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Home My WebLink About201-015 Ima~Project Well History File CoVe/l~age 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. o~,0 ~--.0 I _'~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type ~' Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: , [] Other Project Proofing By: BEVERLY ROBIN VINCENT SHERYL{~~INDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERYL~INDY +c~~ = TOTAL PAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~L~YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED Old__AL PAGE 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: IS~ Quality Checked 12110/02Rev3NOTScanned.wpd e e (~." ... MICROFILMED 07/25/06 DO NOT PLACE . ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFichc\CvrPgs _Inscrts\Microfil m _Marker. doc " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged II Abandoned 0 Suspended 0 WAG 20AAC25.105 20AAC25110 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3952' SNL, 995' WEL, SEC. 36, T12N, R15E, UM Top of Productive Horizon: 797' NSL, 1663' WEL, SEC. 23, T12N, R15E, UM Total Depth: 1079' NSL, 1889' WEL, SEC. 23, T12N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 721567 y- 5979863 Zone- ASP4 TPI: x- 715324 y- 5989714 Zone- ASP4 Total Depth: x- 715090 y- 5989989 Zone- ASP4 18. Directional Survey 0 Yes II No 21. Logs Run: MWD GR I RES I NEU I DEN I PWD Zero Other 5. Date Comp., Susp., or Aband. 2/16/2004 6. Date Spudded 2/14/2001 7. Date T.D. Reached 2/2412001 8. KB Elevation (ft): 51.88' 9. Plug Back Depth (MD+ TVD) 16453 + 9307 10. Total Depth (MD+TVD) 16550 + 9351 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1b. Well Class: II Development 0 Exploratory 0 Stratigraphic Test 0 Service 12. Permit to Drill Number 201-015 303-111 13. API Number 50- 029-22414-02-00 14. Well Name and Number: PBU NK-12B 15. Field I Pool(s}: Prudhoe Bay Field I Niakuk Oil Pool Ft Ft 16. Property Designation: ADL 034625 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) - CÁSING '. .$IÌÈ:.. 20" 10-3/4" 7-518" 4-1/2" ,WT:PeR.fJ:.. .: 94# 45.5# 29.7# 12.6# , ' , ' :GBADe:;: ' H-40 NT-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD '~:~=:;~.~~:ß 'J.':::r:. ~~}~ (~G,: '. ,'; '. ca¡~I~ ß~~' ' : Surface 80' Surface 80' 30" 280 cu ft Arcticset 40' 4764' 40' 4144' 13-1/2" 435 cu ft Class 'G' 38' 11092' 38' 7440' 9-7/8" 806 cu ft Class 'G' 10849' 16550' 7317' 9351' 6-3/4" 921 cu ft LiteCrete, 286 cu ft Class 'G' 22. 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD ~"~f:; - . p(JI.Læ:i - . " 24; . '<fueIÑG RECORD " SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 10855' TVD PACKER SET (MD) 10799' '2&. .'. ":~Ö~f~Tùk~iC~,: S9Ý~~. ~è. ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 16260' Set WFT WS-R-BB packer /' 16235' Set Whipstock / ~b~ ~\rp. 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TesT PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 24-HoUR RATE .27. CORE DATA - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~",~R 3 1 20L PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oil-Bel GAs-McF WATER-Bel Oil-Bel None Form 10-407 Revised 12/2003 GAs-McF WATER-BeL ORIGiNAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) IØ83 orL 1iR!i 100' ~( 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Kuparuk 16142' 9161' None Base of Kuparuk 16443' 9303' \.' i.i'1' is 1 2 Ot: 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ J\A.Ìe. tt,~ Title Technical Assistant Date 03-3/.°l.( PBU NK-12B 201-015 303-111 Prepared By NameiNumber: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Mary Endacott, 564-4388 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 8: ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ORIGiNAL ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Well: Field: API: Permit: NK-12C Prudhoe Bay Unit 50-029-22414-03-00 203-055 Accept: Spud: Release: 02/10104 02/18/04 02/25/04 Nordic #1 PRE-RIG WORK 04/06/03 RAN BHPS. PULLED HOLD OPEN SLEEVE FROM SSSVN @1993 WLM. DRIFTED WI 3.70' DUMMY WHIPSTOCK TO 11,076' WLM. 06/15/03 DRIFTED 3.84" GAUGE RING TO OBSTRUCTION @ 770' SLM. RUN 3.70" LIB THROUGH OBSTRUCTION WI NO PROBLEMS. DRIFTED WI 3.80" CENT GAUGE RING TO SSSV WI NO PROBLEMS. 06/16/03 SWADGED OUT TIGHT SPOTS WI 3.84" SWEDGE FROM SURFACE TO TRSSSV @ 1997' SLM (TIGHT SPOTS @ 771', 1021', 1383', 1583'). SET HOLD OPEN SLEEVE IN TRSSSV @ 1997' SLM (NO-GO OD- 3.835", OAL- 105", ID- 2.860", BODY OD- 3.753"). 06/29/03 LOGGED INJECTIVITY I BREAKDOWN PROFILE FROM TD-16300' MD. SET DOWN AT MAX DEVIATION ONCE WHILE RIH. LOGGED BASELINE SITP DATA. PUMPED 400 BBLS 1%KCL TO FLUID PACK WELL. LOGGED STEP RATE TEST. LOGGED INJECTION PASSES FOR 4 BPM AND 2 BPM INJECTION RATES. TOOK STOPS FOR ISIP REVIEW. LOGGED WARM BACK PASSES AT 1 HOUR AND 3 HOURS AFTER PUMPS SHUT DOWN. LEFT WELL SHUT IN. TAGGED TD @ 16419' MD. NO OTHER PROBLEMS RIH OR POOH. 07/05/03 DRIFT FOR SBHPS, WI 2.80 CENT, SB TAG TD @ 16362' WLM. RUN TANDEM PETREDAT GAUGES. MAKE 10 MIN STOP IN LUB. MAKE 15 MIN STOPS @ 16332' WLM (9200' SS), 16124' WLM (9100' SS), 15925' WLM (9000' SS), AND 45 MIN STOP @ 16332' WLM (9200' SS). MAKE 10 MIN LUB. STOP. PULLED HOLD OPEN SLEEVE @ 1992' WLM. TIGHT SPOTS @ 1896',1376', 1211',1049' AND 768' ALL WLM'S. SET 4-1/2" SLIP STOP @ 7376' SLM. PULLED 1" DV'S (INT LATCH) FROM ST A'S 3 & 2. 07/06/03 SET 1" GLV (INT LATCH, 1/4" PORT, TRO-2000#) @ STA 3. SET OV (INT LATCH, 5/16" PORT) @ STA 2. PULLED 4-1/2" SLIP STOP CATCHER SUB FROM 7376' SLM. RIG DOWN. SECURED WELL. 07/22/03 DRIFT WI 3.625" CENT. & SAMPLE BAILER TO 11,950' WLM WITH NO PROBLEMS, APPEARED TO STOP DUE TO DEV. NOTIFIED DSO OPE A. OF WELL STATUS. 12/01/03 DRIFTED 10' X 3.70" DUMMY WHIPSTOCK TO 1051' SLM - HIT PARAFFIN. DRIFTED 3.60" GAUGE RING TO TRSSSV - COULD NOT GET THRU. 12/02/03 PUMPED 108 BBLS HOT DIESEL - BRUSH FLUSH TBG. DRIFT 10' X 3.70" DUMMY WHIPSTOCK, UNABLE TO PASS 11,077', POSSIBLE WINDOW ENTRANCE. DRIFT WI 41/2" BRUSH & 3.65" SWEDGE, TAG SOFT I STICKY BOTTOM @ 16,367' WLM. DRIFT WI 10' X 3.65 BAR BELL ASSY. TO 16,364' WLM, TAG STICKY I SOFT BOTTOM. NOTIFY DSO OF WELL STATUS, LEFT SII. NK-12C, Coil Tubing Drilling Page 2 12/20/03 MU AND RIH WITH 30.26' OF DRIFT. (18.66' X 3.125" OD AND 7.91' X 3.650" OD). DRIFTED TO 16,400' CTM. DID NOT TAG. POOH AND RDMO. FREEZE PROTECT STILL IN PLACE. NOTIFY DSO OF WELL STATUS. 12/25/03 SET C-SUB @ 10818' SLM. PULLED DOME FROM ST A 3, PULLED S/O FROM ST A 2. SET DUMMY GL V IN ST A # 2,3. PULL C-SUB. 01/17/04 T/I/O 1500/300/200. MIT IA TO 3000 PSI. PASSED (CTD DIAGNOSTICS) FILLED AND PRESSURED UP IA W/ 54.3 BBLS CRUDE. START TEST (1500/3000/630), 1ST TEST LOST 120 PSI IN 15 MINS, (1500/2880/630), 2ND 15 MINS LOST 40 PSI, (1500/2840/630) FOR A TOTAL OF 160 PSI. IN 30 MINS. BLEED IA. RDMOL FINAL WHP'S 1500/380/200. legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report Page 1 .. NK-12 NK-12 REENTER+COMPlETE NORDIC CALISTA NORDIC 1 Start: 2/9/2004 Rig Release: 2/25/2004 Rig Number: N1 Spud Date: 11/1/1993 End: 2/25/2004 Date' From - To Hours' Task Code NPT Phase Description of Operations 2/912004 14:00 - 17:00 3.00 MOB P PRE Rig released from DS1-17B at 1400 hrs. Move Nordic 1 to edge of pad 17:00 - 00:00 7.00 MOB N WAIT PRE WOW Temp = -25F Wind = 44 Gust WC = -73 F Visibilty Poor 0.00 P DECOMP 0.00 WEXIT 0.00 P PROD1 0.00 COMP 0.00 P POST 2/10/2004 00:00 - 06:00 6.00 MOB N PRE Weather conditions improved at 0400 hrs. At 0530 hrs, T= -14F, WC= 46F wI Wind @ 14 to 25 mph. Getting ready to move 06:00 - 08:00 2.00 MOB P PRE Make ready to move rig. warm up drivers, Road trip 08:00 - 17:00 9.00 MOB P PRE Move rig from DS1-17B to NK-12C (11 miles) 17:00 - 20:00 3.00 MOB P PRE Prepare wellhead for moving rig over. Wind gusting to 30 to 40 mph. Wind perpendicular to rig. Unable to open cellar doors. Pull ahead and open doors. Pull over well, close doors and secure. RIG ACCEPTED AT 2000 HRS 2/10/2004 20:00 - 00:00 4.00 MOB P PRE NU BOPE 2/1112004 00:00 - 08:00 8.00 BOPSURP PRE Pressure Test BOP. Jeft Jones, AOGCC wavered witnessing the BOP test, due to weather 08:00 - 18:00 10.00 RIGU N WAIT PRE WOW. Winds at 30-50 mph. -12F, -80 Wind chill. Next step is changing reels with Peak Crane. 25 mph wind limit. 18:00 - 00:00 6.00 RIGU N WAIT PRE WOW. Winds at 30-40 MPH wI WC -65 to 81 F 2/12/2004 00:00 - 06:00 6.00 RIGU N WAIT PRE WOW. Wind at 25-40 mph. 06:00 - 00:00 18.00 RIGU N WAIT PRE WOW. Wind at 20-35 mph. 2/13/2004 00:00 - 06:00 6.00 RIGU N WAIT PRE WOW, Winds gusting 10 to 40 mph T = -20F, WC = -70F 06:00 - 18:00 12.00 RIGU N WAIT PRE WOW, Winds at 28 gusting to 45 mph T = -15F, WC = -66F. Access road from East dock to Niakuk, blows in very quick. Using rig loader to keep road open. 18:00 - 00:00 6.00 RIGU N WAIT PRE WOW. Wind gusting to 30 to 50 mph 2/14/2004 00:00 - 06:00 6.00 RIGU N WAIT PRE WOW T = -19 F Winds gusting to 30 mph, WC = -60F 06:00 - 08:00 2.00 RIGU N WAIT PRE WOW. Wind dropped to 10-24 MPH. Called for Peak Crane. 08:00 - 11:00 3.00 RIGU N WAIT PRE Wait for Peak crane to arrive with reel of coiled tubing. 11:00-12:00 1.00 RIGU P PRE Spot Crane and reel of coiled tubing. RlU lines. Wind at 10-15 mph. -22F, -42 WC. 12:00 - 12:15 0.25 RIGU P PRE SAFETY MEETING. Review lifting plan, hazards and mitigation for picking reel from rig reel house and installing new reel of coiled tubing. 12:15 -14:15 2.00 RIGU P PRE Pick reel from reelhouse. MlU reel stand support bushings. Pick new reel and set on reel jacks in reelhouse. Set bushings into reel. Good tight fit. 14:15 - 18:00 3.75 RIGU P PRE MlU internal Coil connecter to pull coil to injecter head. Install reel hardline. Pull CT to injecter head. Installed new CT Pack-oft and new brass. 18:00 - 21:45 3.75 RIGU P PRE Pumped air through end of CT to check integrity of hardline. Stabbed Inject into pack oft. Dress CT and install BOT CT (Drifted CTC wI 1.44" Steel Ball) Open Well Pw = 0 psi. 21 :45 - 22:35 0.83 RIGU P PRE Pumped 5 bbl MEOH and 5 bbl2% KCL. PT hardlines to 4500 psi. Pumped CT Dart. At 60 bbl pumped, ilea plug in CT. Printed 31112004 9'5355 AM Page 2 ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From ~ To Hours Phase Task Code NPT 2/14/2004 21 :45 - 22:35 0.83 RIGU P 22:35 - 23:50 1.25 RIGU N 23:50 - 00:00 0.17 RIGU N PRE WAIT PRE FLUD PRE 2/15/2004 00:00 - 01 :00 1.00 RIGU N 01:00 - 02:00 1.00 RIGU N 02:00 - 02:15 0.25 RIGU N 02:15 - 03:15 1.00 RIGU N 03:15 - 03:30 0.25 RIGU N 03:30 - 04:00 0.50 RIGU N 04:00 - 05:00 1.00 RIGU N 05:00 - 05:14 0.23 RIGU N 05:14 - 06:15 1.02 RIGU P 06:15 - 07:00 0.75 RIGU P 07:00 - 08:45 1.75 CLEAN P 08:45 - 09:00 0.25 CLEAN P 09:00 - 10:00 1.00 CLEAN P 10:00 -12:30 2.50 CLEAN P 12:30 - 14:00 1.50 CLEAN P 14:00 - 15:20 1.33 CLEAN P 15:20 - 16:15 0.92 CLEAN P FLUD PRE FLUD PRE FLUD PRE FLUD PRE FLUD PRE FLUD PRE FLUD PRE FLUD PRE PRE PRE WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 16:15 - 16:45 0.50 CLEAN P WEXIT 16:45 - 19:45 3.00 CLEAN P WEXIT 19:45 - 20:10 0.42 CLEAN P WEXIT 20:10 - 22:05 1.92 CLEAN P WEXIT 22:05 - 00:00 1.92 STWHIP P WEXIT Start: 2/9/2004 Rig Release: 2/25/2004 Rig Number: N1 Spud Date: 11/1/1993 End: 2/25/2004 Description of Operations Approximately 3120ft from end. Pmax = 3700 psi and holding at 62 bbl pumped. RU to pump MEOH in the end of CT. Pumped 0.5bbl, Pressure up to 2200 psi Cycled between pumping MEOH on both ends ofCT Try and cir down CT. Volume total pumped = 71 bbl, CTvol = 72.1 bbl, ice in last 65 ft of CT. Pressured up to 3700 psi. Lowered level wind and steamed coil outside rig above roof. Working to thaw 1st 20 ft CT No luck Released pressure Cut off 43 ft CT off. Ice in CT after cutting 30 ft CT off. Rehead CTC, small groove in CT. Pull test CTC to 35k OK Pumped 9 bbl down CT, P inc to 4000 psi, still ice in CT. RU to pump MEOH through end of CT. Pumped 0.5 bbl, switch and pressured up on CT to 4000 psi. Pin 15 min = 3700 psi steady. PJSM on way forward Released Pressure. Make CT ready to RIH. RIH at 1.7 fpm steaming CT. CTP = 3500 psi. RIH. Pumping 120 deg F 2% down annulus while RIH At 90 ft in, CTP . dropped off to 100 psi. Cir down CT 1.58 bpm. POOH OOH, SD pumps, closed SV and unstab injector. Pumped Dart to catcher. Landed, SD and removed dart catcher. Recovered dart. Cir CT and warm up Insert 1.44" steel ball and displace. Ball landed at 66.7 bbls. M/U WF CTC. Failed press test. M/U again, Failed PT. M/U again Pull I Press test OK. SAFETY MEETING. Review procedure, hazards and mitigation for M/U Milling I MWD BHA. M/U BHA #1, 3.80" mill, string reamer, WF straight motor, Sperry MWD, WF MHA and CTC. BHA = 49.87 FT. RIH. Take returns to Tiger tank. Dispose of retums. RIH clean to XN nipple at 10,841 ft. Tagged XN on depth, no correction. Milled XN nipple. 2.7/2.7 bpm, 2900 psi, Milled thru it in 20 min. Low woe, 100 psi motor work. Ream up and down 4 times. RIH at 90 fpm, 2.5 bpm, 2200 psi. Clean liner. Up wt at 14,000 ft = 41K. RIH clean to 16,050'. Stop at 16,050 ft. Up wt = 47 K. Own WT = 16K. Log I ream down from 16,050 ft with Sperry MWD GR. 2.5 bpm, 2600 psi, 300 FPH. Logged down to 16,350 ft. Stop and made -7 ft CTD GR Tie-in correction. Tie-in Log was DEN/NEU/GR OF 02122/01. Backream up to 16,040 ft at 10 FPM. 2.5 bpm, 2700 psi, 43K up wi. Clean liner, no motor work. RIH and flag CT at 16,000 FT EOP. [49.9 ft BHA]. POOH with Logging I Reaming BHA. circ at 2.5/1.85 bpm, 2500 psi. PJSM LD Milling BHA and PU Packer setting BHA. Pump dart Vct = 68.7 bbl RIH wI WFT WS-R-BB Packer assy. Wt Check, up = 34.5K PrInted. 31112004 9.5355 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours .Task Code NPT Phase 2/15/2004 22:05 - 00:00 1.92 STWHIP P WEXIT 2/16/2004 00:00 - 01 :25 1.42 STWHIP P WEXIT 01:25 - 01:33 0.13 STWHIP P WEXIT 01:33 - 01:42 0.15 STWHIP P WEXIT 01 :42 - 02:34 0.87 STWHIP P WEXIT 02:34 - 02:45 02:45 - 06:00 06:00 - 09:00 0.18 STWHIP P 3.25 STWHIP P 3.00 STWHIP P WEXIT WEXIT WEXIT 09:00 - 11 :00 2.00 STWHIP N WAIT WEXIT 11:00-12:45 1.75 STWHIP N WAIT WEXIT 12:45 - 13:00 0.25 STWHIP P WEXIT 13:00 -14:30 1.50 STWHIP P WEXIT 14:30 - 17:15 2.75 STWHIP P WEXIT 17:15 - 19:00 1.75 STWHIP N DPRB WEXIT 19:00 - 19:33 0.55 STWHIP N DPRB WEXIT 19:33 - 20:00 0.45 STWHIP N DPRB WEXIT 20:00 - 21 :55 1.92 STWHIP N DPRB WEXIT 21 :55 - 23:00 1.08 STWHIP P WEXIT 23:00 - 23:15 0.25 STWHIP P WEXIT 2/17/2004 23.15 - 00:00 00:00 - 01 :20 WEXIT WEXIT 0.75 STWHIP P 1.33 STWHIP P Page 3 t8 Start: 2/9/2004 Rig Release: 2/25/2004 Rig Number: N1 Spud Date: 11/1/1993 End: 2/25/2004 Description of Operations up, RIH Wt Check dwn =15k RIH to 16,000 ft and corrected to flag (= + 6.3 ft) PU wt = 53k. RIH logging down at 30 fpm to setting depth 16260 ft ( btm packer) Ref Log Sperry Sun dated 2-15-2004 PUH 6.3 ft, (Didn't PU string 100%) to get to ball drop postion, Drop 5/8" ball to set packer Displaced ball at Q = 1.5 bpm using 20 bbl High Vis Biozan pill. Volume pumped 64.7 bbl pressure inc. Pmax = 4000 psi. Allow Pkr to set. Taking orientation survey with Sperry's ESS before pulling off. Lost 300 psi PUH. Released from packer with 15k over and CTP of 3000 psi POOH logging with SWS MGR, CCL to 15,890 ft POOH, filling the hole down back side UO BHA. Down load Sperry and SWS data. Sperry shows Packer lug at 325 deg. Tray program TF will be at 320 deg. SWS Memory GRlCCL shows bottom ofWF packer at 16,264 ft. Wait on orders for whipstock space out. Told to add 15 ft pup joint to place top of whipstock at 16,232.6 ft. Casing collar is at 16,241ft. Wait for WF to deliver whipstock. SAFETY MEETING. Review procedure, hazards and mitigation for M/U WF whipstock BHA. M/U WFT whipstock BHA with latch, 15.66 ft spacer pup jt, whipstock and running tools. BHA = 44.36 ft. 2 SWS RA tags set in Whipstock 7.83 ft from top of whipstock. ' Lug set to position topside of tray at 320 deg. [40L]. RIH with WF whipstock on running tools. RIH clean to 10,818 ft. Set down several times, increase pumps, Pull up hole 300 ft, RIH set down again several times. Skirted Running tool has square edge that may be setting up on a profile in the Baker S-3 Packer at 10,799'. Skirted running tool is 28' from bottom of BHA. [10,818-28=10,790'] This area has drifted a 3.80" mill and a 3.56" WF Packer. POH to check BHA for marks. LD WS BHA. Leading edge on Overshot I box tap has a square shoulder and markered MU WFT WS and tapered OS I Box tap (45 deg bevel) RIH with WS to 10600', Wt check = 32k up RIH past jewerly in tail pipe. RIH to EOP flag 16,000 ft (16,053 ft) Corrected to 16,044.4 ft PU wt 54k-up RIH to latch WS Tagged at 16261' w/5k, latched, worked 3 times Pulled up to 66k (12k over) and sheared off. BOTTON OF WFT WSRBB PACKER @ 16265' (from Tie in) TOW @ 16,233.62 ft BOTTOM OF RAMP@ 16,242.69' RA MARKER @ 16,241.45 ft (2) ORIENTATION @ 40 DEG LEFT HIGHSIDE POOH POOH to 7298' Printed 3/112004 953 55 AM BP EXPLORATION Operations Summary Report Page 4 t8 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK~12 NK~12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/9/2004 Rig Release: 2/25/2004 Rig Number: N1 Spud Date: 11/1/1993 End: 2/25/2004 Date From - To Hours Task Code NPT Phase Description of Operations 2/1712004 01 :20 - 02:00 0.67 STWHIP P WEXIT Gas to surface from bottoms up, SD, checked flow, OK, lined out circulating gas and contaminated fluid through gas buster. Circulated 26 bbl contaminated mud to solids tanks. CT displacement correct 02:00 - 03:00 1.00 STWHIP P WEXIT Re-set Trip Sheet to 244 bbl. POOH. 03:00 - 06:00 3.00 STWHIP P WEXIT LD BHA, 2-3/8". CT crimped at 4' above CTC. Cut off 6 ft CT, dress CT, rehead. Pull tested to 35k. PT to 3800 psi 06:00 - 06:45 0.75 STWHIP P WEXIT MIU 3.80" Window Milling BHA with 3.80" HC diamond window mill, 3.79" HC diamond string mill, WF motor, 2 jts PH6, WF MHA and CTC. BHA = 83.18'. 06:45 - 09:45 3.00 STWHIP P WEXIT RIH with BHA #4, window milling BHA. RIH clean to top of whipstock. Tag whipstock at 16,231 ft. Correct to 16,234', [+3 ft CTD]. Flag CT at 16,234 ft. 09:45 - 10:45 1.00 STWHIP P WEXIT Milling 3.80" window in 4.5" liner with 2# Biozan. 2.5 I 2.5 bpm, 2400 - 2800 psi, 2500# woe, 46K up wt, 13K dwn wi. Milled to 16,234.8 ft. No stalls. 10:45 - 12:30 1.75 STWHIP P WEXIT Milling 3.80" window. 2.5 I 2.5 bpm, 2350 - 2800 psi, 3-4K woe, Milled to 16,236 ft. No stalls. 12:30 -13:30 1.00 STWHIP P WEXIT Milling 3.80" window. 2.5 12.5 bpm, 2350 - 2800 psi, 4-5K woe, Milled to 16,237 ft. No stalls. 13:30 -14:45 1.25 STWHIP P WEXIT Milling 3.80" window. 2.5 / 2.5 bpm, 2350 - 2800 psi, 4-5K woe, Pick up clean and backream window. Ream down. Milled to 16,239 ft. No stalls. 14:45 -15:45 1.00 STWHIP P WEXIT Milling 3.80" window. 2.5 I 2.5 bpm, 2350 - 2800 psi, 4-5K woe, Milled to 16,239.5 ft. Motor stalled. Pick up clean and backream window. Ream down. Milled to 16,240'. Exit liner into formation @ 16239.5'. 15:45 - 16:45 1.00 STWHIP P WEXIT Mill 10' formation from 16240' to 16250' with 2.5/2.5bpm, 235012800psi, 3-4k woe & 10fph ave ROP. Tentative window depths are: Towsrrow = 16234'; BOW = 16240', RA PIP Tag = 16241.4'. 16:45 - 17:45 1.00 STWHIP P WEXIT Backream/ream window/rat hole & make several dress/drift passes with & without pumping. Window looks clean. Meanwhile swap wellbore to 8.6ppg reconditioned flopro mud. Recovering metal shavings on magnets. 17:45 - 20:40 2.92 STWHIP P WEXIT Paint EOP flag @ 15717' & POOH window milling BHA#4. 20:40 - 21 :30 0.83 STWHIP P WEXIT LD BHA. Window mill 3.79", string mill 3.78". 21 :30 - 23:45 2.25 STWHIP P WEXIT Pump MeOH back into coil to FP. Cut off Weatherford CTC. Dress pipe and attempt to install DS CTC. Hammer on DS dim pier to within 2" of required location. Unable to get dimpler on any further. Pull off dim pier with 26K Ibs injector pull. Caliper pipe. Pipe is egged. OD varies from 2.37" to 2.42". While working on CTC, replace threaded connections on choke manifold with new welded connections. 23:45 - 00:00 0.25 STWHIP P WEXIT RU to test BOPE. 2/1812004 00:00 - 05:00 5.00 BOPSURP PROD1 Test BOPE to 250/3500 psi as per AOGCC regs and BP policy. Witness of test waived by Chuck Sheve of AOGCC. 05:00 - 06:00 1.00 DRILL N SFAL PROD1 File & round-off CT tip to uniform OD. 06:00 - 07:00 1.00 DRILL P PROD1 Install DS CTC. Pull test to 35k. PT to 3500psÎ. Line up & PT inner reel valve to 35OOpsÎ. 07:00 - 08:30 1.50 DRILL P PROD1 PJSM. M/U drilling BHA #5 with BHl1.8deg extreme motor, Sperry PWD/MWD/GR (taper-lock style) & new HTC RWD 3-3/4" x 4-1/8" bicenter bit #3. M/U injector. Printed 31112004 953'551W1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 5" BP EXPLORATION Operations Summary Report NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 2/18/2004 08:30 - 11 :45 From - To Hours 3.25 DRILL Task Code NPT PROD1 11:45-12:10 12:10 - 14:25 14:25 - 15:20 15:20 -15:30 15:30 - 15:35 15:35 -15:50 15:50 - 16:00 16:00 - 16:35 16:35 - 17:15 17:15 -17:30 17:30 - 18:15 18:15 - 00:00 2/19/2004 00:00 - 01 :45 01:45 - 02:15 02:15 - 03:20 03:20 - 03:45 03:45 - 06:45 06:45 - 07:25 07:25 - 08:00 08:00 - 08:30 08:30 - 09:15 09:15 - 09:30 09:30 - 10:00 15:15 - 17:00 0.42 DRILL 2.25 DRILL 0.92 DRILL 0.17 DRILL 0.08 DRILL 0.25 DRILL 0.17 DRILL 0.58 DRILL 0.67 DRILL 0.25 DRILL 0.75 DRILL 5.75 DRILL 1.75 DRILL 0.50 DRILL 1.08 DRILL 0.42 DRILL 3.00 DRILL 0.67 DRILL 0.58 DRILL 0.50 DRILL 3.08 DRILL 1.00 DRILL 1.75 DRILL P P P P P P N P P P N P P P P P P P P P P P P P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 2/9/2004 Rig Release: 2/25/2004 Rig Number: N1 Spud Date: 11/1/1993 End: 2/25/2004 Description of Operations RIH BHA #5. SHT MWD & orienter @ 1300' - OK. RIH to EOP flag. Subtract 3.5' from CTD. Continue RIH & tag TD @ 16248'. Correct CTD to 16250'. Orient TF to 50L. Drill to 16290' with 55L TF, 2.6/2.6bpm, 3500/3680psi, 20fph aye ROP. Observe higher than normal GR MWD readings. Drill to 16316' with 45L TF, 2.6/2.6bpm, 3450/3600psi, 3 h aye ROP. Attempt to float off btm survey - survey not comin PUH into window to rectify SCR overload proble Rectify SCR problem. PUH 16160' for GR tie-in log. Log down GR & tie-in wellbore to Geol PDC log. RBIH to 16260'. Log down RA PIP tag & add to CTD. Corrected window depths are: TOWSrrOW 16235'; BOW = 16241', RA PIP Tag = 16243'. RBIH & tag m @ 16320'. Orient & drill to 16335' with L TF, 2.6/2.6bpm, 3450/3600psi, 30fph aye ROP. Attempt to float off bt urvey - still not able to. Orient & drill to 163 'with 45L TF, 2.6/2.6bpm, 3450/3600psi, 30fph aye ROP. Drill from 16, 'to 16,450' at 2.5/2.5 3,500/3,700 psi. Erratic detection f m MWD. Unable to get full surveys. Short surveys re OK while drilling. Drill 16,475'. Still not able to get full survey off bottom. C tinue using short surveys. iper trip to window. Hole in good condition. Attempt to get full survey at various spots, no good. Orient to 90R. Drill at 2.5/2.5 3,400/3,700 psi. Orient to 45L. Drill at 2.5/2.5 3,400/3,700 psi. Drill to 16560'. Orient TF around to 90L. P/U wt = 40k, SIO wt = 15k. Drill to 16589' with 60L TF, 2.5/2.5bpm, 3550/3850psi, 50fph aye ROP & 3k woe. Not getting any MWD surveys. Wiper trip to window & switch mud pumps to see if MWD surveys will improve. RBIH to 16352'. Shoot off btm survey - no luck. Creep in hole & reshoot surveys - still no luck. Orient TF around to 90L. P/U wt = 39k, S/O wt = 13k. PVT = 322bbls. Drill to 16600' with 80L TF, 2.4/2.4bpm, 3400/3750psi, 25fph aye ROP & 3k woe. Getting on-the-fly btm surveys again. Drill to 16625' with 90L TF, 2.6/2.6bpm, 3700/3900psi, 25fph ave ROP & 2k WOB. Geo does not want to drill any further without full surveys for azimuth confirmation. Decide to POOH to P/U RES tool & C/O MWD. Paint EOP flag @ 16000' & POOH drilling BHA#5. DOH. PJSM. SIB injector. Flush & UD BHA. Bit gauge 2/3/1 with some abrasive wear on the hole opening blades possibly due to drilling 1-2% Chert/Pyrite. M/U drilling BHA #6 with new BHI 1.5deg Xtreme motor & new HTC RWD 3-3/4" x 4-1/8" bicenter bit #4, new Sperry PWD/MWD/GR-RES, orienter & MHA. Scribe tools & initialize Printed 31112004 9 53 55 AM WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 3;)3 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' doey Burton / deni Thompson ProActive Diagnostic Services, Inc. P. O. Box 13G9 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR CD-ROM FILM COLOR Open Hole I I 1 NK 12b 4-01-03 Res. Eval. CH I,~0.~~) I 1 Mech. CH 1 Caliper Survey Print Name: ProActive Diagnostic Services, Inc., 3 IO K Street Suite 2OO,,.a~nchorage~.',A.~ 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog:com Website: www.memorylog.com Permit to Drill 2010150 MD 16550 .~i TVD DATA SUBMITTAL COMPLIANCE REPORT 411612003 Well Name/No. PRUDHOE BAY UN NIA NK-12B Operator BP EXPLORATION (ALASKA) INC 9351 /" Completion Dat 3/19/2001 ~ Completion Statu 1-OIL APl No. 50-029-22414-02-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_.~o Sample N_~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Med, ja Fmt (data taken from Logs Portion of Master Well Data Maint) Name Log Log Scale Media Run No Interval Start Stop OH I Dataset CH Received Number 10038 MD Vision Den/Neu 2 TVD Vision DEN/Neu 2 Cl~Vision RES 2/5 e~V~sion Res 2/5 11092 16550 FINAL 11092 16550 FINAL 15152 16550 FINAL 15152 16550 FINAL 11092 16550 FINAL 11092 16550 Open 511112001 oh 5/15/2001 /_~0038 oh 5/15/2001 oh 5/15/2001 oh 5/15/2001 oh 5/15/2001 Comments 11092-16550 b,~-I' I" 11092-16550 Digital Data (~~ · / 15152-16550 BL, Sepia ~ 15152-16550 BL, Sepia 11092-16550 BL, Sepia 11092-16550 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R ~.c~.iv~.d '~ Daily History Received? (~ I N Formation Tops ~)/N Comments: Compliance Reviewed By: Date: STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3952' SNL, 995' WEL, SEC. 36, T12N, R15E, UM At top of productive interval 797' NSL, 1663' WEL, SEC. 23, T12N, R15E, UM At effective depth 1011' NSL, 1835' WEL, SEC. 23, T12N, R15E, UM At total depth 1079' NSL, 1889' WEL, SEC. 23, T12N, R15E, UM [] Plugging [] Time Extension [] Perforate [] Pull Tubing [] Variance [] Other J [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service X = 721567, Y = 5979863 X = 715324, Y = 5989714 X = 715146, Y = 5989923 X = 715090, Y -- 5989989 6. Datum Elevation (DF or KB) RKB = 51.88' 7. Unit or Property Name 8. Well Number NK-12B 9. Permit Number 201-015 10. APl Number 50- 029-22414-02 11. Field and Pool Niakuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 16550 feet Plugs (measured) 9351 feet 16453 feet Junk (measured) 9307 feet 36' of 47' Tool, Gun w/top and bottom rollers (06/01 Casing Structural Conductor Surface Intermediate Production Liner ~ength ' Size Cemented MD TVD 80' 20" 280 cu ft Arctic Set (Approx.) 80' 80' 4724' 10-3/4" 435 cu ft Class 'G' 4764' 4144' 11054' 7-5/8" 806 cuft Class 'G' 11092' 7440' 5701' 4-1/2" 919 cu ft LiteCrete, 272 cu ft 'G' 10849' - 16550'/~ 7317' - 9351' Perforation depth: measured true vertical 9157'-9167', 9165'- 9177', 9173'-9183', 9177'- 9187', 9251'-927~pR (} 1 ~0D3 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10855' ^l~ska0tl&G~C0ns. Cc.~ Packers and SSSV (type and measured depth) 7-5/8" x 4-1/2" Baker 'ZXP' packer at 10849'; 7-5/8" x 4-1/2" Baker 'S-3' packer at 10799'; 4-1/2" HES 'CP-2' TRSSSV Nipple at 2023' // 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 4. Estimated date for commencing operation April 20, 2003 / 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Mary Endacott, 564-4388 I15. Status of well classifications as: [] Oil I-I Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is Signed Ma~ and best of my knowledge CT Drilling Engineer Date Conditions of Approval: Notify Commission ~o representative may witness ~ Plug integrity .~ BOP Test X Location clearance Mechanical Integrity Test .X~ Subsequent form requir~110- order of the Commission ~'~ ~~..-~. A-'~'.... Form 10-403 Rev. 06/15,88RBDMS BFL' UKII INAL ,., Approval No. <;:~"~'" I ) I Commissioner Date 0 ~/>/'~1 APR 2 ?~ Submit In Triplicate A', , ObP To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: M.S. Endacott CTD Engineer Date: March 28, 2003 Re: CTD Sidetrack of well NK-12B NK-12B is scheduled for a through tubing sidetrack with the Nordic 1 coil drill~_, rig. The sidetrack, NK-12C, will kick off from a window milled in Zone 4MFS and will target Zone 4BB-4MFS. The lower set of perfs will be 'isolated by a cast iron bridge plug and the new sidetrack will be completed with a fully cemented liner across the upper perfs. The following describes work planned to prep for sidetracking and is submitted as an attachment to Form 10- 403. A schematic diagram of the proposed sidetrack is attached for reference. 1. Gas lift mandrels have been dummied off. 2. MIT,~' ~,~ 3. CIBP will be set at 16,320'. ' 4. Whipstock will be set at 16,310' ~ Steps 3-4 will be performed with the drilling coil, scheduled on April 20, 2003. M.S. Endacott CTD Drilling Engineer CC: Well File Terrie Hubble TREE = 4-1116" 5M CIW NK 12B S .OT S; ~,CTUATOR= BAKERC ~ 'ID (~ 16420' C'rM 02128102. KB. ELEV = 51.88" KOp= 1300' MaxAngle= 79 ~ 13~i 2023' H4-1/2"HES CP-2TRSSSV NIP, ID=3.813" I Datum IVD= . 15543'. JI ! L ~S LIFT MANDRELS Datum 'IV D = 8800' SS 110-314"CSG, 45.5#,NT-80SBTC, ID=O.950"H 4764' . I "~'~-'~"~""~"~"~~~'~'T~'~~ DATE ~ ~ 2 7098 5471 ! 59 CAMCO DMY NT 0 '08~23~02 I I--~ ~0776' I--14-1/2" .ES X UP, ~D -- 3.813" I .E~OP, A~O. SUMMA~ ~ ~--I ,o84~' HT-.~8"X4-1,Z'SAKE~ZX,~r~ID:4.~:~" I REFLOG: TCPPEI~ [~ ~' I'~ ANGLEAT TOPPERF: 60@ 16135' 10869' BAKER7" X 5" HlVlC LNR HGR, D =4.938" Note: Refer to Production DB for historical perf data SIZE SPF' INTB:~VAL . OpnlSqz DATE I I / I I 2-718" 6 16135- 16155 ~ O 10/15/01 2-71~' 6 16167- 16187 0 10/15101 2-718" 6 16175- 16195 O 05/12101 INSCC' 14-1/2'' LKP,, 12.6#, L-80 HYD 521, ID= 3.958" DATE : REV BY COIVlVIENTS DATE REV BY COIVlVIENTS FRUDHOE BAY uNrr ORIGINAL COIVPLErlON 08/04/01 3N/TP ELIVD ON XN NPR_E WB.I~ NK-12B 03119/01., CH/KAK RIG SIDEI'RACK 10/15/01 CAO/Ilh ADD PERFS PERMITNo: 2010150 05108/01 , pcr UPDATED 03/11/02 DAVI~h MILL aDP APINo: 50-029-23414-02 05112/01 ~ ATD/tlh ADDPERFS 08/31/02 DTR/'[P GLV C/O SEC36, T12N, R15E, 1327' FSL & 996' FEL 08126101i JLG/tlh SETClBP :11/28/02 TN/TP NII=PLEIDCORRECTION 07113101 I JP/KAK PERFS & FISH ; BP Exploration {Alaska) PERI=ORATION SUMMA RY REF LOG: TCPPER= ANGLEAT TOPPERF: 60 @ 16135' Note: Refer to Production DB for historical perf data SIZE SPF INT~VAL Opn/Sqz DATE 2-7/8" 6 16135- 16155 O 10/15/01 2-7/8" 6 16150 - 16175 O 06/04/01 2-7/8" 6 16167- 16187 O 10/15/01 2-7/8" 6 16175- 16195 O 05/12/01 2-11Z' 6 16330- 16390 O 03/15/01 DATE REV BY COIVlVIENTS DATE REV BY COIVlVIENTS ORIGINAL COIVPLETION 08/04/01 '[N/TP ELIVD ON XN NPR. E 03119101 CH/KAK RIG SIDErRACK 10/15/01 CAO/~lh ADD PERFS 05108101 pcr UPDATED 03/1 1/02 DAVI~h MILL (]BP 05112/01 ATD/tlh ADDPERFS 08/31/02 DTR/'[P GLV C/O 08126101 JLG/tlh SET ClBP : 11/28/02 TN/TP NII=PLEID CORRECTION 07113101 JP/KAK PERFS & FISH TREE = 4-1116" 5M ClW 'WFI LHEAD = 13-518" 5M FMC ACTUATOR = BAKER C "i~§'7~'~'"; ........................................................... 51.88, BF. ELEV = KOP = 1300' Max Angle = 79 @ 13722" Datum MD = 15543' Datum 'rVD = 8800' SS 110-3/4" CSG, 45.5#, NT-80S BTC, ID = 9.950" I--~ 4764' IMinimum ID = 2.377" @ 16,650' 2 7/8" ST-L pin ID or 2.35" @ liner top packer seal assy PERFORATION SUMMARY REF LOG: TCPPERF ANGLE AT TOP PERF: 60 ~ 16135' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 2-718" 6 16135- 16155 O 10115101 2-718' 6 16150- 16175 O 06104101 2-7~8" 6 16167- 16187 O 10115!01 2-718" 6 16175- 16195 O 05112101 2-112" 6 16330 - 16390 O 03115/01 14-1/2" TBG, 12.6#, L-80 IBT-M, ID = 3.958" I--~ 10855' PROPOSED 7-5/8" CSG, 29.7#, NT-95-HS, I---~ 11092' NSCC, ID = 6.875" I 4 1/2" whipstock with RA tag I--~ 16310' 16320' 16453' 16550' 14-1/2" LNR, 12.6#, L-80 HYD 521, ID = 3.958" i (" I'D @ 16420' CTM 02/28102. FETY NOTES: CIBP MILLED & PUSHED TO 2023' I-~4-1/2" HES CP-2 TRSSSV NIP, ID = 3.813" GAS LIFT MANDRELS 10778' 10799' 10822' 10642' 10855' I 10854" 10849' 10869' I--~4-1/2" HES X NIP, ID= 3.813" 1-17-5/8" x 4-1/2" BAKER S-3 PKR, ID = 3.850" 4-112" HES XN NIP, ID MILLED TO = 3.8" I--~4-1/2" WLEG I I--~ELMD'ir LOGGED 06104101 I 1-17-5/8,, x 4-1/2" BAKB:~ZXPPKR, ID=4.938" I I-I BAKER 7"X 5" HMC LNR HGR, ID: 4.938" 7-5/8" MILLOUT WINDOW 092' - 11104' ' 7 15900 I--ITOL(-89 0ss)&topoflinercmt I 16725" crossover 17450' DATE REV BY COMMENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 08/04/01 TN/TP ELMD ON XN NIPPLE 03/19101 CH/KAK RIG SIDETRACK 10/15/01 CAO/tlh ADD PERFS 05108/01 pcr UPDATED 03/11102 DAV/tlh MILL CIBP 05/12/01 ATD/tlh ADD Pffi=,FS 08/31/02 DTR/TP GLV C/O 06/26/01 JLG/tlh SET CIBP 11/28/02 TN/'rP NIPPLE ID CORRECTION 07113/01 JP/KAK PERFS & FISH 03/28/03 MSE PROPOSED CTD SIDETRACK PRUDHOE BAY UNIT WB.L: NK-12c PERMIT No: APl No: 50-029-23414-03 SEC 36, T12N, R15F_, 1327' FSL & 996' FEL BP Exploration (Alaska) ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 3952' FNL, 995' FEL, Sec. 36, T12N, R15E, UM At top of productive interval 4481' FNL, 1663' FEL, Sec. 23, T12N, R15E, UM At effective depth 4409' FNL, 1722' FEL, Sec. 23, T12N, R15E, UM At total depth 4201' FNL, 1889' FEL, Sec. 23, T12N, R15E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic__ Service_ (asp's 721567, 5979863) (asp's 715324, 5989715) (asp's 715263, 5989786) (asp°s 715090, 5989989) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Niakuk Unit 8. Well number NK-12B 9. Permit number / approval number 201-015 10. APl number 50-029-22414-02 11. Field / Pool Niakuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4712' Production 11040' Liner 5701' 16550 feet Plugs (measured) 9351 feet 16250 feet Junk (measured) 9213 feet Size Cemented 20" 280 c.f. Arcticset 10-3/4" 435 c.f. Class 'G' 7-5/8" 806 c.f. Class 'G' 4-1/2" 921 c.f. LiteCrete, 286 c.f. Class 'G' CIBP set @ 16250'. (09/29/2001) EL Guns left in hole as fish @ 16417' SLM. Measured Depth True Ve~ical Depth 132' 132' 4764' 4144' 11092' 7440' 10849'-16550 7317'-9351' Perforation depth: measured Open Perfs 16135'- 16195', Perfs below ClBP 16330'- 16390'. true vertical Open Perfs 9159' - 9187', Perfs below .ClBP 9251' - 9279'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, NT-80 TBG @ 10849'. 4-1/2" Tubing Tail to 10855'. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" Baker ZXP Packer @ 10849'. 4-1/2" HES CP-2 TRSSSV Nipple @ 2123'. NOV 0 ? ZOO1 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure AJasl(~ 0i~ & Go,s Cons. CommJsa0 Anchorage 14. Prior to well operation 10/10/2001 Subsequent to operation 10/20/2001 Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-in Well Shut-in Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · ORIGINAL Date October 24. 2001 Prepared by DeWayne R. S=hnorr 564.5174 SUBMIT IN DUPLICATE 09/29/2001 10/14/2001 10/15/2001 09/29/01 10/14/01 10/15/01 NK-12B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DRILL-POST WORK: DRIFT TUBING W/2 7/8 DUMMY GUN DRILL-POST WORK: ADD PERF DRILL-POST WORK: ADD PERF EVENT SUMMARY DRIFT TUBING W/2 X 7/8 DUMMY GUN TO 16,250' WLM. UNLOAD IA AND TUBING WITH GAS LIFT, WAIT ON WELL TO UNLOAD. SHOOT FLUID LEVELS, TUBING = 10373', IA=10450', RIG BACK FOR NIGHT CONTINUE IN MORNING. ***WELL SHUT IN *** PERF 16167'-16187' & 16135'-16155', 4-10' GUN RUNS, CORRELATED TO ANADRILL VISION DEN/NEUTR ***FINAL*** LOG DATED 22-24-FEB-2001, PER TOWN PE. SET DOWN AT 12150' AND 12600', PULL HEAVY AFTER RUN # 2-3- 4, CHARGE DATA: 2906 PJ 27.7", .36" EH, 15 GMS, 2 7/8 6SPF CORRELATED WITH GR/CCL. ***DSO TO BOL *** FLUIDS PUMPED BBLS 3 DIESEL FOR TESTING SURFACE PRESSURE EQUIPMENT ( 3 TESTS 12 METHANOL WATER 15 TOTAL 10/15/2001 ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED USING 2-7/8" HSD, PJ, 6 SPF, 60 DEGREE PHASING & RANDOM ORIENTATION. 16135' - 16155' 16167' - 16187' Page 1 ,.. , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_X RKB 51.88 feet 3. Address ExploratoryM 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchora~le, AK 99519-6612 Service~ Niakuk 4. Location of well at surface 8. Well number 3952' FNL, 995' FEL, Sec. 36, T12N, R15E, UM (asp's 721567, 5979863) NK-12B At top of productive interval 9. Permit number / approval number 4481' FNL, 1663' FEL, SEC 23, T12N, R15E, UM (asp's 715324, 5989715) 201-015 At effective depth 10. APl number 50-029-22414-02 At total depth 11. Field / Pool 4201' FNL, 1889' FEL, SEC 23, T12N, R15E, UM (asp's 715090, 5989989) Niakuk Oil Pool 12. Present well condition summary Total depth: measured 16550 feet Plugs (measured) ClBP set @ 16300' MD on 6/26/2001. true vertical 9351 feet Effective depth: measured 16300 feet Junk (measured) EL Guns left in hole as fish @ 16417' SLM. true vertical 9237 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" 280 cubic feet Amticset 80' 80' Surface 4712' 10-3/4" 435 cubic feet Class G 4764' 4144' Production 11040' 7-5/8" 806 cubic feet Class G 11092' 7440' Li nar 5701' 4-1/2" 184 bbls 12 ppg LiteCrete & 51 bbls 15.8 ppg Class G 16550' 9351' Perforation depth: measured 16150' - 16195'; (Isolated below ClBP 16330' - 16390'). true vertical 9165' - 9187'; (Isolated below CIBP 9251' - 9279'). RECEIVED Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tubing @ 10855' MD. AUG 1 2.001 Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" Baker 8-3 PACKER @ 107ge' MD; 7-5/8" X 4-1/2" Baker ZXP PACKER @ 1086g' MD. 4-1/2" HES CP-2 TRSSSV Nipple @ 2023' MD. Alaska 0il & Gas Cons. Commission 13. Stimulation or cement squeeze summary Anchorage Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (4/27/01) 467 3234 0 - 534 Subsequent to operation (shut in) 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Niakuk Surveillance Engineer Date Dwight Warner~ ~/ I Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · ORIGINAL,., SUBMIT IN DUPLICATE NK-12B DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS & SET CIBP Date Event Summary 4/12/2001: 5107/2001: 5/12/2001: 5/26/2001: 6/04/2001: 6/07/2001 - 6/09/2001: 6/16/2001: 6/1712001: 6/26/2001: 6/30/2001: 7/15/2001: 7/20/2001: 7/30/2001: Ran SBHP/FBHP Survey. Performed a Brush/Flush w/Hot Oil & Diesel/Xylene. Worked down to 16348' SLM. MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & recorded Jewerly Log f/11000' to 10650'. Flowed well for underbalance. Shot 20' of add perforations f/: 16175' - 16195' MD (Zone 2C3) Used 2-7/8" HSD carriers & all shots @ 6 SPF, random orientation, & underbalanced press. POOH w/guns - ASF. Ran 2nd gun run but could not get below 12810'. RD. RIH w/2-7/8" DG & tagged PBTD @ 16355' SLM. No trouble getting through 12810'. MIRU ELU. PT'd equip. RIH w/perf guns & did tie-in. Shot 25' of add perforations f/: 16150' - 16175' MD (Zone 2C3) Good shot indication. Used 2-7/8" PJ carriers & all shots @ 6 SPF, random orientation, & underbalanced press. POOH -. guns left in hole as fish. RD ELU. Made numerous attempts to retrieve fish w/no success but to push fish downhole to 16410' SLM. Made another fishing attempt - unsuccessful. Fish @ 16417' SLM. Placed well BOL w/GL & performed welltest. Oil = 233 bbls, Water = 52 bbls, FM Gas = inconclusive, FTP = 536 psi, duration = 6.4 hrs. MIRU CTU. PT'd equip. RIH & set a ClBP in the 4-1/2" liner @ 16300' CTM. This was to isolate the open perforations located @: 16330' - 16390' MD (Kuparuk Zone) Tagged CIBP & POOH. FP'd well. RD CTU. Ran SBHP Survey. RIH w/3.20" CENT / Sample Bailer & drifted to 16254' SLM. RIH to 12770'. Attempted to run Borax RST log but unable to pump into FM. Attempted to drift well but hit hydrate plug @ 760'. NK-12B is currently shutin. Future wellwork options are being contemplated. A Hot Oil treatment is scheduled for the near future. Page 1 NK 12B I WELLI-EAD= 13-5/8" 5M FMC ACTUATOR= BAKER C KB. ELEV = 51.88' BF. ELEV = 'i~=Max Angle = 79 ~ 13722'13°°' i ~-~-- - '1 202a' H4-112"HES C~-2T.SSSV .P.,D =3.~38" I i Datum MD = i'~00~ . I Datum TV~s-- 8800' i ~ c~s L~._.____~.D.a_S ,10-3/4"CSG, 45.5#,NT-BOSBTC, ID=9.950" : J s~T TV~ D~ TYPE' VLV LATCH PORT DATE i ' 3 i3239 3037 40 KBG-2LS DOME NTG 1.0" 03/25/01 Minimum ID = 3.725" @ 10843' ~ ~ 2 17098 5471 59 KBG-2LS DOME NTG 1.0" 03/25/01 4-1/2" HFS XN NIPPLE ~ 1 10711 7249 59 K~-2[S SO NTO 1.0" 03/25/01 I I----I lOWS' H*l/2' ms x aP, .D -- 3.613" I I I----q 10~' 1-14-1/2".~s x~ ~P. ~D--3.725"I PERFORATION S UMIVIA RY REF LOG: TCP PERF ANGLEATTOPPI~F: 62 I 7-5/8" I~ILLOHTWNDOWl1092'- 11104' I No~: Refer to ~oduction DB for historical per[ data SIZE SPF ~NTERVAL Opn/Sc{z DATE 2-7/8" 6 16150-16175 0 06/04/01 ~-----~-------~ 11052' HTOPOFBAKa~VVHImTOCK I 2-1/2" 6 16330-16390 0 03/1~01 I~~s ~DaE~.m I I I7~/~'aS~,29.7#,NT95 HS, NSOC, D=6.875" H 15024' ~ 14'1/2''~"~ 12.6#, L-80 HYD 521,.0152 bpf, ID = 3.958" DATE REV BY COMMI~ITS DATE REV BY COMIVENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 07/13/01 JP/KAK PERFS &FISH WELL: I~K-12B 03/19/01 CH/KAK RIG SIDETRACK 08/04/01 TN/TP B. MD ON XN NPPLE PEI~VlIT No: 201-015 05/08/01 pcr UPDATED APl No: 50-029-23414-02 05/12/01 ATD/tlh ADD PERPS SEC36; T12N; R15E1327' FSL99~ FB. 06/26/01 JLG/IIh SET CIBP BP Exploration (Alaska) PERFORA'nON SUMMA RY REF LOG: TCP PERF ANGLEATTOP PI~F: 62 Note: Refer to Production DB for historical per[ data SIZE SPF INTERVAL Opn/Sc{z DATE 2-7/8" 6 16150 - 16175 O 06/04/01 2-7/8" 6 16175 - 16195 O 05/12/01 2-1/2" 6 16330 - 16390 O 03/15/01 DATE REV BY COMMI~ITS DATE REV BY COMIVENTS ORIGINAL COMPLETION 07/13/01 JP/KAK PERFS &FISH 03/19/01 CH/KAK RIG SDETRACK 08/04/01 TN/TP B. MD ON XN NPPLE 05/08/01 pcr UPDATED 05/12/01 ATD/tlh ADD PERFS 06/26/01 JLG/IIh SET CIBP 05111101 ' Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57t t ATTN: Sherrie NO. 1135 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 . Anchorage, AK 99501 Field: Prudhoe Bay & Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD d~oo- lq 5 B-29A 21204 SCMT 04113101 2. D.S. t5-45A 20392 MCNL 09108100 I I 1 D.S. t5-42A 20307 MCNL 07/16100 I 1 1 D.S. 5-22A 20477 MCNL 1t/16/00. -1 t 1 D.S. 4-41A 21029 MCNL 01/07/01 OWDW-SW 2tt49 RST 031t4101 I I 1 · NK-12B 21130 OH EDIT IMP & DIN (PDC)' 02124101 1 NK-t 2B 21t30 MD VISION RES 02/24101 t 1 - - NK-12B 21130 TVD VISION RES 02/24101 1 1 NK-12B 21t 30 MD VISION DIN 02124!01 1 NK-12B 21130 TVD VISION DIN 02/24101 - I I 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 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 . Anchorage, AK_ 99503-5711 A'I'TN: Sherrie STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM I~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL [~] GAS r~ SUSPENDED r'] ABANDONED [--] SERVICE 2. Name of Operator ~.~.~ ~ 7, Permit Number BP Exploration (Alaska), Inc. VEI~F~D 201-015 3. Addmss~~~'~~'~ { 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 50-029-22414-02 4. Location of well at sudace __~' ~ '_~ 9. Unit or Lease Name 3952' FNL, 995' FEL, Sec. 36, T12N, R15E, UM (asp's 721567, 5979863) ." :'.;ii': ".'i.'i--.":'~,.~''' Niakuk At Top Producing Interval '~.,~_.:~.__ ,'" ".-. ' 10. Well Number 4481' FNL, 1663' FEL, SEC 23, T12N, R15E, UM (asp's 715324, 5989715) --~.J-/-~'--~.-~ NK-12B 4201' FNL, 1889' FEL, SEC 23, T12N, R15E, UM (asp's 715090, 5989989) - '" 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 51.88 feetI ADL 34625 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 February 14, 2001 February 24, 2001 March 19, 2001I 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 16550' MD /9351' TVD 16453' MD /9307' TVD YES [] No D'1 2023' (Nipple) feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR/Res/Neu/Den/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 94# H-40 Surface 80' 30" 280 cubic feet Arcticset 10-3/4" 45.5# NT-80 40' 4764' 13-1/2" 435 cubic feet Class G 7-5/8" 29.7# L-80 38' 11092' 9-7/8" 806 cubic feet Class G 4-1/2" 12.6# L-80 10849' 16550' 6-3/4" 164 bbls 12 ppg LiteCrete & 51 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, unde~balanced press, & 60° phasing 4-1/2" 12.6" L-80 IBT-M 10855' 10849' 16330' - 16390' MD; 9251' - 9279' TVD 10799' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3336' FP w/138 bbls Diesel (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 25, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 3/26/2001 4.3 Test Period > I 1436 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -824 psi 24-Hour Rate > 3984 5593 2 28. CORE DATA Brief description of Iithology, 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 6, 2001 (Permit #201-015) RECEIVED Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Alaska 0il & Gas Cons, Commission ORIGINAL GEOLOGIC MARKERS 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 16142' 9161' Base of Kuparuk 16443' 9303' 31. LIST OF ATTACHMENTS Summary of NK-12B Rig Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ...,~,~v~ ~ Title BPDrillin.qEnRineer Date Scott Kolstad INSTRUCTIONS Prepared by Paul Rauf 564-5799. General: This form is designed for submitting a complete and correct well completion report and Icg 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". RECEIVED Form 10-407 ORIGINAL MAY 0'9 ZOO1 Naska 0il & Gas Cons. Commission ".'.. BP EXPLORATION .. page1 of 2 Final 'Well I Event Summa · Legal Well Name: NK-12 Common Well Name: NK-12B Event Name: REENTER+COMPLETE Start Date: 2/10/2001 End Date: · . ..,.. .... ....DATE ". '. ..... .TMD. ,.:.......::.. . . 24 HOUR sUMMARY . . 2/10/2001 (fi) Wells Group completing well I pad prep. 2/1112001 (ft) Spot Rig. MIRU Doyon 14, Displace Freeze protect, ND tree, NU BOP 211212001 (fi) Complete testing BOP's & related equipment. POH LD 4 112" tbg. 2/1312001 (ft) Make mill assembly run to 11,294 ft. Set BP on e-line. 2/1412001 11,125.0 (ft) Run whipstock, mill window. 211512001 11,125.0 (ft) POH mill assembly, PU & RIH 6 3/4" bit & directional tools. 2/16/2001 11,286.0 (ft) Orient & time drill out window. Drill ahead wi 6 3~4" bit. 2/1712001 12,246.0 (ft) Drill 6 3/4" directional hole. Wiper trip to check window & well bore. 2/1812001 13,680.0 (ft) Drill 6 3~4" directional hole. 2/1912001 14,351.0 (ft) Wiper trip @ 13,967 ft. O-K. Drill 6 3/4" hole. 2/20/2001 14,850.0 (ft) Drill 6 3/4 hole from 14,351 to 14,850. 2/2112001 15,248.0 (ft) Drilled f/14,850 t/15,248. Circ. hole clean. Begin T.O.H. 2/22/2001 15,248.0 (ft) Complete trip out of hole. Test BOP. PIU BHA. Begin trip in hole. 2/2312001 16,080.0 (ft) Complete trip in. Circ. for ECD. Drill to 16,080. 2/24/2001 16,550.0 (ft) T.D. well at 16,550. ST to shoe. Swept hole. Spot pill. POH. 2/2512001 16,550.0 (ft) Complete TOH. PJU and run 4 1/2 tubing to 8122. 2/2612001 16,550.0 (ft). Run 4 112" liner to 16,500'. Poor circulation. POH 8 stands. 2/27/2001 16,550.0 (ft) TI'H with liner. Condition mud. Cement liner. Displace well. POH w/dp 2/28/2001 16,550.0 (ft) POH with liner tool. Test BOP. Fishing with slickline unit. 31112001 16,550.0 (ft) R.T. 4 11116 overshot and 3 1/16 grapple. TIH wi 3" collar catcher. 312/2001 16,550.0 (ft) Trip out with 3" collar catcher. R.T. 3 1/16 grapple. Build mill assem 3/3/2001 16,550.0 (ft) R.T. 4 3/4 mill. P/U 3 3/4 and RIH. 3/4/2001 16,550.0 (ft) Mill to 10883.5. POH change mills. RIH and mill. Start trip out. 3/5/2001 16,550.0 (ft) Complete TOH. Run impression block on slickline. PIU 3 3/4 mill. 316/2001 16,550.0 (ft) Mill fish and sweep hole clean. P.O.H. P/U clean-out assem. 3/7/2001 16,550.0 (ft) RIH with cleanout string and drill cement fl 10,889 to 12,331' 3/.812001 16,550.0 (ft) Cleanout Cement from 4.1/2" Liner fl 12,331 to 14,435 ft 3/9/2001 16,550.0 (ft) Cleanout Cement from 4.1/2" Liner fl 14,255 ft to 14,542 ft. POH. 3/1012001 16,550.0 (ft) Test BOP's, PU new MM. RIH. Cleanout liner. 3/1112001 16,550.0 (ft) Cleanout cement to 15,739'- Motor failure. POH. 3/1212001 16,550.0 (ft) Roundtrip for MM. Cleanout 4 1/2" liner to 16,056'. 3/1312001 16,550.0 (ft) Cleanout 4 1/2" liner to 16,452'. POH. RIH w/tandem scrapers 3/1412001 16,550.0 (ft) Fin RIH w/scrapers. Flush well & displace w/brine. POH 3/15i2001 16,550.0 (ft) RIH wi DPC perf guns & perforate. Circ oil from well. 3/16/2001 16,550.0 (ft) Kill well, POH w/guns LDDP. 3/17/2001 16,550.0 (ft) LDDP & guns, PU & RIH w/4 112" completion. Printed: 518/2001 12:34:51 PM BP EXPLORATION page 2 of 2 Final Well I Event Summary Legal Well Name: NK-12 Common Well Name: NK-12B Event Name: REENTER+COMPLETE Start Date: 2/10/2001 End Date: DATE ".. ":"TMD' ....' ' ".. . . 24 HOUR SUMMARY ... :.':"" 3/18/2001 16,550.0 (ft) Run 4 112" completion, land same. ND BOP 3/1912001 16,550.0 (fi) NU tree, test same. Freeze protect RDMO NK 12 B ., Printed: 518/2001 12:34:51 PM TRE~= 4-1116" 5M CIW WELLHEAD= 13-5/8" 5M FMC ACTUATOR= BAKER C 'i~'§'i'"~"'~ ........................................................................... 51.88, 'K0~'":: .............................................. ~3001 .~.~.~¥ ................. ~9~-~,~,~ Datum MD = 13800' Datum 'rVDss= 8800' [10-314" CSG, 45.5#, NT-80S BTC, ID = 9.950" ~-~-'~ NK-12B Minimum ID = 3.725" @ 10843' 4-1/2" HES XN NIPPLE I SA~.' NOTES 2023' I--~ 4-1/2" HES CP-2 TRSSSV NIP, ID = 3.938" I GAS LIFT MANDRELS 03125/01 03/25/01 03/25/01 14-1/2" TBG, 12.6#, L-80 IBT-M, ID= 3.958" 10855' 10778' 10799' 10822' 10843' 10855' 10849' 10869' I--~4-1/2" HES X NIP, ID = 3.813" I--~7-5/8" X 4-1/2" BAKER S-3 PKR, ID= 3.850" PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PEP, F: 62 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 16330- 16390 O 03/15/01 17-5/8" CSG, 29.7#, NT 95 HS, NSCC, ID = 6.875" I'"~ 15024' IELMD - 'Ir NOT LOGGED I 11092' I--ITOPOF BAKER WHIPSTOCK I 11106' I~EZSV BRIDGEPLUG I 7-5/8" MILLOUTWINDOWl1092'- 11104'I ~~113s9°' I-Im°p"&~ cer~nt 4-1/2" LNR, 12.6#, L-80 HYD 521, .0152 bpf, ID = 3.958" 16453' 16550' DATE REV BY COMMENTS ORIGINAL COMPLETION 03/19/01 CH/KAK RIG SIDETRACK 05/08/01 pcr updated PRUDHOE BAY UNIT WI=IL: NK-12B PERMIT No: 201-015 APl No: 50-029-23414-02 SEC 36; T12N; R15E 1327' FSL 996' FEL BP Exploration (Alaska) BP EXPLORATION · Page '1 of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: ' Sub, Date From-To Hours Task Code Phase " Description of. Operations 2/10/2001 16:30 - 18:00 1.50 MOB PRE PJSM. Prepare rig for move. Move off of NK 43. Remove Hydril and Diverter riser. 18:00 - 00:00 6.00 MOB PROD PRE Waiting On Wellsgroup to Remove hardlines, circulate well and FP, Pull BPV and prep area for rig. 2/11/2001 00:00 - 06:00 6.00 MOB PROD PRE Wait on wells group to remove hardlines, Circulate and FP well. Install BPV and prep area for rig to move onto well. 06:00 - 09:00 3.00 MOB PRE Move in rig. Spot same. Place Xtree next to wellhead for completion phase. Shim rig, cantilever derrick into position and connect lines. Spot cuttings tank. ACCEPT rig at 0900 hrs 11th Feb 01. 09:00 - 12:00 3.00 WHSUR DECOMP RU circulating system on tree. Offioad seawater. Double valve annulus. Test surface lines 3,500 psi O-K. 12:00 - 14:00 2.00 WHSUR' DECOMP PJSM. Check wellhead pressures, tbg 300 psi, annulus 100 psi. RU & pull BPV w/lubricator. 14:00 - 17:00 3.00 KILL DECOMP Circulate out freeze protect fluid from tbg & annulus. 17:00 - 18:00 1.00 WHSUR DECOMP RD surface lines from tree. Observe well dead. Install TWC, test from btm 1000 psi. 18:00- 20:30 2.50 BOPSUR DECOMP PJSM. ND Tree. NU BOP's 20:30 - 22:00 1.50 BOPSUR : DECOMP Change top pipe rams to 2 7/8" x 5". 22:00 - 23:00 1.00 BOPSUI~ = DECOMP PU test joint. RU to test BOP's. 23:00 - 00:00 1.00 BOPSUR i DECOMP PJSM. Test BOPE to BP & AOGCC regulations. AOGCC rep. Jeff Jones waived witnessing test. 2/12/2001 00:00 - 07:30 7.50 BOPSUR DECOMP PJSM. Test BOP, choke manifold, HCR valves, & all tubular safety valves to BP & AOGCC regulations. AOGCC rep. Jeff Jones waived witnessing test. 07:30 - 09:00 1.50 WHSUR !DECOMP PU lubricator extension & RU DSM lubricator & pulling tools. Pull TWC, RD DSM pulling tools & lubricator. 09:00 - 10:30 1.50 PULL 'DECOMP MU landing jt, unseat tbg hanger. Observe well dead. Pull hanger to rig floor. 110,000 lbs overpull. Normal up weight 150,000 lbs. 10:30 - 11:30 1.00 CLEAN . DECOMP Circulate well w/8.6 ppg seawater. 11:30 - 13:00 1.50 PULL ' DECOMP PJSM. LD landing jt & tbg hanger. RU to LD 4 1/2" tbg. 13:00 - 16:30 3.50 PULL , DECOMP POH & LD 4 1/2" tbg to TRSSSV. RD control line spooling equipment. 15:30 - 00:00 7.50 PULL DECOMP Con't POH & LD 4 1/2" tubing, 12.6 Ib/ft, L-80, NSCT. Tubing in good condition. 2/13/2001 00:00 - 01:00 1.00 PULL DECOMP Con't POH & LD 4 1/2" tubing, 12.6 Ib/ft, L-80, NSCT. Tubing in good condition. Total 286 jts, 16 ft cut off. 01:00 - 01:30 0.50 PULL :DECOMP RD tubing handling equipment. 01:30 - 02:00 0.50 BOPSUI~ DECOMP PU & run test plug, pressure lower pipe rams to BP & AOGCC regulations. Pull & LD test plug. 02:00 - 03:00 1.00 WHSUR DECOMP Install wear bushing. PU milling assembly. 03:00 - 04:00 1.00 CLEAN i DECOMP PJSM. PU & RIH w/BHA 04:00 - 10:00 6.00 CLEAN ' DECOMP PU & RIH 4" DP from pipe shed. SLM & rabbit same. 10:00 - 12:00 2.00 CLEAN DECOMP Break circulation. Slip & cut drilling line. 12:00 - 15:00 3.00 CLEAN DECOMP Con't RIH w/mill assembly on 4" DP from derrick. SLM same. Tag cut off tubing @ 11,294 ft. 15:00 - 16:30 1.50 CLEAN DECOMP Circulate bottoms up @ 11,290 ft w/1,400 psi @ 6 BPM. Flow check - well static. 16:30 - 22:30 6.00 CLEAN DECOMP POH w! mill assembly. LD same. 22:30 - 23:00 0.50 CLEAN DECOMP PJSM. RU Schlumberger electric line. 23:00 - 00:00 1.00 PXA DECOMP MU & RIH w/7 5~8" EZSV on e - line. Set EZSV @ 11,106 ft KB. 2/14/2001 00:00 - 02:00 2.00 PYA DECOMP RIH w/7 5~8" EZSV bridge plug on E-line. Set EZSV @ 11,106 ft KB. (Loggers depth) 02:00 - 02:30 0.50 PYA DECOMP Rig down Schlumberger E-line. 02:30 - 03:00 0.50 PYA DECOMP Test casing to 3500 psi high and 300 psi Iow for 30 minutes. OK Printed: 4112/2001 10:27:03 AM BP EXPLORATION Page 2 of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Descripti°n'of Operations "' Date From-To Hours Task Code .... · 2/1412001 03:00 - 04:30 1.50 STWHIP PROD1 PJSM. Pick up 6 3/4" Milling assembly, MWD and Whipstock and Anchor. 04:30 - 14:30 10.00 STWHIP PROD1 RIH with Milling assembly and Whipstock blade and anchor. Tag up on EZSV bridge plug at 11,109'. (Drillers depth) 14:30 - 15:00 0.50 STWHIP PROD1 Orient Whipstock blade 61 deg to right of high side. Set down 20k to set anchor and 35K to sheer off from mill. String rotating free. 15:00 - 16:30 1.50 STWHIP PROD1 Displace brine with drilling mud 16:30-22:30 6.00 STWHIP PROD1 Mill window from 11,092 ftto 11,104ft. Con't drill open holeto 11,125 . Work mills through window O-K. 22:30 - 00:00 1.50 STWHIP PROD1 Circulate hi - vis sweep & clean hole. 2/1512001 00:00 - 01:00 1.00 STWHIP PROD1 .Perform LOT @ 7 5/8" csg window @ 11,092 ft w/EMW of 12.9 ppg. 01:00 - 06:00 5.00 STWHIP PROD1 Flow check. Well static. POH w/6 3/4" window milling assembly. 06:00 - 08:00 2.00 STWHIP PROD1 PJSM. Flow check. Well static. Lay down 6 3/4" window milling BHA. 08:00 - 09:00 1.00 STWHIP PROD1 Pick up BOP jetting tool & clean out stack. 09:00 - 10:30 1.50 DRILL PROD1 Make up 6 3/4" directional drilling assembly w/new PDC bit. With mud motor set at 1.15 degree. 10:30 - 13:00 2.50 DRILL PROD1 RIH w/6 3/4" bit on 4" DP from derrick. 13:00 - 16:00 3.00 DRILL PROD1 PJSM. Con't RIH wi 6 3~4" bit picking up 4" DP from pipe shed. SLM & rabbit same. 16:00 - 17:00 1.00 DRILL PROD1 PJSM. Slip & cut drlg line. 17:00 - 23:30 6.50 DRILL WTHR PROD1 phase 3 weather conditions. Keep hole fill pump running & monitor well. General house keeping. 23:30 - 00:00 0.50 DRILL PROD1 Phase 3 weather condtions lifted. Con't RIH wi 6 3/4" bit on 4" DP. 2/16/2001 . 00:00 - 02:00 2.00 DRILL PROD1 RIH with 6 3/4" drillimng asembly on 4" DP to top of casing window. Run through window slowly with no problem. 02:00 - 22:30 20.50 DRILL PROD1 Work trench 11,120 ft to 11,125 ft. Time drill from 11,125' at 2 fi/hr and slowly increase ROP to 35 fi/hr. Broke off ledge & fell into old hole 11,186 ft. Pull back and build trench 11,125 ft to 11,140 ft, orient @ 180 'degs time drill at 3 - 8 fi/hr rolling tool face to 80 degs. Slowly increase .WOB & differential until well side tracked. 22:30 - 00:00 1.50 DRILL PROD1 Directionally drill 6 3/4" hole 11,165 ft to 11,286 ft. 2117/2001 00:00 - 11:00 11.00 DRILL PROD1 . Directionally drill 6 3/4" hole 11,286 ft to 11,669 ft. Rotate and slide. WOB 3-5K. RPM 80. PSI 2600. GPM 275 11:00 - 11:30 0.50 DRILL PROD1 . Circulate and work pipe. 11:30 - 12:30 1.00 DRILL PROD1 POH to 7 518" casing window. No problems entering window. 12:30 - 13:00 0.50 DRILL PROD1 . RIH. No problems going through window and rs-entering kick off point. 13:00 - 00:00 11.00 DRILL PROD1 Directionally drill 6 3~4" hole from 11,669 to 12,286 ft. Slide and rotate. WOB 3-5 K. RPM 75. PSI 2,200. GPM 276 2/18/2001 00:00 - 00:00 24.00 DRILL PROD1 ,Directionally drill 6 3/4" hole from 12,246 ft to 13,680 ft. Slide and rotate. WOB 4 - 7 K. RPM 85. PSI 2,600. GPM 276 AST= 7.25 hrs, ART= 10.25 hrs, ADT= 17.5 hrs 2/19/2001 00:00 - 08:00 8.00 DRILL PROD1 Directionally drill 6 3/4" hole from 13,680 ft to 13,967 ft. Slide and rotate. WOB 4 - 7 K. RPM 65 - 85. PSI 2,600. GPM 276 08:00 - 09:30 1.50 DRILL PROD1 Circulate bottoms up for wiper trip. Flow check - well static. PJSM held for upcoming wiper trip. 09:30 - 13:30 4.00 DRILL PROD1 Wiper trip to 11,600 ft. Hole in good shape. 13:30 - 00:00 10.50 DRILL PROD1 Directionally drill 6 3~4" hole from 13,967 ft to 14,351 ft. Slide and rotate. WOB 3 - 7 K. RPM 65 - 85. PSI 2,600. GPM 276 2/20/2001 00:00 - 00:00 24.00 DRILL PROD1 Directionally drill 6 3/4" hole from 14,351 ft to 14,850 ft. Slide and rotate. WOB 2 - 6 K. RPM 65 - 85. PSI 2,800. GPM 275 AST=17.25 ART=2.25 2/21/2001 00:00 - 16:30 16.50 DRILL PROD1 Drilling 6 3/4 hole from 14,850 to 15,248. ART= 4.75 AST= 3.75 Printed: 4112/2001 10:27:03 AM BP EXPLORATION Page 3 of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: . Sub Phase " DeScription of OperatiOns Date From-To HoUrs. Task Code · 2121/2001 00:00 - 16:30 16.50 DRILL PROD1 275 g.p.m @ 2800 PSI. 3-5 WOB. Bring mud wt. up to 11 p.p.g, while drilling '"ruff formation. Top of Tuff=- 14909 MD 8485 TVD 16:30 - 18:30 2.00 DRILL PROD1 Circulate hole clean prior to T.O.H. Observe hole for static. 18:30 - 19:30 1.00 DRILL PROD1 P.O.H. with 10 stands, monitoring well for proper fill and swabbing. 19:30 - 20:00 0.50 DRILL PROD1 Pump dry job. Observe well. 20:00 - 22:30 2.50 DRILL PROD1 P.O.H. to 11,150. While lowering blocks to floor to latch onto stump, elevators were set down on girt in derrick. 22:30 - 23:30 1.00 DRILL TDRV PROD1 Investigate incident. Link tilt was extended to far back, allowing elevators to come to rest on girt in derrick. Inspection of derrick and topdrive conducted prior to lowering blocks to floor. Inspect elevators, bails, pins, hoses, etc., etc., on topdrive. Adjust "link tilt clamp". 23:30 - 00:00 0.50 DRILL PROD1 Safety meeting with new crew coming on tour. Discussion of link tilt incident and controlling the scene after an incident occurs. 2/22/2001 00:00 - 05:30 5.50 DRILL PROD1 P.O.H. to BHA. Monitor well at BHA. 05:30 - 07:00 1.50 DRILL PROD1 Lay down BHA. Break and grade bit. Clear floor for BOP test. 07:00 - 07:30 0.50 DRILL PROD1 Remove wear ring. Install test plug. 07:30 - 11:30 4.00 BOPSUI~ PROD1 Test BOP per State/B.P. policy. 5 minute Iow @ 250 10 minute high @ 3500 11:30 - 12:30 1.00 DRILL PROD1 One hour "Safety Standdown" with both crews and service personnel. 12:30 - 17:30 5.00 BOPSUI; PROD1 Complete BOP test. Install wear ring. 17:30 - 20:30 3.00 DRILL PROD1 Pick up and make up new BHA with GR/RES/DEN/NEU/PWD tools. Re-run bit number 1. Orient and shallow test MWD-MOTOR. 20:30 - 22:30 2.00 DRILL PROD1 RIH to app. 5000'. Stop to cut drilling line. 22:30 - 00:00 1.50 DRILL PROD1 Slip and cut drilling line. 2/23/2001 00:00 - 05:00 5.00 DRILL PROD1 RIH. Orient tool face, work bit and BHA through window. Continue RIH to 15,023' 05:00 - 05:30 0.50 DRILL PROD1 Wash an ream to bottom as precaution. 05:30 - 07:00 1.50 DRILL PROD1 Circulate a reduced rate due to high ECD and slowly bring GPM up to drilling rate as ECD stablized. 07:00 - 00:00 17.00 DRILL PROD1 Directionally drill 6 3~4" hole from 15,248 ft to 16,080 ft. WOB 5-6 K. RPM 60-90. PSI 3700. GPM 260 AST=0 ART=13 2/24/2001 00:00 - 06:30 6.50 DRILL PROD1 Directionally drill 6 3~4" hole from 16,080 ft to 16,550 ft. WOB 5-6 K. RPM 60-90. PSI 3700. GPM 260 AST=0 ART=4 1/4 06:30 - 08:30 2.00 DRILL PROD1 Circulate and condition mud. 08:30 - 10:00 1.50 DRILL PROD1 POH to top of Tuffs at 14,850' for short trip. No hole problems. 10:00 - 11 .'00 1.00 DRILL PROD1 RIH to bottom, no problems. 11:00 - 15:00 4.00 DRILL PROD1 Circulate weighted barofibre sweep S-S. Spot liner running pill in open hole section. Drop 2" rabbit. 15:00 - 20:00 5.00 DRILL PROD1 POH to casing shoe @ 11,000, wiping slight overpull area's at 11,850 to 12,100 and 13,000.( No overpull noted after wiping.) 20:00 - 21:30 1.50 DRILL PROD1 Cut drilling line and service top drive. 21:30 - 00:00 2.50 DRILL PROD1 POH from casing shoe. 2/2512001 00:00 - 01:30 1.50 DRILL PROD1 POH to 3607' 01:30 - 03:00 1.50 DRILL PROD1 POH. Lay down 81 joints 4" drill Pipe. 03:00 - 04:30 1.50 DRILL PROD1 POH. Lay down HWDP and BH^. 04:30 - 07:30 3.00 DRILL PROD1 Down load LWD tools memory. PJSM. Remove RA source and lay Printed: 4/12/2001 10:27:03 AM BP EXPLORATION Page 4 of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Date From - To Hours Task 'Sub Code 'Phase Description of Operations 2/25/2001 04:30 - 07:30 3.00 DRILL PROD1 down rest of BHA. 07:30 - 08:30 1.00 CASE PROD1 Clear floor, PJSM and rig up to run liner. 08:30 - 13:00 4.50 CASE PROD1 Run 4 1/2" HYD 521 L-80 12.6~. Check floats. Use lift nubbin and safety clamp on each joint. Fill liner every 15 joints. 13:00 - 13:30 0.50 CASE PROD1 Casing tongs failed. Replace with backups. 13:30 - 20:00 6.50 CASE PROD1 Continue to RIH with liner to 5663. Stop to P/U liner hanger/packer. 20:00 - 21:30 1.50 CASE PROD1 P/U Baker 7X5 HMC hydraulic set Packer. Cim. liner volume. 21:30 - 00:00 2.50 CASE PROD1 RIH to 8122, with 4 1/2 liner on d.p. filling every 10 stands. 2126/2001 00:00 - 03:30 3.50 CASE PROD1 Run 4 1/2" liner on 4 "drill pipe to 10,879'. Fill every 10 stands. 03:30 - 05:00 1.50 CASE PROD1 Make up cementing head on joint of drill pipe and lay down on skate. Circulate and take up and down weight and rotating parameters. 05:00 - 07:00 2.00 CASE PROD1 Run liner and pass through casing window with no problems. 07:00 - 10:00 3.00 CASE PROD1 Wash and rotate through tight hole from 12,650' to 13,311' 10:00 - 13:00 3.00 CASE COND PROD1 Circulate and condition brine contaminated mud. 13:00 - 19:00 6.00 CASE PROD1 RIH with 4 112 liner on d.p., to 16,464'. Work tight hole. 19:00 - 20:30 1.50 CASE PROD1 Work pipe to establish fluid course and slowly break circ. Hole sticky and packing off. Circ. @ 10 SPM 1350PSl. Work pipe to 16,500' as circulating ability deteriorates. (3 strokes per minute at 1300 PSI.) 20:30 - 21:00 0.50 CASE PROD1 Work three stands out to 16,250'. 21:00 - 21:30 0.50 CASE PROD1 Work pipe and attempt to establish good circ. rate--to no avail. 21:30 - 22:00 0.50 CASE PROD1 POH working 5 stands out. 22:00 - 00:00 2.00 CASE PROD1 Rotate/Reciprocate liner and Establish circ. rate @ 10 SPM 1500 PSI and stage up over several hours to 45 SPM @ 1400. Liner rotating values= 30 RPM- 5,500 fi/lbs. @ 15,776' 30 RPM--3,000 fi/lbs. @ window. 2/27/2001 00:00 - 05:30 5.50 CASE PROD1 Wash to bottom with 4 1/2 liner F/15,776 T/16,550. No hole problems. 05:30 - 09:30 4.00 CASE PROD1 Circulate and condition mud for cement job. Rotate and reciprocate liner. Final rate and pressure while conditioning mud: 190GPM @ 1250 PSI. UP=205K Down--135K 09:30 - 12:30 3.00 CEMT PROD1 Perform cement job as follows: 5 bbls. CW 100, test lines to 4500, 45 bbls. CW 100 then 20 bbls. mudpush {~ 11.5 ppg. Pump 164 bbls. lead cement followed by 51.23 tail @ 15.8. Kick out plug and displace with 125 bbls. Packed off with app. 55 bbls. gone on displacement. 12:30 - 18:00 5.50 CEMT PROD1 Release from liner top. Dump 51 bbls. cement from d.p. to annulus with 125 Perf. pill, 25 caustic flush, 20 HI-Vis sweep, 40 Bara clean and 20 HI-Vis sweep. Swap to rig and displace well bore over to seawater.( App. 50 bbls. cement at surface.) L/D cement head and clear floor of all vendors equipment. 18:00 - 19:00 1.00 CEMT PROD1 Slowly slack off/rotate down 75K on liner top and turn to the right, setting liner top packer. Observe shear. No erractic torque. 19:00 - 19:30 0.50 CEMT PROD1 Test liner to 3500 for 10 minutes. 19:30 - 00:00 4.50 CEMT PROD1 POH lxl with 81 jts. DP. Stand back remaining pipe in derrick. 2/28/2001 00:00 - 01:30 1.50 CEMT PROD1 Slip and cut drilling line. 01:30 - 04:30 3.00 CEMT PROD1 POH with liner running tool. 04:30 - 05:00 0.50 BOPSUF PROD1 Remove wear ring. 05:00 - 09:30 4.50 BOPSUF PROD1 Test BOP per B.P. policy. @ 250 Iow for 5 minutes; 3500 High for 10 minutes. No failures--good tests. 09:30 - 10:00 0.50 BOPSUF PROD1 Install wear ring and R/D test equipment. 10:00 - 15:30 5.50 FISH CASE PROD1 Evaluate options: Liner running tool came apart down hole. Meet with Baker fishing, Baker Packers, and wireline fishing group to determine the best approach to recover lost tool. Stage equipment to rig. Rig Printed: 411212001 10:27:03 AM BP EXPLORATION Page5 of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Sub phase DescriPtion of Operations Code 2/28/2001 10:00 - 15:30 5.50 FISH CASE PROD1 Inventory of all shackles following 9es Incident. Rig Service and PIU 2.718" handling equipment. 15:30 - 21:00 5.50 FISH CASE PROD1 i Fish with 2.641 spear on slick line and remove "RS stuffing box" from !well bore @ 10889 WLM. L/D and R/D wireline equipment. Teflon seals =were gone from tool. 21:00 - 00:00 3.00 FISH CASE PROD1 P/U and strap Baker Fishing Tool equipment. Build BHA with Overshot dressed with cut lip and 3 1/16 overshot. 3/1/2001 00:00 - 03:30 3.50 FISH CASE PROD1 RIH with 4 11/16 overshot with 3 1116 grapple. 03:30 - 04:00 0.50 FISH CASE PROD1 Circ. and wash F/10720 T/10845. Get benchmarks for fishing limits before going inside hanger. Circulate at 170 gpm at 490 PSI. UP WT.=182K DWN. WT.=140K String WT,=160K Torque@10 RPM=4500 04:00 - 05:00 1.00 FISH CASE PROD1 Fish for lost stinger at 10,870. Tag fish top at 10,870 with 5K down, Pull up to above liner top to 10,800. Slack off and not 1-3k down drag bumps not present prior to going inside liner. 05:00 - 11:00 6,00 FISH CASE PROD1 Trip out of the hole slowly. 11:00 - 16:00 5.00 FISH TDRV PROD1 Service loop on top drive was damaged when the iron ruffneck spinner was clamped onto it. 16:00 - 18:00 2.00 FISH CASE PROD1 Have new fishing tools delivered from Baker 18:00 - 18:30 0.50 FISH CASE PROD1 M/U 3 13/16 guide shoe, and collar catcher. Collar catcher fingers 2.390. (.015 thousands larger than tubing fish body) 18:30 - 23:30 5.00 FISH CASE PROD1 RIH. Circ. and wash F/10720 T/10845. Get benchmarks for fishing limits before going inside hanger. Circulate at 170 gpm at 490 PSI. UP WT.=180K DWN. WT.=135K String WT.=156K Torque@20 RPM=400. 23:30 - 00:00 0.50 FISH CASE PROD1 RIH to 10,870 tagging fish top. Attempt to catch fish with 5-12 k down, no indication of latch up, Attempt to rotate down and catch fish. No !pressure increase or indication of forward progress. 3/2/2001 00:00 - 01:00 1.00 FISH CASE PROD1 ~Fish with" cripple lip" guide shoe and 3" collar catcher. Fish top at !10870. No signs of latch up to fish. Deplete fishing tactics. No forward 'progress. Shoe O.D.= 4 11/16 I.D, = 3 13/16. 01:00 - 05:00 4.00 FISH CASE PROD1 P.O.H, with Cripple Lip Guide. Minimal wear on leading edge. Confirmed that fish cemented in place. 05:00 - 05:30 0.50 FISH CASE PROD1 L/D BHA and inspect Guide shoe. 05:30 - 06:30 1.00 FISH CASE PROD1 Service rig. Remove all excess vendors equipment from rig floor. 06:30 - 07:30 1.00 FISH CASE PROD1 Build fishing BHA with 3 1/16" grapple with 4 11/16" "Cut lip guide" and 3 1/16" dressing shoe and extention. 07:30- 09:30 2.00 FISH CASE PROD1 RIH to 4650. 09:30 - 10:30 1.00 FISH CASE PROD1 Slip and cut drilling line. 10:30 - 13:00 2.50 FISH CASE PROD1 RIH to 10,811. 13:00 - 17:30 4.50 FISH CASE PROD1 Wash down to 10,840. Get bench mark values prior to going inside liner top. Circ. down and tag fish top @ 10,870. Rotate over top of fish and dress with 3 1/16 guide shoe. Note torque increase as guide dresses top of fish. Work over fish. Able to get fish started into guide by rotating and working down. Note 5-15K overpulls. Unable to work fish into Extention far enough to get to grapple. Abort fishing operations 17:30 - 21:30 4.00 FISH CASE PROD1 POH to BHA. 21:30 - 22:00 0.50 FISH CASE PROD1 Lay down and inspect fishing assembly. Clear floor of all excess equipment. 22:00 - 23:00 1.00 FISH CASE PROD1 M/U milling assembly with 4 3/4 "Concave Mill". 23:00 - 00:00 1.00 FISH CASE PROD1 RIH with milling assembly to 1000. Crew change. 3/3/2001 00:00 - 03:30 3.50 FISH CASE PROD1 R.I.H. with 4 3/4 concave mill. 03:30 - 10:30 7.00 FISH CASE PROD1 Mill on 2 3/8 fish from 10870 to 10882. Pumping sweeps as needed lift Printed: 4112/2001 10:27:03 AM BP EXPLORATION Page6.of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations ' ., Date From,-To HoUrs Task " Code · , 3/3/2001 03:30 - 10:30 7.00 FISH CASE PROD1 metal cuttings, 10:30 - 11:30 1.00 FISH CASE PROD1 Circ. hole clean. Pump dry job. 11:30 - 16:00 4.50 FISH CASE PROD1 P.O.H. with 4 3/4 "Concave mill" 16:00 - 17:00 1.00 FISH CASE PROD1 L/D 4 314 mill. Inspect mill for wear. Mill has wear area in center app. 1/2 inch deep by 3" wide. 17:00 - 17:30 0.50 FISH CASE PROD1 Test casing to 3000 for 10 minutes. PIU 3 3/4 semi fiat bottom mill. 17:30 - 23:00 5.50 FISH CASE PROD1 RIH with mill to 10,825. Wash to fish top at 10, 882. Get bench mark values prior to going inside liner top. 23:00 - 00:00 1.00 FISH CASE PROD1 Mill on fish top from 10,882 to 10,882.5. Pump barafibre sweep after milling 3 ft. Brought back small amounts of plug rubber cement and metal. 3/4/2001 00:00 - 09:00 9.00 FISH CASE PROD1 Mill on top of 2 318 fish from 10,882.5---10883.5. After reaching a depth of 10,882.5 the pressure increased whenever mill was put on bottom. No forward progress being made. Test casing to 3500 psi/10 minutes. 09:00 - 14:00 5.00 FISH CASE PROD1 Trip out of hole with 3 314 mill. 14:00 - 15:30 1.50 FISH CASE PROD1 Change out 3 314 mills. Mill pulled was bald. No cuffing potential left. App. 1" worn from bottom. 15:30 - 18:00 2.50 FISH CASE PROD1 RIH to 9912, with fiat bottom jumk mill. 18:00 - 18:30 0.50 FISH CASE PROD1 Service top drive. 18:30 - 19:00 0.50 FISH CASE PROD1 RIH getting milling bench marks prior to going inside top of liner top. 19:00 - 22:00 3.00 FISH CASE PROD1 Attemtp to mill 2 318 fish. Unable to get torque response once mill is set on bottom. Suspect last 4 foot of fish is free and spinning on top of wiper plugs. No progress made. Total of fish milled at this point=app. 13.5. Fish remaining in hole =3.75. 22:00 - 00:00 2.00 FISH CASE PROD1 Puli out of the hole to wireline fish remaining 2 3/8. 3/5/2001 00:00 - 03:00 3.00 FISH CASE PROD1 P.O.H. with 3 3/4 mill to slickline fish. 03:00 - 04:30 1.50 FISH CASE PROD1 L/D BHA. Clear floor for next operation. 04:30 - 12:00 7.50 FISH CASE PROD1 PJSM. R/U wireline equipment. RIH with 2 1/2 wireline bailing tool. No junk recovered. RIH with 3.7 impression block- indications of possible junk on Iow side- no obvious fishing neck. 12:00 - 13:30 1.50 FISH CASE PROD1 PIU 3 3/4" mill #3 and drop pony collar. Stiffen assembly with stabiliser 6 ft from mill. 13:30- 16:30 3.00 FISH CASE PROD1 RIH with mill #3. 16:30- 17:00 0.50 FISH CASE PROD1 Cut drilling line. 17:00 - 17:30 0.50 FISH CASE PROD1 RIH getting bench mark milling values prior to going inside liner top. Tag fish at 10883.5. Pump weighted Barafibre sweep while sitting on bottom. 17:30 - 00:00 6.50 FISH CASE PROD1 Mill on fish top with all known milling practices, from 10,883.5 to 10,884.5. Pump 5 bbl. weighted Barafibre sweeps to assist lifting metal out of hole. Dry drill- surging hole periodically to lift debris from hole- good torque response. WOM 9 KLbs. 3/6/2001 00:00 -' 01:30 1.50 FISH CASE PROD1 Mill on fish top with all known milling practices, from 10,884.5 ft to 10,889 ft. Pump 5 bbl. weighted Barafibre sweeps to assist lifting metal out of hole. Dry drill- surging hole periodically to lift debris from hole- good torque response. WOM 8 KLbs, RPM 90. 01:30 - 04:30 3.00 FISH CASE PROD1 Circulate & sweep hole clean. Test casing 3000 psi - 10 mins. O-K 04:30 - 09:30 5.00 FISH CASE PROD1 PJSM. Pump dry job. POH w/milling assy. 09:30 - 11:00 1.50 FISH CASE PROD1 LD milling BHA. Mill worn 1/4". Nothing in boot basket. 4.3~4" stabiliser showing evidence of contacting restricted ID. 11:00 - 12:00 1.00 FISH CASE PROD1 PJSM. Rig up 2 7/8" DP handling equipment. 12:00 - 12:30 0.50 FISH CASE PROD1 PU & surface test 3 1/8" Mud Motor. 20 SPM @ 300 psi. 12:30 - 13:30 1.00 FISH CASE PROD1 MU PDC bit on MM & BHA. 13:30 - 22:00 8.50 FISH CASE PROD1 PU & RIH w/181 jts 2 7~8" DP from pipe shed. SLM same. Printed: 4112/2001 10:27:03 AM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: .. Sub Phase Description.of Operations ' Date From - To Hours Task' Code , 3/6/2001 22:00 - 22:30 0.50' FISH CASE PROD1 Circulate DP. 20 SPM ~ 1000 psi. RD 2 7/8" DP handling equipment. 22:30 - 00:00 1.50 FISH CASE PROD1 Con't RIH w/3 3/4" PDC bit on 4" DP from derrick. 3/7/2001 00:00 - 02:00 2.00 REMCM' STAB PROD1 Continue to RIH to top of 4.1/2" liner @ 10,852 ft. 02:00 - 02:30 0.50 REMCM' STAB PROD1 Take Parameters above liner top. Up/Down= 152/125 Klbs, Rotating 138 klbs w/3,500 fflbs @ 30 RPM. 02:30 - 00:00 21.50 REMCM' STAB PROD1 Dril cement from 10, 889 ft to 12, 331 ft. Vary parameters to optimise progress without stalling motor. Using 200 psi differential, 2-3 klbs WOB. Flowrate @ 114 GPM. P-rates 90 to 170 fi/hr. Connections clean. Sweeping hole every 400 ft with weighted pills. Bit Hours = 14 Circulating hours on motor= 19 hrs. 3/8/2001 00:00 - 13:30 13.50 REMCM' STAB PROD1 Dilling Cement inside 4.1/2" Liner from 12,331 ft to 13,420 ft. P-rates @ 90- 160 fi/hr. Vary RPM to see if torque would reduce- no go 13:30 - 14:30 1.00 REMCM' 'STAB PROD1 Pump 25 bbls Hot Diesel cushioned by 15 bbl Hi Weight sweep either side of diesel. 14:30 - 00:00 9.50 REMCM' 'STAB PROD1 Drilling cement from 13,420 ft to 14,255 f. No reduction in torque with diesel sweep- nothing seen at surface in terms of wax etc. Raise Drill side concentration by 2%. Torque near max. Hours on Bit = 30 Circulating Hours = 42 319/2001 00:00 - 10:30 10.50 REMCM' 'STAB PROD1 Drill cement 14,255 ft to 14,542 ft. Repeated stalls on MM. 10:30 - 13:30 3.00 REMCM' 'STAB PROD1 Sweep hole wi 30 bbl weighted pill. Open PBL sub, circ hole clean, close PBL sub. 13:30 - 16:00 · 2.50 REMCM' 'STAB PROD1 POH w/3 3/4" bit above 4 1/2" liner top @ 10,581 ft. 16:00 - 17:00 1.00 REMCM' 'STAB PROD1 Test casing to 3,500 psi - 5 mins. O-K. Repeat test to achieve flexing effect to release possible cement wall cake on casing. 17:00 - 20:00 3.00 REMCM' 'STAB PROD1 Con't POH w/3 3/4" bit racking 4" DP in derrick. 20:00 - 21:00 1.00 REMCM' 'STAB PROD1 PJSM. LD PBL sub. Pump dry job. RU 2 7/8" handling equipment. 21:00 - 00:00 3.00 REMCM' 'STAB PROD1 Con't POH w/3 3/4" bit racking 2 7/8" DP in derrick. 3/10/2001 00:00 - 01:00 1.00 REMCM' 'STAB PROD1 PJSM. LD BHA. Mud motor locked up. Bit had 6 damage cutters. . 01:00 - 05:00 4.00 REMCM' 'STAB PROD1 PJSM. Test BOP, choke manifold, HCR valves, & all tubular safety valves to BP & AOGCC regulations. AOGCC rep. Chuck Scheve witnessed test. 05:00 - 06:00 1.00 'REMCM' 'STAB PROD1 PU new BHA. Surface test MM O-K. 06:00 - 10:00 4.00 REMCM' 'STAB PROD1 RIH w/3 3/4" bit on 2 7/8" DP. 10:00 - 10:30 0.50 REMCM' 'STAB PROD1 Circ DP volume. RD 2 7/8" handling equipment. RU 4" handling equipment. 10:30 - 13:00 2.50 REMCM' 'STAB PROD1 Con't RIH w/3 3/4" bit on 4" DP to 10,795 ft. 13:00 - 14:30 1.50 REMCM' 'STAB PROD1 PJSM. Slip & cut drlg line. Service Top Drive. 14:30 - 17:30 3.00 REMCM' 'STAB PROD1 Con't RIH w/3 3/4" bit on 4" DP. Break circ@ 4 1/2" liner top & every 10 stds inside of liner. Estabished parameters same as drilling @ same depths. 17:30 - 00:00 6.50 REMCM' STAB PROD1 Slide drill cement 14,542 ft to 14,650 ft. Displace to clean mud w/2% EP lube. Torque decrease to 8,000 fi/lbs off btm. Increasing percentage of EP lube. 3/11/2001 00:00 - 22:00 22.00 REMCM' STAB PROD1 Drill cement 14,650 ft to 15,739. Repeated stalls on Mud Motor. Unable to drill. Motor weakening prior to failure for several hours, i.e maximum differential pressure able to put on motor without stalling was 80 psi. 22:00 - 00:00 2.00 REMCM' STAB PROD1 Sweep hole w/30 bbl weighted pill. Hold PJSM for upcoming trip. 3112/2001 00:00 - 02:30 2.50 REMCM' 'STAB PROD1 PJSM. Sweep hole w/30 bbl weighted pill. Open PBL sub, circ hole Printed: 4112/2001 10:27:03 AM .. BP EXPLORATION Page 8 of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYEN Rig Release: 3/19/2001 Group: RIG Rig Name: DOYEN 14 Rig Number: Sub . Date FrOm - To HoUrs Task Code Phase.' Description of oPerations 3/1212001 00:00 - 02:30 2.50 REMCM'I'STAB PROD1 clean, close PBL sub. Pump dry job. 02:30 - 06:30 4.00 REMCM'I'STAB PROD1 Flow check. POH w/3 3/4" bit on 4" DP. 06:30 - 07:30 1.00 REMCM'I'STAB PROD1 PJSM. RU 2 718" DP handling equipment. Pump second dry job. 07:30 - 09:30 2.00 REMCM'I'STAB PROD1 POH w/3 3/4" bit on 2 7/8" DP. 09:30 - 10:00 0.50 REMCM'I'STAB PROD1 PJSM. LD BHA. Mud motor locked up. Bit had no damage. 10:00 - 11:30 1.50 REMCM'I'STAB PROD1 MU new MM. Surface test same O-K. PU 6 additional 3 1/8" DC's. RIH wi BHA. 11:30 - 15:00 3.50 REMCM'I'STAB PROD1 RIH w/3 3~4" bit on 2 7/8" DP. 15:00 - 16:30 1.50 REMCM'I'STAB PROD1 Circ DP volume. RD 2 7/8" DP handling equipment. 16:30 - 18:00 1.50 REMCM'~'STAB PROD1 Con't RIH wi 3 3~4" bit on 4" DP to 10,773 ft. 18:00 - 18:30 0.50 REMCM'I'STAB PROD1 Break circulation. Test casing 3,500 psi / 10 mins. O-K. 18:30 - 21:00 2.50 REMCM'~'STAB PROD1 Con't RIH wi 3 3/4" bit on 4" DP to TOC @ 15,739 ft. 21:00 - 00:00 3.00 REMCM'~'STAB PROD1 Drill cement 15,739 ft to 16,056 f. 3/13/2001 00:00 - 04:00 4.00 REMCM'I'STAB PROD1 Drill cement from 16,056 ft to 16,453 ft. Top of Landing Collar. 04:00 - 06:30 2.50 REMCM'I'STAB PROD1 Circulate well w/weighted sweep. 106:30 - 10:00 3.50 REMCM'~'STAB PROD1 PJSM Flow check. Pump dry job. POH w/3 3/4" bit on 4" DP to above 4 1/2" liner top ~ 10,851 ft. SLM 10:00 - 11:00 1.00 CASE PROD1 Pressure test casing to 3,500 psi for 30 mins. O-K 11:00 - 14:00 3.00 CASE PROD1 Con't POH wi 3 3~4" bit on 4" DP. SLM 14:00 - 14:30 0.50 CASE PROD1 PJSM. RU 2 7/8" DP handling equipment. 14:30 - 18:00 3.50 CASE PROD1 Con't POH w/3 3/4" bit on 2 7/8" DP. SLM 18:00 - 19:00 1.00 CASE PROD1 PJSM. LD BHA. 19:00 - 19:30 0.50 CLEAN COMP MU 4 1/2" scraper BHA. 19:30 - 21:30 2.00 CLEAN COMP RIH w/4 1/2" scraper on 2 7~8" DP. 21:30 - 22:00 0.50 CLEAN COMP Circ DP volume. RD 2 7/8" DP handling equipment. MU 7 5/8" scraper. 22:00 - 00:00 2.00 CLEAN COMP Con't RIH w/tandem scrapers to top of 4 1/2" liner @ 10,851 ft. 3/14/2001 00:00 - 01:30 1.50 CLEAN COMP PJSM. Slip & cut drilling line. Service TD 01:30 - 04:00 2.50 CLEAN COMP Con't RIH w/tandem scrapers on 4" DP to 16,126 ft. 04:00 - 06:00 2.00 CLEAN COMP Wash tandems scrapers 16,126 ft to top of LC @ 16,453 ft. 06:00 - 15:00 9.00 CLEAN COMP PJSM. Flush casing w/50 bbls hot diesel, 50 bbls hot H20, 50 bbls hot diesel, 50 bbls hot H20,. 25 bbls Baraclean pill, 30 bbls hi-vis brine. Displace wi 9.3 filtered brine to 70 NTU's. Spot 85 bbl perf pill, pump dry job. 15:00 - 20:30 5.50 CLEAN COMP POH w/tandem scrapers on 4" DP. 20:30 - 21:30 1.00 CLEAN COMP LD 7 5~8" scraper & PBL sub. RU 2 7/8" DP handling equipment. 21:30 - 23:30 2.00 CLEAN COMP Con't POH w/4 1/2" scraper on 2 7/8" DP. 23:30 - 00:00 0.50 CLEAN COMP LD BHA. 3/15/2001 00:00 - 01:00 1.00 PERF COMP PJSM. Clear floor, PU Halliburton perforating equipment. 01:00 - 07:30 6.50 PERF COMP MU perforating guns on 5,591 ft of 2 7/8" DP. RIH filling pipe every stand w/fresh H20. MU safety it, vent sub, Champ packer, jars & Fas-Fil valve. 07:30 - 13:30 6.00 PERF COMP Con't RIH w/DPC perforating guns on 4" DP to 14,087 ft. 113:30 - 14:00 0.50 PERF COMP Test Fas-fill valve w/250 psi, confirmed closed. 14:00 - 15:00 1.00 PERF COMP Con't RIH to 16,453 ft w/perf guns. Tag LC. PU & put guns on depth 16,330 ft to 16,390 ft. Set 7 5/8" Champ packer. 15:00 - 16:00 1.00 PERF COMP PJSM. Test lines 3,000 psi. Fire guns w/2,700 psi annular pressure. Total 60 ft perfs, 6 SPF ~ 60 degree phasing. Noted imediate strong blow. 16:00 - 17:00 1.00 PERF 'COMP Reverse circulate DP volume through vent sub @ 4 BPM. 17:00 - 17:30 0.50 PERF COMP POH 2 stds. Observe well flowing. 17:30 - 19:30 2.00 PERF WCON COMP Circulate bottoms up through choke w/9.3 ppg filtered brine. Noted perf pill & oil in returns after 260 bbls returned. Total gain'of 16 bbls. Shut Printed: 4/12/2001 10:27:03 AM BP EXPLORATION Page.9 of lO Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYEN Rig Release: 3/19/2001 Group: RIG Rig Name: DOYEN 14 Rig Number: .. Date .From ' To HoUrs .TaSk Sub ' · .Code . Phase . . Description of Operations 3/1512001 17:30 - 19:30 2.00 PERF WCON COMP well in for build up. 19:30 - 00:00 4.50 PERF WCON COMP Monitor well for build up. Build surface volume of 9.3 ppg filtered brine. Final pressure readings DP 80 psi, Csg 125 psi. 3/16/2001 00:00 - 01:00 1.00 KILL WCON COMP PJSM. Monitor shut in pressures. Build surface volume of 9.3 ppg filtered brine. SIDPP 110 psi, SICP 150 psi alter initial build up. 01:00 - 04:30 3.50 KILL WCON COMP Circulate well through vent sub @ 10,528 ft w/clean filtered 9.3 ppg brine through choke ~ 4 BPM w/275 psi back pressure, decrease back pressure to 200 psi as fluid moving up annulus. Pump hole volume + 25% excess wi 9.3 ppg in & out. Observe well flowing. Pump addtional 100 bbls wi same parameters. Observe well flowing. Shut well in. No losses or gains during well kill operations. 04:30 - 11:00 6.50 KILL WCON COMP Monitor shut in pressures. Build surface kill fluid of 9.8 ppg brine. Prepare filtered 9.3 ppg brine for bullheading formation fluids out of 4 1/2" liner. SIDP 100 psi SICP 90 psi after initial build up. 11:00 - 13:00 2.00 KILL .. WCON COMP Bullhead 4 1/2" liner volume + 25% excess using 9.3 ppg filtered brine @ 1 BPM wi 2,400 psi. Total 80 bbls pumped. 13:00 - 15:00 2.00 KILL WCON COMP Circulate hole volume through vent sub @ 10,528 ft w/9.3 ppg brine. Observe well flowing. No losses or gains during operation. Shut well in for build up. 15:00 - 16:00 1.00 KILL WCON COMP Monitor well for build up. Observe SIDPP 25 psi, SICP 30 psi. after initial build up. 16:00 - 20:30 4.50 KILL WCON COMP Circulate well through vent sub @ 10,528 tt w/clean filtered 9.8 ppg brine through choke @ 4.5 .BPM wi 150 psi back pressure, decreasing back pressure to 25 psi as fluid moving up annulus. Pump hole volume + 5% excess w/9.8 ppg in & out. Observe well dead. No losses or gains during well kill operations. 20:30 - 21:30 1.00 PERF COMP PJSM. POH LD 15 jts 4" DP. Flow check. Observe well dead. 21:30 - 00:00 2.50 PERF COMP Con't POH LD DP, flow check well every 60 jts. 3/17/2001 00:00 - 06:30 6.50 PERF COMP PJSM. Con't POH w/perf guns laying down 4" DP. Flow checks every 60 jts, showing well static. 06:30 - 07:30 1.00 PERF COMP PJSM. Slip & cut drlg line. 07:30 - 08:00 0.50 PERF COMP Con't POH laying down 4" DP 08:00 - 09:00 1.00 PERF COMP PJSM. LD jars, packer, safety jt. Break all service connections. RU 2 7~8" DP handling equipment. 09:00 - 15:00 6.00 PERF COMP Con't POH w/perf guns laying down 2 7/8" DP. 15:00 - 16:00 1.00 PERF COMP PJSM. LD perf guns. Flow check. Well static. 16:00 - 18:00 2.00 RUNCO~ COMP Clear floor. Pull wear bushing. RU 4 1/2" completion handling tools. 18:00 - 00:00 6.00 RUNCO~ COMP PJSM. MU & RIH w/4 1/2" completion from pipe shed. 3/18/2001 00:00 - 02:00 2.00 RUNCO~ COMP PJSM. MU & RIH w/4 1/2" completion, pick up from pipe shed. 02:00 - 03:00 1.00 RUNCO~ COMP MU TRSSSV, connect control line test same 5,000 psi OK. 03:00 - 06:00 3.00 RUNCO~ COMP Con't RIH w/4 1/2" completion putting bands on every joint for control line. Use 50 SS bands. 06:00 - 08:00 2.00 RUNCO~ ~1 COMP Sting into PBR @ 4 1/2" liner top 10,848 It to 10,859 It tubing tally. While spacing out completion string, control line was crimped while setting the slips. 08:00 - 09:00 1.00 RUNCOI~BARR COMP PJSM. RU to POH to lay down tbg. 09:00 - 12:00 3.00 RUNCOI~ARR COMP POH LD 4 1/2" tubing to TRSSSV. Recover 50 SS bands. 100% recovery. 12:00 - 13:30 1.50 RUNCOI~BARR COMP PJSM. MU new control line to TRSSSV test same 5,000 psi. OK. 13:30 - 16:00 2.50 RUNCOI~BARR COMP RIH w/4 1/2" completion putting bands on every joint for control line. MU 3 each pup jts, install one joint below tubing hanger. Use 55 SS bands. 16:00 - 17:00 1.00 RUNCOI~ COMP MU tubing hanger. Test control line 5,000 psi OK. Land tubing wi Printed: 4112/2001 10:27:03 AM BP EXPLORATION Page. 10 of 10 Operations Summa Report Legal Well Name: NK-12 Common Well Name: NK-12B Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/10/2001 End: Contractor Name: DOYON Rig Release: 3/19/2001 Group: RIG Rig Name: DOYON 14 Rig Number: · Sub Phase Description of Operations Date From-To Hours Task Code. . 3118/2001 16:00 - 17:00 1.00 RUNCOI~ COMP Re-entry guide @ 10,855 ft. RILDS. RU to displace annulus to inhibitive brine. 17:00 - 20:00 3.00 RUNCOI~ COMP PJSM. Test lines to 3,500 psi. OK. Displace annulus wi inhibitive 9.8 ppg brine ~} 3 BPM. 20:00 - 22:00 2.00 RUNCOI~ COMP Drop packer setting ball / rod. Pressure up down tubing 3,500 psi to set packer, leave pressure for 30 mins. OK. Bleed off tubing pressure to 1,500 psi, test annulus to 3,500 psi for 30 mins. OK. Bleed off tubing pressure to shear RP valve @ 600 psi tubing pressure. Bleed off pressure to 0 psi. 22:00 - 23:00 1.00 RUNCOI~I COMP LD landing joint. Install TWC, test from below 3,500 psi OK. 23:00 - 00:00 1.00 RUNCOI~! COMP Clear floor. PJSM. ND BOPE 311912001 00:00 ~ 02:00 2.00 RUNCOI~! COMP Complete ND BOPE, secure same for rig move 02:00 - 04:30 2.50 RUNCOI~I COMP NU production tree, test control line to 5,000 psi O-K. Test tree & adapter flange to 5,000 psi O-K. 04:30 - 05:30 1.00 RUNCOI~! !COMP RU DSM pull TWC valve w/lubricator. 05:30 - 08:00 2.50 RUNCOI~! COMP Freeze protect well to 3,336 ft w/138 bbls of diesel {~ 3 BPM w! 2,000 psi. U-tube & equalize. 08:00 - 09:00 1.00 RUNCOI~I COMP Install BPV w/lubricator. 09:00 - 11:00 2.00 RUNCOI~I COMP Secure well. Clean mud pits. Blow down circulating system. Printed: 4112/2001 10:27:03 AM ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Niakuk Well ..................... : NK-12B API number ............... : 50-029-22414-02 Engineer ................. : A. Nutter COUNTY: ....' .............. : Doyon 14 STATE: ................... : Alaska 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 ....... : 18.70 ft KB above permanent ....... : ....-~.. DF above permanent ....... : - 51.88 ft Vertical section origin Latitude (+N/S-) ......... : 0.00 ft Departure (+E/W-) ........ : 0.00 ft Platform reference point, Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 323.48 degrees 24-Feb-2001 07:05:49 Page 1 of 7 Spud date ................ : 14-Feb-01 Last survey date ......... : 24-Feb-01 Total accepted surveys...: 171 MD of first survey ....... : 0.00 ft MD of last survey ........ : 16550.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 13-Feb-2001 Magnetic field strength..: 1150.12 HCNT Magnetic dec (+E/W-) ..... : 27.05 degrees Magnetic dip ............. : 80.87 degrees MWD survey Reference Criteria -- Reference G .............. : 1002.68 mGal Reference H .............. : 1150.12 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-) ..... : 27.05 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.05 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6 lC 08] ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 07:05:49 Page 2 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 2 91.88 0.24 195.09 3 191.88 '0.21 194.47 4 291.88 0.22 173.63 5 391.88 0.03 331.81 6 491.88 0.55 13.08 7 591.88 1.03 24.72 8 691.88 3.67 12.83 9 791.88 5.53 7.26 10 891.88 6.01 6.71 11 991.88 7.39 8.25 12 1091.88 8.65 7.51 13 1191.88 9.62 6.60 14 1291.88 10.16 4.98 15 1391.88 11.34 3.24 16 1491.88 12.15 2.85 17 1591.88 13.60 2.82 18 1691.88 15.52 4.34 19 1791.88 16.21 3.22 20 1891.88 18.10 0.68 21 1991.88 20.74 357.11 22 2091.88 22.18 357.88 23 2191.88 23.94 359.17 24 2291.88 25.89 356.49 25 2391.88 26.54 356.08 26 2491.88 28.57 358.10 27 2591.88 31.00 356.97 28 2691.88 31.56 356.63 29 2791.88 32.13 356.86 30 2891.88 34.75 357.68 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft).- (ft) 0.00 0.00 0.00 0.00 91.88 91.88 -0.12 -0.19 100.00 191.88 -0.36 -0.57 100.00 291.88 -0.65 -0.93 100.00 391.88 -0.79 -1.10 100.00 491.88 -0.45 -0.61 100.00 591.87 0.29 0.67 100.00 691.77 2.81 4.61 100.00 791.45 8.38 12.51 100.00 890.94 15.67 22.49 100.00 990.26 24.05 34.06 100.00 1089.28 34.02 47.88 100.00 1188.01 45.53 63.63 100.00 1286.52 58.23 80.72 100.00 1384.76 72.40 99.32 100.00 1482.67 88.09 119.65 100.00 1580.15 105.32 141.90 100~00 1676.94 124.53 166.99 100.00 1773.13 145.39 194.27 100.00 1868.68 168.49 223.74 100.00 1962.98 195.62 256.96 100.00 2056.05 225.93 293.51 100.00 2148.05 257.99 332.66 100.00 2238.74 292.78 374.75 100.00 2328.46 329.91 418.83 100.00 100.00 100.00 100.00 100.00 0 -0 -0 -0 -0 .O0 .05 .15 .17 .17 -0 0 1 2 4 .07 .41 .50 .82 .04 5 7 9 11 12 .58 .48 .43 .15 .47 13.55 14.65 16.24 18.04 19.01 18.30 16.71 15.72 14.09 11.22 2417.11 368.42 465.02 8.90 2503.90 409.58 514.64 6.75 2589.36 452.96 566.48 3.85 2674.31 497.08 619.16 0.85 2757.75 542.86 674.20 -1.76 Total displ (ft) At Azim (deg) .00 .19 .59 .95 .11 0.00 195.09 194.90 190.61 188.57 0 0 4 12 22 .61 .79 .85 .83 .85 186.51 31.64 18.04 12.71 10.19 34 48 64 81 100 .51 .46 .33 .49 .10 9.30 8.88 8.43 7.87 7.16 120 142 167 195 224 .41 .66 .78 .10 .54 6.46 5.90 5.56 5.31 4.86 257 293 333 375 418 .61 .99 .03 .01 .98 4.07 3.26 2.71 2.15 1.53 465.11 514.69 566.50 619.16 674.20 1.10 0.75 0.39 0.08 359.85 DLS (deg 100f 0.00 0.26 0.03 0.08 0.25 0.53 0.50 2.67 1.91 0.48 1.39 1.26 0.98 0.61 1.22 0.81 1.45 1.96 0.75 2.03 2.89 1.47 1.83 2.25 0.67 2.23 2.49 0.59 0.58 2.66 Srvy Tool / tool qual ) type type 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 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 MWD M MWD M MWD M [(c)2001 Anadrill IDEAL ID6 lC 08] ANADRILL SCHLUMBERGER.Survey Report 24-Feb-2001 07:05:49 Page 3 of 7 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 31 2991.88 36.04 356.30 100.00 32 3091.88 36.50 358.52 100.00 33 3191.88 38.87 356.64 100.00 34 3291.88 39.97 356.35 100.00 35 3391.88 39.85 356.78 100.00 36 3491.88 41.24 358.21 100.00 37 3591.88 43.38 357.29 100.00 38 3691.88 44.72 357.32 100.00 39 3791.88 45.13 358.72 100.00 40 3891.88 45.37 1.33 100.00 41 3991.88 45.81 2.41 100.00 42 4091.88 45.31 0.30 100.00 43 4191.88 44.45 0.03 100.00 44 4291.88 44.53 357.42 100.00 45 4391.88 43.64 354.62 100.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- disPl Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 2839.26 591.16 732.03 -4.81 732.05 2919.89 640.24 791.13 -7.48 791.16 2999.03 690.86 852.19 -10.08 852.25 3076.28 744.11 915.57 -13.97 915.68 3152.98 797.87 979.61 -17.81 979.78 3228.97 3302.92 3374.79 3445.60 3516.00 3585.98 3656.00 3726.86 3798.20 3870.04 46 4491.88 42.84 351.57 100.00 3942.90 47 4591.88 42.55 351.84 100.00 4016.39 48 4691.88 42.44 352.67 100.00 4090.13 49 4791.88 41.50 353.23 100.00 4164.48 50 4891.88 42.73 349.81 100.00 4238.67 51 4991.88 44.62 344.81 100.00 4311.01 52 5091.88 45.59 342.25 100.00 4381.60 53 5191.88 48.63 340.99 100.00 4449.65 54 5291.88 51.77 336.90 100.00 4513.67 55 5391.88 53.95 332.49 100.00 4574.06 56 5491.88 54.90 328.28 100.00 57 5591.88 56.61 325.07 100.00 58 5691.88 58.11 323.54 100.00 59 5791.88 58.85 320.48 100.00 60 58'91.88 58.97 321.10 100.00 4632.25 4688.54 4742.47 4794.76 4846.40 851.74 1044.55 -20.64 1044.76 907.37 1111.81 -23.30 1112.05 965.12 1181.26 -26.56 1181.56 1023.29 1251.83 -29.00 1252.17 1080.33 1322.84 -28.97 1323.15 1136.32 1394.23 -26.63 1394.49 1192.67 1465.60 -24.94 1465.81 1249.25 1536.16 -24.73 1536.36 1306.48 1606.21 -26.29 1606.43 1365.11 1675.60 -31.11 1675.89 1424.64 1743.60 1484.39 1810.70 1543.60 1877.63 1601.82 1944.00 1661.00 2010.30 -39.33 -49.11 -58.22 -66.43 -76.34 1744.04 1811.36 1878.53 1945.13 2011.75 Srvy tool type 359.62 1.52 MWD M -- 359.46 1.39 MWD M -- 359.32 2.63 MWD M 359.13 1.12 MWD M 358.96 0.30 MWD M -- 358.87 1.67 MWD M -- 358.80 2.23 MWD M 358.71 1.34 MWD M 358.67 1.07 MWD M -- 358.75 1.87 MWD M -- 1724.15 2077.61 -91.55 2079.63 1790.69 2145.53 -111.64 2148.43 1860.31 2215.04 -134.76 2219.14 1934.34 2286.68 -162.40 2292.44 2012.50 2358.69 -196.50 2366.87 358.91 0.89 MWD M 359.03 1.59 MWD M -- 359.08 0.88 MWD M -- 359.06 1.83 MWD M -- 358.94 2.14 MWD M 358.71 2.24 MWD M 358.45 0.34 MWD M 358.22 0.57 MWD M -- 358.04 1.01 MWD M -- 357.83 2.60 MWD M 357.48 3.94 MWD M 357.02 2.06 MWD M 356.52 3.18 MWD M -- 355.94 4.44 MWD M -- 355.24 4.14 MWD M 2093.22 2429.37 -236.69 2440.87 354.44 3.55 2175.73 2498.41 -282.12 2514.29 353.56 3.16 2259.93 2566.79 -331.25 2588.07 352.65 1.98 2345.13 2633.95 -383.72 2661.76 351.71 2.71 2430.67 2700.30 -437.86 2735.57 350.79 0.54 MWD M -- MWD M -- MWD M MWD M MWD M Tool qual type [(c)2001 Anadrill IDEAL ID6 lC 08] -- -- ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 07:05:49 Page 4 of 7 Seq Measured Incl Azimuth Course ~ depth 'angle angle length - (ft) (deg). (deg) (ft) 61 5991.88 58.22 322.50 100.00 62 6091.88 58.42 322.03 100.00 63 6191.88 58.23 321.58 100.00 64 6291.88 59.63 322.12 100.00 65 6391.88 60.07 321.66 100.00 66 6491.88 59.44 321.94 100.00 67 6591.88 59.30 322.69 100.00 68 6691.88 59.16 321.33 100.00 69 6791.88 59.04 321.88 100.00 70 6891.88 58.77 324.36'100.00 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 4898.51 2515.98 2767.37 -490.64 2810.53 4951.03 2601.06 2834.67 -542.72 2886.16 5003.54 2686.12 2901.56 -595.34 2962.00 5055.14 2771.74 2968.91 -648.25 3038.86 5105.37 2858.18 3036.95 -701.62 3116.94 5155.74 2944.53 3104.84 -755.04 '3195.33 5206.69 3030.56 3172.94 -807.64 3274.11 5257.85 3116.45 3240.65 -860.53 3352.96 5309.21 3202.21 3307.90 -913.82 3431.80 5360.86 3287.83 3376.39 -965.21 3511.64 71 6991.88 59.23 321.77 100.00 5412.37 72 7091.88 58.90 322.82 100.00 5463.77 73 7191.88 59.62 324.17 100.00 5514.89 74 7291.88 60.85 323.18 100.00 5564.54 75 7391.88 61.39 323.16 100.00 5612.83 76 7491.88 60.52 322.79 100.00 5661.38 77 7591.88 60.17 323.39 100.00 5710.86 78 7691.88 60.77 325.62 100~00 5760.15 79 7791.88 61.44 323.93 100.00 5808.48 80 7891.88 61.77 323.86 100.00 5856.03 81 7991.88 61.73 326.40- 100.00 82 8091.88 61.76 326.79 100.00 83 8191.88 62.60 327.61 100.00 84 8291.88 62.21 325.40 100.00 85 8391.88 62.03 323.47 100.00 86 8491.88 62.47 322.38 100.00 87 8591.88 62.53 324.28 100.00 88 8691.88 62.78 322.95 100.00 89 8791.88 62.80 321.92 100.00 90 8891.88 62.83 323.93 100.00 5903.37 5950.71 5997.38 6043.70 6090.47 6137.03 6183.21 6229.15 6274.87 6320.56 3373.53 3459.29 3545.23 3632.03 3719.60 3807.02 3893.92 3980.90 4068.43 4156.39 4244.43 4332.39 4420.64 4509.14 4597.51 4686.00 4774.70 4863.52 4952.44 5041.38 3444.89 -1016.71 3512.75 -1069.17 3581.84 -1120.30 3651.77 -1171.72 3721.85 -1224.21 3791.65 -1276.85 3861.14 -1329.04 3931.97 -1379.55 4003.49 -1430.05 4074.56 -1481.89 41'46.82 -1532.25 4220.36 -1580.74 4294.70 -1628.65 4368.60 -1677.55 4440.50 -1728.96 4511.10 -1782.31 4582.25 -1835.28 4653.75 -1887.97 4724.24 -'1942.19 4795.21 -1995.81 Srvy tool type 349.95 1.41 MWD M 349.16 0.45 MWD M 348.40 0.43 MWD M 347.68 1.47 MWD M 346.99 0.59 MWD M 3591.79 3671.86 3752.95 3835.15 3918.02 346.33 0.67 MWD M 345.72 0.66 MWD M 345.13 1.18 MWD M 344.56 0.49 MWD M 344.05 2.14 MWD M 343.56 2.27 MWD M 343.07 0.96 MWD M 342.63 1.37 MWD M 342.21 1.50 MWD M 341.79 0.54 MWD M 4000.87 341.39 0.93 4083.47 341.01 0.63 4166.96 340.67 2.03 4251.23 340.34 1.62 4335.67 340.01 0.34 4420.85 339.72 2.24 4506.68 339.47 0.34 4593.14 339.23 1.11 4679.62 338.99 2.00 4765.22 338.73 1.72 4850.43 338.44 1.06 4936.11 338.17 1.69 5022.13 337.92 1.21 5107.89 337.65 0.92 5193.97 337.40 1.79 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 MWD M MWD M Tool qual type [ (c)2001 Anadrill IDEAL ID6 lC 08] ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 07:05:49 Page 5 of 7 Seq Measured Incl AzimUth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 91 8991.88 63.14 323.37 92 9091.88 61.69 323.42 93 9191.88 60.55 323.02 94 9291.88 59.45 324.08 95 9391.88 59.77 325.76 96 9491.88 59.85 326.42 97 9591.88 59.32 324.26 98 9691.88 59.55 323.02 99 9791.88 58.82 322.80 100 9891.88 58.33 323.29 101 9991.88 58.41 323.26 102 10091.88 58.08 323.02 103 10191.88 58.58 323.46 104 10291.88 58.36 320.32 105 10391.88 58.74 320.40 106 10491.88 58.59 319.93 107 10591.88 58.53 319.16 108 10691.88 58.22 320.01 109 10791.88 58.64 320.27 110 10891.88 58.68 318.55 111 10991.88 59.72 319.34 112 11092.00 60.65 320.74 113 11104.00 61.59 322.81 114 11134.33 59.57 324.12 115 11231.54 59.87 328.18 116 11325.70 66.05 331.94 117 11423.21 70.30 336.06 118 11519.35 74.34 335.24 119 11618.59 74.99 333.57 120 11714.08 74.65 329.50 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.12 12.00 30.33 97.21 94.16 97.51 96.14 99.24 95.49 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 6365.99 6412.29 6460.59 6510.59 6561.18 6611.47 6662.10 6712.95 6764.18 6816.31 6868.76 6921.39 6973.89 7026.19 7078.37 7130.37 7182.53 7234.97 7287.33 7339.34 7390.54 7440.32 7446.12 7461.02 7510.05 7552.85 7589.10 7618.30 7644.54 7669.56 5130.47 5219.10 5306.66 5393.26 5479.49 5565.83 5652.02 5738.12 5824.00 5909.33 5994.47 6079.50 6164.61 6249.79 6334.98 6420.25 6505.36 6590.32 6675.37 6760.56 6846.19 6932.89 6943.40 6969.81 7053.64 7136.89 7225.83 7315.35 7409.32 7500.55 4866.96 -2048.61 4938.11 -2101.46 5008.25 -2153.89 5077.90 -2205.34 5148.49 -2254.92 5220.22 -2303.14 5291.15 -2352.17 5360.49 -2403.22 5429.00 -2455.01 5497.19 -2506.31 5565.43 -2557.23 5633.47 -2608.23 5701.65 -2659.17 5768.71 -2711.76 5834.40 -2766.19 5899.99 -2820.90 5964.91 -2876.26 6029.74 -2931.46 6095.14 -2986.07 6159.99 -3041.64 6224.77 -3098.05 6291.35 -3153.83 6299.60 -3160.33 6320.83 -3176.06 6390.53 -3222.80 6463.19 -3264.56 6544.53 -3304.18 6627.95 -3341.95 6714.27 -3383.29 6795.26 -3427.20 5280.54 5366.67 5451.77 5536.12 5620.64 Srvy tool type 5705.71 5790.43 5874.55 5958.28 6041.58 337.17 0.59 MWD M 336.95 1.45 MWD M 336.73 1.19 MWD M 336.52 1.43 MWD M 336.35 1.48 MWD M 6124.82 6207.96 6291.26 6374.29 6456.94 336.19 0.58 MWD M 336.03 1.94 MWD M 335.85 1.09 MWD M 335.67 0.75 MWD M 335.49 0.64 MWD M 6539.67 6622.16 6704.57 6787.29 6870.01 335.32 0.08 MWD M 335.16 0.39 MWD M 335.00 0.62 MWD M 334.82 2.69 MWD M 334.63 0.39 MWD M 6953.10 7037.59 7047.89 7073.91 7157.18 334.45 0.43 MWD M 334.26 0.66 MWD M 334.07 0.79 MWD M 333.90 0.47 MWD M 333.72 1.47 MWD M 7240.87 7331.33 7422.83 7518.51 7610.61 333.54 1.24 333.38 1.53 333.36 17.01 333.32 7.65 333.24 3.62 MWD M MWD MWD M MWD MWD 333.20 7.46 MWD 333.21 5.86 IMP 333.24 4.28 IMP 333.26 1.75 IMP 333.24 4.13 IMP Tool qual type 6-axis 6-axis 6-axis 6-axis [(c) 2001 Anadrill IDEAL ID6 lC 08] ANADRILL SCHLUMBERGER Survey Report 24-Feb-2001 07:05:49 Page 6 of 7 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 11810.41 75.52 329.33 122 11906.57 76.57 329.05 123 12002.13 77.53 328.88 124 12098.52 77.63 325.89 125 12195.19 76.42 325.09 126 12289.95 '74.33 324.69 127 12386.02 75.13 323.66 128 12482.77 76.24 323.31 129 12576.67 76.27 321.75 130 12671.39 77.67 320.58 131 12768.01 78.16 321.96 132 12863.95 77.70 320.74 133 12961.04 78.75 320.39 134 13057.34 77.39 320.23 135 13152.17 78.26 320.11 136 13247.09 77.25 319.74 137 13343.47 77.71 319.34 138 13440.37 78.68 319.54 139 13533.45 77.55 318.59 140 13627.14 78.23 319.22 141 13721.52 78.86 317.56 142 13818.57 77.80 317.08 143 13914.45 76.40 318.42 144 14009.05 76.47 317.83 145 14107.20 77.41 316.68 146 14201.92 76.51 318.27 147 14300.25 73.71 320.06 148 14394.53 71.24 321.19 149 14490.95 69.95 322.91 150 14588.11 67.89 324.48 96.33 96.16 95.56 96.39 96.67 94.76 96.07 96.75 93.90 94.72 96.62 95.94 97.09 96.30 94.83 94.92 96.38 96.90 93.08 93.69 94.38 97.05 95.88 94.60 98.15 94.72 98.33 94.28 96.42 97.16 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 7694.35 7717.54 7738.96 7759.69 7781.40 7805.32 7830.62 7854.54 7876.86 7898.21 7918.44 7938.50 7958.32 7978.22 7998.22 8018.36 8039.25 8059.07 8078.24 8097.90 8116.64 8136.27 8157.68 8179.87 8202.05 8223.42 8248.69 8277.08 8309.11 8344.06 7593.13 7685.99 7778.69 7872.60 7966.74 8058.39 8151.06 8244.81 8336.00 8428.21 8522.61 8616.36 8711.29 8805.36 8897.90 8990.48 9084.35 9178.96 9269.77 9361.08 9453.22 9547.71 9640.70 9732.26 9827.30 9919.07 10013.81 10103.59 10194.50 10285.15 6875.40 -3474.57 6955.55 -3522.37 7035.34 -3570.38 7114.62 -3621.11 7192.25 -3674.48 7703.49 333.19 0.92 7796.58 333.14 1.13 7889.47 333.09 1.02 7983.13 333.03 3.03 8076.52 332.94 1.49 7267.25 -3727.21 7342.39 -3781.45 7417.73 -3837.24 7490.12 -3892.72 7562.00 -3950.59 8167.31 8258.94 8351.48 8441.28 8531.77 Srvy tool type 7635.70 -4009.70 7708.97 -4068.29 7782.38 -4128.66 7854.88 -4188.83 7926.07 -4248.21 8624.48 8716.61 8809.73 8901.99 8992.76 IMP IMP IMP IMP IMP 7997.05 -4307.92 8068.64 -4368.98 8140.70 -4430.66 8209.50 -4490.33 8278.54 -4550.54 9083.56 9175.56 9268.31 9357.30 9446.78 332.85 2.24 IMP 332.75 1.33 IMP 332.65 1.20 IMP 332.54 1.61 IMP 332.42 1.91 IMP 8347.70 -4611.97 8417.57 -4676.40 8486.74 -4739.23 8555.22 -4800.62 8625.43 -4865.51 9537.00 9629.34 9720.35 9810.08 9903.09 332.29 1.49 IMP 332.18 1.33 IMP 332.05 1.14 IMP 331.93 1.42 IMP 331.81 0.93 IMP 8693.43 -4927.88 9992.99 8765.31 -4990.02 10086.18 8834.80 -5047.05 10174.79 8906.50 -5102.98 10264.80 8979.55 -5156.66 10354.87 331.69 1.13 IMP 331.57 0.63 IMP 331.44 1.02 IMP 331.32 1.57 IMP 331.20 0.98 IMP 331.08 1.85 IMP 330.95 1.19 IMP 330.82 2.00 IMP 330.70 0.61 IMP 330.57 1.49 IMP 330.45 1.89 IMP 330.35 3.35 IMP 330.26 2.86 IMP 330.19 2.15 IMP 330.13 2.60 IMP 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 08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 151 14683.40 68.13 324.99 152 14775.77 61.65 325.55 153 14867.26 55.23 324.61 154 14963.51 54.40 325.07 155 15062.53 53.83 325.18 95.29 92.37 91.49 96.25 99.02 156 15155.81 54.31 323.97 157 15254.33 55.30 322.68 158 15350.25 56.00 322.67 159 15446.78 56.60 323.01 160 15542.63 57.02 321.86 93.28 98.52 95.92 96.53 95.85 161 15639.06 57.66 321.21 162 15736.64 58.96 321.88 163 15830.63 58.96 320.80 164 15924.29 59.37 321.25 165 16020.04 59.82 321.58 96.43 97.58 93.99 93.66 95.75 166 16116.21 60.24 321.06 167 16212.01 61.13 321.10 168 16307.17 61.92 321.29 169 16405.96 63.10 321.42 170 16493.23 63.74 321.83 96.17 95.80 95.16 98.79 87.27 Final Survey Projected at TD 171 16550.00 63.74 321.83 56.77 24-Feb-2001 07:05:49 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 8379.74 8418.91 8466.78 8522.24 8580.28 8635.02 8691.80 8745.92 8799.48 8851.95 8903.99 8955.25 9003.72 9051.72 9100.18 9148.23 9195.13 9240.50 9286.10 9325.15 9350.27 10373.49 10457.04 10534.93 10613.57 10693.76 9051.69 -5207.67 10442.84 9120.39 -5255.31 10526.14 9184.29 -5299.89 10603.77 9248.60 -5345.19 10682.12 9314.42 -5391.06 10762.06 330.09 330.05 330.01 329.97 329.94 10769.28 10849.78 10928.97 11009.27 11089.47 9375.96 -5434.84 10837.26 9440.53 -5482.93 10917.24 9503.50 -5530.95 10995.81 9567.50 -5579.46 11075.53 9631.08 -5628.36 11155.10 329.90 329.85 329.80 329.75 329.70 11170.60 11253.58 11334.06 11414.40 11496.93 9694.64 -5678.86 11235.46 9759.67 -5730.49 11317.67 9822.55 -5780.80 11397.37 9885.07 -5831.38 11476.92 9949.62 -5882.89 11558.69 329.64 329.58 329.52 329.46 329.41 11580.18 10014.66 -5934.95 11641.18 11663.64 10079.65 -5987.43 11723.85 11747.22 10144.83 -6039.85 11806.67 11834.79 10213.28 -6094.58 11893.48 '11912.80 10274.46 -6143.03 11970.85 329.35 329.29 329.23 329.17 329.13 11963.69 10314.49 -6174.49 12021.36 329.09 7 of 7 DLS Srvy Tool (deg/ tool qual 100f) type type 0.56 7.04 7.07 0.95 0.58 1.17 1.47 0.73 0.69 1.10 0.87 1.45 0.98 0.60 0.56 0.64 0.93 0.85 1.20 0.85 0.00 IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis MWD - IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis IMP 6-axis Projected [(c)2001 Anadrill IDEAL ID6 lC 08] -- -- ~ILA OIL AND GAS CONSERYA~I~ION COP~ISSIO~V Dan Stone Senior Petroleum Engineer, ENS BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. 7'm AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Niakuk NK- 12B BP Exploration (Alaska) Inc. Permit No: 201-015 Sur Loc: 1327'NSL, 996'WEL, Sec. 36, T12N, R15E, UM Btmhole Loc. 927'NSL, 1728'WEL, Sec. 23, 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~'d:~ day of February, 2001 dlffEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA~" .~. AND GAS CONSERVATION COMI~i SION PERMIT TO DRILL 20 AAC 25.005 I r"l Exploratory ~, Stratigraphic Test [] Development Oil la' Type of work ~ Drill [] Redrill lb. Type of well U Re-Entry [] Deepen Service Development Gas Si! Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB')' 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 53.4' Niakuk Oil Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ~. ;~'~'C~ A,D~I~034625 4. Location of well at surface 7. Unit or P~perty Name 11. Type Bond (See 2O AAC 25.025) 1327' NSL, 996' WEL, SEC. 36, T12N, R15E, UM Niakuk At top of productive interval 8. Well Number 837' NSL, 1662' WEL, SEC. 23, T12N, R15E, UM NK-12B Number 2S100302630-277 At total depth 9. Approximate spud date 927' NSL, 1728' WEL, SEC. 23, T12N, R15E, UM 02/05/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034630, 927' MDI NK-02 is 380' away at 15252.' 2560 16374' MD / 9303' TVD 16. TO be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11000' MD Maximum Hole Angle 73 ° Maximum surface 2991 psig, At total depth (TVD) 9090' / 3900 psig 18. Casing Program' Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casine Weieht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 6-3/4" 4-1/2" 12.6# L-80 I BT-M 5524' 10850' 7325' 16386' 9303' 20-7.,¢u ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen operations. -J,~ ~V J~ $ ~001 Present well condition summary Alaska Oil& Gas COns. Commission Total depth: measured 15040 feet Plugs (measured) true vertical 9476 feet Anchorage Effective depth: measured 14944 feet Junk (measured) true vertical 9430 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 280 cuft Arctic Set (Approx.) 80' 80' Surface 4724' 10-3/4" 435 cu ft Class 'G' 4764' 4146' Intermediate Production 14986' 7-5/8" 806 cuft Class 'G' 15024' 9468' Liner Perforation depth: measured 14466' - 14551', 14563' - 14583' true vertical 9208' - 9190', 9241' - 9251' 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: Scott, KolStad, 564'5347 Prepared By Name/Number. Terrie Hubble, 564-4628 21. I hereby certifY that the foregoing is true an~ correct to the best of my knoWledge Signed Dan Stone ¢~..-.~..~.. 3~"~-). ~ Title Senior Petroleum Engineer, ENS Date % / I ~ f% I ,"'~'~I! ~ t' t"~'~ I ~,~?~" ,' ll~l~itll ' ~r ' . ' ' ' .' ~. !..~. ..... ' tf~'~ ~ I ~ ' "~1 '~ "'~ ........ ,' '!',~n',~ ~', Permit Number APl Number A,,13/orov~al Date See cover letter ~.~)/'-" ~,/,~--' 50- 029-22414-02 '('/~ t~-- '~ I for other requirements Conditions of Approval: Samples Required [] Yes I~ No Mud Log Required [] Yes I~ No Hydrogen Sulfide Measures ~ Yes [] No Directional Survey Required I~ Yes [] No Required Working Pressure for DOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ]~3.5K ~ Othe(~RIGiNAL $1GI~..::.I,.', ~:~ ,. by order of Approved By D Taylor Seamount Commissioner the commission Date o¢~''~'''' ~)// Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate I Well Name: I NK-12B Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Producer Surface Location: Target Location: Kuparuk Sands Bottom Hole Location: X = 721,567.13 Y = 5,979,862.62 1,327' FSL 996' FEL T 12N, R 15E, S 36 Umiat X = 715,324 Y = 5,989,755 837' FSL 1,662' FELT 12N, R 15E, S23 Umiat X = 715,255 Y = 5,989,843 927' FSL 1,729' FEL T 12N, R 15E, S23 Umiat I AFE Number: 15L0505 I I Estimated Start Date: 12/05/2001 IMD=116,374'1 I TVD=19,303' I Rig: I Doyon 14 I I Operating days to complete: 124 I I GL/MSL: 1~8.9' I I RKB= 153.4' I I Well Design (conventional, slimhole, etc.): 16 3A,, Sidetrack I Objective: I Kuparuk Reservoir Mud Program: 6-3/4" Intermediate / Production hole: Freshwater LSND Interval Density Viscosity YP PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate KOP to 9.6 - 9.8 40-50 15-20 8-12 8.5 - 9.5 6 - 8 cc -200' above Tuffs H RZ - TD 10.4 - 10.745 - 60 18 - 28 10 - 16 8.5 - 9.5 <5 <9 Directional: KOP: I ~11,000' MD Maximum Hole Angle: Close Approach Wells: 73° Tangent NK-02, 380' cntr to cntr distance encountered at 15,252' NK-02A, 487' cntr to cnter distance at 15,308' RECEIVED JAN I 9 ~001 Alaska 0il & Gas Cons, Commission Anchorage NK-12B Permit to Drill Page 1 Logging Program: Intermediate ! Production Hole Drilling: MWD / GR / Res / Neu / Den / PWD Open Hole: None Cased Hole: None Formation Markers: Formation Tops MDbkb TVDss Comments SV5 3660' Not Penetrated SV 4 3950' ,, SV3 / T5 4300' ,, SV2 4490' ,, SV1 4900' ,, UG4 5380' ,, WS-2 6580' ,, TWSK 7190' KOP at base of WSK. 40' vertical uncertainty -11,000' -7350' KOP CM-3 -11,155' 7400' 40' vertical uncertainty TUFFS -14,882' 8450' 40' vertical uncertainty HRZ -15,950' 8940' 40' vertical uncertainty Kuparuk -16,130' 9090' 20' vertical uncertainty T Kingak -16,325' 9238' 20' vertical uncertainty TD -16,374' 9303' Casin! I/Tubinq Proqram: Hole Csg! Wt/Ft Grade Conn Length Top Btm Size Tb9 O.D. MD/TVD MD/TVD bkb 6-3/4" 4 ~" 12.6# L-80 IBTM 5,524' 10,850'/ 16,374'/9303' 7,325' Tubing 4 Y2" 12.6# L-80 IBTM -10,850' Surface 10,850' / 7,325' Cement Calculations: Casin¢, Size 14 Y2" Liner Basis: Lead: N/A Lead TOC: N/A I Total Cement Volume: Tail: Based on TOC 1000' MD above top of Kuparuk formation with 50% excess and 82' shoe track. Tail TOC: 15,122' MD, 8,565' TVDbkb Lead IN/A ;;)~ ~3- I Tail I ~ bbls / ~ft~/,,1~ sks of Dowell Premium 'G' at I 15.8 ppg and 1.17 cf/sk. RECEIVED JAN [ 9 ZOO! NK-12B Permit to Drill Alaska 0il & Gas Cons. Commission Page 2 Anchorage Well Control: For intermediate hole drilling, 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 BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- , Maximum anticipated BHP: · Maximum surface pressure: 3,900 psi @ 9,090' TVDss - Kuparuk Sands 2,991 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 3500 psi (required for casing test) 9.0 ppg NaCI brine / 2,200' of 6.8 ppg Diesel (This provides 196 psi over balance assuming 3,900 psi in the Kuparuk) Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · 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 recently measured on NK Pad: 40 ppm from NK-14, 1/7/01. Closest surface location measured recently(~60' away): 40 ppm from NK-14, 1/7/01. Recent data from nearest BHL: 20 ppm from NK-29, 1/1/01. DRILLING CLOSE APPROACH: All wells pass BP close approach guidelines. Wells NK-02 and NK-02A are the closest wells to the NK-12B well bore. Both of these well bores are plugged and abandoned and therefore are a minimal risk. Disposal'. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. NK-12B Permit to Drill RECEIVED JAN 1 9 2001 Alaska Oil & Gas Cons. Commission Anchorage Page 3 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: 1. P&A with CTU as per Sundry. 2. Cut tubing. 3. Cimulate well to kill weight fluid. 4. Pressure test casing and tubing pack offs. 5. Install BPV. 6. If necessary, level the pad and prepare location for rig move. 7. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Ri.q 1. 2. 3. 4. 5. 6. . . . 10. 11. 12. 13. 14. 15. Operations: MIRU Doyon 14. Circulate 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 7-5/8" window milling assembly and RIH to top of tubing stub. POOH. RU E-line and set ClBP to place KOP in a clean sandstone at the base of the West Sak at -11,000' MD. To avoid cutting a casing collar, set the BP 2' - 3' above a collar. RIH with 7-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock as necessary and set. M.!!I w~in,.,d,,o,,w~in.,,.7-5/8" casi,n,g..Ped, o. rm. FI,'F te,.s.t..PO..OH, , .~'3..,~, ,~_~,? __~, ~'V~ t~/;~.r..i, . RIH w~[n t~ a/,~ anmng assembly To wmpstocK. I~.ICK-O!! ana arm to/MHL ~ -fa aegrees inc,nafion. Continue to drill through Kuparuk Sand to Top Kingak dropping angle to -35 degrees inclination. Spot liner running pill. POOH w/DP. Run and cement a 4 W', 12.6 # production liner. Displace cement w/viscosified brine per[ pill followed by fresh water spacer and mud. Release from liner and circulate out excess cement and displace well to sea water. POOH. After cement has gained compressive strength, test the casing and liner from the landing collar to surface to 3J300 psi for 30 minutes ~ Drill pipe convey per[orate Kuparuk sands @ 6JSPF. :~:::~::~> ~'~ Install 4-1/2", 12.6# L80 tubing completion. Drop ball/rod & set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Freeze protect the well to -2200' and secure the well. 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 Spud Date: 2/05/2001 Scott Kolstad BP Alaska Drilling and Wells 564-5347 kolstasr@ bp.corn RECEIVED JAN 9 001 Ataska OiJ & Gas Co~s. Commission Anchorage NK-12B Permit to Drill Page 4 Job 1: MIRU Hazards and Contingencies ~ Well NK-11 and NK-13 are located 29.79' and 29.73' from NK-12 respectively. Confirm that the well has been shut in and depressurized (including annulus and header lines) prior to moving the rig. Reference RPs · :o "Drilling/Workover Close Proximity Surface and Subsurface Wells Procedure" Operational Specifics Job 2: Decomplete Well Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics Job 3: Run Whipstock Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics JAN .[ 9 ~001 Alaska Oil & Gas Cons. Commission Anchorage NK-12B Permit to Drill Page 5 Job 4: DrillinQ Intermediate/Production Hole Hazards and Contingencies :> No faults are expected along the proposed well path. The proposed path does drill over the top of a few faults and it is important not to let the well deviate too far below the line. :> Gas cut mud has been observed in the Ugnu and West Sak sands. This will be controlled with appropriate mud weights. A minimum of 9.2 ppg is recommended in the West Sak. ::> The NK-12B 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-12B 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 6 a,~,, open hole section would be -96 bbls assuming an influx from the Kuparuk at ~16,387' MD. This is a worst case scenario based on a 8.3 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 10 3/~,, shoe, and 10.5 ppg mud in the hole. Reference RPs Operational Specifics Job 5: Install 4 1/2" Production Liner Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .~. Operational Specifics RECEIVED · J~N 1 9 ~001 Alaska Oil & Gas Cons r,,,~;~s. ' .................................................. . ............ ..:::.~..::..~ ........ ..:.:~......: ........................... ~ ........ ~..:.:...: .............. ~....: ...... :...~....:.. . ~?~,~ ..... -,on NK-12B Permit to Drill Page 6 Job 6: DPC Perforate Hazards and Contingencies ~ The well will be perforated underbalanced. History has shown lost circulation to the formation is likely if the well is perforated overbalanced. A contingency of perforating the well post rig with coil tubing is being evaluated. Reference RPs Operational Specifics Job 7: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. Reference RPs Operational Specifics Job 8: NDINUIRelease Riq Hazards and Contingencies ~> No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics J/IN 1 ~ 2001 Alaska Oil & Gas Cons. Commission An~Or~e NK-12B Permit to Drill Page 7 NK-12B 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 recently measured on NK Pad: 40 ppm from NK-14, 1/7/01. Closest surface location measured recently(~60' away): 40 ppm from NK-14, 1/7/01. Recent data from nearest BHL: 20 ppm from NK-29, 1/1/01. Gas cut mud has been observed in the Ugnu and West Sak sands. This will be controlled with appropriate mud weights. A minimum of 9.2 ppg is recommended in the West Sak. The NK-12B 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-12B 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 6 aA" open hole section would be ~96 bbls assuming an influx from the Kuparuk at ~16,387' MD. This is a worst case scenario based on a 8.3 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 10 %" shoe, and 10.5 ppg mud in the hole. CONSULT THE Niakuk PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 RECEIVED dllN 1 9 ~001 Alaska Oil & Gas Cons. Commission Anchorage NK-12B Hazards and Contingencies Page ! of I Report Date: Client: Field: Structure I Slot: Well: Borehole: UWIIAP~: Proposal Name I Modified Date: Tort I AHD I DDI I ERD ratio: Grid Coordinate System: Location LaULong: Location Grid NIE Y/X: Grid Convergence Angle: Grid Scale Factor: NK-12B Proposed Well Profile - Geodetic Report January 15, 2001 Naska Ddlling & Wells Niakuk study NK-12BNK-12MainPadlNK-12Feasibiliflr 50-029-22414-02 NK-12B (P2) / January 15, 2001 205.697' 111010.19 ff / 6.60111.184 NAD27 Alaska State Planes, Zone 04, US Feet N 70 2050.155, W 148124.279 N 5979862.620 flUS, E 721567.130 itUS +1.69409073o 0.99995577 Survey I DLS Computation Method: Vertical Section Azimuth: Only v..c.. Section Origin: TVD Reference Datum: TVD Reference ElevaUon: Minimum Curvature / Lubinski 323.480° N 0.000 it, E 0.000 it KB 52.5 it relative to Mean Sea Level Magnetic Declination: 27.081° Total Field Strength: 57505.508 nT Magnetic Dip: 80.870° Declination Date: January 15, 2001 Magnetic Declination Model: BGGM 2000 North Reference: Tree North Total Corr Mag North -> True North: +27.081 ° Coordinate Reference To: Well Head Schlumberger Station ID Tie-In Survey Top Colville Top of Window Base of Whipstock KOP Crv 12/100 .DI 10992.50 10995.15 11000.00 11013.00 11025.00 Incl I (°) 59.72 59.75 59.79 61.87 61.87 (°) (ft) (it) (ft) 319.34 7391.16 6846.18 6224.75 319.38 7392.50 6848.46 6226.49 319.45 7394.94 6852.64 6229.67 319.45 7401.28 6863.96 6238.29 319.45 7406.93 6874.52 6246.34 (ft) -3098.05 -3099.54 -3102.27 -3109.65 -3116.53 DLS (~lOOfl) ~US) (flUS) 0.00 5985992.78 718286.56 1.64 5985994.47 718285.02 1.64 5985997.57 718282.20 16.00 5986005.97 718274.57 0.00 5986013.81 718267.45 Grid Coordinates Northing I Easting Geo~lraphic Coordinates Latitude I Longitude N 70 21 51.369 W 148 13 34.879 N 70 21 51.386 W 148 13 34.923 N 70 21 51.417 W 148 13 35.003 N 70 21 51.502 W 148 13 35.219 N 70 21 51.581 W 148 13 35.420 End Crv Drp 6/100 CMl / Tuffs 11100.00 11131.46 15307.91 15342.09 154OO.OO 70.46 74.08 74.08 72.03 68.55 322.40 7437.22 6942.98 6299.58 -3159.67 323.54 7446.79 6972.94 6323.49 -3177.71 323.54 8592.54 10989.16 9553.63 -5564.41 323.54 8602.50 11021.86 9579.92 -5583.83 323.54 8622.03 11076.36 9623.76 -5616.23 12.00 5986065.75 718222.76 12.00 5986089.12 718204.02 0.00 5989247.14 715722.99 6.00 5989272.84 715702.80 6.00 5989315.70 715669.12 N 70 21 52.104 W148 13 36.682 N 70 21 52.339 W148 13 37.210 N 70 22 24.094 W148 14 47.079 N 70 22 24.352 W148 14 47.648 N 70 22 24.783 W148 14 48.597 15500.00 15600.00 15700.00 15800.00 15900.00 62.55 56.55 50.55 44.55 38.55 323.54 8663.39 11167.35 9696.94 -5670.30 323.54 8714.05 11253.52 9766.25 -5721.51 323.54 8773.43 11333.93 9830.91 -5769.29 323.54 8840.89 11407.68 9890.23 -5813.12 323.54 8915.69 11473.98 9943.56 -5852.52 6.00 5989387.25 715612.91 6.00 5989455.01 715559.68 6.00 5989518.23 715510.01 6.00 5989576.22 715464.45 6.00 5989628.36 715423.49 RECEIVED N 70 22 25.502 W148 14 50.180 N 70 22 26.184 W148 14 51.680 N 70 22 26.819 W148 14 53.080 N 70 22 27.402 W148 1454.363 N 70 22 27.926 W148 14 55.517 NK-12B (P2) report.xls Page 1 of 2 JAN 1 9 2.001 Alaska Oil & Gas Cons. Commission Anchorage 1/15/2001-1:00 PM Station ID End Drp Top HRZ Kuparuk Target Kingak TD 15959.21 15959.69 16178.21 16178.21 16358.88 16373.53 Incl I 35.00 35.00 35.00 35.00 35.00 35.00 323.54 323.54 323.54 323.54 323.54 (fl) 8963.11 8963.50 9142.50 9142.50 9290.50 VSec 11509.43 11509.70 11635.04 11635.04 11738.67 NI'S I EI'WI (fl) (ft) 9972.06 -5873.58 9972.28 -5873.74 10073.09 -5948.23 10073.09 -5948.23 10156.44 -6009.81 323.54 9302.50 11747.07 10163.19 -6014.80 (°llOOfl) 6.00 0.00 0.00 0.00 0.00 Grid Coordinates I Northing I Eaating (flus) (flus) 5989656.23 715401.60 5989656.44 715401.43 5989755.00 715324.00 5989755.00 715324.00 5989836.49 715259.98 0.00 5989843.09 715254.79 OeogmphicCoordinates Latitude I Longitude N 70 22 28.207 W148 14 56.134 N 70 22 28.209 W148 14 56.139 N 70 22 29.200 W148 14 58.321 N 70 22 29.200 W148 14 58.321 N 70 22 30.019 W148 15 0.124 N 70 22 30.085 W148 15 0.271 Legal Description: Surface: 1326 FSL 996 FEL S36 T12N R15E UM Tie-In: 2271 FSL 4093 FEL S25 T12N R15E UM Target' 837 FSL 1662 FEL S23 T12N R15E UM BHL: 927 FSL 1729 FEL S23 T12N R15E UM No~hina(YirffUSl 5979862.62 5985992.78 5989755.00 5989843.09 Eastina {X)rffUSl 721567.13 718286.56 715324.00 715254.79 NK-12B (P2) report.xls Page 2 of 2 1/15/2001-1:00 PM VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: NK-12B (P2) Field: Niakuk Structure: Main Pad Section At: 323.48 deg Date: January 15, 2001 Schlumberger 0I 2000- 4000- Proposal Survey TleJn Survey1(~993 MD 7391 T'VD 59.72' 319.34°~az 6846departure Top of Window 11000 MD 7395 TVD / 59.79" 319.45' az 6853 departure / .l~eofWhipstock11013 MI:) 7401.' TVD / \ 6~1.87° 319.45" az 6864 depan'ure i / /';.i KOP Cw 12/10011025 MD ~'407 TVD ..L._.._7,:: ........... i..7 .._:.. 6~.:87.-.....319.45,.az..6875.de~l itu re .................................................... ! / / .-' End Crvl1131MD 74~,7TVD i / ;'" , ' ...-" 74.08' 323.64' az 69'~." departure .... Hold Angle 74.08° Dfp6/100 '~5308MD 8593TVD ............ ~ ................... ? ..................... 74:08'"' 32'~. :54' 'i~' 10989'dep~,'~tur e : · "' i End Drp 15959 MD 6963 T'VD '" i " 35.00' 323.54'az 11509 departure ; ; i Tawget 16178MD g142TVD ................ C~";/'T;'"~'~!5'~=2~{'D-5~'~"3~'~i ..................... i ......... i ................ F .... ~ ......... ? ............. ~" .......... i .......... 3~.~'""323.54' ~ 11635 depa~ure .............. T~,~ ~'~,D"~"~V~'- ~ .......... ~ ..... -t ~ ................... ~ '~]: :.': '. :' TD.'.'.163~4 MD 9303~ '~." '~'~ ~'"'~ ~ ~ ~K~2- -'~ ............ ~- ,K-~ I I I I 0 2000 4000 6000 8000 10000 12000 VeAical Section Depa~ure at 323.48 deg from (0.0, 0.0). (1 in = 2000 feet) PLAN VIEW Client: Alaska Drilling & Wells Well: NK-12B (P2) Field: Niakuk Structure: Main Pad Scale: i in = 2000 ft Date: 15-Jan-2001 Schlumberger A A A O Z I D O V V V -8000 -6000 -4000 -2000 0 I I I I 2000 1200( 10000- 8000- 60001 4O00 2000 -2000 True North Mag Dec ( E 27.08° ) 16374 MD 9303 TVD End Drp 35.00" 323.54"az '15959MD 8963TVD 10163N 6015W ' 35.00' 323.54'az · .' g972 N 5874 W ..... . '~ ...................... 15308 MD 8593 "I~D ,.~,, ..... ' ." ::~% 16178 MD 9143TVD ' X 3S.O0' 323.54' = . \~. NK-12A lOO7.. ,.9 w : 5._ \ %,\ i "~.~_ '~ B~se of Whlp~tm=kl1013 MD 74011TVD ' .3 8'J,87' 319.45'aZ 6238N 3110V~ , % ' '%o i' ~o.o,w,--llOOO,~D ,.',~3.79' 319.45'az 6230N 3102W / .--" End Crv11131MD 7447TVD ." i Tle.lnSuwey1099~MD 7391!TVD 74.08' 323.54'az 6323N 3178W ~;"' .................. i"" 59,72' 319.34'az 6225N 3~98W / N K-12 KOP Crv t2/10011025 MD 7407 TVD 61.87' 319.45°az 6246N 3117W Proposal ....... Survey -8000 -6000 -4000 -2000 0 2000 12000 -10000 -8000 6000 4OOO 2OOO --2000 <<< WEST EAST >>> W > T~REE:' 4¢1/16" - 5M ClW WELLHEAD: 13-5/8' - 5M FMC UNIVERSAL 10-3/4', 45.5#/ff, J 4764' J NT-80S BTC KOP: 500' MAX ANGLE: 63 ° @ 8995' MD RT-(~'" 41' GL-SL = 19' OTIS 4 1/2" TRSSSV 1988 MANDRELS 1 3210 2 7165 3 10600 4 13121 5 14178 'rVDss 30O9 5489 7174 8422 9015 4-1/2" 12.6# NT80 NSCT TUBING TUBING ID: 3.958" CAPACITY: 0.01522 BBI_/FT 7 5/8", 29.7#/ft, NT95HS NSCC NOTE: CARBON TUBING AND CASING PERFORATION SUMMARY: Ref Si~°~ Interva SPF Open/Sqzd I NT95HS NSCC DATE 1/4/94 REV. BY MEM COMMENTS PRE- No TYPE I Durum 2 y 3 Durum 4 y 5 Durum 'X' nipple (OTIS~)8.rS~" ID y Dumm Packer, Bal~er SABL 3.951" ID TROP/size 14246 14303 4-1/2" 'X' Nipple OTIS i14333 (3.813" ID) 4-1/2" 'XN' Nipple (3.725" ID) 14351 4-1/2" WLEG I 14372 Niakuk WELL: NK- 12A APl NO- 50-029-22-41401 Sec. ur. ng TREE: ~1/16'-5M CIW WELLHEAD: 13-5/8'-5M FMC UNIVERSAL 10-3/4', 45.5#/ft, I 4764' NT-80S BTC I I Diesel KOP: 500' MAX ANGLE: 63 ° @ 8995' MD 4-1/2" X nipples in tail pipe Whipstock @ __.11,000' MD 14246 I 'X' nipple (OTIS) 3.813" I 7-5/8' Packer, Baker SABL 14303 I 3.951' ID 143.33 14351 ! i 4-1/2" 'X' Nipple OTIS (3.813' ID) I 4-1/2' 'XN' Nipple (3.725' ID) 14372 I 4-1/2' WLEG PBTD J 14944 J ,J NTg5HS NSCC NK-12B .,~_ 'NAL _=41' GL-SL = 19' 4 1/2" TRSSSV 1 21oo,I 4-1/2" 12.6# L-80 BTC-Mod tbg (GLM's in 7-5/8" csg are 4-1/2" x 1") 7-5/8" x 4-1/2" Production Pkr Top of 4-1/2" Production Liner ,,t) o 'r~ : fl '/:~ 'F,* ;i *'f ,~d~ P&A ~ Cmt ~ _+16,385' MD 4-1/2" 12.6# L-80 BTC-Mod Liner DATE 10-3-00 REV. BY LRC COMMENTS Proposed Sidetrack I Niakuk WELL: NK- 12B APl NO: 50-029-22-41402 Sec. 36,T12N,R 15E BP Alaska Drilling and Wells III DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 122100 CK122100B 100. O0 100. O0 PYMT ;OMM£NTS: peenit To Drill --ee HANDL [NC INST: S/H - Tereie Hob )le X4628 : HE.ATTACHEDC~Ci(181NPAi';~.~g-G~,b~gJF..~;~-~.GABOVF- 'ml[e]m~rllmm '~ 1OO. OO 1OO_ OO '.~r.....l... ~.'...'..." '..... ...... ": .'~.. : v ~i':.'.:.'..':b:.': :~' 'i:'" ~:.'..}'... ...... '" ': ~ "i .a "::" "~F.AS~ ...... ":."." ....'"'~,,:.:, .... ~.~....~:. ' ;',."*,,'"'":..,.. ::'.~i.'.:~:.j~. ?'.,..:.'..:...~... ....... ':,.. :.~:....~:; ..¥ .' '. ' .' "'...;':'~:":, :::..' .~.~.~ ::. :.':~..~ ~; 'i!i .:"'.:'0.!'.~:..B'.0...~:t'9.....6:612:;':;:::"..~'i:ii:::'i '.:" '. '...'. '.'...",~ri:.i!i. '":% ':t,..=:::.:.~'AN~HO~G:~!A~$~":995,1.9-66'12.:'?~'i:i:.iI~i':/· ',:i?,:~,:".'" '::'::.':'i';!..: ::?:':.:!:'.'" :.. ~:;:?':i,":',:'~?.:.::'::?' .' :. ":, ' '." .. ~::.~' :": "'?:~::.~ '.,,.!::':!.:,: .... .':.::~..,.!i~., .!:',~:: ' ,.',!::,:..::~.'.'...:.......:, .., ', "....',:,,::, .. .. ,~:~,,:~.,:,. .... ,,,,,.: ,:,, '.: :~,:r,!.,.,.. ," ,... ' . . , ,.;. '':" h::':' ...,:~i.~..,!,~,. , ' :.'..'.::, · ', ..."., '" ,'r ':""~., ': " ~.:,'~ ,,.", :'":!; :'."; ...:.,...... . '. · · ..... . ' '..' ...... ..... . ..... .......: .....: ' ..... .... · '. ,.......'........' .,',4~ ....... .... ... ......,~....... .....OU,l.!:!!~ib -......>..: .......... ..,.. "'" .... '"'' ""' '"::":' ..... :"'':'~i:':'~': .... :'::":"':".":'i'i::'''''~':~ i ...... "' ...... ::::"?' '..., ..',.', .' .. ' . ..' = :::!i?" ;~".'.:"~::':~:"'.. "::;i~:.' ~':.?:i:.i':':i?' . ·: ':,~!.:..:' '.' ."::~:":..'.:'::::~.: . '.:,~...;::... '"'..,:.!.~:::~'.:;:i~.~ :'.-.'.' · .'DATE" ..: .:~:.9[i.,'.,..'": '~;i:::'...:..!,:~:~2":..' .~. :'." .&.:::iAMOUNT~: ':': ' ' :.,, ~ ::.'4' . ".. ".. ANCHI3R'i~OE' . '.'. "' '"'...' AK "**'50'1: . m RE: NK-12B (Proposed PTI) 201-015) Subject: RE: NK,12B (Proposed PTD 20t-015) Date: Men, 29 Jan 2001 19:45:32-0000 From: "Kolstad, Scoff" <KolstaSR@BP.corn> To: "'Tom Maunder'" <torn_maunden~admin.state.ak.us> Tom, Below is some corrected information regarding NK-19A in response to your questions. 1. Based on the Anadrill directional plan (P2) that was attached to the permit application the cement calculation should read: Cement Calculations: Casing Size: 4 1/2" Liner Basis: Lead: None Tail: Based on TOC 1000' MD above top of Kuparuk formation with 50% excess and 82' shoe track. Tail TOC: 15,178' MD, 8,557' TVDbkb Total Cement Volume: Lead N/A Tail: 46 bbls / 258.3 ft^3 / 221 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. 2. A FIT test to 12.5 ppg will be performed after milling the window. This will provide a kick tolerance of -96 bbls described in the hazards section of Drill Intermediate/Production hole. 3. The casing test pressure will be 3500 psi in step 9 of the Rig Operations Summary. / 4. The top of the 4 1/2" liner will have a 7_XP liner top packer. V/' Judging from the way operations are going on NK-43 my guess is the NK-12B spud date will be about 2/8/01. Thanks for catching these. Let me know if you have any other questions. " Scott Scott Kolstad Drilling Engineer BP Alaska Drilling and Wells PH: (907) 564-5347 Fax: (907) 564-4040 ..... Original Message--- From: Tom Maunder [mailto:tom maunder~admin.state, ak. usl Sent: Saturday, January 27, 2001 8:02 AM To: Scott Kolstad Cc: Dan Stone Subject: NK-12B (Proposed PTD 201-015) Scott, I was reviewing this application and had a few questions. 1. I looked at the cement calculations and the volume you have specified is not gauge plus 50% plus shoe track as you indicate. My calculations show gauge plus 10% at most. 2. You are sidetracking a fair distance up the hole. You do not mention any LOT or FIT outside the window. 3. You specify 3500 psi for the BOP test pressure due to your casing test requirements, and eventually you do test the tubing and annulus to that pressure. Prior to perforating and running the completion, you only test to 3000 psi. Is there a typo there?? ~,~ 4. I presume there will be a 7_.XP on top of your liner. Thanks, look forward to your reply. Also, does the spud date still look \\~v..~. 1 of 2 1129/01 10:57 Ab WI=LL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION WELL NAME ,~-/'~ ~ PROGRAM: exp · INIT CLASS ~'"'L/ /~/~/4_ 1. Permit fee attached ................. . ........ 2. Lease number appropriate~'.5.~5~..~/~..=~./, ./q-..~o.t. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available· in drilling unit ............ 8. If deviated, is wellbore plat included ............. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ APPE DATE 12. Permit can.be issued without administrative approval ...... ~/, ~ .eD 113. Can permit be approved before 15-day wait ........... GEOL AREA 14. Conductor string provided ................... 15. Surface casing protects all known USDWs.... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to fie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate weilbore separation proposed ....... : ...... ENGINEERING dev v' redrll ~ serv wellbore seg ann. disposal para req ~'~) UNIT# ON/OFF SHORE 23. If diverter required, does it meet regulations .... : ..... ~ ¥~ I~ . . 24. Drilling fluid program schematic & equip list adequate ...... (~) N ___ : : ; ; . 25. BOPEs. do they meet regulation ................ ~ N ,_-~ , · ' A~ _I~T~E 26. BOPE press rating app'ropriate; test to Z,,,S~.~ psig. {~) N ~kl~C>~ ~-%-~,~.~.~J~c"~e..,.~ ~c_~\ ~.%~. . ' ' ~~)~ '[~-~'~ 27.' Choke manifold comphes w/APl RP-53 (May 84) .. ~ N ' .. ,., ,. ,. ,' ' c,. ~, _ A. . . ' · ' ' ....... N ' \~.~ ' ' ' 28. Work will occur without operation shutdown...'.... ...... (,~ ~ .~ 29. Is presence of H2S gas probable .................. y ~ ~ot-~X~,<-,~.,c<~, %\'~-'~.%, t,~,.~ ,),~,,~¥,,k-~,~, G\o ~ [-~c.x~r-~ ~ .~ 3'> ~,~,~.,~ ~,-~.~,-~ GEOLOGY 30 Permit can be issued wlo hydrogen sulfide measures ...... ~' ' 311 Data presented on potential overpressure zones ....... Y/I~ ,~'~~,~', · 32. Seismic analysis of shallow gas zones .... . ......... II'AP.P.~R DATE , 33. Seabed condition survey (if off-shore) ............ ../,,,~r, y N ' ' ' .... Il ~ j, ~.Z,o / 34. Contact name/phone for weekly progress reports [explora.<te~·only] Y N , ' ' ' ' ' ~ANNULAR DISPOSAL35. With proper cementing rec0rds,.this plan . ' ' ' ~ '~'"'""~ . ". ." Il '(A) will contain waste in a suitable receiving zone; ........ Y N / . . b, ~ - ~-~"X ' [IAPPR . 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: . UlC~Annular 'COMMISSION: V~-~ - ~ ~l~ Comments/Instructions: Z 0 ,=.1 Z ,--I -r' c:~nsoffice\wordian~iana~checklist. (rev. 11101//00)