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201-029
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED nn n 6 nn.n 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 • Suspended ❑ Well Class t f 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 11b. Developmegt ,Fli..Explopail Service Siretigraphi eSY❑ t`] eV 2_ Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit t0 Drill Number/Sundry BP Exploration (Alaska), Inc 3/26/2019 201-029 * 318561 3. Address: T Date Spudded. 15, API Number'. P.O. Box 196612 Anchorage, AK 99519-6612 3/23/2001 50-029-22491-01-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 3/30/2001 PBU NK -08A 9 Ref Elevations KB 52.83 17. Field/Pool(s): Surface 1268 FSL, 1099 FEL, Sec. 36, T12N, RISE, UM Top Of Productive Interval: 1069' FSL, 567'FEL, Sec. 22, T12N, R15E, UM GL 19.10 • BF 22.17 PRUDHOE BAY, NIAKUK OIL 10. Plug Back Depth(MD/TVD): 18. Property Designation: Total Depth: 1384' FSL, 845' FEL, Sec. 22, T12N, RISE, UM • 9776' / 6076' • ADL 034630. 034625'& 034626 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 721465 - y- 5979799 Zone - ASP 4 • 18517'/ 9426' • 84-062 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MDfTVD: TPI: x- 711134 y- 5989867 Zone - ASP 4 Total Depth: x- 710847 y- 5990174 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore 21. Re-drill/Lateral Top N/ndow MD1TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) , 12436'/ 7353' 22. Logs Obtained List all logs run and, pursuant t0 AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs 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 /NEU/DEN 23' CASING, LINER AND CEMENTING RECORD CASING WT.PER FT. GRADE SETTING DEPTH MD BOTTOM SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM 20" 94# H-40 114' 34' 114' 30" 260 sx Arctic Set (Approx.) 13-3/8" 68# NT -80 E12236' _ 33' 4137' 16" 1890 sx PF'E', 375 sx Class'G' 9-5/8" 47# NT -a05 12436' • 0' 7353' 12-1/4" 400 sx Clam *G% 185 Bible AS II 7"x4-1/2" 29#/12.6# L-80 18517' 7251' 9426' 8-1/2" 150 We Class'G' 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation GRADE DEPTH SET (MD) PACKER SET (MD17V Size and Number; Date Perfd): 4-1/2" 12.6# L-80 9878' - 12341' 12284-17275' Avivil ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. vowckpok ATE Was hydraulicfracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed /0 diry information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED VERIF ED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): WA Date of Test: Hours Tested:: Production for Oil -Bbl ' Gas -MCF: Water -Bbl: Choke Slue Gas -Oil Ratio Test Period y Flax Tubing Press Casing Press: I Calalated 24 Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil GreWN- API (corr): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 --Submit ORIGINAL only A,-R,26APRi9 i./Jr/7 RR�IS1PR15 J 28. CORE DATA Conventional Corals) Yes ❑ No (Z Sidewall Cores yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this forth, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 17976' 9086' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk 17976' 9086' Base of Kupawk 18335' 9308' Formation at total depth: Base of Kuparuk 18335' 9308' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Noces, Noel Authorized Title: SI cialist Contact Email: Noel.Nocas@bp.com 2110 Contact Phone. +1 9075645027 Authorized Signature: Date: 41211011 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. 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 1a. 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level 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 20. Report true vertical thickness of permafrost in Box 20. 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 and printed logs 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 wrresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the wrresponding formation, and a beef 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 5/2017 Submit ORIGINAL Only WELL NAME: NK -08A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9878' Cut & Pull Tubing -12500' 90 Bbls Class'G' 9859' Set Whipstock 9776' Set 2nd Whipstock T/I/O=SSV/0/400, Temp=Sl. PPPOT-T (PASS), PPOT-IC (FAIL). Pre RST. PPPOT-T: Stung into test port (800 psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Function LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-C: Stung into test port (150 psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 1100 psi in 15 min, lost 600 psi in 1/4/2019 second 15 min (FAIL). Bled void to 0 psi. T/I/O = 406/47/505 (SLB Cementing - Plug and Abandonment Reservoir Plug) LRS pumped the following down TBG: 'REFER TO LRS AWGRS FOR LRS SPECIFIC DETAILS*** 11 BBLS 60/40 290 BBLS 1% KCI 2 BBLS 60/40 SLB pumped the following down TBG: 2 BBLS freshwater 90 BBLS 15.8 PPG Class G unislurry CMT 7 BBLS freshwater LRS pumped the following down TBG: 183 BBLS preheated DSL (Total dispacement = 190 BBLS) FWHPS: 929/29/661 ***LRS in control of well upon departure*** 1/18/2019 lEstimated TOC = 12500' MD / 7384' TVD T/1/0=406/47/505. Assist Cement Crew (Pre rig) Circulated and heated Diesel to 80*F. Pumped 11 bbls 60/40 meth spear down TBG followed by 290 bbls 1 % KCL., Pumped 2 bbls 60/40 to FP surface lines. Pumped 183 bbls Diesel down TBG for displacement ***SLB pumped 7 bbls of freshwater after cement for a total displacement of 190 bbls*** 1/18/2019 FWHP's 990/29/661. Well shut in upon departure. Hang tags T/1/0=452/124/589 Temp=Sl (LRS Unit 70 -Assist Slickline: AOGCC MIT-T) MIT-T ***PASSED*** @ 2577 psi (Target psi 2500 Max applied psi 2750) Pumped 3.8 bbls of -10*f diesel down TBG to reach test psi 1 st test 1 st 15 min TP lost 115 psi 2nd 15 min 42 psi for a total of 157 psi in 30 min AOGCC MIT-T ***PASSED*** to 2574 psi (Witnessed by Austin Mcleod) Target psi 2500 Max applied psi 2750 psi. Pressured up TBG to 2735 psi with 2.74 bbls diesel. 1st 15 min TBG lost 119 psi. 2nd 15 min TBG lost 42 psi for a total loss of 161 psi in 30 min. Bled back TBG to 280 psi, bled back - 2.77 bbls. 2/6/2019 1 ***Continued on 02-07-19 WSR*** Daily Report of Well Operations NK -08A 'WELL S/I ON ARRIVAL SWCP 4518***(sidetrack) BRUSHED BPV PROFILE W/ 4-1/2" BRUSH. RAN 3.84" NO-GO TO TRSSSV 2014' SLM (2037' MD). RAN FLAPPER CHECKER TO TRSSSV 2014' SLM (2037' MD) (open). DRIFT W/ 2.80" CENT & 2.50" S -BAILER TAG TOC @ 12,271' SLM (aogcc witness tag) ROPE SOCKET HUNG UP @ TRSSSV, WIRE PARTED @ ROPE SOCKET WHILE ATTEMPTING TO WORK PASSED FLAPPER. SET 4-1/2" HOLD OPEN SLV IN TRSSSV @ 2014' SLM. PASSING STATE WITHNESS MIT -T. PULL 4-1/2" HOLD OPEN SLV IN TRSSSV @ 2014' SLM. RIH W/ 4-1/2" SERIES 10 EXERCISE TOOL. 2/6/2019 ***CONTINUE WSR TO 2/07/19*** ***CONTINUE WSR FROM 2/06/19 SWCP 4518***(side track) RAN 4-1/2" SERIES 10 EXERCISE TOOL TO 2016' SLM. RAN FLAPPER CHECKER TO FMX TRSSSV @ 2014' SLM(2037' MD) FLAPPER CLOSED. SET HOLD OPEN SLV (167" oal, 3.86" no-go) TO 2014' SLM. FISH SLICKLINE TOOL STRING FROM 12,244' SLM SAMPLE OF CEMENT IN BAILER. PULL HOLD OPEN SLV FROM 2014' SLM. RAN 4-1/2" SERIES 10 EXERCISE TOOL TO 2016' SLM. LRS PREFORMED PASSING MIT -IA. 2/7/2019 ***CONTINUE WSR TO 2/08/19*** ***Continued from 02-06-19 WSR*** (LRS Unit 70 -Assist Slickline: MIT-IA/Sidetrack) Pumped 4.7 bbis of 10* diesel down TBG to 2500 psi for differential pressure for MIT -IA. MIT -IA PASSED @ 4137 psi. Max applied=4250 psi. Target pressure= 4000 psi. Pressured up IA to 4228 psi with 16 bbls diesel. 1st 15 min IA lost 62 psi. 2nd 15 min IA lost 29 psi for a total loss of 91 psi in 30 min. Bled IA to 150 psi (15 bbls) and TBG to 300 psi 2 bbls) 2/7/2019 ***Continued on 02-08-19 WSR*** `*'Continued from 02-07-19 WSR*** (LRS Unit 70- Assist Slickline: OA Integrity Test/Sidetrack) OA Integrity Test Passed. Pumped 4.5 bbls diesel down OA. OA lost 30 psi in 5 min, no observable flow to surface. Bled OA to 500 psi, bled back — 4 bbls. Tags hung. AFE sign hung on well. Slickline in control of well upon departure. 2/8/2019 FWHPS=450/250/500 ***CONTINUE WSR FROM 2/07/19 SWCP 4519***(sidetrack) MAKE 2 RUNS W/ 4-1/2" SERIES 10 EXERCISE TOOL TO 2016' SLM. RAN FLAPPER CHECKER TO 2014' SLM(2037' MD) FLAPPER NOT FULLY OPEN. RAN 4-1/2" SERIES 10 EXERCISE TOOL TO 2016' SLM. RAN FLAPPER CHECKER TO 2014' SLM(2037' MD) FLAPPER NOT FULLY OPEN. RAN 3.70" CENT & 4-1/2" DAP TOOL, SET DAP @ 2014' SLM & DRIFT W/ 3.70" CENT W/ NO ISSUE TO 10,550' SLM, HANG UP IN DAP TOOL @ 2014' SLM & UNABLE TO GET FREE. **IN HOLE W/ TOOL STRING** 2/8/2019 **'CONTINUE WSR TO 2/09/19*** Daily Report of Well Operations NK -08A ***CONTINUE WSR FROM 2/08/19 SWCP 4518***(sidetrack) DEPLOY GO -DEVIL CUTTER & CUT WIRE @ 2014' SLM. PULL GO -DEVIL FROM 1995' SLM. RAN 3.68" CENT & 3.65" BLIND BOX TOTOOL STRING @ 1998' SLM & JAR FREE. PULL 4-1/2" DAP TOOL FROM 2014' SLM. SET 4-1/2" HOLD OPEN SLV @ 2014' SLM(2037' MD). RAN 2.72" CENT & 2-1/2" JUC FISH TOOL STRING FROM 12,181' SLM & PULL HOLD OPEN SLV FROM 2014' SLM(2037' MD). ***WELL LEFT S/I ON DEPARTURE*`* 2/9/2019 ***FMX TRSSSV FLAPPER NOT OPENING ALL THE WAY*** T/I/O = 330/250/560. Temp = SI. Inflow Test ***PASSED*** (pre rig). ALP = 1290 psi, SI @ casing valve. T FL @ near surface. Bled TP to BT from 330 psi to 0 psi in 38 min (0.62 bbls energized fluid). IAP decreased 10 psi during bleed. Monitored for 30 min for any flow. No observable flow conveyed during the 30 min monitor. SI and monitored for 30 min. WHPs unchanged. Final WHPs = 0/240/560. 2/11/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:30 ***WELL S/I ON ARRIVAL*** (sidetrack) RIGUP HES RELAY UNIT 046 2/13/2019 ***CONT. TO 2/14/19 WSR*** ***CONT. FROM 2/13/19 WSR*** (sidetrack) CONT. RIGUP HES RELAY UNIT 046 RAN HOLD OPEN SLEEVE ABOVE HES 3.625" JET CUTTER, SAT DOWN @ 2016' RMD. METAL MARKS ON JET CUTTER APPEARS TO BE FROM FLAPPER ON SSSV. UNABLE TO PASS. 2/14/2019 ***JOB POSTPONED*** ***WELL FOUND S/I ON ARRIVAL***(sidetrack) TAG TRSSSV NO GO AT 2015' SLM. SET 3.84" HOLD OPEN SLEEVE WITH NS ANCHOR AT 2037' MD (Min ID = 2.83") PERFORM 450# PULL TEST ON HOLD OPEN SLEEVE @ 2037' MD(good test) DRIFT W/ 2'1-7/8" STEM, 2.50" CENT THROUGH HOLD OPEN SLEEVE TO 2035' SLM. 2/26/2019 ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED—** ***WELL S/I ON ARRIVAL*** (Sidetrack) R/U HES ELINE UNIT #4863 3/11/2019 ***JOB CONTINUED ON 12 -MAR -2019*** ***JOB CONTINUED FROM 11 -MAR -2019*** HES ELINE UNIT #4863 INITIAL T/1/0 = 500/175/680. MIRU HES & WELLTEC. CUT TBG @ 9878' MD W/ WELLTEC CUTTER (good indication of cut) ALL LOGS CORRELATED TO PDS MTT LOG DATED 03 -JAN -2019. FINAL T/I/O = 350/150/675. WELL LEFT S/I ON DEPARTURE. 3/12/2019 ***JOB COMPLETE ON 12 -MAR -2019*** 3/12/2019 ***CONT JOB FROM 03/11/19 WSR*** T/1/0=215/150/619 LRS unit #46 ( CMIT TBGxIA, CIRC -OUT) See log for details Continued 3/12/2019 WSR to 03/13/19 Daily Report of Well Operations NK-08A T/1/0=215/150/619 LRS Unit 46 (COMBO MIT TBGxIA, CIRC-OUT) Combo MIT Tx IA, *** TEST/PASS*** Target pressure of 4000 psi, Max applied 4250 si, Pumped 15.5 bbls DSL o achieve test pressure of 4205/4163, 1st 15min. TBG/IA lost 22/24, 2nd 15min TBG/IA lost 17/17 for total loss of 39/41, bled 16 bbls DSL back 16 bbls, (Circ-out) Pumped 10 bbls Methanol (60/40) down TBG followed by 1040 bbls 120* fresh water. Pump 1 bbl 60/40 spacer, followed by 172 bbls of 90* dsl down IA taking returns up tbg to NK-29 flowline to production. U-tube for 1 hour. Bleed TxIA to -7/-2. Bled back 2 bbls. Freeze protect NK-29 with 10 bbls 60/40. FWHP= 0/0/574 **Fluid packed tags hung on IAV/WV** 3/13/2019 **AFE sign hun I** T/1/0=250/250/500 R/U lubricator, set 4" CIW "H" TWC #294 through tree. Performed LTT on TWC... pass. R/D production tree, R/U 4" Dryhole tree Temp #70. Torqued to API specs. PT'd against TWC. see "Field Charted Tests" Removed blind from IA and installed integral flange w/ block valve and jewelry. Remove blind from OA and installed integral flange w/ 3/16/2019 cap and jewelry. PT'd to specs. FWP's TWC/0/500 see log for details. TWO = TWCNac/340. Temp = Sl. Bleed WHP's to 0 psi. (Pre-Rig). OA FL @ Near Surface. Bled OAP from 340 psi to 189 psi in 3 hours 20 minutes, (all gas). SI bleed for 3/18/2019 Vac truck to empty slop trtr's. Continued on WSR 3-19-19. TWO = TWCNac/530. Temp = SI. Bleed WHPs to 0 psi (Pre RIG). No AL, wing valve, flowline, scaffold or wellhouse. Dry hole tree installed. OA FL @ Near Surface. Bled OAP to BT from 530 psi to 300 psi in 1 hr. (gas/fluid 8 bbls, Brat max capacity). Monitored for 30 min. OAP increased 40 psi during monitor. Final WHPs = TWCNac/340. 3/18/2019 SV = C. MV = O. IA, OA = OTG. 02:00 Continued from WSR 3-18-19. T/I/O = TWCNact202. Temp = SI. Bleed WHP's to 0 psi. (Pre-Rig). Dry hole tree. OA FL @ Near Surface. Bled OAP from 340 psi to 189 psi in 3 hours 20 minutes, (all gas). SI bleed for Vac truck to empty slop trlr's. OAP increased 13 psi during SI for Vac Truck, Continue OAP bleed. Bled OAP from 340 psi to 72 psi in 7 hours 35 minutes, ( 2.5 bbl of fluid returned). Rig down & monitor for end of shift. OAP increased 18 psi during 15 minute monitor. Final WHP's = TWCNac/90. SV = C. MV = O. IA, OA = OTG. 04:45 3/19/2019 TWO = TWC/Vac/100. Temp = SI. Bleed WHPs to 0 psi (Pre RIG). Dryhole tree. No wellhouse. OA FL @ Near Surface. Bled OAP to BT from 100 psi to 0 psi in 8 hrs, gas & fluid, returned 3.5 bbls. Monitored for 30 min. OAP increased 0+ psi. Final WHPs = TWCNac/O+. 3/19/2019 SV = C. MV = O. IA, OA = OTG. 16:55 TWO = TWCNac/10. Temp = SI. WHPs (Pre RIG). Dryhole tree, no wellhouse. IAP unchanged, OAP increased 10 psi overnight. 3/20/2019 SV = C. MV = O. IA, OA = OTG. 16:30 T/I/O=TWC/0/0 R/D piggyback block valve assem. on IA, installed piggyback IA Temp #104. Torqued to specs. R/D integral on OA valve, installed piggyback gate valve Temp #102. Torqued to specs. PT'd both piggybacks aganst inner valves. see "Field Charted 3/20/2019 Tests" FWP's TWC/0/0 see log for details. 0312212019 North America - ALASKA - BP Page 1 MOB Operation Summary Report 1.40 Common Well Name: NK -08 MOVE RIG FROM DS16 THROUGH D817 TO AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 3/22/2019 End Date: 4/16/2019 X3 -0199F -C. (8,452,503.00 ) Project: Niakuk Site: NK PRE Rig Name/No.: PARKER 272 Spud Date/Time: 7/14/1994 12:00:00AM Rig Release: 4/2212019 Rig Contractor. PARKER DRILLING CO. MOB BPUOI: USA00001319 Active datum: ACTUAL KB P272 @67.45usft (above Mean Sea Level) PRE Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) P 3/22/2019 05:00 - 08:30 3.50 MOB P 1.40 PRE GENERAL RIG DOWN OPERATIONS ON 0700 - 08:00 _ 16-14C _ _ - DISCONNECT INNER CONNECTS ON -MUD MODULE ON WEST SIDE OF RIVER MODULES 0800 - 10:30 - SKID RIG FLOOR MOB N - LOWER MAST TO HEADACHE RACK - DRILL MODULE AND UTILITY MODULE ON STAGE MODULES AND WAITAT TARMAC - PREP MODULE FOR MOVE WBS:MOB "' RELEASE FROM 16-14C AT 05:00 HRS ON — 08:30 - 12:00 j 3.50 MOB P 1.40 PRE MOVE RIG FROM DS16 THROUGH D817 TO 0600 - 0700 1.00 MOB P 140 PRE THE SAG RIVER ICE ROAD 12:00 - 0000 12.00 MOB N 1.40 PRE HALT RIG MOVE ON SAG RIVER DUE TO HIGH 1.00 MOB P 1.40 PRE WINDS 0700 - 08:00 _ _ _ _ _ -MUD MODULE ON WEST SIDE OF RIVER _ ROAD TO TARMAC CAMP TURNOFF _ 0800 - 10:30 2.50 MOB N 140 - DRILL MODULE AND UTILITY MODULE ON STAGE MODULES AND WAITAT TARMAC SAG RIVER ICE ROAD CAMP FOR ROADS AND PADS TO CLEAR WINDS EXCEED DESIGN LIMITS FOR RIG ROADS AND GIVE APPROVAL TO CONTINUE MOVE AND UNABLE TO MAINTAIN SAFE RIG MOVE . WORKING PRESSURES ON TIRES. PHASE 2 WEATHER CONDITIONS CALLED AT _12:00 3/23/2019 00.00 - 02:00 2.00 MOB N 1.40 PRE CONTINUE TO WAITON WEATHER _ _ _ _ _�_ _ _ L_ __ _ _ CONDITIONS TO IMPROVE_ 0200 - 0300 1.00 MOB P 1.40 PRE MOVE MODULES TO JACOBS YARD ON WEST SIDE OF SAG RIVER ICE ROAD - FIELD STILL REMAINS IN PHASE 2 WEATHER CONDITIONS - WIND AND VISIBILITY IMPROVED ENOUGH TO CONTINUE TO MOVE UTILITY MODULE AND DRILL MODULEACROSS SAG RIVER ICE ROAD. 03:00 - 04'.30 1.50 MOB N 1.40 PRE WAIT FOR ROADS AND PADS TO CLEAR THE ROADS AND GIVE APPROVAL TO CONTINUE THE RIG MOVE TO NK -08 FIELD STILL REMAINS IN PHASE 2 WEATHER _ CONDITIONS _ 0430 - 0600 1.50 MOB P 1.40 PRE CONTINUE MOVING ALL THREE MODULES FROM JACOBS YARD THROUGH THE EAST GUARD SHACK TO THE INTERSECTION WITH WEST DOCK ROAD PHASE 2 CONDITIONS LIFTED AT 0430 Printed 4/2312019 3:32:15PM "All dephts reported in Drillers Depths— 0600 - 0700 1.00 MOB P 140 PRE STOP AT THE INTERSECTION WITH WEST DOCK ROAD AND STAGE MODULES TO 1.00 MOB P 1.40 PRE ALLOW TRAFFIC TO PASS MOVE ALL 3 RIG MODULES ALONG SPINE 0700 - 08:00 _ _ _ _ _ _ _ ROAD TO TARMAC CAMP TURNOFF _ 0800 - 10:30 2.50 MOB N 140 PRE STAGE MODULES AND WAITAT TARMAC CAMP FOR ROADS AND PADS TO CLEAR ROADS AND GIVE APPROVAL TO CONTINUE RIG MOVE Printed 4/2312019 3:32:15PM "All dephts reported in Drillers Depths— North America - ALASKA - BP Operation Summary Report Page 2 0rx Common Well Name: NK -08 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/22/2019 End Date: 4/16/2019 X3 -0199F -C: (8,452,503.00 ) Project: Niakuk Site: NK LINES Rig Name/No.: PARKER 272 Spud Daterrime: 7/14/1994 12:00:OOAM Rig Release: 4/22/2019 Rig Contractor PARKER DRILLING CO. BPUOI: USA00001319 Active datum: ACTUAL KB P272 (gD67.45usft (above Mean Sea Level) - TAKE ON FLUIDS FOR PIT CALIBRATION Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ - (usft) 10:30 - 18:00 5.50 MOB P 1.40 PRE CONTINUE RIG MOVE WITH ALL 3 MODULES 22:00 - 23:00 23:00 - 00:00 3/24/2019 00:00 - 01:00 01:00 - 01:30 1.00 MOB P 1.00 MOB P 1.00 WHSUR P 0.50 WHSUR P - RIG UP RIG FLOOR LINES - SPOT CUTTINGS BOX AND RIG UP STEAM LINES TO NK -08 LINE - TAKE ON FLUIDS FOR PIT CALIBRATION 1.40 PRE BRIDLE DOWN SIMOPS: DERRICK - HOOK UP BLOCKS TO TOP DRIVE - INSTALLTORQUE TUBE PIN SPOT DUMMY WELL HOUSE OVER NK -08 16:00 - 1730 1.50 MOB P 1.40 PRE SPOT DRILL MODULE OVER NK -08 1.40 PRE RIG UP TO TEST TWC FROM BELOW AND ABOVE - RIG UP SECONDARY KILL TO IA - VERIFY E -STOP FUNCTION PRIOR TO - TEST SURFACE LINES TO 4500 PSI WITH MUD PUMP: GOOD _ 1.40 PRE ATTEMPT TO PRESSURE TEST TWC FROM MOVINGOVERWELL - PRESSURE UP WITH MUD PUMP THROUGH IA - AT 1500 PSI (5 BELS PUMPED) OBSERVE -MARRY UP UTILITY MODULE AND MU - SHUT DOWN WITH PRESSURE ON IAAND TROUBLESHOOT LEAKING TWC MODULE TO DRILL MODULE 1730 - 1830 1.00 MOB P 1.40 PRE RIG UP INNER CONNECTS AND MAKE UP ELECTRICAL CONNECTIONS AND STEAM CONNECTIONS 18:30 - 19:30 1.00 MOB P 1.40 PRE RAISE THE DERRICK - INSPECT DERRICKAND VERIFY CHECKLIST 'FOR RAISING DERRICK COMPLETE DERRICK OFF THE RACKAT 500 KLBS 19:30 - 20:30 1.00 MOB P 1.40 PRE SKID THE RIG FLOOR FROM DERRICK OVER POSITION TO WELL CENTER - MOVE HAUNCH AND INSTALL - RAISE PIPE CAT - INSTALL HANDRAILS AND LANDINGS ON RIG FLOOR 20:30 - 21:00 0.50 MOB P 1 T 1.40 PRE PERFORM RIG E -STOP (BLACKOUT) TEST WITH ELECTRICIAN 21:00 - 22:00 1.00 MOB P 1.40 PRE RIG UP RIG FLOOR EQUIPMENT - INSTALL MAN RIDERS AND PIN IN PLACE -INSTALL OFF-LINE MOUSE HOLES 22:00 - 23:00 23:00 - 00:00 3/24/2019 00:00 - 01:00 01:00 - 01:30 1.00 MOB P 1.00 MOB P 1.00 WHSUR P 0.50 WHSUR P Printed 4/23/2019 3:32:15PM '•All dephts reported in Drillers Depths" - RIG UP RIG FLOOR LINES - SPOT CUTTINGS BOX AND RIG UP STEAM LINES - SPOT FLOW BACK TANK AND RIG UP HARD LINE - TAKE ON FLUIDS FOR PIT CALIBRATION 1.40 PRE BRIDLE DOWN - REMOVE BRIDLE LINES AND HANG IN DERRICK - HOOK UP BLOCKS TO TOP DRIVE - INSTALLTORQUE TUBE PIN - CALIBRATE TOTCO PVT SYSTEM WBS:RU "' ACCEPT RIG AT 23:00 HRS ON 03/23/2019 1.40 PRE CALIBRATE BLOCKS AND CHECK CROWN-0-MATIC 1.40 PRE RIG UP TO TEST TWC FROM BELOW AND ABOVE - RIG UP SECONDARY KILL TO IA - OPEN TO GAUGE ON TREE - TEST SURFACE LINES TO 4500 PSI WITH MUD PUMP: GOOD _ 1.40 PRE ATTEMPT TO PRESSURE TEST TWC FROM BELOW TO 4000 PSI - PRESSURE UP WITH MUD PUMP THROUGH IA - AT 1500 PSI (5 BELS PUMPED) OBSERVE PRESSURE ON TREE AT 1300 PSI - SHUT DOWN WITH PRESSURE ON IAAND TROUBLESHOOT LEAKING TWC Printed 4/23/2019 3:32:15PM '•All dephts reported in Drillers Depths" North America - ALASKA - BP Page 3 0� Operation Summary Report Common Well Name: NK -08 - 04:30 1.00 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/22/2019 End Date: 4/16/2019 X3 -0199F -C: (8,452,50100) Project: Niakuk Site: NK 06:00 - 07:30 Rig Name/No.: PARKER 272 Spud Date/rime: 7/14/1994 12:00:00AM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. - TEST FROM BELOW WITH MUD PUMP TO BPUOI: USA00001319 Active datum: ACTUAL KB P272 @J67.45us6 (above Mean Sea Level) - TEST FROM ABOVE WITH TEST PUMP TO Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) ._ - WsfU SUCK OUT TREE 01:30 - 02:00 0.50 WHSUR N 1.40 PRE SEAT POPPET ON LEAKING TWC 0200 - 0300 1.00 WHSUR P 0300 - 0330 0.50 WHSUR P 03:30 - 04:30 1.00 WHSUR P 0430 - 0600 1.50 WHSUR P 06:00 - 07:30 1.50 BOPSUR P 07:30 - 08:30 1.00 BOPSUR P 08:30 - 14:30 6.00 BOPSUR P 14:30 - 15:00 0.50 BOPSUR P Printed 4/232019 3*32:15PM `*All dephts reported in Drillers Depths— - RIG UP HOSE FROM TREE TO BLEED TRAILER - BLEED OFF PRESSURE ON TREE QUICKLY TO BLEED TRAILER AND SEAT POPPET ON TWC 1.40 PRE CONTINUE TO PRESSURE TEST TWC FROM BELOW AND ABOVE TO 4000 PSI FOR 5 CHARTED MIN - TEST FROM BELOW WITH MUD PUMP TO j 4000 PSI: GOOD TEST - TEST FROM ABOVE WITH TEST PUMP TO 4000 PSI: GOOD TEST 1.40 PRE BLOW DOWN LINES AND RIG DOWN TEST EQUIPMENT SUCK OUT TREE 1.40 T PRE RIG EVACUATION / H2S DRILL WITH RIG _ CREW 1.40 PRE NIPPLE DOWN ADAPTER FLANGE AND TREE PER FMC REPRESENTATIVE - BLEED OFF HANGER VOID AND TERMINATE CONTROL LINES PER FMC • - NIPPLE DOWN TREE AND ADAPTER FLANGE AND RAISE TO BOP DECK - FUNCTION LOCK DOWN SCREWS AND GLAND NUTS - INSPECT HANGER THREADS (GOOD) AND _ MAKE UP XO_ (7.5 TURNS) 1.40 PRE NIPPLE UP BOP STACKAND HIGH PRESSURE RISERS - NIPPLE UP RISER ON WELLHEAD - NIPPLE UP BOPS STACK ON RISER - INSTALL LOW PRESSURE RISERS - ATTACH TURNBUCKLES AND CENTER STACK -CONNECT FLOW LINE AND HOLE FILL LINES - AIR UP AIR BOOTS - INSTALL MOUSE HOLE _ 1.40 PRE RIG UP TO TEST BOPE - MAKE UP TEST JOINTS AND FOSV ASSEMBLIES - FILL STACK AND PURGE AIR FROM SYSTEM 1.40 PRE PRESSURE TEST BOPE T 250 / 5000 PSI FOR 5 CHARTED MIN EACH -TESTANNULAR PREVENTER TO 250/3500 PSI FOR 5 CHARTED MIN EACH - TEST WITH 2-7/8" AND 5' TEST JOINTS - TEST GAS ALARMS, PVT AND FLOW SHOW TEST WITNESS WAIVED BYAOGCC REPRESENTATIVE BOB NOBLE AT 06:43 HRS ON 03/24/2019 ALL TESTS WITNESSED BY RIG MANGER OR WSL SEE ATTACHED TEST CHARTS 1,40 PRE RIG UP TO PULL TWC WITH LUBRICATOR - INSTALL DUTCH RISER - LOAD LUBRICATOR TOOLS IN PIPE SHED Printed 4/232019 3*32:15PM `*All dephts reported in Drillers Depths— Printed 4/23/2019 3:32:15PM **All dephts reported in Drillers Depths" North America - ALASKA - BP Page 4 bw Operation Summary Report Common Well Name: NK-08 APE No Event Type. RE-ENTER- ONSHORE (RON) Start Date'. 3/22/2019 End Date. 4/16/2019 X3-0199F-C: (8,452,503.00 ) Project: Niakuk Site: NK Rig Name/No.: PARKER 272 Spud Date/rime: 7/14/1994 12:00:00AM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001319 Active datum: ACTUAL K8 P272 @67.45usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) _ 15:00 - 17:00 2.00 BOPSUR P 1.40 PRE PULLAND LAY DOWN TWC WITH LUBRICATOR -MAKE UP LUBRICATORAND EXTENSIONS - MAKE UP LUBRICATOR TO DUTCH RISER AND PRESSURE TEST 3500 PSI FOR 5 MIN: GOOD TEST - PULL AND LAY DOWN TWC - RIG DOWN LUBRICATOR AND DUTCH RISER 17:00 - 18:00 1.00 BOPSUR P 1.40 DECOMP HOLD RIG EVACUATION /H2S DRILL AND PRE-SPUD MEETING WITH YEAROUT'S CREW WBS:DECOMP 18:00 - 18:30 0.50 CASING P 1.40 DECOMP .RIG UP TO PULL 4-1/7IBT-M TUBING - RIG UP HYDRAULIC SPOOLER - RIG UP CASING TONGS CALIBRATE BLOCKS WITH BAKER MWD 1830 - 2000 1.50 CASING P 9,879.40 DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT PUMP 50 BELS OF 8.5 PPG 3% KCL DOWN THE IA TAKING RETURNS TO THE CUTTINGS TANK -7 BPM, 1150 PSI - SHUT DOWN AND VERIFY CLEAN 8.5 PPG OUT PUMP 220 BBLS OF 8.5 PPG 3% KCL DOWN THE TUBING TAKING RETURNS TO THE FLOW BACKTANK .7 BPM, 850 PSI - SHUT DOWN TO MONITOR WELL, WELL OUT OF BALANCE Printed 4/23/2019 3:32:15PM **All dephts reported in Drillers Depths" Printed 4/2312019 3:32:15PM **All dephts reported in Drillers Depths" North America - ALASKA - BP Page 5 Pf�* Operation Summary Report Common Well Name: NK -08 APE No Event Type: RE -ENTER -ONSHORE (RON) Start Date: 3/22/2019 End Date: 4/16/2019 X3 -0199F -C: (8,452,503.00 ) -Project: Niakuk Site: NK Rig Name/No.: PARKER 272 Spud Daterrime: 7/14/1994 1200:00AM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001319 Active datum: ACTUAL KB P272 @67.45usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr)_ _ _ ...__(usft)_ 20:00 - 00:00 4.00 CASING N 9,879.40 DECOMP CIRCULATE TO GET THE WELL IN BALANCE OBSERVE FLUID LEVEL CONTINUE TO DROP BELOW THE WELLHEAD ON THE TUBING SIDE. IA STILL FLOWING TO THE FLOW BACK TANK - FILL TUBING WHEN FLUID LEVEL DROPS BELOWWELL HEAD SEVERAL TIMES - FLUID CONTINUES TO FLOW TO THE FLOW BACK TANK - PUMPED AN ADDITIONAL 250 BBLS OF 8.5 PPG 3% KCL DOWN THE TUBING - PULL 290 BELS OF DIESEL/ KCL OFF THE TIGER TANK FOR HYDROCARBON RECYCLE '- CALL OUT ADDITIONAL 3% KCL FROM HOT ,WATER PLANT ! 'CLOSE BLIND/SHEAR RAMS AND PUMP AN ADDITIONAL 80 BBLS DOWN THE TUBING TAKING RETURNS TO FLOW BACK TANK -4 BPM, 250 PSI - SHUT DOWN AND CLOSE VALVE TO FLOW 'BACKTANK WELL STILL OUT OF BALANCE - 40 PSI ON IA LINE TO FLOW BACK TANK, TUBING OPEN TO ATMOSPHERE TOTAL 8.5 PPG 3% KCL PUMPED DOWN TUBING = 550 BBLS ANNULAR VOLUME OF 9-5/8" x4-1/2" TO TUBING CUTAT 9878' MD = 529 BBLS TUBING VOLUME TO CUT AT 9876' MD = 150 BBLS VOLUME IN TUBING AND ON IA BELOW CUT = 163 BBLS WAIT FOR ADDITIONAL FLUIDS TO ARRIVE ON LOCATION AND FOR DIRTY DIESEL/ KCL RETURNS TO BE SUCKED OUT OF FLOW BACK TANK. SIMOPS: - BUILD STANDS OF 5" DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT Printed 4/2312019 3:32:15PM **All dephts reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 6 ad:35 Common Well Name: NK -08 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/22/2019 End Date: 4/16/2019 X3 -0199F -C. (8,452,503.00 ) Project: Niakuk Site: NK Rig Name/No.: PARKER 272 Spud Daterrime: 7/14/1994 12:00:OOAM Rig Release: 4122/2019 Active datum: ACTUAL KB P272 @87.45usft (above Mean Sea Date From - To Ars Task (hr) 3/25/2019 00:00 - 01:30 1.50 CASING 01.30 - 02'.30 1.00 CASING 02.30 - 03:30 uu::1u 0400 BPUOI: USA00001319 Code NPT Total Depth Phase Description of Operations (usft) N 9,879.40 DECOMP CONTINUE TO BRING ON FLUIDS, MAKE ROOM IN FLOW BACK TANKAND ATTEMPT TO GET WELL IN BALANCE PUMP AN ADDITIONAL 200 BBLS DOWN THE TUBING TAKING RETURNS TO FLOW BACK TANK --7 BPM, 950 PSI - SHUT DOWN AND CLOSE VALVE TO FLOW BACK TANK '- WELL STILL OUT OF BALANCE -40 PSI ON IA LINE TO FLOW BACK TANK, TUBING OPEN TOATMOSPHERE - 8.5 PPG IN, 8.4 PPG WITH DIESEL OUT TOTAL 8.5 PPG 3% KCL PUMPED DOWN TUBING = 750 BELS SIMOPS: - BUILD STANDS OF 5" DRILL PIPE WITH 'OFF-LINE STAND BUILDING EQUIPMENT N 9,879.40 DECOMP WAIT FOR ADDITIONAL FLUIDS TO ARRIVE FROM HOT WATER PLANTAND FOR EMPTY DIRTY VAC TRUCKS TO MAKE ROOM IN FLOW 'BACKTANK SIMOPS: - BUILD STANDS OF 5" DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT 1.00 CASING IN 9.879.40 DECOMP PUMP AN ADDITIONAL 200 BBLS DOWN THE 04:00 0.50 _ I 05:00 1.00 TUBING TAKING RETURNS TO FLOW BACK TANK - 7 BPM, 950 PSI - SHUT DOWN AND MONITOR WELL FOR 10 MIN: STATIC - 8.5 PPG IN, 8.5 PPG OUT TOTAL 8.5 PPG 3% KCL PUMPED DOWN TUBING = 950 BBLS SIMOPS: - BUILD STANDS OF 5" DRILL PIPE WITH OFF-LINE STAND BUILDING EQUIPMENT CASING P 9,879.40 DECOMP RIG DOWN AND BLOW DOWN LINES TO FLOW BACK TANK _ CASING P 9,879.40 DECOMP RIG UP AND PULL TUBING HANGER TO RIG FLOOR. - ENGAGE TUBING HANGER WITH XOAND 5" DRILL PIPE - BACKOUT LOCK DOWN SCREWS - HANGER FREE WITH 115 KLBS 0500 - 0630 1.50 CASING P 9,879.40 DECOMP CIRCULATE 35 BBL SOAP PILL SURFACE TO SURFACE - 15 BPM, 1000 PSI Printed 4/23/2019 3:32:15PM "All dephts reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 7 Common Well Name: NK -08 APE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/22/2019 End Date: 4/16/2019 X3 -0199F -C'. (8,452,503.00 ) Project: Niakuk Site: NK Rig Name/No.: PARKER 272 Spud Date/time: 7/14/1994 12:00:OOAM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. _ BPUOI: USA00001319 _ _ Active datum: ACTUAL KB P272 @67.45us8 (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations - - - (hr) ( us8) 08:30 - 17:00 10.50 .. CASING P _ 9,878.40 DECOMP PULLAND LAV DOWN 4-1/2", 12.8 LB/FT IBT-M TUBING FROM CUT AT 9878' MD - TERMINATE CONTROL LINE - LAV DOWN TUBING HANGER AND 5" DRILL I PIPE -PU 115 KLBS AT 9878' MO - LAY DOWN A TOTAL OF 247 FULL JTS, 2 GLM ASSEMBLIES, I SSSV, 1(T) PUP JOINT AND 1(36.341) CUT JOINT GOOD CUT, NO FLARE 17:00 - 18:00 1.00 CASING P 9,879.40 DECOMP RIG DOWN DOYON CASING TONGS AND ELEVATORS. REMOVE TUBING FROM PIPE SHED 18:00 - 18:30 0.50 CASING P 9,879.40 DECOMP SERVICE TOP DRIVE, BLOCKS AND WASH _._..PIPE 18:30 - 1930 1.00 WHSUR P 9,879.40 DECOMP 'RIG UP TO PULL 9-5/8"CASING PACK -OFF 19:30 3/26/2019 00:00 00:00 01:30 01:30 - 03:30 -MAKEUP RUNNING TOOL702 JOINTS OF 5" HWDP - SUCK OUT STACK RUN IN THE HOLE AND ENGAGE PACK -OFF 4.50 WHSUR N 9,879.40 DECOMP BLEED OFF GAS FROM OA BEFORE PULLING I PACK -OFF - NOT ENOUGH PRESSURE TO REGISTER ON OA PRESSURE GAUGE - BLEED OFF THROUGH 2" LINE TO FLOW BACKTANK SIMOPS: - BUILD STANDS OF 5" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT 1.50 WHSUR N 9 879.40 DECOMP CONTINUE TO BLEED OFF OA PRIOR TO PULLING 9-5/8" CASING PACK -OFF - VERIFIED WITH HANDHELD GAS METER 0 LEL, 0 1-12S, 0 CO AND 02 DID NOT CHANGE FROM BACKGROUND LEVELS SIMOPS: - BUILD STANDS OF 5" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT 2.00 WHSUR P 9,879.40 DECOMP PULLAND LAV DOWN 9-5/8" CASING PACK -OFF - BACK OUT LOCK DOWN SCREWS PER FMC REPRESENTATIVE - WORK UP TO 40 KLBS IN 2 KLB INCREMENTS, NO MOVEMENT - RIG UP STEAM BLANKET AND WARM UP SPOOL WHILE PULLING 40 KLBS - DISCUSS WITH FMC AND AGREE TO WORK UP TO 70 KLBS - WORK UP TO 70 KLBS IN 2-5 KLBS INCREMENT - PACK -OFF SLOWLY PULLED FREE WITH 70 KLBS - PULL PACK -OFF TO RIG FLOOR AND LAY DOWN SIMOPS: - BUILD STANDS OF 5" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT Printed 4/23/2019 3:32:15PM **All dephts reported in Drillers Depths" North America - ALASKA - BP Page 8 Operation Summary Report Common Well Name: NK -06 AFE No Event Type: RE -ENTER -ONSHORE (RON) Start Date: 3/22/2019 Entl Date 4/15/2019 X3 -0199F -C: (8,452 503 00 ) Project: Niakuk Site: NK Rig Name/No.: PARKER 272 Spud DateTme: 7/14/1994 12:00:00AM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. _ BPUOI: USA00001319 Active datum ACTUAL KB P272 @67.45usft (above Mean Sea Level) Date From - To His Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) 03:30 05:30 2.00 WHSUR P 9,879.40 DECOMP INSTALL NEW 9-5/8" PACK -OFF PER FMC REPRESENTATIVE -MAKE UP NEW PACK -OFF TO RUNNING TOOLAND SIN THE HOLE - PACK -OFF LANDED SEVERAL INCHES HIGH - FMC REP VERIFIED PACK -OFF NOT SET - REPEAT 2X WITH SAME RESULT - SET DOWN ALLAVAILABLE WEIGHT SEVERAL TIMES - NO SUCCESS PULL PACK -OFF TO RIG FLOOR AND INSPECT REPLACE INNER SEAL ON PACK -OFF - INSPECT CASING NECK FROM RIG FLOOR WITH FLASHLIGHT -MINOR AMOUNT OF FLUID ON BACKSIDE OF 9-5/8" CASING NECK: INDICATION OF SLIPS WITH "H" PACKING - APPEARS TO BE HYDRO -LOCKED AND UNABLE TO GET PACK -OFF IN - RIG UP VAC LINE WITH 1" LINE, RUN THROUGH IA VALVESAND SUCK OFF FLUID FROM BEHIND 9-5/8" CASING NECK i 5' IN WITH NEW PACK -OFF AND LAND ON MARK VERIFY PACK -OFF IN - RUN IN LOCK DOWN SCREWS PER FMC _ __REPRESENTATIVE 05:30 - 06:30 1.00 WHSUR P T 9,879.40 DECOMP PRESSURE TEST 9-5/8" CASING PACK -OFF TO 4000 PSI FOR 15 CHARTED MIN -GOOD TEST WSUP APPROVED TEST 06:30 - 07:00 0.50 WHSUR P 9,879.40 DECOMP INSTALL 9" ID WEAR RING, RUN IN LOCK DOWN SCREWS AND LAY DOWN RUNNING TOOL _ 07:00 - 10:00 3.00 STWHIP P 9,679.40 WEXIT MAKEUP AND RUN IN THE HOLE WITH 9-5/8" WHIPSTOCKAND WINDOW MILLING ASSEMBLY TO 953' MD -MAKE UP BAKER ONTRAKAND SCRIBE TO MILLING ASSEMBLY - MAKE UP WHIPSTOCK (VERIFIED SHIMS INSTALLED FOR LOW -SIDE EXIT)AND MILLING ASSEMBLY - SHALLOW HOLE TEST MWD AT 120' MD: GOOD - RUN IN THE HOLE AT 45 FPM PER SLB FISHING HAND -MONITOR WELL WITH TRIP TANKAND HOLE FILL: GOOD DISPLACEMENT - MUD WEIGHT IN/OUT = 8.5 PPG WBS: WEXIT Printed 4/23/2019 3:32:15PM ••AII dephts reported in Drillers Depths" Printed 4/23/2019 3:32:15PM **All dephts reported in Drillers Depths" North America - ALASKA - BP Page 9 j95 Operation Summary Report Common Well Name: NK -08 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/22/2019 End Date: 4/16/2019 X3 -0199F -C: (8,452,503 00 ) Project: Niakuk Site: NK Rig Name/No.: PARKER 272 Spud DateRime: 7/14/1994 12:00:OOAM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001319 Active datum: ACTUAL KB P272 @67.45usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations -. ._— (hr1. (usft) 10:00 - 16:00 6.00 STWHIP P 9,879.40 WEXIT RUN IN THE HOLE WITH 9-5/8" WHIPSTOCK ASSEMBLY PICKING UP 5" DRILL PIPE SINGLES FROM 953' MD TO 5181' MO - FILL PIPE EVERY 2000' MD - RUN IN THE HOLE AT 45 FPM PER SLB FISHING HAND MONITOR WELL WITH TRIP TANKAND HOLE FILL: GOOD DISPLACEMENT I - MUD WEIGHT IN/OUT = 8.5 PPG HELD KICK WHILE TRIPPING DRILLAND AAR WITH YEAROUTS CREW: 1.5 MIN WELL SECURE 16:00 - 20:00 4.00 STWHIP P 9,879.40 WEXIT CONTINUE TO RUN IN THE HOLE WITH 9-5/8" WHIPSTOCK ASSEMBLY ON 5" DRILL PIPE STANDS OUT OF THE DERRICK FROM 5181' MD TO 9812' MD '. '- FILL PIPE EVERY 2000' MD - RUN IN THE HOLE AT 45 FPM PER SLB FISHING HAND - MONITOR WELL WITH TRIP TANKAND HOLE FILL: GOOD DISPLACEMENT - MUD WEIGHT IN/OUT = 8.5 PPG - PU 204 KLBS, SO 140 KLBS AT 9812' MD WASH DOWN AND ORIENT WHIPSTOCK 150` RIGHT OF HIGH -SIDE - FROM 9812' MD TO TOP OF STUMP AT 9936' MD - TAG TOP OF STUMP WITH 10 KLBS TO TRIP ANCHOR - PICK UP 24' AND SET WHIPSTOCK -SET DOWN ON WHIPSTOCKAND SHEAR li OFF WITH 45 KLBS TOP OF WHIPSTOCK SLIDE AT 9890'MD 20A0 - 21:30 1.50 STWHIP P 9,879.40 WEXIT _ DISPLACE WELL FROM 8.5 PPG 3%KCLTO 9.5 PPG _SND - 550 GPM, 1200 PSI - MONITOR WELL FOR 10 MIN AFTER Wg16WEMEaN;F ISTATIG 21 30 - 00'.00 2.50 J r11��`yy��1 STWHIP P 9,879.40 WEXIT MILL 9-5/8" CASING WINDOW FROM 9859' MD rzrz TO 9862' MD (CORRECED DEPTHS) N K Uri 450 GPM, 1300 PSI, 80-120 RPM, 11-19 KFT-LBS TORQUE, 4 KLBS WOB - PU 204 KLBS, SO 141 KLBS, ROT 162 KLBS AT 9890' MD - MUD WEIGHT IN/OUT = 9.5 PPG 3/27/2019 00:00 - 09.00 9.00 STWHIP P 9,925.00 WEXIT CONTINUE TO MILL 9-5/8" CASING WINDOW AND 21' OF NEW HOLE FROM 9862' MD TO 9893' MO (CORRECTED DEPTHS) - 450 GPM, 1310 PSI, 80-120 RPM, 11-18 KFT-LBS TORQUE, 5-15 KLBS WOB - PU 204 KLBS, SO 141 KLBS, ROT 162 KLBS AT 9890' MD - MUD WEIGHT IN/OUT = 9.5 PPG - TOP OF WINDOW: 9890' MD (6136' TVD) - BOTTOM OF WINDOW. 9904' MD (6143' TVD) SIMOPS: - BUILD STANDS OF 5" DRILL PIPE UTILIZING OFF-LINE STAND BUILDING EQUIPMENT Printed 4/23/2019 3:32:15PM **All dephts reported in Drillers Depths" Common Well Name. NK -08 Event Type. RE-ENTER- ONSHORE (RON) Project: Niakuk Rig Name/No.: PARKER 272 Active datum: ACTUAL KB P272 @87 Date From - To 09:00 - 10:30 North America - ALASKA - BP Operation Summary Report Start Date: 3/22/2019 Site: NK Spud Date rime. 7/14/1994 45usft (above Mean Sea Level) Him Task Code NPT (hr) 1.50 STWHIP P 10:30 - 14:30 4.00 STWHIP P 14:30 - 18:00 3.50 STWHIP P - 18:00 - 19:00 1.00 STWHIP P 19:00 - 22:00 3.00 STWHIP -P -� 22:00 - 00:00 2.00 STWHIP P 3/28/2019 00:00 - 03:30 3.50 STWHIP AFE No Eno Date: 4/16/2019 X3 -0199F -C:(8,452.503.00) JAM Rig Release: 4/22/2019 SPUOIUSA00001319 Page 10 o06 Total Depth Phase Description of OpereBons (usft) 9,925.00 WEXIT RIG UPAND PERFORM LOT - MUD WEIGHT: 9.5 PPG, 6121' TVD, 9859' MD - PUMP 6.5 BELS TO 950 PSI, BLEED BACK 5 BBLS - LOT EM W = 12.4 PPG - KICK TOLERANCE >25 BBL WITH EMW >12.2 PPG — _ - LOT APPROVED BY ODE 9,925.00 WEXIT PULLOUT OF THE HOLE ON ELEVATORS FROM THE TOP OF THE WINDOWAT 9893' MD TO THE TOP OF THE BHAAT 948' MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OUT OF THE HOLE (STATIC) - MUD WEIGHT: 9.5 PPG - OBSERVE 1 JOINT DISCREPANCY IN THE DP -_ _ (1 JOINT SHORT) _ 9,925.00 WEXIT LAY DOWN MILLING ASSEMBLY FROM 9481 TO SURFACE - MONITOR WELL FOR 10 MIN AT THE TOP OF THE BHA (STATIC) - RACK BACK HWDP AND LAY DOWN MILLING TOOLS LEAD MILL 3/8" UNDER, FOLLOW MILL I/4" UNDER, DRESS MILL 3/16" UNDER 9,925.00 WEXIT CLEAN AND CLEAR RIG FLOOR FLUSH STACK _OPEN M_ANUALVALVES 9,925.00 WEXIT MAKE UP THE 1.5" MOTOR BHA TO TOTAL LENGTH OF 1092' MD - HOLD PRESPUD MEETING WITH LYLE BUCKLER'S CREW WHILE SURFACE TESTING MWD 9,925.00 _ WEXIT RUN IN THE HOLE ON 5" DP FROM THE TOP OF THE BHAAT 1092' MD TO 3925' MD AT MIDNIGHT - BHA WEIGHT 83 KLBS - SHALLOW HOLE TEST THE MWD WITH 550 GPM, 1020 PSI (GOOD TEST) - STRAP IN THE HOLE DUE TO DP DISCREPANCY OBSERVED ON THE TRIP OUT P 9,925.00 WEXIT RUN IN THE HOLE ON 5" DP FROM 3925' MD TO 9894' MD - STRAP IN THE HOLE DUE TO DP DISCREPANCY OBSERVED ON THE TRIP OUT - TOP OF THE WINDOW OBSERVED AT 9859' MD - ORIENT MOTOR 150° ROHS AND RUN TO BOTTOM AT 9894' MD 1 41232019 3:32:15PM **All dephts reported in Drillers Depths" NorthAmerica- ALASKA - BP Operation Summary Report Page 11;C 6 Common Well Name: NK -08 AFE No Event Type: RE-ENTER- ONSHORE (RON) _ Start Date: 3/22/2019 End Date'. 4/16/2019 X3 -0199F -C (8,452,503.00 ) Project: Niakuk - --- Site: NK - INSPECT BIT, 2 MISSING CONES Rig Name/NO.: PARKER 272 Sputl DateRme: 7/14/7994 12:0O:OOAM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. - LAY DOWN DIRECTIONAL TOOLS BPUOI: USA00001319 Active datum: ACTUAL KB P272 @67.45usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _(hr) DRILL (usft) 9,934.00 03:30 - 21:00 17.50 _ DRILL P 9,934.00 WEXIT DIRECTIONAL DRILLB-1/2" INTI HOLE FROM 9894' MD TO 9934' MD - 500-650 GPM, 1450-2200 PSI ON BOTTOM, 40-50 RPM, 12-18 KFT-LBS, 5-22 KLBS WOB - MW IN/OUT= 9.5 PPG, NO LOSSES DRILLING AHEAD - GASWATCH BACKGROUND RANGE =30 UNITS, MAX = 60 UNITS - NO BACKREAMING AT CONNECTIONS, SURVEY EVERY 30' FOR DIRECTIONAL MONITORING - SIMOPS: PICKUP 4" DRILLPIPE WITH OFFLINE EQUIPMENT - OBSERVE LOW ROP DUE TO ERRATIC TORQUE AND PUMP PRESSURES WITH THE MOTOR STALLING WHILE DRILLING. DISCUSS PLAN FORWARD WITH ODE AND WOS, DECISION MADE TO PULL OUT OF THE HOLE -. ___ _' - AND INSPECT THE BIT. _ 21:00 - 00:00 3.00 DRILL P 9 934 00 WEXIT PULL OUT O T 3/29/2019 00:00 - 01:00 1.00 DRILL 01:00 02:30 F HE HOLE FROM BOTTOM AT 1 9934' MD TO 3400' MD AT MIDNIGHT -- MONITOR THE WELL FOR 10 MIN PRIOR TO 'PULLING OFF BOTTOM (STATIC) - NO ISSUES PULLING THROUGH WINDOW - PU 200 KLBS, SO 145 KLBS AT 9934' MD -MW IN/OUT =9.5 PPG P r 9,934.00 W— EXIT PULL OUT OF THE HOLE FROM 3400' MD TO THE TOP OF THE BHA AT 1092' MD - MW IN/OUT = 9.5 PPG - MONITOR WELL FOR 10 MIN AT THE TOP OF THE BHA (STATIC) — 1.50 DRILL P ? 9,934.00 WEXIT PULLOUTOFTHE HOLE WITH THE BHA rnmeo 4232019 3:32:15PM '•AII dephts reported in Drillers Depths" FROM 1092' MD TO SURFACE - INSPECT BIT, 2 MISSING CONES - LAY DOWN DIRECTIONAL TOOLS DISCUSS PLAN FORWARD WITH ODE 02:30 - 03:00 0.50 DRILL P 9,934.00 WEXIT CLEAN AND CLEAR RIG FLOOR 03:00 - 05:00 2.00 DRILL N 9,934.00 WEXIT WAIT ON FISHING TOOLS 05:00 - 06:00 1.00 FISH N 9,934.00 WEXIT MAKE UP REVERSE CIRCULATING BASKET ASSEMBLY ON 5" HWDP PER SLB FISHING _ REP TO TOTAL LENGTH OF 931 - MD 06:00 - 10:00 4.00 FISH N 9,934.00 WEXIT RUN IN THE HOLE ON 5" DP FROM THE TOP ..- _ OF THE BHAAT 931'MD 709840' MD 10:00 - 11:30 1.50 FISH N 9,934.00 WEXIT _ OBTAIN BENCHMARK PARAMETERSAND ATTEMPT TO FISH LOST CONES AT 9934' MD - PU 192 KLBS, SO 135 KLBS, ROT 160 KLBS - 30 RPM, 9K TORQUE - WASH AND REAM DOWN TO 9904' MD, OBSERVE OBSTRUCTION AT 9904' MD, SET DOWN UP TO 14 KLBS ON OBSTRUCTION, OBESERVE ERRATIC TORQUE UP TO 18 KFT-LBS, UNABLE TO PROCEED PAST 9904' MD 11:30 - 15:00 3.50 FISH N 9,934.00 WEXIT PULLOUT OF THE HOLE FROM 9904'MD TO THETOPOFTHEBHAAT931'MD - MONITOR WELL FOR 10 MIN PRIOR TO PULLING OUT OF THE HOLE (STATIC) - MUD WEIGHT IN/OUT = 9.5 PPG rnmeo 4232019 3:32:15PM '•AII dephts reported in Drillers Depths" Common Well Name: NK -08 Event Type: RE-ENTER- ONSHORE(RON) Project: Niakuk North America - ALASKA - BP Operation Summary Report i Start Date: 3/22/2019 Site: NK AFE No End Date: 4/16/2019 X3 -0199F -C (8,452,503.00 ) Page 12 gfj5 nia nenxvn._ rnnnr=rt uz Spud Date/Time: 7/14/1994 12:00:OOAM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. _ BPU01: USA00001319 _ Active datum: ACTUAL KB P272 Q67.45us8 (above Mean Sea Level) _ Date From - To Him Task Code NPT Total Depth Phase Descnption of Operations (i _ __ _ (u_s8) 15:00 - 17:00 2.00 FISH N 9,934.00 WEXIT RACK BACK HWDP AND LAY DOWN RCJB FROM 931' MD TO SURFACE - MONITOR THE WELL FOR 10 MIN AT THE TOP OF THE BHA (STATIC) - ALL TEETH ROUNDED OFF, 2 TEETH DAMAGED, NO RECOVERY IN RCJB 17:00 - 21:00 4.00 STWHIP N 9,934.00 WEXIT MAKE UP AND RUN IN THE HOLE WITH 9-5/8" ! I HYDRAULIC SET WHIPSTOCKAND WINDOW MILLING ASSEMBLY TO 773' MD - MAKE UP BAKER ONTRAKAND SCRIBE TO MILLING ASSEMBLY - MAKE UP WHIPSTOCK (VERIFIED SHIMS INSTALLED FOR LOW -SIDE EXIT)AND MILLING ASSEMBLY - SHALLOW HOLE TEST MWD AT 100' MD (GOOD TEST) - RUN IN THE HOLE AT 63 FPM PER SLB FISHING HAND -MONITOR WELL WITH TRIP TANKAND HOLE FILL: GOOD DISPLACEMENT WEIGHT IN/OUT =9.5 PPG 21:00 - 00:00 3.00 STWHIP N 9,934.00 _-MUD WEXIT RUN IN THE HOLE WITH 9-5/8" WHIPSTOCK ASSEMBLY ON 5" DRILL PIPE STANDS OUT OF THE DERRICK FROM 773' MD TO 4100' MD - FILL PIPE ON THE FLY AND TOP OFF EVERY 5 STANDS - RUN IN THE HOLE AT 90 FPM PER SLB FISHING HAND - MONITOR WELL WITH TRIP TANKANO HOLE FILL: GOOD DISPLACEMENT -MUD WEIGHT IN/OUT=9.5 PPG 3/30/2019 00:00 - 04:30 4.50 STWHIP N 9,934.00 _ WEXIT CONTINUE TO RUN IN THE HOLE WITH 9-5/8" WHIPSTOCKASSEMBLY ON 5" DRILL PIPE STANDS OUT OF THE DERRICK FROM 4100' MD TO 9801' MD - FILL PIPE ON THE FLY AND TOP OFF EVERY 5 STANDS - RUN IN THE HOLE AT 90 FPM PER SLB FISHING HAND - MONITOR WELL WITH TRIP TANK AND HOLE FILL: GOOD DISPLACEMENT -MUD WEIGHT IN/OUT=9.5 PPG - PU 185 KLBS, SO 134 KLBS 0430 - 05:00 0.50 STWHIP N 9,934.00 WEXIT WASH DOWN AND ORIENT WHIPSTOCK 150° RIGHT OF HIGH -SIDE - RUN 10' PAST SET DEPTH AND PICK UP TO SET DEPTH AT 9801' MD (BOTTOM OF ANCHOR) - FUNCTION BYPASS VALVE UNTIL CLOSED AND PRESSURE UP TO SET WHIPSTOCK ANCHOR - SET DOWN ON WHIPSTOCKAND SHEAR OFF WITH 50 KLBS - TOP OF WHIPSTOCK SLIDE AT 9776' MD Printed 4/23/2019 3:32:15PM "All dephts reported in Drillers Depths" North America - ALASKA - BP Page 13df�J2 Operation Summary Report Common Well Name: NK -08 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 3/22/2079 End Date: 4/16/2019 X3 -0199F -C: (8,452,503 00 ) Project: Niakuk Site: NK Rig Name/No.: PARKER 272 Spud Date/Time: 7/14/1994 12:00:OOAM Rig Release: 4/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00007319 Active datum: ACTUAL KB P272 @67.45usft (above Mean Sea Level) - Date From - To Hm Task Code NPT Total Depth Phase Description of Operations hr (usft) �,�05:00 - 07:30 2.50 STWHIP N 9,934.EXIT p( 00 W MILL 9-5/8" CASING WINDOW FROM 9776' MD TO 9783'MD 500 GPM, PSI, 80-120 RPM, 11-18 KFT-LBS TORQUE, 5-15 KLBS WOB - PU 185 KLBS, SO 141 KLBS, ROT 162 KLBS - MUD WEIGHT IN/OUT = 9.5 PPG - OBSERVE -500 PSI PRESSURE LOSS WHILE MILLING, DECISION MADE TO PULL OUT OF THE HOLE TO TROUBLESHOOT PRESSURE - ---LOSS _ __ 07:30 - 11:30 4.00 STWHIP N 9,934.00 WEXIT _ PULL OUT OF THE HOLE FROM 9783'MD TO THE TOP OF THE BHAAT 748' MD - MONITOR THE WELL FOR 10 MIN PRIOR TO PULLING OUT OF THE HOLE (STATIC) i- MONITOR DISPLACEMENT ON TRIP TANKS: ,GOOD DISPLACEMENT _ MUDWEIGHT IN/OUT 9.5 PPG 11:30 - 13:30 2.00 STWHIP N 9,934.00 WEXIT I RACK BACK HWDPAND LAY DOWN UNNECESSARY BHA COMPONENTS FROM 1748' MD TO SURFACE � - MONITOR WELL FOR 10 MIN AT THE TOP OF THE BHA (STATIC) TEST BYPASS SUB, BYPASS SUB LEAKING, LAY DOWN BYPASS SUB AND MWD - MILLS GAGE = LEAD MILL 1/8 UNDER, FOLLOW MILL 1/16 UNDER, DRESS MILL IN GAGE _' _ 13:30 - 14:00 0.50 STWHIP N 9,934.00 WEXIT _ RUN IN THE HOLE WITH WINDOW MILLING ASSEMBLY TO TOTAL LENGTH OF 695'MD - MONITOR DISPLACEMENT ON TRIP TANKS GOOD DISPLACEMENT_ 14.00 - 18:00 4.00 STWHIP N 9,934.00 WEXIT RUN IN THE HOLE ON 5" DP FROM 695' MD TO 7300' MD - MONITOR DISPLACEMENT ON TRIP TANKS. — - - _ GOOD DISPLACEMENT_ _ 18:00 - 79:00 1.00 STWHIP N 9,934.00 WEXIT CUT AND SLIP 93'OF DRILL LINE -CALIBRATE BLOCK HEIGHT IN AMPHION — AND BAKER SYSTEMS 19:00 - 20:30 1.50 STWHIP N 9,934.00 WEXIT _ RUN IN THE HOLE ON 5" DP FROM 7300' MD TO THE WINDOW AT 9776' MD - MONITOR DISPLACEMENT ON TRIP TANKS: GOOD DISPLACEMENT 20:30 - 00:00 3.50 STWHIP N 9,934.00 WEXIT MILL 9-5/8" CASING WINDOW FROM 9783'MD TO 9790' MD, DRILLADDITIONAL 12' TO GET THE UPPER DRESS MILL PAST THE BOTTOM OF THE WINDOW TO 9802' MD - 450 GPM, 1225 PSI, 80.120 RPM, 16-18/11 KFT-LBS TORQUE ON/OFF, 5 KLBS WOB - PU 198 KLBS, SO 132 KLBS, ROT 158 KLBS - MUD WEIGHT IN/OUT = 9.6 PPG - REAM OUT WINDOW WITH MILLING ASSEMBLY, DRY DRIFT WINDOW WITH MILLING ASSEMBLY WITH NO ISSUES - TOP OF WINDOW: 9776' MD (6084' TVD) — — - BOTTOM OF WINDOW: 9790' M_ D (6090' TVD) 3/31/2019 0000 - 0200 2.00 STWHIP N 9,934.00 WEXIT COMPLETE WINDOW MILLING - SEE PREVIOUS TIME ENTRY FOR DETAILS Printed 423/2019 3:32:15PM "All dephts reported in Drillers Depths" TREE = 4-1/16' CIW 5M WELLHEAD FMC R= BAKER V = 60.8 INTERVAL 5283' = 221T900'le 6 17970- 18070 = 78' @ 14657= 2-12" 18248'D= 18090-18130 9200 SS 13-3/8- CSG, 68#, N-80, NSOC, D = 12.415" 1 Minimum ID = _" � _• aE 117- LNR, 290, ? HY D 511, .0371 bpf, D = 6.184" LNR I— 12344' PERFORATION SLIVWRY REQ LOG: SVS M WORY GR/OCL ON 04/06/01 ANGLE AT TOP RERF: 52' @ 17970' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-12" 6 17970- 18070 S 0111819 2-12" 6 18090-18130 S 01/18/19 2-12' 6 18150-18230 S 01/18/19 2-12" 6 18240 - 18300 S 01/18/19 2-12' 6 18315-18340 S 01/18/19 47#, NT -80S NSCC, D= 8.681' 13220' NK -08 9776' —t9518' VVFiPSTOCK BY RIG (03/J0/19) 9859' 958" WHPSTOCK BYFW f03M19) 9878' -4-12' WELLTEC MECH TBG CUT (3/12/19) ST92 6 3 REMOVED 03130MB when TBG pulled 12236' 9.518' X 7- BKR ZXP PKKD = 7.500" 12253' 9-518" X 7" BKR HYD LNR HGR D = 62 I 12264' H4-12"HES X NP, D=3.813' 12285' 7" X 4-12' BAK9i S-3 PKR ID = 3.875" 12308' 4-12" HES X NP, D 72329' 4-12' HES XN NP, ID = 3.725" 12342' 4-12' WLEG, D=3.958" ELMD TT NOT LOGGED 12343' 7" X4-12" XO, D= 3.938" 9.5/8' MLLOUTVITDOW TOP Q 12436 I PBT I— 18429' j STL NSCT, D=6.875" 15898' 4-12" LNR 12.68, L-80, HYDRL 521, 18517' .0152 bpf, I[)= 3.918" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/31184 ORIGINAL COMPLETHM 0121/19 JJUJMD P&A RESERVOIRPLUG 84/09MI RIG SIDETRACK NK08A 0321/19 RCB/JMD SETHOSLVw/ANCHOR 02/18/11 MB/JMD ADDEDSSSV SAFETYNOTE 0321/19 KFM/JMO TBGCUT&VALVE EDIT 05)04/12 JMD CSG DEPTH a WBS CORREC 0424/19 JNUJMD+ WHIPSTOCK SET 0326/19 0921117 JNUJMD ADDED OKB REF & BFE 0424/19 JNUJMD+ 2ND WS & TBG PULL 03730/19 01117/19 MTWJMD GLV C!O 01/02J19 /0 319 NEAKUK UNIT WELL: NK -08A PERMIT No: %10290 API No: 50-029-22491-01 SEC 36 T12N RISE, 1266' NSL 1099 ) BP Expkua8on (Alaska) MEMORANDUM TO: Jim Regg 4, 317liq P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: Austin McLeod Petroleum Inspector Section: 36 Township: 12N Drilling Rig: N/A J Rig Elevation: N/A Operator Rep: Robert Ryan/Jeremy Grimes Casing/Tubing Data (depths are MD): Conductor: 20" O.D. Shoe@ Surface: 13-3/8" O.D. Shoe@ Intermediate: 9-5/8" O.D. Shoe@ Production: N/A O.D. Shoe@ Liner: 7"x4-1/2" O.D. Shoe@ Tubing: 4-1/2" O.D. Tail@ Plugging Data: Test Data: DATE: February 6, 2019 SUBJECT: Plug Verification PBU NK -08A BPXA PTD 2010290; Sundry 318-561 Range: 15E Total Depth: 18517 ft MD 114 Feet 5798 Feet 12436 Feet N/A Feet 18517 Feet 12341 Feet Suspend: N/A Csg Cut@ Csg Cut@ Csg Cut@ Csg Cut@ Csg Cut@ Tbg Cut@ Meridian: Umiat Lease No.: ADL 034630 Casino Removal N/A Feet N/A Feet N/A Feet N/A Feet N/A Feet N/A Feet Type Plug Founded on Depth Btm Dept To MW Above vended Fullbore Bottom 18517 ft MD 12271 ft MD 6.9 ppg Wireline tag - 593 593 Initial 15 min 30 min 45 min Result Tubing 2735 2616 2574 IA 151 156 157 P OA 593 593 593 Remarks: Arrived at NK -08A for a plug tag via slickline and a MIT -T. Plug was for redrill of PBU NK -0813; 15.8ppg Class G cement. Slickline tool string consisted of 2.5" sample bailer, 2.8" centrilizer, weight bar and jars with a — total weight of 200 lbs. Cement stringers were worked through with ease from a Measured Depth of —12,200 ft to 12,271 ft, which is where the top of cement (TOC) was found. Multiple tags were made at 12,271 ft by picking up 200 ft above TOC and re -tagging at the same depth. While coming out of the hole, the wire parted when trying to work through the SSSV leaving the tool string downhole. A hold open sleeve was installed in SSSV followed by a passing test on the tubing. On 2/7/19, after the tool string was fished out, I went back and observed cement in the bailer. Notes/Extras: Inclination at plug depth -60 degrees. Top perforation -17,970'. MIT -T Pretest: Tubing-280psi, IA-127psi, OA-593psi with 2.74bbls in; 2.77bbls out. Casing/Tubing data does not include rig RK13. Other Lease Numbers: 034625/034626 Attachments: none rev. 11-28-18 2019-0206_Plug Verification_PBU_NK-08A_am • • w w� . 1//7,-ws THE STATE Alaska Oil and Gas ®fALS KA Conservation Commission 5 r# �_ 333 West Seventh Avenue —1117„;;;;,%"t _ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALAS**' Fax: 907.276.7542 www.aogcc.alaska.gov Kenneth Allen Engineering Team Lead BP Exploration(Alaska), Inc. PO Box 196612 scoNED DEC 1 5 ZQ17 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Niakuk Oil Pool, PBU NK-08A Permit to Drill Number: 201-029 Sundry Number: 317-516 Dear Mr. Allen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis. S. French �t• Chair DATED this l day of December, 2017. RBO S LAG : u 2 7 RECEIVED •ALCZSTATE OF ALASKA .-( 711 ? ASKA OIL AND GAS CONSERVATION COMMIS ION D IZY ` APPLICATION FOR SUNDRY APPROVALS NOV 0 2 2017 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ p /QPI sb,yldown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 h A (P4dEj ram ❑ Plug for Redrill EJ• Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-029 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development a. 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22491-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No IZI • PBU NK-08A • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 034630,034625&034626 ' PRUDHOE BAY,NIAKUK 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): 18517 • 9426 • 18429 9368 3535 V None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 34-114 34-114 1530 520 Surface 5765 13-3/8" 33-5798 33-4137 5020 2270 Intermediate 12406 9-5/8" 30-12436 30-7353 6870 4760 Production Liner 6281 7"x 4-1/2" 12236-18517 7251-9426 8160/8430 7020/7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 17970-18340 9082-9311 4-1/2"12.6# L-80 28-12341 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 12284/7275 4-1/2"HES TRSSSV 2037/1971 12.Attachments: Proposal Summary 121 Wellbore Schematic IZ1 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch IZI Exploratory 0 Stratigraphic 0 Development El ' Service 0 14.Estimated Date for Commencing Operations: February 1,2018 15. Well Status after proposed work: . Oil 0 WINJ 0 WDSPL 0 Suspended E0 ' 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Sperry,Nathan be deviated from without prior written approval. Contact Email: Nathan.Sperry@bp.com Authorized Name: Allen,Kenneth W Contact Phone: +1 907 564 4258 Authorized Title: Engineering Team Lead Authorized Signature: /l, Cr Date:I NL/ /' COMMISSION USE Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test 0 Location Clearance 0 '3 17• S Other: 8 0p f t 5 t to 4 aa O p ,{-i✓lvJa ✓pre VK��� its1 I-z, �S0vC) sz � Post Initial Injection MIT Req'd? Yes 0 No I Spacing Exception Required? Yes 0 NoE SSubsequent Form Required: / 9- 1 0.7- APPROVED BYTHE Approved by: tia2:1-\_______ COMMISSIONER COMMISSION Date: 1-7-- (-1 1%3 117-- 12/j /11 CAY ORIGINAL rECv mac:: G 6 2517 \ti Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attac is in Duplicate • • bP NK-08A Sundry Application Well Type: Producer Current Status: The well is currently shut-in. Request: Approval is requested for the P&A of NK-08A to sidetrack and complete NK-08B. CMIT-TxIA Passed to 4000 psi (8/4/2017) MIT-OA Passed to 1100 psi (8/4/2017) PPPOT-T Passed to 4500 psi (7/3/2017) PPPOT-IC Failed to 3500 psi (7/3/2017) Well History: NK-08 was drilled and completed in 1994. The well was rotary sidetracked in 2001 to NK-08A. The well has TxIA communication that has been manageable by bleeds. The oil rate has dropped significantly. Scope of Work: The sidetrack plan for NK-08B well includes the following operations. Pre-rig, the perforations will be P&A'd with cement. Once the cement has setup, the final top of cement will be determined with a drift run followed by an integrity test of the tubing and inner annulus. Next, the tubing will be jet cut. The rig will move over the well and pull the tubing. The 7" intermediate liner will be set at the top of the Sag River formation and the 6-1/8" production hole will be drilled in the Sag River formation with a heel sump in the Ivishak reservoir. The production liner will be fully cemented 4-1/2" 13Cr liner. 4-1/2" tubing will be run to the top of the production liner. MASP: 3,535 psi Estimated Start Date: March 1, 2018 �"elCflf. 74 e �v�Je'Cr ;,..ell f plc�t3/vcl`,a7 fG to 4'146 �'Prl .S�rPRa/, (y 6); eG/s 4,-retCtigv ifr < RIP Acfr,". J y. Wil ;04,0147 fecvfref, 79C)111 i4) /10. 1 1'4 47 ore 1_11, c,,etct. NK-08A Sundry 1 11/1/2017 • Loepp, Victoria T (DOA) From: Sperry, Nathan <Nathan.Sperry@bp.com> Sent: Tuesday, November 28, 2017 9:55 AM To: Loepp,Victoria T (DOA) Cc: Lastufka,Joseph N Subject: RE: PBU NK-08A(PTD 201-029, Sundry 317-516) Plug for Redrill Follow Up Flag: Follow up Flag Status: Flagged Victoria, Our plan is to squeeze cement into the perfs and to leave a plug inside the 4-1/2" liner.The minimum planned plug length is 1300' MD.The cement will be 15.8ppg Class G.The planned TOC is 16,675' MD. The minimum volume pumped will be 20 bbls(112.4 cu ft,96 sacks). Regards, Nathan Sperry Drilling Engineer C: (907)268-8416 0: (907) 564-4258 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, November 28, 2017 8:50 AM To:Sperry, Nathan<Nathan.Sperry@bp.com> Subject: PBU NK-08A(PTD 201-029,Sundry 317-516) Plug for Redrill Nathan, Please include a detailed procedure for the cementing of the perforations. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa,alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.ciov • 1 S Pre-Rig Prep Work: Step Service Line Description of Work 1 F P&A perfs with cement. Min TOC is 100' above the shallowest perforation. 2 S D&T TOC. Drift for jet cut. b6 fi ✓ /1-616"CC- / C 3 E Run MTT log to determine 9-5/8"collar locations. / `� 4 E Jet Cut TBG-10,000' MD. Planned KOP is-10,000' MD. 24- k.3 5 F A/SL: CMIT-TxIA 4000 psi. 6 D Bleed TWO to 0 psi. 7 V Install Dry Hole Tree. Install Annulus Valves. Set TWC. Proposed Drilling Rig Operations: 1. Rig up Parker 272. • 2. Test TWC from above and below to 4,000 psi psi for 5 minutes each. 3. Nipple down tree. Nipple up BOPE and test to 4,000 psi. (Configured from top to bottom: 13- 5/8" annular preventer, 2-7/8"x 5"VBRs in the upper cavity, blind/shear rams, mud cross and 2-7/8"x 5"VBRs in the lower cavity). a. Test rams and annular to 250 psi/4,000 psi with 4" and 5"test joint. b. Notify AOGCC 24 hrs in advance of full test. 4. Pull TWC with lubricator. 5. Rig up hard lines to BOP. Circulate out diesel freeze protection and displace well to clean seawater. 6. Pull tubing from the pre-rig cut. 7. Optional:Perform 9-5/8"cleanout run to tubing stub. 8. Change IC packoff(FMC). 9. Pick up the 9-5/8" whipstock, bottom trip anchor, and 8-1/2" window milling assembly (to include full gauge string mills). Run in to the top of tubing stub, orient, and set whipstock. Top of the whipstock will be set at 10,000' MD. 10. Swap wellbore over to 9.5 ppg LSND milling fluid. Drill 8-1/2" x 9-7/8" Intermediate Hole 11. Mill window in 9-5/8"casing plus 20'-40' (depending on next assembly) of new formation. 12. Pull into the window and perform LOT. Minimum LOT required is 11.9 ppg EMW for 25 bbl kick tolerance. 13. Pull out for drilling BHA#1. 14. Make up 8-1/2" motor assembly and drill until three consecutive clean surveys are obtained. 15. Pull out of the hole. Make up 8-1/2"x 9-7/8" drilling RSS BHA#1 w/MWD/RES/PWD/near-bit GR and run in the hole. 16. Kick off and drill 8-1/2"x 9-7/8" intermediate interval per the directional plan to TSGR TD of 15,691' MD. 17. At TD, circulate until wellbore is clean. 18. Perform short trip to the window. 19. Run in to TD, circulate the wellbore clean and pull out on elevators. Run & Cement 7" Intermediate Liner 20. Change upper 2-7/8"x 5"VBR's to 7"fixed rams and test to 250 psi low/4,000 psi high for 5 min each. NK-08A Sundry 2 11/1/2017 • 21. Run 7", 26#L-80, VamTop HC liner to TD,with 150' liner lap into 9-5/8"window. 22. Cement liner with 15.8 ppg Class G tail cement. Circulate excess cement above TOL. Plan for TOC to be 1,300' MD above TKUP. 23. Set liner top packer and liner hanger. POOH and LD liner running tool. 24. Change upper 7"fixed rams to 2-7/8"x 5"VBRs and test to 250 psi low/4,000 psi high for 5 min each. 25. Test 7" liner to 250 psi low for 5 min/4,000 psi high for 30 min after cement has reached a minimum 500 psi compressive strength. Drill 6-1/8" Production Hole Section 26. Make up the 6-1/8"drilling BHA with MWD/GR/RES and trip in the hole. 27. Run in and tag landing collar. 28. Displace wellbore to 9.2 ppg QuikDril-N. 29. Perform a flowcheck on 7" liner(no flow test). 30. Drill shoe track and 20 ft of new formation. Pull above shoe and perform FIT. Minimum FIT required is 10.2 ppg EMW for>25bbls KT. 31. Drill 6-1/8" production interval per the directional plan to TD of-19,697' MD. 32. At TD, circulate bottoms up until the wellbore is clean. 33. Perform short trip to the shoe. 34. Run in the hole to TD, circulate the wellbore clean and pull out of the hole on elevators. 35. Lay down excess drillpipe and BHA. Run 4-1/2" Production Liner& Perforate 36. Run 4-1/2", 12.6 ppf, 13Cr, VamTop production liner to TD with 150 ft liner lap into 7"casing. 37. Fully cement the liner. 38. Set liner hanger and liner top packer. 39. Displace wellbore to clean 9.2ppg brine above the top of the liner. 40. Pull out and and lay down the liner running tool. 41. Pressure test 9-5/8" casing x 7" liner x 4-1/2" liner envelope to 250 psi low for 5 min/4,000 psi high for 30 min. 42. Run in and perforate liner. Perforate with HES 2-7/8" MaxForce perf guns(1,600' planned). Run 4-1/2" Completion 43. Rig up and run 4-1/2", 12.6# 13Cr VamTop completion per the tally. Tag up in PBR, space out, and land tubing hanger. Run in the lockdown screws. 44. Displace tubing and IA to clean brine. 45. Reverse circulate in heated brine and inhibited brine to IA and tubing (surface to surface). 46. Drop ball & rod and set production packer. Individually test tubing and IA to 250 psi low for 5 min/ 4,000 psi high for 30 min. 47. Hold pressure on the IA and bleed tubing pressure down to shear the DCR valve. Pump both ways to confirm circulation ability. 48. Reverse circulate in diesel freeze protect down IA using rig's injection pump to freeze protect IA and tubing to 200' TVD below BPRF. 49. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. NK-08A Sundry 3 11/1/2017 • ND/NU 50. Install TWC and test from above and below to 250 psi low/4,000 psi high for 5 minutes each. 51. Nipple down the BOPE. Nipple up the adapter flange and double master valves. Test to 250 psi/ 5,000 psi for 5 minutes each with diesel. 52. Ensure Heet is left on top of TWC and only diesel is left in the tree. 53. Install all annulus valves and secure the well. Release Rig 54. Rig down Parker 272. 55. Move rig off location. Post-Rig Operations 1. Change out dry hole tree for production tree. 2. Pull TWC, ball and rod, and RHC plug. Pull shear valve and install GLVs. 3. Flowback, per ASRC. 4. Install flow lines and well house. Drilling Engineer: Nathan Sperry (907) 564-4258 Production Engineer: Kirsty Schultz (907) 564-5105 Geologist: Mark Bowman (907) 564-4259 NK-08A Sundry 4 11/1/2017 TREE= 4-1/16'CM'SM SES: WELL REQUIRES A SSW WHIJEAD= FMC • waLANGLE>70° 12666.OLD 5-1/2"LNOWEWS ACTUATOR= BAKER NK-08A p&A.d ARE t#DT SWANN ON DIAGRAM. CX<E3.ELEV= 60.8' REF ELB/= 52.83' BFBIV= 22.17 KOP= 900' 2037' —14-1/2"HES FW TRSSSV MP,E)=3.813" Max Angle= 78' t, 14657 0 Datum NU= 18248' GAS LIFT MANDRES Daturn TVD= 9200'SS ST NO TVD DEV TY FE VLV LATCH PORT DATE 3 3572 3033 55 MG-14.4 DONE RK 16 04/22/12 2 8403 5433 61 NU3-M DONE RK 16 04/22/12 1 12198 7232 59 M3-M SO RK 24 04/22/12 13-3/8"CSG,68#,N-80,NSCC,ID 12.415' H Me' _Al 12236" —9-5/8"X 7-BKR ZXP PKR,ID=7.500" 12253' —19-5/8"X r BKR HYD LIW FIGR,D=6.276' 12264' 4-1/2"I-ES X MP,ID=3 813" Minimum ID =3.725" © 12329' 12286' --17"X 4-1/2"BAKER S-3 PKR,D=3.875" 4-1/2" HES XN NIPPLE 12308' I—4-112"FES X NV,ID=3.813" 12328' H4-1/2"FES XN MP, =3.725" 4-1/7'TBG,12.8#,L-80 13T-M,K)=3.958" H 12342' • 12342' H4-1/2"WLEG,ID=3.958' ELMD Tr NOT LOGGED 7"LW,29,1,?HY D 511_0371 bpf,13=6.184" H 12343' V 12343' —r x 4-1/2-X0,1E) 3.938" TOP OF 4-1/2"LNR H 12344' PERFORATION SUMMARY 9-518'OALLOUT WINCOW REF LOG:SWS it/ENERY GR/CCL ON 04/06/01 TOP 12436' ANGLE AT TOP PBRE:520 @ 17970° istte:Refer b Production DB for Nstorical pert data SE SPF INTERVAL Opn/Sqz DATE 2-117 6 17970-18070 0 04/06/01 2-1/2' 6 18090-18130 0 04/06101 ? H WI- STOOK SET ON TOP OF OSP 2-1/2' 6 18150-18230 0 04/06/01 S 2-112" 6 18240-18300 0 04/06/01 lIP 4. 12462" H 9-5/8"( P-SET 03/22/01 2-1/7 6 18315-18340 0 04/06/01 4. 4. 4. .4 Immo. 9-5/8"CSG,47#,NT-80S NSCC,0 8.681" 13220' PBTD 18429' 7-5/8"CSG,29.7#,STL NSCT,D=6875" H 15898' PI 4-1/2'LW,12.6#,L-80,11Y DRI..521, — 1851T .0152 bpf,ID=3.918' DATE REV BY 0OP4ENTS DATE REV BY COMENTS NAKIX 08/31/94 MORTAL COMPLETION 02/18/11 MAID ADDEO SSSV SAFETY NOTE ELL: NK-08A 04109101 RIO SMETRACK(M(-08A) 6 05/04/12 MACAU GLV C/O(04/22/12) Fewr ND: 2010293 10/17/04 GRUTLH CaRRECRONS 05/04/12 JM) CSG DEFTH&WBS CORFEC11C API lb: 50-029-22491-01 10/09/05 RPHTLI-1 WAIVER SFTY NOTE DELETED I 09/21/17 .1141JAD ADDED Of<8,REF,&EWE SEC 36,T12N,R15E,1266'NSL, 1099'WEL 09/08/06 CS/PJC IVEY M)DATUM CORRECTIONS 01/04/07 G.F/TLH GLV CIO(12/26/06) liP Exploration(Alaska) TREE= 4-1/16"CNV5M • . SA NOTES: WELL REQUIRES SSSV. VV13_LI-EAD= FMC N K 0 8 A WELL ANGLE>70°@ 12666'.OLD 5-1/2"LNRIPERFS ACTUATOR= BAKER P&A'd ARE NOT SHOWN ON DIAGRAM. KB.ELEV= 52.83' BF.ELEV= 19.6' I I KOP= 900' Max Angle= 78°@ 14657 203T H 4-112"HES FMX TRSSSV NP,ID=3.813" Datum MD= 18248' O Datum TVD= 9200'SS GAS LFT MANDRELS ST MJ TVD DEV TYPE VLV LATCH PORT DATE LI 3 3572 3033 55 tutvIG-M1Ximmy RK 16 04/22/12 2 8403 5433 61 144G-M Dummy RK 16 04/22/12 1 12198 7232 59 AMID-M Dummy RK 24 04/22/12 13-3/8"CSG,68#,N-80,NSCC,13=12.415" H 5806' Al , Cut tubing at -10,000' MC IS �— 12236' H 9-5/8"X 7"BKR ZXP PKR,D=7.500" — — 12253' H9-5/8"X 7"BKR HYD LNR HGR,D=6276" ' r I 12264' —14-1/2"4-1/2"I-ES X NP,ID=3.813" Minimum ID =3.725" @ 12329' $ g 12285' HI7"x 4-1/2"BAKER S-3 PKR,D=3.875" 4-1/2" HES XN NIPPLE I I 12308' H4-1/2"HES X NP,ID=3.813" I I 12329' H4-1/2"HES XN NP,ID=3.725" 4-1/2"TBG, 12.6#,L-80 DT-M,ID=3.958" H I 12342' 12342' --I4-1/2"WLEG,D=3.958" H BMD TT NOT LOGGED 7"LW,29#,?HYD 511,.0371 bpf,13=6.184" H 12343' 12343' H 7"X 4-1/2"X0,13=3.938" TOP OF 4-1/2"LNR — 12344' 9-5/8"MLLOUT WINDOW TOP@ 12436' F RFORATION SUMMARY REF LOG:SWC kU*JRY GR/CCL ON 04/06/01 12462' H 9-5/8"CMP-SET 03/22/01 ANGLE AT TOP PERF:52°@ 17970' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE Top of 4-1/2" annulus cement to . 2-1/2" 6 17970-18070 04/06/01 16,254' w/ 30% washout (4/2/01) 2-1/2" 6 180 18130 s 04ro6/ 1 Pre-rigTOC to 17,870' MD minimum 2-1/7 6 18150-18230 S 04/06/01 2-1/T 6 18240-18300 S 04/06/01 • lholi 2-1/2" 6 18315-18340 S 04/06/01 111 9-5/8"CSG,47#,NT-80S NSCC,D=8.681" H 13220' ;SAI• PBTD 18429' 7-5/8"CSG,29.7#,STL NSCT,D=6.875" —I 15898' , 4-1/2"LNR,12.6#,L-80,HY DRL 521, 18517' .0152 bpf,D=3.918" DATE REV BY COMMENTS DATE REV BY COMMENTS MAKUC UNIT 08/31/94 ORIGINAL COMPLETION 02/18/11 M3/JMO ADDEDSSSV SAFETY NO IE WELL: NK-08A 04/09/01 RIG SIDETRACK(NK-08A) 05/04/12 M3MJND GLV C/O(04/22/12) FU AT No: `2010290 10/17/04 GRC/TLH CORRECTIONS 05/04/12 JM) CSG DEPTH&WBS CORRECTIC AR No: 50-029-22491-01 10/09/05 RPFVTLH WAIVER SF-1Y NOTE DELETED "L 1' NS Proposed Re-Rog SEC 36,T12N,R15E,1266'NSL, 1099'WEL 09/08/06 CS/PJC 1 V D/MO DATUM CORRECTIONS 01/04/07 GJF/TLH GLV C/O(12/26/06) — BP Exploration(Alaska) TREE= 4-1/16"CNV 5M SA NOTES: WELL REQUIRES A SSSV. ACTLFEAD= BAKER PROP E D NK-08' K-0 8 WELL ANGLE>70°@ OLD 5-1/2"LNR/PERFS P&A'd ARE NOT SHOWN ON DIAGRAM. st$i FTORT a KB-E EV= 5283' LNR. BF.ELEV= 19.6' ) I KOP= -- J —900 2000' 4-112'SCSSV NP D=_ Max Angle= _°@ I Datum MD= GAS UFT MANDRB S Datum TV D= 9200'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 7 6 5 13-3/8"CSG,68#,N-80,NSCC,D=12A15" –{ 5806' 43 2 1 TOP OF7"LNR 8860' 8850' –19-5/8"X 7"LTP w/HGR,13= " Minimum ID = " –4-1/2"HES X NP,V=3.813" S ► –17"X 4-1/2"BAKER S-3 PKR,D=3.875" 9-5/8"SLB IM 8 vTOCK(_/_/ /) –{ 10000' • –14-1/2"HES X NP,D=3.813" 9-5/8"CSG,47#,NT-80S NSCC,ID=8.681" –� –10000' H4-112"HES XN NP,D=3.725" MLLOIIT WI'VDOW(NK-08A) 10000'- ' 4-1/2'TBG,12-6#,13-CR VAM TOP, –� 155410 0152 bpf,ID=3.958' 15541' H4-1/2"VI/LEG,D=3.958" TOP OF 4-1/2"LNR H 15541' -i ELMO n NOT LOGGED 7"LNR,26#,L-80 VT HC,.0383 bpf,D=6.276" –I 16691' PERFORATION SUMMARY REF LOG:SINS M AURY GR/CCL ON 04/06/01 ANGLE AT TOP PERE:52°@ 17970' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE PBTD --I ee. . $ w. 4-1/2"LNR,12.6#,13-CR,VAM TOP, –j 19697' 46:4 .0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS NAKUK UMT 08/31/94 ORIGINAL COMPLETION WELL: NK-08 04/09/01 RIG SIDETRACK(NK-08A) PST No: RIG SIDETRACK(NK-08B) AR No: 50-029.22491-0:>' jMD BI1L.T PROPOS® SEC 36,T12N,R15E,1266'NSL, 1099'WB_ BP Exploration(Alaska) 1 • 0 •U o ; ceU• _ WW> N W m F< m \ O > U U co 8 F O . 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S en 0 .Z/l Ol-,lZ O & O ,Z/t 0-Xt C (/D4 O (3M1 XJWi130) • • - Loepp, Victoria T (DOA) From: Sperry, Nathan <Nathan.Sperry@bp.com> Sent: Tuesday, November 28, 2017 9:55 AM To: Loepp,Victoria T(DOA) Cc: Lastufka,Joseph N Subject: RE: PBU NK-08A(PTD 201-029, Sundry 317-516) Plug for Redrill Follow Up Flag: Follow up Flag Status: Flagged Victoria, Our plan is to squeeze cement into the perfs and to leave a plug inside the 4-1/2" liner.The minimum planned plug length is 1300' MD.The cement will be 15.8ppg Class G.The planned TOC is 16,675' MD. The minimum volume pumped will be 20 bbls(112.4 cu ft,96 sacks). Regards, Nathan Sperry Drilling Engineer C: (907)268-8416 0: (907)564-4258 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, November 28,2017 8:50 AM To:Sperry, Nathan<Nathan.Sperry@bp.com> Subject: PBU NK-08A(PTD 201-029,Sundry 317-516) Plug for Redrill Nathan, Please include a detailed procedure for the cementing of the perforations. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov 1 • • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsi e 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or I "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist A.Swork) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • • x r, Thousand Cubic Feet of Gas ("MCF") per Month us o o -- o '� 1 , - 0 0 00 0 O c 0 0 0 co o 0 0 0 0 o Olz N O srOe oo i , o ll 9 rn G �/ a . T rOCV e 1-1 o N ° � �1101111 liii- ._ z * 0 rO�GP� m vVCU a a ° cu v o° a � St0 o a....._=_..4...._„_.44,,,,,..__ " °0 , 1 ° , OOP a 0 1 Q C a •t a O 8 _ a a' I _, ; b Z 0.0 - _ - rim r r0e -o Z _ a4 13„ 0I D ._._ 6 ° Fromm wI 0oa �, I c'r0 0 I m �8 ° ° a°O °� o—'. IOP w a a N W M ° 0 ° � tl ° ° rr • Y o °o • a0�4 z 3 0 0 141 0® O20c -0 �`o a ° `P/ QO oao e ' S LSI a coCC " CL8 _. ��( 3 LU 0 o ,-.„e ...N P, o c d4,� a 0 o°O° Q � C o 4 8 V = O o o a OOt 4P 0 8 r o ° m Z oo,, ova a y .., 1pOr i� d l I' ' a 4P/ doa e ° Do o n°e 900c o J o8• � _ a v roOck V s1 ,S,,?, N Q $zl VD M e v .4' N m n • EA. _. c vi b00 a Z `�. =i..po N �` m 3 r O A dam, 08 £ *0 �o O a I O a`3 U rOoe CL 000-s CO 0 0 0 0 0 `P 0 0 0 0 .1 r O 0 0 --i 0 0 r+ 0 y;uow -lad Ja4eM 3 o siaa.ie8 J ypuo j aad no 4o siaJJe8 Imag~' 'reject Well History File Cover i ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aC-l- Oe~.? Well History Fileldentifier RESCAN DIGITAL DATA OVERSIZED (Scannable) F__3 Color items: / Diskettes, No. i B Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner n Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [] Logs of various kinds cJ Other Project Proofing BY: BEVERLY ROBIN VINC',ENT SHERY~WINDY Scanning Preparation / x 30 = _~.~__ BY: BEVERLY ROBIN VINCENT SHERY~WINDY ~.. % : TOTAL PAGES 3/ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER ~N SCANNING PREPARATION: -.~e.-- YES BY: BEVERL',C~J) VINCENT SHERYL MARIA WINDY DATE:~F~/S/ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERL,~ VINCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL ~AGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality Checked 12/10/02Rev3NOTScanned,wpd • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 4 y, July 6, 2011 ,;'�,�¢. �: i (;f`, Mr. Tom Maunder Q •'1 Alaska Oil and Gas Conservation Commission ^ 0 I 333 West 7th Avenue avl, Anchorage, Alaska 99501 o Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk 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, Mehreen Vazir, at 659 -5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 Corrosion Initial top of Vol. of cement 0 Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1780280 500292015801 P&A 3/9/91 NA NA NA NA NA NK -02A 1780790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA te,7, NK-04 1842000 500292121700 P&A 4/14/96 NA NA NA NA NA NK -05 1850270 500292129000 P&A 4/15/98 NA NA NA NA NA NK-06 1852760 500292148800 P&A 4/15/96 NA NA NA NA NA NK -07A 2010830 600292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 500292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292261800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 500292242500 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 500292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030550 500292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1981340 600292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2080310 500292288801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 600292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -18 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1981850 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/8/2011 NK -19A 2010700 500292260701 1.8 NA 1.8 NA 15.3 5/8/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940880 500292248700 2 NA 2 NA 22.1 5/16/2011 NK -22A 2012280 500292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970880 500292278000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -28 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1980930 500292267800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1981900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.8 5/8/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.6 5/9/2011 NK-43 2010010 600292299800 1 NA 1 NA 5.1 5/9/2011 NK-81A 2080350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK-62A 2030470 600292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-65A 2050830 500292288901 1 NA 1 NA 8.5 5/8/2011 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ 9 ¡UO 80 l-OÐcr Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job# LOQ Description Date B olor P2-37A 11491392 MEM PROD PROFILE 11115106 , Y-23B 11418299 MEM PROD PROFILE 09106106 1 NK-07A 11588698 MEM GLS 12121106 1 07-01A 11555031 GAS ENTRY SURVEY 12119106 1 NK-D8A 11485780 MEM GLS 12120/06 1 NK-27 11588699 MEM GLS 12122106 1 NK-43 11513659 PRODUCTION PROFILE 12/22106 1 DS 09-32 11555530 INJECTION PROFILE 12116106 1 P2-14 11539745 MEM PROD PROFILE 12107106 1 Y-OSA 11539744 MEM INJECTION PROFILE 12106106 1 S-02A 11285936 MEM PROD PROFILE 08117106 1 12-32 11536184 USIT 12105/06 1 MPS-10A 11486087 COMPOSITE WFLlLDL 12/14106 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L 1 11588700 MEM PROD PROFILE 12123/06 1 E-11 B 11434757 DSI 10/24106 1 E-11 B 11434760 DSI 10129106 1 E-11B 11434760 FMI 10129106 1 G-14A 11485777 MEM PROD PROFILE 11127/06 1 G-14A 11485777 SCMT 11127/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 SCANNED JAN 3 0 2007 900 E, Benson Blvd, Anchorage, Alaska 99508 Date Delivered: 01125/2007 NO. 4125 Field: Prudhoe Bay L C CD . . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 0\ e e (~, '''.;, "'r"";;,~'" .: .;..1i.o.... . >;-.'-- . .. ,1- - MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: 8eth Well r MPI-09 MPI-09 )..\JQ - (\..) J ___ -- ~I-Q~ 0 1.L~ I NK-08A U NK-08A 18-34 ,C\ç- i6¥ 04-05A í('¡3 "13 ~ 18-05A '1 \.. ). -1. ( G 07-36 ; Q'7 - { ~ 'I 14-36 18 J .. I (.3 C-13A / q 7 - ; ..., J U-12 18S--/~J.... R-21 I S3 -. Il.~ R-12 í9 3 -. 0 ;~... E-16 /SC - (¡ (i :3 J-23 I '8 .,... \) J t F-31 I 3 ~ - ¡ ,-7 H-35 Cj '} - ¡ t.t q Job# 10563225 10980572 10772241 10560316 10703956 10564525 10703939 10563112 10866557 10564527 11075900 10674388 10687647 10564529 10663003 10703943 10563217 10563216 Log Description INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PSP GLS PPROF W/DEFT PSP LDL PRODUCTION PROFILE LEAK DETECTION LOG LEAK DETECTION LOG INJECTION PROFILE MEM PROD & INJECTION PROFILE LDL PRODUCTION PROFILE PSP PPROF W/GHOST/DEFT PRODUCTION PROFILE SBHP SURVEY SBHP SURVEY PPROF W/GHOST Date 10/05/03 06/09/05 04/04/04 10/22/03 11/27/03 09/27/03 10/24/03 10/13/03 07/14/04 09/29103 07/05/05 10/27/07 09/20/03 10/01/03 03/10/04 10/28/03 09/28/03 09/27/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ) I :;<~V U- v¡ ) h, '--. (,~\:''i' ) A r. 'Jon!: ,-. ¿--. ¡, hi h.\E- r',. c: C' r- p ·0-; '- U J ~\.Jj;é~~~ ~ '-JLr''- 07/20/05 NO. 3438 aOI -- ð ~c Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth '} J J Received by: lJ..í~ ~- .~ .--- (1/ ¡ f. i)k~·· '-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TI 1 . Operations Performed: Abandon 0 Alter Casing D Change Approved ProgramD Repair Well 0 Pull TubingD Operation Shutdown 0 PluQ Perforations 0 Perforate New Pool 0 Perforate 0 Stimulate Œ:I OCftttrGJ2004 WaiverD Time ExtensionD Re-erAl~~§pQ~N~~IIt]n¿;. Commission 52.83 8. Property Designation: ADL-OO34626 11. Present Well Condition Summary: 4. Current Well Class: Development Œ] Stratigraphic 0 9. Well Name and Number: NK-08A ExploratoryD ServiceD 5. Permit to rill umber: 201-0290 6. API Number 50-029-22491-01-00 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 10. Field/Pool(s): Niakuk Field / Niakuk Oil Pool Total Depth measured 18517 feet true vertical 9425.6 feet Effective Depth measured 18429 feet true vertical 9368.5 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 34 114 34.0 - 114.0 1530 520 Liner 108 7" 29# L-80 12236 - 12344 7250.8 - 7305.9 8160 7020 Liner 6173 4-1/2" 12.6# L-80 12344 - 18517 7305.9 - 9425.6 8430 7500 Production 12408 9-5/8" 47# NT80S 30 - 12438 30.0 - 7353.5 6870 4760 Surface 5765 13-3/8" 72# N-80 33 - 5798 33.0 - 4136.6 4930 2670 Perforation decth: Measured depth: 17970 -18070,18090 -18130,18150 -18230,18240 -18300,18315 -18340 True vertical depth: 9082.07 - 9143.27,9155.49 - 9179.97,9192.26 - 9241.76,9247.98 - 9285.54, 9295.01 - 9310.92 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 27 12342 Packers & SSSV (type & measured depth): 4-112" Baker S-3 Perm Packer 4-1/2" HES TRSSSV 7" Baker ZXP Liner Top Packer @ 12285 @ 2037 @ 12236 12. Stimulation or cement squeeze summary: Intervals treated (measured): 17970 -18340 Treatment descriptions including volumes used and final pressure: 50 Bbls Diesel/ Xylene, 123 Bbls 7.5% HCL w/10% Xylene @ 3650 psig Recresentative Dailv Averaae Production or Iniection Data 13 Prior to well operation: Subsequent to operation: Oil.Bbl Gas-Me! Water-Bbl Casino Pressure Tubina Pressure 933 0.8 1110 2160 576 989 1 1481 700 607 Copies of Logs and Surveys run - Daily Report of Well Operations, ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ! ServiceD 14. Attachments: Printed Name WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Title Production Technical Assistant Signature Phone 564-4657 Date 10/13/04 r.J r..:!!\...I..A LI ,\ ,,; '. ,'. ' ..', PNYn ~ ~ Form 10-404 Revised 4/2004 NK-O8A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/18/04 MIRU CTU # 5 FOR FCO I ACID STIM. FINISH WELDING ON ADDITIONAL PIPE FOR LONG STRING. PUMP 1.25" BALL THRU CT. MUIRIH W 12.5" JSN. SOFT TAG FILL @ 18380' (UP CTM). PUMP 10 BBL FLOPRO SWEEP. CONTINUED ON 09/19/04 WSR. 09/19/04 CONTINUED FROM 09/18/04 WSR. BEGIN JETTING FILL FROM 18380' WI FLOPRO, TAKING 10-20' BITES, CHASING UP ABOVE PERFS. JET DOWN TO 18423' DN/18409' UP. PUMP FINAL 20 BBL FLOPRO SWEEP FROM TD, CHASE TO ABOVE BTM GLM. JET 50 BBL 50/50 DIESEUXYLENE ACROSS PERFS FROM 18700- TO 18414'. CHASE OUT OF HOLE @ 80% WI XS. SHUT IN GL AND BLEED IA. CLEAR XS 1 % KCL FROM COIL TO TANKS. RIH WI 2.5" JSN AND FLUID PACK WELL WITH FILTERED 1% KCL DOWN BACKSIDE. INITIAL INJECTIVITY = 1820 PSI @ 1 BPM. RECIPROCATE 123 BBLS OF 7.5% HCL W/10% XYLENE AND OVERDISPLACE WI 60 BBLS OF FILTERED 1% KCL FROM 17970-18340'. FINAL INJECTIVITY = 1800 PSI @ 1 BPM. TURN WELL OVER TO ASRC FOR FLOW BACK. RDMO. BBLS 121 50/50 Methonal 427 1 % KCL 878 1% XS KCL 60 FloPro 50 50/50 Diesel/Xylene 123 7.5% HCL w/10% Xylene 55 Crude 1714 TOTAL FLUIDS PUMPED Page 1 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2781 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk 05/13/03 Color Well Job # Log Description Date Blueline Prints CD NK.14 [ C{ ~¢' O(~ SBHP SURVEY 04~20~03 NK-08A ~..O~ ,O'2-ct SBHP. SURVEY 04/19/03 NK-20 I['C~'~ i ~i' t SBHP SURVEY 04~20~03 NK-21 [c~,C~1~f-~ SBHP SURVEY 04/19/03 NK-07A ~ t, (~, '~ SBHP SURVEY 04/21/03 4-18/S-30 i~.~. i~ ~ PSP GLS 04/18/03 1-33B/L-24 .~q~. ~,~' LDL 04/19/03 3-45/M-29 i ~'~) -O.~ i INJECTION PROFILE 03/27/03 D.S. 15-47' Ic1¢5 ~t'l ~-.. LDL 03/21/03 D.S. 17-11 ! 1~' - oq,~.~-.~ GLS 04/27/03 ;D.S. 18-14A !~¢-~. OO-]. LDL 04/03/03 D.S. 13-29L1 '~,O'~-, C~=~c~ PRODUCTION PROFIL'E 04~06~03 ID:s. 18-03A t'~ - ~,O'3-- LDL 03127/03 D-05 t"~O , C~C~ ~ PRODUCTION PROFILE 04/13/03 D.S. 9-20 t"3'-] . O c~- ~ INJECTION PROFILE 04/15103 E-13A I ct '"l, ~ (2 "Z.,, SBHP SURVEY 04/24/03 D.S. 1-28 i~(~ ' OC'| .~ CHFR 03/31/03 D.S. 4-18 t ~,~: ~ ~,~ FLOWING BHP & TEMP 04113/03 J-23 I ~ ~ O *~) ~ LDL 04/25103 N-20A [c~ .- I~ ~-~ CHFR 04/10/03 D.S. 1-34 I ~(47 --I I~'~' CHFR 03/29/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T,O: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Permitto Drill 2010290 MD 18517 J TVD DATA SUBMITTAL COMPLIANCE REPORT 4118~2003 Well Name/No. PRUDHOE BAY UN NIA NK-08A Operator BP EXPLORATION (ALASKA) INC 9426 J' Completion Dat 4/9/2001 ,'~ Completion Statu l-OIL Current Status l-OIL APl No. 50-029-22491-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample N__9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No I ED _C~' De Density ED Ne Neutron , ED ~' Ind Induction/Resistivity Interval Start Stop 12252 18517 (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Open 2/5/2002 10558 Directional Survey Directional Survey 2 12252 2 12252 FINAL FINAL 18517 18517 Open 2/5/2002 10558 Open 2/5/2002 1055~ OH 6/21/2001 OH 6/21/2001 ,Qj[ecti~al Survey, Digital Data ~rectional Survey, Paper Copy Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Re ceived ?,~---"r~'-~ Analysis .._._Y-,/-N""~'- Rer~.iv~.d? Daily History Received? Formation Tops ~)/N Comments: Compliance Reviewed By: Date: Schlumbe er Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie NO. 1776 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD NK-08A 21294 M10, DIN & CDR 03/30/01 1 NK-08A 21294 MD CDR-RESISTIVITY 03/30/01 1 1 NK-08A 21294 TVD CDR-RESISTIVITY 03/30/01 1 1 NK-08A 21294 MD VISION DEN/NEUTRON 03/30/01 1 1 NK-08A 21294 TVD VISION DEN/NEUTRON 03/30/01 1 1 2/4/2002 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED FEB $ 2002 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A1ZN: Sherrie Received ~ ~ bp Date: 06-18-2001 Transmittal Number:92139 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type NK-08A 04-09-2001 ANADRILL - 0 18517.00 SURVEY REPORT; ASCII DATA; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Lisa Weepie (AOGCC) Attn: Sandy Lemke (Phillips Alaska) Attn: Susan Nisbet (Exxon Mobil ProduCtion Co.) RECEIVED JUN 2_ 1 2001 Alaska Oil & Ga 00n~ ~,~,,, .... .,~,,. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL r~ GAS D SUSPENDED D ABANDONED r-] SERVICE D ~_~.~~ 2. Name of Operator 7. Permit Number BP Exploration (Alaska), Inc. ~ 201-029 3. Address ~t~~ 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612~,.~ ~.~. ~,,, 50-029-22491-01 4. Location of well at surlace ~. ~,'..~.~~,' 9. Unit or Lease Name 4013' FNL, 1098' FEL, Sec. 36, T12N, R15E, UM (asp's 721466, 5979799) ' "' ~' ' ' i ',:, ... Niakuk At Top Producing Interval ; 4210' FNL, 566' FEL, SEC 22, T12N, R15E, UM (asp's 711134, 5989867): ....... '-,,~:..i:-:!-',~; ~ NK-08A At Total Depth ...... ~ ......... i 11. Field and Pool 3895' FNL, 845' FEL, SEC 22, T12N, R15E, UM (asp's 710847, 5990174) ', .............................. ' 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 52.83 feetI ADL 34626 Niakuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions March 23, 2001 March 30, 2001 April 9, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 18517' M D / 9426' TVD 18429' M D / 9368' TVD YES r~ No I--II 2037' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR/Res/Neu/Den 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO'ITOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 94# H-40 Surface 80' 30" 260 Sx Arcticset 13-3/8" 68# NT80CYH E 41' 5806' 16" 1890 Sx PFE & 375 Sx Class G 9-5/8" 47# NT80S 38' 12436' 12-1/4" 400 Sx Class G (downsqz'd OA 9-5/8" x 13-3/8" w/185 bbls AS I) 7"/4-1/2" 29#/12.6# L-80 12253' 18517' 8-!/2" 150 bbls 15.8 ppg Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1~2"guns, 6 SPF, & 60°phasing 4-1/2" 12.6" L-80 12342' 12236' 17970'- 18070' MD; 9082'-9143' TVD 12285' 18090' - 18130' MD; 9155' - 9180' TVD 18150' - 18230' MD; 9192' - 9242' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 18240' - 18300' MD; 9248' - 9286' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 18315' - 18340' MD; 9295' - 9311' TVD 3336' FP w/138 bbls Diesel (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 12, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 4/13/2001 3.4 Test Pedod >I 1117 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 601 psi 24-Hour Rate > 4691 5238 182 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved February 21,2001 (Permit #201-029) RECEIVED Form 10-407 Rev. 7-1-80 ORIGII / L CONTINUED ON REVERSE SIDE GEOLOGIC MARKER~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Kuparuk 17976' 9086' Base of Kuparuk 18335' 9308' 31. LIST OF ATTACHMENTS Summary of NK-08A Rig Sidetrack Drilling Operations + End of Well Survey. 2,2. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~1'~. [.. ~,4.~'.-----'--- Title BPDrillin.qEn,qineer Date H/~'{ [9! Z. O0~ Bill Isaacson INSTRUCTIONS Prepared by Paul Rauf 564-5799. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP EXPLORATION Page 1 of 1 Final Well I Event Summary Legal Well Name: NK-08 Common Well Name: NK-08A Event Name: REENTER+COMPLETE Start Date: 3/18/2001 End Date: 4/9/2001 DATE TMD 24 HOUR SUMMARY 3/19/2001 (ft) MIRU. Circ out freeze protect. 3/20/2001 (ft) Circ. well dead. N/D tree. N/U BOP and test. Begin L/D 4 1/2 tubing. 3/21/2001 (ft) Complete L/D tubing. Test lower rams. P/U mills, RIH on DP to 9900. 3/22/2001 (ft) Complete trip in hole. CBU. P.O.H. Set bridge plug. P.U. Whipstock. 312312001 (ft) Trip in with whipstock. Swap fluids. Cut window. Begin T.O.H. 3/24/2001 12,700.0 (ft) Complete TOH. P/U drilling assembly. RIH and drill 8 1/2 hole. 312512001 13,011.0 (ft) Drill F/12,700 T/13,011. Sweep hole. POH. Test BOP. P/U BHA. 3/26/2001 13,766.0 (ft) RIH with rotary steerable assembly. Get baseline ECD. Drill ahead. 3/27/2001 15,589.0 (ft) Drill fl13,766 t/15,589 with one short trip @14,053--No Problems. 3/28/2001 17,119.0 (ft) Drill 1530' of 8 1/2 hole, f/15,589 t/17,199. Begin short trip. 3/29/2001 17,886.0 (ft) Complete short trip to window. Drill f/17,119 t/17,886. 3/30/2001 18,517.0 (ft) Drilled 631' hole, t/18,517. Short trip to 16,256. Sweep hole. 3/31/2001 18,517.0 (ft) Spot liner run pill. POH LD excess DP. Run 4 1/2 liner. 4/1/2001 18,517.0 (ft) RIH with liner to window. Circulate/condition mud. Rig repairs. 4/2/2001 18,517.0 (ft) Complete rig repairs RIH and cement liner. Begin trip out of hole. 4/3/2001 18,517.0 (ft) Finish POH. Test BOPE. RIH with cleanout string. 4/4/2001 18,517.0 (ft) Displace well to clean 8.7 ppg Brine & spot Perf. Pill. POH 4/5/2001 18,517.0 (ft) Finish POH. MU & RIH w/TCP guns. RU W/L & Run Gamma tool 4/6/2001 18,517.0 (ft) Correlate guns on depth. Perforate. Well flowing. Build Kill wt. fluid 4/7/2001 18,517.0 (ft) Kill well w/10 ppg brine. Observe well dead. POH w/guns LDDP. 4/8/2001 18,517.0 (ft) PU & RIH w/4 1/2" completion. Displace to inhibited brine. ND BOP's 4/9/2001 18,517.0 (ft) Freeze Protect well. Test SSSV. RDMO NK-08a RECEIVED ,. :. Printed: 5/18/2001 9:10:02AM BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: NK-08 Common Well Name: NK-08A Spud Date: 7/14/1994 Event Name: REENTER+COMPLETE Start: 3/18/2001 End: 4/9/2001 Contractor Name: DOYON Rig Release: 4/9/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Date From-To Hours Task Sub I Code Phase Description of Operations 3/19/2001 11:00 - 17:30 6.50 RIGU DECOMP PJSM. Cantilever derrick into transport position. Move off of NK 12 B. Move in rig & spot same on NK 8 A. Shim rig, cantilever derrick into position and connect lines. Spot cuttings tank. ACCEPT rig at 1730 hrs March 19, 2001. ~ 17:30 - 21:30 4.00 RIGU DECOMP Take on Seawater. RU circ lines & test same. RU DSM lubricator & pull BPV. 21:30 - 23:30 2.00 RIGU DECOMP Circulate well w/280 bbls sea water. Returns 100% diesel. Shut well in. 23:30 - 00:00 0.50 RIGU DECOMP Build surface volume of sea water. Load pipe shed w/5" DP. RU floor for LD 4 1/2" tbg & PU 5" DP. 3/20/2001 00:00 - 01:00 1.00 RIGU DECOMP Build surface volume of sea water. Load pipe shed with 5" DP. 01:00 - 04:00 3.00 RIGU DECOMP Circulate out freeze protect diesel, 280 bbl. 04:00 - 05:00 1.00 RIGU DECOMP Install TWC valve in tubing hanger and test from below to 1000 psi. 05:00 - 06:00 1.00 WHSUR DECOMP Nipple down tree. 06:00 - 07:00 1.00 WHSUR DECOMP Rig down SSSV control lines from FMC head. 07:00 - 10:00 3.00 BOPSUF DECOMP Nipple up BOP, kill and choke lines. Flow line. 10:00 - 17:00 7.00 BOPSUF DECOMP PJSM. Test BOP,s as per policy--250 psi for 5 min./3500 psi for 10 minutes. John Crisp with AOGCC waived witness of initial BOP test. 17:00 - 18:00 1.00 BOPSUF DECOMP L/D test equipment and prep. floor for next operation. 18:00 - 19:00 1.00 PULL DECOMP Pull 2 way check valve from tubing hanger. Back out lock down screws. 19:00 - 20:00 1.00 PULL DECOMP Pull tubing free from jet cut with 230K up @ 12,996 WLM. Calculated up wt.=195K Actual up wt. = 165K. 20:00 - 21:30 1.50 PULL DECOMP Circulate bottoms up to monitor for gas. No gas at bottoms up. Check well for flow .... No flow. 21:30 - 00:00 2.50 PULL DECOMP Lay down tubing hanger, and 1,650 ft. of tubing. 3/21/2001 00:00 - 01:00 1.00 PULL DECOMP POH 4 1/2" completion and lay down tubing. 01:00 - 01:30 0.50 PULL DECOMP Rig down control line spooler, S.S.S.V. and lay down same. 01:30 - 09:00 7.50 PULL DECOMP POH 4 1/2" completion and lay down tubing. Recovered 312 jts and 21.6' cut off. Good indication of jet cut. 09:00 - 09:30 0.50 PULL DECOMP Clear floor and rig down tubing handling tools. 09:30 - 10:30 1.00 BOPSUF DECOMP PJSM. Pressure test lower pipe rams, 3500 psi high 250 psi Iow. 10:30 - 11:00 0.50 BOPSUF DECOMP Install wear bushing. 11:00 - 11:30 0.50 CLEAN DECOMP Service rig. 11:30 - 15:00 3.50 CLEAN DECOMP Pick up 8 1/2" mill and millimg BHA. 15:00 - 00:00 9.00 CLEAN DECOMP RIH lxl with drill pipe to 9,900. Stand back 14 stands for future use. 3/22/2001 00:00 - 04:00 4.00 CLEAN DECOMP RIH picking up drill pipe lxl. Tag 4 1/2 tubing stump at 12,996. 04:00 - 05:00 1.00 CLEAN DECOMP Circulate hole clean. Observe well. 05:00 - 13:00 8.00 CLEAN DECOMP P.O.H. to set bridge plug. 13:00 - 19:30 6.50 CLEAN DECOMP P.J.S.M. Rig up Schlumberger and R.I.H. setting C.I.B.P. at 12,462 W.L.M. Pull out of the hole and rig down. 19:30 - 20:30 1.00 STWHIP LNR1 Pressure test 9 5/8 casing to 3500 for 30 minutes. 20:30 - 00:00 3.50 STWHIP LNR1 Pick up, orient, and shallow test mills, Whipstock and MWD. 3/23/2001 00:00 - 01:00 1.00 STWHIP LNR1 Slip and cut drilling line. Service rig and top drive. 01:00 - 09:00 8.00 STWHIP LNR1 RIH with milling BHA and whipstock to 12,300'. 09:00 - 10:00 1.00 STWHIP LNR1 Orient tool face to 85 deg left of high side. Tag bridge plug at 12,459'. Set whipstock anchor. 10:00 - 11:30 1.50 STWHIP LNR1 PJSM with rig crew and Peak truck drivers. Displace brine with LSND 9.4 ppg mud. Take brine returns directly to vac trucks v~hile receiving mud and displacing. 11:30 - 18:30 7.00 STWHIP LNR1 Mill 9 5/8" casing window and new hole from 12,436' to 12,466'. High torque was noted once string was rotating in one spot for a period of '"~ I~E~ time' Milling fluid was delivered with 2% lubricant added. (1.5°/° T°rque [L~, ~, Trim 11 and .5% BDF-263) An additional 2% of lubetex was added in an attempt to assist in high torque. This proved to have little effect. Printed: 4/12/2001 10:28:24AM BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: NK-08 Common Well Name: NK-08A Spud Date: 7/14/1994 Event Name: REENTER+COMPLETE Start: 3/18/2001 End: 4/9/2001 Contractor Name: DOYON Rig Release: 4/9/2001 Group: RIG 'Rig Name: DOYON 14 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations , , 3/23/2001 18:30 - 20:00 1.50 STWHIP LNR1 Circulate weighted, barafibre sweep S.S. while working pipe. (Sweep weighted 3 ppb. over current mud system.) 20:00 - 21:00 1.00 STWHIP LNR1 Perform F.I.T. to 12.8 E.M.W. (1260 PSI) 21:00 - 00:00 3.00 STWHIP LNR1 P.O.H. to pick up drilling assembly. 3/24/2001 00:00 - 03:00 3.00 STWHIP LNR1 P.O.H. to pick up drilling assembly. 03:00 - 05:00 2.00 STWHIP LNR1 Lay down 8 1/2" milling BHA. Mills in gauge. 05:00 - 06:00 1.00 STWHIP LNR1 Flush BOP stack with jetting sub. Clear floor. 06:00 - 07:00 1.00 DRILL LNR1 Pick tools up beaver slide. OD and ID new BHA. Close rams and re-check pressures recorded on F.I.T. 07:00 - 09:00 2.00 DRILL LNR1 Make up new BHA with 8 1/2 MXC-1 mill tooth bit and 1.5 degree bent housing motor. Orient and shallow test same. 09:00 - 14:00 5.00' DRILL LNR1 RIH to 11,900' with drilling BHA #1. 14:00 - 15:00 1.00 DRILL LNR1 Slip and cut drilling line. 15:00 - 16:00 1.00 DRILL LNR1 RIH and orient to pass into window. 16:00 - 00:00 8.00 DRILL LNR1 Establish ledge and drill away from old hole from 12,466' to 12,700', building angle to app. 70 degrees. Drilling with following values: WOB- 5-20 550 GPM @ 2350 PSI 30 RPM ART=I.5 AST=4.5 3/25/2001 00:00 - 07:30 7.50 DRILL LNR1 Directionally drill from 12,700' to 13011'. Build angle to app. 70 degrees. Drilling with following values: WOB= 27 GPM=550 PSI-2400 RPM=45 TQ=11K ART=0.75 AST=5.5 07:30 - 09:30 2.00 DRILL LNR1 Pump weighted sweep S-S. Observe well. 09:30 - 15:30 6.00 DRILL LNR1 P.O.H. to pick up rotary steerable assembly with PDC bit. 15:30 - 17:00 1.50 DRILL . LNR1 Lay down BHA, grade bit, clear floor of all excess equipment. 17:00 - 17:30 0.50 BOPSUI~ LNR1 B.O.L.D.S. and remove wear ring from upper bowl. 17:30 - 22:00 4.50 BOPSUR LNR1 Test B.O.P. with A.O.G.C.C. rep.(Jeff Jones) present, to 250/3500. 22:00 - 22:30 0.50 BOPSUR LNR1 Install wear ring and clear floor of all test equipment. 22:30 - 00:00 1.50 DRILL LNR1 P/U rotary steerable,extention sub, control collar and shallow test same. 3/26/2001 00:00 - 02:00 2.00 DRILL LNR1 Pick up rotary steerable BHA with new 8 1/2" PDC bit. 02:00 - 06:30 4.50 DRILL LNR1 RIH pick up 150 jts 5" drill pipe. 06:30 - 09:00 2.50 DRILL LNR1 RIH break circulation at 7150' and 11466' 09:00 - 10:30 1.50 DRILL LNR1 Slip and cut 120' drilling line. 10:30 - 11:00 0.50 DRILL LNR1 RIH to 12233' 11:00 - 11:30 0.50 DRILL LNR1 Obtain PWD base line with and without rotation. 11:30 - 12:00 0.50 DRILL LNR1 Service top drive. 12:00 - 14:00 2.00 DRILL LNR1 RIH from 12,233 to 13,011 .( MAD pass from 12,300 to 12,500) 14:00 - 00:00 10.00 DRILL LNR1 Drilling with rotary steerable and PDC bit from 13,011 to 13,766. Monitor E.C.D. and maintain app. 1 ppg over mud wt. Pump weighted barafibre sweeps to control cuttings beds. Control ECD spikes while making connections with slow reaming/backreaming and reduced pump rate. WOB=12 to 15 GPM=550@2200 psi off bottom Rotary=120 ART=6.8 hrs. 3/27/2001 00:00 - 03:00 3.00 DRILL LNR1 Drilling from 13,766 to 14,053, pumping weighted barafibre sweeps to control cuttings beds. WOB=14-17 RPM=120 GPM=550@2750 TRQ. on BTM.=15-20 03:00 - 03:30 0.50 DRILL LNR1 Circ. sweep out of hole while adjusting rotary steerable. Observe well. 03:30 - 06:00 2.50 DRILL LNR1 Short trip to 12584 with no adverse hole conditions. 06:00 - 07:00 1.00 DRILL LNR1 Drilling from 14,053 to 14,149. 07:00 - 07:30 0.50 DRILL LNR1 Note increase in flow while drilling ahead and increase in pit volume. Printed: 4/12/2001 10:28:24AM BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: NK-08 Common Well Name: NK-08A Spud Date: 7/14/1994 Event Name: REENTER+COMPLETE Start: 3/18/2001 End: 4/9/2001 Contractor Name: DOYON Rig Release: 4/9/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 3/27/2001 07:00 - 07:30 0.50 DRILL LNR1 :Picked up off bottom and well was shut in when flow was noted. Observe 100 PSI on d.p and no casing pressure. Open choke with no pressure on annulus. Bleed d.p. pressure to zero. Observe static well. 07:30 - 09:00 1.50 DRILL LNR1 Circ. bottoms up to confirm no well control issues. No gas with bottoms up. 09:00 - 00:00 15.00 DRILL LNR1 Drilling from 14,053 to 15,589. Began seeing 5-7,000 ft. pds. torque increase on bottom. Add lubricants as needed. 3/28/2001 00:00 - 01:00 1.00 DRILL LNR1 Drilling from 15,589 to 15,686. Drlg with: WOB= 10-13 RPM-120 TQ=16-29 GPM=550@2900 01:00 - 01:30 0.50 DRILL LNR1 Service top drive. 01:30 - 21:30 20.00 DRILL LNR1 Drilling from 15,686 to 17,119. Reduce surface torque with a total of 4% lubricants added. A combination of 3% lubetex/dril-n-slide and 1% E.P. lube. 21:30 - 23:00 1.50 DRILL LNR1 Circ. sweep out of hole. Pump dry job. Observe well for flow. 23:00 - 00:00 1.00 DRILL LNR1 Begins short trip to window. (At 16,200 at midnight.) Pulled off bottom at 285K with pumps off; 275K pumps on. No adverse hole conditions. 3/29/2001 00:00 - 02:30 2.50 DRILL LNR1 Continue short trip to shoe. No adverse hole conditions. Window area clean, with no problems on exit or entry. 02:30 - 04:00 1.50 DRILL LNR1 Cut drilling line/service top drive. 04:00 - 06:30 2.50 DRILL LNR1 Short trip back to bottom, filling pipe at 14,680. No tight spots or fill. 06:30 - 08:00 1.50 DRILL LNR1 Roll mud to reduce ECD's. 08:00 - 00:00 16.00 DRILL LNR1 Drill ahead from 17,119 to 17,886. Adding lubricants to control torque. (Dril-N-slide and lubetex) and raising mudweight to 11.1 ppg. Allow EP Mudlube to dilute out once through Tuffs. No drag, No Losses. Parameters steady. 3/30/2001 00:00 - 14:00 14.00 DRILL LNR1 Drill from 17,886 to 18,517 with torque reaching max. make-up on d.p. (29,000) Adding lubetex, and E.P. mudlube to battle torque in Kingak. Asset called TD. 14:00 - 16:30 2.50 DRILL LNR1 Noted signs of un-drilled kingak shales at shakers. Bring mud wt. up from 11.3 to 11.5ppg.. Did not survey on bottom due to "hole talk" (risk/reward evaluation.) 16:30 - 19:30 3.00 DRILL LNR1 Short trip to 12,256 with no adverse hole conditions or fill. 19:30 - 00:00 4.50 DRILL LNR1 Stage up pumps slowly while monitoring ECD's. Pump 3 ppb. over weighted sweep S-S once ECD's would allow. (Rotate/reciprocate while sweep exited DP and was up inside casing. ) Begin spotting liner running pill in open hole, treated with 6% lubetex. Skakers clean. No sign of unstable shale. 3/31/2001 I00:00 - 01:30 1.50 DRILL LNR1 Spot liner running pill treated with 6% lubetex. Pump dry job. 01:30 - 09:00 7.50 DRILL LNR1 Drop rabbit. Observe well. Pull off bottom with 320K pumps off. Tripping i out getting P/U slack-off weights. Hole in good shape. 09:00 - 15:30 6.50 DRILL LNR1 !Lay out all excess D.P. lxl. 15:30 - 18:00 2.50 DRILL LNR1 'Lay down and lay out BHA. Clear floor of all vendors equipment. Ready floor for next operation. i18:00 - 19:30 1.50 CASE LNR1 P.J.S.M. Rig up to run 4 1/2 liner. 19:30 - 00:00 4.50 CASE LNR1 RIH with 4 1/2 liner, using collar clamp and nubbins on each joint. Fill pipe every 5 jts. App. 2000 ft. at crew change time. 4/1/2001 !00:00 - 11:00 11.00 CASE LNR1 RIH with 4 1/2 liner, using collar clamp and nubbins on each joint. Fill pipe every 5 jts. Pick up 2 jts. 7", 29# Hydril 511. R/U false floor over 7" stump and P/U 3 jts. 2 7/8 and plug carrier/plug. 11:00 - 12:00 1.00 CASE LNR1 P/U and make up "Baker" Flex lock hydraulic liner hanger/packer and 1 Printed: 4/12/2001 10:28:24AM BP EXPLORATION Pag,e 4 of 6 Operations Summa Report Legal Well Name: NK-08 Common Well Name: NK-08A Spud Date: 7/14/1994 Event Name: REENTER+COMPLETE Start: 3/18/2001 End: 4/9/2001 Contractor Name: DOYON Rig Release: 4/9/2001 Group: RIG ~Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/1/2001 11:00- 12:00 1.00 CASE LNR1 stand D.P. 12:00 - 13:30 1.50 CASE TDRV LNR1 Trouble shoot problems with rotation ability of topdrive. Will not rotate when assigned. 13:30 - 14:30 1.00 CASE LNR1 Circulate liner volume and record liner wt. in IADC book. (55K in 11.5 mud.) 14:30 - 19:30 5.00 CASE LNR1 RIH and break circulation at 12,334. Top drive system currently working, but recommendation from Varco was to change "Mother board," (Topdrive brains) as system could fail anytime. 19:30 - 21:30 2.00. CASE LNR1 Break circ. at shoe and circ. and condition mud @ 5bbls. per minute at 620 psi. Replace topdrive brains etc. while circutating. 21:30 - 00:00 2.50 CASE TDRV LNR1 Continue to repair/program "Mother board" circuit on topdrive. Roll mud and maintain 11.5 wt. 4/2/2001 00:00 - 01:00 1.00 CASE TDRV LNR1 Complete.repair work on top drive. 01:00 - 04:30 3.50 CASE LNR1 RIH from 12,334 to 15,882. Rotating torque at window=7,000 @ 20 RPM 04:30 - 06:00 1.50 CASE LNR1 Break circulation and stage pumps up to 4.5 b.p.m, while monitoring for fluid loss. Roll mud uphole and break gels, while reciprocating 20' strokes. (Turbulators can slide 20 on jt. before coming into contact with stop rings.) Rotate liner for benchmark torque values =10,000 ft. lbs 06:00 - 10:30 4.50 CASE LNR1 RIH from 15,882 to 17,510. Begin washing each jt. down as precautionary measure. (HRZ top a @ 17,695) Tag bottom @ 18,517. P/U cement head. Wash down @ 3 BPM/600 psi 10:30- 14:00 3.50 CASE LNR1 Circ./condition mud for cement job. Final circ. rate= 9 BPM @ 1960 PSI. No losses 14:00 - 17:00 3.00 CASE LNR1 Pump 5 bbls. CW 100 and test lines to 4,000. Pump 65 bbls. CW 100, 30 BBLs. Weighted spacer and 149.9 bbls. of class "G" cement @ 15.8 ppg. Drop wiper plug and displace with rig pumps @ 10 BPM. Bump plug @ calculated displacement and set hanger with 3000. Check floats. Set down 20K and pressure shear away from liner with 4,000 psi. P/U to verify release. Set 70K down and set packer with 15-20 RPM. Full returns. 17:00 - 18:00 1.00 CASE LNR1 Circulate bottoms up. Clear floor of all vendors excess equipment. 18:00 - 19:00 1.00 CASE LNR1 Slip and cut drilling line. 19:00 - 00:00 5.00 CASE LNR1 Lay out cement head. Observe well. P.O.H. with running tool. Test choke manifold on trip out of hole. 4/3/2001 00:00 - 01:30 1.50 CASE LNR1 Con't POH w/setting tool racking 5" DP in derrick. 01:30 - 03:00 1.50 CASE LNR1 Con't POH w/setting tool laying down excess 5" DP 03:00 - 03:30 0.50 CASE LNR1 Make service breaks & LD Baker setting tool. 03:30 - 04:00 0.50 CASE LNR1 Clear floor of excess tools. Service rig. 04:00 - 04:30 0.50 CASE LNR1 Pull wear bushing. 04:30 - 09:00 4.50 CASE LNR1 PJSM. Test BOP's as per BP & AOGCC policy--250 psi for 5 rain / 3,500 psi for 10 minutes. Chuck Scheve with AOGCC waived witness of BOP test. 09:00 - 09:30 0.50 CASE LNR1 Install wear bushing. 09:30 - 10:00 0.50 CASE LNR1 Service Top Drive. 10:00 - 10:30 0.50 CASE LNR1 Pressure test casing 500 psi/3,500 psi. 10 mins each. O-K 10:30 - 11:30 1.00 CASE LNR1 PJSM. RU 2 7/8" DP handling equipment. PU & MU BHA consisting of 3 3/4" bit, 2 7/8" MM, FS, & Circ sub. Surface test MM. O-K. 11:30 - 21:30 10.00 CASE LNR1 PU & RIH w/3 3/4" bit on 2 7/8" DP from pip~,~l%e~d.~l~l ~, gr~t,,Aa,~.e. Break circ every 2,000'. ~, ~- { ~' ~vF t~ it '-~1~ r~ N~' i 21:30 - 00:00 2.50 CASE LNR1 RD 2 7/8 DP handling equipment. MU PBL ~u~b ~4~s~J f/2' DI~: (3on t RIH w/3 3/4" bit on 5" DP. .4/4/2001 00:00 - 04:30 4.50 CASE LNR1 Con't RIH w/3 3/4" bit on 5" DP from derrick. ~¥hr~u~'.b IJ~tt,:~(Jp w/ Ii ~ I ~ i r ~,~ ri, ~'h ,' , BP EXPLORATION Page 5 of Operations Summary Report Legal Well Name: NK-08 Common Well Name: NK-08A Spud Date: 7/14/1994 Event Name: REENTER+COMPLETE Start: 3/18/2001 End: 4/9/2001 Contractor Name: DOYON Rig Release: 4/9/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Date From,To Hours Task Code Phase' Description of Operations 4/4/2001 00:00 - 04:30 4.50 CASE LNR1 no problems. Tag landing collar @ 18,433 ft. Drillers depth. 04:30 - 05:00 0.50 CASE LNR1 Break circulation. PJSM for displacing well. 05:00 - 06:30 1.50 CASE LNR1 i Pump series of sweeps consisting of caustic, hi-vis, baraclean, hi-vis. i Total of 110 bbls. 06:30 - 14:00 7.50 CASE LNR1 Displace well w/sea water followed by 8.7 ppg clean brine @ 110 NTU's 14:00 - 16:00 2.00 CASE LNR1 Spot perforating pill in 4 1/2" liner. 16:00 - 20:00 4.00 CASE LNR1 i POH w/3 3/4" bit to above 4 1/2" liner @ 12,236 ft. 20:00 - 21:00 1.00 CASE LNR1 PJSM. Pressure test casing to 500 psi - 5 mins / 3,500 psi - 30 mins. 21:00 - 00:00 3.00 CASE LNR1 Con't POH w/3 3/4" bit. 4/5/2001 00:00 - 01:00 1.00 CASE LNR1 Con't POH w/3 3~4" bit on 5" DP. LD 4 jts 3 1/2" DP & PBL sub. 01:00 - 05:00 4.00 CASE LNR1 PJSM. RU 2 7/8" handling equipment. Pump dry job. Con't POH w/3 3/4" bit on 2 7/8" DP. 05:00 - 06:00 1.00 CASE LNR1 LD 5 jts 2 7~8" DP & BHA. 06:00 - 07:00 1.00 CASE LNR1 Clear floor. RU to run perforating guns. 07:00 - 08:00 1.00 CASE LNR1 PJSM. PU & RIH w/2 1/2" perforating guns. 08:00 - 13:30 5.50 CASE LNR1 RIH w/perforating guns on 2 7/8" DP. 13:30 - 15:00 1.50 CASE LNR1 MU Halliburton RTTS packer assy & jars. 15:00 - 20:30 5.50 CASE LNR1 Con't RIH w/perforating guns on 5" DP to 18,398 ft. POH to 18,368 ft. 20:30 - 00:00 3.50 CASE LNR1 PJSM. RU Halliburton slick unit & pressure control equipment. MU Schlumberger Memory Gamma Tool. RIH w/same to 12,366 ft. Con't RIH w/pumps @ 0.8 BPM & 250 psi to 12,860 ft. Increase pump rate to 1.7 BPM @ 420 psi & con't RIH to 13,005 ft. Log well down & up from 12,000 ft - 13,000 ft. 4/6/2001 00:00 - 02:30 2.50 CASE LNR1 POH w! memory Gamma tool on slick line. Mis run on up Icg. 02:30 - 05:30 3.00 CASE LOG LNR1 Re-run Gamma Tool. Pump down from 11,500 ft to 12,875 ft @ 1.5 BPM w/320 psi. Log down / up 12000 ft to 12,875 ft. 05:30 - 06:30 1.00 CASE LNR1 Down Icad Gamma - good Icg. RD Halliburton slick line. 06:30 - 07:00 0.50 CASE LNR1 Rig up pump lines to pump diesel for under balance perforating. 07:00 - 09:00 2.00 CASE LNR1 PJSM. Test surface lines to 3,500 psi. Displace DP to 14,100 ft w/225 bbls diesel @ 3 BPM w/max 2,500 psi. 09:00 - 09:30 0.50 CASE LNR1 PU & put guns on depth w/top shot @ 17,970 ft MD / 9,080 ft TVD. Set I packer. Close annular. 09:30 - 10:00 0.50 CASE LNR1 i PJSM Test surface lines to 3,800 psi. Fire guns (2 1/2" - 6 SPF - 60 degree phasing) w/3,500 psi. Observe strong initial blow. Bleed off :pressure to 400 psi. 10:00 - 11:30 1.50 CASE LNR1 ~PU string observe by pass valve open. Reverse circulate DP with 8.7 ppg brine @ surface. 11:30 - 12:30 1.00 CASE WCON LNR1 Observe well flowing. Monitor 45 minute build up @ SlOP 450 psi, SlDP 450 psi. 12:30 - 14:00 1.50 CASE WCON LNR1 Reverse circulate DP w/8.7 ppg brine. Shut well in. 14:00 - 00:00 10.00 CASE WCON LNR1 Monitor shut in pressures. Build surface volume of 10 ppg brine. SlDP 480 psi, SlOP 480 psi after initial build up. Circ 3 bbls every hour to keep fluid movement through surface lines. Move DP periodically to ensure free movement. 4/7/2001 00:00 - 04:00 4.00 CASE WCON LNR1 Displace well to 10 ppg kill weight brine @ 4 BPM thru choke following well control pumping rates & procedures. No losses, no gains. 04:00 - 04:30 0.50 CASE WCON LNR1 Flow check showing well static. PJSM for next operation. 5' i~ ~ 'b I 04:30 - 08:30 4.00 CASE LNR1 POH w/perforating guns to 16,055 ft racking ~1~ ~t ~ I~. ~'1~_* ~ checks showing well static. 08:30 - 09:30 1.00 CASE LNR1 PJSM. Slip & cut drilling line. 09:30 - 15:30 6.00 CASE LNR1 Con't POH w/guns laying down 5" DP. 15:30-16:30 1.00 CASE LNR1 LDHalliburtonpackerassy&jars. ~?~A¥ ~! o 2001 &las~m Oi~ & G~ Corns. Commi~.~i~' Printed: ,~{?.~IF ~ ¢:~ 8: 2 4 AM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: NK-08 Common Well Name: NK-08A Spud Date: 7/14/1994 Event Name: REENTER+COMPLETE Start: 3/18/2001 End: 4/9/2001 Contractor Name: DOYON Rig Release: 4/9/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 4/7/2001 16:30 - 17:00 0.50 CASE LNR1 PJSM. RU 2 7/8" DP handling equipment. 17:00 - 22:30 5.50 CASE LNR1 Con't POH w/guns laying down 2 7/8" DP. 22:30 - 23:30 1.00 CASE LNR1 PJSM. LD perforating guns. Total of 18 each. 100% shots fired. 23:30 - 00:00 0.50 CASE LNR1 Clear floor of equipment. 4/8/2001 00:00 - 00:30 0.50 CASE LNR1 Rig down floor from all 2 7/8" & 5" DP handling equipment. 00:30 - 01:00 0.50 CASE LNR1 Pull wear bushing. 01:00 - 01:30 0.50 RUNCOI~ COMP RU to run 4 1/2" completion string. 01:30 - 10:00 8.50 RUNCOI~ COMP PJSM. MU & RIH w/4 1/2" completion from pipe shed. 10:00 - 11:00 1.00 RUNCOI~ COMP MU Halliburton FMX TRSSSV. Test control line to 5,000 psi. O-K. 11:00 - 14:30 3.50 RUNCOI~ COMP Con't RIH w/4 1/2" completion string. Total 52 SS bands used. 14:30 - 15:00 0.50 RUNCOI~ COMP Tag 4 1/2" x 7" XO @ 12,344 ft. PU space out completion. Install 1 x pup jt one jt below tubing hanger. 15:00 - 16:00 1.00 RUNCOI~ COMP MU tubing hanger - Test control line 5,000 psi. O-K. 16:00 - 16:30 0.50 RUNCOI~ COMP Land tubing hanger. Re - entry guide @ 12,341 ft. RILDS. RU surface lines for displacement of inhibited brine. 16:30 ~ 20:00 3.50 RUNCOI~ COMP PJSM. Reverse circulate annulus to 10 ppg inhibited brine @ 3 BPM. 20:00 - 21:30 1.50 RUNCOI~ COMP Set packer @ 12,285 ft w/3,500 psi leave pressure for 30 min. O-K. Bleed down pressure to 1,500 psi. Test annulus to 3,500 psi 30 rains O-K. Shear RP valve @ 8,403 ft. 21:30 - 22:30 1.00 RUNCOI~ COMP LD landing joint. Install TVVC, test from below 1,500 psi OK. Clear floor. 22:30 - 00:00 1.50 RUNCOI~ COMP PJSM. ND BOPE. 4/9/2001 00:00 - 02:00 2.00 WHSUR COMP N/U Tree and adator flange. Test tree to 5000 psi- good. 02:00 - 03:00 1.00 WHSUR COMP R/U DSM and pull TWC with Lubricator. 03:00 - 06:00 3.00 WHSUR COMP Displace to well 250 bbls of diesel to freeze protect down to 3,670 ft ( 100 ft below top GLM) with HOT OIL. 06:00 - 07:00 1.00 WHSUR COMP Allow well to U-tube while Rigging down and preparing to move. 07:00 - 09:00 2.00 RIGD COMP Remove secondary valve. Secure tree. Close SSSV ( 510 psi underbalance on well- open perforations). Suck down all fluids. RDMO. Rig Released to NK-07A @ 0900 hrs on 9th April 2001. RECEIVED 8 200t ~,I~sl<~ Oil & g~ {;¢r~s. Oommissio~,': Printed: 4/12/2001 10:28:24AM TREE= 4-1/16" CNV 5M WELLHEAD= FMC ACTUATOR= BAKER ~'Bi '~'~'¥'"= ~2~6'; i~'i~7~'~" ~- 41 .o' KOP = 900' ~tum ~ = 17494' ............................................................................................................. ~tum ~ 8800' 13-3/8" CSG, 72#, N-80, NSCC, ID = 12.415" I'"'{ 5806' IMinimum ID -3.725"@ 12329' 4-1/2" HES 'XN' NIPPLE 4-1/2" TBG, 12.6#, L-80 IBT-M, ID = 3.958" Id 12342' TOP OF 4-1/2" LNR Id 12344' NK-08A 2037' 12236' 12253' I-I 12264' 12285' 12308' 1232g' ~ 12342' SAFETY NOTES: OLD 5-1/2" LNR AND I:~RFS P& A'd AND NOT SHOWN ON THIS DIAGRAM. H 4-1/2 " HES 'FMX' TRSSSV NIPPLE, ID = 3.813" I GAS LIFT MANDRELS H 9-5/8 " X 7" BAKER 'ZXP' PKR, ID = 7.500" 9-5/8" X 7" BAKER HYD LNR HANGER, ID = 6.276" Id 4-1/2" HES'X' NIP, ID= 3.813"I Id 7"X 4-1/2" BAKER'S-3' PKR, ID = 3.875" Id Id 4-1/2" HES 'X' NIP, ID = 3.813"I 4-1/2" HES 'XN' NIP, ID = 3.725" 4-1/2" WLEG, ID = 3.958" ELMD TT - NOT LOGGED 7" XO, HYD 511 X 4-1/2" HYD 521, ID = 3.938" PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CCL - 04/06/01 ANGLE AT TOP PERF: 52° Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 17970-18070 O 04/06/01 2-1/2" 6 18090-18130 O 04/06/01 2-1/2" 6 18150-18230 O 04/06/01 2-1/2" 6 18240-18300 O 04/06/01 2-1/2" 6 · 18315-18340 O 04/06/01 9-5/8" MILLOUT WINDOW TOP @ 12436' ? Id WHIPSTOCK SET ON TOP OF CIBP I 12462' I'"{ 9-5/8" CIBP- SET ON 3/22/01 9-5/8" CSG, 47#, NT80S NSCC, ID = 8.681" Id 13220' 18429' ] 15898' I 4-1/2" LNR, 12.6#, L-80, HYDRIL 521, 18517' DATE REV BY COMMENTS DATE REV BY COMMENTS NIAKUK UNIT 08/31/94 ORIGINAL COMPLETION WELL: NK-08A 01/22/01 SlS-lsl CONVERTED TO CANVASPi~_iFT~.. 2~i~);~/F, ~ , ~,,~ 04109101 RiG SIDETRACK Sec. 36, T12N, R15E, 1266' NSL, 1099' WEL , 04/21/01 CH/TP CORRECTIONS BP I~,~ia,at~A~l~a~ Gas C~:,~"'~s. Commissior A~chorage ANADRILL SCHLUMBERGER Survey report 9-Apr-2001 20:48:23 Page 1 of 8 Client ................... : BP Exploration (Alaska) Inc. Field .................... : Niakuk Well ..................... : NK-08A API number ............... : 50-029-22491-01 Engineer ................. : C. Mercier COUNTY: .................. : Doyon 14 STATE: ................... : Alaska Spud date ................ : 22-Mar-01 Last survey date ......... : 30-Mar-01 Total accepted surveys...: 192 MD of first survey ....... : 0.00 ft MD of last survey ........ : 18517.00 ft Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Tally GL above permanent ....... : 19.07 ft KB above permanent ....... : N/A DF above permanent ....... : 52.83 ft Vertical section origin Latitude (+N/S-) ......... : 0.00 f~ 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: 313.46 degrees Geomagnetic data --- Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 22-Mar-2001 Magnetic field strength..: 1150.13 HCNT Magnetic dec (+E/W-) ..... : 27.02 degrees Magnetic dip ............. : 80.87 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1150.13 HCNT Reference Dip ............ : 80.87 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections - Magnetic dec (+E/W-) ..... : 27.03 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.03 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_03] RECEIVED ~,~,,:~. ~,orilmloslori., Anchorage ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 20:48:23 Page 2 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 33.83 0.00 0.00 3 92.83 0.23 0.52 4 192.83 0.25 6.05 5 292.83 0.26 9.40 6 392.83 0.53 8.14 7 492.83 0.92 3.96 8 592.83 1.63 356.97 9 692.83 4.40 349.31 10 792.83 7.83 343.84 11 892.83 9.72 338.25 12 992.83 11.57 331.54 13 1092.83 13.50 328.23 14 1192.83 15.19 323.45 15 1292.83 16.04 323.14 16 1392.83 16.97 322.72 17 1492.83 18.48 320.17 18 1592.83 20.17 319.07 19 1692.83 21.00 318.75 20 1792.83 22.30 316.39 21 1892.83 24.42 316.29 22 1992.83 29.42 319.09 23 2092.83 33.16 315.38 24 2192.83 36.84 312.64 25 2292.83 37.14 312.47 26 2392.83 37.69 314.99 27 2492.83 39.54 316.50 28 2592.83 43.44 317.00 29 2692.83 45.25 316.87 30 2792.83 45.86 316.67 0.00 33.83 59.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 TVD depth (ft) 0.00 33.83 92.83 192.83 292.83 392.83 492.82 592.79 692.64 792.06 890.89 989.17 1086.78 1183.66 1279.97 1375.85 1471.10 1565.46 1659.08 1752.02 1843.82 1932.96 2018.41 2100.31 2180.19 2259.62 2337.75 2412.64 2484.16 2554.18 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type -- 0.00 0.00 0.08 0.35 0.61 1.00 1.78 3.32 7.47 16.45 30.00 47.19 68.02 92.21 118.73 146.75 176.90 209.80 244.80 281.59 321.19 366.31 418.11 475.44 535.60 596.35 658.70 724.82 794.59 865.86 .00 .00 .12 .54 .98 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.12 0.52 0.03 0.54 2.77 0.09 0.98 5.03 1 2 5 10 20 .66 .92 .14 .33 .64 0.19 1.67 6.48 0.31 2.93 6.05 0.29 5.15 3.23 -0.50 10.34 357.24 -3.11 20.88 351.45 35 51 70 90 112 .O3 .69 .43 .88 .46 -8 -16 -26 -40 -57 .13 35.96 346.93 .04 54.12 342.76 .96 75.41 339.05 .91 99.66 335.76 .00 126.08 333.12 135 158 184 210 237 266 300 338 377 418 .13 .91 .11 .61 .82 .50 .02 .07 .86 .55 -74.13 154.12 331.25 -93.12 184.18 329.63 -114.57 216.85 328.11 -137.68 251.61 326.83 -162.58 288.08 325.64 -189.95 327.27 324.52 -220.34 372.24 323.71 -255.65 423.85 322.90 -296.93 480.57 321.84 -341.25 540.04 320.81 460 505 553 604 656 .55 -385.14 600.37 320.10 .25 -428.68 662.61 319.69 .51 -474.06 728.76 319.42 .57 -521.78 798.60 319.20 .59 -570.68 869.93 319.00 0.00 0.00 0.39 0.03 0.02 0.27 0.39 0.73 2.79 3.48 2.07 2.22 2.06 2.06 0.85 0.94 1.70 1.73 0.84 1.56 2.12 5.16 4.21 4.00 0.32 1.63 2.08 3.91 1.81 0.63 TIP MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M [(c)2001 Anadrill IDEAL ID6_lC_03] ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 20:48:23 Page 3 of 8 Seq Measured Incl Azimuth Course 9 depth angle angle length - (ft) (deg) (deg) (ft) 31 2892.83 49.44 315.67 32 2992.83 51.06 315.79 33 3092.83 50.97 317.18 34 3192.83 52.94 318.06 35 3292.83 54.23 317.55 36 3392.83 53.22 319.02 37 3492.83 54.12 319.66 38 3592.83 55.54 320.12 39 3692.83 59.42 317.08 40 3792.83 60.04 316.46 41 3892.83 59.58 317.00 42 3992.83 60.14 316.72 43 4092.83 60.36 317.94 44 4192.83 60.49 319.40 45 4292.83 61.81 320.15 46 4392.83 63.40 319.61 47 4492.83 63.83 320.16 48 4592.83 62.56 318.82 49 4692.83 61.68 320.94 50 4792.83 59.43 317.72 51 4892.83 58.84 316.11 52 4992.83 58.80 315.75 53 5092.83 59.15 316.30 54 5192.83 59.49 315.90 55 5292.83 59.60 316.22 56 5392.83 59.98 316.18 57 5492.83 59.88 315.95 58 5592.83 60.03 315.66 59 5692.83 60.53 315.73 60 5792.83 60.94 316.21 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 100.00 2621.53 939.67 709.88 -621.87 943.74 100.00 2685.48 1016.49 764.93 -675.53 1020.52 100.00 2748.39 1094.11 821.30 -729.05 1098.20 100.00 2810.01 1172.65 879.47 -782.12 1176.94 100.00 2869.38 1252.89 939.09 -836.18 1257.41 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 2928.54 2987.79 3045.39 3099.15 3149.55 3199.84 3250.05 3299.67 3349.03 3397.28 3443.29 3487.73 3532.83 3579.60 3628.76 3680.07 3731.84 3783.38 3834.41 3885.09 3935.41 3985.51 4035.58 4085.16 4134.04 1333.22 999.26 -889.82 1413.36 1060.37 -942.31 1494.58 1122.89 -994.97 1578.54 1186.09 -1050.75 1664.76 1249.01 -1109.90 1751.05 1837.38 1924.00 2010.61 2097.66 2185.89 2274.91 2363.66 2451.50 2538.10 2623.77. 2709.25 2794.86 2880.77 2966.88 3053.20 3139.65 3226.14 3312.92 3400.08 1311.95 -1169.15 1375.05 -1228.28 1438.89 -1287.13 1504.19 -1344.56 1571.07 -1401.12 1638.96 -1458.33 1707.46 -1516.05 1775.32 -1574.02 1842.91 -1630.98 1908.96 -1687.70 1971.65 -1746.33 2033.12 -1805.83 2094.79 -1865.33 2156.76 -1924.97 2218.83 -1984.78 2281.20 -2044.60 2343.52 -2104.64 2405.59 -2164.99 2467.74 -2225.65 2530.46 -2286.28 Srvy tool type 318.78 3.66 MWD_M 318.55 1.62 MWD_M 318.41 1.08 MWD_M 318.35 2.09 MWD_M 318.32 1.35 MWD_M 1338.02 318.32 1.56 1418.57 318.37 1.04 1500.29 318.46 1.47 1584.57 318.46 4.65 1670.90 318.37 0.82 1757.31 318.29 0.66 1843.76 318.23 0.61 1930.57 318.19 1.08 2017.53 318.21 1.28 2105.09 318.27 1.47 2193.83 318.34 1.66 2283.38 318.40 0.65 2372.62 318.44 1.74 2460.98 318.49 2.07 2548.03 318.52 3.59 2633.83 318.47 1.50 2719.30 318.39 0.31 2804.92 318.32 0.59 2890.86 318.25 0.48 2977.01 318.19 0.30 3063.37 318.13 0.38 3149.86 318.07 0.22 3236.36 318.01 0.29 3323.13 317.95 0.50 3410.32 317.90 0.59 Tool qual type [(c)2001 Anadrill IDEAL ID6_lC_03] ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 20:48:23 Page 4 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD depth (ft) Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 61 5892.83 60.83 316.34 100.00 4182.70 3487.33 62 5992.83 61.05 316.31 100.00 4231.27 3574.64 63 6092.83 60.50 317.63 100.00 4280.10 3661.74 64 6192.83 60.10 317.00 100.00 4329.64 3748.41 65 6292.83 60.10 317.09 100.00 4379.49 3834.93 66 6392.83 59.93 316.88 100.00 4429.47 67 6492.83 59.73 316.77 100.00 4479.73 68 6592.83 59.65 317.72 100.00 4530.20 69 6692.83 59.44 317.18 100.00 4580.88 70 6792.83 60.33 317.22 100.00 4631.06 71 6892.83 60.45 316.99 100.00 4680.46 72 6992.83 60.47 317.43 100.00 4729.77 73 7092.83 60.58 316.78 100.00 4778.97 74 7192.83 60.54 316.53 100.00 4828.12 75 7292.83 59.39 316.93 100.00 4878.18 76 7392.83 60.52 316.90 100.00 4928.24 77 7492.83 59.59 317.56 100.00 4978.16 78 7592.83 59.75 317.66 100.00 5028.66 79 7692.83 59.45 318.00 100.00 ~ 5079.26 80 7792.83 58.89 318.04 100.00 5130.51 81 7892.83 59.55 317.73 100.00 5181.68 82 7992.83 59.54 317.78 100.00 5232.37 83 8092.83 60.03 316.71 100.00 5282.70 84 8192.83 60.88 316.25 100.00 5332.01 85 8292.83 61.35 315.86 100.00 5380.31 86 8392.83 61.24 315.92 100.00 5428.34 87 8492.83 60.41 316.23 100.00 5477.09 88 8592.83 60.59 315.83 100.00 5526.33 89 8692.83 61.03 316.60 100.00 5575.10 90 8792.83 61.03 316.45 100.00 5623.54 3921.38 4007.68 4093.82 4179.82 4266.13 4352.90 4439.71 4526.59 4613.54 4699.97 4786.38 4872.84 4958.93 5044.93 5130.52 5216.18 5302.14 5388.37 5475.24 5562.71 5650.34 5737.56 5824.51 5911.71 5999.07 2593.59 -2346.66 2656.81 -2407.03 2720.60 -2466.58 2784.46 -2525.47 2847.90 -2584.54 2911.24 -2643.63 2974.28 -2702.78 3037.67 -2761.39 3101.18 -2819.68 3164.64 -2878.45 3228.34 -2937.63 3292.18 -2996.73 3355.96 -3055.99 3419.29 -3115.76 3482.33 -3175.10 3545.55 -3234.23 3609.15 -3293.07 3672.90 -3351.26 3736.83 -3409.17 3800.66 -3466.60 3864.39 -3524.22 3928.20 -3582.17 3991.65 -3640.83 4054.73 -3700.74 4117.78 -3761.51 4180.75 -3822.56 4243.64 -3883.13 4306.28 -3943.55 4369.30 -4003.96 4432.79 -4064.15 3497.65 3585.03 3672.29 3759.15 3845.83 317.86 0.16 317.82 0.22 317.80 1.28 317.79 0.68 317.78 0.08 3932.44 4018.88 4105.21 4191.41 4277.91 317.76 0.25 317.74 0.22 317.73 0.82 317.72 0.51 317.71 0.89 4364.84 4451.84 4538.89 4625.96 4712.52 317.70 0.23 317.69 0.38 317.68 0.58 317.66 0.22 317.64 1.20 4799.08 4885.72 4972.04 5058.29 5144.16 317.63 1.13 317.62 1.09 317.62 0.18 317.63 0.42 317.63 0.56 5230.07 5316.27 5402.68 5489.66 5577.19 317.64 0.71 317.64 0.04 317.63 1.05 317.61 0.94 317.59 0.58 5664.86 5752.14 5839.15 5926.42 6013.90 317.56 0.12 317.54 0.87 317.52 0.39 317.50 0.80 317.48 0.13 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M [(c)2001 Anadrill IDEAL ID6_iC_03] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) TVD depth (ft) 9-Apr-2001 20:48:23 Vertical section (ft) 91 8892.83 61.88 316.18 100.00 5671.32 6086.81 92 8992.83 62.34 316.24 100.00 5718.10 6175.09 93 9092.83 62.21 316.48 100.00 5764.62 6263.49 94 9192.83 62.57 316.35 100.00 5810.97 6351.99 95 9292.83 62.69 317.21 100.00 5856.94 6440.64 96 9392.83 62.62 317.25 100.00 5902.88 6529.28 97 9492.83 62.71 317.28 100.00 5948.80 6617.92 98 9592.83 63.15 317.10 100.00 5994.30 6706.77 99 9692.83 63.50 317.88 100.00 6039.20 6795.91 100 9792.83 63.27 318.34 100.00 6084.00 6885.02 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 101 9892.83 63.22 317.65 102 9992.83 63.49 317.83 103 10092.83 63.74 318.16 104 10192.83 63.43 317.89 105 10292.83 64.00 318.44 6129.02 6173.86 6218.30 6262.79 6307.07 6351.63 6397.25 6443.23 6488.96 6535.45 6582.52 6629.43 6676.76 6725.17 6774.47 6824.03 6873.89 6923.96 6974.08 7024.25 106 10392.83 63.08 319.21 107 10492.83 62.63 319.00 108 10592.83 62.63 318.14 109 10692.83 62.94 318.98 110 10792.83 61.66 317.57 111 10892.83 62.18 318.49 112 10992.83 61.86 318.32 113 11092.83 61.65 319.33 114 11192.83 60.44 318.33 115 11292.83 60.48 317.82 116 11392.83 60.11 317.47 117 11492.83 60.07 317.28 118 11592.83 59.84 316.56 119 11692.83 60.00 316.25 120 11792.83 59.77 316.75 Displ Displ Total +N/S- +E/W- displ (ft) (ft) (ft) 4496.31 -4124.83 6101.72 4560.12 -4185.99 6190.09 4624.18 -4247.08 6278.59 4688.36 -4308.17 6367.19 4753.08 -4368.99 6455.99 4818.28 -4429.30 6544.81 4883.53 -4489.59 6633.65 4948.86 -4550.10 6722.69 5014.73 -4610.48 6812.05 5081.28 -4670.17 6901.44 6974.03 7063.16 7152.46 7241.74 7331.09 5147.63 -4729.93 6990.73 5213.78 -4790.03 7080.11 5280.35 -4849.98 7169.69 5346.93 -4909.88 7259.24 5413.74 -4969.68 7348.90 7420.23 7508.78 7597.23 7685.81 7774.03 7861.97 7949.96 8037.66 8124.77 8211.49 5481.12 -5028.62 7438.39 5548.38 -5086.88 7527.34 5614.97 -5145.64 7616.13 5681.63 -5204.49 7705.04 5747.71 -5263.41 7793.57 5813.31 -5322.41 5879.36 -5381.04 5945.66 -5439.04 6011.53 -5496.63 6076.26 -5554.76 8298.12 8384.60 8471.00 8557.42 8643.80 6140.45 -5613.28 6204.23 -5671.98 6267.45 -5731.10 6330.12 -5790.77 6392.87 -5850.32 Page At Azim (deg) 7881.79 7970.10 8058.17 8145.64 8232.64 8319.50 8406.18 8492.73 8579.25 8665.74 317.47 317.45 317.43 317.42 317.41 317.41 317.41 317.40 317.41 317.41 317.42 317.43 317.43 317.44 317.45 317.47 317.48 317.50 317.51 317.52 317.52 317.53 317.55 317.56 317.57 317.57 317.57 317.56 317.55 317.54 5 of 8 DLS (deg/ i00f) 0.88 0.46 0.25 0.38 0.77 0.08 0.09 0.47 0.78 0.47 0.62 0.31 0.39 0.39 0.75 1.15 0.49 0.76 0.81 1.79 0.96 0.35 0.91 1.49 0.45 0.48 0.17 0.66 0.31 0.49 Srvy tool type Tool qual type [(c)2001 Anadrill IDEAL ID6_lC_03] ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 20:48:23 Page 6 of 8 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 11892.83 59.71 317.01 122 11992.83 59.00 317.73 123 12092.83 58.86 316.79 124 12192.83 59.18 317.53 125 12292.83 59.31 316.36 126 12392.83 59.59 316.34 127 12436.00 59.66 316.74 128 12452.00 59.91 314.54 129 12478.22 60.58 313.28 130 12569.99 65.71 309.08 131 12666.44 70.24 314.76 132 12763.94 74.52 315.92 133 12857.87 74.09 315.49 134 12956.05 73.61 314.86 135 13019.75 73.28 316.97 136 13115.66 72.22 316.19 137 13211.60 72.63 315.38 138 13306.81 73.41 314.46 139 13404.29 73.96 313.53 140 13498.47 74.42 312.02 141 13595.86 74.57 312.48 142 13692.15 73.79 313.26 143 13788.12 73.49 315.27 144 13882.31 73.96 315.21 145 13980.47 74.29 316.65 146 14075.09 74.61 316.41 147 14172.95 75.21 315.44 148 14268.43 75.70 314.29 149 14364.53 76.04 313.34 150 14460.16 76.58 312.42 100.00 100.00 100.00 100.00 100.00 100.00 43.17 16.00 26.22 91.77 96.45 97.50 93.93 98.18 63.70 95.91 95.94 95.21 97.48 94.18 97.39 96.29 95.97 94.19 98.16 94.62 97.86 95.48 96.10 95.63 TVD depth (ft) 7074.65 7125.62 7177.23 7228.70 7279.84 7330.67 7352.50 7360.55 7373.56 7415.02 7451.21 7480.72 7506.13 7533.43 7551.59 7580.03 7609.00 7636.80 7664.19 7689.85 7715.88 7742.13 7769.17 7795.56 7822.42 7847.78 7873.26 7897.24 7920.70 7943.33 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 8730.02 8815.85 8901.32 8986.87 9072.65 9158.66 9195.85 9209.66 9232.42 9314.18 9403.49 9496.34 9586.70 9680.96 9741.96 9833.42 9924.80 10015.83 10109.38 10199.99 10293.81 10386.45 10478.52 10568.89 10663.21 10754.24 10848.64 10941.03 11034.22 11127.12 6455.91 -5909.36 6519.21 -5967.62 6582.12 -6025.75 6644.98 -6084.05 6707.77 -6142.72 8752.10 8838.14 8923.79 9009.52 9095.45 317.53 0.23 317.53 0.94 317.53 0.82 317.52 0.71 317.52 1.01 6770.09 -6202.16 6797.12 -6227.78 6807.01 -6237.44 6822.79 -6253.84 6876.61 -6315.47 9181.55 9218.79 9232.61 9255.32 9336.65 MWD_M MWD_M MWD_M MWD_M 6936.35 -6381.90 7002.44 -6447.19 7067.17 -6510.34 7134.05 -6576.82 7177.91 -6619.30 9425.58 9518.43 9608.82 9703.05 9764.09 317.51 0.28 MWD_M 317.50 0.82 MWD 317.50 11.98 MWD 317.49 4.89 MWD 317.44 6.92 MWD 7244.44 -6682.25 9855.68 7309.99 -6746.03 9947.11 7374.29 -6810.51 10038.09 7439.27 -6877.82 10131.49 7500.80 -6944.33 10221.83 317.38 7.20 MWD 317.36 4.53 MWD 317.35 0.64 MWD 317.33 0.79 MWD 317.32 3.22 MWD 7563.90 -7013.80 10315.33 7626.93 -7081.69 10407.71 7691.20 -7147.63 10499.67 7755.40 -7211.30 10590.04 7823.23 -7276.96 10684.44 317.31 1.35 MWD 317.30 0.91 MWD 317.28 1.24 MWD 317.25 1.08 MWD 317.21 1.62 MWD 7889.39 -7339.68 10775.59 7957.27 -7405.40 10870.05 8022.46 -7470.91 10962.41 8086.98 -7538.15 11055.45 8150.20 -7606.24 11148.12 317.16 0.48 MWD 317.12 1.12 MWD 317.10 2.03 MWD 317.08 0.50 MWD 317.07 1.45 MWD 317.07 0.42 MWD 317.06 1.14 MWD 317.04 1.27 MWD 317.01 1.02 MWD 316.98 1.09 MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_iC_03] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 151 14555.15 77.03 312.24 152 14651.91 77.59 311.41 153 14746.85 77.44 311.50 154 14843.65 77.29 311.52 155 14938.51 77.38 311.37 156 15035.00 77.27 311.54 157 15128.10 77.24 311.54 158 15224.62 77.12 312.67 159 15321.36 77.00 312.86 160 15414.59 76.92 312.60 161 15512.11 76.77 312.01 162 15608.18 76.56 313.36 163 15704.74 76.62 313.55 164 15801.39 76.48 312.90 165 15894.83 76.01 312.24 166 15990.87 74.94 311.47 167 16087.10 74.95 312.70 168 16182.90 74.71 312.93 169 16279.07 74.61 313.85 170 16375.30 74.42 313.76 171 16472.31 74.33 313.68 172 16568.01 74.09 314.19 173 16663.63 73.86 314.65 174 16758.13 72.90 313.84 175 16853.59 71.29 312.93 176 16948.07 68.82 312.97 177 17042.34 66.60 312.03 178 17138.91 64.14 310.35 179 17234.98 63.16 310.18 180 17330.31 62.06 309.20 94.99 96.76 94.94 96.80 94.86 96.49 93.10 96.52 96.74 93.23 97.52 96.07 96.56 96.65 93.44 96.04 96.23 95.80 96.17 96.23 97.01 95.70 95.62 94.50 95.46 94.48 94.27 96.57 96.07 95.33 TVD depth (ft) 7965.01 7986.27 8006.79 8027.97 8048.77 8069.94 8090.48 8111.90 8133.56 8154.59 8176.79 8198.95 8221.34 8243.82 8266.04 8290.13 8315.12 8340.19 8365.63 8391.33 8417.46 8443.50 8469.89 8496.92 8526.27 8558.50 8594.25 8634.50 8677.14 8720.99 9-Apr-2001 20:48:23 Page Vertical section (ft) 11219.59 11313.94 11406.58 11500.98 11593.48 Displ Displ Total +N/S- +E/W- displ (ft) (ft) (ft) 8212.48 -7674.61 11240.30 8275.43 -7744.95 11334.33 8336.79 -7814.42 11426.60 8399.40 -7885.15 11520.66 8460.66 -7954.53 11612.80 At Azim (deg) 316.94 316.90 316.85 316.81 316.77 11687.56 11778.31 11872.40 11966.67 12057.49 8522.98 -8025.08 11706.54 8583.19 -8093.05 11796.98 8646.30 -8162.88 11890.79 8710.31 -8232.09 11984.86 8771.94 -8298.81 12075.48 316.72 316.68 316.65 316.62 316.59 12152.43 12245.90 12339.83 12433.83 12524.58 8835.86 -8369.04 12170.18 8899.23 -8437.75 12263.44 8963.83 -8505.94 12357.24 9028.21 -8574.43 12451.08 9089.61 -8641.27 12541.63 316.55 316.52 316.50 316.48 316.45 12617.51 12710.41 12802.86 12895.60 12988.34 13081.76 13173.85 13265.74 13356.28 13447.11 9151.64 -8710.52 12634.30 9213.92 -8779.48 12726.97 9276.76 -8847.31 12819.25 9340.47 -8914.70 12911.87 9404.67 -8981.63 13004.52 316.41 316.38 316.36 316.34 316.32 9469.24 -9049.15 13097.85 9533.13 -9115.47 13189.86 9597.46 -9181.11 13281.71 9660.63 -9245.98 13372.21 9723.02 -9311.99 13462.92 316.30 316.28 316.27 316.26 316.24 13535.92 9783.53 -9377.00 13551.59 13623.12 9842.46 -9441.30 13638.62 13710.83 9900.27 -9507.34 13726.07 13796.78 9955.91 -9573.03 13811.70 13881.24 10009.97 -9638.16 13895.81 316.22 316.19 316.16 316.12 316.08 7 of 8 DLS (deg/ 100f) 0.51 1.02 0.18 0.16 0.18 0.21 0.03 1.15 0.23 0.28 0.61 1.38 0.20 0.67 0.85 1.36 1.23 0.34 0.93 0.22 0.12 0.57 0.52 1.31 1.91 2.61 2.53 3.00 1.03 1.47 Srvy tool type Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)2001 Anadrill IDEAL ID6_lC_03] ANADRILL SCHLUMBERGER Survey Report 9-Apr-2001 20:48:23 Page 8 of 8 Seq Measured Incl Azimuth Course TVD # depth angle angle length depth - (ft) (deg) (deg) (ft) (ft) Vertical Displ section +N/S- (ft) (ft) Displ Total At DLS Srvy Tool +E/W- displ Azim. (deg/ tool qual (ft) (ft)- (deg) 100f) type type 181 17426.57 60.25 310.80 96.26 8767.43 13965.39 10064.15 -9702.75 13979.65 316.05 2.38 182 17522.13 57.64 310.46 95.56 8816.73 14047.15 10117.46 -9764.87 14061.14 316.02 2.75 183 17618.54 55.13 311.94 96.41 8870.10 14127.37 10170.32 -9825.28 14141.13 315.99 2.90 184 17714.07 53.15 313.76 95.53 8926.06 14204.78 10222.96 -9882.05 14218.43 315.97 2.58 185 17809.94 52.65 314.57 95.87 8983.89 14281.23 10276.23 -9936.90 14294.86 315.96 0.85 MW/) 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 186 17905.21 51.89 315.37 95.27 9042.19 14356.55 10329.48 -9990.21 14370.20 315.96 1.04 187 18000.85 52.26 316.89 95.64 9100.97 14431.91 10383.87 -10042.49 14445.63 315.96 1.31 188 18095.11 52.35 317.50 94.26 9158.61 14506.34 10438.59 -10093.17 14520.20 315.96 0.52 189 18190.84 51.78 317.94 95.73 9217.46 14581.63 10494.45 -10143.96 14595.67 315.97 0.70 190 18287.12 51.16 319.13 96.28 9277.44 14656.65 10550.89 -10193.84 14670.91 315.99 1.16 MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis 191 18382.51 49.54 319.87 95.39 9338.30 14729.69 10606.73 -10241.54 14744.21 316.00 1.80 MWD 6-axis Final Survey Projected at TD: 192 18517.00 49.54 319.87 134.49 9425.58 14831.38 10684.97 -10307.49 14846.31 316.03 0.00 Projected [(c)2001 Anadrill IDEAL ID6_iC_03] AI,ASKA OIL AND GAS CONSERVATION CO~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Niakuk NK-08A BP Exploration (Alaska) Inc. Permit No: 201-029 Sur Loc: 1266'NSL, 1099'WEL, Sec. 36, T12N, R15E, UM Btmhole Loc. 1533'NSL, 1029'WEL, Sec. 22, T12N, R15E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced'well. The permit to redrill does not exempt you from obtaining additional permits required by. law from other governmental agencies, and does not authorize conducting drilling oPerations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) 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, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this %i ~ day of February, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA! _AND GAS CONSERVATION COMM. ;ION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [].Stratigraphic Test [] Development Oil a. Type of work [][] DrilIRe_Entry [][] DeepenRedrill lb. Type of well [] Service [] Development Gas ./[~Sin~ Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 52.6' Niakuk Oil Pool 3. Address.~,J/._~,-~6' ProDerty Designation P.O. BOX 196612, Anchorage, Alaska 99519-6612 ~-~'~;-~".~-,A~)~L 034626 4. Location of well at surface 7. Unit or PFo~erty Name 11. Type Bond (See 20 AAC 25.025) 1266' NSL, 1099' WEL, SEC. 36, T12N, R15E, UM Niakuk At top of productive interval 8. Well Number 1090' NSL, 555' WEL, SEC. 22, T12N, R15E, UM NK-08A Number 2S100302630-277 At total depth 9. Approximate spud date 1533' NSL, 1029' WEL, SEC. 22, T12N, R15E, UM 03/02/01 Amount $200,000.00 2. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034625, 1029' MDI No Close Approach 2560 18704' MD / 9415' TVD 6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12580' MD Maximum Hole Angle 75 o Maximum surface 3001 psig, At total depth (TVD) 8987' / 3900 psig 8. Casing Program Specifications Setting Depth Size To3 Bottom Quantity of Cement Hole Casin,q Weight Grade Couplin.q Len,qth MD TVD MD TVD (include stare data) 8-1/2" 4-1/2" 12.6# L-80 Hydril 521 6304' 12400' 7338' 18704' 9415' 715 sxClass'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. JAN 3 ]. ? 0 0 Present well condition summary Total depth: measured 16700 feet Plugs (measured) Alaska 0il & Gas Cons. Commission true vertical 9505 feet Anchorage Effective depth: measured 16559 feet Junk (measured) true vertical 9434 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 260 sx Arcticset (Approx.) 80' 80' Surface 5765' 13-3/8" 1890 sx PF 'E', 375 sx Class 'G' 5806' 4144' Intermediate 13182' 9-5/8" 400 sx Class 'G' 13220' 7743' Production 2880' 7-5/8" 500 sx Class 'G' 13018' - 15898' 7645' - 9100' Liner 974' 5-1/2" 141 sx Class 'G' 15711' - 16685' 8996' - 9497' Perforation depth: measured 16038' - 16068', 16068'- 16088', 16088'- 16120', 16152'- 16162' true vertical 9173' - 9188', 9188' - 9198', 9198' - 9214', 9230' - 9235' 20. Attachments [] 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'. Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~--------------~_. -~,,~..~, ~ Title Senior Drilling Engineer Date , / 3 ,..:.:.;". :.:'...?. ".. :.:.: :.:.:.i,:.~.?" :':..~'":?: :.'::: :'::'..:; :::,' ,':.;': ;... ?!.::(~:." :.;,.':; !'"~:: :;::!;"' ' '~ "':'""::'::":':~ :' '"'''.,v ":,. ' ......... .. .... ........... . ' ........... .,.... :': ."' ¢om.'rn, ls.s,i~n.:use,'.O.l', .,,., ,' .... ..... . ..., ......................... . ., .... , y,.,,,:..,..,.,.,.,.,,.,.,., ::,:.?,...:,:,v :,,, ~::.,,:.,~.,: ,.,..::==.~.....,..:.::.'.i. :..,.: ..,~ .:::: ..,,,.:~ ,.,¥, Permit Number I APl..l~lumber I Ap_.provalDate I See cover leii~r :'P_.JC_) / - ~ '.'~_~_-~'~ 50-~029-22491-01 ~__.~ -o~/- ~) ( for other requirements COnditions of Approval: Samples I:~uired [] Yes ~"~o Mud Log Required [] Yes J~"No Hydrogen Sulfide Measures .~['/Yes ' [] No Directional Survey Required .,]~["Yes '1-'1 No Required Working Pressure for ROPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: '~C~,.~ ~%~ ~)'~ --~.,---~---- , . .... Commissioner the commission Date ,~'- Approved By Form 10-401 Rev. 12-01-85 Submit In Triplicate NK-08A Permit to Drill RECEIVEI''~ I Well Name: I NK-08A I JAN 3 ] Z001 Alaska Oil & Gas Cons. Commission Anchorage Sidetrack and Comploto Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location: x = 721,465.3 / Y = 5,979,798.6 1266' FSL 1099' FEL S36 T12N R15E Umiat Target Location- x = 711,145.0 / Y = 5,989,888.0 1090' FSL 555' FEL S22T12N R15E Umiat Bottom Hole Location: X = 710,658.7 / Y = 5,990,318.5 1533' FSL 1029' FEL S22T12N R15E Umiat AFE Number: 15L1502 I Estimated Start Date: 103/02/01 MD: I~ 8,704' I I TVD: 194~5' I Rig: I Doyon 14 I Operating days to complete: 126.25 I Cellar Elevation: 119.1' I RKB: 1 52.6' I Well Design (conventional, slimhole, etc.): I Conventional Big Bore I Objective: I Niakuk Kuparuk Development Formation Markers Formation Tops MD TVDss Comments Base Permafrost SV3 SV1 Ugnu 4A West Sak 6485' CM3 / K-12 12,546' 7355' Kick-off Point 12,580' 7373' Kick-off at Base West Sak / Top Colville CM3 Shale Wall 17,268' 8644' Tuffs 17,374' 8697' Top HRZ 17,616' 8818' Top Kuparuk 17,954' 8987' Est. pore pressure 3900 psi (8.3 ppg EMW) Top Kingak 18,524' 9272' TD 18,704' 9362' Casing/Tubing Program Hole ~ize Csg/ - Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8-1/2" 4-1/2" 12.6# L-80 Hydril 521 -6304' 12,400'/7338' 18,704'/9415' Tubing 4-1/2" 12.6# L-80 IBT-M ~12,520' GL 12,550' / 7409' NK-08A Permit to Drill Directional KOP: I 12,580' MD Maximum Hole Angle: Close Approach Well: Survey Program: -75° In Tangent Interval 12,821' to 16,881' MD -60° Through Reservoir Target Interval All wells pass BP Close Approach guidelines. The nearest close approach well is NK-34 which is -1700' well-to-well at 18,623' MD and passes under Major Risk rules. Standard MWD Surveys from kick-off to TD. Mud Program 8-1/2" Pro(Juction Hole LSND (12,580' to 18,704' MD) Interval Density Funnel YP LSR YP pH APl FL (ppg) Viscosity Colville 9.3 - 9.4 45-60 18-25 8-10 8.5 - 9.5 +/-6 Tuffs 11.0 45-60 18-25 8-10 8.5 - 9.5 +/-4 'Shale Wall' HRZ 11.0 45-60 18-25 8-10 8.5 -9.5 +/-4 Kuparuk 11.0 45-60 18-25 8-10 8.5 -9.5 +/-4 Kingak 11.0 45-60 18-25 8-10 8.5 -9.5 +/-4 Logging Program Production Hole Section Drilling: Open Hole: Cased Hole: MWD ! GR / Resistivity ! Neutron ! Density None None Cement Calculations Casing Size I 4-1/2" Production Liner I Basis: Tail: Based on 2250' of open hole with 30% excess and 84' of 4-1/2" shoe joint. Tail TOC: -16,454' MD (8441' TVD).- approximately 1500' MD above top Kuparuk. Total Cement Volume: Tail I 149 bbl/837 f¢ / 715 sks of Dowell Premium Latex 'G' at 1 15.8 ppg and 1.17 cf/sk. Well Control: 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 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3900 psi @ 8987' TVDss - Kuparuk · Maximum surface pressure: 3001 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) RECEIVED · Planned BOP test pressure: · Planned completion fluid: 3500 psi 8.6 ppg Brine / 6.8 ppg Diesel JAN 3 ] 2001 Alaska Oil & Gas Cons. Commission Anchorage NK-08A Permit to Drill Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · Niakuk Pad is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: NK-08 44 ppm Jun 13, 99 (well was shut-in August of 1999) Adjacent producers at Surface: NK-07 39 ppm Dec 1, 98 (well was shut-in late Dec 1998) NK-09 0 ppm Oct 3, 00 NK-28 35 ppm Apr 25, 00 NK-29 20 ppm Oct 14, 00 Adjacent producers at TD: All as above: NK-08, 09, 28, 29 NK-34 30 ppm Oct 3, 00 The maximum recorded level of H2S on the pad was 60 ppm from NK-28 on Jan 17, 2000. DRILLING CLOSE APPROACH: All offset wells pass close approach guidelines, however it is critical to address and understand all close approach issues prior to beginning operations. There are several near by wells that could become an issue if the well path deviates a significant distance from the plan. PRODUCTION SECTION: · The NK-08A well path will drill full sections of the Tuffs, and HRZ shales. Each of these formations have been troublesome in the Niakuk area and have shown severe hole instability problems. Follow all shale drilling practices to limit high ECD's. We will also be using increased mud weights and shale stabilizers in the drilling fluid. ,,' · The Kuparuk reservoir is expected to be under-pressured at the NK-43 bottom' ~hole location. Because of the high mud weights required to drill the surrounding shale intervals, losses and differential sticking could be a problem. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling out in the 8-1/2" production interval. · Differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the permeable Kuparuk Sands. · The kick tolerance for the 8-1/2" open hole section would be an infinite influx assuming a kick from the Kuparuk interval at -17,950' MD. This is a worst case scenario based on a 8.5 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" window, and 10.9 ppg mud in the hole. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage NK-08A Permit to Drill Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · 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. SIDETRACK & COMPLETE SUMMARY Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. RIH with CTU, through tubing, to top of fill in 5 Y2" liner. Perform a cement P&A using 15.8 ppg class 'G' cement with adequate cement volume to fill the 5 Y2" liner from top of fill to a minimum of 100' into the tubing tail. Squeeze 5 additional bbls into the perforations. NOTE: The AOGCC has requested on prior sidetracks exiting above the reservoir, that the top of cement be brought up into the tubing tail -100', therefore the minimum top of cement should be 15,616'. Top of cement may extend further up into the tubing as long as it does not interfere with the upcoming tubing cutting operations. 2. Tag and document top of cement and drift tubing for upcoming tubing cut. 3. Liquid pack the tubing and 9-5/8" x 4-1/2" annulus to surface. Test the integrity of the cement plug and casing by simultaneously pressure testing both the tubing and annulus to 3000 psi for 30 minutes. Increase tubing pressure prior to the 9-5/8" annulus to avoid possibility of tubing collapse. 4. Cut the 4 Y2", 12.6#, tubing at approximately 13,100' MD. Displace the well to kill weight fluid by circulating down the tubing through the tubing cut. Continue to circulate until kill weight fluid returns to surface. Freeze protect top 2200' MD with diesel. 5. Pressure test the casing pack off for 30 minutes. If 9 5/8" casing was set on emergency slips, test the 9 5/8" pack off to 3,800 psi, which is 80% of the casing collapse pressure. If the 9 5/8" casing was landed on a mandrel hanger, test the pack off to 5,000 psi. Test the tubing hanger seals to 5000 psi for 30 minutes. 6. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 7. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ri.q 1. 2. 3. 4. 5. 6. 7. Operations: MIRU Doyon 14. Cimulate out freeze protection and displace well to kill weight fluid. Set TWC & test from below. Nipple down tree. Nipple up and test BOPE. Pull and lay down 4-1/2" tubing from E-line cut and above. MU 9 5/8" window milling assembly and RIH to top of tubing stub. POOH. Set CIBP at -12,600' MD. To avoid cutting a casing collar, set the BP 2' - 3' above a collar. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock as necessary and set. Mill window in 9-5/8" casing. Perform FIT test to 12.5 ppg. POOH. RECEIVE D J/ N 3 ] 2001 Alaska Oil & Gas Cons. Commission Anchorage NK-08A Permit to Drill 8. RIH with 8 1/2" drilling assembly to whipstock. Kick-off and drill the 8-1/2" hole section to TD at +/- 18,704' MD (9415' TVD). POOH. 9. Run and cement a 4 ¥2", 12.6# production liner. Displace cement w/viscosified brine perf pill followed by fresh water spacer and mud. Release from liner and circulate out excess cement and displace well to kill weight fluid. POOH. After cement has gained compressive strength, test the casing and liner from the landing collar to surface to 3000 psi for 30 minutes 10. Drill pipe convey perforate Kuparak sands @ 6JSPF. 11. Install 4-1/2", 12.6# L80 tubing completion. 12. Drop ball/rod & set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 13. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 14. Freeze protect the well to ~2200' and secure the well. 15. Rig down and move off. Post-Riq Work: 1. Pull the ball and rod / RHC plug from below the new production packer. Install gas lift valves. Estimated Pre-rig Start Date: Estimated Spud Date: 01/25/01 03/02/01 William Isaacson Operations Drilling Engineer 564-5521 RECEIVED JAN Alaska Oil & Gas Cons. Commission Anchorage NK-08 Proposed Pre-Rig GL-SL = 19' TREE: 4"- 5M CIW Non-chrome -- -- ~ ~ ~ -- ET- TS =39'. WELLHEAD: 13-5/-'~- 5M Universal Big Bor(~L.~ / Actuator:Baker ~1 ---OTIS4'I/2" TRSSSVseries 10 .12151' . 13-3/8",68#/ft, I , I ___ j ~ NT80CYHE, BTC I 5806 I / GAS LIFT MANDRELS KOP: 300' 8 5 7548 5004 60.0 NSCT TUBING .... I (MERLA TMPDX W/RK LATC, HFR 3.958" ID 0.0152 bbl/ft ~ 3 13359 7808 61.3 2 14790 8498 59.7 Tubing Cut at ~ 13,100' MD N ~ NO. Status Ptro Pso (: ,1/13/98) 6 Dummy 5 Dummy LINER HANGER I , I % I 4 Dummy PACKER 9-5/8" x7-5/8" I 13018 I --'~'~L fl 3 Dummy 2 Dummy 1 S/O 20/64" 9-5/8", 47#/FT, ' ~ L NT80S, NSCC 113220 I I ~ '" l' -- 4-1/2" X Nipple (3.813" I 15590' I Top Ceme,nt P&A Plug ~_~ i ~ -- 7-5/8" x 4-1/2" Baker SABL- I 15652'1 at~1,5,616 MD -- 4-1/2," XN Nipple (3.725' ID) I 15704' I -- 43-1/2" X Nipple (3.813" i,D) L15687' J topof6 TBR (5.75" ID) I 15711' I / -- 4-1/2' I 15716' I PERFORATION SUMMARY: Ref Log: SBT8/27/94 J / k 7-5/8"29.7#/FT,NT-80S LINER Size Interval SPF Open/Sqzd ~ (6.875" ID, 0.0459 bbl/ft) I 3 3/8 16038-16068 4 All Sqzd I 3 3/8 16068-1_ 6088 6 as part of ' 3 3/8 16088:16120 6 P&A 5-1/2' 17#/FT,NT-80S LINER , , , PBTD I 16559' I (4.892" ID, 0.0232 bbl/ft) I 16685 I I DATE REV. BY COMMENTS Niakuk 9/14/94 K SMITH INITIAL PERF WELL' NK-O8 5/6/95 MFH Add Perf APl NO' 50-029-22491 1/13/98 M.Sloan Updated GLV info 1/10/01 WSI Proposed Pre Rig for ST Prudhoe Bay Drilling GAS LIFT MANDRELS (Otis 4-1/2" LB 1 1/2" VALVES W/R,*, t.?,TCHES) h,19 ItAI-tlhH-~ T~/l~.h[rh aNIRI F 6 3512 2995 55.7 5 7548 5004 60.0 ,~ t t o~ R7R.q 60.7 (MERLA TMPDX 1" VALVES W/RK LAT~HFR 3 13359 7808 61.3 2 14790 8498 59.7 I 1.RRRR R91.q R4,6 No. Status Ptro Pso 1/13/98) 6 Dummy 5 Dummy 4 Dummy 3 Dummy 2 Dummy 1 S/O 20/64" PERFORATION SUMMARY: Ref Log: SBT 8/27/94 Size Interval SPF Open/Sqzd 3 3/8 16038-16068 4 All Sqzd 3 3/8 16068-16088 6 as part of 3 3/8 16088-16120 6 P&A 3 3/8 16152-16162 6 TREE: 4-1/16" - 5M CIW Chrome WELLHEAD: 13 5/8" - 5M FMC NK-08A Proposed Completion Cellar Box Elevation = 19.1' Doyon 14 RKB = 52.6' 4-1/2" Halliburton 'Series 10' tubing retrievable SSSV w/control line to sudace. I 2150' I 13-3/8", 68 #/ft, L-80, BTC 4-1/2" Gas Lift Mandrels with handling pups installed. , , GAS LIFT MANDRELS # I TVD Size Valve Type 1 i TBD 1-1/2' RP Shear ! 2 TBD } 1-1/2" , DV ' 3 TBD 1-1/2" i DV 1-1/2" ~, DV I! 54 TBD TBD 1-1/2" DV BAKER 7" x 9-5/8" +/-12,400' I Liner Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger 3 joints 7" Hydri1511 Crossover to 4-1/2" Hydri1521 4-1/2" 12.6# L-80, IBT Tubing 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out immediately above 7" x 4-1/2" XO in liner. Window Milled from Whipstock of Window at +/-12,580' MD Top Bridge Plug set at +/-12,600' MD Pre-Rig Tubing Cut at +/-13,100' ~ 7-5/8" Liner Top 113,018' I 9-5/8", 47 #/ft, NS0, NSCC 113,220' I RbuEtVEL,. J/iN 3 1 2001 .Alaska Oil & Gas Cons. Cor~miss. gnchor~ge Top cement P&A plug at -15,616' MD Plug Back Depth I +/-18~620' 4-1/2", 12.6 #/ft, L-80, Hydril 521 i +/-18,704' 7-5/8", 29.7 #/ft, NT80 115,89s'l Perforations from 16,038' to 16,162' 5-1/2", 17 #/ft, N80 I 16,685' i Date Rev By Comments 1/29/01 WSI Proposed Completion NIAKUK WELL: NK-08A APl NO: 50-029-22491-01 Shared Services Drilling Report Date: Client: Reid: Structure I Slot: Well: Borehole: UWI/APB: Proposal Name I Modified Date: Tort I AHD I DDI I ERD ratio: Grid Coordinate System: Location I. aULong: Location Grid FUE Y/X: Grid Convergence Angle: Grid Scale Factor: Station ID Tie-In Survey Colville CM3 Top of Window Base Whipstock KOP Crv 7/100 End Crv Drp 4/100 End Drp 12492.60 12545.64 12580.00 12596.00 12608.00 12700.00 12800.00 12821.15 16881.44 16900.00 17000.00 17100.00 17200.00 17263.71 NK-O8A Schlumberger Proposed Well Profile - Geodetic Report January 26, 2001 Alaska Drilling & Wells Niakuk Main Pad / NK-08 NK-08 NK-O8A 50-029-22491-01 NK-08A (P4) / January 26, 2001 161.439° / 13661.11 tt / 6.642 / 1.451 NAD27 Naska State Planes, Zone 04, US Feet N 70 2049.555, W 14812 7.308 N 5979798.600 ItUS, E 721465.300 flUS +1.69329634° O.99995572 StU4 Survey I BLS Cemputation Mathod: Vertical Section Azimuth: OnlY v..,,, .origin: Feas--"'"'ibil'V TVO Reference Elevation: Magnetic Declination: Total Reid Strength: Magnetic Dip: Declination Date: Magnetic Declination ~xlel: NO~th Reference: Total Corr Mag North .> True North: Coordinate Reference To: Minimum Curvature / Lubinski 313.410o N 0.000 It, E 0,000 ft KB 52.6 tt relative to Mean Sea Level 27.131° 57504.606 nT 80.868° November 21, 2000 BGGM 2000 True North +27.131° Well Head Incl 59.75 59.90 59.99 60.51 ¢} {.) ~) (W (m 317.26 7380.94 9244.31 6833.09 -6261.24 317.52 7407.60 9290.05 6866.83 -6292.29 317.68 7424.81 9319.71 6888.79 -6312.34 315.55 7432.75 9333.58 6898.89 -6321.88 0.00 0.50 0.50 12.00 Grid Coordin~es I Northing I Easflng ~us) (ftUS) 5986443.38 715005.18 5986476.19 714973.15 5986497.55 714952.46 5986507.36 714942.63 Oe~raphic Coordinates LatitudeI Long"deI N 70 21 56.732 W 148 15 10.429 N 7021 57.064 W 148 15 11.337 N 7021 57.280 W 148 15 11.924 N 70 21 57.379 W 148 15 12.204 60.51 315.55 7438.65 9344.01 6906.34 -6329.20 66.89 314.54 7479.40 9426.41 6964.66 -6387.45 73.82 313.54 7513.00 9520.53 7030.08 -6455.12 75.29 313.34 7518.63 9540.91 7044.10 -6469.92 75.29 313.34 8549.64 13468.12 9739.64 -9325.98 0.00 5986514.59 714935.09 7.00 5986571.16 714875.14 7.00 5986634.55 714805.57 7.00 5986648.13 714790.37 0.00 5989257.97 711856.04 N 70 21 57.452 W148 15 12.418 N 70 21 58.025 W148 15 14.123 N 70 21 58.668 W148 15 16.104 N 70 21 58.806 W148 15 16.537 N 70 22 25.287 W148 16 40.168 74.55 313.34 8554.47 13486.04 9751.94 -9339.01 70.55 313.31 8564.45 13581.42 9817.38 -9408.40 66.55 313.27 8621.02 13674.47 9881.18 -9476.13 62.55 313.23 8663.98 13764.75 9943.04 -9541.88 60.00 313.21 8694.60 13820.61 9981.30 -9582.59 4.00 5989269.88 711642.65 4.00 5989333.24 711771.36 4.00 5989395.01 711701.78 4.00 5989454.90 711634.23 4.00 5989491.93 711592.41 N 70 22 25.407 W148 16 40.649 N 70 22 26.050 W148 16 42.582 N 70 22 26.677 W148 1644.566 N 70 22 27.264 W148 16 46.492 N 70 22 27.660 W148 16 47.685 RECEIVED NK-O8A (P4) report.xls JAN 3 1 Alaska Oil & Gas Cons. Commission Anchorage Page 1 of 2 1/26/2001-9:20 AM Station ID Shale Wall Top Tuffs Top HRZ Kuparuk Target Kingak TD/7" Csg Pt MD 17267.71 17373.71 17615.71 17953.71 17953.71 18523.71 18703.71 Incl 60.00 60.00 60.00 60.00 60.00 60.00 313.21 313.21 313.21 313.21 313.21 313.21 313.21 8696.60 8749.60 8870.60 9039.60 9039.60 9324.60 9414.60 13824.08 13915.88 14125.45 14418.17 14418.17 14911.80 15067.68 9983.67 -9585.12 10046.52 -9652.03 10190.02 -9804.78 10390.43 -10018.12 10390.43 -10018.12 10728.41 -10377.91 10835.14 -10491.52 I Grid Co~dinates DLS Northing Easfing (°ll00ft) {ttUS~ {ltUSI 0.00 5989494.23 711589.81 0.00 5989555.07 711521.08 0.00 5989693.99 711364.16 0.00 5989888.00 711145.00 0.00 5989888.00 711145.00 0.00 5990215.18 710775.40 0.00 5990318.50 710658.69 GeO~lraphic Coordinates I LaUtude I Longitude N 70 22 27.683 W 148 16 47.759 N 70 22 28.301 W 148 16 49.719 N 70 22 29.710 W 148 16 54.194 N 70 22 31.678 W 148 17 0.444 N 70 22 31.678 W 148 17 0.444 N 70 2234.998 W148 17 10.985 N 70 22 36.046 W148 17 14.314 Le~lal Description: SuEace' 1265 FSL 1099 FEL S36 T12N R15E UM Tie-In' 2816 FSL 2079 FEL S26 T12N R15E UM Target' 1089 FSL556 FEL S22 T12N R15E UM BHL' 1533 FSL 1029 FEL S22 T12N R15E UM No~hin=i33[flUS] 5979798.60 5986443.38 5989888.00 5990318.51 Eastina{X}[flUSl 721465.30 715005.18 711145.00 710658.69 RECEIVED 3 I ZOO1 Alaska Oil & Gas ConS. Commission Anchorage NK-08A (P4) report.xls Page 2 of 2 1/26/2001-9:20 AM VEKTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: NK-08A (P4) Field: Niakuk Structure: Main Pad Section At: 313.41 deg Date: January 26, 2001 Schlumberger 5000= 6000= 7000= 8000= 9000= 10000 8000 T'~-In Sm~ey 12493 MD 7381 'P.,'D $9.75' 317.2.6" az 9244depsr~'e , Pmposal Survey RECEIVED ~. Top of W~n~ 12580 MD 7425 'II/D '~ /59.99~ 317.68~az 9320depart~e __ _ ~ _ _ A~ska 0il & Gas Cons Commission ~."~,:'.~'X--~;' / ~ ~ Hold Angle 75.29° .......... K~.~- I~ MD 9.0 ~D-: -~ ~old ........ Angle 60.00°' ':~ '- ~> ' ~ ..... ~ ~ TDI7" C~ ffi 1~ d~e 9~0 10000 11000 12000 13000 14000 15000 Vertical Section Departure at 313.41 deg from (0.0, 0.0). (1 in = 1000 feet) Client: Alaska Drilling & Wells Well: NK-08A (P4) Field: Niakuk Structure: Main Pad Scale: 1 in = 1000 ft Date: 26-Jan-2001 Schlumberger -11000 -10000 -9000 -8000 -7000 -6000 12000- A A 10000 A 0 z I I L Tz~e ~o=th ~ - 12000 Mag Dec ( E 27.13° ) 18704 MD 94151VD 60.00' 313.21' az 10835 N 1~92W ............................................ 11000 ~ ~ Ta~I oooo 9981 N 9~3W' ~ ~ ~.2~' ~'~ ~ ~ 9000 nd Cw 1281 D = = 75~29" 313:~ ~"~Z' 7~"N" ~70W KOP CW 7110012~8 MD 7439 ~D ..................... ~" / E a~ ~lp~k125~ MD 74331 VD 6).51" 315.~'~ 68~N 6~2V " / / Top ~ ~ndow 125~ MD 742 ~ ~O ,/ 59,9~ 317,~*az ~89N 63 2W / 59,75~ 317,26' az ~33 f 6261 W 5ooo I -~000 -~0000 -9000 -sooo -7000 -6000 F- D O V V V <<< WEST EAST >>> NK-08A Ri.qsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE HYDROGEN SULFIDE- Heald Point Niakuk Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Highest level of H2S measured on NK Pad: 60 ppm from NK-28. Highest level of H2S from adjacent wells at Surface: 39 ppm from NK-07. Highest level of H2S from adjacent wells at TD' 35 ppm from NK-28. The NK-08A well path will drill full sections of the Tuffs and HRZ and some Kingak shale. Each of these formations have been troublesome in the Niakuk area and have shown severe hole instability problems. Follow all shale drilling practices to limit high ECD's. We will also be using increased mud weights and shale stabilizers in the drilling fluid. The Kuparuk reservoir is expected to be under-pressured at the NK-08A bottom hole location. Because of the high mud weights required to drill the surrounding shale intervals, losses and differential sticking could be a problem. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling the production interval. Differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the permeable West Sak or Kuparuk Sands. The kick tolerance for the 8Y2" open hole section would be an infinite influx assuming a kick from the Kuparuk at ...17,950' MD. This is a worst case scenario based on an 8.5 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" window, and 10.9 ppg mud in the hole. CONSULT THE Niakuk PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 NK-08A Hazards and Contingencies Page ! of I DATE I [ CHECK NO. 1 H ..1_ 8 0:9 G 8 ~,,~ooI oo~o,~,~ VENDOR ALASKAO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 122100 CK122:lOOH :i00. O0 100. O0 PYMT .;OMI'lENTS' Pe'r~r~it To D'ri11 -ee HANDL [NO INST' S/H - Te~'~'ie Hub ~le X4&~8 rm~ ATTACmEO CHECK ,S ,. P*.Y.Em' FO. rmas D~:SCRmED *.BOVE. ~ ~, 00. O0 :l OO. OO ':,'.::.',:::! 2: i' :A~;;'AF.,~II.~IATE,~ ,:i,,!i' ":::.', :!::!::i;i :~,.;:i NA~ION~,:CITY,,~.~K :":.: ,':, !'. ":' :: .: :: .:. '"Ci".'EVEL~,'ND OHiO .~' .:'. :' ..... :" ,:,, · . " :,. ':i,'.,'~i,.,:: ':'..:?~ili'~i,:~6-aoo,:::,:::" ~.,i!:::',.,,.':;,.::" 412 ' ,ool PAY WELL PERMIT CHECKLIST COMPANY /~5" ' ~- WELL NAME',/V~/'~.: ~_~ PROGRAM: exp FIELD & POOL ~_~... ~-~/~?Z~.~ INIT CLASS '..~ ~ ~J ?~_.~/L_- GEOL AREA ADMINISTRATION II APPR DATE I ENGINEERING GEOLOGY APPR DATE 1. Permit fee attached ...................... . . 2. Lease number appropdate?Y~.-~.~.~.,'.~.'z~. ~. ~.. Z~-. ~zT,.~ / 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 ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... '× redrll ~'" serv~ wellbore seg ann. disposal para req ~ UNIT# ('~_.;'//"~_~ .~-~'~"3~ ON/OFF SHORE N 14. Conductor stdng provided ................... Y N ./ , 15. Surface casing protects all known USDWs ............ ~ --Y--R- ~_~.'~/[ ~F,..~z-~-- .c~,,..~/--~ ~ z,_,,c//...,(__~ 16. CMT vol adequate to circulate on conductor & surf csg ..... ~_~' ~,.~.~ 17. CMT vol adequate to tie-in long string to surf csg ........ ,,y,. N 18. CMT will cover all known productive horizons. ' ~ N 19. Casing designs adequate for C, T, B & permafrost ....... N ~ - - 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... ~ N '-~(:3~.-.¢,,~ ~ ~ . 22. Adequate wellbore separation proposed ............. (,~ N ' · 23. If diverter required, does it meet regulations 24. Drilling .fluid program schematic & equip list adequate ..... 25. DOPEs, do they meet regulation ........ .:--~k:',, ..... 26. DOPE press rating appropriate; test to "~5~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. ,/. 30. Permit can be issued wlo hydrogen sulfide measures ..... y~.~ 31. Data presented on potential overpressure zones ....... ,Y/'l~'" ,~-",~,~ ~ '/',,z.~,'~- - - " -' ~' - 32. Seismic analysis of shallow gas zones ............. ~ rjY N . 33. Seabed condition survey (if off-shore) ............ .~ Y N 34. Contact name/phone for weekly progress reports [explor, effi~ only] Y , ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... 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 ,// ' GEOLOGY: ENGINEERING: UIC/A~ular, COMMISSION: Comments/Instructions: ' I§ rtl c:\msoffice\wordian\diana\checklist (rev. 11/011/00)
