23 94.55 93.67 6033.17 -325.69 127.54 1734.33 1739.02 85.79 1.32 MWD_IFR MSA 71 6481.55 3.53 99.78 94.50 6127.39 -328.35 126.70 1741.49 1746.10 85.84 1.85 MWD_IFR.MSA 72 6575.18 2.59 106.13 93.63 6220.88 -330.65 125.63 1746.37 1750.88 85.89 1.07 MWD_IFR_MSA 73 6668.86 1.68 103.99 93.68 6314.50 -332.41 124.71 1749.73 1754.17 85.92 0.97 MWD_IFR_MSA 74 6760.71 1.42 94.47 91.85 6406.31 -333.44 124.29 1752.17 1756.58 85.94 0.40 MWD_IFR MSA 75 6852.94 1.09 91.58 92.23 6498.52 -334.07 124.18 1754.19 1758.58 85.95 0.36 MWD_IFR_MSA 76 6945.02 1.28 72.00 92.08 6590.58 -334.27 124.47 1756.04 1760.45 85.95 0.48 MWD_IFR_MSA 77 7039.79 1.13 72.54 94.77 6685.33 -334.17 125.08 1757.94 1762.39 85.93 0.16 MWD IFR MSA 78 7133.55 0.86 72.66 93.76 6779.08 -334.10 125.57 1759.50 1763.97 85.92 0.29 MWD_IFR MSA 79 7226.53 0.67 59.26 92.98 6872.05 -333.93 126.05 1760.63 1765.14 85.90 0.28 MWD_IFit MSA 80 7319.28 0.57 339.24 92.75 6964.80 -333.32 126.76 1760.93 1765.49 85.88 0.86 MWD_IFR_MSA 81 7402.14 1.14 290.50 82.86 7047.65 -332.43 127.44 1760.01 1764.62 85.86 1.06 °MWD_IFR_MSA Final Projected Survey: 82 7455.00 1.14 290.50 52.86 7100.50 -331.82 127.80 1759.03 1763.66 85.84 0.00 Projected [(c)2002 Anadrill IDEAL ID6_iC_10) SchWhopgr Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # Log Description NO. 1910 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7fh Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Date Color Sepia BL CD L-104 22110 SCMT 02/11/02 2 L-106 YoZoZ 22111 SCMT 02/10/02 2 S-105 Qp -/,5 a PROD PROFILE/DEFT/GLS 02/28/02 1 1 L-120 22086 PP IMP DATA 02/09/02 1 L-120 - O 22086 MD VISION RESISTIVITY 02/09/02 1 1 L-120 22086 TVD VISION RESISTIVITY 02/09/02 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnicai Data Center LR2-1 ��1�� 900 E Benson Blvd. Anchorage AK 99508-4254 MAR 2 ,_. 2002 Date Delivered: er__r._....., .. _ _ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Receive by: ` 3/20/2002 schhMkopgop Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # Log Description NO. 1897 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia BL CD L-111 abQ-nso 22104 ARC D/N DATA (PDC) 02/27/02 1 L-111 22104 MD VISION RESISTIVITY 02/27/02 1 1 L-111 22104 TVD VISION RESISTIVITY 02/27/02 1 1 L-111 22104 MD VISION D/N 02/27/02 1 1 L-111 22104 TVD VISION D/N 02/27/02 1 1 L-106 j-aa STATIC BOTTOM HOLE PRESSURE 02/20/02 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 J 12002 Date Delivered: MalftcMaftwistallgown Ancbe Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received: v J 3/12/2002 Schkmbepgr Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # Log Description NO. 1858 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia BL CD L-106 22026 PEX AIT DSI (PDC) 01/04-10102 1 L-106 22026 PEX-AIT 01/04-10/02 1 1 L-106 22026 PEX-CNL-LITHODENSITY 01/04-10/02 1 1 L-106 22026 PEX-TRIPLE COMBO 01/04-10/02 1 1 L-106 22026 PEX-DIPOLE SONIC 01/04-10/02 1 1 L-106 22026 PEX-TVD 01/04-10/02 1 1 L-106 22026 PEX-CALIPER 01/04/02 1 1 L-106 22026 PEX-CALIPER 01/10/02 1 1 L-106 22026 RFT 01/10/02 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, RECEIVED Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 MiAR o 5 2002 Date Delivered: egUiRkA(]IIRC. riffle Anchorage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received b 3/1/2002 schlumbepgep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COP`! EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 RECEIVED 900 E Benson Blvd. Anchorage AK 99508-4254 n nnn Date Delivered: Aft8(M&CM$C=-CMMM— Andwp NO. 1849 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie MMMMMMMMM--M' M� 2/27/2002 schlumbemp Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Well Job # NO. 1815 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Log Description Date Color Sepia BL CD i .SONIC • - • r r r ©--- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. r E11"D Petrotectnical Data Center LR2-1 REC 900 E Benson Blvd. Anchorage AK 99508-4254 FEB 19 2002 Date Delivered: Aniftap Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATfN: Sherrie Receive b : 2/18/2002 chkmhepr NO. 1767 Alaska Data and Consulting Services Company: Alaska Oil & Gas Cons Comm 3940 Arctic Blvd, Suite 300 Attn: Lisa Weepie Anchorage, AK 99503-5711 333 West 7th Ave, Suite 100 ATTN: Sherrie Anchorage, AK 99501 Field: Borealis Well Job # Log Description Date Color Sepia BL CD L-106 1 22025 ISONIC PROCESSING 01/04/02 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. ��Pc'�� Anchorage AK 99508-4254 FEB 0 12002 Date Delivered: Andto W Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie 1/30/2002 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-106 Date Dispatched: 10-Jan-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosei @slb.com Fax: 907-561-8417 Al aska i Gas Cons, dY1m1sSIgF s A»c!-Eorage o ALASKA 0 TON Y KNIWLES, GOVERNOR �K1AT 011L A�GAS t�T tt CONSERQATIOas CO��s USSIOls 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit L-106 BP Exploration (Alaska), Inc. Permit No: 201-223 Sur Loc: 2419' NSL, 3559' WEL, Sec. 34, T12N, R11E, UM Btmhole Loc. 2576' NSL, 1734' WEL, Sec. 34, T12N, R11E, UM Dear Mr. Crane: 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 permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L-106. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, oteltAL -Id-� Cammy Oechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 3rd day of December, 2001 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA, L AND GAS CONSERVATION COMi` 'SION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ® Drill ❑ Redrill T7Type of well ❑ Exploratory ❑ Stratigraphic Test ® Development Oil ❑ Re -Entry ❑ Deepen ❑ Service ❑ Development Gas ❑ Single Zone ❑ Multiple Zone 2. Name of Operator 5 Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 77' Prudhoe Bay Field / Borealis Pool (Undefined) 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028239 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2419' NSL, 3559' WEL, SEC. 34, T12N, R11 E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2576' NSL, 1734' WEL, SEC. 34, T12N, R11 E, UM L-106 Number 2S100302630-277 At total depth 9. Approximate spud date 2576' NSL, 1734' WEL, SEC. 34, T12N, Fit E, UM 12/15/01 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028238, 1734' MD No Close Approach 2560 7484' MD / 7110' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)) Kick Off Depth 300' MD Maximum Hole Angle 25 o Maximum surface 2902 psig, At total depth (TVD) 6457' / 3560 psig 18. Casing Program Specifications Setting DepthSize T Bottomoo Quantity of Cement Hole in W i ht Grade Cour)lina Len th MD TVD MD TVD(include t t 42" 34" x 20" 91.5# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set (Approx.) 9-7/8" 7-5/8" 29.7# L-80 BTC 2631' Surface Surface 2631' 2579' 286 sx AS Lite 133 sx Class 'G' 6-3/4" 5-1/2" 15.5# L-80 BTC-M 6801' Surface Surface 6801' 6425' 209 sx Class'G' 6-3/4" 3-1/2" 9.2# L-80 IBT-M 683' 6801' 6425' 7484' 7109' (Longstring Cemented with 5-1/2" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate' Production ® ;x L Li Liner NOV 14 2001 Alaska Oil & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments M Filing Fee ❑ Property Plat ❑ BOP Sketch ❑ Diverter Sketch ® Drilling Program ® Drilling Fluid Program ❑ Time vs Depth Plot ❑ Refraction Analysis ❑ Seabed Report ❑ 20 AAC 25.050 Requirements Contact Engineer Name/Number: Robert O nthal, 564-4387 Prepared By Name/Number.Terrie Hubble, 564-4628 21. 1 hereby certify that the foregoi is true and coVtt to the best of my knowledge Signed Lowell Crane Title Senior Drilling Engineer Date r> - Gcr>ttiioni tls�+,Qn Permit Number API Number Approval Date See cover letter 2LU / 50- 0-Z — 2 sc, for other requirements Conditions of Approval: Samples Required ❑ Yes Ed o Mud Log Required ❑ Yes � No Hydrogen Sulfide Measures ❑ Yes No Directional Survey Required E Yes ❑ No Required Working Pressure for BOPE ❑ 2K ❑ 3K ❑ 4K ❑ 5K ❑ 10K ❑ 15K ❑ 3.51K psi f U Other: �50`� S� �� es�c- w.:��. c�v.r-� n�vQc v-3G�x2 �'NO�G Pp Signed by order of Original Y Approved B Commissioner the commission Date Form 10-401 Rev. 12-01-85 t,ett°i)y OkIGINAL Submit In"Triplicate Well Name: I L-106 Drill and Complete Plan Summary Type of Well service /producer/ injector): jProducer Surface Location: X = 583,357.31' Y = 5,978,142.99' As -Built 2419' FSL, 3559' FEL, Sec. 34, T12N, R11E Target Location: X = 585,180' Y = 5,978,320' 2576' FSL, 1734' FEL, Sec. 34, T12N, R11 E Bottom Hole Location: X = 585,180' Y = 5,978,320' 2576' FSL, 1734' FEL, Sec. 34, T12N, R11 E AFE Number: 15M4018 Rig: Nabors 9ES Estimated Start Date: 112/15/20021 1 Operating days to com lete: 112.9 MD: 17484.' TVD: I BF/MS: 47.0' 1 1 RKB: 77.0' Well Design conventional, slimhole, etc.: Microbore Ion strip ) Objective: I Ku aruk Formation Mud Program: 9-7/8" Surface Hole (0-2631'): Spud Mud Density Viscosity seconds Yield Point Ib/1— 00� API FL mis/30min PH Initial 8.5 - 8.6 300 50 — 70 15 — 20 8.5 — 9.5 below Permafrost 9.3 - 9.5 200 45 — 60 < 10 8.5 — 9.5 interval TD 9.6 max 200 45-60 1 < 8 8.5 — 9.5 6 3/4" Intermediate / Production Hole (2631' — 7485'): LSND Interval Density Tau o YP PV pH API HTHP (pp) Filtrate Filtrate Upper 9.3-9.5 4-7 20-25 8-12 8.5-9.5 4-6 Interval Top of 10.6 5-8 20-25 12-20 8.5-9.5 3-5 <10 by I HRZ I I I I HRZ L-106 Permit to Drill Page 1 Directional: Ver. I (Anadrill) WP-04 KOP: 300' Maximum Hole Angle: 25.20 at 2576-5596' MD Close Approach Wells: All wells pass major risk criteria. Loaaina Proaram: Surface Drilling: MWD (GR /RES) Open Hole: Gas Detection, PEX (GR/DENT/NEUT/Di- pole Sonic) Cased Hole: None Production Hole Drilling: MWD(GR /RES) Open Hole: PEX, MDT, Gas Detection, Cuttings and Fluid samples Cased Hole: GR/CCL, USIT cement evaluation (contingency) Note: Di -pole sonic required 100' above and below Kuparak. RFT of 20 pressures samples from Kuparak/Schrader bluff each. Formation Markers: Formation Tops MDbkb TVD Notes SV5 1568 1571 SV4 1722 1709 Base Permafrost 1871 1854 SV3 2072 2049 SV2 2248 2219 SV1 2565 2519 UG4A 2932 2851 UG3 3319 3202 UG1 3862 3693 Ma 4173 3974 WS2 N sands 4428 4205 WS1 O sands 4567 4331 Obf Base 5072 4788 CM2 Colville 5399 5084 THRZ 6582 6208 BHRZ Kalubik 6786 6412 K-1 6874 6500 TKUP 6951 6577 EMW=10.4 ppg Ku aruk C LCU Ku aruk B Ku aruk A TMLV Miluveach 7484 7110 L-106 Permit to Drill Page 2 Casing/Tubing Program: Hole Size Csg/ Tbg O.D. Wt/Ft Grade Conn Length Top MD/TVD Btm MD/TVD bkb 42" 34 x 20" 91.5# H-40 WLD 80' GL 80/80 9-7/8" 7 5/8" 29.7# L-80 BTC 2631' GL 263172579' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 6801' GL 680176425' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 683' 1 680176425' 748477109' Tubing 3-1/2" 9.2# L-80 IBT-mod 6801' 1 GL 680176425' Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from LOT 14.8 ppg target surface shoe Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casino Size 17-5/8" Surface Basis: Lead: Based on 1871' of annulus in the permafrost @ 250% excess and 284' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2155' MD 2124' TVDbkb . Total Cement Volume: Lead 226 bbl / 1270ft / 286 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/sk. Tail 27.5 bbl / 155.6 ft / 133 sks of Dowell Premium `G' at 15.8 Ppq and 1.17 cf/sk. Casing Size 5-1/2"x3-1/2" Production Lon strin Basis: Lead: Based on TOC 1000' above top of Kuparuk formation & 30% excess + 80' shoe. Lead TOC: 5950' MD, 5590' TVDbkb Total Cement Volume: Lead 43.3 bbls / 244 ft / 208.5 sks of Dowell Premium `G' at 15.8 DDa and 1.17 cf/sk. Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 4500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. L-106 Permit to Drill Page 3 Production Interval- • Maximum anticipated BHP: 3560 psi @ 6457' TVDss — Kuparuk Sands • Maximum surface pressure: 2902 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: 4500 psi (for future frac stimulation treatments) • Planned completion fluid: 8.6 ppg filtered seawater or brine / 6.8 ppg Diesel Disposal: • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-106 Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre -Rig Work: The 20" conductor. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and/or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. (Diverter waiver applied for and pending approval) Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2631' MD / 2579' TVD. Surface hole TD will be +/-100' TVD below the top of the SV1 sand. POH LD BHA. 4. Perform open hole logging program of PEX/Di-pole Sonic. 5. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 6. ND diverter spool and NU casing / tubing head. 7. NU BOPE and test to 4500 psi. 8. MU 6-3/4" drilling assembly with MWD/GR/NEUT/DENS/RES and RIH to float collar. Test the 7 5/8" casing to 4500 psi for 30 minutes. 9. Drill out shoe joints and displace well to LSND drilling fluid. 10. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 11. Drill to ±100' above the HRZ, ensure mud is condition to 10.6 ppg and perform short trip as needed. During this time hold the 'Pre -Reservoir' meeting highlighting kick tolerance and detection. 12. Drill ahead to --150' of rat hole into the Miluveach formation. 13. Condition hole for logging and POOH. Make wiper trip as dictated by hole conditions. 14. Perform open hole logging program. Run PEX/Di-pole Sonic and RFT logs. 15. Condition hole for liner and POOH. 16. Run and cement the tapered production casing as required from TD to 1000' above the Kuparuk. Displace the casing with seawater during cementing operations and freeze protect the 5 1/2" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 5/8" shoe. Record on chart and submit to town.) 17. Test the casing to 4500 psi for 30 min. 18. Run the 3-1/2", 9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. 19. Sting seal assembly into tieback receptacle and test to 4500 psi for 30 minutes both the tubing and annulus. 20. Release tubing pressure and shear RP valve. 21. Install TWC and test from below to 2900 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. L-106 Permit to Drill Page 5 22. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to -3500' TVD. 23. Rig down and move off. Estimated Spud Date: 12-15-2002 L-106 Permit to Drill Page 6 L-106 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ➢ L-Pad is not designated as an H2S site. In the first seven wells drilled to date on this pad there has been no report H2S as being present. As a pre -caution, follow at all time the Standard Operating Procedures for H2S. ➢ The closest surface location is L-107. L-107 will be -80' wellhead to wellhead from the proposed well location. The well does not require a surface shut-in. Reference RPs Operational Specifics Job 2: Drilling and Logging Surface Hole Hazards and Contingencies ➢ In this interval, no faults should be penetrated. ➢ A surface gyro will be required while drilling the surface hole. All wells pass major risk criteria. ➢ There has been consistent observation of gas hydrates while drilling wells off this pad. Expect to encounter hydrates from the base of permafrost to the shoe setting depth. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation ➢ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RPs Operational Specifics Job 3: Install surface Casing Hazards and Contingencies ➢ It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at ±1000'MD to allow a secondary circulation as required. Reference RPs ., Operational Specifics L-106 Permit to Drill I Page 7 r Job 7: Drilling Production Hole Hazards and Contingencies ➢ KICK TOLERANCE: In the worst case scenario of 10.5 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 14.8 ppg at the surface casing shoe, 10.6 ppg mud in the hole, kick tolerance is 25.1 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 14.8 ppg. ➢ A fault is expected to be penetrated by L-106 in the base of the Schrader / top of Colville transition. at -5400' - 5500' TVDss. The throw is --75' down to the west. This is not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. Reference RPs Operational Specifics Job 8: Loq Production Hole Hazards and Contingencies ➢ Ensure the hole is in very good condition to avoid a stuck tool string ➢ If logging time is excessive or hole conditions dictate, perform an intermediate clean out run between logging runs. Reference RPs 4. Operational Specifics Job 9: Case & Cement Production Hole Hazards and Contingencies ➢ The 5-1/2" casing will be cemented to 1000' above the Kuparuk sand, the upper most hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with LWD resistivity log. ➢ If losses are encountered while running the production casing, be prepared to treat with barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 100% returns are not established. ➢ After freeze protecting the 51/2" x 7-5/8" casing annulus to 2600' with 83 bbls of dead crude, the hydrostatic pressure will be assuming a diesel column to surface casing point at 2579' TVD, with 1000' of 12.0 ppg cement above the top of Kuparuk at 5591' TVD and 10.6 ppg mud to 2579' TVD, the hydrostatic pressure will be equivalent to 9.3 ppg or 3138 psi. (This is below the reservoir pressure of 3498 psi at top of Kuparuk) It is essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ➢ Ensure a minimum hydrostatic equivalent of 10.6 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ➢ The well will be under -balanced after displacing the cement with sea water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. L-106 Permit to Drill Page 8 Reference RPs Operational Specifics Job 12: Run Completion Hazards and Contingencies ➢ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics Job 13: ND/NU/Release Rig Hazards and Contingencies ➢ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics L-106 Permit to Drill Page 9 Borealis L-106: Proposed Completion ITREE: 3-1/8" -5M CIW Carbon WELLHEAD: 11"- 5M FMCG5 7-5/8", 29.7 #/ft, L-80, BTC 2635' 5-1/2", 15.5 #/ft, L-80, BTC Plug Back Del 7400` 3-1/2", 9.2 #/ft, L-80, I 7,485` Cellar Elevation = 47' RKB - MSL = 77' 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 2200' 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS # MD Size Valve Type 1 TBD 1 " DV 2 TBD 1" DV 3 TBD 1" DV 2" 9.2# IBT Mod L-80, Tubing 3-1/2" Baker CM Sliding Sleeve al Asembly R O placed at +/-150' above the Kuparuk Formation ig Nipple with 2.813" seal bore ding Nipple with 2.813" seal bore and 2.666" No -Go ID. Date Rev By Comments 2-09-01 LRC Proposed Seal Bore Completion - WP3 Microbore with 5-1/2"x3-1/2" tapered longstring 1/17/01 BWS L-106 diagram 2-09-01 RSO L-106 Prop Comp. Borealis WELL: L-106 API NO: 50-029-????? BP Alaska Drilling & Wells L-106 Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: • Gas hydrates were observed in offset wells. These are expected to be encountered near the base of the Permafrost at 1850' and near the TD hole section as well. • Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: • The production section drilled with a recommended mud weight of 10.6 ppg to ensure shale stability in the HRZ shale. Read the Shale Drilling Recommended Practice. • Tight hole, hole packing -off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. • In the worst case scenario of 10.5 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 14.8 ppg at the surface casing shoe, 10.6 ppg mud in the hole, kick tolerance is 25.1 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 14.8 ppg. • A fault is expected to be penetrated by L-106 in the base of the Schrader / top of Colville transition at -5400' - 5500' TVDss. The throw is -75' down to the west. There is not a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. • L-Pad development may have "kick tolerances" in the 25 bbl range or less. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S • This drill -site not designated as an H2S drill site. Recent wells drilled on L-pad did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 L-106 Proposed Well Profile -Geodetic Report Report Date: October 26, 2001 Client: Alaska Drilling & Wells Field: Prudhoe Bay Unit - WOA (Drill Pads) Structure 1 Slot: L-Pad ! L 106 Well: L-106 F089 Borehole: L-106 UWUAPUI: Survey Name I Date: L-106 (P4) / October 26, 2001 Tort 1 AHD I DDI I ERD ratio: 65.394° / 1960.26 ft / 5.13010.27E Grid Coordinats System: NAD27 Alaska State Planes, Zone 4, US Feet Location UttLong: N 70.35025031, W 149.32323183 Location Grid WE YIX: N 5978142.990 ftUS, E 583357.310 ftUS Grid Convergence Angie: +0.63736049° Vertical Section Azimuth: 85.090° Vertical Section Origin: N 0.000 ft, E 0.000 fl TVD Reference Datum: KB TVD Reference Elevation: 78.6 ft relative to MSL Sea Bed I Ground Level Elevation: 44.100 ft relative to MSL Magnetic Declination: 26.151 ° Total Field Strength: 57468.877 nT Magnetic Dip: 80.759° Declination Date: December 30, 2001 Magnetic Declination Model: BGGM 2001 North Reference: True North Total Corr Mag North a True North: +26.151 ° Local Coordinates Referenced To: Well Head Schiumbepp KOP Bid 1/100 300.00 0.00 345.00 300.00 0.00 0.00 0.00 0.00 5978142.99 583357.31 N 70.35025031 W 149.32323183 400.00 1.00 345.00 399.99 -0.15 0.84 -0.23 1.00 5978143.83 583357.07 N 70.35025261 W 149.32323370 500.00 2.00 345.00 499.96 -0.61 3.37 -0.90 1.00 5978146.35 583356.37 N 70.35025952 W 149.32323914 600.00 3.00 345.00 599.86 -1.38 7.58 -2.03 1.00 5978150.55 583355.20 N 70.35027102 W 149.32324831 700.00 4.00 345.00 699.68 -2.45 13.48 -3.61 1.00 5978156.43 583353.55 N 70.35028714 W 149.32326114 800.00 5.00 345.00 799.37 -3.82 21.06 -5.64 1.00 5978163.98 583351.44 N 70.35030785 W 149.32327762 Cry 1.5/100 900.00 6.00 345.00 898.90 -5.50 30.32 -8.12 1.00 5978173.21 583348.85 N 70.35033314 W 149.32329775 1000.00 6.52 357.95 998.31 -6.13 41.04 -9.68 1.50 5978183.92 583347.18 N 70.35036243 W 149.32331041 1100.00 7.31 8.54 1097.59 -4.37 53.01 -8.94 1.50 5978195.89 583347.78 N 70.35039513 W 149.32330441 1200.00 8.30 16.86 1196.66 -0.21 66.21 -5.90 1.50 5978209.12 583350.67 N 70.35043119 W 149.32327973 1300.00 9.43 23.31 1295.47 6.34 80.65 -0.56 1.50 5978223.62 583355.85 N 70.35047064 W 149.32323638 1400.00 10.65 28.35 1393.94 15.28 96.30 7.07 1.50 5978239.35 583363.31 N 70.35051339 W 149.32317444 1500.00 11.93 32.34 1492.00 26.61 113.16 16.98 1.50 5978256.32 583373.03 N 70.35055945 W 149.32309399 SV5 1568.18 12.83 34.61 1558.60 35.69 125.34 25.05 1.50 5978268.59 583380.96 N 70.35059273 W 149.32302848 Cry 2/100 1581.05 13.00 35.00 1571.15 37.53 127.71 26.69 1.50 5978270.98 583382.58 N 70.35059920 W 149.32301516 1600.00 13.00 36.68 1589.61 40.31 131.16 29.19 2.00 5978274.45 583385.04 N 70.35060863 W 149.32299487 L-106 (P4) report.xis Page 1 of 3 10/26/2001-2:41 PM SW 1722.18 13.29 47.37 1708.60 60.54 151.70 47.73 2.00 5978295.20 583403.35 N 70.35066474 W 149.32284436 1800.00 13.69 53.82 1784.28 75.49 163.19 61.75 2.00 5978306.84 583417.24 N 70.35069613 W 149.32273054 End Cry 1845.64 14.00 57.41 1828.60 85.00 169.35 70.76 2.00 5978313.10 583426.18 N 70.35071296 W 149.32265740 Base Permafrost 1871.41 14.00 57.41 1853.60 90.52 172.71 76.01 0.00 5978316.52 583431.39 N 70.35072214 W 149.32261478 Cry 2/100 1897.18 14.00 57.41 1878.60 96.04 176.07 81.26 0.00 5978319.94 583436.60 N 70.35073132 W 149.32257216 1900.00 13.99 57.64 1881.34 96.64 176.43 81.84 2.00 5978320.30 583437.17 N 70.35073230 W 149.32256745 2000.00 13.79 65.94 1978.43 118.62 187.76 102.93 2.00 5978331.87 583458.14 N 70.35076325 W 149.32239624 SV3 2072.25 13.81 72.00 2048.60 135.16 193.94 119.00 2.00 5978338.22 583474.13 N 70.35078014 W 149.32226578 2100.00 13.86 74.31 2075.54 141.65 195.86 125.35 2.00 5978340.21 583480.46 N 70.35078538 W 149.32221423 2200.00 14.22 82.42 2172.56 165.69 200.72 149.06 2.00 5978345.34 583504.11 N 70.35079866 W 149.32202174 SV2 2247.52 14.48 86.11 2218.60 177.46 201.90 160.77 2.00 5978346.65 583515.81 N 70.35080188 W 149.32192668 2300.00 14.83 90.02 2269.37 190.72 202.34 174.04 2.00 5978347.23 583529.07 N 70.35080308 W 149.32181895 Bid 4/100 2321.79 15.00 91.58 2290.43 196.30 202.26 179.65 2.00 5978347.22 583534.68 N 70.35080286 W 149.32177341 2400.00 18.13 91.59 2365.38 218.45 201.64 201.93 4.00 5978346.84 583556.97 N 70.35080117 W 149.32159254 2500.00 22.13 91.59 2459.26 252.63 200.69 236.32 4.00 5978346.28 583591.36 N 70.35079857 W 149.32131336 SV1 2564.68 24.72 91.59 2518.60 278.18 199.98 262.02 4.00 5978345.85 583617.06 N 70.35079663 W 149.32110472 End Bid 2576.72 25.20 91.59 2529.51 283.22 199.84 267.10 4.00 5978345.77 583622.15 N 70.35079624 W 149,32106348 7-5/8" Csg Pt 2630.96 25.20 91.59 2578.60 306.17 199.20 290.19 0.00 5978345.39 583645.24 N 70.35079449 W 149.32087603 UG4A 2931.57 25.20 91.59 2850.60 433.33 195.66 418.11 0.00 5978343.27 583773.18 N 70.35078481 W 149.31983757 UG3 3319.48 25.20 91.59 3201.60 597.41 191.09 583.20 0.00 5978340.54 583938.29 N 70.35077229 W 149.31849735 UG1 3862.11 25.20 91.59 3692.60 826.95 184.70 814.13 0.00 5978336.72 584169.26 N 70.35075477 W 149.31662264 Me 4172.66 25.20 91.59 3973.60 958.31 181.05 946.29 0.00 5978334.54 584301.44 N 70.35074476 W 149.31554975 WS2 4427.95 25.20 91.59 4204.60 1066.30 178.04 1054.93 0.00 5978332.74 584410.10 N 70.35073650 W 149.31466781 WS1 4567.20 25.20 91.59 4330.60 1125.20 176.40 1114.19 0.00 5978331.76 584469.36 N 70.35073199 W 149.31418673 Obf Base 5072.26 25.20 91.59 4787.60 1338.84 170.45 1329.13 0.00 5978328.20 584684.34 N 70.35071564 W 149.31244183 CM2 5399.38 25.20 91.59 5083.60 1477.22 166.60 1468.35 0.00 5978325.90 584823.58 N 70.35070505 W 149.31131164 Drp 2/100 5596.50 25.20 91.59 5261.96 1560.60 164.28 1552.23 0.00 5978324.51 584907.47 N 70.35069867 W 149.31063070 5600.00 25.13 91.59 5265.13 1562.08 164.24 1553.72 2.00 5978324.49 584908.96 N 70.35069856 W 149,31061860 5700.00 23.13 91.59 5356.39 1602.69 163.11 1594.58 2.00 5978323.81 584949.83 N 70.35069545 W 149.31028690 5800.00 21.13 91.59 5"9.02 1640.11 162.07 1632.23 2.00 5978323.19 584987.48 N 70.35069259 W 149.30998126 5900.00 19.13 91.59 5542.91 1674.30 161.11 1666.62 2.00 5978322.61 585021.88 N 70.35068994 W 149.30970208 6000.00 17.13 91.59 5637.94 1705.21 160.25 1697.72 2.00 5978322.10 585052.98 N 70.35068757 W 149.30944961 6100.00 15.13 91.59 5734.00 1732.81 159.48 1725.49 2.00 5978321.64 585080.76 N 70.35068545 W 149.30922417 6200.00 13.13 91.59 5830.97 1757.06 158.81 1749.89 2.00 5978321.24 585105.16 N 70.35068361 W 149.30902609 L-106 (P4) report.xis Page 2 of 3 10/26/2001-2:41 PM 6400.00 9.13 91.59 6027.17 1795.40 157.74 1788.46 2.00 5978320.60 585143.74 N 70.35068066 W 149.30871298 6500.00 7.13 91.59 6126.16 1809.44 157.35 1802.59 2.00 5978320.37 585157.87 N 70.35067959 W 149.30859827 Top HRZ 6581.94 5.49 91.59 6207.60 1818.39 157.10 1811.59 2.00 5978320.22 585166.87 N 70.35067890 W 149.30852521 6600.00 5.13 91.59 6225.58 1820.05 157.06 1813.26 2.00 5978320.19 585168.54 N 70.35067879 W 149.30851165 6700.00 3.13 91.59 6325.32 1827.20 156.86 1820.45 2.00 5978320.07 585175.73 N 70.35067823 W 149.30845328 Base HRZ 6786.35 1.40 91.59 6411.60 1830.59 156.76 1823.86 2.00 5978320.01 585179.14 N 70.35067796 W 149.30842560 6800.00 1.13 91.59 6425.25 1830.89 156.75 1824.16 2.00 5978320.01 585179.44 N 70.35067793 W 149.30842316 End Drp 6856.36 0.00 91.58 6481.60 1831.44 156.74 1824.72 2.00 5978320.00 585180.00 N 70.35067790 W 149.30841862 K-1 6874.36 0.00 91.58 6499.60 1831.44 156.74 1824.72 0.00 5978320.00 585180.00 N 70.35067790 W 149.30841862 Top Kuparuk / C 6951.35 0.00 91.58 6576.59 1831.44 156.74 1824.72 0.00 5978320.00 585180.00 N 70.35067790 W 149.30841862 Target 6951.36 0.00 91.58 6576.60 1831.44 156.74 1824.72 0.00 5978320.00 585180.00 N 70.35067790 W 149.30841862 TMLV 7334.36 0.00 91.58 6959.60 1831.44 156.74 1824.72 0.00 5978320.00 585180.00 N 70.35067790 W 149.30841862 TD 5-1/2" Csg Pt 7484.37 0.00 91.58 7109.61 1831.44 156.74 1824.72 0.00 5978320.00 585180.00 N 70.35067790 W 149.30841862 Lenal Description: Surface: 2419 FSL 3559 FEL S34 T12N R11 E UM Target: 2576 FSL 1734 FEL S34 T12N R11 E UM BHL : 2576 FSL 1734 FEL S34 T12N R11 E UM Northino (Y) fftUS1 Eastina M fftUSI 5978142.99 583357.31 5978320.00 585180.00 5978320.00 585180.00 L-106 (P4) report.xis Page 3 of 3 10/26/2001-2:41 PM VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: L-106 (P4) Field: Prudhoe Bay Unit - WOA Structure: L-Pad Section At: 85.09 deg Date: October 26, 2001 0 --._. - -- - - -- -- _ __-- KOP Bld U100 300 MD 300 TVD 0.00• 345.00' az 0d W1 Schlumberger ----. CM 1.0/199 1000 - - --- . _ _ ___ _ ._ .__ _. _ - -- -- -- "0Mc-b99:TVD--- -- --_-.._- b.00. 345A0•ez .ba.prw• �. CM MOO 1561 MD 1571 TVD -= 13.W 35.00• ez 36 dsWL" SV5 1568 MO 1559 TVD End Cry 180 MD 1829 TVD - - -- - -- -- - - - - - - - r -1430• 67.(f`.� 85 dspYTre- - - - -- - - - - -- - - - SV4 1722 MD 1709 ND ,j' --.-Cn2MO01807MD 1879TVD-_ _ -- -_ - - - - -- - - -- -- - —�-~-- - - -- -- -- - - - - -_ -- -- -- - Base Permafrost 1871 MD 1854 ND 2000 14.W 57.41• az 98depanva _. _.__ - - - '- -- _ -- -- - - - - - - - - _ - - - - - - - - - - - - - - - - - OM 41100 2322 MD 2290 ND SV3 2072 MD 2049 ND _ __ - - _ __ _. - __ ._ _. _ - 15.00' 01.58' 198 d.pB t. __ - __ - -. - __ - - - - __ SV2 2248 MD 2219 ND -End 91d 2577 MD 25M TVD 25.20. 91.591 ez 283 depenuro SVt 2565 MO 2519 ND 741/r Cep Pt2831 MO 2579 ND -25.20. 91.Wu 3054eWwe - ND o � -- -- - - -- - - -- - - -- - -- - -- - - -- - -- - - - -- - UG4A 2932 MD 2651 C 3000 p - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - UG3 3319 MD 3202 ND Hold Angle 25.20e vo UG1 3862 MD 3693 ND Q Co Q`m' nnn 4VW -... __ ___-___--.. -.._-_..-.-....-..--..--.._-. .._-...-.. _..._..--:._. .-_..-.__ -.._-. - -...---...-_-__-._. Ma 4113 MD 3974 ND cc WS2 4428 MD 4205 ND 0 _ - - ._ __. - __ - - - _ - - - - _ - _ - __ __ - - .__ - _ - - - - _ _ - - - - WS1 4567 MD 4331 ND 2 _ - - - __ _ - _. - - - - - - - - __ - - - - _ _ - _ _ _ - - __ - - - - - - OM Base 5072 MO 4788 ND 1— 5000 -- -- - - 2mo _. — -- 5507 MD 5262 WD - - - - - - - - - - - - - - -- - - - b.20 91.69• az - - - - CM2 5399 MD 5084 ND 1581 depenue End Dry NN MO 6482 TVD 000• 91.59• a _ 1831 depunxe - - - _ - - - __ Top HRZ 6582 MD 6208 ND MIMD 6577 NO Base 874 D 6 00 VD ND - - - K-1 6874 MD 6500 ND -O.QO. 91.Wa _ - Top Kuparuk1C 6951 MD 6577TVD 1831 d*Wun TD 5.1w Ce9 Pt -- - -- - --- -- - - - - - - - - - - - - - _ - - -- 1LV 1334 MD 6960 TVD V.w�...... - - _ 4fl4.MD_71.1D ND . 1831 depenve -1000 0 1000 2000 3000 Vertical Section Departure at 85.09 deg from (0.0, 0.0). (1 in = 1000 feet) 1000• A A A 2 w 500• Z 0• -1000' PLAN VIEW Client: Alaska Drilling & Wells Well: L-106 (P4) Field: Prudhoe Bay Unit - WOA Structure: L-Pad Scale: 1 in = 500 ft Date: 26-Oct-2001 -500 0 500 1000 15( Schlumberger 2000 2500 True North Mag Dec ( E 26.150 ) N &d 4H00 EM Btd End Orp 6856MD 6482TVD . Taryat 6951 t 6577 TVD " 2322 MO 2290 ND Y57T MD 2530 TVD 0.00. 91.58' ai 0.00• 91.58' az 1b.00' 91.58'. u: 2520' 91.w - 7.5r9- Cap Pt DrP 21100 tb7 N 1825E 167 N 1626 E 202 N 180E \ 20D N 267 E 2631 MO 2679 TVD 5597 MD 6262 ND " 25.20' 91.59•u 520 91.59• u j Cm 2JI 00 199 N 200 E 1897 MD 1879 ND 164 N 1552 E . 14.00' 57A1' u 176 N 81 E \ i I TD:ICap Pt End Crv—._ 746rr MD 7110 ND 1846 MD 1829 NO 0.00 91.68• u " 14.00' 67A1• a 167 N 1825E 169 N 71 E Cry L700 \ Cry 1.51100 . 1561 MD 1671 N90 D 0 MD 899 iVD' "- 13.00' 35.OV 6.00• 345.00'u . 128 N 27 E '\ 30 N 8 W KOP BM 11100 300 MD 300 TVD 0.00' 345.00' m ON OE -500 0 500 1000 1500 2000 2500 <<< WEST EAST >>> •1000 500 '0 -500 •-1000 Schlumberger Anticollision Report Company:BPAmoco " Date 10/26/2001 "=irne` 14:37:52 Page: Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NEj Reference.. =Well: L-906, True North Reference Well: L-166 Vertical (TVD) Reference" : . " i L7106 plan 78.6 Reference Wellpath: Plan L-106 Ab: " Sybase F NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 7484.37 it Scan Method: Trav Cylinder North Maximum Radius: 1500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/21/2000 Validated: No Version: 8 Planned From To Survey Toolcode Tool Name ft ft 28.50 500.00 Planned: Plan #4 V1 CB -GYRO -SS Camera based gyro single shots 500.00 7484.37 Planned: Plan #4 V1 MWD MWD - Standard Casing Points MD ' TVD Diameter Hole Size Name ft ft ' in in 2630.96 2578.60 7.625 8.500 7 5/8" 7484.37 7109.53 5.500 6.000 5 1 /2" Summary < Offset Wellpath ---s Reference Offset Ctr-Ctr No -Go Allowable Site Well ; Wellpath MD MD Distance Area Deviation Warning It ft ft ft ft EX NWE#1 NWEl-01 NWEl-01 V3 299.99 300.00 446.77 6.16 440.61 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01A V0 299.99 300.00 446.77 6.16 440.61 Pass: Major Risk EX NWE#1 NWE1-02 NWE1-02 V2 1665.44 1700.00 267.88 32.19 235.83 Pass: Major Risk PB L Pad L-01 L-01 V14 599.16 600.00 104.19 10.74 93.45 Pass: Major Risk PB L Pad L-104 PB L Pad L-107 PB L Pad L-110 PB L Pad L-114 Plan L-104 V3 Plan: L- L-107 V14 L-110 V11 L-114 V14 499.75 745.69 449.72 899.46 500.00 750.00 450.00 900.00 30.87 66.14 220.65 293.83 10.70 20.17 13.74 52.41 9.30 211.36 14.26 279.57 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk PB L Pad L-115 L-115 V7 1009.20 1000.00 233.67 16.00 217.78 Pass: Major Risk PB L Pad L-116 L-116 V10 995.19 1000.00 187.63 15.88 171.75 Pass: Major Risk PB L Pad L-117 L-117 V11 965.70 950.00 251.13 15.52 235.75 Pass: Major Risk Target: L-106 Tgt --,-'Iell: L-106 Site: PB L Pad Drilling Target Conf.: 99% .cased on: Planned Program Centre Location: Vertical Depth: 6498.00 ft below Mean Sea Level Map Northing: 5978320.00 ft Local +N/-S: 156.83 ft Map Easting : 585180.00 ft Local +E/-W: 1824.71 ft Latitude: 70°21'02.440N Longitude: 149'18'30.307W Polygon +N/-S ft +E/-W ft Northing ft Easting ft 1 302.22 -196.68 5978620.00 584980.00 2 297.57 223.33 5978620.00 585400.00 3 -302.45 216.68 5978020.00 585400.00 4 -297.79 -203.33 5978020.00 584980.00 100 600 500 Q0 300 200 100 0 -100 -200 -300 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o r— ao o- o — N m CV CV C\1 CV L-106 Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: • Gas hydrates were observed in offset wells. These are expected to be encountered near the base of the Permafrost at 1850' and near the TD hole section as well. • Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: • The production section drilled with a recommended mud weight of 10.6 ppg to ensure shale' stability in the HRZ shale. Read the Shale Drilling Recommended Practice. • Tight hole, hole packing -off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. • In the worst case scenario of 10.5 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 14.8 ppg at the surface casing shoe, 10.6 ppg mud in the hole, kick tolerance is 25.1 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 14.8 ppg. • A fault is expected to be penetrated by L-106 in the base of the Schrader / top of Colville transition at -5400' - 5500' TVDss. The throw is -75` down to the west. There is not a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. • L-Pad development may have "kick tolerances" in the 25 bbl range or less. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S This drill -site not designated as an H2S drill site. Recent wells drilled on L-pad did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 L-106 Subject: L-106 Date: Fri, 30 Nov 2001 18:29:11 -0600 From: "Odenthal, Robert S" <OdenthRS@BP.com> To: "'tom_maunder@ ad min. state. ak.us"' <tom maunder@admin.state.ak.us> Dear Mr. Maunder: I forgot to put the stuff in for a SSSV when filling out the permit to drill paperwork. 1 know under Conservation rule 98a that this is required. Julie from your office said I needed to write this to you so you would have for your records. If you need anything else so I can get the permit for L-106 please let me know. Robert S. Odenthal BP Exploration Alaska Drilling Engineer Work # : 907-564-4387 Cell #: 907-440-0185 E-mail: odenthrs@bp.com 1 of 1 11/30/01 4:08 PM ME14 I&W P 3 To: Tom Maunder, AOGCC From: Robert S. Odenthal Subject: Dispensation for 20 AAC 25.035 (c) on L-115 Date: November 14, 2001 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale for the request. To date, none of the 5 Borealis/Ivishak wells at L-pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All five of the surface holes for the Borealis Development (L-116, L-110, L-114, L-115 and L-107) and the first Ivishak well (L-01) were drilled to the shale underlying the SV-1 sands. The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is ±300' TVD above the Ugnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-106 is planned to reach 9.6 ppg mud weight before TD at 2,500' TVDss. This request is being made based on the previously submitted mud weight and RFT data for L-Pad, (Permit # 201-167 well L-117.) Your consideration of the waiver is appreciated. Sincerely, Robert S. Odenthal GPB Operations Drilling Engineer 564-4387 r❑ 500 1500 G H w 2000 0 2500 3000 3500 Borealis Surface Hole Mud Weight MW (PPg) 8 8.5 9 9.5 10 �- L-01 -�L-116 -�L-110 -0- L-114 --*-Pore Pressure —� L-107 NM 8/22/2001 L-117 Drilling Permit DATE CHECK NO. Fo 9/.28/OI OOi98 440 H 198740 VENDOR ALASKAO I LA 00 GROSS DISCOUNT NET DATE INVOICE / CREDIT MEMO DESCRIPTION 10d dd 092701 CK092701D 100.00 H PYMT OMMENTS: Per it to Drill ee MANDL NG INST: SIH — Terri Hu6b a X4628 L_- J ob THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. u FIRST NATIONAL BANK OF ASHLAND NO. H 1 6 1 4 U BP EXPLORATION, (ALASKA) INC. AN AFFILIATE OF CONSOLIDATED COMMERCIAL ACCOUNT NATIONAL CITY BANK P.O. BOX 196612 CLEVELAND, OHIO ANCHORAGE,:ALASKA 99519-6612 56.389 00198740 PAY To The ORDER Of Its L98740nm i:04 L 203895I: 00844 L91" TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME &'( Z - �D CHECK 1 CHECK WHAT APPLIES STANDARD LETTER ADD-ONS OPTIONS "CLUE" DEVELOPMENT MULTILATERAL The permit is for a new wellbore segment of existing well Permit No, I API No. (If api number last two (2) Production should continue to be reported as a function of digits are between 60-69) the original API number stated above. DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(f), all records, data and REDRILL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50-70/80) from records, data and logs acquired for well (name on permit). EXPLORATION ANNULAR D POSAL Annular disposal has not been requested ... NO INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved ... C� YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved ... REDRILL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of fluids generated... ANNULUS c ) YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved. subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. U �b Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY _ WELL NAME r , -, PROGRAM: FIELD & POOL [NIT CLASS �✓ % 6 % L GEOL AREA ;TRATION 1. Permit fee attached . . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . .. . . ... .. . 3. Unique well name and number ... . . . . .. . . .. . . . . . 4. Well located in a defined pool .. .. . . ... .. . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . .. .. . . 7. Sufficient acreage available -in drilling unit... . . . . . . . . . 8. If deviated, is wellbore plat included .. .... .. . . .. . . . 9. Operator only affected party ..... . . . . . . . . . . . . . . 10. Operator has appropriate bond in force . . .. . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . DATE 12. Permit can -be issued without administrative approval... .. . 1 /, 261: t41 13. Can permit be approved before 15-day wait.. . . . . . . . . . N N N N N N. N N N N N N dev ✓ redril serywellbore seg ann. disposal para UNIT# &IMA,S 7 D ON/OFF SHORE 0W ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . . . N 15. Surface casing protects all known USDWs. .. .. . . . . tYN 16. CMT vol adequate to circulate on conductor & surf csg.. . . . 17. CMT vol adequate to tie-in long string to surf csg. .. .. .. . rN 18. CMT will cover all known productive horizons. 19. Casing designs adequate for C, T, B & permafrost. . . . ...20. Adequate tankage or reserve pit .... .. .. .. . . . . . . . s�t 21. If a re -drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . ... EN 23. If diverter required, does it meet regulations . .. .. . . . .. N 24. Drilling fluid program schematic & equip list adequate . . . N W�N J --'> \ . l smz- G 25. BOPEs, do they meet regulation . .. .... N ATE 26. BOPE press rating appropriate; test to i-, osig. N ��sS� P5� (L247 «i 27. Choke manifold complies w/API RP-53 (May 84) . .. .. ... N 28. Work will occur without operation shutdown ... . . . . . . . Y N 29. Is presence of H2S gas probable .. . . .... . . .... . .. Y CN GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. ... IN N 31. Data presented on potential overpressure zones .. . . . . . N 32. Seismic analysis of shallow gas zones.... .... . . . . ^! AP DATE 33. Seabed condition survey (if off -shore) . ... .. y !v Y N / , Z0, 6/ 34. Contact name/phone for weekly progress reports (explorat5ry only) Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . .. ... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste . .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQg)�ENGINEERING: UI nular COMMISSION: al�ir- �r�5ycr_�c Comr�r ents/Instructions: f7 KlL tztlL t'n), ACC; 17?3A) recC��C+ tic, fie u�' ccrefYvlC�C� c:\msoffice\wordian\diana\cheddist (rev. 11/01//00) . Svbr ti l(if� it//e\�3�