The URL can be used to link to this page

Home My WebLink About198-036 A STATE OF ALASKA e ALASKA~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ;~1¡;-,;\ ;~,,; 1a. Well Status:D Oil DGas D Plugged IBI Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic IBI Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/7/2006 198-036 305-388 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 03/18/1998 50- 029-20570-01-00 4a. Location of Well (Governmental Section): 7. Date T.o. Reached 14. Well Name and Number: Surface: 04/06/1998 PBU 16-14Ai 1534' FNL, 527' FWL, SEC. 24, T10N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 66.15' Prudhoe Bay Field I Prudhoe Bay 1533' FSL, 1691' FWL, SEC. 13, T10N, R15E, UM Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 4002' FSL, 35' FEL, SEC. 14, T10N, R15E, UM 11150 + 9037 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 719306 y- 5929396 Zone- ASP4 15175 + 9026 Ft ADL 028332 ------- -_._-~~- --------~ 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 720379 y- 5932496 Zone- ASP4 ~-- -~--- - N/A MD Total Depth: x- 718581 y- 5934913 Zone- ASP4 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes IBI No NIA MSL 1900' (Approx.) 21. Logs Run: MWD, DIR, GR, RES I AIT, DT I BHC, CNL, LDL, GR, Caliper, SP, MRES, 4-Phase RES, CBL 22. CASING, INER AND CEMENTING RECORD iX' i/· ".',.. ····.··.i../.:i/ />·~¡'¡r .....~I~ .lfiti"B· li/'.// ·//·x// .......2j$~..c/·/ VVJ·,......,·~.·. ¡'...... "'/. ·rOF····/.·.. gq$ clOP I:S()'"''ÞM 20" 94# H-40 Surface 110' Surface 110' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2675' Surface 2671' 17-1/2" 3000 sx Fondu, 1250 sx Permafrost 9-5/8" 47# L-80 I SOO-9~ Surface 8963' Surface 7693' 12-1/4" 500 sx Class 'G' 7" 26# L-80 8773' 1 0444' 7899' 9055' 8-1/2" 288 sx Class 'G' 4-1/2" 12.6# L-80 10292' 15175' 9031' 9026' 6" 477 sx Class 'G' 23. Perforations 0Ren to Production (MD + TVD of Top and 24)/ ". ..... .... ;..<! ·,!"./··'i'/../i /. ////.///...//. . Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None None MD TVD MD TVD 215. ,../,;;;;,..... II.t / .. ~(;ß~å\WìjiE:!)) i.h 20 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10214' P&A wI 25.2 Bbls Class 'G' Cement 9941' Set EZSV 9921' Set Whisptock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF W A TER-Bsl CHOKE SIZE GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl GAs-McF W A TER-Bsl Oil GRAVITy-API (CORR) 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". None RBDMS 8Ft MAY 2 2 2006 .......""II""t>..IA' Form 1 0-407 Revised 12/2003 UK I tJ IIHt-Il1 o ON REVERSE SIDE G 28. GEOLOGIC MARKER 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". Sadlerochit I Zone 2A 9906' 8812' 9030' None 26P 13487' 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 ~ ~ Title Technical Assistant Date DS/ lì /'()(p PBU 16-14Ai 198-036 305-388 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I A roval No. Drilling Engineer: Jeff Cutler, 564-4134 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. IrEM 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). IrEM 8: 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. IrEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IrEM 20: True vertical thickness. IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrEM 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). IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IrEM 27: If no cores taken, indicate "None". IrEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e 16-14B Prudhoe Bay Unit 50-029-20570-02 206-003 Accept: Spud: Release: Ri: 02/08/06 02/16/06 03/06/06 Nabors 2ES PRE-RIG WORK 12/29/05 DRIFTED AND PULLED 41/2" A-1 INJECTION VALVE # HAS-297 WI 2.25 ORIFICE. HUNG TAG NOTING VALVE IS OUT. DRIFTED TO 10,362' WLM WI 1 7/8" ROLLER STEM TOOL STRING, 3.25 CENTRALIZER AND 1.50 SAMPLE BAILER. TOOLS STOPPED DUE TO HAW, SAMPLE BAILER M/T. 01/06/06 BLEED IA FROM 800 TO 250 PSI. RIH WITH 2.3" BON. 01/07/06 CONI' RIH WHILE PUMPING DIESEL DOWN BACKSIDE. TAG CIBP AT 11167' CTMD, CORRECT DEPTH TO 11150'. PUH TO 11050' CORR CTMD AND FLAG PIPE. PUH TO 10650 AND PUMP 1 % KCL DOWN COIL. PUMP 25.2 BBLS 15.8 PPG CLASS "G" CEMENT, LAY IN TO 9970'. BUMP WHP, DROP 7/8" BALL AND CLEANOUT TO 10200' WI BIOZAN. POOH AT 80% JETTING ALL JEWELRY. FP TO 2600' WI 60/40 METH. RDMO. ESTIMATED TOC AT 10200'. 01/09/06 DRIFT WI 3.70" CENT. AND SAMPLE BAILER TO 10,214' MD (NO SAMPLE RECOVERED). 01/15/06 CORRELATED TO BP TUBING SUMMARY DATED 13-APR-1995. TBG PUNCH 9452' - 9454', STRING SHOT 9494' - 9506', CHEM CUT 4-1/2" TBG AT 9505' WITH 3-5/8" CHC, 3-3/8" ANCHORS, 2 X 2" X 48" BRF3, 15" GG, 3 CENTRALIZERS. 01/17/06 RAN GYRO LOG FROM SURFACE TO 9500' (PRE SIDETRACK). 01/18/06 T/I/O= 100/35010 CIRC-OUT (PRE RWO) PUMPED 5 BBLS NEAT AND 471 BBLS 1% KCL DOWN TUBING, UP THE lA, TAKING RETURNS TO THE FLOWLINE OF WELL 16-15. PUMPED 70 BBLS DIESEL DOWN TUBING AND U-TUBE OVER TO IA FOR FREEZE PROTECT. CMIT TXIA TO 2500 PSI. 01/19/06 CMIT TXIA PASSED TO 2500 PSI. PUMPED 6 BBLS DIESEL TO PRESSURE UP TO 2500 PSI. 2ND TEST LOST 10 PSI ON TBG, 20 PSI ON IA IN 15 MIN TEST. 2ND 15 MIN TEST LOST 0 ON TBG, 0 PSI ON IA. MIT OA PASSED TO 2000 PSI. PUMPED 6 BBLS DIESEL TO PRESSURE UP OA TO 2000 PSI. 1 ST TEST LOST 80 PSI IN 1ST 15MIN, 40 PSI IN 2ND 15 MIN TEST. BLED PRESSURES DOWN. FWHP'S= 01010. 01/29/06 T/I/O= 180/10/25. TEMP= SI. BLEED WHP'S TO 0 PSI (PRE-BPV). TUBING FL AT 456' (7 BBLS). IA FL AT SURFACE. OA FL NEAR SURFACE. 01/30/06 T/I/O= 220/10/25. TEMP= SI. BLEED WHP'S TO 0 PSI (PRE-BPV). INTEGRALS INSTALLED ON IA AND OA. TUBING FL AT 456' (7 BBLS). IA FL AT SURFACE. OA FL NEAR SURFACE. BLED TUBING PRESSURE TO SLOP TRAILER FROM 220 PSI TO 0+ PSI IN 30 MINUTES. DURING BLEED IA WENT ON VAC. BLED OAP FROM 25 PSI TO 0+ PSI IN 30 MINUTES. DURING OA BLEED TUBING PRESSURE INCREASED 30 PSI. BLED TUBING PRESSURE FROM 30 PSI TO 0+ PSI IN 10 MINUTES. WING VALVE APPEARS TO BE LEAKING BY. OPENED WING AND BLEED FL TO 0+ PSI IN 1 HOUR. SI WING VALVE. MONITORED FOR 30 MINUTES. FINAL WHP'S= O+NAC/O+. 02/06/06 BRUSHED DB NIPPLE WI 3.80" SWAGE, 4.5" BLB AND 3.75" G-RING AT 2169' SLM. SET 4.5" DB LOCK WI CARRIER (3 SETS REG PKG) AND P-PRONG EQ SUB WI 1/4" PORTS (69" OAL). SET P-PRONG AT 2167' SLM (1 3/4" FN - 96" OAL). e BP EXPLORATION Operations Summary Report Page 1 _ legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 16-14B 16-14B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 2/6/2006 Rig Release: Rig Number: Spud Date: 2/16/2006 End: 3/6/2006 Date From - To Hours Task Code NPT Phase Description of Operations ~--_.__.- - __~_.·_.._n. 2!7 /2006 13:00 - 00:00 11.00 MOB P PRE Move rig to 16-14 2/8/2006 00:00 - 13:00 13.00 MOB P IPRE Move rig / Rig up / Spot buildings / Rig up lines and berms 13:00 - 13:30 0.50 WHSUR P DECOMP Pre-Spud safety and envirornental awareness meeting. Rig accepted for operations @ 13:00 hrs 02/08/2006. 13:30 - 14:00 0.50 WHSUR P DECOMP PJSM Install secondary Annulus valve 14:00 - 17:30 3.50 WHSUR P DECOMP PJSM Rig up slick line 17:30 - 22:00 4.50 WHSUR P DECOMP Run in hole with 3.55" bell guide and retreive prong Run in hole with 3 1/2" slirnline pulling tool Run #1 attempt to retrieve DVP plug pinned with brass Run #2 Attempt to retrieve DVP plug pinned with steel Run #3 Install oil jars RIH and jar DVP plug free POH 22:00 - 22:30 0.50 WHSUR P DECOMP Reverse circulate lines and test lines to 3500psi 22:30 - 00:00 1.50 WHSUR P DECOMP Reverse circulate 48bbl seawater / Flip lines and pump 35bbl Soap Pill / Chase with clean seawater the long way to surface / 9BPM @ 11 OOpsi 2/9/2006 00:00 - 01 :00 1.00 WHSUR P DECOMP Circulate well to seawater 9BPM @1100psi 01:00 - 01 :30 0.50 WHSUR P DECOMP Test casing to 1500psi for 10 mintutes - Blow down surface equipment 01 :30 - 04:30 3.00 WHSUR P DECOMP Run DVP plug in hole with slickline - Test to 1000psi frorn below. Blow down surface equipment. 04:30 - 06:30 2.00 WHSUR P DECOMP Nipple down tree & adaptor and remove from cellar 06:30 - 08:00 1.50 WHSUR P DECOMP Nipple up BOP's 08:00 - 10:00 2.00 WHSUR P DECOMP RIH with slickline and pull prong @2194' - POOH change out tools and RIH and pull DVP Plug - Rig down wireline 10:00 - 12:00 2.00 WHSUR P DECOMP Make up landing joint and Pull hanger to rig floor - 135K up WI free - Cut control lines - Lay down Hanger - Lay down 2 pup joints and one joint 4 1/2" tubing 12:00 - 12:30 0.50 WHSUR P DECOMP Secure control lines and clear floor 12:30 - 14:30 2.00 WHSUR P DECOMP PJSM Rig up and run RTTS storm packer Set 5' below wellhead test to 1000psi 14:30 - 15:00 0.50 WHSUR P DECOMP PJSM make up test joint and set test plug. 15:00 - 20:30 5.50 WHSUR P DECOMP Test BOP 250 psi low 4000 psi high Waived witness by Jeff Jones of AOGCC. Witnessed by Dick Maskell and Blair Neufeld. 20:30 - 21 :00 0.50 WHSUR P DECOMP Rig down test joint and pull test plug - Clear floor 21 :00 - 21 :30 0.50 WHSUR P DECOMP Make up and attempt to set wear ring / Too short / POOH 21 :30 - 22:30 1.00 WHSUR P DECOMP PJSM Engage RTTS storm packer - Pull RTTS and tubing to rig floor 22:30 - 00:00 1.50 WHSUR P DECOMP Remove saver sub and rig up 4 1/2" handling equpment with compensator 2/10/2006 00:00 - 04:00 4.00 WHSUR P DECOMP Lay down 41/2" 12.6# L-80 13 cr tubing - 9534'- 7330' Spool up control lines. 55 SS bands recovered out of 58. Rig down control line spooler and lay down SSSVLN. 04:00 - 15:00 11.00 WHSUR P DECOMP Lay down 4 1/2" 12.6# L-80 13 cr tubing 7330'-surface Recovered 227jts + 19.91'cut joint, 6 gas lift mandrels and an SSSV landing nipple. Tubing was cut in middle of first full joint of tubing leaving 21.21' of tubing jt #1 plus a pup joint 9.75' long screwed in to the top of the packer. Will have to mill up -30' of 4.5" tubing. Chemical cut was clean - no flaring. 15:00 - 17:30 2.50 WHSUR P DECOMP Rig down tubing handling equipment. Clean and clear floor. Install wear ring. 17:30 - 19:00 1.50 WHSUR P DECOMP PJSM Make up milling assembly to 766'. Printed: 3/1312006 10:59:24 AM · BP EXPLORATION Page 2 .. Operations Summary Report Legal Well Name: 16-14B Common Well Name: 1 6-14B Spud Date: 2/16/2006 Event Name: REENTER+COMPLETE Start: 2/6/2006 End: 3/6/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS2ES Rig Number: , I Date From - To Hours Task I Code I NPT Phase Description of Operations ----.-.. ----+~-+ -~-.- . ---~.~-.- --- , I RIH picking up singles from pipe shed 766'-7275'. Fill pipe 2/10/2006 19:00 - 23:30 4.50 WHSUR ; P DECOMP i I every 3000' 123:30 - 00:00 0.50 WHSUR P DECOMP Service Top drive. 2/11/2006 100:00 . 03:00 3.00 CLEAN P DECOMP RIH picking up singles from pipe shed 7275'- 9502' . Fill pipe I every 3000' i 03:00 - 10:00 7.00 CLEAN P DECOMP Break circulation and wash down to top of cut off @ 9502' - 2' I high from calculated. 175K up 158K down 170K rotating 4000 i Nibs off bottorn torque. Start milling on 4.5" tubing stub. 60 I i í RPM. 5k WOB. 5000 ftIIbs torque. 490 gpm @ 2640psi. Mill I i 9502'-9510' by 05:45 hrs. Swap system to 8.5ppg Flo-Pro mud/milling fluid while milling. I Mill to 9517' where progress halted. Suspect that a coupling I 110:00 - 12:00 may be turning. 2.00 CLEAN P DECOMP Pump Hi vis sweep Mix and pump dry job. Blow down top drive i and remove blower hose i 12:00 - 15:00 3.00 CLEAN P DECOMP POOH 9517' - 766' 115:00 - 17:00 2.00 CLEAN P DECOMP Pull out BHA . Clean out boot baskets , Clear floor 17:00 - 18:30 1.50 CLEAN P DECOMP Wait on Baker overshot 118:30 - 19:30 1.00 CLEAN P DECOMP Make up BHA #2 to 759' 19:30 - 22:00 2.50 CLEAN P DECOMP Run in hole 759'-9448' fill pipe every 3000' 122:00 - 23:00 1.00 CLEAN P DECOMP Engage overshot @9517' Pull 350K and jar with 100k overpull. i No success disengage overshot i 23:00 - 00:00 1.00 CLEAN P DECOMP Pump dry job POOH Mud weight in and out 8.5ppg 2/12/2006 00:00 - 03:00 3.00 CLEAN P DECOMP POOH to BHA @760' 03:00 - 04:00 1.00 CLEAN P DECOMP Rack back HWDP. layout jars and overshot. Service float and 1 clear floor. 04:00 - 05:00 1.00 CLEAN P DECOMP Make up BHA #3 with burn shoe and washpipe. 05:00 - 08:00 3.00 CLEAN P DECaMP Run in hole with BHA #3. Fill pipe every 300' 08:00 - 19:30 11.50 CLEAN P DECOMP Mill over Tubing stub with collar @ 9524'. Start milling on packer @9532' Up 175K Down 155K Rotating 170K Off bottom torque 3000 ftIIbs On bottom 3K·7K ftIIbs. 60m RPM, 10K weight on bit, 250 GPM @ 780psi Progress stopped at -9533.5' and no further progress for several hours. Tried aU known techniques to make headway. Pump a 30bbl safecarb/nutplug sweep was run to make the slip rings more abrasive hoping to grind them up. No progress so pumps were shut off and milled without circulation in an attempt to heat things up. Again no success. 18:00 - 19:30 1.50 CLEAN P DECOMP Circulate bottoms up 200 strokes / min @ 1600psi - Pump dry job Blow down surface equipment. Remove Blower hose 19:30 - 22:30 3.00 CLEAN P DECOMP POOH 9534' to 799' MW in and out 8.4 ppg. 22:30 - 00:00 1.50 CLEAN P DECaMP POOH with BHA from 799' to jars at 62'. Change out burn shoe and empty boot baskets. All 3 boot baskets were full - approx 40 Ibs of debris. Mill about 50% worn but still had cutting structure. 2/13/2006 00:00 - 04:00 4.00 CLEAN P DECOMP RIH 798' to 9534' wash to bottom 04:00 - 11 :30 7.50 CLEAN P DECOMP Mill with burn shoe on Packer. Initially shoe made 3-4 inches then did not drill off until 11: 15 when it broke through. Monitor well 11 :30 - 12:00 0.50 CLEAN P DECOMP Run in hole with dril pipe, chase packer down hole to cement. Tag @10,150' e Printed: 3/1312006 10:59:24 AM · e Page 3 .. BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: NPT i Phase I Description of Operations : ;~¿~~~ I Circulate supersweep around 2 x bO~~~~ up, 200SPM : @ 1750psi ! Monitor well - Pump dry job Blow down surface equipment DECOMP ¡!cut 81' of drilling line. Inspect and lubricate draw works. Inspect Traction motor brushes. Lube Elmago splines. Service Crown DECOMP Service Top drive DECOMP POOH 10,150' to 799' DECOMP . POOH 799' to 62' Lay down Baker fishing tools. Clear floor DECOMP I' PJSM rig up E-line, run gauge ring and junk basket to 9960'. POOH to 9039' where tool became stuck. Worked tool free I down then pulled obstruction up hole to liner lap at 8773'. I POOH to change out line weak point due to max overpull on line when stuck. DECOMP I POOH with E-line guage ring 1 junk basket and rehead rope ¡socket. DECOMP RIH with gauge ring 1 junk basket on E-line. At 9250' lost 300 Ibs on line weight. Pulled back up with no overpull. Lowered back down with no loss of weight on line. RIH to 9960'. POOH with no overpull, only slight fluctuation at liner lap. POH UD guage ring 1 junk basket. DFAL DECOMP Trouble shoot wireline tools firing ability. Arrn firing head, M/U tools and EZSV. RIH with EZSV and set @ 9941' ELM. POH & RID SWS. Close blind rams and test casing to 4000 psi, OK. M/U whipstock BHA to 847'. Up-load MWD, orient. Test MWD @ 325 gpm @ 700 psi. RIH from 847' to 9850'. Fill pipe @ 3000' intervals. Install top drive blower hose. Orient whipstock 29 degrees RHS. Tag EZSV @ 9933', set anchor with 11 K down, shear lug with 35K down. Record milling parameters & SPR. Mill window in 7' 26# casing from 9916' to 9921'. UWT = 180K, DWT = 140K, RWT = 170K. WOB = 5K. Torque = 5K @ 100 rpm. Pump @ 325 gpm @ 1480 psi. No metal cuttings in returns, pump high vis weighted sweeps. No metal or cement in retums. Mill window in 7' 26# casing and 20' of new formation from 9921' to 9943'. WOB = 5/1 OK. Torque = 4/5K @ 100 rpm. Pump @ 330 gpm @ 1600 psi. Pump 2 high vis sweeps and 2 super sweeps, circ until clean. Recovered 40# of metal cuttings. Pull into casing. Perform FIT to 10.17 ppg EMW. (770 psi with 8.5 ppg mud @ 8825' TVD) Pump dry job. Blow down surface equipment. Mud weight in and out = 8.5 ppg. POH for BHA to 829', change handling equip. POH with BHA. Stand back 2 stands HWDP, UD whipstock milling assy from 649'. Down load MWD. Upper mill full gauge. Clear rig floor. Pull wear ring, flush BOP stack and function rams. Install wear ring. Blow down lines. M/U BHA to 746'. P/U insert bit, 1.5 degree mud motor drilling assy. Orient, up load & surface test MWD. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 16-14B 1 6-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To I Hours Task Code 12:00 - 14:30 ! 2.50 CLEAN P 2/13/2006 14:30 - 15:30 1.00 CLEAN P I I 15:30 - 16:00 0.50 CLEAN P 16:00 - 19:00 3.00 CLEAN P 19:00-21:00 2.00 CLEAN P 21 :00 - 00:00 3.00 CLEAN P 2/14/2006 00:00 - 01 :30 1.50 CLEAN P 01:30 - 04:00 2.50 CLEAN P 04:00 - 06:30 2.50 CLEAN N 06:30 - 11 :30 11 :30 - 12:30 12:30 - 15:30 5.00 CLEAN P 1.00 CLEAN P 3.00 STWHIP P DECOMP DECOMP WEXIT 15:30 - 20:30 5.00 STWHIP P WEXIT 20:30 - 21:00 0.50 STWHIP P WEXIT 21 :00 - 00:00 3.00 STWHIP P WEXIT 2/15/2006 00:00 - 08:00 8.00 STWHIP P 08:00 - 11 :30 3.50 STWHIP P 11 :30 - 12:00 0.50 STWHIP P 12:00 - 12:30 0.50 STWHIP P 12:30 - 16:00 3.50 STWHIP P 16:00 - 18:00 2.00 STWHIP P 18:00 - 19:00 1.00 STWHIP P 19:00 - 22:00 3.00 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 2/6/2006 Spud Date: 2/16/2006 End: 3/6/2006 Printed: 3/1312006 10:59:24 AM e Page 4" BP EXPLORATION Operations SummaryRep,~rt Start: Rig Release: Rig Number: NPT I_~_~~_~~L Description of Operations WEXIT i RIH P/U 4' HT40 drill pipe from 746' to 3553', fill pipe. WEXIT RIH P/U 4' HT40 drill pipe from 3553' to 6067'. WEXIT RIH with stands from derrick from 6067' to 9802'. Fill pipe @ 3000' intervals. Orient & install top drive blower hose. Pass throu h window, wash to bottom @ 9943'. Drill ahead from 9943' to 10238'. Pump @ 247 gpm psi. UWT = 180K, DWT = 150K, RWT = 165K, Torque = 5/6K @ rpm's AST =11.89' ART =1.63. ROP slow in Zone 4 to -10140' (10 fph) but impro formation change. PROD1 Drill 6 1/8' hole. Pump @ 316 gpm @ 2280 psi. W = 5K. Torque = 617K @ 80 rpm. Drill to 13912' MD rotating a 0 to 100 fph. Minimal sliding required from this point. Weathe t phase 2. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 16-14B 1 6-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I I From - To I Hours I Task Code ., ----)----- ..---t- 22:00 - 00:00 i 2.001 STWHIP P 00:00 - 02:00 : 2.00 i STWHIP P 02:00 - 03:30 ì 1.50 i STWHIP P 2/15/2006 2/16/2006 03:30 - 00:00 20.50 DRILL P PROD1 2/17/2006 16:30 - 18:30 18:30 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 2/18/2006 00:00 - 01 :30 01 :30 - 03:30 03:30 - 04:30 04:30 - 06:00 06:00 - 08:00 08:00 - 09:30 09:30 - 10:30 10:30 - 11 :00 11 :00 - 00:00 2/19/2006 00:00 - 00:00 16.50 DRILL P PROD1 P P PROD1 PROD1 PROD1 PROD1 3.00 DRILL 1.50 DRILL 2.00 DRILL 1.00 DRILL P 1.50 I DRILL P 2.00 1.50 DRILL P 1.00 DRILL 0.50 DRILL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 P PROD1 2/20/2006 24.00 DRILL P PROD1 11.00 DRILL P 2/6/2006 Spud Date: 2/16/2006 End: 3/6/2006 Drill 6 1/8' hole from 10238' to 10847'. U = 180K, DWT = 145K, RWT = 165K. Torque = 5/6K @ rpm. Pump @ 250 gpm @ 1540 psi. WOB = 10K. Pump sweep, observe well. ROP slowed to 10/15 ft per . POOH from 10,847' to 9950' for PDC bit & high speed motor. UWT=195K, DWT=145K. MAD Pass from 9989' 80'. Drop dart to open ci b (sub did not open, dart landed on corrosion rig @ t f jars. Ring was cocked) purnp dry job. POOH from 9 to 2338' for PDC bit & BHA. POH from 'to BHA @ 746'. Monitor well. POH wi A, down load MWD. UD mud motor and bit. Clear rig fl , monitor well. ML BHA #3, P/U high speed mud motor with 1.5 degree end, check float. P/U PDC bit & orient. Shallow pulse test MWD @ 280 gpm @ 830 psi. RIH from 737' to 3544', fill pipe. RIH from 3544' to 6339'. Fill pipe. Test MWD @ 260 gpm @ 1100 psi. RIH from 6339' to 10729'. SM. Cut & slip 85' drilling line. Change out low clutch quick rele e valve. Servic 'g & top drive. Install blower hose. Fill pipe & orient Wash & r m from 10729' to 10847'. Hole in good shape, no fill. Drill from 1084 to 11757'. UWT = 185K, DWT = 140K, RWT = 165K. TQ = 6K @ rpm. Pump @ 316 gprn @ 2250 psi. ART = 7.03 hrs. AST = 1. hrs. Drill 6 1/8' hole from 11 7' to 12829'. AST = 6.95 hrs. ART = 5.92 hrs. UWT = 185K, D = 135K, AWT = 165K. Torque on and off bottom = 6I7K @ 60 r . WOB = 5K. Pump @ 316 gpm @ 2280 psi. Mud weight in . ppg, out 8.7 ppg. Drill 6 118' hole from 12829' to 134 '. Pump @ 316 gpm @ 2370 psi. Torque = 617K on & off botto @ 60 rpm. WOB = 5K. UWT = 185K, DWT = 130K, RWT = 1 K. AST = 2.13 hrs, ART = 4.67 hrs. Printed: 311312006 10:59:24 AM ) n";r~ 1 r;¡::21 ('"1 0 ;' . \ 'r"":-~ :'lill7 : ~ ¡ II I I ¡ il. /,i \ : I ! h\" \. QJJ ì ~/ r 1 ! : ! I i i-r~ J A~\., ! ¡ / Ó~, 'rD'\"':»\ ¡ ¡~f,~~.' .' ð \ \ill II' /In'''I' !f,n\II"'U\1 1\ ,.,p, w il.' \ L.=:JJ U U \~: \) i ' ) I j ¡ FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COJDIISSION 333 w. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU 16-14Ai Sundry Number: 305-388 " 1"" f" ¢) (.;¡ iJ)\)5 ~\ ~ ,., '~\'. \1\.\'. It;; ~\, D t. Y iJ<.! i¡J . }((! ~«;^\~n~í:,.I . \) " Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this-z..-z...aay of December, 2005 Enc!. ') V-1~~1Wá ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 6 2005 APPLICATION FOR SUNDRY APPROVALAI.skaO¡I&GasCons.Commiss 20 AAC 25.280 Anchorage 1. Type of Request: iii Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Other o Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 1m Service /' 5. Permit To Drill Number 198-036 ../ 6. API Number: 50- 029-20570-01-00 /' 66.15 9. Well Name and Number: PBU 16-14Ai /' 8. Property Designation: 11. Total Depth MD (ft): 15175 Casin9 Structural Conductor Surface Intermediate Production Liner 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 9026 11150 9037 IIISO, 12100, 12500,13380, 14528 Length Size MD./ TVD Burst Junk (measured): None Collapse ADL 028332 110' 20" 110' 110' 1530 520 2675' 13-3/8" 2675' 2671' 4930 2670 8963' 9-5/8" 8963' 7693' 8150 5080 1671' 7" 8773' - 10444' 7899' - 9055' 7240 5410 4883' 4-1/2" 10292' - 15175' 9031' - 9026' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 10700 - 10800 9051 - 9049 Packers and SSSV Type: 7" x 1-1/2" BKR S-3 4-1/2" CAMCO SVN Tubing Size: 4-1/2", 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 9535' Tubing MD (ft): 9579 12. Attachments: 1m Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: / o Exploratory 0 Development 1m Service 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Nam~ve Wesley Ý Title Senior Drilling Engineer /' /' ~./ F I Prepared By Name/Number: Signatureþ~ ~7 Phone 564-5153 Date ¡z/<¡¡ Zt7,?-S- Sondra Stewman, 564-4750 Commission Use Only Deœmbe~]OO5 Dat~U 15. Well Status after proposed work: DOil o Gas o WAG 0 GINJ o Plugged DWINJ 1m Abandoned o WDSPL Contact Jeff Cutler, 564-4134 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance I Sundry Number: '3 0 S - '5 -8- 9 Other:T.est- ßoPE +0 4000 f~' RBDMS BFL DEC 2 2 20D5 COMMISSIONER APPROVED BY THE COMMISSION Date I], rþz,~r£ Submit In Duplicate -,INAL ) ) o b,:) GçpN/ø:' . To: Winton Aubert - AOGCC Date: December 13, 2005 From: Jeff Cutler - BPXA GPB Rotary Drilling Subject: Reference: 16-14Bi Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20570-02 Approval is requested for the proposed P&A of PBU well 16-14A. Well 16-14 was initially drilled in 1981 as a producer. It was sidetracked as a horizontal MIST injector in April 1998. It has had a successful history of 6 MI bulbs in the Victor. The purpose of the 16-14B sidetrack is to mobilize and capture EOR reserves in the Victor interval. This MIST program builds off the success of the 16-14Ai MIST program that has resulted in 3200 MBO incremental recovery. The sidetrack is currently scheduled for Nabors rig 2ES, beginning around January 20th 2006, after the completion of the 01-04A RWO. The pre-rig work for ,.,/ this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Current Condition: ./ Currently on MI injection. ./ Between Apri/1998 and November 2004 perforations have been added for 6 MI injection bulbs. ./ 7", 26#, L-80 liner landed at 10,444'. ./ 4-1/2", 12.6#, L-80 liner landed at 15,175'. ./ 7" X 4-1/2" Baker ZXP packer at 10,292'. ./ 4-1/2': 12.6#, 13Cr Tubing with WLEG at 9,579'. ./ 4-1/8 CIW tree Gray gen 11/ retro to Gray New Standard. ./ 03/26/05: MITIA Passed to 3000 psi. .' _,_ ./ 04/01/05: PPPOT- T Passed to 5000 psi. ,/ """"""-7 ./ 9-APR-1998: Schlumberger CBT/GR/CCL log in 7" liner shows adequate cement to satisfy/A... 'OG9Ø zonal isolation requirements '\, "..,,/ Scope * Notify the field AOGCC representative with intent to plug and abandon * Pre-Ri~ Work: 1 . Replace all live Gas Lift valves with Dummy valves and fluid pack a~n cessary for CT P&A. 2. RU CT unit. RIH with CT and P&A the 16-14A well bore. Pum sufficient cement to leave top of cement in the 7" liner at -10,200' MD. Calculated cement volume; 6.5 bbls, based on 858' of 4-1/2" , 12.6# liner (cap. = 0.0152 bbl/ft) and 92' of 7",26# liner (cap. = 0.Q9~/bbl/ft). / 3. Drift the 4%" tubing to confirm clear to the required cut depth of 9,534' MD. 4. RIH with the appropriate chemical cutter and cut the 4%" tubing at -9,534' MD. A chemical cutter will be used on this well due to the fact that an overshot packer milling assembly will be run and the chemical cutters have shown less tendency to flare the tbg stub than the jet cutters. 5. Displace the well to clean seawater by circulating down the tubing and through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 6. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all Lock Down / Screws, repair or replace as needed. 7. Bleed casing and annulus pressures to zero. 8. Set a BPV. Secure the well. 9. Remove well houses required to rig up Nabors 2ES. Level the pad as necessary. 10. Provide total pre-rig costs on the handover form. 16-14Bi Application for Sundry ) ) RiQ Operations: 1. MI I RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well t<;ß,eawater. Set BPV. 3. Nipple down tree. Nipple up and test BOPE to 4,000psi. 4. R/U. Pull 4%" tubing from the cut at -9,534' Mo and above. 5. MU BOT packer milling assembly and RIH. Mill 7" X 4-1/2" Baker S3 packer at 9,535'. 6. The packer milling assembly will not have a PRT, the packer will be pushed down to the top of cement at 10,200' Mo, POH 7. R/U E-line. M/U 6.125" gauge ring I junk basket I CCL. RIH and tag up on the packer to ensure it is ^ below the depth required to set the EZSV. POH. 8. RIH with HES EZSV on E-line. Set bridge plug at -9,934', as required to avoid cutting a casing collar while milling the window. POH. RID E-line. 9. Pressure-test the 7" liner to 4,000 psi for 30 minutes. Record test. !'¡ 10. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly. Orient whip stock 30 degrees 'IÑ~ lO - 4,0 ~ right of high side and set on bridge plug. Shear off of whip stock. ,ø r~~{. 11. oispla?e the well to 8.4 ppg Flo-Pro drilling fluid. Completely displace the well prior to beginning milling , operations. 12. Mill window in 7" liner at ± 9,910' Mo, plus approximately 20' beyond middle of window. Circulate well bore clean. 13. Pull up into 7" liner and conduct an FIT to 10.0 ppg EMW. POH. 14. M/U 6-1/8" Dir/GR/Res assembly and RIH. 15. Drill the 6-1/8" production interval building at -12°/100' to horizontal, targeting Ivishak zones 2 and 3. Drill ahead to an estimated TO of 15,267' MD. 16. Run and cement a 4-1/2" liner with 1 00' liner lap in the 7" drilling liner. Displace cement with perf pill and mud. 17. Release from liner, displace well to clean seawater. 18. Pressure test 4-1/2" liner to 4,000 psi for 30 mins. 19. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. Estimated perf interval of 90' included in the AFE costs 20. POH. LD DP and perf guns. 21. R/U and run a 4%", 12.6#, L-80 tubing completion, stinging into the 4%" liner tie back sleeve. 22. Freeze protect the well to -2,200' TVD. 23. Set packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each test. 24. Set a BPV. 25. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 26. Secure the well. 27. Rig down and move off. Post-RiQ Work: 1. Install wellhouse and flowlines. TiminQ: This sidetrack is scheduled for spud in mid January 2006. Estimated Pre-rig operations start date: Estimated Rig operations I spud date: 01/01/06 01/20106 Jeff Cutler Operations Drilling Engineer 564-4134 16-14Bi Application for Sundry TREE = WELLHEAD :;;: ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/16" CWV VETCO BAKER 66.15' 40.43 4200' --..,...........,..--- 93 @ 10979" 9979' 8800' SS ) 13-3/8" CSG, 72#, L-80, 10 = 12.347" l-i 2675' ~ I 9-5/8" X 7" BKR PKRlHGR, 10 = 6.25" l-i 8773' Minimum 10 = 3.813" @ 9558' 4-1/2" HES X NIPPLE 14-112" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" l-i 9578' 9-5/8" CSG, 47#, N-80, 10 = 8.681" l-i 9772' 16-14A SA ). NOTES: 4-1/2" CHROME TBG. WELL> 700 @ 10269' AND > 900 @ 10468'. * A-1INJ VLV SEf IN SVN @ 2197' ON 10/1/00 (1.55" BEAN ). êl:~' \lIP 2197' l-i 4-1/2" CAMCO SVN, 10 = 3.813" 1 .. GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3518 3518 1 MMGM DMY RK 04/15/98 2 5084 5014 34 MMGM DMY RK 04/13/98 L 3 6568 6201 43 MMGM DMY RK 04/13/98 4 7901 7202 39 MMGM DMY RK 04/13/98 I , 5 8747 7878 35 MMGM DMY RK 04/13/98 ~ ~ 6 9467 8463 36 KBG2LS DMY BTM 04/13/98 9-5/8" MILLOUT WINDOW 8963' - 8979' (OFF WHIPSTOCK) 9535' l-i 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" I 9558' l-i 4-1/2" HES X NIP, 10 = 3.813" 1 9579' l-i 4-1/2" WLEG 1 l-i ELMO TT NOT LOGGED 10292' 1- 7" X 4-1/2" BKR ZXP PKRI HGR, 10 = 4.430" 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" l-i 10444' ÆRFORA TION SUMMARY REF LOG: ANADRILL MWD ON 03/30/98 ANGLE AT TOP PERF: 92 @ 11525' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 10700 - 10775 0 11/23/04 2-7/8" 6 10775-10800 0 11/18/04 2-78" 6 11525 - 11625 0 10/24/03 2-7/8" 6 12300 - 12400 C 02/20/02 2-7/8" 6 13130 - 13230 C 09/29/00 2-7/8" 6 14081 - 14181 C 10/31/99 2-3/4" 4 14976 -15076 C 10/29/99 NOTE: LOWER 3 ZONES ISOLATED BY CIBPS DA TE REV BY COMMENTS 07/09/81 ORIGINAL COM PLETION 04113/98 RIG SIDETRACK 03/08/01 CI-VKA K CORRECTIONS 08/16101 CHItlh ÆRF CORRECTIONS 10/09/01 CJ/KAK ÆRF CORRECTIONS 02124/02 DCRIKAK ADÆRF & CIBP I CIBP SET 11/18/04 l-i 11150' I CIBP SET 10/23/03 l-i 12100' I CIBP SET 02/19/02 l-i 12500' 14-1/2" CIBP SET 09/28/00 1--1 13380' 14-1/2" CIBP SET 1 0/29/99 l-i 14258' I PBTD l-i 15089' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" l-i 15175' DA TE REV BY COMMENTS 10/23/03 BJMcMTLF CORRECT ÆRF/CIBP SET 11/18-23/04 DBM'TLP CIBP, ADD ÆRFS PRUDHOE BA Y UNrr WB..L: 16-14A ÆRMrr No: 1980360 API No: 50-029-20570-01 SEC 24, T10N, R15E, 1534' SNL & 527' 8NL BP Exploration (Alaska) TREE = WB.LHEAD :¡ ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = Datum lVD = 4-1/16" CIW VETCO BAKER 66.15' 40.43 4200' 93 @ 10979" 9979' 8800' SS ') 13-3/8" CSG, 72#, L-80, ID = 12.34r l-i 2675' ~ I 9-5/8" X 7" BKR PKRlHGR, ID = 6.25" 1-1 8773' Minimum ID = 3.813" @ 9558' 4-1/2" HES X NIPPLE 4-112" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 1'1 9-5/8" CSG, 47#, N-80, ID = 8.681" l-f 9772' 16-14A SAl } NOTES: 4-1/2" CHROME TBG. WELL> 70° @ 10269' AND > 90° @ 10468'. * A-1INJ VLV SET IN SVN @ 2197' ON 10/1/00 (1.55" BEAN ). e 2197' 1-1 4-112" CAMCO SVN, ID = 3.813" 1 ~ GAS LIFT MA NDRELS ST MD lVD DEV TYÆ VLV LATCH PORT DATE 1 3518 3518 1 MMGM DMY RK 04/15/98 2 5084 5014 34 MMGM DMY RK 04/13/98 L 3 6568 6201 43 MMGM DMY RK 04/13/98 4 7901 7202 39 MMGM DMY RK 04/13/98 , I 5 8747 7878 35 MMGM OMY RK 04/13/98 ~ ~ 6 9467 8463 36 KBG2LS DMY BTM 04/13/98 9-5/8" MILLOUT WINDOW 8963' - 8979' (OFF WHIPSTOCK) 9535' 1-1 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 9558' 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 9579' 1-1 4-1/2" WLEG 1 1'1 ELMO TT NOT LOGGED 10292' 1- 7" X 4-1/2" BKR ZXP PKRI HGR, ID = 4.430" I r LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 10444' PERFORA TION SUMMARY REF LOG: ANADRILL MWD ON 03/30/98 A NGLE AT TOP PERF: 92 @ 11525' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 10700 -10775 0 11/23/04 2-7/8" 6 10775 - 10800 0 11/18/04 2-78" 6 11525 - 1162~ 0 ("" 1 0/24/03 2-7/8" 6 12300 - 12400 C 02/20/02 2-7/8" 6 13130 - 13230 C 09/29/00 2-7/8" 6 14081 - 14181 C 10/31/99 2-3/4" 4 14976 - 15076 C 10/29/99 NOTE: LOWER 3 ZONES ISOLATED BY CIBPS I CIBP SET 11/18/04 1'1 11150' I CIBP SET 10/23/03 1-1 12100' I CIBP SET 02/19/02 1-1 12500' 14-1/2" CIBP SET 09/28/00 1-1 13380' 14-1/2" CIBP SET 1 0/29/99 1-1 14258' I PBTO 1-1 15089' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 15175' DA TE REV BY COMMENTS 10/23/03 BJMcMITLF CORRECT PERF/CIBP SET 11/18-23/04 DBM'TLP CIBP, ADD PERFS DA TE REV BY COMMENTS 07/09/81 ORIGINAL COM PLETION 04113/98 RIG SIDETRACK 03/08/01 CI-VKAK CORRECTIONS 08/16/01 Cl-l/tlh PERF CORRECTIONS 10/09/01 CJ/KAK PERF CORRECTIONS 02124/02 OCRlKAK ADPERF & aBP ffiUOHOE BA Y UNrr W8...L: 16-14A ÆRMrr No: 1980360 API No: 50-029-20570-01 SEC 24, T10N, R15E, 1534' SNL & 527' EWL BP Exploration (Alaska) 16-14Bi ProposE::J Completion ) ~ , ~ i ~ ~ri~ ~',:";I ':1 I"""", 'I"':.":::~': ""::;,:,'-',::';';':;:"::"':',: I r TREE = WB...LHEAD = ACTUATOR = KB. B...EV = BF. B...EV = KOP= Max Angle = Datum MD = Datum lVD = 4-1/16" CrN V ETCO BAKER 66.15' 40.43 4200' 93 @ 10979" 9979' 8800' SS 2200' - 4-1/2" X nipple 10::: 3.813" ~ 2675' - 13-3/8" 72#, L-80 CSG, 10::: 12.347" ..- 4-1/2", 12.6#, L-80, TC-II TBG, 10::: 3.958" ~ 8773' - 9-5/8" X 7" Baker Packer Minimum ID = 3.725" @ 9790' 4-1/2" HES XN NIPPLE r 9730' - 4-1/2" X Nipple, 10::: 3.813 9750' - 7" X4-1/2" Baker 83 Packer, 10::: 3.875" 9770' - 4-1/2" X Nipple, 10::: 3.813" 9790' - 4-1/2" XN Nipple, 10::: 3.725" ) 9800' - 4-1/2" WLEG f 9810' - 4-1/2" Hanger / Liner Top Packer ~ off of whipstock @ 9910' I a~ PBTO::: 15187' 4-1/2", 12.6#, L-80, IBT-M, LNR 10 ::: 3.958 - 15267' I X C c .£ III. - 7" X 4-1/2" BKR ZXP PKR milled and pushed to the top of the 4-1/2" liner 9772' - 9-5/8" 47#, N-80 C8G, 10::: 8.681 7" X4-1/2" BKR ZXP PKR - 10292' 7", 26#, L-80, LNR 10 ::: 6.276 - 10444' 4-1/2",12.6#, L-80, LNR 10::: 3.958" - 15175' DATE REV BY COMMENTS 07/09/81 ORIGINAL COM PLETION 04/13/98 RIG SIDETRACK 03/08/01 CH/KAK CORRECTIONS 08/16/01 CHltlh ÆRF CORRECTIONS 10/09/01 CJ/KAK PERF CORRECTIONS 02/24/02 DCRlKAK ADPERF & CIBP ÆRFORA TION SUMIV1A RY REF LOG: ANADRILL MWD ON 03/30/98 ANGLEATTOPÆRF: 92 @ 11525' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE NOTE: DA TE REV BY COMMENTS 10/23/03 BJM:MfTLF CORRECT PERF/CIBP SET 11/18-23/04 DBMfTLP CIBP, ADD PERFS 11/17/05 JNC Proposed CorT1Jletion PRUDHOE BA Y UNIT WB...L: 16-14A ÆRMIT No: '1980360 API No: 50-029-20570-01 SEe 24, T10N, R15E, 1534' SNL & 527' EWL BP Exploration (Alas ka) COMPANY Pm-AILS REFERENCE INFORMATION SURVEY !'ROGIÜ\M P!an: !6-j4B wp:04(l6~¡4A/Platl16-!4B) BI'Am\Jco !'rueNol1h lkpÜl Fm lkpih Tù Surv~yi¡'hm Cr\7"<ikd By:Twy J¡¡kaho~ky (jüka!()((þbp.c()l¡it~1ê: ¡ <ì<)IÜJ){} l'1(1!!!K:d: 16~14B \\1\04 V12 Checked Dale Revi~w¢d: \\.·'ELL DF!'AILS CASING DETAILS No. TVD MD Name Size N;i¡)JIè Slot !6~!'¡A 14 TARGET DETAILS Name TVD +N/-S +E/-W Northing Eastîng Shape 16-148 Tl 72105L90 Point 16-148 T1 Point 16-148 TO 9056.50 3597.09 5933035.2 I Point SECTION DETAILS See MD THC TVD +N/-S +E/-W DLcg TFacc VSec Target 1 9910.00 14.01 OJ)O OJ)O 1133.61 1 15.78 l1.00 30.00 3 30.99 12.00 3L94 4 0.00 5 12.00 6 39.00 9056.50 0.00 16-148 TO 7 40.19 9056.44 6.00 1453. I 1 8 40.19 9046.90 0.00 9 6.00 I6-14B TI 10 6.00 II 15278.40 89.78 9l.8I 9056.50 5141.97 0.00 0.00 16-14B 1'2 9056.46 15267.00 41/2" 4.500 -- FORMATION TOP DETAILS No. TVDPath MDPath FOD1ntion 10170.66 10300.87 9056.50 15278.40 TCGL BCGL HOT -"' -,:: " a " u ~ " t VenìcaJ Scctìon at 90.00° [600ft/in] Bl'AmoùJ PROGRAM Plan: 16-14BwpÜ4 (JÚ-14A/Pbn 16-J4E¡ COMPANY DETAILS REfERENCE INFORMAt!ON SECTION DETAILS See MD Inc Az] TVD +N/-S +E/-W DLcg TFace VSec Target 1 9910.00 14.01 8815'()2 1169.40 0.00 0.00 1 9930.00 15.78 8819.96 I 12.00 30.00 3 10156.20 30.99 8959.84 12.00 31.94 4 10300.03 30.99 1316.81 0.00 0.00 5 10502.86 90.00 39.00 1430.39 12.00 19.77 6 39.00 9056.50 3597.09 000 0.00 16-14B TO 7 40.19 9056.44 3612.95 6.00 8 40.19 9046.90 487 L58 0.00 9 65.00 9046.50 2895.66 6.00 91.25 16-148 TI 10 91.81 9048.26 3329.42 6.00 90.05 II 15278.40 9L8I 9056.50 514l.97 5475.18 0.00 0.00 5475.18 16-14B 1'2 16-14/\ [943.96 Creakd By Tmy Jakabosky tjakat(}(Î.l!.bp,coili}þte: Dati::: TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape 16-14B 1'1 ]6-14BT2 16-14B TO 9056.50 3597.09 Point Poim 720694.47 Poinl CASING DEl' AILS No. TVD MD Name Size 9056.50 4 U2" 4.500 " :§ '" '" t:c TOP DETAILS TVDPalh MDPalh Formation TCGL BCGL HOT 490 2100 2800 3500 4200 4900 5600 6300 7000 WCsl(-)/Easl(+) [700fliin] e Sperry-Sun BP Planning Report e Company: 8P Amoco Date: 11/22/2005 Time: 12:49:53 Page: 1 Field: Prudhoe 8ay Co-ordinate(NE) Reference: Well: 16-14A, True North Site: P8 DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-14A Section (VS) Reference: Well (0.00N,0.00E,90.00Azi) Wellpath: Plan 16-148 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 16-148 wp04 Date Composed: 8/31/2005 Version: 22 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe 8ay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: P8 DS 16 TR-10-15 UNITED STATES: North Slope Site Position: Northing: 5927441.99 ft Latitude: 70 12 15.545 N From: Map Easting: 718969.88 ft Longitude: 148 14 4.567 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.66 deg Well: 16-14A Slot Name: 14 16-14A Well Position: +N/-S 1943.96 ft Northing: 5929396.43 ft Latitude: 70 12 34.664 N +E/-W 392.96 ft Easting : 719306.30 ft Longitude: 148 13 53.161 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 15278.00 9056.50 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 LCU/TSAD 0.00 0.00 10170.66 8965.50 TCGL 0.00 0.00 10300.87 9016.50 8CGL 0.00 0.00 15278.40 9056.50 HOT 0.00 0.00 Targets Map Map <-- Latitude ---> <--- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 16-148T1 9046.50 5120.87 2895.66 5934599.00 722051.90 70 13 25.023 N 148 12 29.057 W 16-148 T2 9056.50 5141.97 5475.18 5934695.00 724629.60 70 13 25.216 N 148 11 14.135 W 16-148 TO 9056.50 3597.09 1493.32 5933035.21 720694.47 70 13 10.040 N 148 13 9.797 W Plan Section Information MD IncI Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9910.00 40.59 14.01 8815.02 3065.73 1169.40 0.00 0.00 0.00 0.00 9930.00 42.68 15.78 8829.96 3078.57 1172.82 12.00 10.46 8.85 30.00 10156.20 66.94 30.99 8959.84 3244.68 1248.67 12.00 10.72 6.72 31.94 10300.03 66.94 30.99 9016.17 3358.14 1316.81 0.00 0.00 0.00 0.00 10502.86 90.00 39.00 9056.50 3519.38 1430.39 12.00 11.37 3.95 19.77 10602.86 90.00 39.00 9056.50 3597.09 1493.32 0.00 0.00 0.00 0.00 16-148 TO 10623.44 90.33 40.19 9056.44 3612.95 1506.44 6.00 1.61 5.78 74.42 12271.07 90.33 40.19 9046.90 4871.58 2569.66 0.00 0.00 0.00 0.00 12684.68 89.78 65.00 9046.50 5120.87 2895.66 6.00 -0.13 6.00 91.25 16-148 T1 13131.55 89.78 91.81 9048.26 5209.86 3329.42 6.00 0.00 6.00 90.05 15278.40 89.78 91.81 9056.50 5141.97 5475.18 0.00 0.00 0.00 0.00 16-148 T2 e Sperry-Sun BP Planning Report e Company: 8P Amoco Date: 11/22/2005 Time: 12:49:53 Page: 2 Field: Prudhoe 8ay Co-ordinate(NE) Reference: Well: 16-14A, True North Site: P8 DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-14A Section (VS) Reference: Well (0.00N,0.00E,90.00Azi) Wellpath: Plan 16-148 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD IncI Azim TVD Sys TVD VS N/S EIW DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft ft deg/100ft ft ft 9910.00 40.59 14.01 8815.02 8748.52 1169.40 3065.73 1169.40 0.00 5932494.69 720386.13 Start Dir 12/10 9930.00 42.68 15.78 8829.96 8763.46 1172.82 3078.57 1172.82 12.00 5932507.62 720389.17 MWD+IFR+MS 10000.00 49.97 21.57 8878.29 8811.79 1189.16 3126.41 1189.16 12.00 5932555.92 720404.11 MWD+IFR+MS 10100.00 60.76 27.98 8935.08 8868.58 1223.83 3200.82 1223.83 12.00 5932631.30 720436.61 MWD+IFR+MS 10156.20 66.94 30.99 8959.84 8893.34 1248.67 3244.68 1248.67 12.00 5932675.86 720460.17 End Dir : 1015 10170.66 66.94 30.99 8965.50 8899.00 1255.52 3256.09 1255.52 0.00 5932687.46 720466.68 TCGL 10200.00 66.94 30.99 8976.99 8910.49 1269.42 3279.23 1269.42 0.00 5932711.00 720479.90 MWD+IFR+MS 10300.00 66.94 30.99 9016.16 8949.66 1316.80 3358.11 1316.80 0.00 5932791.22 720524.97 MWD+IFR+MS 10300.03 66.94 30.99 9016.17 8949.67 1316.81 3358.14 1316.81 0.00 5932791.24 720524.98 Start Dir 12/10 10300.87 67.04 31.03 9016.50 8950.00 1317.21 3358.80 1317.21 11.97 5932791.92 720525.36 8CGL 10400.00 78.28 35.11 9046.01 8979.51 1368.83 3437.90 1368.83 12.00 5932872.47 720574.65 MWD+IFR+MS 10500.00 89.67 38.89 9056.49 8989.99 1428.59 3517.15 1428.59 12.00 5932953.43 720632.09 MWD+IFR+MS 10502.86 90.00 39.00 9056.50 8990.00 1430.39 3519.38 1430.39 11.97 5932955.71 720633.82 End Dir : 1050 10600.00 90.00 39.00 9056.50 8990.00 1491.52 3594.87 1491.52 0.00 5933032.94 720692.73 MWD+IFR+MS 10602.86 90.00 39.00 9056.50 8990.00 1493.32 3597.09 1493.32 0.00 5933035.21 720694.47 16-148 TO 10623.44 90.33 40.19 9056.44 8989.94 1506.44 3612.95 1506.44 6.00 5933051.44 720707.12 End Dir : 1062 10700.00 90.33 40.19 9056.00 8989.50 1555.84 3671.43 1555.84 0.00 5933111.34 720754.80 MWD+IFR+MS 10800.00 90.33 40.19 9055.42 8988.92 1620.37 3747.82 1620.37 0.00 5933189.56 720817.08 MWD+IFR+MS 10900.00 90.33 40.19 9054.84 8988.34 1684.91 3824.21 1684.91 0.00 5933267.79 720879.36 MWD+IFR+MS 11000.00 90.33 40.19 9054.26 8987.76 1749.44 3900.61 1749.44 0.00 5933346.02 720941.65 MWD+IFR+MS 11100.00 90.33 40.19 9053.68 8987.18 1813.97 3977.00 1813.97 0.00 5933424.25 721003.93 MWD+IFR+MS 11200.00 90.33 40.19 9053.10 8986.60 1878.50 4053.39 1878.50 0.00 5933502.48 721066.21 MWD+IFR+MS 11300.00 90.33 40.19 9052.52 8986.02 1943.03 4129.78 1943.03 0.00 5933580.71 721128.49 MWD+IFR+MS 11400.00 90.33 40.19 9051.94 8985.44 2007.56 4206.17 2007.56 0.00 5933658.94 721190.77 MWD+IFR+MS 11500.00 90.33 40.19 9051.37 8984.87 2072.09 4282.56 2072.09 0.00 5933737.16 721253.06 MWD+IFR+MS 11600.00 90.33 40.19 9050.79 8984.29 2136.62 4358.95 2136.62 0.00 5933815.39 721315.34 MWD+IFR+MS 11700.00 90.33 40.19 9050.21 8983.71 2201.15 4435.34 2201.15 0.00 5933893.62 721377.62 MWD+IFR+MS 11800.00 90.33 40.19 9049.63 8983.13 2265.68 4511.73 2265.68 0.00 5933971.85 721439.90 MWD+IFR+MS 11900.00 90.33 40.19 9049.05 8982.55 2330.21 4588.12 2330.21 0.00 5934050.08 721502.18 MWD+IFR+MS 12000.00 90.33 40.19 9048.47 8981.97 2394.74 4664.51 2394.74 0.00 5934128.31 721564.47 MWD+IFR+MS 12100.00 90.33 40.19 9047.89 8981.39 2459.27 4740.90 2459.27 0.00 5934206.54 721626.75 MWD+IFR+MS 12200.00 90.33 40.19 9047.31 8980.81 2523.80 4817.29 2523.80 0.00 5934284.76 721689.03 MWD+IFR+MS 12271.07 90.33 40.19 9046.90 8980.40 2569.66 4871.58 2569.66 0.00 5934340.36 721733.29 Start Dir 6/100 12300.00 90.29 41.92 9046.74 8980.24 2588.66 4893.39 2588.66 6.00 5934362.72 721751.65 MWD+IFR+MS 12400.00 90.16 47.92 9046.35 8979.85 2659.25 4964.17 2659.25 6.00 5934435.51 721820.15 MWD+IFR+MS 12500.00 90.03 53.92 9046.18 8979.68 2736.84 5027.17 2736.84 6.00 5934500.74 721895.87 MWD+IFR+MS 12600.00 89.89 59.92 9046.26 8979.76 2820.59 5081.73 2820.59 6.00 5934557.70 721978.00 MWD+IFR+MS 12684.68 89.78 65.00 9046.50 8980.00 2895.66 5120.87 2895.66 6.00 5934599.00 722051.90 16-148 T1 12700.00 89.78 65.92 9046.56 8980.06 2909.59 5127.23 2909.59 6.00 5934605.77 722065.64 MWD+IFR+MS 12800.00 89.77 71.92 9046.95 8980.45 3002.85 5163.18 3002.85 6.00 5934644.41 722157.81 MWD+IFR+MS 12900.00 89.77 77.92 9047.35 8980.85 3099.37 5189.19 3099.37 6.00 5934673.21 722253.52 MWD+IFR+MS 13000.00 89.77 83.92 9047.74 8981.24 3198.07 5204.97 3198.07 6.00 5934691.84 722351.72 MWD+IFR+MS 13100.00 89.78 89.92 9048.13 8981.63 3297.88 5210.34 3297.88 6.00 5934700.11 722451.33 MWD+IFR+MS 13131.55 89.78 91.81 9048.26 8981.76 3329.42 5209.86 3329.42 6.00 5934700.55 722482.87 End Dir : 1313 13200.00 89.78 91.81 9048.52 8982.02 3397.84 5207.70 3397.84 0.00 5934700.37 722551.32 MWD+IFR+MS 13300.00 89.78 91.81 9048.90 8982.40 3497.78 5204.53 3497.78 0.00 5934700.11 722651.31 MWD+IFR+MS 13400.00 89.78 91.81 9049.29 8982.79 3597.73 5201.37 3597.73 0.00 5934699.86 722751.31 MWD+IFR+MS 13500.00 89.78 91.81 9049.67 8983.17 3697.68 5198.21 3697.68 0.00 5934699.60 722851.30 MWD+IFR+MS 13600.00 89.78 91.81 9050.06 8983.56 3797.63 5195.05 3797.63 0.00 5934699.34 722951.30 MWD+IFR+MS 13700.00 89.78 91.81 9050.44 8983.94 3897.58 5191.88 3897.58 0.00 5934699.08 723051.29 MWD+IFR+MS 13800.00 89.78 91.81 9050.82 8984.32 3997.53 5188.72 3997.53 0.00 5934698.82 723151.28 MWD+IFR+MS 13900.00 89.78 91.81 9051.21 8984.71 4097.48 5185.56 4097.48 0.00 5934698.56 723251.28 MWD+IFR+MS 14000.00 89.78 91.81 9051.59 8985.09 4197.43 5182.40 4197.43 0.00 5934698.31 723351.27 MWD+IFR+MS e Sperry-Sun BP Planning Report e Company: 8P Amoco Date: 11/22/2005 Time: 12:49:53 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-14A, True North Site: P8 DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-14A Section (VS) Reference: Well (0.00N,0.00E,90.00Azi) Wellpath: Plan 16-148 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S EIW DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft ft deg/1 OOft ft ft 14100.00 89.78 91.81 9051.98 8985.48 4297.38 5179.24 4297.38 0.00 5934698.05 723451.27 MWD+IFR+MS 14200.00 89.78 91.81 9052.36 8985.86 4397.33 5176.07 4397.33 0.00 5934697.79 723551.26 MWD+IFR+MS 14300.00 89.78 91.81 9052.74 8986.24 4497.28 5172.91 4497.28 0.00 5934697.53 723651.26 MWD+IFR+MS 14400.00 89.78 91.81 9053.13 8986.63 4597.23 5169.75 4597.23 0.00 5934697.27 723751.25 MWD+IFR+MS 14500.00 89.78 91.81 9053.51 8987.01 4697.18 5166.59 4697.18 0.00 5934697.01 723851.24 MWD+IFR+MS 14600.00 89.78 91.81 9053.90 8987.40 4797.12 5163.42 4797.12 0.00 5934696.76 723951.24 MWD+IFR+MS 14700.00 89.78 91.81 9054.28 8987.78 4897.07 5160.26 4897.07 0.00 5934696.50 724051.23 MWD+IFR+MS 14800.00 89.78 91.81 9054.66 8988.16 4997.02 5157.10 4997.02 0.00 5934696.24 724151.23 MWD+IFR+MS 14900.00 89.78 91.81 9055.05 8988.55 5096.97 5153.94 5096.97 0.00 5934695.98 724251.22 MWD+IFR+MS 15000.00 89.78 91.81 9055.43 8988.93 5196.92 5150.78 5196.92 0.00 5934695.72 724351.22 MWD+IFR+MS 15100.00 89.78 91.81 9055.81 8989.31 5296.87 5147.61 5296.87 0.00 5934695.47 724451.21 MWD+IFR+MS 15200.00 89.78 91.81 9056.20 8989.70 5396.82 5144.45 5396.82 0.00 5934695.21 724551.21 MWD+IFR+MS 15278.00 89.78 91.81 9056.50 8990.00 5474.78 5141.98 5474.78 0.00 5934695.01 724629.20 41/2" 15278.40 89.78 91.81 9056.50 8990.00 5475.18 5141.97 5475.18 0.00 5934695.00 724629.60 16-148 T2 PRUDHOE Oil PRUDHOE BAY 100 50 10 5 16-14A Gas Water Rate Rate ( MMcf/d ) ( MbbUd ) 05 0.1 1998 99 2000 02 03 04 05 Date ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 Repair Well D Pluç Perforations[K] Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate [K] 66.15 8. Property Designation: ADL-0028332 11. Present Well Condition Summary: 4. Current Well Class: Development D Stratigraphic D 9. Well Name and Number: 16-14A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryO ServiceŒ) Stimulate ŒJ OtherD WaiverO Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 198-0360 6. API Numbel 50-029-20570-01-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 15175 feet true vertical 9026.4 feet Plugs (measured) 11150,12100,12500,13380,14258 Effective Depth measured 12100 feet true vertical 9030.5 feet Junk (measured) None Casing Length Size CONDUCTOR 80 20" 94# H-40 LINER 1671 7" 26# L-80 LINER 4883 4-1/2" 12.6# L-80 PRODUCTION 8494 9-5/8" 47# N-80 PRODUCTION 443 9-5/8" 47# SOO-95 SURFACE 2641 13-3/8" 72# L-80 MD TVD Burst Collapse 31 111 31.0 - 111.0 1530 520 8773 - 10444 7899.4 - 9054.5 7240 5410 10292 - 15175 9030.6 - 9026.4 8430 7500 26 - 8520 26.0 - 7692.8 6870 4760 8520 - 8963 7692.8 - 8056.9 8150 5080 30 - 2671 30.0 - 2670.9 4930 2670 Perforation depth: Measured depth: 10700 - 10725, 10725 - 10775, 10775 - 10800 True vertical depth: 9051.07 - 9050.62, 9050.62 - 9049.46, 9049.46 - 9048.82 IV£: 1 8 2005 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 26 9579 Alaska '; ., . ¡ COmm¡~~\.!.. ¡'t!'kit'I'i'lf """"".:i:¡ ""UI,", @ge Packers & SSSV (type & measured depth): 4-112" Cameo A-1lnjection SSV 7" Top Packer 4-1/2" Baker S-3Perm Packer 4-1/2" Baker ZXP Packer @ 2197 @ 8773 @ 9535 S~I~W~t:I' JAN ~ 0 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure -13.4 0 420 -17.9 0 468 13 Prior to well operation: Subsequent to operation: Oil-Bbl 0 0 Tubing Pressure 3270 3270 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations - ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilD GasD DevelopmentD ServiceŒ] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ,JJ C~ Cc~ WAG D GINJŒ] WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-398 Title Production Technical Assistant Signature Form 10-404 Revised 4/2004 J\L Phone 564-4657. rt.DDMS 3rt ,~~,eo 20051/13/05 OR\G\Nh ) ) 16-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/16/04 CTU#5: COIL FLAG/SET CIBP. MIRU AFTER PHASE II BLOW. DIG UNIT OUT. MU/RIH WI PDS GR/CCL & 3.625" NOZZLE FOR CIBP DRIFT. RIH TO 115001, PUH LOGGING AT 40 FPM. FLAG PIPE 110901 CTMD. CONT' ON WSR 11/17104... 11/17104 CTU #5, CIBP/ADD PERF/ACID; CONT' FROM WSR 11/16/04... LOGGING UP AT 40 FPM. LOG FROM 115001 TO 100001 CTMD. POOH. PDS DATA REPORTED TO BE GOOD. RIH WITH BAKER 41/2" CIBP. PDS CAN NOT CORRELATE DATA. POOH WI CIBP. CUT 1001 PIPE. MU/RIH WI MEM GR/CCL WI 3.62511 DRIFT. LOG FROM 116011- 10000', FLAG PIPE @ 110081. POOH. MU/RIH WI 4.511 CIBP. CONTINUED ON 11/18/04 WSR. 11/18/04 Perforate 107751.108001 6 SPF 11/22/04 Perforate 107251-1077516 SPF 11/23/04 CONTINUED FROM 11/22/04 WSR. RIH WI GUN #4. DEPTH CORRECTION @ CIBP. SHOOT INTERVAL 107001-107251. POOH. MU/RIH WI 2.511 JSN. PUMP STAGE 1: 25 BBLS 3% NH4CL, 10 BBL 7.5% HCL, 10 BBL 9:1 HF ACROSS PERFS. PUMP STAGE 2: 34 BBLS NH4CL, 40 BBLS 7.5% HCL, 40 BBLS 9:1 HF, 131 BBLS NH4CL. RECIPROCATE ACROSS PERFS. POOH, FP BACKSIDE WI 31 BBLS METH. RDMO.. PRE-ACID INJECTIVITY: 1.7 BPM @ 1377 PSI. POST-ACID INJECTIVITY: 2.0 BPM @ 205 PSI FLUIDS PUMPED BBLS 405 505 213 50 50 1223 60/40 Methanal 1 % KCL NH4CL wI 10% U-66 I 0.20/0 F-103 7.5% HCL 9-1 HCL - HF TOTAL Page 1 TREE = 4-1/16" crw ~~~!:~~. 0 = ,.. ,.. ".... ,...,..,y...§!.~,~. ACTUA TOR = BAKER 'Kì3:"ELST';' . ... ,..... ""@>O"""66':15; BF~''"Ël8T;,"w,"m"wm,""",w¡Õ:43 .....mmn,"........................,.""""""""""'" " . '-d..............,. ... .>" 'n'.m KOP = 4200' ,~~,~,~.~,9.!~ ~'" "~~"n~~i'~~~~:" Datum MD = 9979' "õâiumïV6';;ww", ""'880Õi'SS ') 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 26751 1 9-5/8" X 7" BKR PKR/HGR, 10 = 6.25" I.., 8773' Minimum ID = 3.813" @ 9558' 4-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" 1-1 9578' 9-5/8" CSG, 47#, N-80, 10 = 8.681" 1-1 97721 16-14A SAt 'J NOTES: 4-1/2" CHROME TBG. WELL> 70° @ 10269' AND > 90° @ 10468'. * A-1 INJ VL V SET IN SVN @ 2197' ON 10/1/00 (1.55" BEAN). 8 2197' 1-1 4-1/2" CAMCO SVN, 10 = 3.813" 1 ~ ~ GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH PORT 3518 1 MMGM DMY RK 5014 34 MMGM DMY RK 6201 43 MMGM DMY RK 7202 39 MMGM DMY RK 7878 35 MMGM DMY RK 8463 36 KBG2LS DMY BTM L ST MD 1 3518 2 5084 3 6568 4 7901 5 8747 6 9467 DATE 04/15/98 04/13/98 04/13/98 04/13/98 04/13/98 04/13/98 I ~ r 9-5/8" MILLOUT WINDOW 8963' - 8979' (OFF WHIPSTOCK) 9535' 1-1 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 1 . 95581 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 9579' 1-1 4-1/2" WLEG 1 1-1 ELMO TT NOT LOGGED 1 10292' 1- 7" X 4-1/2" BKR ZXP PKR/ HGR, 10 = 4.430" 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 10444' ÆRFORA TION SUMMARY REF LOG: ANADRILL MWD ON 03/30/98 ANGLE AT TOP PERF: 92 @ 11525' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 10700 - 10775 0 11/23/04 2-7/8" 6 10775 - 10800 0 11/18/04 2-78" 6 11525 - 11625 0 10/24/03 2-7/8" 6 12300 - 12400 C 02/20/02 2-7/8" 6 13130 - 13230 C 09/29/00 2-7/8" 6 14081 - 14181 C 10/31/99 2-3/4" 4 14976 - 15076 C 10/29/99 NOTE: LOWER 3 ZONES ISOLATED BY CIBPS CIBPSET 11/18/04 1-1 11150' 1 CIBP SET 10/23/03 1-1 12100' I CIBP SET 02/19/02 1-1 12500' 14-1/2" CIBP SET 09/28/00 1-1 13380' 14-1/2" CIBP SET 10/29/99 1-1 14258' I PBTD 1-1 15089' I 14-112" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 15175' I DA TE REV BY COMMENTS 10/23/03 BJMcMITLF CORRECT ÆRF/CIBP SET 11/18-23/04 DBMlTLP CIBP, ADD ÆRFS DA TE R8/ BY COMMENTS 07/09/81 ORIGINAL COMPLETION 04/13/98 RIG SIDETRACK 03/08/01 CH/KAK CORRECTIONS 08/16/01 CI-Vtlh ÆRF CORRECTIONS 10/09/01 CJ/KAK PERF CORRECTIONS 02/24/02 DêFVKAK ADÆRF & CIBP PRUDHOE BAY UNIT WELL: 16-14A PERMIT No: 1980360 API No: 50-029-20570-01 SEC 24, T10N, R15E, 1534' SNL & 527' EWL BP Exploration (Alas ka) . . ) '~:~~Œ J)~ ~1!Æ~[[&\ ) AT,ASIiAOILAND GAS CONSERVATION COMMISSION l~'ß-026 FRANK H. MURKOWSKI, GOVERNOR 333 W. ¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA.99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Lee Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 16-14A Sundry Number: 304-398 Dear Mr. Lee: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a mmission decision to Superior Court unless rehearing has been requested. " BY ORDER OF JYE COMMISSION DATED thisf- day of November, 2004 Enel. SCANNED NOV 0 5 2004 ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROæ 20 AAC 25.280 NOV n StratigraphicD Service Œ] 9. Well Name and Numper: 16-14A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator I Name: Suspend 0 Repair Well D Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7.KB Elevation (ft): 66.15 KB 8. Property Designation: ADL-0028332 11. Total Depth MD (ft): 15175 Total Depth TVD (ft): 9026.4 Casing Length Size Conductor 80 Liner 1671 Liner 4883 Production 8494 Production 443 Surface 2641 Perforation Depth MD (ft): 11525 - 11625 Packers and SSSV Type: 4-1/2" Baker 8-3 Perm Packer 4-1/2" Baker ZXP Packer 4-1/2" Camco A-1 Injection 8SV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal ŒJ 20" 94# H-40 7" 26# L-80 4-1/2" 12.6# L-80 9-5/8" 47# N-80 9-5/8" 47# 800-95 13-3/8" 72# L-80 Perforation Depth TVD (ft): 9031.39 9028.6 Detailed Operations Program 0 BOP Sketch 0 November 16, 2004 Date: Printed Name Signature '~L Form 10-403 Revised 06/2004 ) )¡Jc;A- 1'1 ~ 1200t D~ III"Î'/~ ?nn4 Operation Shutdown D Perforate[K] i:~~WW~¡:¡¡.""BW~fi~~~aID Plug Perforations Œ] StimulateŒ] Time Ext1filnïe~@~1B OtherD Perforate New Pool D Re-enter Suspended Well 0 4. Current Well Class: Development D 5. Permit to Drill Number: 198-0360./ Exploratory D / 6. API Number / 50-029-20570-01-00 15089 8961.9 TVD Plugs (md): Junk (md): 12100, 13380, 14258 Burst None MD Collapse top bottom top bottom 31 111 31.0 111.0 1530 520 8773 10444 7899.4 9054.5 7240 5410 10292 15175 9030.6 9026.4 8430 7500 26 8520 26.0 8056.9 6870 4760 8520 8963 7692.8 8056.9 8150 5080 30 2671 30.0 2670.9 4930 2670 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # 13Cr80 26 9579 Packers and SSSV MD (ft): 9535 10292 2197 8773 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒJ / 15. Well Status after proposed work: Oil D GasD WAG D GINJŒ] PluggedD AbandonedD WINJD WDSPLD Prepared by Garry Catron 564-4657. Contact Tim Lee Title Phone Petroleum Engineer 564-4038 11/2104 Commission Use Only Sundry Number: 3oLf- ?:fl<ë Mechanciallntegrity Test D Location Clearance D RBDMS BFL NOV - 4 2004 .;, t BY ORDER OF THE COMMISSION Date: 1(~7' OR\G\NA - SUBMITIN DUPLICATE . , ) ') bp ... ..\If.''', -....~ ~.....- ~~- ~...- ....~ ~...... .I't~I\~ ". To: John Smart/Doug Cismoski GPB Well Ops Team Leaders 9/8/04 From: Tim Lee DS 16 PE SubjectDS 16-14A CIBP/ADPERF PBD16WL14-C CAP SUS Est. Cost: $140M NOB: 400 Well 16-14Ai is a horizontal MIST injector which has injected MI in 5 previous bulbs.~~is MI Injection bulb will be the last of 6 scheduled bulbs. All five previous bulbs have required an acid stimulation to achieve the desired injection rate. The first step in the process will be to perform a schmoo-b-gone to ensure that the tubing is clean for optimal plug setting. Next, a memory log will be run to determine the plug setting depth, making sure to avoid any collars. The procedure will then entail setting a cast iron bridge plug to isolate the previous injection zone, perforating a new zone for additional MI injection, and performing an acid stimulation on well 16-14Ai. C..:t: B P (;2 1... ll. IS"O ' M d ~ ? Pe-,f i jO 700( - .goo' v~d The estimated date of job commencement is October 8\2004. ~, (.~' Y'túlvvþ . \LL6,k- Contact Tim Lee at 564-4038 (work) or 360-3565 (cell) with any questions or comments. BP Exploration (Alaska) ffiLOHOE SA Y um WELL: 16-14A PERMIT No: 1980360 AR No: 50-029-20570-01 SEC 24, T1 ON, R15E, 1534' SI'l. & 527' BNL ()A. TE RBI BY COMf\!ENTS 10123/03 BJM::MffLF CORRECT PERF/aBP SET REV BY COMf\!ENTS ORIGINAL COMPLETION RIG SIDETRACK Q-I/KA K CORRECTIONS CH'tlh ÆRF CORRECllONS CJ/KAK ÆRF CORRECllONS OCRIKAK ADPERF & aBP DATE 07/09/81 04/13/98 03/08/01 08/16/01 10/09/01 02/24/02 9535' H 7" X 4-112" BKRS-3 PKR, D = 3.875" I 9558' H 4-112" HES X NIP, 10 = 3.813" I 9579' H 4-112" WLEG I H 8..MDTTNOT LOGGED 14-1/2" LNR, 12.6#, L-80. .0152 bpf, 10= 3.958" H 15175' 17' LNR, 26#, L-80, .0383 bpf, 10 = 6.276" H 10444' I 12100' H CIBP, SET ON 10/23103 PERFORATION SUMVIARY REF LOG: ANADRILL MNDON03ß0/98 ANGLEATTOPÆRF: 92@ 11525' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL OpnlSqz DA TE 2-78" 6 11525 - 11625 0 10/24/03 2-7/8" 6 12300 - 12400 C 02120/02 2-7/8" 6 13130-13230 C 09/29/00 2-7/8" 6 14081 -14181 C 10/31/99 2-314" 4 14976 - 15076 C 10/29/99 NOTE: LOWER 3 ZOflES ISOLATED BY CIBPS I 12500' HCIBP, SET ON 02/19/02 13380' H4-1/2" CIBP, SET ON 9/28/00 I 14258' H4-1/2" CBP, SETON 10/29/99 I PBTD H 15089' 9-5/8" CSG. 47#, N-80, 10 = 8.681" H 9772' 10292' I- 7" X 4-1/2" BKR ZXP PKRI HSR, 10 = 4.430" 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, D = 3.958" H 9578' I.., 9-5/8" MLLOUT WINDOW 8963' - 8979' ( OFF WHIPSTOCK) 13-318" CSG, 72#, L-80, 10 = 12.347" H 2675' ~ ~ GAS LIFT MANDRELS ST MD TV D DEV TYPE VLV LATCH PORT DATE 1 3518 3518 1 MMGM DV RK 04/15/98 2 5084 5014 34 MMGM DV RK 04/13198 L 3 6568 6201 43 MMGM DV RK 04/13/98 4 7901 7202 39 MMGM DV RK 04/13198 1 9-5/8" X 7' BKR PKRlHGR, 10 = 6.25" H 8773' I l , 5 8747 7878 35 MMGM DV RK 04/13198 ~ i 6 9467 8463 36 KBG2LS DV BTM 04/13198 Minimum ID = 3.813" @ 9558' 4-1/2" HES X NIPPLE 2197' H 4-1/2" CAMCO SVN. 10 = 3.813" I e TRæ = .. 4-1/16" CIW "!Y~~I;!A.I?_=. V ETCO AGTUATOR= BAKER KB. ELBI = 66.15' BF:ËCèi';'" .m..... ····-·-·...··46:·4"3' KC)'P= .m·.m.m .......420d M~ix-A'ngië·-;;--··..···9"3'..@Tó9=¡9ì: õãtürTl'K/D;' m., ·....m ·..·······...·00"7"9' '6ãfüñï"ï,Ftj'; .............- 886"Ö"'ss SAFETY NOTES: 4-1/2" CHROMETBG. WELL> 70° @ 10269' AND> 90° @ 10468'. * A-1INJ VLV SET IN SVN @ 2197' ON 10/1/00 (1.55" BEAN ). 16-14A ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION F<E:CEf\/E~t::.'¡; REPORT OF SUNDRY WELL OPERATIOfi 04 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Suspend D Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations []] Perforate New Pool D 4. Current Well Class: Perforate ŒJ^.I'.'~ I' ., !'Wé!.y~g Com:, CfllT~1illJ ¡O\ I'JI" 1.,1 d II ~- Stimulate ŒJ Time Extensi~H)f;::~ìf' Re-enter Suspended Well 0 5. Permit to Drill Number: 198-0360 Name: BP Exploration (Alaska), Inc. Development D Exploratory 0 Service ŒJ 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Stratigraphic D 9. Well Name and Number: 16-14A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 66.15 8. Property Designation: ADL-0028332 11. Present Well Condition Summary: Total Depth measured 15175 feet true vertical 9026.4 feet Plugs (measured) Junk (measured) None Effective Depth measured 12100 feet true vertical 9030.5 feet 6. API Number 50-029-20570-01-00 12100,12500,13380,14258 Casing Length Size MD TVD Conductor 80 20" 94# H-40 31 111 31.0 - 111.0 liner 1671 7" 26# L-80 8773 - 10444 7899.4 - 9054.5 Liner 4883 4-1/2" 12.6# L-80 10292 - 15175 9030.6 - 9026.4 Production 8937 9-5/8" 47# N-80 26 - 8963 26.0 - 8056.9 Production 443 9-5/8" 47# SOO-95 8520 - 8963 7692.8 - 8056.9 Surface 2641 13-3/8" 72# L-80 30 2671 30.0 - 2670.9 Perforation deDth: Measured depth: 11525 - 11625 True vertical depth: 9031.39 - 9028.64 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 26 9579 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 4-1/2" Camco A-1 Injection SSV 7" Liner Top Packer @ 9535 @ 10292 @ 2197 @ 8773 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Burst Collapse 520 5410 7500 4760 5080 2670 1530 7240 8430 6870 8150 4930 Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure 0 0 24454 400 3301 0 0 11260 290 2946 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] 16. Well Statús "åfter pròposed work: Operational Shutdown D OilD GasO WAG ŒJ GINJO WINJO WDSPLO Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run- Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garr Catron Signature r~ 1 6 2004 Title Production Technical Assistant Date 2/23/04 Form 1 0-404 Revised 12/2003 16-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/23/03 CTU #5: COIL FLAG/CIBP/ADD PERFS. --CONTINUED-- RIH WITH BAKER BHA & SWS MEMORY CCUGAMMA W/2.20" CARRIER», 2.125" XO, 2.70" XO, 3.7011 X 5.94' DRIFT BACK TO 3.5" NOZZLE. LOG 12,300' TO 11,400', FLAG AT 12,000', POOH. RIH WITH 2.75" <J> SETTING TOOL, 3.525" 1AA WL ADP KIT, 3.59311 1AA CIBP. SET CIBP @ 12,100', REFERENCED TO SHLUMBERGER MWD 3/16/98. MIT-T TO 3000 PSI PASSED. RIH WITH 251 X 2-7/8" PJ 2906 PERF GUNS. TIE INTO CIBP & PERFORATE 11,600' TO 11,625', POOH. CUT 100' PIPE. RIH WITH 25' X 2-7/8" PJ 2906 PERF GUNS. ---CONTINUED ON 10/24/03 WSR--- 10/23/03 SET CIBP @ 12100' 10/24/03 CTU #5: COIL FLAG/CIBP/ADD PERFS. --CONTINUED-- TIE INTO CIBP AT 12,100' & PERFORATE 11,575' TO 11,600', POOH. RIH WITH 25' X 2-7/811 PJ 2906 PERF GUNS. TIE INTO CIBP & PERFORATE 11,550' TO 11,575', POOH. RIH with 25' x 2-7/811 PJ 2906 Perf Guns. Tie into CIBP & perforate 11,525' to 11,550', POOH. Cut 100' from coil. Perform weekly BOP test. RIH with 2.7511 JSN, start jetting NH4CI water, 7.5% acid & 9%/1% HCI/HF Mud acid as per program. 10125/03 CTU #5, ACID TREATMENT. CONTINUED-- JET ACROSS PERFS WITH 25 BBL'S NH4CL I 50 BBL'S 7.5 HCL I 50 BBL'S 9%/1 % HCUHF MUD ACID I 100 BBL'S NH4CL. POOH AFTER TOTAL OVER FLUSH HAD BEEN PUMPED. INITIAL INJECTION PRESSURE WI NH4CL WATER 1250 PSI AT 1.6 BPM. FINAL INJECTION PRESSURE PUMPING NH4CL WATER OVER FLUSH 1010 PSI AT 1.8 BPM. BULLHEAD 60/40 METH AT 1100 PSI/2.1 BPM. FIRST STAGE ACID TITRATED AT 7.6% HCL AND <50 PPM IRON. SECOND STAGE ACID (MUD) TITRATED AT 9% HCL AND 1% HF AND < 50 PPM IRON. «NOTE: THE NH4CL WATER WAS IN AN UP RIGHT TANK ON LOCATION AND SHOULD HAVE BEEN FILTERED BUT DUE TO MISCOMMUNICATION NOT RUN THROUGH A FILTER» --JOB COMPLETE-- FLUIDS PUMPED BBLS 12 Diesel 12 1 % KCL 53 Crude 130 NH4CI water 50 7.5% HCI 50 9% 1 1 % HCI/H F Mud Acid 440 60140 Methanal 747 TOTAL Page 1 TREE = 4-1/16"CIW WELLJ-EAD = V ETCO AClUATOR = BAKER KB. 8...BI = 66.15' BF. ELBI = 40.43 KOP= 4200' Max Angle = 93 @ 10979" Datum M) = 9979' Datum lVD = 8800' SS 16-14A SAFETY NOTES: 4-112" CHROMETBG. WEll. > 70° @ 10269' AND> 90° @ 10468'. * A-1INJ VLV SET IN SVN @ 2197' ON 10/1/00 (1.55" BEAN ). <I 4-1/2" CAMCO SVN, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" 9-5/8" X 7' BKR PKR/HGR, ID = 6.25" 8773' ST MD 1 3518 2 5084 3 6568 4 7901 5 8747 6 9467 GAS LIFT MANDRELS TV D DEV TYPE VL V LA TCH PORT 3518 1 MMGM DV RK 5014 34 MMGM DV RK 6201 43 MMGM DV RK 7202 39 MMGM DV RK 7878 35 MMGM DV RK 8463 36 KBG2LS DV B1M DATE 04115/98 04/13/98 04113/98 04113/98 04/13/98 04/13/98 Minimum ID = 3.813" @ 9558' 4-1/2" HES X NIPPLE 9-5/8" MLLOur WINOOW 8963' - 8979' ( OFF WHIPSTOCK) 9-5/8" CSG, 47#, N-80, ID = 8.681" 9535' H 7" X 4-1/2" BKRS-3 PKR, [) = 3.875" I 4-1/2" HES X NIP. ID = 3.813" 14-1/2"TBG, 12.6#, 13-CR, .0152 bpf, [) =3.958" I 7" X 4-1 /2" BKR ZXP PKR/ !-GR, ID = 4.430" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PERFORATION SUMMARY RB= LOG: A NA DRILL MJlJD ON 03130/98 ANGLEATTOPÆRF: 92@ 11525' I\bte: Refer to Produetion DB for historieal perf data SIZE SPF II'-ITERV AL Opn/Sqz DATE 2-78" 6 11525 -11625 0 10/24/03 2- 7/8" 6 12300 - 12400 C 02120/02 2- 7/8" 6 13130 - 13230 C 09/29/00 2-7/8" 6 14081-14181 C 10/31/99 2-3/4" 4 14976 - 15076 C 10/29/99 NOTE: LOWER 3 ZOf\ES ISOLATED BY CIBPS I 12100' I CIBP, SET ON 10/23/03 I 12500' t-lCIBP. SET ON 02/19/02 I 13380' I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMEI'-ITS DATE RBI BY COMrvENTS 07/09/81 ORIGINAL COMPLETION 10/23/03 BJ Me MffLF CORRECT PERF/aBP SET 04/13/98 RIG SIDEfRACK 03/08/01 CH/KA K CORRECTIONS 08/16/01 CH'tlh ÆRF CORREC110NS 10/09/01 CJ/KA K ÆRF CORREC110NS 02/24/02 DCRiKA K ADPERF & aBP ffiLDHOE BA Y UNIT WELL: 16-14A PERMIT No: 1980360 AA No: 50-029-20570-01 SEC 24, T1 ON, R15E, 1534' Sf\l. & 527' 8NL BP Exploration (Alaska) RE: 16.-14A (PTD# 1980360) 4 Year MITIA ( l r' Subject: RE: 16-14A (PTD#J980360}4 YearMITIA From: "Dube, Anna T"<Anna.Dube@BP.eom> Date: Wed, 24 Dee 2003 10:44:28 -0900 T.Q:,JatDl~$Regg<jirri¿tegg@àdiriíri1ståte.åk.lls> < ""'- CC: Winton GAubert <wintoll_aubert@admin.state.ak.us>, Admin AOGCC Prudhoe Bay <aogec-prudhoe_bay@admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWW ellIntegrityEngineer@BP.com> Jim, Tubing integrity is implied by the pressure differential between the tubing and IA before and after the test was conducted. Beginning WHPs 12/21/03 (2550/240/270) 2000+ psi differential Post test WHPS 12/22/03 (2550/700/340) 1800+ psi differential There was some thermal affects warming the fluid and increasing pressure but still showing a differential. I've included a plot of TIO pressures. This history also shows good pressure differential. In the future, we will attempt to produce more of a pressure differential during the test. Please feel free to call if you have any additional questions, Thanks, Anna Dube Well Integrity Engineer GPB Wells Group Phone: '(907) 659-5'102 Pager: (907) 659-5100 xl154 -----Original Message----- From: J ame s Regg [~~~~ 1'~.~-=jJ:_~~~~g~~_~9~i_:Q_.~!~-~ e ..:.._~k . ~~] Sent: Tuesday, December 23, 2003 9:40 AM To: Dube, Anna T Cc: Winton G Auberti Admin AOGCC Prudhoe Bay Subject: Re: 16-14A (PTD# 1980360) 4 Year MITIA Anna - The test looks more like a CMIT than an MITi there was no differential pressure between the tubing and IA, and no way to determine if there is any communication. Was there any other testing done to confirm integrity of the primary barrier (tbg)? Dube, Anna T wrote: ~tA~~~~E~) Jt\N 2 @ 200¿~~, 1 of2 12/30/2003 8:51 AM RE: 16.-14A (PTD# 1980360) 4 Year MITIA . { t l Jim, winton, and Bob, Please see the attached MITIA form for the 4 year AOGCC requirement for well 16-14A (PTD# 1980360). The AOGCC representative declined witnessing the test. Thank you, Anna Dube Well Integrity Engineer GPB Wells Group Phone: ( 907 ) 659 - 5100 Pager: (907) 659-5100 x1923 «MIT PBU 16-14A 12-14-03.xls» .. TIO PBU 16-14A Content-Description: 12-24-03.doe TIO PBU 16-14A . . Content- Type: appheatIon/msword Content-Encoding: base64 20f2 12/30/2003 8:51 AM ('r) a ---- "1" N ---- N "..... 4-< 0 r/J cd -;-> ..9 P-, 0 >--; t-< ~ a \() ('r) a co 0- "..... =t\:: a t-< P-, '-" -< "1" .---< , \() "..... ( ~f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / Drill SITe 16 12/21/03 Anna Dube WITnessing declined by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 16-14A Type Ini. G TVD 8,518' TubinQ 2,550 2,550 2,550 2,550 Interval 4 P.T.D. 1980360 Type test P Test psi 2,130 CasinQ 240 2,500 2,460 2,460 P/F P Notes: Well Type Inj. TVD Tubino Interval P.T.D. Type test Test psi CasinQ P/F Notes: Well Type Inj. TVD Tubino Interval P.T.D. Type test Test psi Casino P/F Notes: Well Typelni. TVD TubinQ Interval P.T.D. Type test Test psi Casino P/F Notes: Well Type Ini. TVD Tubino Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) SCA~NEJ~ DEC 3 1 2003 MIT Report Form Revised: 06/19/02 2003-1214_MIT _PBU_16-14A.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / DS 16 1 O/31/O3 Joe Anders None Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. 1980360 Type test P Test psiI 2,130 CasingI 180 4,000 3,940 3,920 P/FI P Notes: MITIA to 4000 psi, pre-MI injection start. p.T.D.I ITyPe test Test P/FI Notes: We.,I Type,hi.I TVD TubingI Type testI Test CasingI P/FI Notes: I Type ,nj.I TVD I Tubingl Type teslI Test psiI P/F/ Notes: We,,I Type Inj.I TVD I Tubingl Type tesl~ Test psiI P/FI Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 16-14 10-31-03.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X ClaP/Add Perfs/ACID Pu, tubing _ Alter casing_ Repair well_ Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1532' FNL, 4753' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 3755' FNL, 3585' FEL, Sec. 13, T10N, R15E, UM At effective depth 1298' FNL, 3172' FEL, Sec. 13, T10N, R15E, UM At total depth 1270' FNL, 3191' FEL, Sec. 13, T10N, R15E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 719307, 5929395) (asp's 720383, 5932487) (asp's 720723, 5934955) (asp's 720703, 5934983) 6. Datum elevation (DF or KB feet) RKB 66 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-14A 9. Permit number / approval number 198-036 10. APl number 50-029-20570-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 15175 feet Plugs (measured) 9026 feet Tagged ClBP @ 12528' (02/19/2002). Tagged ClaP @ 13380' (09/28/2000). Tagged ClaP @ 14258' (10/30/1999). Effective depth: measured 12528 feet Junk (measured) true vertical 9024 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 300 sx Permafrost 110' 110' 3000 sx Fondu & 1250 Surface 2609' 13-3/8" 2675' 2675' sx Permafrost Production 8897' 9-5/8" 500 sx Class 'G' 8963' 8057' Liner 1671' 7" 288 sx Class 'G' 10444' 9055' Sidetrack Liner 4883' 4-1/2" 477 sx Class 'G' 15175' 9026' Perforation depth: measured Open Perfs 12300-12340, 12368-12428, Isolated Below ClaP- 13130-13230, 14081-14181, 14976-150~"lJ[EC~'~'~,~~ true vertical Open Perfs 9027' - 9027', 9026' - 9026', Isolated Below claP- 9029'- 9030', 9031'- 9030', 9029' - 9028'. i~{~.~ ~ co 200~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR TaG @ 9579'. .. Packers & SSSV (type & measured depth) 9-5/8"x7"BKRzPxKpR/p~H~F~7;3; ~;¢~!~'/'2,B,~;RamSc3o~~7,.t~~ 7" x 4-1/2" BKR 0 ' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 02/01/2002 Subsequent to operation 03/13/2002 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-in 17061 Casing Pressure Tubing Pressure 2955 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service MI Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~~,~/~~O,~,.~'~'~ Title: Technical Assistant DeWayne R. Schnorr Date March 14, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 16-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/14/2OO2 02/18/2OO2 02/19/2OO2 O2/2O/2OO2 O2/21/2OO2 SBHP/FBHP SURVEY: DRIFT/TAG; STATIC BO1-FOM HOLE PRESSURE SURVEY PERFORATING: CAST IRON BRIDGE PLUG; PERFORATING PERFORATING: CAST IRON BRIDGE PLUG; PERFORATING PERFORATING: PERFORATING PERFORATING: ACID TREATMENT EVENT SUMMARY 02/14/02 PULLED 4-1/2" A-1 INJECTION FROM 2173' WLM. RAN 3.62" DRIFT, 3-3/8" DUMMY GUN, TTL & 1-3/4" SAMPLE BAILER. TAG EOT @ 9549' WLM & STOPPED FALLING DUE TO DEVIATION @ 10271' WLM. RAN STATIC BHP 02/18/02 MIRU DS CTU #3, MU BAKER BHA, PDS MEMORY TOOLS, 3.625" CENTRALIZER. RIH. 02/19/02 MEMORY LOG FROM 12,000 TO 12,666' CTMD, FLAG AT 12,400'. (-26' CORRECTION) (AN ERROR WAS MADE ON THIS MEMORY LOG THAT PLACED THE CIBP & SUBSEQUENT GUN RUNS OFF DEPTH). POOH. SET BAKER 4-1/2" CIBP AT 12528' (DOWN WT) 12521' (UP WT). SHOOT 2-7/8", 6 SPF GUNS FROM 12408'-12428' (GUN #1). POOH. RIH W/GUN #2. SHOOT 2-7/8", 6 SPF GUNS FROM 12388'-12408'. POOH. 02/20/02 MU NEW BAKER CONNECTOR. MU GUN #3. RIH. SHOOT 2-7/8", 6 SPF GUNS FROM 12368'-12388' (GUN #3). POOH. MU PDS MEMORY TOOLS, RUN MEMORY GR/CCL AND RE-FLAG PIPE. TAG CIBP AT 12528' (DOWN). FLAG PIPE. POOH. RIH W/GUN #4. TIE IN AT FLAG. SHOOT 12320' - 12340'. POOH W/GUN #4. RIH W/GUN #5. TIE IN AT FLAG. SHOOT 12300' - 12320'. POOH W/G U N #5. 02/21/02 MU 3" JSN. RIH. INITIAL INJECTIVITY 1.4 BPM @ 2000 PSI WHP. ACID WASH PERFS W/100 BBLS 7.5% HCL, 50 BBLS 9:1 MUD ACID. GOOD WHP BREAKBACKS AS EACH ACID HIT PERFS. OVERDISPLACE ACID INTO FORMATION W/3% NH4CL. WHP COMING UP W/OVERDISPLACEMENT. POOH. CONDUCT INJECTIVITY TEST. 2.0 BPM @ 1800 PSI. LEFT WELL SHUT-IN, FP'D TO 2500' W/DIESEL FLUIDS PUMPED BBLS 1 PUMP 1 BBL DIESEL TO PRESSURE TEST LUBRICATOR. 226 60/40 METHANOL WATER 93 1% KCL WATER 4O DIESEL 100 7.5% HCL ACID 50 9:1 MUC ACID Page 1 16-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 218 13% NH4CLW/10% U-66 & 0.2% F103 I 728 ITOTAL I 02/19-20/2002 ADD PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" POWERJET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 12300'-12340' 12368'-12428' Page 2 Well Compliancert File on Left side of folder 198-036-0 .~MD 15175 -"~VD 09027 PRUDHOE BAY UNIT 16-14A 50- 029-20570-01 ARCO letion Date: '~/13/98 Completed Status: WAGIN Current: T Name . _ C 9213 C 9448 L CBL L IMP-CDR-MD L IMP-CDR-TVD Interval Sent Received T/C/D I r.~LUM IMP-CDR 1 ~LUM PDC FINAl5174 ,-~AL 8100-9050 L PDC ~N'A~13600-14260 10/29/99 R SRVY RPT S~ 13123.90-15176. R SRVY RPT . ~S/CT:ILUM 8996.20-15109.58 Daily Well Ops ~l,./f~ - Was the well cored? yes Comments: OH 5/21/99 6/10/99 CH 2/16/00 2/25/00 OH 5 4/23/98 4/30/98 OH 5/21/99 6/10/99 OH 5/21/99 6/10/99 CH 5 2/16/00 2/25/00 C OH 5/9/98 5/13/98 OH 7/22/98 7/23/98 Are D~ Ditch Samples Required? yes ..~, And Receive'- Analysis Description Receive-" Sample Monday, May 01,2000 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: May 1, 2001 FROM: John Crisp, SUBJECT' Petroleum Inspector Safety Valve Tests Prudhoe Bay Field :DS-16 May l, 2001: I traveled to BP's Prudhoe Bay Field to witness the semi-annual SVS tests on DS-16. I witnessed SVS tests on BP's DS-16. Testing went very well. No failures were witnessed. We had more than adequate manpower to test this Pad in a timely manner. Flow 2 Supervisor Roy Wells checked in w/the Pad Operators & Leads on D$-16 that were performing tests to make sure operations were being performed in a safe & efficient manner. Preventive maintenance had been performed on SVS for this Pad two weeks before State testin~ was conducted. ~ SUMMARY: ! witnessed SVS tests on BP's PBU DS-16. 2,0. w..e!ls., 40 comoonents tested. No. failures witnessed. 0% failure rate. Attachments.; svs PBU DS-16 5-01-01jc cc; NON-C. ONFIDENTIAL SVS PBU DS-16 5-01-01jc Alaska Oil and Gas Conservation Comm[~ Safety Valve System Test Report Operator: BPX Operator Rep: W. Williams AOGCC Rep: Jolm.' Cr.!sp_ Submitted By: John Crisp Date: Field/Unk/PM: Pmdhoe Bay Field DS-16 Separator psi: LPS 171 HPS 5/1/01 i i Well Permit Separ Set L/P Test Test Test Date oa, WAG, GINJ, Number Number . PSI PSI ,,Trip Code Code Code Passed G~Sor 16'0i 1801360 16-02 1801500~ 16-03 1810110! ........ ,'l~-04A 1921510: '171 ''150!"' 110: e e ' ' OIL! 16-05 181037'6' 171 'i'501 125 " P" P OIL 16'06 1810510 ...... , 16-07 1852040 16-08A 1991260 171 150 120 P 'P ~ OiL 16-09A 1910380 171 150 120 P P OIL 16-10A 1991230 l~-il 1801180, "' 16-12A 19901~0 .L '171 150 120 P P ' 'oIL 16-13 1810270 1~1 150 140 'P P ' oIL 16-14A 1980360! 3000] 1800 1800 'P '' P " GINJ .. ,, . r, 16-15 1852640 171 150 120 P P OIL , 16-16 1801270! 16-17 1852200 171 150 125 P P ' ' ' OIL 1'6-18 1852430 '" 171 150 100 P P ' '' Of L 16-19 1852650 171 150 ~20 P '" ~ ..... OIL 16-2o ~85285o ~7~ ~5o ~o P ~ " ' oi~ ... , 16-21 1853120 171 150 90 P P ' OIL · . . , , ., ~6-22 ~900810 ~?~ ~so 120 P P oI~ ~6_23 .... 1900,db ............... 16-24 1860240 ...... 16-25 "1920510 "171 150 90 P' P ..... oIL 16-26A' 1991270 171" i50 120 P P ' '' OIL 16-27A· 2000040 ~51 ~50 1~0" P P OI~ , 16-28 ~920620 ~71 lS0 ~s P P om ~6-29A ~920660 ....1~'' ~S0 ~20 P P " Om . , 16230 '1920760 '171 150 120 P P I OIL 16-31 1920750 ...... , , . ,, ., Wells: 20 Components: 40 Failures: 0 Failure Rate: 0.00% F190 By , . Remarks: RJF 1/16/01 Page 1 0£2 qxzq DlZlIT 1'~_1~ ~_nl_(ill,~'l WeIl Permit Separ Set L/P Test Test Test Date ou, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed CAS or CY,CLE RJF 1/16/01 Page 2 of 2 SVS PBU DS-16 5-01-01jcl STATE OF ALASKA ~.. .... ,~,'~E~SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_X (ClBP) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1532' FNL, 4753' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 1526' FSL, 1695' FWL, Sec. 13, T10N, R15E, UM At effective depth At total depth 1277' FNL, 34' FEL, Sec. 14, T10N, R15E, UM 5. Type of Well: Development__ Exploratory__ Stratigraphic__ Service__X (asp's 719307, 5929395) (asp's 720383, 5932487) (aps's 718582, 5934912) 6. Datum elevation (DF or KB feet) RKB 66 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-14Ai 9. Permit number / approval number 198-036 10. APl number 50-029-20570-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical 15175 feet Plugs (measured) 9026 feet ClBP set @ 13380' MD (9/28/2000). C/BP @ 14258' MD (10/30/1999). Effective depth: measured true vertical 13380 feet Junk (measured) 9031 feet Casing Length Conductor 110' Surface 2609' Production 8897' Liner 1671' Liner 4883' Size Cemented Measured Depth 20" 300 sx Permafrost 110' 13-3/8" 3000 Sx Fondu & 1250 Sx 2675' Permafrost 9-5/8" 5o0 sx C~ass G ~ ~ ~ - ~ :8963' 7" 288 Sx Class G 10444' 4-1/2" 477 sx class G ¢- '- 15175' ,r True vertical Depth 110' 2675' 8057' 9055' 9026' Perforation depth: measured 13130'- 13230'; (Isolated below ClBP's 14081'.; 14181' 14976', 15076'). true vertical 9030' - 9030'; (Isolated below ClBP's 9031' - 9030'; 9029'- 9028'), O~_/~.~.~/FAL Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR, Tbg @ 9579' MD. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 9535' MD; 4-1/2" Camco Bal-0 SSSV @ 2197' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see atfached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Dally Average Production or Iniection Data Gas-Mcr Water-Bbl 12383 - 17014 Casing Pressure . Tubing Pressure 2308 2992 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __ Gas __ Suspended Service MI Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedjennifer Watson ~ ~~0~ Title DS16 Surveillance Engineer Date Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE - · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 66 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorac.:je, AK 99510-0360 service__x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1532' FNL, 4753' FEL, Sec. 24, T1 ON, R1 SE, UM (asp's 719307, 5929395) 16-14Ai At top of productive interval 9. Permit number / approval number 1526' FSL, 1695' FWL, Sec. 13, T1 ON, R15E, UM (asp's 720383, 5932487) 198-036 At effective depth 10. APl number 50-029-20570-01 At total depth 11. Field / Pool 1277' FNL, 34' FEL, Sec. 14, T10N, R15E, UM (aps's 718582, 5934912) Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 15175 feet Plugs(measured) Tagged ClBP @ 14258' MD (~EOE true vertical 9026 feet Effective depth: measured 14258 feet Junk (measured) MAP~ true vertical 9029 feet -'A--J~$~a Casing Length Size Cemented Measured Depth True ve~J~ Conductor 110' 20" 300 Sx Permafrost 110' 110' Surface 2609' 13-3/8" 3o00 Sx Fondu & 1250 Sx 2675' 2675' Permafrost Production 8897' 9-5/8" 500 Sx Class G 8963' 8057' Liner 1671' 7" 288 Sx C~ass G 10444' 9055' Liner 4883' 4-1/2" 477 Sx Class G 15175' 9026' Perforation depth: measured 14081'- 14181'; (isolated below CIBP 14976' - 15076'). true vertical 9031' - 9030'; (Isolated below CIBP 9029' - 9028'). Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR, Tbg @ 9579' MD. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 9535' MD; 4-1/2" Camco Bal-O SSSV @ 2197' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure , 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 800 - - 2900 Subsequent to operation 16000 - 2500 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil__ Gas __ Suspended __ Service MI Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~,~-,.,~~/~,-~I../ Title Arco Engineering Supervisor Date Signed Erin Oba ' Prepared by Paul Rauf 263.4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE -- r. 16-14Ai DESCRIPTION OF WORK COMPLETED FB MUD ACID STIMULATION W/DIVERTER Date Event Summary 2/03/2000: 2/23/2000: 2/25/2000: RIH & drifted through SSSV to 10300' SLM (HAW). MITIA to 1500 psi - passed. Performed a Fullbore Mud Acid Stimulation Treatment to increase injectivity as follows: MIRU pumping equip. PT'd equip to 3000 psi. Pumped stimulation fluid sequence fullbore to treat the open perforation interval located @: 14081'- 14181' MD (Zone 3) Reference Log: MWD 3/16/1998. Pumped: (a) 5 bbls of 50/50 MEOH Water @ 3 bpm, followed by (b) 50 bbls of 50% Diesel, 50% Xylene @ 5 bpm, followed by (c) 100 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 5 bpm, followed by (d) 50 bbls of 9% HCL - 1% HF, & 3% Acetic Acid @ 2 bpm, followed by (e) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 5 bpm, followed by (f) 25 bbls of 9% HCL - 1% HF, & 3% Acetic Acid @ 5 bpm, followed by (g) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 5 bpm, followed by (h) 25 bbls of 9% HCL - 1% HF, & 3% Acetic Acid @ 5 bpm, followed by (i) 10 bbls of Saturated NH4CL w/0.5 Benzoic Acid Flake Diverter, followed by (j) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 3 bpm, followed by (k) 25 bbls of 9% HCL - 1% HF, &3% Acetic Acid @ 6 bpm, followed by (I) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid Overflush, followed by (m) 300 bbls NH4CL Water flush, followed by (n) Shutdown. No significant breaks during job. RDMOL. Returned well to MI injection & obtained representative injection data. Schlumberger NO. 121197 2/16/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 !'"lq, o, I ri q ' I"Z_ I Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 3-09 99470 CNTG 1:~ ~ff q ~- 991202 I I 1 D.S. 4-02A 99467 RST-SlGMA .~. '~(--/ct ,991221 1 I 1 D.S. 16-14A Lt.l(__ 99449 PERF DEPTH CONTROL MEM GR/CCL t~..z:')(~'91029 1 I 1 D.S. 18-15B 99446 RST-'~:-~ 3 .... -991104 I I 1 ,, ........ : ~a~~ ~_ ~_ _~ _~' R EC E iV E [ DATE: FEB 25 2000 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~[~oJ'r!01'a[ji~ 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 (set ClBP) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 66 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchora~le, AK 99510-0360 service__x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1532' FNL, 4753' FEL, Sec. 24, T10N, R15E, UM (asp's 719307, 5929395) 16-14Ai At top of productive interval 9. Permit number / approval number 1526' FSL, 1695' FWL, Sec. 13, T1 ON, R15E, UM (asp's 720383, 5932487) 198-036-0 At effective depth 10. APl number 50-029-20570-01 At total depth 11. Field / Pool 1277' FNL, 34' FEL, Sec. 14, T10N, R15E, UM (aps's 718582, 5934912) Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 15175 feet Plugs (measured) Tagged CIBP @ 14258' MD (10/30/1999). true vertical 9026 feet Effective depth: measured 14258 feet Junk (measured) true vertical 9029 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 300 Sx Permafrost 110' 110' Surface 2609' 13-3/8" 3000 sx Fondu & 1250 Sx 2675' 2675' Permafrost Production 8897' 9-5/8" 500 Sx C~ass G 8963' 8057' Liner 1671' 7" 288 Sx C~ass G 1 0444' 9055' Liner 4883' 4-1/2" 477 Sx C~ass G 15175' 9026' Perforation depth: measured 14081'- 14181'; (Isolated below CIBP 14976' - 15076'). RECEIVED true vertical9031'-9030'; (Isolated below CIBP 9029'-9028'). DEC 1 6 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR, Tbg @ 9579' MD. Anchorage Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 9535' MD; 4-1/2" Camco Bal-0 SSSV @ 2197' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation (shut in, awaiting facility modifications) 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service MI Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~,, ,-~,~ Title Arco Engineering Supervisor Date Erin Oba " - Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 16-14Ai DESCRIPTION OF WORK COMPLETED SET ClBP & PERFORATING OPERATIONS Date Event Summary 10/29/1999: 10/30/1999 - 10/31/99: 11/07/1999: MIRU CTU. PT'd equipment to 4000 psi. RIH & set CIBP @ 14250' MD to isolate the following perforation interval: 14976' - 15076' MD (Zone 2B) Ran Memory GR-CCL log f/ClBP to 13,800' MD. POOH. RIH w/2-7/8" Powerjet carriers &tagged top of ClBP @ 14258' MD. Shot 100' of Add Perforations @: 14081' - 14181' MD (Zone 3) Reference Log: MWD 3/16/1998. All shots were @ 6 SPF, random orientation, & 60° phasing. POOH w/guns. ASF. RD. Injectivity test: w/130 bbls of Crude pumped, 2500 psi @ 1 bpm. Well is waiting for facility modifications prior to the start of injection of MI. 5/21/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12590 Compan~ Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Job # Log Description Date BL Sepia CDR D.S. 16-14A '~8~04 CDRIMPULSE (PDC) 980330 '-~-~-i_.~,.~? 1 D.S. 16-14A 98~04 CDR COMPOSITE 980330 1 1 D.S. 16-14A 98404 CDR COMPOSITE TVD 980330 I I Please sign and return one copy of tills transmittal to Sherrie at the above address. Thank ' STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1532' FNL, 4753' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 1526' FSL, 1695' FWL, Sec. 13, T10N, R15E, UM At effective depth At total depth 1277' FNL, 34' FEL, Sec. 14, T10N, R15E, UM 5. Type of Well: Development__ Exploratow___ Stratigraph ic__ Service~X 6. Datum elevation (DF or KB feet) RKB 66 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-14Al 9. Permit number / approval number 98-36 10. APl number 50-029-20570-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical 15175 feet 9026 feet Effective depth: measured 15089 feet true vertical 9028 feet Plugs (measured) Casing Length Conductor 1 10' Surface 2609' Production 8897' Liner 1671' Liner 4883' Junk (measured) Tagged PBTD @ 15089' MD Size Cemented Measured Depth 20" 300 Sx Permafrost 110' 3000 Sx Fondu & 1250 Sx 2675' 13 - 3/8" Permafrost 9-5/8" 5oo sx Class G 8963' 7" 288 Sx Class G 1 0444' 4-1/2" 477 Sx Class G 151 75' True vertical Depth 110' 2675' 8057' 9055' 9026' Perforation depth: measured 14976' - 15076'. true vertical 9029' - 9028'. : .. ' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR, Tbg @ 9579' MD. '4(¢~¢~'--'-'..,~.~/,¥:,~,." Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 9535' MD; 4-1/2" Camco Bal-0 SSSV @ 2197' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl shut in - 32000 - Casing Pressure Tubing Pressure - . 2850 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' ~_~¢~ '~. ~ Title Arco Engineering Supervisor Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLIOATE~ 16-14Ai DESCRIPTION OF WORK COMPLETED FULLBORE MUD ACID STIMULATION WITH DIVERTER Date Event Summary 7/29/1998: Performed a Fullbore Mud Acid Stimulation Treatment as follows: MIRU & PT'd equipment to 4500 psi. Pumped stimulation fluid sequence fullbore to treat the open perforation interval located @: 14976'- 15076' MD (Zone 2B) Pumped: (a) 10 bbls of 50/50 MEOH Water for de-icing, followed by (b) 150 bbls of 2% NH4CL Water @ 5.5 - 2.4 bpm, followed by (c) 50 bbls of 50% Diesel, 50% Xylene @ 308 bpm, followed by (d) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 3.2 bpm, followed by (e) 10 bbls each of Saturated NH4CL w/0.5 ppg Benzioc Acid Flake Diverter, followed by (f) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 2.7 bpm, followed by (g) 10 bbls each of Saturated NH4CL w/0.5 ppg Benzioc Acid Flake Diverter, followed by (h) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 2.7 bpm, followed by (i) 50 bbls of 9% HCL - 1% HF, & 3% Acetic Acid @ 1.6 bpm, followed by (j) 50 bbls of 12% HCL w/10% Xylene & 3% Acetic Acid @ 1.3 - 2.5 bpm, followed by (k) 336 bbls of 2% NH4CL Water flush w/50 ppt Citric Acid @ 2.4 - 3.6 bpm, followed by (I) 220 bbls hot 1% KCL Water overflush @ 3.0 - 5.4 bpm, followed by (m) shutdown. RDMOL. Returned well to MI injection & obtained valid injection data. STATE OF ALASKA .~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [~] Gas [-~ Suspended [~Abandoned [] Service MIST Injector 2. Name of OPerator 7. Permit Number ARCO Alaska Inc. 98-36 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ...- ~ 50-029-20570-01 4. Location of well at surface '_. '"' ? ~-~ 9. Unit or Lease Name 1534' SNL, 527' EWL, SEC. 24, T10N, R15E, UM¢,/~/¢'~; .'!~ Prudhoe Bay Unit At top of productive interval ,._..;- !; ~ 10. Well Number 1526' NSL, 1695' EWL, SEC. 13, T10N, R15E, UM 2~. 16-14Ai ·.':~ 41.:"-,, -; ! 111. Field and Pool At total depth ~ - -- ~ 4001' NSL, 38' WEL, SEC. 14, T1 ON, R15E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 66.15'I ADL 028332 12. DateSpudded 113. DateT.D. Reached I 14. Datecomp.,SuSp.,°rAband.115. Water depth, ifoffshore 116. No. of Completions ' 3/18/98 I 4/6/98 I 4/13/98 I N/A MSLI One 17. Total Depth (MD+-rvu) 118. Plug Back DePth (MDb-TVa)II9. Directional Survey 120. Depth where sSSV set 121. Thickness of Permafrost 15175 9027 FTI 15089 9028 FTI [~Yes [~No I (Nipple) 2197' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, DIP, GR, RES/ALT, DT/BHC,. CNL, LDL, GR, Caliper, SP, MRES, 4-Phase RES, CBL 23. CASING7 LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE S~ZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2675' 17~1/2" 3000 sx Fondu, 1250 sx Permafrost 9-5/8" 47# L-80 / S00-95 Surface 8963' 12-1/4" 500 sx Class 'G' 7" 26# L-80 8773' 10444' 8-1/2" 288 sx Class 'G' 4-1/2" 12.6# L-80 10292' 15175' 6" 477 sx Class 'G' r'~ -~'J i (~ i ! 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr 9579' 9535' MD TVD MD TVD 14976' - 15076' 9029' - 9028' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel -"'-, v ELi ,,, 27. PRODUCTION TEST Date First production I Method of Operation (Flowing, gas lift, etc.) ..... ~1!15~,,~ July 19, 1998 I MIST Injector Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-McF WATER-DeL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE .......... , ,, '28. CORE DATA ......... Brief description of litholog~, porosity," fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top of Sadlerochit 9901' 8808' 26P 13487' 9030' 31. List of Attachments Summary of Daily Drilling Reports, Surveys , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ 8/ / Dan Stone ..................... Title ,Engineering Supervisor Date 16-14Ai 98-36 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and 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 only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 RECEIVED 24 1998 Alaska 0il & ~as Cons. Comrnis$1or, Anchorage Facility i PB DS 16 Progress Report Well 16-14A Rig Nabors 2ES Page 1 Date 06 May 98 Date/Time 11 Mar 98 12 Mar 98 13 Mar 98 14 Mar 98 15 Mar 98 21:00-00:00 00:00-00:30 00:30-05:00 05:00-06:00 06:00-08:00 08:00-09:30 09:30-12:00 12:00-12:30 12:30-14:00 14:00-15:00 15:00-19:00 19:00-21:00 21:00-00:00 00:00-00:30 00:30-04:00 04:00-06:00 06:00-08:30 08:30-10:00 10:00-10:30 10:30-14:00 14:00-17:00 17:00-19:00 19:00-21:00 21:00-22:30 22:30-00:00 00:00-00:30 00:30-01:30 01:30-04:00 04:00-06:00 06:00-09:00 09:00-10:30 10:30-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-20:30 20:30-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-02:30 02:30-03:00 03:00-04:00 04:00-04:30 04:30-04:45 04:45-06:00 06:00-09:30 09:30-10:00 10:00-10:15 10:15-11:30 11:30-12:00 12:00-12:30 12:30-15:00 Duration 3 hr 1/2 hr 4-1/2 hr lhr 2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1 hr 4hr 2 hr 3 hr 1/2 hr 3-1/2 hr 2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 3 hr 2 hr 2hr 1-1/2 hr 1-1/2 hr 1/2 hr 1 hr 2-1/2 hr 2 hr 3 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 7-1/2 hr 1-1/2 hr 1 hr 1 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 1/4 hr 1-1/4 hr 3-1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 1/2 hr 2-1/2 hr Activity Rig moved 50.00 % Held safety meeting Rig moved 100.00 % Fill pits with Seawater Fill pits with Seawater (cont...) Removed Accessories Reverse circulated at 9030.0 ft Held safety meeting Reverse circulated at 9030.0 ft Serviced Production swab valve - manual Circulated at 9030.0 ft Circulated at 9030.0 ft Rigged down Surface tree Held safety meeting Rigged down Surface tree Rigged up BOP stack Rigged up BOP stack (cont...) Tested BOP stack Held safety meeting Tested Well control Fished at 30.0 ft Circulated at 6500.0 ft Laid down fish Set Retrievable packer at 50.0 ft with 0.0 psi Removed Tubing head spool Held safety meeting Removed Tubing head spool Serviced Seal assembly Serviced Seal assembly Serviced Seal assembly (cont...) Rigged up BOP stack Tested BOP stack Set Retrievable packer at 50.0 ft with 0.0 psi Held safety meeting Set Retrievable packer at 50.0 ft with 0.0 psi Laid down 6550.0 ft of Tubing Serviced Block line Made up BHA no. 2 Rigged up Logging/braided cable equipment Held safety meeting Rigged up Logging/braided cable equipment Prepared & tn:ed cutting charge at 9375.0 ft Rigged down Logging/braided cable equipment Made up BHA no. 1 Singled in drill pipe to 600.0 ft Held drill (Kick while tripping) Singled in drill pipe to 1200.0 ft Singled in drill pipe to 6550.0 ft (cont...) Circulated at 6520.0 ft Fished at 6550.0 ft Circulated at 9375.0 ft Pulled out of hole to 4000.0 ft Held safety meeting Pulled out of hole to 2500.0 ft ORIGINAL RECEIVED 19 199 Alaska Oil & Gas Cons. Commis,. ~ori Anchorage Progress Report Facility PB DS 16 Well 16-14A Rig Nabors 2ES Page 2 Date 06 May 98 Date/Time 15:00-16:00 16:00-18:00 18:00-18:15 18:15-19:30 19:30-21:30 21:30-00:00 16 Mar 98 00:00-00:30 00:30-02:30 02:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-09:30 09:30-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-00:00 17 Mar 98 00:00-00:30 00:30-02:30 02:30-06:00 06:00-08:30 08:30-10:30 10:30-11:30 11:30-21:00 21:00-22:00 22:00-02:30 18 Mar 98 02:30-04:30 04:30-06:00 06:00-07:00 07:00-12:00 12:00-13:30 13:30-00:00 19 Mar 98 00:00-06:00 06:00-12:00 12:00-22:00 22:00-22:30 22:30-23:30 23:30-00:30 20 Mar 98 00:30-01:30 01:30-06:00 06:00-10:30 10:30-12:00 12:00-16:00 16:00-17:00 17:00-22:00 22:00-01:30 21 Mar 98 01:30-06:00 Duration 1 hr 2 hr 1/4 hr 1-1/4 hr 2 hr 2-1/2 hr 1/2 hr 2 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr lhr 3-1/2 hr 1/2 hr 2 hr 3-1/2 hr 2-1/2 hr 2 hr lhr 9-1/2 hr 1 hr 4-1/2 hr 2 hr 1-1/2 hr 1 hr 5 hr 1-1/2 hr 10-1/2 hr 6 hr 6 hr 10hr 1/2 hr 1 hr 1 hr 1 hr 4-1/2 hr 4-1/2 hr 1-1/2 hr 4 hr 1 hr 5 hr 3-1/2 hr 4-1/2 hr Activity Pulled BHA Laid down 1800.0 ft of Tubing Held drill (Kick while tripping) Laid down 700.0 ft of Tubing Circulated at 9834.0 ft Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Conducted electric cable operations Tested Casing - Via string Tested Casing - Via string (cont...) Made up BHA no. 2 R.I.H. to 6180.0 ft Singled in drill pipe to 8500.0 ft Held safety meeting Singled in drill pipe to 8997.0 ft Circulated at 8998.0 ft Circulated at 8998.0 ft Held safety meeting Mixed and pumped slurry - 52.000 bbl Circulated at 8998.0 ft Laid down 920.0 ft of 5in OD drill pipe Serviced Block line Pulled out of hole to 0.0 ft Held safety meeting Made up BHA no. 2 R.I.H. to 6550.0 ft R.I.H. to 8964.0 ft (cont...) Circulated at 8963.0 ft Set tool face ~ Milled Other sub-surface equipment at 8963.0 ft Circulated at 9002.0 ft Pulled out of hole to 9002.0 ft Pulled BHA Made up BHA no. 3 Made up BHA no. 3 R.I.H. to 8950.0 ft R.I.H. to 9002.0 ft Drilled to 9400.0 ft Drilled to 9380.0 ft Drilled to 9568.0 ft Drilled to 9917.0 ft Circulated at 9917.0 ft Pulled Drillpipe in stands to 8979.0 ft Serviced Block line Ran Drillpipe in stands to 9875.0 ft Drilled to 10115.0 ft Drilled to 10203.0 ft Circulated at 10203.0 ft Pulled out of hole to 10203.0 ft Pulled BHA Tested BOP stack Made up BHA no. 4 R.I.H. to 10050.0 ft Progress Report Facility PB DS 16 Well 16-14A Rig Nabors 2ES Page 3 Date 06 May 98 Date/Time 06:00-07:00 07:00-09:00 09:00-16:30 16:30-17:30 17:30-19:00 19:00-21:00 21:00-02:30 22 Mar 98 02:30-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-10:00 10:00-10:30 10:30-11:00 11:00-16:30 16:30-18:00 18:00-20:30 20:30-21:30 21:30-22:00 22:00-23:00 23:00-00:00 23 Mar 98 00:00-00:30 00:30-01:30 01:30-05:00 05:00-06:00 06:00-07:00 07:00-19:00 19:00-22:00 22:00-23:00 23:00-02:30 24 Mar 98 02:30-04:30 04:30-06:00 06:00-07:30 07:30-12:00 12:00-00:00 25 Mar 98 00:00-06:00 06:00-12:00 12:00-20:30 20:30-22:30 22:30-04:00 26 Mar 98 04:00-04:30 04:30-06:00 06:00-08:00 08:00-13:30 13:30-15:30 15:30-20:30 20:30-22:30 22:30-03:30 27 Mar 98 03:30-05:00 05:00-05:30 05:30-06:00 06:00-10:00 10:00-11:30 11:30-13:00 Duration 1 hr 2 hr 7-1/2 hr lhr 1-1/2 hr 2hr 5-1/2 hr 1 hr 2-1/2 hr 1/2 hr 1 hr 2-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 2-1/2 hr 1 hr 1/2 hr 1 hr lhr 1/2 hr 1 hr 3-1/2 hr 1 hr lhr 12hr 3 hr 1 hr 3-1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 4-1/2 hr 12 hr 6hr 6 hr 8-1/2 hr 2 hr 5-1/2 hr 1/2 hr 1-1/2 hr 2 hr 5-1/2 hr 2 hr 5 hr 2 hr 5 hr 1-1/2 hr 1/2 hr 1/2 hr 4 hr 1-1/2 hr 1-1/2 hr Activity R.I.H. to 10040.0 fi Drilled to 10203.0 fi Drilled to 10444.0 ft Circulated at 10444.0 ft Opened hole to 9400.0 ft (8-1/2in) Circulated at 10444.0 fi Laid down 476.0 ft of 5in OD drill pipe Laid down 945.0 ft of 5in OD drill pipe Pulled BHA Pulled BHA Rigged up Casing handling equipment Ran Liner to 1643.0 fi (7in OD) Installed Liner hanger Circulated at 1640.0 ft Ran Drillpipe in stands to 10444.0 ft Ran Drillpipe in stands to 10444.0 ft Circulated at 10444.0 ft Mixed and pumped slurry - 59.000 bbl Displaced slurry - 201.000 bbl Circulated at 8773.0 fi Rigged down Circulating head Laid down 300.0 fi of Drillpipe Serviced Block line Laid down 6355.0 fi of Drillpipe Pulled Drillpipe in stands to 2232.0 ft Pulled Drillpipe in stands to 0.0 fi Made up BHA no. 5 R.I.H. to 10256.0 ft Tested Casing Drilled cement to 10436.0 ft Drilled to 10462.0 fi Drilled to 10527.0 ft Drilled to 10527.0 ft Drilled to 10813.0 ft Drilled to 11290.0 fi Drilled to 11542.0 ft Drilled to 11762.0 fi Drilled to 12006.0 ft Circulated at 12006.0 ft Pulled out of hole to 12006.0 ft Serviced Block line Pulled out of hole to 3500.0 ft Pulled BHA Tested BOP stack Made up BHA no. 6 R.I.H. to 10521.0 ft Took MWD survey at 10905.0 ft Pulled out of hole to 325.0 ft Pulled BHA Tested BOP stack Tested BOP stack Tested BOP stack Held safety meeting Made up BHA no. 7 Progress Report Facility PB DS 16 Well 16-14A Rig Nabors 2ES Page 4 Date 06 May 98 Date/Time 13:00-19:00 19:00-20:00 20:00-21:00 21:00-02:30 28 Mar 98 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-09:30 09:30-12:30 12:30-13:00 13:00-14:30 14:30-00:00 29 Mar 98 00:00-06:00 06:00-12:00 12:00-00:00 30 Mar 98 00:00-06:00 06:00-12:00 12:00-15:00 15:00-17:30 17:30-18:00 18:00-20:00 20:00-22:30 22:30-04:30 31 Mar 98 04:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-15:00 15:00-18:00 18:00-19:00 19:00-20:00 20:00-00:00 01 Apr 98 00:00-06:00 06:00-12:00 12:00-12:30 12:30-15:00 15:00-15:15 15:15-00:00 02 Apr 98 00:00-00:30 00:30-06:00 06:00-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-15:30 15:30-19:00 19:00-21:00 21:00-22:30 22:30-00:00 03 Apr 98 00:00-00:30 00:30-01:00 01:00-01:30 01:30-03:30 Duration 6hr 1 hr 1 hr 5-1/2 hr 1 hr 1/2 hr 1 hr 1 hr 3-1/2 hr 3 hr 1/2 hr 1-1/2 hr 9-1/2 hr 6hr 6 hr 12hr 6 hr 6hr 3 hr 2-1/2 hr 1/2 hr 2 hr 2-1/2 hr 6 hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2hr 5-1/2 hr 3 hr 1 hr 1 hr 4 hr 6 hr 6 hr 1/2 hr 2-1/2 hr 1/4 hr 8-3/4 hr 1/2 hr 5-1/2 hr 3 hr 2 hr 1 hr 1/2 hr 3 hr 3-1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr Activity R.I.H. to 10400.0 ft Serviced Block line Took MWD survey at 10400.0 ft Pulled out of hole to 202.0 ft Pulled BHA Functioned downhole tools at 0.0 ft Made up BHA no. 8 R.I.H. to 1100.0 ft R.I.H. to 10622.0 ft Took MWD survey at 11005.0 ft R.I.H. to 11975.0 ft Circulated at 12006.0 ft Drilled to 12235.0 ft Drilled to 12426.0 ft Drilled to 12521.0 ft Drilled to 12807.0 ft Drilled to 12970.0 ft Drilled to 13154.0 ft Drilled to 13192.0 ft Circulated at 13192.0 ft Took MWD survey at 13192.0 ft Pulled out of hole to 10910.0 ft Took MWD survey at 10910.0 ft Pulled out of hole to 225.0 ft Pulled BHA Pulled BHA Made up BHA no. 9 Serviced Block line R.I.H. to 10564.0 ft Took MWD survey at 10564.0 ft R.I.H. to 13133.0 ft Reamed to 13192.0 ft Drilled to 13303.0 ft Drilled to 13600.0 ft Drilled to 13727.0 ft Held safety meeting Drilled to 13780.0 ft Held drill (Kick while drilling) Drilled to 13941.0 ft Held safety meeting Drilled to 14030.0 ft Drilled to 14031.0 ft (cont...) Circulated at 14031.0 ft Pulled out of hole to 13000.0 ft Held safety meeting Pulled out of hole to 6000.0 ft Pulled out of hole to 200.0 ft Pulled BHA Installed BOP test plug assembly Tested BOP stack Held safety meeting Tested Kelly Retrieved BOP test plug assembly Made up BHA no. 10 RECEIVED AUG 1,9 Alaska Oil & Gas Cons. Commiss Anchorage Oil Progress Report Facility PB DS 16 Well 16-14A Rig Nabors 2ES Page 5 Date 06 May 98 Date/Time 04 Apr 98 05 Apr 98 06 Apr 98 07 Apr 98 03:30-06:00 06:00-07:30 07:30-08:30 08:30-10:00 10:00-10:15 10:15-11:00 11:00-15:00 15:00-15:15 15:15-17:00 17:00-17:30 17:30-06:00 06:00-12:00 12:00-12:30 12:30-16:30 16:30-18:30 18:30-21:30 21:30-22:30 22:30-00:00 00:00-00:30 00:30-03:00 03:00-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-12:30 12:30-16:30 16:30-17:00 17:00-18:00 18:00-18:15 18:15-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-15:30 15:30-16:00 16:00-19:00 19:00-19:30 19:30-21:30 21:30-00:00 00:00-00:30 00:30-01:30 01:30-03:30 03:30-05:30 05:30-06:00 06:00-07:00 07:00-12:00 12:00-12:30 12:30-14:30 14:30-16:00 16:00-23:30 23:30-00:00 Duration 2-1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 1/4 hr 3/4 hr 4 hr 1/4 hr 1-3/4 hr 1/2 hr 12-1/2 hr 6 hr 1/2 hr 4 hr 2 hr 3 hr lhr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 2 hr 3-1/2 hr 1/2 hr 4 hr 1/2 hr 1 hr 1/4 hr 5-3/4 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 3hr 1/2 hr 3 hr 1/2 hr 2 hr 2-1/2 hr 1/2 hr 1 hr 2 hr 2 hr 1/2 hr 1 hr 5 hr 1/2 hr 2 hr 1-1/2 hr 7-1/2 hr 1/2 hr Activity R.I.H. to 4500.0 ft R.I.H. to 10400.0 ft (cont...) Serviced Block line R.I.H. to 13000.0 ft Held safety meeting R.I.H. to 14000.0 ft Drilled to 14100.0 ft Held drill (Kick while drilling) Drilled to 14140.0 ft Held safety meeting Drilled to 14327.0 ft Drilled to 14417.0 ft (cont...) Held safety meeting Drilled to 14452.0 ft Circulated at 14452.0 ft Pulled out of hole to 10360.0 ft Serviced Block line Pulled out of hole to 9500.0 ft Held safety meeting Pulled out of hole to 9000.0 ft Laid down 470.0 ft of 4in OD drill pipe Pulled out of hole to 200.0 ft Pulled BHA Pulled BHA (cont...) Made up BHA no. 11 R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 14442.0 ft Washed to 14452.0 ft Drilled to 14500.0 ft Held drill (Kick while drilling) Drilled to 14727.0 ft Held safety meeting Drilled to 14918.0 ft Drilled to 15078.0 ft (cont...) Held safety meeting Drilled to 15175.0 ft Tested High pressure lines Pulled out of hole to 10400.0 ft Serviced Block line Pulled out of hole to 6000.0 ft Laid down 1100.0 ft of 4in OD drill pipe Held safety meeting Laid down 1000.0 ft of 4in OD drill pipe Pulled out of hole to 200.0 ft Pulled BHA Rigged up Casing handling equipment Rigged up Casing handling equipment Ran Liner to 3100.0 ft (4-1/2in OD) Held safety meeting Ran Liner to 4800.0 ft (4-1/2in OD) Rigged up Tubing handling equipment Ran Tubing to 4700.0 ft (2-7/8in OD) Installed Liner hanger Facility Date/Time 08 Apr 98 09 Apr 98 10 Apr 98 11 Apr 98 12 Apr 98 PB DS 16 Progress Report Well 16-14A Rig Nabors 2ES Page Date Duration Activity 00:00-00:30 00:30-01:00 01:00-02:00 02:00-02:15 02:15-05:30 05:30-06:00 06:00-07:00 07:00-09:30 09:30-12:00 12:00-12:30 12:30-14:00 14:00-15:30 15:30-16:30 16:30-20:30 20:30-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-06:00 06:00-07:00 07:00-07:15 07:15-08:00 08:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-14:30 14:30-21:00 21:00-00:00 00:00-00:30 00:30-02:30 02:30-03:15 03:15-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-14:00 14:00-21:30 21:30-01:30 01:30-02:30 02:30-06:00 06:00-08:30 08:30-10:30 10:30-12:00 12:00-12:30 12:30-13:30 13:30-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-11:30 11:30-12:00 12:00-12:30 12:30-14:30 1/2 hr 1/2 hr 1 hr 1/4 hr 3-1/4 hr 1/2 hr 1 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 4 hr 3-1/2 hr 1/2 hr 1/2 hr 1 hr 4hr 1 hr 1/4 hr 3/4 hr 4 hr 1/2 hr 1/2 hr 1/2 hr lhr 6-1/2 hr 3 hr 1/2 hr 2 hr 3/4 hr 2-3/4 hr 5 hr 1 hr 1/2 hr 1-1/2 hr 7-1/2 hr 4 hr lhr 3-1/2 hr 2-1/2 hr 2 hr 1-1/2 hr 1/2 hr 1 hr 10-1/2 hr 1/2 hr 4 hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 2hr Held safety meeting Circulated at 4800.0 ft Ran Liner on landing string to 6000.0 ft Held drill (Kick while tripping) Ran Liner on landing string to 10300.0 ft Circulated at 10300.0 ft Circulated at 10300.0 ft (cont...) Ran Liner on landing string to 10175.0 ft Circulated at 15175.0 ft Held safety meeting Circulated at 15175.0 ft Mixed and pumped slurry - 101.000 bbl Displaced slurry - 170.750 bbl Circulated at 15075.0 ft Pumped out of hole to 11000.0 ft Held safety meeting Serviced Block line Laid down 850.0 ft of 5in OD drill pipe Pulled Drillpipe in stands to 3000.0 ft Pulled Drillpipe in stands to 0.0 ft (cont...) Held safety meeting Rigged up Logging/braided cable equipment Conducted electric cable operations Held safety meeting Rigged down Logging/braided cable equipment Tested Liner - Via string Serviced Top ram Tested BOP stack Installed TCP Held safety meeting Ran Tubing to 5000.0 ft (2-7/8in OD) Installed Perforating tools Ran Drillpipe to 9000.0 ft (4in OD) Ran Drillpipe to 15086.0 ft (5in OD) Rigged up High pressure lines Worked toolstring at 15076.0 ft Reverse circulated at 15086.0 ft Laid down 6000.0 ft of 5in OD drill pipe Laid down 4200.0 ft of 4in OD drill pipe Retrieved Perforating tools Laid down Tubing of 2430.0 ft Laid down 1600.0 ft of Tubing (cont...) Retrieved TCP Serviced Top ram Held safety meeting Rigged up Tubing handling equipment Ran Tubing to 4700.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 7390.0 ft (4-1/2in OD) Installed SCSSSV Ran Tubing to 9589.0 ft (4-1/2in OD) Installed Tubing hanger Held safety meeting Installed Tubing hanger 6 06 May 98 Progress Report Facility PB DS 16 Well 16-14A Rig Nabors 2ES Page 7 Date 06 May 98 Date/Time 13 Apr 98 14:30-18:30 18:30-20:30 20:30-00:00 00:00-00:30 00:30-02:45 02:45-04:30 04:30-05:15 05:15-06:00 06:00-07:00 07:00-08:00 Duration 4 hr 2 hr 3-1/2 hr 1/2 hr 2-1/4 hr 1-3/4 hr 3/4 hr 3/4 hr 1 hr 1 hr Activity Reverse circulated at 9589.0 ft Installed Production packer Rigged down BOP stack Held safety meeting Installed Wellhead integral components Tested Wellhead integral components Tested Casing - Via annulus Freeze protect well - Diesel of 150.000 bbl Freeze protect well ~ 150.000 bbl of Diesel (cont...) Installed Multipurpose tool Client ARCO Alaska, Inc. Field: Prudhce Bay Well Name: DS 16-14A APl numbe~ Job number: 4(XX)2323 Rig: Nabors 2ES Borough: North Slope State: AK Survey Calculations Calc method for posifi¢ Minimum Curvature Calc method for DLS: Mason & Taylor Depth references Permanent datum MSL 0 ft Depth reference KB 66.15 ft GL above Permanent ft KB above Permanent 66.15 ff DF above Permanent 64.75 ft Vertical section off'lin Latitude (+N/S-): 2538.88 FT Departure (+E/W-): 1020.29 FT Azim from rotary table to target. 331.4 degrees Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD # Depth angle : angle length depth (it) (dec~l) (de~l) (it) (ft) I 8996.20 33.10 16.8 0.0 8084.34 2 9069.10 39.61 18.3 72.9 8143.02 3 9132.19 39.29 19.7 63.1 8191.75 4 9163.98 37.86 19.1 31.8 8216.61 5 9258.13 35.83 18.4 94.1 8291.91 6 9353.85 34.59 15.6 95.7 8370.10 7 9385.66 34.14 14.7 31.9 8396.43 8 9447.18 35.61 13.0 61.5 8446.89 9 9541.32 35.84 12.6 94.1 8523.28 10 9573.49 36.73 13.3 32.2 8549.24 11 9605.25 36.74 13.7 31.7 8574.64 12 9636.88 37.30 14.5 31.7 8599.95 13 9668.84 36.52 14.9 31.9 8625.46 14 9732.91 36.77 16.2 64.1 8676.89 15 9790.84 37.63 15.5 57.9 8723.01 16 9858.36 40.41 13.6 67.6 8775.53 17 9891.32 40.08 14.7 32.9 8800.64 18 9923.56 40.98 13.5 32.3 8825.19 19 9955.60 43.35 13.3 32.0 8848.91 Spud Date: 16-Mar-98 Last survey date: 6-Apr-98 Total accepted surveys:155 MD of first survey: 8996.2 ft MD of last survey: 15109.00 ft RECEIVED APR 16 1998 BPXA PDC Geoma~lnetic data Magnetio Model: BGGM 1998 Version Magnetic Date: 03/10/98 Magnetic field strength: 1147.68 HCNT Magnetic dec (+E/W-): 28.44 degrees Magnetic Dip: 80.72 degrees MWD Survey Reference Criteria Reference G: 1002.76 milliG Reference H: 1147.70 HCNT Reference Dip: 80.72 degrees Tolerance G: 3 milliG Tolerance H: 7 HCNT Tolerance Dip: 0.3 degrees Correction Magnetic dec (+E/W-): 28.44 Gdd convergence (+E/W 0 Total az corr (+E/W-): 28.44 degrees degrees degrees Vertical Displacement section +N/S- +E/VV- (ft) (ft) (ft) Total at Azrn DLS displacement (deg/ (fi) (de~) lOOf) 1740.70 2538.90 1020.30 2736.24 1770.59 2580.06 1033.36 2779.31 1797.62 2617.97 1046.42 2819.36 1810.89 2636.67 1053.00 2839.17 1849.11 2690.10 1071.15 2895.51 21.89 0.00 21.83 9.01 21.79. 1.50 21.77 4.65 21.71 220 1887.69 2742.85 1087.30 2950.50 1900.70 2760.23 1092.00 2968.39 1926.65 2794.37 1100.41 3003.23 1967.86 2847.95 1112.58 3057.56 1982.12 2866.52 1116.85 3076.41 1996.19 2884.96 1121.28 3095.20 2010.22 2903.47 1125.93 3114.13 2024.16 2922.00 1130.79 3133.17 2051.61 2958.85 1141.05 3171.25 2076.60 2992.53 1150.61 3206.11 2107.66 3033.72 1161.28 3248.39 2123.27 3054.33 1166.47 3269.49 2138.69 3074.69 1171.58 3290.33 2154.66 3095.58 1176.56 3311.63 21.62 2.13 21.58 2.13 21.49 2.87 21.34 0.35 21.29 3.05 21.24 0.76 21.20 2.33 21.16 2.56 21.09 1.2.7 21.03 1.66 20.95 4.48 20.90 2.38 20.86 3.69 20.81 7.42 Page 1 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DL,~ # Depth angle angle length depth section +N/S- +E/VV- displacement (deg/ 20 9986.60 45.88 14.7 31.0 8870.97 2170.68 3116.70 1181.83 3333.25 20.77 8.76 21 10018.55 48.42 12.1 31.9 8892.67 2188.06 3139.45 1187.24 3356.44 20.72 9.95 22 10050.53 50.94 11.9 32.0 8913.37 2206.58 3163.31 1192.31 3380.56 20.65 7.89 23 10082.41 53.18 10.6 31.9 8932.98 2225.90 3187.99 .1197.22 3405.38 20.58' 7.72 24 10113.21 55.27 11.4 30.8 8950.99 2245.15 3212.51 1201.98 3430.02 20.51 7.11 25 10144.55 57.33 11.4 31.3 8968.35 2265.10 3238.04 1207.13 3455.73 20.45 6.58 26 10172.79 60.13 11.7 28.3 8983.04 2283.58 3261.74 1211.98 3479.63 20.38 9.94 27 10204.19 63.97 11.6 31.4 8997.76 2304.75 3288.90 1217.58 3507.04 20.31 12.23 28 10236.65 67.39 11.5 32.5 9011.14 2327.38 3317.91 1223.50 3536.31 20.24 10.53 29 10268.76 70.26 11.4 32.1 9022.73 2350.29 3347.24 1229.44 3565.89 20.17 8.95 30 10300.81 72.73 12.4 32.0 9032.89 2373.37 3376.93 1235.70 3595.92 20.10 8.27 31 10332.79 76.43 12.8 32.0 9041.40 2396.57 3407.03 1242.43 3626.50 20.04 11.63 32 10365.14 80.51 12.8 32.3 9047.85 2420.31 3437.89 1249.44 3657.89 19.97 12.63 33 10386.92 83.45 12.2 21.8 9050.89 2436.57 3458.96 1254.11 3679.29 19.93 13.76 34 10436.52 89.25 12.4 49.6 9054.05 2473.97 3507.30 1264.65 3728.34 19.83 11.70 35 10468.46 89.83 12.5 32.0 9054.30 2498.10 3538.55 1271.55 3760.08 19.77 1.84 36 10500.54 90.27 12.6 32.0 9054.28 2522.20 3569.78 1278.51 3791.83 19.70 1.41 37 10532.69 90.79 12.4 32.2 9053.98 2546.46 3601.22 1285.48 3823.77 19.64 1.73 38 10564.40 91.27 13.2 31.7 9053.41 2570.24 3632.13 1292.50 3855.24 19.59 2.94 39 10596.28 91.71 11.8 31.9 9052.58 2594.26 3663.26 1299.40 3886.89 19.53 4.60 40 10628.32 90.69 13.5 32.0 9051.91 2618.32 3694.47 1306.41 3918.65 19.47 6.19 41 10660.65 91.13 13.9 32.4 9051.39 2642.30 3725.95 1314.05 3950.88 19.43 1.64 42 10692.57 90.93 11.6 31.9 9050.82 2666.26 3757.07 1321.06 3982.56 19.37 6.92 43 10723.71 91.10 12.1 31.1 9050.27 2689.92 3787.50 1327.45 4013.39 19.31 1.70 44 10755.44 91.41 12.4 31.7 9049.58 2713.89 3818.47 1334.17 4044.84 19.26 1.36 45 10787.50 91.47 13.2 32.1 9048.77 2737.96 3849.76 1341.28 4076.73 19.21 2.50 46 10852.32 91.68 13.9 64.8 9046.99 2785.99 3912.73 1356.46 4141.19 19.12 1.13 47 10915.25 91.88 14.0 62.9 9045.03 2832.30 3973.75 1371.61 4203.81 19.04 0.36 48 10979.39 92.61 13.7 64.2 9042.52 2879.64 4036.03 1386.97 4267.70 18.97 1.23 49 11039.50 92.60 13.8 60.1 9039.79 2924.01 4094.35 1401.24 4327.49 18.89 0.17 50 11107.43 91.44 14.5 67.9 9037.39 2973.83 4160.15 1417.83 4395.12 18.82 1.99 51 11170.01 92.09 14.1 62.6 9035.47 3019.67 4220.78 1433.28 4457.50 18.76 1.22 52 11233.45 91.85 13.9 63.5 9033.28 3066.38 4282.36 1448.64 4520.74 18.69 0.49 53 11295.61 90.31 15.1 62.1 9032.11 3111.72 4342.47 1464.18 4582.67 18.63 3.14 54 11359.40 89.62 15.1 63.8 9032.15 3157.84 4404.06 1480.80 4646.35 18.58 1.08 55 11423.27 89.86 15.1 63.9 9032.44 3204.04 4465.76 .1497.45 4710.13 18.54 0.38 56 11518.38 91.65 14.6 95.1 9031.19 3273.07 4557.67 1521.82 4805.02 18.46 1.95 57 11581.13 91.78 14.4 62.7 9029.31 3318.83 4618.34 1537.51 4867.55 18.41 0.38 58 11641.93 90.69 14.1 60.8 9028.00 3363.39 4677.26 1552.47 4928.17 18.36 1.86 59 11698.80 89.52 13.2 56.9 9027.90 3405.51 4732.55 1565.90 4984.88 18.31 2.59 60 11766.00 89.59 13.1 67.2 9028.42 3455.65 4797.98 1581.19 5051.81 18.24 0.18 61 11826.84 89.79 12.7 60.8 9028.75 3501.18 4857.25 1594.76 5112.35 18.18 0.74 62 11891.18 89.66 11.4 64.4 9029.06 3550.04 4920.23 1608.20 5176.39 18.10 2.03 63 11948.63 90.03 10.0 57.4 9029.21 3594.46 4976.63 1618.86 5233.31 18.02 2.52 Page 2 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimu~ Course TVD Vertical Displacement Total at.~.m DLS I # Depth angle angle length depth section +N/S- +E/VV- displacement (deg/ I 64 11985.60 89.52 7.8 37.0 9029.36 3623.81 5013.18 1624.58 5269.84 17.96 6.10 65 12016.86 89.73 7.6 31.3 9029.56 3649.03 5044.20 1628.78 5300.65 17.90 0.93 66 12047.80 89.59 8.0 30.9 9029.75 3673.90 5074.81 1632.97 5331.07 17.84 1.37 67 12079.84 89.55 7.2 32.0 9029.99 3699.73 5106.53 1637.20 5362.56 17.78 2.50 68 12111.06 89.93 6.0 31.3 9030.13 3725.30 5137.62 1640.80 5393.27 17.71 4.02 69 12142.23 89.97 5.7 31.1 9030.16 3750.95 5168.56 1643.97 5423.71 17.64 0.97 70 12174.44 90.07 3.3 32.2 9030.15 3777.92 5200.66 1646.50 5455.07 17.57 7.46 71 12205.48 91.30 360.0 31.1 9029.77 3804.78 5231.74 1647.39 5484.98 17.48 11.32 72 12235.52 91.71 356.9 30.0 9028.99 3831.49 5261.71 1646.58 5513.33 17.38 10.42 73 12268.86 91.95 353.5 33.4 9027.92 3862.02 5294.97 1643.79 5544.26 17.25 10.20 74 12300.56 91.40 350.5 31.7 9026.99 3891.68 5326.35 1639.38 5572.93 17.11 9.62 75 12332.32 90.82 348.3 31.7 9026.38 3921.82 5357.50 1633.55 5601.01 16.96 7.18 76 12364.86 90.58 345.0 32.6 9025.98 3953.27 5389.21 1626.02 5629.17 16.79 10.15 77 12397.35 90.51 340.6 32.4 9025.67 3985.02 5420.15 1616.45 5656.05 16.61 13.58 78 12459.44 91.20 336.9 62.1 9024.74 4046.59 5478.01 1593.94 5705.20 16.22 6.06 79 12491.93 91.61 334.9 32.5 9023.95 4078.98 5507.67 1580.68 5730.01 16.01 6;?.8 80 12523.19 90.34 333.3 31.3 9023.41 4110.24 5535.82 1567.01 5753.33 15.81 6.53 81 12554.46 88.29 330.5 31.3 9023.79 4141.53 5563.42 1552.27 5775.92 15.59 11.09 82 12585.88 86.54 327.4 31.4 9025.21 4172.86 5590.28 1536.07 5797.48 15.36 11.61 83 12616.93 87.09 323.5 31.0 9026.93 4203.64 5615.75 1518.50 5817.43 15.13 12.37 84 12641.84 87.46 321.0 24.9 9028.11 4228.19 5635.42 1503.27 5832.47 14.94 10.14 85 12681.73 88.83 318.7 39.9 9029.40 4267.26 5665.90 1477.56 5855.39 14.62 6.71 86 12713.26 89.52 319.0 31.6 9029.86 4298.10 5689.69 1456.77 5873.22 14.36 2.38 87 12745.06 89.86 317.3 31.8 9030.03 4329.05 5713.37 1435.55 5890.96 14.10 5.45 88 12776.64 90.07 :316.9 31.5 9030.05 4359.58 5736.45 1414.11 5908.18 13.85 1.43 89 12807.61 89.97 316.8 31.0 9030.04 4389.58 5759.07 1392.91 5925.12 13.60 0.46 90 12839.26 90.03 315.8 31.7 9030.04 4420.19 5781.98 1371.01 5942.31 13.34 3.16 91 12871.68 89.69 316.4 32.4 9030.12 4451.44 5805.33 1348.54 5959.90 13.08 2.13 92 12904.02 90.14 315.9 32.3 9030.17 4482.60 5828.62 1326.17 5977.59 12.82 2.08 93 12935.73 90.17 315.9 31.7 9030.08 -4513.15 5851.39 1304.11 5994.95 12.56 0.09 94 12997.65 90.34 315.0 62.0 9029.80 4572.76 5895.57 1260.61 6028.84 12.07 1.48 95 13059.09 90.24 316.9 61.4 9029.49 4631.93 5939.66 1217.89 6063.23 11.59 2.94 96 13123.90_ 90.17 316.9 64.8 9029.26 4694.65 5986.94 1173.57 6100.87 11.09 0.19 97 1~173.33 89.54 312.3 49.4 9029.39 4741.92 6021.61 1138.40 6128.28 10.71 9.40 98 13204.90 89.82 310.9 31.6 9029.56 4771.66 6042.59 1114.77 6144.56 10.45 4.52 99 13236.54 89.78' 306.7 31.6 9029.67 4800.82 6062.39 1090.15 6159.62 10.19 13.29 100 13268.03 90.12 302.9 31.5 9029.70 4828.98 6080.36 1064.29 6172.80 9.93 12.11 101 13299.83 89.60 299.5 31.8 9029.78 4856.46 6096.83 1037.10 6184.41 9.65 10.82 102 13331.67 89.29 296.6 31.9 9030.09 4883.11 6111.83 1008.95 6194.55 9.37 9.14 103 13393.95 90.03 297.0 62.3 9030.46 4934.39 6139.92 953.34 6213.49 8.83 1.35 104 13456.04 90.58 297.7 62.0 9030.13 4985.75 6168.40 898.27 6233.47 8.29 1.44 105 13522.31 91.02 297.8 66.3 9029.20 5040.94 6199.27 839.60 6255.87 7.71 0.68 106 13553.98 91.02 294.7 31.7 9028.64 5066.85 6213.29 811.18 6266.02 7.44 9.78 107 13585.79 91.39 291.5 31.8 9027.97 5091.80 6225.76 781.94 6274.67 7.16 10.13 Page 3 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimu'oh Course 'rVD Verticel Displacement To'mi at Azm DLG I # Depth angle angle length depth section +N/S- +E/W- displacement (deg/ I 108 13617.13 90.62 287.5 31.3 9027.42 5115.09 6236.20 752.45 6281.43 6.88 13.01 109 13647.49 90.34 283.5 30.4 9027.17 5136.24 6244.33 723.16 6286.06 6.61 13.19 110 13684.22 89.29 278.7 36.7 9027.28 5159.67 6251.39 687.16 6289.04 6.27 13.39 111 13722.62 89.05 274.5 38.4 9027.84 5181.80 6255.80 649.02 6289.38 5.92 10.95 112 13746.86 89.88 273.2 24.3 9028.07 5194.84 6257.43. 624.78 6288.55 5.70 6.35 113 13778.40 90.31 272.3 31.5 9028.01 5211.23 6258.94 593.32 6287.00 5.42 3.17 114 13813.80 91.32 269.5 35.4 9027.51 5228.66 6259.50 557.93 6284.32 5.09 8.41 115 13843.72 90.86 266.5 29.9 9026.94 5242.04 6258.46 528.06 6280.69 4.82 10.15 116 13875.40 89.88 264.1 31.7 9026.74 5254.88 6255.86 496.47 6275.53 4.54 8.18 117 13905.58 88.61 260.8 30.2 9027.13 5265.73 6251.89 466.54 6269.27 4.27 11.71 118 13939.95 88.24 257.8 34.4 9028.08 5276.29 6245.51 432.75 6260.48 3.96 8.78 119 13966.23 88.65 255.7 26.2 9028.79 5283.23 6239.51 407.26 6252.78 3.73 8.16 120 13973.30 88.74 255.4 7.1 9028.95 5284.96 6237.73 400.39 6250.57 3.67 4.41 121 14007.13. 89.14 253.5 33.8 9029.58 5292.59 6228.68 367.83 6239.53 3.38 5.74 122 14038.53 89.45 253.0 31.4 9029.96 5299.04 6219.63 337.76 6228.79 3.11 1.87 123 14070.15 90.03 249.8 31.7 9030.11 5304.54 6209.52 307.72 6217.14 2.84 10.26 124 14101.75 90.28 246.3 31.5 9030.02 5308.19 6197.74 278.51 6204.00 2.57 11.14 125 14133.85 90.52 243.9 32.1 9029.80 5310.23 6184.21 249.41 6189.23 2,31 7.82 126 14163.97 90.40 242.1 30.2 9029.56 5311.05 6170.47 222.52 6174.48 2.07 5.64 127 14195.83 90.25 238.9 31.8 9029.38 5310.55 6154.82 194.84 6157.90 1.81 10.07 128 14228.24 89.17 237.5 32.4 9029.54 5308.74 6137.74 167.31 6140.02 1.56 5.46 129 14259.78 89.05 235.6 31.6 9030.03 5306.07 6120.33 140.95 6121.95 1.32 6.02 130 14291.83 88.83 234.0 32.0 9030.62 5302.39 6101.89 114.80 6102.97 1.08 5.05 131 14322.68 88.99 .231.5 30.9 9031.21 5297.75 6083.19 90.21 6083.86 0.85 8.11 132 14352.65 89.26 230.9 30.0 9031.67 5292.41 6064.37 66.85 6064.74 0.63 2.50 133 14379.22 89.29 231.6 26.5 9032.00 5287.72 6047.77 46.20 6047.94 0.44 3.02 134 14444.43 89.63 231.7 65.2 9032.62 5276.68 6007.31 -4.93 6007.32 359.95 0.54 135 14476.47 89.91 232.0 32.1 9032.75 5271.35 5987.49 -30.17 5987.56 359.71 1.28 136 14506.90 89.72 230.8 30.4 9032.85 5266.07 5968.52 -53.93 5968.76 359.48 4.00 137 14538.96 90.06 232.0 32.1 9032.91 5260.50 5948.49 -79.01 5949.02 359.24 3.89 138 14569.54 89.04 231.3 30.5 9033.15 5255.33 5929.57 -102.93 5930.46 359.01 4.06 139 14601.43 88.86 230.8 31.9 9033.73 5249.60 5909.52 -127.74 5910.90 358.76 1.67 140 14633.30 89.14 230.8 31.9 9034.29 5243.74 5889.36 -152.45 5891.34 358.52 0.88 141 14664.75 89.01 231.2 31.4 9034.79 5238.07 5869.60 -176.85 5872.27 358.27 1.34 142 14696.76 89.32 230.9 32.1 9035.26 5232.30 5849.43 -201.81 5852.91 358.02 1.34 143 14728.59 89.78-230.7 31.8 9035.51 5226.45 5829.33 -226.46 5833.73 357.78 1.58 144 14760.62 91.14 230.4 32.0 9035.26 5220.43 5809.00 -251.16 5814.42 357.52 4.35 145 14792.49 92.03 230.2 31.9 9034.37 5214.26 5788.61 -275.68 5795.17 357.27 2.94 146 14824.42 92.40 229.1 31.9 9033.14 5207.75 5767.95 -299.96 5775.74 357.02 3.34 147 14856.16 92.38 229.7 31.8 9031.8t 5201.14 5747.27 -324.08 5756.40 356.77 1.89 148 14888.04 91.76 228.2 31.8 9030.67 5194.29 5726.40 -348.04 5736.97 356.52 5.10 149 14919.96 90.89 227.9 32.0 9029.92 5186.90 5705.02 -371.84 5717.12 356.27 2.88 150 14951.70 90.77 228.7 ' 31.7 9029.47 5179.72 5683.93 -395.50 5697.68 356.02 2.55 151 14983.59 90.49 226.9 31.9 9029.12 5172.22 5662.51 -419.13 5678.00 355.77 5.71 Page 4 Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth Course TVD Vertical Displacement Total at Azm DL~ # Depth angle angle length depth section +N/S- +E/W- displacement (deg/ {fl:) {dec~l) (deg) {fl:) {fi:) {ft) {ft) Iff) (~t=l:) {de!~) lOOf) 152 15015.76 90.74 227.4 32.2 9028.77 5164.29 5640.61 -442.74 5657.96 355.51 1.74 153 15047.40 90.80 226.9 31.6 9028.34 5156.51 5619.12 -465.90 5638.40 355.26 1.59 154 15077.76 91.17 226.6 30.4 9027.82 5148.83 5598.29 -488.04 5619.53 355.02 1.57 155 15109.58 91.42 226.6 31.8 9027.10 5140.71 5576.45 -511.14 5599.83 354.76 0.79 Page 5 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 16 16-14A SURVEY REPORT 8 May, 1998 Your Ref: API-500292057001 Cast Survey 16-April-98 Job Number AKMM80177 KBE - 66.15 MWD surveys tie-on to Anadrill MWD surveys (16-14A Sidetrack survey) DRILLING SERVICES Survey Reft svy3387 Prudhoe Bay Unit Measured Depth (ft) 13123.90 13173.33 13204.9O 13236.54 13268.03 13299.83 13331.67 13393.95 13456.04 13522.31 13553.98 13585.79 13617.13 13647.49 13684.22 13722.62 13746.86 13778.40 13813.81 13843.72 13875.40 13905.58 13939.95 13966.23 13973.30 140O7.13 14038.53 14070.15 14101.75 141 33.85 90.170 89.540 89.820 89.78O 90.120 89.6OO 89.290 90.030 90.580 91.020 91,020 91.390 90.620 90.340 89.290 89.050 89.880 90.310 91.320 90.860 89.880 88.610 88,240 88.650 88.740 89.140 89.450 90.030 90.280 90.520 316.900 312.320 310.900 306.750 302.900 299.510 296.630 297.020 297.660 297.760 294.750 291.470 287.500 283.460 278.710 274.550 273.170 272,340 269.530 266,470 264.100 260.780 257.810 255.720 255.360 253.550 253.020 249.840 246.260 243.850 Sub-Sea Depth fit) 8963.49 8963.62 8963.79 8963.90 8963.93 8964.01 8964.32 8964.69 8964.35 8963.43 8962.87 8962.20 8961.65 8961.39 8961.51 8962.07 8962.29 8962.24 8961.74 8961.17 8960.96 8961.36 8962.31 8963.02 8963.18 8963.81 8964.19 8964.34 8964.25 8964.03 Vertical Depth (ft) 9029.64 9029.77 9029.94 9030.05 9030.08 9030.16 9030.47 9030.84 9030.50 9029.58 9029.02 9028.35 9027.80 9027.54 9027.66 9028.22 9028.44 9028.39 9027.89 9027.32 9027.11 9027.51 9028.46 9029.17 9029.33 9029.96 9030.34 9030.49 9030.40 9030.18 Sperry-Sun Drilfing Services Survey Report for 16-14A Your Ref: API-500292057001 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (o/looft) (ft) 5990.95 N 1167.72 E 5935418.59 N 720299.53 E 5841.30 6025.65 N 1132.54 E 5935452.25 N 720263.36 E 9.353 5879.40 6046.62 N 1108.94 E 5935472.52 N 720239.16 E 4.584 5902.65 6066.45 N 1084.29 E 5935491.63 N 720213.95 E 13.117 5924.89 6084.43 N 1058.45 E 5935508.85 N 720187.59 E 12.274 5945.40 6100.90 N 1031.25 E 5935524.53 N 720159.93 E 10.785 5964.55 6115.88 N 1003.16 E 5935538.69 N 720131.42 E 9.097 5982.31 6143.99 N 947.59 E 5935565.16 N 720075.05 E 1,343 6015.91 6172.50 N 892.43 E 5935592.07 N 720019.09 E 1.359 6049.88 6203.31 N 833.77 E 5935621.16 N 719959.56 E 0.681 6086.50 6217.32 N 805.37 E 5935634.34 N 719930.77 E 9.503 6103.32 6229.80 N 776.13 E 5935645.96 N 719901.17 E 10.374 6118.70 6240.25 N 746.59 E 5935655.55 N · 719871.34 E 12.902 6132.10 6248.35 N 717.34E 5935662.80 N 719841.87 E 13.338 6143.13 6255.41 N 681.31 E 5935668.81 N 719805.65 E 13.244 6153.82 6259.84 N 643.18 E 5935672.13 N 719767.40 E 10.850 6162.10 6261.48 N 618.99 E 5935673.06 N 719743.18 E 6.643 6166.18 6262.99 N 587.49 E 5935673.66 N 719711.65 E 2.964 6170,89 6263.57 N 552.09 E 5935673.21 N 719676.25 E 8.432 6175.06 6262.53 N 522.21 E 5935671.30 N 719646.41 E 10.344 6177.06 6259.92 N 490.64E 5935667,78 N 719614,93 E 8.095 6177.67 6255.95 N 460.73 E 5935662.94 N 719585.15 E 11.777 6176.76 6249.57 N 426.97 E 5935655.59 N 719551.59 E 8.705 6173.85 6243.56 N 401.40 E 5935648.83 N 719526.20 E 8.102 6170.46 6241.79 N 394.56 E 5935646.87 N 719519.41E 5.247 6169.40 6232,73 N 361.97 E 5935636.86 N 719487.11 E 5.479 6163.69 6223.70 N 331.90 E 5935626.96 N 719457.31 E 1.955 6157.77 6213.63 N 301.93 E 5935616.03 N 719427.65 E 10.223 6150.80 6201.82 N 272.63 E 5935603.37 N 719398.70 E 11.357 6142.02 6188.28 N 243.53 E 5935588.99 N 719370.00 E 7.545 6131.51 Comment Tie-on to Anadrill MWD survey Alaska State Plane Zone 4 PBU EOA DS 16 Continued... 8 May, 1998 - 9:26 - 2 - DrillQuest Prudhoe Bay Unit Measured Depth (ft) Incl. 14163.97 14195.83 14228.24 14259.78 14291.83 14322.68 14352.65 14379.22 14444.43 14476.47 14506.90 14538.96 14569.54 14601.43 14633.30 14664.75 14696.76 14728.59 14760.62 14792.49 14824.42 14856.16 14888.04 14919.96 14951.70 14983.59 15015.76 15047.40 15077.76 15109.58 90.400 90.250 89.170 89.050 88.830 88.990 89.260 89.290 89.630 89.910 89.720 90.060 89.040 88.860 89.140 89.010 89.320 89.780 91.140 92.030 92.400 92.380 91.760 90.890 90.770 90.490 90.740 90.800 91.170 91.420 Azim. 242.130 238.910 237.540 235.640 234.O40 231.510 230.850 231.640 231.680 232.040 230.820 231.970 231.270 230.760 230.760 231.210 230.950 230.680 230.440 230.150 229.110 229.680 228.200 227.870 228.680 226.950 227.390 226.890 226.610 226.600 Sub-Sea Depth (ft) 8963.78 8963.60 8963.77 8964.26 8964.85 8965.44 8965.90 8966.23 8966.85 8966.98 8967.07 8967.14 8967.38 8967.96 8968.52 8969.02 8969.49 8969.74 8969.48 8968.60 8967.37 8966.04 8964.89 8964.15 8963.69 8963.34 8963.00 8962.57 8962.05 8961.33 Vertical Depth (ft) 9029.93 9O29.75 9029.92 9030.41 9031.00 9031.59 9032.05 9032.38 9033.00 9033.13 9033.22 9033.29 9033.53 9034.11 9034.67 9035.17 9035.64 9035.89 9035.63 9034.75 9033.52 9032.19 9031.04 9030.30 9029.84 9029.49 9029.15 9028.72 9028.20 9027.48 Sperry-Sun Drilling Services Survey Report for 16-14A Your Ref: API-500292057001 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 6174.60 N 216.69 E 5935574.54 N 719343.57 E 5.724 6120.63 6158.93 N 188.96 E 5935558.07 N 719316.31E 10.118 6107.86 6141.86 N 161.41 E 5935540.21 N 719289.27 E 5.383 6093.68 6124.50 N 135.09 E 5935522.09 N 719263.46 E 6.035 6079.08 6106.05 N 108.89 E 5935502.88 N 719237.81E 5.038 6063.38 6087.39 N 84.33 E 5935483.52 N 719213.80 E 8.216 6047.32 6068.60 N 60.99 E 5935464.06 N 719191.01 E 2.379 6031.00 6051.97 N 40.27 E 5935446.84 N 719170.78 E 2.975 6016.56 6011.52 N 10.88W 5935404.92 N 719120.84 E 0.525 5981.52 5991.73 N 36.08W 5935384.41 N 719096.22 E 1.423 5964.39 5972.76 N 59.87W 5935364.76 N 719072.99 E 4.058 5947.94 5952.76 N 84.92W 5935344.03 N 719048.53 E 3.741 5930.58 5933.77 N 108.89W 5935324.36 N 719025.12 E 4.045 5914.13 5913.72 N 133.68W 5935303.59 N 719000.93 E 1.696 5896.69 5893.56 N 158.36W 5935282.72 N 718976.85 E 0.879 5879.15 5873.76 N 182.79W 5935262.23 N 718953.00 E 1.489 5861.94 5853.65 N 207.69W 5935241.40 N 718928.69 E 1.264 5844.46 5833.54 N 232.36W 5935220.59 N 718904.61 E 1.676 5826.96 5813.20 N 257.10W 5935199.53 N 718880.48 E 4.312 5809.24 5792.85 N 281.61W 5935178.47 N 718856.57 E 2.937 5791.48 5772.18 N 305.91W 5935157.11 N 718832.87 E 3.455 5773.39 5751.54N 329.99W 5935135.78 N 718809.41 E 1.795 5755.30 5730.61 N 354.01W 5935114.17 N 718786.00 E 5.030 5736.93 5709.28 N 377.74W 5935092.15 N 718762.91 E 2.915 5718.11 5688.15 N 401.43W 5935070.35 N 718739.84E 2.580 5699.50 5666.74 N 425.05W 5935048.26 N 718716.85 E 5.495 5680.60 5644.87 N 448.64W 5935025.71 N 718693.90 E 1.573 5661.24 5623.35 N 471.84W 5935003.53 N 718671.34E 1.591 5642.19 5602.55 N 493.95W 5934982.10 N 718649.85 E 1.528 5623.75 5580.70 N 517.06W 5934959.58 N 718627.38 E 0.786 5604.35 Comment Alaska State Plane Zone 4 PBU EOADS 16 Continued... 8 May, 1998 - 9:26 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 16-14A Your Ref: API-500292057001 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 15176.00 90.500 226.600 8960.22 9026.37 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 5535.07 N 565.31W 5934912.57 N 718580.47 E 1.385 5563.86 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 354.168° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15176.00ft., The Bottom Hole Displacement is 5563.86ft., in the Direction of 354.168° (True). Comment Projected Survey Alaska State Plane Zone 4 PBU EOADS 16 8 May, 1998 - 9:26 - 4 - DriilQuest O F! I I--I_1 ~ G SE FI~./I r' E S 09-May-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 16-14A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 13,123.90' MD n/a' MD 15,176.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. 4/23/98 GeoQuest 500 ~V. International Airport Road Anchorage, AK 99518-1199 ATTN: SherrJe NO. 111019 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D.S. 1-131~;-~'H~L~ 98192 CNTG 971224 I 1 1 D.S. 4-41-~ '~(-/q~ 98190 TDTP 971220 I I 1 D.S. 5-1B ~-~.)~ 98180 TDTP 971225 I I 1 GNI #1 PRESS/TEMP LOG 98031 3 I 1 GNI #2 PRESS/TEMP LOG 980314 I 1 D.S. 1-02 PRODUCTION PROFILE 980328 1 1 :D.S. 6-16 PRODUCTION PROFILE 980328 I 1 -- 'D.S. 9-06 PRODUCTION PROFILE W/DEFT 980329 1 1 D.S. 16-14A CEMENT BOND LOG 980409 I 1 -- SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. BP EXPLORATION BP Exptoration (Alaska) Inc, goo East I~enson P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: Name: Company: Location: Fax Number: TELECOPY FROM: ' Name: Department: Location: Fax Number: ,. C)px PAGES TO FOLLOW) -4)4/03/98 14:07 FAX 907 564 5193 BP' EXIJLUI(A'I'IUN ~luuz BLAIR WONDZELL, AOGCC RE: FORWARD PLANTS FOR DS 16-14a Mr Wondzell, for the current water injection sidetrack, DS 16-14a, being drilled by Nabors 2ES, we plan to make a wireline conveyed CBL mn over the 7" liner in order to satisfy AOGCC regulations (reference 20-AAC 25.030 Sec 5-3). The bounding barrier above Zone 4 is encountered at +/- 40 degrees inclination. This will allow the wireline CBL ample capacity to log all of the 7" liner down into the reservoir (Zone 4) and provide confirmation of isolation of injected water to Zones 2/3/4 of the Ivishak. We therefore request your approval to dispense with an additional CBL log of the 4-1/2" liner shortly to be mn on this sidetrack as the only new lithology open behind this liner will be the same zones as isolated by the 7" liner. Please call me at 564-5582 with any questions. Yours sincerely, Christopher Brown 4/3/98 Operations Engineer, Nabors 2ES. 14:U~ FAA BU'/ ~4 ~lHd ~ uu~ BP EXPLORATION ENGINEERING DATA SHEET NO,~ OF.~ BASEDON ENGINEER (~[i~(.~ ~~ DEPT. APP'VL DATE BUDG ET/AFE NO. FILE NO. AK 2337.1 (3194) TONY KNOWLE$, GOVEi~NOI~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Fcbmar-,' 25. 1998 James Smith Engineering Supcrvisor ARCO Alaska. Inc. POBox 196612 Anchorage, AK 99519-6612 ac~ Pmdhoc Bay Unit 16-14A ARCO Alaska. Inc. Permit No. 98-36 Sur. Loc: 1534'SNL. 527'EWL. Sec. 24. T10N. R15E. UM Btmholc Loc: 3888'NSL. 19'WEL, Sec. 14, T10N, RI5E. UM Dear Mr. Smith: Encloscd is the approved application for pcrmit to rcdrill thc above rcfcrcnccd well. Thc permit to rcdrill docs not cxcmpt you from obtaining additional permits rcquircd bx' lax,,' from other governmental agencies, and docs not authorize conducting drilling operations until all other required pcrmitting dctcrminations arc made. Blowout prevention cquipmcnt (BOPE) must be tested in accordance v~'ith 20 AAC 25.035. Sufficicnt notice (approximatcly 24 hours) of thc BOPE tcst pcrformcd bcfore drilling below the surface casing shoe must be givcn so that a rcprcscntativc of thc Commission max witness thc test. Notice mav be given bx' contacting thc Commission pctrolcum ficld inspcctor on the North David W"q'9,-hnst°n / ~ Chairman BY ORDER OF THE COMMISSION dlffEnclosurc cc~ Department of Fish & Game. Habitat Section xv/o encl. Department of Environmcntal Conservation w/o cncl. STATE OF ALASKA Ab,:,,SKA (JIL AND GAS CONSERVATIO~'COM'-~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork l--]Drill [~i;;~Redrill Ilb. Typeofwell I-IExploratory F']StratigraphicTest [-I Dev-~10'p~nt Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 68.2' Prudhoe Bay Field / Prudhoe ~. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028332 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1534' SNL, 527' EWL, SEC. 24, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 2182' NSL, 3399' WEL, SEC. 13, T10N, R153, UM 16-14A At total depth 9. Approximate spud date Amount $200,000.00 3888' NSL, 19' WEL, SEC. 14, T10N, R15E, UM 03/05/98 1"2. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028327, 1392'I No Close Approach 2560 15325' MD / 8970' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9000' Maximum Hole Angle 91° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth .... Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 1609' 8850' 7894' 10459' 8990' 170 sx Class 'G' 6" 4-1/2" 12.6# L~80 BTC-Mod 5016' 10309' 8970' 15325' 8970' 495 sx Class 'G' i"9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10462 feet Plugs (measured) Cement Plug top at 10027' MD (05/08/95) true vertical 9363 feet Effective depth' measured 10027 feet Junk (measured) true vertical 8981 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 300 sx Permafrost 110' 110' Surface 2605' 13-3/8" 3000 sx Fondu, 1250 sx Permafrost 2675' 2675' Intermediate Production 9702' 9-5/8" 500 sx Class 'G' 9772' 8752' Liner 993' 7" 360 sx Class 'G' 9464' - 10457' 8482' - 9359' Perforation depth: measured 9834' - 9854', 9856' - 9876', 9886' - 9946', 9994' - 10004', 10018' - 10024' true vertical 8808'- 8978' (five intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Winton Aubert, 564-4825 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify tl~a~ the foregoing i/St}rue and correct to the best of my knowledge ,.__ Signed it;~~ I__ ~'~~' James Sm Title Engineering Supervisor Date Commission Use Only /~-- ,~;~ 50-029-20570-01 c~! r*~/c'~"~ for other requirements Conditions of Approval' Samples Required []Yes ,~ No Mud Log Requir~d~' [~Yes ~'No Hydrogen Sulfide Measures [~Yes []No Directional Survey Required J~,Yes~]No Required Working Pressure for BOPE [] 2M; [] 3M; J~5M; [] 10M; [] 15M Other: Original Signed By Oavid W. Johnston by order of Approved By Commissioner the commission Date ~:~._ Form 10-401 Rev. 12-01-85 Submit Ii icate I wen Name: IDs 16-14A HAW Sidetrack Summary Type of Well: I lnject°r I Surface Location: 1534' FNL, 527' EWL, S24, T10N, R15E, UM Target Location: 2182' FSL, 3399' FEL, S13, T10N, R15E Bottom Hole Location: 3888' FSL, 19' FEL, S14, T10N, R15E, UM I AFE Number: 14J0386.0 I I Estimated Start Date: I 3/5/98 l MD: I~s,32s' I ITVD: I Well Design: I Rig: Nabors 2ES I Operating days to complete: [ 35 18970' ss I I~ Elev. 168.2' I HAW Sidetrack Objective: IDS 16-14A is proposed as a horizontal sidetrack, MIST injection well. Target is Zone 2C, and the asset desires to inject MI and PW into Zone 2C for two years, then produce Zones 3 and 4. Estimated reserves are 1.3 MMBO. Formation Markers Formation Tops MD Pilot TVD (ss) 8736' TSAD 9903' Top Z3 10,134' 8906' Top Z2 10,250' 8949' Top HOT 10,459' 8990' I KOP: 1900o' MD Directional Maximum Hole Angle: Rig Move Close Approaches: I Drilling Close Approaches: 91 o through targets None None Casing/Tubing Program Hole Size Tubular Wt/Ft Grade Conn Length Top Btm O.D. MD/TVD MD/I'VD 8-1/2" 7" 26# L-80 BTC-MOD 1609' 8850'/7894' 10459'/8990' 6" 4-1/2" 12.6# L-80 BTC-MOD 5016' 10309'/8970' 15325'/8970' Production Tubing [ NA I 4-1/2" 12.6# L-80 BTC-MO D 10283' 26726' 10309'/8970' Mud Program Milling Interval: Gel-free 6% KCI Biozan I Density, ppg I FunnelVis, sec YP Gels I pHI APIFL, cc[ 9.8 - 10.0 50 - 65 50 - 60 20-30 / 30-40 9 - 10 6 - 8 Hazards/Concerns Maintain YP 50 - 60 to insure adequate removal of metal cuttings. Insure adequate preparation to eliminate metal entering motor and MWD from mud bypassing solids control equipment. Intermediate (8-1/2" hole) Section: Gel-free 6% KCl Biozan I Density, PPg I Funnel Vis, sec LSRYPI Gels I PH I AP' FL, cc I HPHT FL 10.0 - 10.5 50 - 65 6 - 11 15-25 / 20-35 8.5 - 9.0 5 - 6 < 10 cc Hazards/Concerns I Be alert for lost circulation, differential sticking due to higher MW. Production (6" hole) Section: Quickdriln (viscosified SW) I Density, ppg I Funnel Vis, sec I LSR YP LSR VisI pHI AP, FL, co I HPHTFL 8.6 - 8.8 55 - 65 14 - 20 > 50,000 8.5 - 9.0 NC < 10 cc Hazards/Concerns Potential high torque could require lubricant use. Be alert for lost circulation, differential sticking due to overbalanced MW. Maximize solids control to keep fluid as clean as possible. Max mud weight 8.8 ppg. Cement Calculations Lead Cement Tail Cement Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments CI G; Tail FW=0; 7" N/A 170 / 15.8 / 1.14 50% excess; Pump time=4+ hr.; TOC - _+9400' MD (_+500' above LCU) 4-1/2" N/A 495 / 15.7 / 1.19 Class G: 30% excess; Pump time = 4 hr.; TOC 150' above TOL Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Logging Program Open Hole Logs: 8-1/2" Hole MWD DidGR; DPC PEX 6" Hole MWD DidGR/4-Phase Cased Hole Logs: CBL Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre- venter will be installed and is capable of handling maximum potential surface pressures. Di- verter, BOPE and mud fluid system schematics on file with AOGCC. Hazards · DS 16 is a known shallow hydrocarbon area. · Stuck pipe, tight hole, and swabbing have occurred in DS 16 wells. · Lost circulation through conductive faults is a possibility on DS 16. DS 16 CI II drilling wastes are to be disposed at CC-2A grind and inject facility. If CII wastes are generated, they will be taken to the Pad 3 disposal site. Pre-Rig Procedure 1. , Operations Summary Notify AOGCC representative prior to commencing P&A operations. Kill well with sea water. If significant fluid loss is experienced (> 20 bbl/hr), inform Nabors 2ES rig representative immediately. 3. RU coiled tubing unit. RIH and pull Baker IBP from tubing @ 9412' MD. POH. , , , , Establish injection using seawater. Bullhead seawater to kill well if necessary. Mix and pump 26.3 bbl (148 ft3) Class G cement. Displace cement until_+5 bbls cement are squeezed into perforations from 9834'-10024' MD, leaving __.14 bbls (_+398') ce- ment above top perforation. Proposed TOC is _+9436' MD (in packer). Highest ac- ceptable TOC is 9200' MD due to required depth of kick-off whipstock. POH, RD CTU. RU electric line unit and chemical cutter for 5-1/2" tubing. RIH and chemical cut 5- 1/2" tubing at _+9020' MD, avoiding collars. FlU and reverse circulate seawater through tubing cut until returns are clear. Moni- tot for fluid loss. Freeze protect well with diesel to 2,000'. Have FMC wellhead services test 9-5/8" packoff to 5,000 psi and service lock down studs. Notify Rig Representative immediately of any pressure test or wellhead con- dition problems. 8. Bleed pressure from tubing, inner and outer annuli; zero psi is required all around. , Install BPV. Remove well house and flowlines. Prepare for rig arrival. Level pad. Dig out cellar. Drillinq Rig Procedure 1. MIRU drilling rig. Kill well if necessary. ND tree, NU and test BQPE. 2. Pull tubing hanger and 5-1/2" tubing. 3. Test 9-5/8" casing to 4000 psi. 4. Set whipstock and mill window through 9-5/8" casing @ _+9020' MD. 5. Kick off and directionally drill 8-1/2" wellbore to 7" liner point @ _+10,459' MD. 6. DPC log. 7. Run and cement 7" L-80 liner to TD. 8. Drill out liner and directionally drill 6" well bore to TD @ 15,325' MD. 3 9. Run and cement 4-1/2" L-80 liner to TD. 10. DPC perforate 4-1/2" liner. 11. 12. Run 4-1/2" L-80 completion with packer @ +10,310' MD. Freeze protect well, set packer, set BPV, ND BOPE, NU and test tree, RDMO. 4 Well: 16-14 Spud Date:06-16-81 Original RKBE:70' Top of Formation: 9831' Annular Fluid:Diesel/9.4 NaC1 Reference Log:BHCS .JO Alaska, Inc. -Prudhoe API #: 50-029-20570-00 Completion: 07-09-81 Hanger Type: Gray Max Hole Angle: 43° @ MD: 6700' Date:07-03-81 Tie In: Type:PRODUCER Status:New Hanger:29' Angle @ TS:27° Angle @ TD:29° Date: 00-00-00 Ann. Comm: LDL 11/30/96 Indicates Collar Leak @ 6552' ;tLL DEPTHS A/~ i~KB DRILLING MD TO TOP OF EQUIPMENT EXCEPT W'HEP~E NOTED. J-1 G-1 o .c o ' o-~ 0-4 Jewelry Depth 1 2115' 2 9420' 3 9436' 4 9448' 5 9507' 6 9508' 7 9509' 9499' 9 10027' (J) Description 5-1/2' Camco BAL-0 SSSVNipple ID=4.562" 5-1/2' Baker PBRAssembly 9-5/8' x 5-1/2" Baker SAB Packer Crossover 5-1/2' x 4-1/2" 4-1/2' Camco DB-6 Landing Nipple ID=3.813" 4-1/2' Baker Shearout Sub 4-1/2' Tubing Tail ELM Tubing Tall (Logged 03/18/82) 10040' IBP (Set in Liner 04/13/95) With Cement ID=0.001" Cap Tagged (05/08/95) Min ID: 4-1/2" Camco DB-6 Landing Nipple ID=3.813" Casing and Tubing (C) Size Weight Grade Top Bottom Description 1 13-3/8" 72# L-80 0' 2675' Casing 2 9-5/8" 47# L-80 0' 9772' Casing 3 7" 29# L-80 9464' 10457' Liner Video Log 10/18/94 shows hole @ 10055' Cemant Plugged 12/11/94 5-1/2" 17% L-80 0' 9448' Tubing-PC 4-1/2" 12.6% L-80 9448' 9509' Tubing-PC J-5 Gas Lift Information (G) MD TVD Stn Mandrel Valve Type Latch Port TRO Date 2911' (2911') 1 CA-MMG CA RD RK 11-19-96 4848' (4812') 2 CA-MMG CA RD RK 11-19-96 6450' (6115') 3 CA-MMG CA RD RK 11-21-96 7692' (7041') 4 CA-MMG CA RD RK 11-15-96 8384' (7584') 5 CA-MMG CA RD RK 8462' (7647') 6 CA-MMG CA RD RK 8850' (7964') 7 CA-MMG CA RD RK 8921' (8023') 8 CA-MMG CA RD RK 9229' (8282') 9 CA-MMG CA RD RK 11-21-96 9309' (8350') 10 CA-MMG CA RD RK J-6,7 C-2 P-1 (ELM CmtCapTag Perforation Data @ 10027' Interval Zone 05/08/95 1 9834- 9854 4 9856- 9876 4 9886- 9946 4 9994-10004 4 10018-10024 3 DEPTHS ) (P) FT SPF Date Comments 20 4 06-29-84 APERF 20 4 03-19-82 IPERF 60 4 03-19-82 IPERF 10 4 06-29-84 APERF 6 2 10-22-92 APERF PBTD=10406' TD=10462' J-8 Hole in Liner @ 10055' Cmt Plug Tagged @ 10052' (02/07195) C-3 FRAC 03/11/90 Datum 8700' SS= 9791' MD 8800' SS= 9903' MD Revision Date: 12-02-96 by ENH Reason: LDL Notation Previous Reason: 11-23-96 Well 16-14 Well ......... F£e:ld ........ : .°rUdhoe .Say ~onTpu:a¢ion.. t Hiafrnum 'Cu-~va:ure Unir. a ........ s FIlleT Surface La~.'..: ?0.20962893 Surface bong. ~ :148.2314337S · . ... b"urEace."~ .... ~ 3746 iamb 495,4 · T/e-in '~:.Urvey~'L00S FSr, 3732 t.andin9 PLo. o t 20.83 ~$la ~427 , :.. .. · · . · STATIO~ ~SASURED' 'ID~h~F£CATION CURVg 8.O0/t00 ~000.00 ~ a.00/[00 ~VS 90S0.19 C~VE t0.00/t00 9929,40 t0000.00 · , .. Anadrill $chlumbe~at': . Alaska Dt'sCric~ 1,IL1 ~ 80th 'Avenue .~ . .. .. · . . D~IO~AL SBL~ P~ for ~e~ '~VI~S ORI~r~C , , ~. . ~o[oo.:'oo s4,22 10200~ 00 , 64.12 [030'0,00 7'4 .~2 .' :10400.00 84.1.2 ?,' a~grl~o POINT 't0~.S~..'/'/ ~0,00- .. (Anadrfl[ (c)~? I6L4A¥0,L '3,2b,5 11~42 AN 16.80 L5.~5 · . ., . · 3S,?O .. aoea,3~ aO3e. L9 aoev.go al2a.~? eo6b.~? aa3o.'s, 8762.36 s. ooa,?s es32.es · . ,. , . . · "1942.t4 3~42.B3 · 1763.29 · 2142.3~ ,. '~?.4~, $~ala ~aci:or.'i .... Convergende'. . ~. . . · · .. · ANADRILL .FEASiBIL'I PLAN NOT APPROVED 'FOP, 'EXECUTION · .. PLAN... · . ~agna~te D~Ln, +28.'463 (~) 0'.gSggS4$4 .. · c- ;. , . .. .... ..... · · '.. .. ·. · C00~$~TE;~ A~S~ 2one 4 ' '~L DL/ ,. ~L~ ~ T- FA~ 200 . :. . 2s~e,.aa ~ 20~0,ls'a Tuolsa.~e s93~3.94 Hs ~B ~S39.a2 N 1020.~S N 9202S3.64 S~31~S4.6~ Ob 0.4S 2567.~0,N 1028,65 ~ 7202~9.91 Sg3~92.S9 H9 8.00 . 30~9.~9.~ :L~72,56 ~ ~203~S,94 59325Q6.51 H8 0,oo 3~2~.&~ ~ .2~8S.o3 K 9204Q0.~ $9~25SL,03 HS LO,QO ~ ~ ,. . , . 32~4.34 , Z20S.SL ~' 7~Q428,48 sg326~4'.2a' X8 ~0.0O ,. · 32~.BS .~ L~28.7S'~ 920439e~ Sg329aY,42 ~ LO,OO .3366,68 N 1254.92 ~ 7~046~,9~ 5932797.9t ~ L0.00 242~.6~ 34az.o'~ N. ~2ao.sa a '.720~as.T? ss32a~s.oa ~ 30.00 · · , . ' * ,;, ~ .. : .. ,. .. , .. .. AKA-DPC F 'STATION IDENT~£CAT~ON DHPTH · mmmmmzmmmmmmm~mmmmmm ~m m c~vz lo.oo/~oo ~os~l.~ ENO 10.00/~00 CURV~ CURVE 10.00/~'00 L£~29'.79 ~ iO.O0/L00 C~/RVS ' ~14~.04 · CURV~ ~L.OO/iOb' .22'33~,'9S z2~oo.oo i2300.00 ~ ss,oo/:oo CURvs c-~R~ :o.oo/loo. PROP~)~SD tl']~5/., PROF%bB ' . ZNOZ. L~T."D%RHCI'20~ AAT~L~ AZIMUTH mmmmm~ mmmmlrmmmm · . 9O,OO ... 9o°0o .. 90.00 · ~.70 90,00 : . .1S,70 90.67 .... B9.9a ~9'.98 89;99 ,. ·89,99 ,~oo.oo 90.00 ,12598.?0'..~o.ol 22~.aa' 12627.S3 "90,01 ~23.30 127oo.o0 ,9i2~I '" 1~.!~ 2J.2~ 9048.20 ~.~o 9o~8.2o 2.??. 90~..22 a~ao.o2 '39~.~?' .90te,.~3 esao.o~ · · .. 19 ~c~v 199~. 9age 2 · ·. .. · · .. .. · ~ m m ~ u mmmm ' m m m mm V&R~ZCA/,-D~P?HS '$EC'L'zON COORDINATBfl-FRON ~ ~ne .. T~ SU~-SBA D~ART HSL~D X Y m mm ~ 'mm m ~m I e ~ I~ m mm~ mmmm m m mmmmm mm mmmmm mm .m ' 90~.20 8990,00 2469,71 3St9,57' ~ t2~6',46~ ~20SO0.O0 S932950,00 . 9058.20 ~~go.o0 "2469.7[ 35[q'.57 N i2'~6.46 E 710~.00.00 S932950.0~ 9os~.2o .e~o~oo 29(3,n .3~.e~ ~ z3'ai~3s s ?20929..oo s~33oso.oo '9osa.20 899o.0o 'a~3,.~-- 3616.5L ~ t324;¢5 Z ?a0S2S,OO 5933050.00 · ~OSa,.OS age~,as as~,ol 364i,29 ~ ii30.68 R ~0530,6~'5933074 - . , .· . . . , , '33'a~.92 44~2.4o'K ~2a.ge '~ 'V20?Oo.oo 59a3900.00 . 3?44.44 81S8,24 N t644,27 ~-~20800~00 8934~00,00 ~96'.19 ~220;88 N .. . ~048.24 e~aO,04 9048.23 'a980'.03 "1~80.2O' 9048.'22 8980.02 -4L40.~3 .. 9o4e:2o a'~ao,Oo '~208:ao SSOB,'29 N · 5S57,30 N S$12.42 N '5667.68 ~ ~ ~o.oo/~oo euRw ~ ii.oo/loo c~va c~Vz 2o.oo/ioo 8~O :O,00/L00 CLrRV8 1270.0,~! 91,25 33~29.ab 9~,25 . "3i6,24' 9038.20 89~0,00, · .. ., 33198,59 8~';90 .3'07,'91 9037.44 89~9.,24 .. ~3~23,05. :'.89..90, 30q'.91 ' 9030:20 e970.00 . . ,. . · · , .. ~eoo.oo , ~o.s9 · 2~9,o0.oo. ~o.92 1402q.03 93.~ . ~39.25 '9033,71 , 240.~0,~ ~1:22., ",. ....239;gS 9033:20 8965~00 . ,, . :,. t4LO0.0~ 90. sa 2~4.36 .9032 o ~3 L4~93.~3 09:34 ' 2~S.oo "~012.S0 CURW 10.00/~O'O 34~ae.4's ~.~ 225..q0" 90~0.2o . . , · ., . · ........... t~_.~ ~ ..!s!. ~ ~.. ~½.~.L~:J~.~_5~ '3.a_ ~ *J.: _.._ ~,. ~27.9.91 '5667,~3 N , ,. 4689.43 5992.46 ~ · . .. · ·. S331,4L :~3sO.el'X ·., 5349.39 629~.~ N'" · mmmm ~o0 io .oo 10.00 0.~0 0.OO · 0. oo 8970,.00 1OL~ o .00 16S'L:)/..% ~. ':..'720805.02 · 1(46.35 E' '"720797.3'7 S954?~2,36. Z62~.~s Z' .?2O??O:e~ :5934B.~8.6:~ ' 350o,40 · .'/~ov2~.~7 5'93494~.0~: zS6~.~o ~ L?2~so,~ s~3soso;oo · . .... . . 2~?,~'9 s ..?2OsOo,oo S93s4oo;oo . .... : .. .. 90b 0o00 90~ 2i. QO 9Q~ ~t.o0 ~ ~,00 ·, 'ab~ ..,0~.~o.0o ~ ~o 99b xs 22.00 · : .. sas.~9.z ?z9~3?.,'(~ ~9~s?s~.2s .hg~ tv.oo 4~0.~6'..S ..~Z9543.,4~ S93S726,20" agL · ,,... 6345,41 62~8.64 '~.' '~2S,54 SZa,.0B ' sase.aa" ". ~&;~ ~ vt~os~.0'0 s~a~o.~':' '~':'O.oo .. . ... , .',... - . ,..:~2 ..... ,. · j · ...~ .. ..... ,.' .j .' · . .- , . . . . . , DS~-14A STAT~O~ ~ND ~o.o0/2oo CURV~ 4-L/2' LINER POINT ~/~ 14700.00 ., 14705oB2 · .1S324,88 t5324.88 253~4 · . L::)ROE)O~ED 91211.21 PRO~XL~I · mw m m lmrlmmrd Iw. mm . ..... '.. ~ ..... - ... :-, --~-~ - -: ............ m ' mn m mmmmmIm m . , INCLN D~R~cTION '.V~RT~CA~D~PTH$ .' $21CTI'0~ LDORDINATg~'FRO"' ALASKA 22s.~s ~ojo.2~ 89?0,09. . . . ~mmm mmmm ~AC~'IO0 6~R i0,OO · ~.00 0.00 "0.00 O,O0 , ,, .............. (Anad~£].], (c)9'7 X6~4Aeb2 .1,2b'-'~. se4's.?3' ~' 9a.~s w. ?~o3~.88 s93523?.ss -~ . 'S~22.0'~ ~.' m ~9.~9 H ~8600.00 5934800'00 ,S422-0a ~ "S~.'09 fl 75B600:o0 ... ...'., ' . -. . . : .:tt' ' · . ' . . . · .... . . , , . . .' ...' ,,. :ExECUT, ON. "', ',-' · -. '' ~ ' , . .'. ., .... ~ . . . ,.. . , , , , .. , , . ., , ,, . ,.,., ... ,,.. ,, ,, ...,. . , , . . . , · . . . ., . 11/I9/1997 12:58 .907-~ 215, ANADRIU.. DPC ...... PAGE 05 , ' ERVICES DRILLING" .... ",: · · ''SHARED S. :KB> E)s a- 4A (PO1) VERTICAL- SECTION. VI'E~ Section at~ 331.44 TVD Sca)e.: '~ ~nch -- 1200 feel Scale' ~ inch = ~200. fee~' ~a~n ..... ; .19 Nov 1997 '. .~,'' . .Anad~j J J SchJu~be~ge~. Harker [den~iftcatton Al TIE-IN.SU~vef 8' CURV~ a.oOltOO c) 'E~ a:oo/too o1. CuRvE to.oo/1o0. · 8 7' CASINO POINT. · F! EHO"tO.O01100 Ct~' · %~ L~I~G H} o]~vE 10,001i00 I1 TARGET fi dl E~O IO.O01tO0'CURVE. K! CURVE"tO.OO/IOO-- "U-ENO tO.O0/~00 .CURVE H)-CURVE ~t.O0/tO0 . NJ-E~ t1.00/ioo CURVE · 01' CURVE lO.O0/iO0 - P) E~O lO;O0/tOO cuav~ O{ CUR~ .ll.O0/iO0 B{..EJ~' ii.O0/iO0 .CL~VE. 'is) CURVE i7'.O0/1.O0 ' 11 ENO iT.00/iO0 CUR~. U{-CURVE' lO.O0/iO0 ¥}. ENO tO.O0/-iO0-CURVE W) 'CUR~ .lO.O0/iO0 Xl .E~O lO.O0/iO0 ¥}' 4-1/2" .LIt~gR POINT · ZJ TtROET 19 al mO/ESL 12137' 9048 3744. 89.98 1~559,. 9048.. 4141 90.0i t2628 90484209. .gO.Oi~ 12700 '9047 -a~O "91.25 13t23 9038 4687.- 91.L~ 13199 9037.." 4759 - ~89;90 13623- '9036 5148-89.90 14027' 9034 .5.~0. 91.~ t405t 9033' 5349. 91 14194 '.903Z' '53~ 89'.34 14688 90]8 .5t87 :89 14706 ~' 51~ -~.Oll 153~ .90~ ~' 90.Otj 15~ 90~ ~ '90.OiL 10800 o BO0 1200 1800 · 2400 3ooo 3600 ~2oo Section Departure 4600 5400 6000 GSO0 7200 SHARED SERVI'C. ES 'BFIILE]:N6' .' DS:t6-:t4A '(PO:t) "VERTZCAL SECTZON VIE jori aP.:. 33i,44 '- 1'VD'Scale,; I Inch = 600 fee[ .. Dep Scale,' I inch =.600 fee[ Dra~ .... · 19 Nov 1997 · Har'ker' ldenti f tcatlon · B) CI,~YE B.O0/!O0 D). ct~. yE ~o:ooI!oo £) 7" cxsI,6 Polm' ,.~. i~u lo.oo/.~oo-cumin G}. LA~OII~ POINT H) cu~ 4..ENO.' i0.00/100 CURVE ,XI. CuRvE 10.00/1o0 L} END JO.O0/fO0 CI~YE ' .'~). CuRvE ~.].00/'~00 N), END, l~.O0/}O0 CURvE .0] CURVE ~0.00/~00 P} ,E~ ~0.00/~00, Ct~ .0}' CUm~ J~,00/100 .' R) END ~!..00/¢0' CURVE $) O.q:IVE ~7.00/~00 el Cm~ ~O.OO/JO0 VI ~O ~0.00/[00 C~ · m .~E ~0.00/~00 X} ~ [0.~0/~00 ~ · y} 4-1/2". kI~ POIm. Zl z~nGET W9 · lid 8F, B SECTN INCLN · 8998 8086 174~ 33.10 gO00 8088 '1743 33.09 9050 8129 .~763 37.06 9929 88~1 2::M2 37.06 ~459 '9058- 2.470 90.00 10159 90~8 '2470 90.00 10459. 9058 2470 90.00 · ]0562 9058 .2544 90.00 · t0562 9058 2544. '90.00 t0587 9058 2562 90.67 .' lt43.0 9048 3190 90.67 ~i466.' cJo,~8 3218 89.~8 '22137 '9048 3744 1~.9~ i2559 9048 4t4! 90.01 . f26~8 ~48 4209 90.01 f2700 9047. '4280 9!.25 ]3t23 9038 4687 91.25 ]3199 '.9037 4759 8g.90 13623 9038 5i48 89.90 140P7 90..~ 535O 9!.22 i405i 9033 5349 9!.~2 t4i94 '~032 53~ 89.34 14688 9038 5187 89.34 t4706 9038 §!82 90.0t !5'325 9038 5025 90.0! 15325 9036 5025 90.0! ,'J5325 90~ 5025 90,0:I ~4o~ ~oo ~o~' ~ob zuoo 2900 3~' ~u _. ~ '-~- '.-~; .... ' "' j . · ' Section Departure ' ~na~ll[ {c)97 i6i4~Ol 3.~.5 l[:~P) ' ' ' ' '' ' ' ' ' ' ' ' * ' ' ' ' ' ' , . . 1'1/19/1997 12:58 9~7-344-2160 · ANAl)RILL DPC - . PAGE 07 E ' ) ~ING POINT ~a~ :E. ~J L) PI ~ 10:00/t~' ~ 10~7 ~4~ N" (331 ~' SCALE ~- - '" ':. ~'. ~WN ..... ' .' 19 Nov 1997 ' ~ .. R) s) T) CURVE t0.00/100 E~ to oo/loo curvE' cm~ ii;ooltoo ENO it..O0/JO0 CURVE. CURVE 10.00/100' t0,00/t00 CL4:IVE 1t430 446t N.. 1524.E t1466 '4497 N -t53!'E." i2t37 515B"N.- 1644 E-' 12559 5557 N:' i548 E' ~2628 5612-N.' . ]507 E t2700 ".5668.N t450 £..' · , e · Anadrj].l Sch]U/ ber'ger,.' I ' v) x) 3500 3000 2500 2000 (~nadrlll (c)97 I61~lPOl 3.2b.5 ii: 45 ~ PI ~500 looo 500 0 50O <- WEST' EAST -> 1000 1500 2000 2500 3000 3500 J i:~/i¥/97 J 00131953] VENDOR ALA.SKAST i 4. O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 121797 6K121797I 100. fJ~ 100.00 PYMT COMMENTS' accompang permit to drill application HANDLINQ INST: s/h kathg campoamo~-: ×5122 J ........ :n I~.HI~CK IS IN PAYMENT FOR ITEMS DE~FIIBED ABOVE. ~I[I]IIF;lll ~ 100. O0 i 00. O0 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS /'"-,,¢ ,,' Y GEOL AREA ~ "~ ~ UNIT# ON/OFF SHORE ... ("'t ,-.,d ADMINISTRATION ENGINEERING GEOLOGY 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... N N N N N REMARKS 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ '~r'~ NN 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. CrON 23. If diverter required, does it meet regulations .......... ,~_ N 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation . :.._.._~.., . . N 26. BOPE press rating appropriate; te'st' t<~' ,_.~G?-.~ ' I~sigl N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ,, N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. ~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... YY NJ Z' , /') 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .............. -33. survey (if off-shore) ............ ./Y N Seabed condition 34. Contact name/phone for we,ekly,Dro~lress repo. rts ...... '. Y N l expmratory onlyj GEOLOGY: ENGINEERING: COM~ R N C_,~:~:~2 CO Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97