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Home My WebLink About198-184Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /?~-' 1 '~'/-/ File Number of Well History File PAGES TO DELETE Complete RESCAN [-3 Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ~) - _.~ Poor Quality Original'- Pages: [] Other- Pages' DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds Other COMMENTS' Scanned by; Beverly Mildred Dareth~ Lowell Date: TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /si ALASKA l.L. AND ~T:;~g~S~~J~ON cOM~.L"ION RECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LOG JAN I B 2006 Alaska Oil & Gas Cons. Commission 1 b. Well ClasAnchorage 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 198-184 305-317 13. API Number 50- 029-20124-01-00 14. Well Name and Number: 1a. Well Status: 0 Oil 0 Gas 0 Plugged 181 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1316' FNL, 879' FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 665' FSL, 2668' FWL, SEC. 17, T11N, R14E, UM Total Depth: 1428' FSL, 3930' FWL, SEC. 17, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664500 y- 5959906 Zone- ASP4 TPI: x- 667995 y- 5961965 Zone- ASP4 Total Depth: x- 669238 y- 5962756 Zone- ASP4 -~------------------------ .--.-------------.---..--." ----------------------- 18. Directional Survey 0 Yes 181 No 21. Logs Run: GR, CNL Zero Other 5. Date Comp., Susp., or Aband. 10/21/2005 6. Date Spudded 10/06/1998 7. Date T.D. Reached 10/12/1998 8. KB Elevation (ft): 54.46' 9. Plug Back Depth (MD+ TVD) 12072 + 8935 10. Total Depth (MD+ TVD) 12153 + 8935 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE Wr.PERFT. GRADE lOP tsOTTOM lOP tsOTTOM SIZE 20" Insulated Conductor Surface 80' Surface 80' 36" 18-5/8" 139# /109# /96.5# K-55 Surface 2524' Surface 2524' 24" 13-3/8" 72# I 68# L-80 I N-80 Surface 4331' Surface 4180' 17" 9-5/8" 40# I 47# L-80 I N-80 Surface 9749' Surface 8671' 12-1/4" 7" 29# N-80 9218' 9843' 8211' 8753' 8-1/2" 2-7/8" 6.16# L-80 9219' 12153' 8211' 8935' 3-3/4" 23. Perforations op'en to Production (MD + TVD of Top and 24. Bottom Interval, Size and Number; if none, state "none"): None 22. MD TVD MD ~CANNED JAN 2 ij ZODß 26. Date First Production: Not on Production Date of Test Hours Tested SIZE 5-1/2", 17#, L-80 TVD PBU C-03A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028305 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CeMENTINGAECOAD 484 sx Cement 4700 sx Permafrost II 1210 sx Class 'G', 950 sx PF II 4670 sx Class 'G', 619 sx Class 'G' 284 sx Class 'G' 109 sx Class 'G' TUBING RECORD DEPTH SET (MD) 8836' - 9291' AMOUNT PULLED PACKER SET (MD) 9170' 25. ACID, . FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 9104' 8225' AMOUNT & KIND OF MATERIAL USED P&A wI 24 Bbls Class 'G' Set EZSV wI Whipstock on Top PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL -BBL PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL -BSL Press. 24-HoUR RATE GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO GAs-McF W ATER-BsL OIL GRAVITY-API (CORR) 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 BFl JAN 1. 9 2n06 Form 10-407 Revised 12/2003 o RIG ff\r't\tN REVERSE SIDE ~ 28. ( GEOLOGIC MARKERS NAME MD 25N 9866' 23SB I Zone 2B 9867' 25P 9877' 22TS 9918' 21 TS I Zone 2A 9999' Zone 1 B 10104' TDF I Zone 1A 10427' TDF I Zone 1A 11480' 29. ( rORMATION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8773' None 8774' 8783' 8817' 8881' 8941' 8982' 8955' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I ~erebY certify that the for,oing. is true ,and correct to the best of my knowledge. Signed Terrie Hubble 'iJ.f',At..R. ~ ~ Trtle Technical Assistant Date 0 I It {p ( Q(p PBU C-03A 198-184 305-317 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Ken Allen, 564-4366 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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). ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: list all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only .( ~ Well: Field: API: Permit: C-03B Prudhoe Bay Unit 50-029-20124-02-00 205-158 Accept: Spud: Release: Rig: 1 0/29/05 11/05/05 11/15/05 Nabors 2ES PRE-RIG WORK 10/17/05 RUN 5.5" GS CORE WI EQ PRONG TO 9093' SLM. MAKE SEVERAL RUNS WI 5.5" GR AND GS TO 9093' SLM. 10/18/05 PULL XX PLUG FROM SS AT 9093' SLM, DRIFT TO DEV AT 10172' SLM WI 2.25" CENT S.B. 10/20/05 RIH WITH 3.5" JSN TO DRIFT TO TOP OF LINER FOR DEPTH CONTROL. SAT DOWN AT TOP OF LINER AT 9240' CTMD. PU WEIGHT AT 9236' CTMD. CORRECT DEPTH TO TOP OF 27/8" LINER AT 9219' MD BKB. PUH 10' (9209') AND FLAG PIPE. POOH. BULLHEAD KILL WELL USING 360 BBLS 1 % KCL. RIH WITH 2.25" BDN TO FLAG DEPTH. LOAD WELL WITH 220 BBLS DIESEL. 10/21/05 LOAD WELL WITH 220 BBLS OF DIESEL. PUMPED 120 BBLS OF 1% KCL, COOL DOWN CT. PUMP 24 BBLS OF 15.8 PPG CLASS G CEMENT (5 BBLS NEAT LEAD SLURRY, 10 BBLS WITH 10 PPB AGGREGATE, 5 BBLS NEAT TAIL SLURRY). BULLHEADED 16 BBLS FROM 9209' CORRECTED CTMD, LAID IN REMAINING 6 BBLS AT WITH 1:1 RETURNS HOLDING 1000 PSI WHP. HELD 500 PSI BUMP PRESSURE FOR 30 MINUTES WITH 30 PSI PRESSURE LOSS. DROPPED BALL FOR NOZZLE AND CONTAMINATED WITH 75 BBLS OF BIOZAN WASHING FROM 7800' TO 9100' CTMD. WASHED WITH XS 2% KCL FROM 7800' TO 9100'. POOH AT 80% WASHING ALL JEWELRY IN TUBING. FP WELL WITH 60/40 METHANOL FROM 2500' TO SURFACE. RECOVERED BALL. BLOW DOWN COIL WITH N2 IN PREP FOR PIPE EXTENSION. RD DS CTU #5. NOTIFY PAD OPERATOR AND PCC OF WELL STATUS. JOB COMPLETE. 10/22/05 RIH WI 4.5" G. RING. 10/23/05 DRIFTED WI 4.5" G. RING. TAGGED CEMENT TOP AT 9104' SLM. TIOO = 0/425/0/0. TEST CEMENT PLUG. PRESSURE TEST IA TO 1000 PSI WITH 3. 7 BBLS OF DIESEL, 0 LOSS AFTER 15 MIN, (PASS) PRESSURE TEST TUBING TO 1000 PSI WITH 3 BBLS DIESEL AFTER STABILIZING 30 PSI DROP IN 15 MIN BLED TUBING TO 0 PSI AND IA BACK TO 50 PSI, ANOTHER GAUGE SHOWED 120 PSI AFTER RIGING DOWN. BLED BACK 21 BBLS OF FLUID BLEEDING DOWN PRESSURE FWP=0/12010/0. RAN GYRO-SCOPE SURVEY FROM 9083' TO SURFACE (PRE RWO). 10/24/05 CORRELATED TO SWS JEWELRY LOG DATED 6-0CT-1998 (PRE RWO). JET CUT TBG AT 8836'. ,. \~ {' BP EXPLORATION Operations Summary Report Page 1 .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-03 C-03 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/27/2005 Rig Release: 11/15/2005 Rig Number: Spud Date: 2/13/1973 End: 11/15/2005 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/29/2005 00:00 - 03:30 3.50 MOB P PRE Move rig from well # C-10 to well C-03. Move camp & pits. Bridle up. UD pipe shed chute. UD derrick. Move off well. 03:30 - 13:30 10.00 MOB P PRE Move and spot sub base over C-03B. Spot welding shop, pits & cuttings tank. Raise derrick. Raise and pin cattle chute. Bridal down & hang lines.R/U floor. Complete pre-spud check list. 13:30 - 14:00 0.50 MOB P PRE Hold pre-spud meeting with Tool pusher, WSl and drill crew. Rig accepted @ 14:00 hrs 10/29/2005. 14:00 - 16:30 2.50 WHSUR P DECOMP R/U circ lines in cellar to tree & annulus. R/U DSM & pull BPV with lubricator. Tubing & annulus = 0 psi. 16:30 - 20:00 3.50 WHSUR P DECOMP Circ down annulus, displace diesel freeze protect from tubing. R/U and pump down tubing taking returns through choke. Pump 45 bbl Safe-Surf-O & displace well to clean seawater @ 4 bpm @ 350 psi. Monitor well. 20:00 - 21 :00 1.00 WHSUR P DECOMP Suck out tree and dry rod BPV in & test from below to 1000 psi. Blow down circ lines and rig down. 21 :00 - 23:00 2.00 WHSUR P DECOMP N/D tree & adaptor flange & remove from cellar. 23:00 - 00:00 1.00 BOPSURP DECOMP N/U 13 5/8" x 5000 psi BOPE. 1 0/30/2005 00:00 - 01 :00 1.00 BOPSUF\P DECOMP N/U 135/8" x 5000 psi BOPE. 01 :00 - 01 :30 0.50 BOPSUP P DECOMP Test BOP to 250 psi low test & 3500 psi high. TWC valve leaking. (Set clocks back 1 hour for daylight savings time.) Gave 24 hour notice to AOGCC for inital BOP test. Witness of test waived by rep. Jeff Jones.Test witnessed by WSL James Willingham & Tool Pusher Ronnie Dalton. 01 :30 - 02:30 1.00 BOPSUP P DECOMP Test choke manifold. 02:30 - 03:30 1.00 BOPSUP P DECOMP R/U DSM lubricator and pull TWC valve. Install new valve, RID lubricator. 03:30 - 07:30 4.00 BOPSUP P DECOMP Test BOPE. 250/3500 psi. Top drive to 250/3500. Witnessed by Maskell - Co Rep. Witness of test waived by AOGCC Rep J. Jones. Clear rig floor of all testing equipment, blow down lines. 07:30 - 08:00 0.50 BOPSUP P DECOMP R/U DSM lubricator, pull TWC, RID lubricator. 08:00 - 09:00 1.00 PULL P DECOMP Bring tubing tools to rig floor. M/U spear for 5 1/2" tubing. 09:00 - 10:00 1.00 PULL P DECOMP Spear 5 1/2" tubing. BOLDS. Pull tubing hanger to rig floor. UWT = 165K. 10:00 - 11 :30 1.50 PULL P DECOMP Release spear, UD landing joint & tools. 11 :30 - 15:00 3.50 PULL P DECOMP POH UD 5 1/2" 17# tubing, spool up control lines to SSSV @ 2131'. RID spooling unit and clear rig floor. Recovered 26 clamps and pins & 3 S.S. bands. According to the records we are missing 1 S.S. band. 15:00 - 21 :00 6.00 PULL P DECOMP POH UD tubing. Recovered 222 joints of tubing, 4 GLM, 1 BVM, and cut joint @ 19.46'. RID tubing equipment, clear and clean rig floor. 21 :00 - 22:00 1.00 BOPSUF P DECOMP M/U test joint, install test plug and test BOPE with 4" test joint. Test top & bottom rams & floor valves to 250/3500. Test annular preventor to 250/2500 psi. Witness of test waived by AOGCC rep Jeff Jones. Test witnessed by WSL James Willingham & Tool pusher Ronnie Dalton. 22:00 - 00:00 2.00 DHB P DECOMP PJSM. R/U Schlumberger wire line & RIH with 8.51 GR/JB & CCL. 1 0/31/2005 00:00 - 05:00 5.00 DHB P DECOMP RIH w/8.51 GR/JB & CCL to 8800' (36' above 5 1/2" tubing stub) Work through tight spot @ 4280', POH. M/U HES EZSV & CCl, RIH, set EZSV plug @ 8225'. POH & get SWS off to side. 05:00 - 06:00 1.00 BOPSUF P DECOMP Close blind rams. Test casing to 3500 psi for 30 min - OK. Printed: 11/21/2005 11:47:15AM ~ (( BP EXPLORATION Operations Summary Report Page 2 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-03 C-03 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1 0/27/2005 Rig Release: 11/15/2005 Rig Number: Spud Date: 2/13/1973 End: 11/15/2005 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/31/2005 06:00 - 08:00 2.00 CASE P DECOMP RU SWS & RIH with FasDrill bridge plug. Set plug @ 2069'. POH RID SWS. Clear rig floor. 08:00 - 10:00 2.00 CASE P DECOMP M/U 9 5/8" spear, Spear casing and pull 170K to free seal assy @ 2054', UWT = 155K. 10:00 - 11 :30 1.50 CLEAN P DECOMP Circ out arctic pack, pump 160 bbl 80 degree diesel followed by 35 bbl soap pill and clean seawater. Pump @ 260 gpm @ 600 psi. 11 :30 - 12:00 0.50 CASE P DECOMP Blow down lines. Pull casing to rig floor. 12:00 - 14:30 2.50 CASE P DECOMP Release spear & UD. UD landing joint & XOs. Break out 10 3/4" casing pup and use as handling sub on thermo casing, UD 3 joints of thermo casing and 3 space out pups. Change out elevators and R/U power tongs & back-ups. 14:30 - 19:00 4.50 CASE P DECOMP POH UD 103/4" casing, C/O handling equip. UD 9 5/8" casing and seal assy. Recovered 43 joints of 103/4" casing, 2 joints of 95/8" casing, 1, FO & 1, seal assy 14.10 long. All casing in good shape & seals on seal assy intact. 19:00 - 21 :00 2.00 CASE P DECOMP RID tongs, handling equip & fishing tools. Clear & clean rig floor. 3.00 CLEAN P I DECOMP M/U BHA, P/U 9 5/8" polish mill, 133/8" casing scraper, junk 21 :00 - 00:00 basket, bumper sub, jars and drill collars to 324'. 11/1/2005 00:00 - 01 :30 1.50 CASE P DECOMP RIH wlpolish mill & 133/8" casing scraper P/U drill collars & HWDP to 972'. 01 :30 - 03:00 1.50 CLEAN P DECOMP RIH P/U drill pipe, tag bottom of PBR @ 2061'. 03:00 - 04:30 1.50 CLEAN P DECOMP Polish PBR, circ soap pill followed by clean seawater. Pump @ 500 gpm @ 640 psi. 04:30 - 07:00 2.50 DHB P DECOMP Close top pipe rams & test 133/8" X 9 5/8" packer and 133/8" casing to 3000 psi. 07:00 - 07:30 0.50 DHB P DECOMP POH to 1065'. 07:30 - 09:00 1.50 DHB P DECOMP M/U storm packer in string and set 5' below well head. Release running tool and POH. Test RTTS to 1000 psi. 09:00 - 10:30 1.50 BOPSUPP DECOMP NID BOPE, remove # 2 annular valve, split bottom flanges and stand back BOP. 10:30 - 12:00 1.50 BOPSUF P DECOMP Remove old well head, bring new spool to cellar, prep casing head. 12:00 - 15:30 3.50 BOPSUP P DECOMP PJSM. Prep cellar for hot work. Cut & dress 133/8" casing stub. 15:30 - 18:00 2.50 BOPSUF, P DECOMP Install McEvoy S3-YB intermideate spool w/19.5 X 133/8" YB bottom pack-off. Energize seals & test void to 1900 psi, hold test for 30 min, OK. 18:00 - 20:30 2.50 BOPSUP P DECOMP N/U 13 5/8" X 5000 psi BOPE. 20:30 - 22:00 1.50 BOPSUP P DECOMP Install test plug & test BOP/well head flange against blind rams to 250/3500 psi, OK. Install wear ring. Break & UD test joint. 22:00 - 00:00 2.00 DHB P DECOMP M/U storm packer running tool, RIH to top of packer & flush. Screw into & retreive Storm packer & release. POH & UD. Clear rig floor. 11/2/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP BHA, rack back HWDP, POH UD 9 drill collars. 01 :00 - 02:30 1.50 CLEAN P DECOMP Break & UD 13 3/8" casing scraper & 10.4" polish mill assy. 02:30 - 03:00 0.50 CASE P DECOMP Pull wear ring. 03:00 - 07:00 4.00 CASE P DECOMP R/U & run 9 5/8" 40# L-80 buttress casing with seal assy to 2017' . 07:00 - 08:00 1.00 CASE P DECOMP Change bails on top drive. 08:00 - 10:00 2.00 CASE P DECOMP M/U circ head, slack off while pumping to comfirm seal assy is in PBR. Space out, drop ball to open EZSV cementer. Slack off Printed: 11/21/2005 11:47:15AM ( { BP EXPLORATION Operations Summary Report Page 3 _ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-03 C-03 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1 0/27/2005 Rig Release: 11/15/2005 Rig Number: Spud Date: 2/13/1973 End: 11/15/2005 Date From - To Hours Task Code NPT Phase Description of Operations 11/2/2005 08:00 - 10:00 2.00 CASE P DECOMP & tag @ 2061'. M/U cement head. Pressure up to 2400 psi to shear cementer open. 10:00 - 12:00 2.00 CASE P DECOMP Pump 5 bbl water & test lines to 4500 psi. Pump 20 bbls mud push, followed by 129 bbl 15.8 ppg "class G" cement. Displace W/155.9 bbl of seawater, bump plug w/21 00 psi. Bleed off & check floats held, OK. CIP @ 12:00 hrs. 12:00 - 15:00 3.00 CASE P DECOMP Pump 15 bbl seawater with cement retarder through BOP, kill line & annulus valves to cuttings tank. Blow down lines. RID casing tools. Suck out 9 5/8" casing below ground level. Drain BOP stack & RID circ lines in cellar. 15:00 - 21 :00 6.00 WHSUR P DECOMP PJSM. NID BOP, break flange @ wellhead & raise stack. Install 12" X 9 5/8" SB-3 slips on 9 5/8" casing with 90K tension. R/U Wachs casing cutter, cut pipe. Pull mouse hole & riser, set back BOP. Dress casing stub. Install McEvoy 135/8" X 5K 2 step tubing spool WI 9 5/8" YBT BTTM pack-off. Energize YBT seals & test void to 2500 psi for 30 min, OK. 21 :00 - 23:00 2.00 CASE P DECOMP N/U BOPE. Install secondary annulus valve on tubing spool. 23:00 - 00:00 1.00 CASE P DECOMP P/U test joint, install test plug. RILDS, test wellhead flange/BOP against blind rams to 250/3500 psi. 11 1312005 00:00 - 01 :00 1.00 CLEAN P DECOMP BOLDS. Pull test plug & install wear ring. 01 :00 - 02:30 1.50 CLEAN P DECOMP M/U 8 1/2" bit, 9 5/8" casing scraper, 2 boot baskets & jars. P/U 9 drill collars, RIH with HWDP from derrick to 950'. 02:30 - 03:30 1.00 CLEAN P DECOMP RIH P/U drill pipe to 2038' . 03:30 - 08:00 4.50 CLEAN P DECOMP Drill cement, float equipment & FasDrill plug. From 2038' to 2077'. UWT == 95K, SWT == 90K, RWT == 95K. WOB == 15/30K. Torque == 3/4000K @ 80 rpm. Pump == 475 gpm @ 760 psi. 08:00 - 13:30 5.50 CLEAN P DECOMP RIH P/U drill pipe. Tag EZSV @ 8225' break circ. 13:30 - 14:30 1.00 CLEAN P DECOMP R/U up and test 9 5/8" casing to 3500 psi. Hold for 30 min, OK. 14:30 - 16:30 2.00 CLEAN P DECOMP Pump 45 bbl high vis sweep & displace well to 10.2 ppg LSND mud @ 510 gpm @ 2200 PSI. 16:30 - 18:00 1.50 CLEAN P DECOMP Cut & Slip drill line. Service top drive & drawworks. 18:00 - 21 :00 3.00 CLEAN P DECOMP Pump dry job, POH from 8225' to 950' 21 :00 - 23:00 2.00 CLEAN P DECOMP Stand back BHA. UD junk baskets, casing scraper, bit sub and jars. Clear rig floor. 23:00 - 00:00 1.00 STWHIP P WEXIT PJSM. M/U whipstock BHA. P/U jt of HWDP, window mills and bit sub. 11/4/2005 00:00 - 03:00 3.00 STWHIP P WEXIT P/U mills & MWD, orient, upload & pulse check. P/U whipstock & bumper sub. RIH with drill collars & HWDP to 1041'. 03:00 - 06:30 3.50 STWHIP P WEXIT RIH with whipstock assy to 8142'. Install blower hose on top drive. Orient 79 degrees left of high side, tag EZSV @ 8224'. UWT == 190K. DWT == 145K. 06:30 - 07:00 0.50 STWHIP P WEXIT Set down 18K and trip bottom anchor. P/U 15K and confirm. Set down 40K and shear lug. Obtain SPRs. 07:00 - 14:00 7.00 STWHIP P WEXIT Mill 9 5/8" casing window from 8202' to 8218'. Mill 20' of new formation to 8230'. WOB == 5 112K. Torque == 8/10K @ 105 rpm. Pump @ 416 gpm @ 2000 psi. Recovered 170 # of metal during milling operations. 14:00 - 15:00 1.00 STWHIP P WEXIT Pump 45 bbl high vislsuper sweep. Ream and work through window. 15:00 - 15:30 0.50 STWHIP P WEXIT Perform F.I.T. to 11.5 ppg EMW. TVD == 7351', OMW == 10.2 ppg, surface pressure 500 psi. 15:30 - 19:00 3.50 STWHIP P WEXIT POH to 1018'. 19:00 - 21 :00 2.00 STWHIP P WEXIT Stand back HWDP. UD drill collars & whipstock mills. Printed: 11/21/2005 11:47;15AM Page 4 .. BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-03 C-03 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 11/4/2005 21 :00 - 22:00 1.00 STWHIP P WEXIT 22:00 - 00:00 2.00 STWHIP N RREP WEXIT 11/5/2005 00:00 - 00:30 0.50 BOPSUF P WEXIT 00:30 - 03:00 2.50 STWHIP P WEXIT 03:00 - 05:30 2.50 STWHIP P WEXIT 05:30 - 08:00 2.50 STWHIP P WEXIT 08:00 - 09:00 1.00 STWHIP P WEXIT '. - 09:00 - 00:00 -15.00 DRILL P INT1 11/6/2005 00:00 - 07:00 7.00 DRILL P INT1 ~ 1.00 DRILL P INT1 08:00 - '00 2.00 DRILL P INT1 10:00 - 11 :00 1.00 DRILL P INT1 11 :00 - 13:00 ~ P INT1 13:00 - 14:30 1.50 DR N RREP INT1 ~, 14:30 - 15:30 1.00 DRILL ~ INT1 15:30 - 17:00 1.50 DRILL INT1 17:00 - 18:00 18:00 - 21 :00 21 :00 - 23:30 1.00 DRILL P 3.00 DRILL P 2.50 DRILL P 0.50 CASE P 2.00 CASE P 0.50 CASE 0.50 CASE LNR1 LNR1 1117/2005 23:30 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 03:00 03:00 - 06:30 LNR1 06:30 - 07:00 P 0.50 CASE P 0.50 CASE P 1.00 CEMT 2.00 CEMT P LNR1 LNR1 LNR1 LNR1 LNR1 Start: 10/27/2005 Rig Release: 11/15/2005 Rig Number: Spud Date: 2/13/1973 End: 11/15/2005 Description of Operations Remove wear ring, P/U ported sub and flush BOPE. Work on rig air system. Purge drilling mud from system. Install wear ring. P/U 8 1/2" BHA, PDC bit, mud motor, flex collars and MWD to 810'. RIH, shallow hole test @ 500 gpm @ 1250 psi. PJSM. RIH P/U drill pipe from shed, 811' to 3982'. RIH with drill pipe from 3982' to 8092'. Fill pipe @ 3000' intervals. Install top drive blower hose. Orient tool face 79 LHS @ 8092'. Take SPRs & drilling parameters. Slide through window @ 8202'. Ream under gauge hole from bottom of window to 8230'. I Drilling from 8350' to 9060'. UWT = 185K, DWT = 145K, RWT = 165K. Pump @ 500 GPM @ 3200 psi, TQ off bottom 7-8 , on 8/9 K, ART 6.24 hrs, AST 4.5 hrs Drill 8 1/2" from 9060' to 9310'. HWT = 190K, DWT = K, RWT = 170K. Torque off bottom = 7500K, on = 95 . Pump @ 500 gpm @ 3300 psi. AST = 1.54, ART = 3.24. Circ for samples @ 9402'. Pump @ 500 gp 3300 psi. Drill from 9402' to 9410'. Circ for sample. ump high vis sweep. Monitor well, static. I Short trip. POH from 9410' to 9 51 window @ 8202'. Hole in I good shape. Monitor well, stat' , mud weight in & out = 10.2 ppg. Blow down top rive. Cut & slip drill line. Adj brakes. Service rig. Replace air valve 0 rown saver. Rebuild quick release valves on high and low um clutches. RIH to botto @ 9410'. Pump hi vis sweep and circ out. Spot liner running pill. Monit well, stable. Mud weight in and out = 10.2 ppg. Drop 2" dri ipe drift. OH to 9 5/8" window @ 8202'. Monitor well, stable. Pump dry job. POH for 7" liner to BHA @ 811'. LID HWDP, jars & drill collars. Down load MWD & pull pulsar. Break & LID MWD, mud motor & bit. Clear & clean rig floor. U to run 7" 26# L-80 BTC-M liner. P/Ù'-7(float equip, fill pipe & check floats. RIH with 7" 26# L-80 BTC-Mii.ner to 1332'. P/U 7" lin'êr.~nger, packer & 1 stand of drill pipe to 1481'. Circulate liner Vi lume, pump @ 6.5 bbl @ 200 psi. UWT = 62K, DWT = 60K. RIH with liner on drill lpe from 1481' to 8202'. Fill pipe @ 930' intervals. "-."" Circ liner & DP volume @ 8';202'. Pump @ 8 BPM @ 1150 psi. UWT = 170K, DWT = 125K. BI down top drive. RIH from 8202' to 9385', hole in g d shape. M/U cement head, manifold & hoses. 9 bottom @ 9410' Stage pump up to 5 BPM @ 850 psi. PJS Pump 5 bbl water, test lines to 4500 psi, pum 20 bb111.8 ppg mud push followed by 57 bbl 15.8 ppg class G cent. Flush lines with mud. Drop wiper plug. Dowell displace ce nt 128 bbl. Bump plug to 4,000 psi. Set down 70K on hanger. ~ off pressure, check floats, OK. CIP 10:45 HRS ~ Printed: 11/21/2005 11:47:15AM "" C-03B Requested slight change to decompletion steps ) 199-/~4 Subject: C-038 Requested slight change to decompletion steps From: "Allen, Kenneth W" <Kenneth.Allen@bp.com> Date: Mon, 24 Oct 2005 16:57:02 -0800 TO:: Winton Aubert <winton_8ubert@admin.state.ak.us> Winton, We just received some results from the pre-rig diagnostics. I have already turned in a permit to drill application with the same procedures you approved on the Sundry, but since the diagnostics were favorable I would like to modify a few steps. I believe they are currently under the approved Sundry since the steps are in the decompletion stages. I have attached the document with the steps I'd like to revise with lines through them. The basic change I'd like to make is to eliminate picking up a 9-5/8" casing scraper and then the 9-5/8" RTTS. This is because our pre-rig combo IA x T test passed at 3500 psi. If we pull the tubing, set the EZSV bridge plug and our 3500 psi test with the rig fails, we will pick up a 9-5/8" RTTS and chase down the leak. Please let me know if you need something further from me or if you do not approve .C?t this change in our plan. Thanks, Ken Allen Operations Drilling Engineer Mobile: 907.748.3907 Office: 907.564.4366 e-mail: allcnkw(Cl)bp.com ~ANNED NOV {} 2 2005 Operations Summary Content-Description: C~03B Operations Summary V3.doc Content-Type: application/msword Content-Encoding: base64 1 of 1 10/25/2005 8:30 AM ) ) C-03B Operations Summary Pre-Ria Work: 1. Bleed OOA, OA, IA & TBG to zero psi. PPPOT - OC (13-3/8") 1,500 psi (If test fails then monitor test port while testing OA), PPPOT - IA (11-3/4" x 9-5/8" thermo Casing) 2,400 psi. Test tubing hanger seals to 5000 psi. Function all lock-down screws. Repair or replace as needed (8 known to need repair on 9-5/8"). 2. Pressure test OOA (18-5/8" x 13-3/8") to 500 psi for 30 minutes. Pressure test the OA (13- 3/8" x 9-5/8 Thermo casing) to 500 psi for 30 minutes. Pressure test T X IA to 3,500 psi for 30 minutes. Attempt to verify / isolate source of Ilbubbing" into the cellar noted in May 2004. 3. Rig up slickline. Pull XX plug at 9,217' set on 6/4/05. Drift 5-1/2" x 4-1/2" tubing to the top of the 3.75" deployment sleeve. Drift 2-7/8" liner as deep as possible recording depth. 4. Fluid pack the tubing and inner annulus. 5. P&A perfs in 2-7/8" liner from the top of the PBTD (....12,072') to 9,100' in the 5-1/2" tubing. RIH with coil to PBTD. Lay in 21.5 bbls of cement to ....8,993' MD and squeeze ....2.5 BBLS into perforations. Wash down to confirm TOC @ ....9, 100'. POH with coil. a. Cement Calculations: · 2-7/8" liner = 12,072' - 9,219' or 2,853' (....16.5 BBLS) · 4-1/2" tubing = 9,219' - 9,180' or 39' (....0.6 BBLS) · 5-1/2" tubing = 9,180' - 9,100' or 80' (....1.9 BBLS) · 2.5 BBLS (....107') for squeeze · Total cement volume of 24.0 BBLS 6. Rig up slickline, drift 5-1/2" tubing. Tag TOC. 7. Chemical cut the 5-1/2", 17#, L-80 tubing in the middle of a joint at.... 8,800' MD. 8. Pressure test T X IA to 3,500 psi for 30 minutes after cement P&A. 9. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to ....2,200'. 10. Bleed all casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 11. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. RU. Pull the 5-1/2" tubing from the pre-rig Chemical cut ....8,800'. Spool up SSSV control lines. 5. MU 8.5" c3sing scraper. RIH picking up '1" DP to tubing stub at ....8,800'. POOH. 6. RU e-line. Run Gauge Ring 1 Junk basket and Gamma Ray tool for 9-5/8",47# casing with CCL to tubing stub - 8,800'. POOH 7. RIH with 9-5/8" EZSV on e-line. Set EZSV at -8,620' to avoid cutting a casing collar during window milling operations. POOH. 8. Test 9-5/8" casing and bridge plug to 3,500 psi for 30 minutes while recording on chart. If test fails PU a 9-5/8" RTTS and chase down the leak. 9. PU a 9-5/8" RTTS. RIH and set RTTS 3t 2,1 OO'md 3nd test the 9-5/8" casing to the lower bridge plug to 3,500 psi for 30 minutes. Chase down læk if present. Record test. POH and LD RTTS. 10. RIH with 9-5/8" F3S Drill on '1" DP. Sot plug 3t ....2,065' (below liner top packer, above FO Cementer). 11. RIH with a 9-5/8" Fas Drill on e-line. Set plug at ....2,065' (below the liner top packer, above the FO cementer. POOH and RD e-line. 12. MU casing spear and pull 9-5/8" x 11-3/4" thermo coasing, 10-3/4" casing and 9-5/8" seal stem at 2,043' md. Send seal assembly to Backer for redessing seals and machining ports. 13. Close the annular and circulate the arctic pack from the 9-5/8" x 13-3/8" annulus with warm diesel. Note: Be prepared for possible trapped gas entrained in the Arctic Pack. 14. POOH and LD Thermo Casing, 10-3/4" casing and 9-5/8" casing. ) ) 15. RIH with a 9-5/8" polish mill and 13-3/8" casing scraper to the BOT tieback seal assembly. CBU and displace to clean sea water. 16. NO BOP stack and Unihead spool. Change the 13-3/8" packoff and test. 17. NU 2-step casing spool and BOP. Test BOP. 18. Close blind rams and test 13-3/8" casing to 3,000 psi. MU 13-3/8" RTTS and isolate leak, if necessary. 19. RIH with 9-5/8" casing and old 9-5/8" seal assembly with ports between seals 1 & 2. 20. Cement 9-5/8" x 13-3/8" annulus to surface. 21. Break BOP stack and set emergency slips. Rough cut 9-5/8" casing. 22. NO BOP stack. Oress off casing stub and set pack-off. NU tubing spool and BOP stack. 23. Test 9-5/8" packoff and BOPE. Test casing to 3,500 psi. 24. MU 8.5" mill with an 8.5" string mill. RIH to float collar & test 9-5/8" to 3500 psi. Drill out float equipment and 9-5/8" Fas Drill plug. 25. Continue running in the hole picking up 4" OP to the 9-5/8" EZSV ....8,620'. Circulate wellbore clean with seawater. 26. PU 9-5/8" whipstock and bottom trip anchor with an 8-1/2" window milling assembly. RIH on 4" DP to EZSV. Orient and set the whipstock. Swap well over to 10.2 ppg milling fluid. 27. Mill a window in the 9-5/8" casing at ±8,600' MD plus 20' of formation from mid window. Note: Verify that the mud weight is 10.2 ppg prior to cutting the window. 28. Perform FIT to 11.5 ppg. POOH for Drilling BHA. 29. MU the 8-1/2" drilling assembly with DIR/GR/RES and RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the Top Sag River. CBU, short trip to window and back to TO, circulate well clean and POOH. 30. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to -8,450' MD. Set hanger / liner top packer and displace cement with mud. POOH. 31. Test the 9-5/8" x 7" liner to 3,500 psi for 30 minutes if sufficient compressive strength has been achieved. Record the test. 32. MU 6-1/8" BHA with OIR/GR/RES/ABI and RIH to the 7" landing collar. Test casing if not previously done. 33. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 10.0 ppg. 34. Orill ahead building to horizontal landing point. POOH for bit & BHA change. 35. MU 6-1/8" BHA with DIR/GR/RES/DEN/NEU/ABI. RIH and MAD pass build section. Drill ahead in the horizontal as per plan to an estimated TO of 11,570'. 36. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 37. Run and cement a 4-1/2", 11.6#, L-80 LTC liner throughout the 6-1/8" wellbore and 150' back into the 7" drilling liner to -9,241' MD. Set liner top packer and displace well to clean seawater above the liner top. NOTE: A perf pill will be left in the 4-1/2" liner. 38. RIH with DPC perf guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns. 39. Run the 4-1/2", 12.6#, L-80 completion tying into the 4-1/2" liner top. 40. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 41. Set and test TWC. 42. ND BOPE. NU and test the tree to 5,000 psi. 43. Freeze protect the IA and Tubing to ....2,200' and secure the well. 44. RDMO. Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. t .. e e ~ IJ ,1T Œ rID ~ ~ ~ ~ ~ ~ ~ / FRANK H. MURKOWSKI. GOVERNOR AI,ASIiA OIL AND GAS / CONSERVATION COMMISSION I 333 W. 7'" 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 C-03A Sundry Number: 305-317 f\ ~ 'Lßü5 s\ìt\~NE\) tm\! \J 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¡fday of October, 2005 ( Encl. ¡'/I) / L¡J&!\- 10/14 ¡ ¿c.,'C!';- V/~f 10 -j" ALASKA 0' AND ~Ä~T~g~S~L::~ON COMMISSION Ç1_~.)~~.~.\ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: B Abandon o Alter Casing o Change Approved Program o Suspend 0 Operation Shutdown 0 Perforate 0 Other o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o 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): 4. Current Well Class; / IBI Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 1184.ri ~,' ." , . ,. . API Number: 50- 029-20124-01-00 /' 99519-6612 54.46' 9. Well Name and Number: . ....'ei.03A·.~ 8. Property Designation: ADL 028305 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENIWELL CONDIIIONSUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12072 8935 9217 11. Total Depth MD (ft): Total Depth TVD (ft): 12153 8935 80' 30" 80' 80' 2524' 18-5/8" 2524' 2524' 930 870 4331' 13-3/8" 4331' 4180' 4930 2270 9749' 11·3/4" x 10-3/4" x 9·5/S" 9749' 8671' 3580 2090 625' 7" 9218' - 9843' 8211' - 8753' 8160 7020 Liner 2934' 2-7/8" 9219' - 12153' 8211' - 8935' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): 10200' - 12070' / 8967' - 8935' Packers and SSSV Type: 9-5/8" x 5-1/2" GUIB packer f" Tubing Size: 5-1/2", 17# x 4-1/2", Tubing Grade: L-80 Packers and SSSV MD (ft): 9170' Tubing MD (ft): 9291' 12. Attachments: !HI Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: o BOP Sketch 13. Well Class after proposed work: ,/ o Exploratory IBI Development 0 Service 16. Verbal Approval: Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name pave Wesley Title Senior Drilling Engineer /ltt't' ¿'0~;í Phone 564-5153 '" Commission Use Only October 18, 2005 Date: 15. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ IBI Abandoned o WDSPL Contact Ken Allen, 564-4366 . J '._ Prepared By Name/Number: Datel (1/1 zl(;~) Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity [!('BOP Test 0 Location Clearari(;ANNEtJ NOV Ð 3 2005 Sundry Number: ~5- tc r ~ (c-h '~iL /;v.lt( ê. - Ci ~ IS · \ r\!^ ,- COMMISSIONER e e Obp G~JJJr.ArAiT To: Winton Aubert - AOGCC Date: October 12, 2005 From: Ken Allen - BPXA GPB Rotary Drilling Subject: C-03A Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well C-03A. This conventional well is currently shut-in due to tubing by inner annulus communication. A subsequent caliper was run and indicated the need to replace the tubing. The wellbore is providing no production or value to the field as it currently sits. Well C-03A was a Coil tubing sidetrack drilled in October 1998 and completed as a Zone 1 well. By December 2002 production had dropped and additional perforations were shot in the heel of the well. By May 2004 production was back down with - 4~00 GOR. Once the T x IA communication was discovered and the resulting caliper indicated a need to replace the tubing a rotary sidetrack target was developed. The plan is to exit the parent C-03A wellbore just above the top of the LCU by milling a 8-1/2" window in the current 9-5/8" liner. The 8-1/2" well bore will drop and turn to the Top Sag River formation were a 7" drilling liner will be set and cemented. The 6-1/8" well bore then builds to horizontal and turns to the Southwest landing at 8,959' ssTVD (Zone 1 A). The planned well then runs horizontally to the west in a corridor between faults, rising gradually through Zone 1 A sands and flattening out to follow the basal Zone 1 B sand over the last 800 feet of the well. A solid 4- ........-- 1/2" liner will be cemented in place throughout the production interval. The C-03B sidetrack is currently scheduled for Nabors 2ES beginning around 10/31/05, after completing the C-10A sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Pre-Ria Work: 1. Bleed OOA, OA, IA & TBG to zero psi. PPPOT - OC (13-3/8") 1,500 psi (If test fails then monitor test port while testing OA), PPPOT - IA (11-3/4" x 9-5/8" thermo Casing) 2,400 psi. ~ Test tubing hanger seals to 5000 psi. Function all lock-down screws. Repair or replace as. needed (8 known to need repair on 9-5/8"). 2. Pressure test OOA (18-5/8" x 13-3/8") to 500 psi for 30 minutes. Pressure test the OA (13- 3/8" x 9-5/8 Thermo casing) to 500 psi for 30 minutes. Pressure test T X IA to 3,500 psi for 30 r minutes. Attempt to verify / isolate source of "bubbing" into the cellar noted in May 2004. 3. Rig up slickline. Pull XX plug at 9,217' set on 6/4/05. Drift 5-1/2" x 4-1/2" tubing to the top of the 3.75" deployment sleeve. Drift 2-7/8" liner as deep as possible recording depth. 4. Fluid pack the tubing and inner annulus. 5. P&A perfs in 2-7/8" liner from t top\of the PBTD (-12,072') to 9,100' in the 5-1/2" tubing. RIH with coil to PBTD. Lay i 21.5 bls of cement to -8,993' MD and squeeze -2.5 BBLS into perforations. Wash dow onfirm TOC @ -9,100'. POH with coil. C-03A Application for Sundry e e a. Cement Calculations: · 2-7/8" liner = 12,072'- 9,219' or 2,853' (-16.5 BBLS) · 4-1/2" tubing = 9,219' - 9,180' or 39' (-0.6 BBLS) . 5-1/2" tubing = 9,180' - 9,100' or 80' (-1.9 BBLS) . 2.5 BBLS (-107') for sq=e · Total cement volume of l1-.0 LS 6. Rig up slickline, drift 5-1/2" tubing. ··OC. 7. Chemical cut the 5-1/2",17#, L-80 tubing in the middle of a joint at - 8,800' MD. .~ 8. Pressure test T X IA to 3,500 psi for 30 minutes after cement P&A. 9. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to -2,200'. 10. Bleed all casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 11. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to §>eawater. Set TWC. r- 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. /' 4. RU. Pull the 5-1/2" tubing from the pre-rig Chemical cut -8,800'. Spool up SSSV control lines. 5. MU 8.5" casing scraper. RIH picking up 4" DP to tubing stub at -8,800'. POOH. 6. RU e-line. Run Gauge Ring / Junk basket and Gamma Ray tool for 9-5/8",47# casing with '--. CCL to tubing stub - 8,800'. POOH 7. RIH with 9-5/8" EZSV on e-line. Set EZSV at -8,620' to avoid cutting a casing collar during window milling operations. POOH and RD e-line. 8. PU a 9-5/8" RTTS. RIH and set RTTS at 2,1 OO'md and test the 9-5/8" casing to the lower .-- bridge plug to 3,500 psi for 30 minutes. Chase down leak if present. Record test. POH and LD RTTS. 9. RIH with 9-5/8" Fas Drill on 4" DP. Set plug at -2,065' (below liner top packer, above FO Cementer). 10. MU casing spear and pull 9-5/8" x 11-3/4" thermo coasing, 10-3/4" casing and 9-5/8" seal /' stem at 2,043' md. Send seal assembly to Backer for redessing seals and machining ports. 11. Close the annular and circulate the arctic pack from the 9-5/8" x 13-3/8" annulus with warm diesel. Note: Be prepared for possible trapped gas entrained in the Arctic Pack. -¥;:- 12. POOH and LD Thermo Casing, 10-3/4" casing and 9-5/8" casing. 13. RIH with a 9-5/8" polish mill and 13-3/8" casing scraper to the BOT tieback seal assembly. CBU and displace to clean sea water. 14. ND BOP stack and Unihead spool. Change the 13;3/8" packoff and test. 15. NU 2-step casing spool and BOP. lest BOP. r- 16. Close blind rams and test 13-3/8" casing to 3,000 psi. MU 13-3/8" RTTS and isolate leak, if necessary. 17. RIH with 9-5/8" casing and old 9-5/8" seal assembly with ports between seals 1 & 2. 18. Cement 9-5/8" x 13-3/8" annulus to surface. 19. Break BOP stack and set emergency slips. Rough cut 9-5/8" casing. 20. ND BOP stack. Dress off casing stub and set pack-off. NU tubing spool and BOP stack. 21. Test 9-5/8" packoff and BOPE. Test casing to 3,500 psi. 22. MU 8.5" mill with an 8.5" string mill. RIH to float collar & test 9-5/8" to 3500 psi. Drill out float _ equipment and 9-5/8" Fas Drill plug. 23. Continue running in the hole picking up 4" DP to the 9-5/8" EZSV -8,620'. Circulate wellbore clean with seawater. ....-J ' . 24. -5 8 whipstock and bottom trip anchor with an 8-1/2" window milling assembly. RIH on . [~L;) \ C - 40) 4" DP to EZSV. Orient and set the whipstock. Swap well over to 10.2 ppg milling fluid. /.U) y tv U C\..(, 25. Mill a window in the 9-5/8" casing at ±8,600' MD plus 20' of formation from mid window. Note: - -, Verify that the mud weight is 10.2 ppg prior to cutting the window. / ' 26. Perform FIT to 12.0 ppg. POOH for Drilling BHA. C-03A Application for Sundry e e 27. MU the 8-1/2" drilling assembly with DIR/GR/RES and RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the Top Sag River. CBU, short trip to window and back to TD, circulate well clean and POOH. 28. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to -8,450' MD. Set hanger /liner top packer and displace cement with mud. POOH. 29. Test the 9-5/8" x 7" liner to 3,500 psi for 30 minutes if sufficient compressive strength has been achieved. Record the test. 30. MU 6-1/8" BHA with DIR/GR/RES/ABI and RIH to the 7" landing collar. Test casing if not previously done. 31. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 10.0 ppg. 32. Drill ahead building to horizontal landing point. POOH for bit & BHA change. 33. MU 6-1/8" BHA with DIR/GR/RES/DEN/NEU/ABI. RIH and MAD pass build section. Drill ahead in the horizontal as per plan to an estimated TD of 11,570'. 34. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 35. Run and cement a 4-1/2", 11.6#, L-80 LTC liner throughout the 6-1/8" wellbore and 150' back into the 7" drilling liner to -9,241' MD. Set liner top packer and displace well to clean seawater above the liner top. NOTE: A perf pill will be left in the 4-1/2" liner. 36. RIH with DPC perf guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns. 37. Run the 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. 38. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 39. Set and test TWC. 40. ND BOPE. NU and test the tree to 5,000 psi. 41. Freeze protect the IA and Tubing to -2,200' and secure the well. 42. RDMO. Post-RiQ Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-Rig Start: Estimated Spud Date: 10/1 8/05 10/31/05 Ken Allen Operations Drilling Engineer 907.564.4366 C-03A Application for Sundry TREE = W¡;:LLHEAD = ACTUATOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = Datum rvD = e 118-5/8" CSG, ??#, ???, ID = ????" I 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.372" @ 9223' TOP OF 2-7/8" LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I TOP OF 7" LNR (40' BOT PBR) I 9218' 3.75" DEPLOYMENT SL V, ID = 3.00" I TOPOF2-7/8" LNR, ID = 2.37" I 14-1/2" TBG,12.6#, L-80, .0152bpf, ID = 3.958" 9-5/8" LNR, 47#, N-80, .0732 bpf, ID = 8.681" PERFORATION SUMMARY REF LOG: GRlCNL ON 10/13/98 ANGLE AT TOP PERF: 82 @ 10200' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 10200 - 10225 0 12/26/02 2" 6 10307 - 10332 0 12/26/02 2" 6 10340 - 10365 0 12/26/02 2" 6 10398 - 10423 0 12/26/02 1-2/3" 4 10800 - 10980 0 10/14/98 1-2/3" 4 11100 - 11300 0 10/14/98 1-2/3" 4 11470 - 11570 0 10/14/98 1-2/3" 4 11690-11840 0 10/14/98 1-2/3" 4 11890 - 11920 0 10/14/98 1-2/3" 4 11960 - 12070 0 10/14/98 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" I 10250' C-03A sAY NOTES: WELL EXCEEDS 70° @ 10130' & GCIIHORlZONTAL@ 10614'. 142' -l 11-3/4" X 9-5/8" THERMOCASE III NOTE: 9-5/8" CSG HAS FCC'S AT 1993', 2074' & 4303' 10-3/4" X 9-5/8" XO I 9-5/8" SEAL ASSY I NOTE: 13-3/8" CSG HAS FCC'S AT 2138' & 2332' 13-3/8" X 9-5/8" BOT A<R / LNR HGR 5-1/2" SSSV OTIS LANDING NIP, ID = 4.562" GAS LIFT MANDRB.S TYÆ VLV LATCH OTIS LBD DMY RM OTIS LBD DMY RM OTIS LBD DMY RM OTIS LBD DMY RA OTIS LBD DMY RA ST MD rvD 5 3023 2968 4 5786 5282 3 8119 7228 2 8808 7814 1 8990 7964 I I 9097' 9155' 9170' 9180' 9217' 9256' 9292' 9279' DEV 9 37 31 33 34 PORT DATE o 05/17/04 o 05/17/04 o 05/17/04 o 10/15/98 o 10/15/98 5-1/2" OTIS SLIDING SLV, ID - 4.562" I 5-1/2" SEAL ASSY I 9-518" X5-1/2" GUIB PKR, ID = 4.75" I ,.- 5-1/2" X4-1/2" XC, ID = 3.892" I 1/ 4-1/2" OTIS XNIP, ID = 3.813" 4-1/2" OTIS)G\ NIP, ID = 3.725" 1 4-1/2" TBG TAIL ID = 3.958" I ELMD 1T LOG NOT AVAILABLE I SIDETRACK WINDOW @ 9843' - 9849' TOP OF WHIPSTOCK @ 9840' RA TAG @ 9849' 2-7/8" LNR, 6.16#, STL, .0058 bpf, ID = 2.37" I DATE REV BY COMMENTS 09/14/03 CMOITLP DATUM MD & PERF ANGLE 05/17/04 KSB/KAK GLV C/O 10/10/04 JLAITLH CSG CORRECTION DATE REV BY 03126/73 10/05/87 10/14/98 07/27/01 CHIKAK 12/26/02 DV / 04/05/03 KAK COMM3\ITS ORIGINAL COM PLETION RWO CTD SIDETRACK (C-03A) CORRECTIONS ADD PERFS CLEANUP PRUDHOE BA Y UNIT WB.L: C-03A PERMIT No: 1981840 AA No: 50-029-20124-01 SEC 19, T11N, R14E, 1316' SNL & 879' WB. BP Exploration (Alaska) C 38 Proposed S FOC'S AT 21 38' & 2332' Cemented 9-5/8" x 13-3/8" Annulus 18-5/8" CSG, 11#, 7??, ID'" 7 CBL Shows Bonding 8400' - 9749'- PERFORATION SUM!Ii1ARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for his TOP OF FISH I chern cut PRUDHOE SAY UNIT WElL: C-03B PERMIT No: 1981840 API No: 50-029-20124-02 SEe 19, T11N, R14E, 1316' SNL & 879' WEl BP exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERES Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1316' FNL, 879' EEL, Sec. 19, T11N, R14E, UM At top of productive interval 4777' FNL, 3192' EEL, Sec. 17, T11N, R14E, UM At effective depth 3932' FNL, 1358' EEL, Sec. 17, T11N, R14E, UM At total depth 3852' FNL, 1349' EEL, Sec. 17, T11N, R14E, UM 5. Type of Well: Development _X Explorato~._ Stratigraphic__ Service__ (asp's 664500, 5959906) (asp's 667419, 5961789) (asp's 669231, 5962675) (asp's 669238, 5962756) 6. Datum elevation (DF or KB feet) RKB 54 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number C-03A 9. Permitnumber/approvalnumber 198-184 10. APInumber 50-029-20124-01 11. F~eld / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 99' 20" Surface 2505' 18-5/8" Surface 4312' 13-3/8" Intermediate 9730' 9-5/8" Liner 625' 7" Sidetrack Liner 2934' 2-7/8" Perforation depth: 12153fe~ 8935 fe~ 12072 fe~ 8935 ~ Plugs (measured) Junk (measured) Cemented Measured Depth True Ve~icalDepth 118' 118' 4700 sx 2524' 2524' 1210 sx 4331' 4180' 3030 sx 9749' 8671' 155 sx 9218'-9843' 8211'-8753' 126 cf Class'G' 9219'-12153' 8212'-8935' measured Open Peds 10200'-10225',10305'-10330',10340'-1-365',10398'-10423',10800'-10980', 11100'-11300',11470'-11570',11690'-11840',11890'-11920',11960'-12070'. true vertical Open Perfs 8967'-8970', 8975'-8976', 8976'-8978', 8980'-8982', 8929-8920, Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 8917-8909, 8904-8891, 8887-8888, 8888-8889, 8887-8880 5-1/2" 17# L-80 TBG @ 9180'. 9-5/8" x 5-1/2" GUIB Packer @ 9170' MD. 5-1/2" Otis SSSV Landing Nipple @ 2131' 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 11/03/02 Subsequent to operation 01/01/03 Representative Daily Averaqe Production orlniection Data OiI-Bbl Gas-Mcf Wate>Bbl 563 19216 7 1302 14087 15 Casing Pressure Tubing Pressure 645 658 15. Attachments Copies of Logs and Surveys run __ Dady Report of Well Operations __ 17. I hereby certify that the foregoing is true and correct to the best of my know. Ledge. ,~ .,'~.~..2 .~t~~ Title: Technical Ass,stent DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · RBDMS BFL , '.-': ' 16. Status of well classification as: Oil__X G as __ ~;~, j~l~t~ _~.~. !~ Date January 16, 2003 Prepared by DeWar/ne R. Schnorr 564-5174 SUBMIT IN DUPLICATE ~ C-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/18/2002 12/20/2002 12/24/2002 12/25/2002 12/26/2002 01/01/2003 01/O3/2003 PERFORATING: DRIFT/TAG PERFORATING: AC-FLUID LEVEL PERFORATING: JEWELRY LOG--DEPTH CONTROL; PERFORATING PERFORATING: JEWELRY LOG--DEPTH CONTROL; PERFORATING PERFORATING: PERFORATING TESTEVENT --- BOPD: 1,302, BWPD: 15, MCFPD: 14,087, AL Rate: 0 ANN-COMM (AC-EVAL AND REPAIR): AC-MONITOR EVENT SUMMARY 11/18/02 DRIFT TBG W/2" DUMMY GUN DOWN TO 10,159' SLM. HAW. TURN WELL OVER TO DSO, LEFT WELL SHUT IN. 12/20/02 T/I/0=SI/1500/1000 (500 PSI + CA) CA FL NEAR SURFACE. 12/24/02 MIRU CTU#5. MU WELDED CONNECTOR, PULL TEST. 12/25/02 KILL WELL W/100 BBL CRUDE + 80 BBL 2%KCL. RIH W/GR/CCL. LOG INTERVAL 10650'-9750'. FLAG @ 10250'. POOH. RIH & PERFORATE 10423'- 10398'. MU/RIH W/GUN #2. 12/26/02 SHOOT GUN #2 FROM 10340'-10365'. POOH. GUN # 2 DID NOT FIRE. RETRIEVED BALL FROM BALL DROP LAUNCHER. RE-MAKE GUN #2. SHOOT GUN #2 FROM 10340'-10365'. FP COIL. POOH. WELD ON NEW CTC. RIH & SHOOT GUN # 3 FROM 10307'-10332'. POOH. RIH W/GUN # 4 & SHOOT FROM 10200'-10225'. POOH. WELL FREEZE PROTECTED TO 2000' W/METH/WTR. RDMO. 01/01/03 TESTEVENT --- BOPD: 1,302, BWPD: 15, MCFPD: 14,087, AL Rate: 0 01/03/03 T/I/O=1000/1120/1020 TEMP = WARM MONITOR WHP's (POST CA BLEED) PAD OP HAD BLED CA FROM 1300 PSI TO 800 PSI ON 01/01/2003. Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) 324 METHANOL WATER 100 CRUDE 111 2% KCL WATER 535 TOTAL SCANNED FEB 0 4 2003 Page I C-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/25 - 26/2002 ADD PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING 2-1/8" POWER ENERJET SPIRAL GUNS, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 10200'-10225' 10307'-10332' 10340'-10365' 10398'-10423' SC~.NNED FEE) 0 4 2803 Page 2 TREE = 6" CIW WELLHEAD = McEVOY SAFETY NOTES: WELL EXCEEDS 70 deg C 03A ACTUATOR: OTIS 10130' & GOES HORIZONTAL @ 10614'. KB. ELEV = 54.46' BF. ELEV = 35.16' K~P--Max Angle-- 97 ~ 1~-?'1518. ";I ~--t 142. H 11-3/4"X9'S/8"THERMOCASE"I Datum MD = 10038' Datum 7VD = 8800' SS I 10-3,4.. CSG, 55.,#, K-55,'D= 9.760" H 1951' I-- if ti----I 205" H 10-3/4"X 9-5/8"xoI I TOPOF9-5'8"LNRH 2043' ~--- ~ 20~' H O-5/8"SEALASSY I I13*3,8"XO*5,O"SOT~R,LNRHGR Id 2059' I- i t 2~:,' H 5-1'2"SSSVOT~SLANDINGNIP'ID:4'562"I AT 1993', 2074' & 4303' ' ' ' ' GAS LIFT MANDRELS I13-3/8''cSG'72#'L-80,D=12.347" Id 4331' ~J ~'~__ ~k 83'MD:TVD DEV TYPE VLV LATCH PORT DATE __--~- 3023 29---~ 9 OTIS LBD DOME RA 16/64- 10/15/98 I 4 5786 5282 37 OTIS LBD SO RA 20/64 10/15/98 NOTE' 13-3/8" CSG HAS FOC'S AT 2138' & 2332' 3 8119 7228 31 OTIS LBD DV RA 0 10/15/98 2 8808 7814 33 OTIS LBD DV RA 0 10/15/98 Minimum ID = 2.372" @ 9223' 1 8990 7964 34 OTIS LBD DV RA 0 10/15/98 TOP OF 2-7/8" LINER I5-1,2.'TBG,17#,L-8°, -I 9155. lTi- 9o9,. 5'1/2"OTISSUDINGSLV. ID'4.562"I 00232bpf, D:4.892" --1 9155' I--I 5-1/2"SEALASSY I s~ sz--t 9170' I-I 9'5/8"XS'l/2"GUIBPKR'ID=4'75"I ' t 918o' I-I 5-1'2"X*l'2"x°"D;3892" I ITOPOF7"L,NE~ (40'BOTPBR)I-I 9218' ~--'""'--~ I I--~---t 9217' I-I 4'l/2"O-nSXN'P'ID:3'813" I I 3'75"DEPLOYMENTSLV,ID=3'00'' H 9219' ~.~----, ITOPOF27'8"L"~,'D:2.37"H 9223' ~---[--I--'--t 9256' I--I 4'1/2"OTISXUN'P"D:3'725"I 4-1/2"TSG,12.6#,L-80,.0152bpf,,D=3.958"I--~ 9291' h--' .... t 9292' I-I 4'1/2"TBGTALID:3'958" I SIDETRACK WINDOW @ 9843' - 9849' I PERFORATION SUMMARY TOP OF WHIPSTOCK @ 9840' REF LOG: GR/CNL 10/13/98 RA TAG @ 9849' ANGLE ATTOP PERF: 92 @ 10800' Note: Refer to Production DB for histo,cal perf data 817~= SPF INTERVAL Opn/Sqz DATE 2" 6 10200- 10225 : O 12/26/02 2" 6 10307- 10332 O 12/26/02 i 2" 6 10340- 10365 I O 12/26/02 2" 6 10398- 10423 O 12/26/02 1-2/3" 4 i 10800-10980 O 10/14/98 1-2/3" , 4 11100-11300 O 10/14/98 1-2/3" 4 11470-11570 O 10/14/98 1-2/3" 4 11690 -11840 O 10/14/98 1-2/3" 4 11890 -11920 O 10/14/98 1-2/3" 4 11980 -12070 O 16/14/98 7" LNR, 29#, N-80, 0 0371 bPf, ,D: 6.164"H 10250' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/26/73 ORIGINAL COMPLETION 12/26/02 DV/DM/TP~ADD PERFS WELL: C-03A 10/05/87 RWO PERMIT NO: 1981840 10/14/98 CTD SIDETRACK APl No: 50-029-20124-01 02/05/01 SlS-lsl CONVERTED TO CANVAS SEC 19, T11N, R14E, 1316' SNL & 87ff WEL 03/01/01 SIS-MD FINAL 07/27/01 CH/KAK CORRECTIONS BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: GR/CNL 10/13/98 ANGLE ATTOP PERF: 92 @ 10800' Note: Refer to Production DB for historical per[data SI7~: SPF INTERVAL Opn/Sqz DATE 2" 6 10200- 10225 O 12/26/02 2" 6 10307- 10332 O 12/26/02 2" 6 10340- 10365 O 12/26/02 2" 6 10398- 10423 O 12/26/02 1-2/3" 4 10800 -10980 O 10/14/98 1-2/3" 4 11100-11300 O 10/14/98 1-2/3" 4 11470-11570 O 10/14/98 1-2/3" 4 11690 -11840 O 10/14/98 1-2/3" 4 11890 -11920 O 10/14/98 1-2/3" 4 11980 -12070 O 16/14/98 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, ~. I. Supo~isor DATE: April 23, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit C Pad Monday, A~)ril 23, 2001.; I traveled to BPXs C Pad and witnessed a portion:of the 30-day retest of the safety valve systems. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 wells and 22 components with 1 failure. The Surface Safety Valve on well C-20B failed to pressure test. This valve is a repeat failure from the previous test. An attempt was made at this time to service the valve but the subsequent retest also failed. This well was shut in until repairs could be completed. I departed location prior to completion of the testing on this Pad due to a required BOP test on Nabors Rig 9ES. I spoke with Merv Liddelow on the morning of 4-24-01 and he indicated there were no further failures on remainder of the wells tested. Merv Liddelow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. Summary: I witnessed a potion of 30-day SVS testing at BPXs C-Pad. PBU C Pad, 11 wells, 22 components, 1 failure 4.55% failure rate on the witnessed portion of the pad. Attachment: SVS PBU C Pad 4-23-01 CS . X. Unclassified Confidential (Unclassified if doc. removed ) SVS PBU C Pad 4-23-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Field/Unit/Pad: Prudhoe / PBU / C Pad Separator psi: LPS 174 Date: 4/23/01 HPS 644 Weft Permit Separ Set L/P Test Test Test Date off, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-O1 1720300 , C-02 1730040 C-03A 1981840 644 550 500 P P OIL C-04A 1960920 , C-05 1730110 174 125 100 P P OIL C-06A 19815701 ,,, C-07A 2000520' 644 550 520 P P OIL ~-08A 1950280! 174 125 120 P P ' OIL :C-09 1790260: - C'10 1790350! C-11 1790460 C-12A 1981160 , C-13A 1971430 C-15 1791090 C-16 1800100 , C-17A 1980230 , , C-18A 1991290 C-19B '2000050 644 550! 525 P e 0IL C-20B 2001140 174 125 110 p '-4..;-.~i~ OIL C-21 1820810 174 125 115 P P OIL C-22 1820880 644~ 550 550 P P OIL C-23A 1961190 C-24 1821410 644! 550 525 P P 0IL , C-25A 1950110 6441 550 475 P P OIL C-26A 1981450 C-27A 1961390 C-28 1821950 C'29A 1961700 C-30 1871360 C-31A 1950060 C-33 1930770 C-34 1880150 RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 4-23-01 CS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI ,Trip Code Code Code Pas.sed .... GAp,. o.r C-35A 1952000 C_36A " 2000050 ...... ~-37 1930550 " , ' . ..... C-38 1860660 C-39 1936~40 6~4 550' 500' e ' "e .... OIL C-41 1930990 ~2-42 1930500 .... Wells: 11 Components: 22 Failures: 1 Failure Rate: 4.55% Remarks: Surface Safety Valve on Well C-20B failed when pressure tested. Retest al~er valve x~ serviced also failed, well was shut in pending repairs. . ........ Tlfis, is a partia! pad test. , , , r i RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 4-23-01 CS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser,~',~'- Commissioner Tom Maunder, P. I. Supervisor DATE: April 23, 2001 FROM' Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit C Pad Monday. ADd! 23, 2001' I traveled to BPXs C Pad and witnessed a portion of the 30-day retest of the safety valve systems. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 wells and 22 components with 1 failure. The Surface Safety Valve on well C-20B failed to pressure test. This vane is a repeat failure from the previous test. An attempt was made at this time to serVice the valve but the subsequent retest also failed. This well was shut in until repairs could be completed. I departed location prior to completion of the testing on this Pad due to a required BOP test on Nabors Rig 9ES. I spoke with Merv Liddelow on the morning of 4-24-01 and he indicated there were no further failures on remainder of the wells tested. MerV Liddelow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. $.u. mmary; I witnessed a potion of 30-day SVS testing at BPXs C-Pad. PBU C Pad, 11 wells, 22 components, 1 failure 4.55% failure rate on the witnessed portion of the pad. A. ttachment_: SVS PBU C Pad 4-23-01 CS X Unclassified Confidential (Unclassified if doc. removed ) SVS PBU C Pad 4-23-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: ' QhUck Scheve Date: FieldfUnit/Pad: Prudhoe / PBU / C Pad Separator psi: LPS 174 HPS 4/23/01 644 We~ Permit Separ Set L/P Test Test Test Date oa, WAG, G/NJ, Number Number PSI PSI Trip .. Code Code Code Passed .GAS or CYCL~ C-01 1720300 C-02 1730040i C-03A ' 1981840: 644 550 ..... 500"P P .... OIL C-04A 1960920 C-0~' 1730110 " 1~4 125 100 'P' e '' oIL C206A 1981570! .......... C-07A 2000520 644 550 520 P P OIL C-08A 1950280 174 " 125 120 P P " ' OIL C-09 1790260 ~_10 '' 1790350 ............ !C-11 1790460 ,C-12A 1981160 C-13A 1971430 ........... ,. , , C-15 1791090 c. 6' 8oo oo ........ c-17A "1980230 ..... ~}lSA 1991290 ......... C-10B 2000050 644 " ~50! 555 ''P e 0IL .... , C-20B 2001140 '174 125 110 P 4 OIL ,, C-21 1820810 174 1251 115 P P OIL , ,. C_22 1820880 644 550 550 P P oIL , , , , C-23A 1961190 C-24 ..... 1821410 644 '550 525 P ' e oil c-25~ 1950110 '~ 644 550 475 P P "' , , , ....... C-26A 1981450 -, .... C-27A "1961390 .,,, C-28 1821950 C-29A 1'9~1700 ....... c-30 'i8~1360 ........ , C-31A 1950060 ....... t ,. I C-33 1930770 c-34 88o15o , , ., ,, ,, RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 4-23-01 CS : · : : _' · i :i:; : :I~ '~!::~7 ' ~ ;: ~=I~ ?;~.~.-:i--':~ ~?. '~-~E~:-; :~9~[-~::I:-~c'~:~-~-'~':?~'~: ': 'ii .... i-~-.Fi~ ...... ii~ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Tri'P, Code Code Code Passed GAS or CYCLE C-35A 1952000' C-36A 2000020 , C-37 1930550 C-38 1860660 'C-39 1930940 644 550 500 ' "i~'' P ......... OIL C-41 1930990 C-42 1930500 ~ ,, Wells: 11 Components: 22 Failures: 1 Failure Rate: 4.55% [] 90 Day Remarks: Surface Safe,ty Valve on Well C-20B failed when pressure tested. Retest after valve serviced also failed, well was shut in pending repairs. Thi~., is a p .ar~,ial pad test. RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 4-23-01 CS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~, ~,~/~\ DATE: Commissioner Tom Maunder, ~ P. I. Supervisor o~lo%-C~ t, THRU: March 23, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests PBF/PBU C:Pad .M. ar.ch 23, 2001: I traveled to PrudhOe Bay Field to witneSs Safety Valve System tests on BPX's C Pad. Well house inspections were also conducted. Merv Liddelow was the BPX representative in charge of testing, and performed the tests in a professional manner. Twenty-one wells on C-Pad were tested with five failures witnessed. The SSV on well C-04A tripped below 50% of the separator psi, the SSV on well C-07^ failed to hold D/P, the pilot on well C-19B was frozen, the pilot on well C-20B failed to trip and the SSV failed to hold D/P. Mr. Liddelow indicated to me that ali failures were repaired within 24 hours. I inspected 21 well houses and noted leaking wing valves on wells C-03A, C-13A and C-19B. A hydraulic fluid leak on the SSV control line of well C-05 and a slight crude oil leak from the SSV on well C-25A were also noted. Mr. Liddel°w indicated he would have these items corrected. The AOGCC test forms are attached for reference. SUMMARY: I witnessed the SVs tests on twenty-one oil producing wells on C Pad in the Prudhoe Bay Field. 21 wells tested 42 components, 5 failures witneSSed, and 11.9% failure rate. 21 well houses inspected. Attachments' SVS PBU C-Pad 3-23-01 JJ ,.cc; SVS PBU C Pad 3-23-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/C Pad Separator psi: LPS 174 Date: 3/23/01 HPS 662 WeB Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed , ~AS or CYCLE C-01 1720300 , C-02 " 17'30040 662 550 525 'P p OIL C-03A' t 1981840 ' 662 550 530 'p P ' OIL C-04A 1960920 '662 ~50 220 3 p OIL C-05 17301i0' i74 125 115 p ' p " OIL , , C-06A 1981'570 662 550 580 P P OIL , C-07A 2000520 662 550 545 P 4 OIL C-08A 1950280 , , C-09 1790260 ,, C-10 1790350 · C-II '1790460 662 550 595 p P OIL C-12A 1981160 C-13A 1971430 662 '5'50 590' P P 'O!~ , C-15 1791090 C-16 1800100 C-17A 1980230 662! 550i '580' P P ...... 0~ :C-18A 1991290 C-19B 2000050 662 550 250! 5 ' p ' ' , OIL , iC-20B 2001140 662 550 0 1 4 OIL C'21 1820810 174 " 125' 120 p P , OIL C-22 1820880! 662 550 560 p p OIL C'23A 19611901 C-24 1821410 662 '550 545 'p P ' '' QIL C-25A 1950110' 662 " 550 510 P P , OIL ,, C-26A 1981450 ,, , . C-27A 1961390 , ,. C-28 1821950 , , , C-29A 1961700 C-30 ' 1871360 662 550 525 P e OiL , C-31A 1950060 662 550 560 p P Oil C-33 1930770 C'34 1880150 C-35A 195~000 174 i2b 120 "p p OIL C-36A 2000020 174 125 115 P P ,0I[ , RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 3-23-01 JJ1 Well Permit Separ Set LfP Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code ,C°de Passed ,,GASorCY.,CLE C-37 19305501 '662 550 550 P P OIL C-38 1860660 C-39 1930940 , C-41 1930990 C-42 1930500 662 ' 550 590 'P e ' ' OIL , , Wells: 21 Components: 42 Failures: 5 Failure Rate: 11.90gJ~] 90 Day 0p,erator reports all failures repaired and passed retest. Remarks: .! RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 3-23-01 JJ1 Well Compliance Report File on Left side of folder 198-184-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD 12153 TVD 08880 Completion Date: C-03A 50- 029-20124-01 Start Stop 10/14/98 Completed Status: 1-OIL BP EXPLORATION (ALASKa) lNG Current: Name Interval D 9118 1 SPERRY GR OH L MCNL FINAL 9670-12072 CH 2 L NGP-MD FINAL 9849-12153 OH L NGP-TVD FINAL 8707-8880 OH T 8945 1 SCHLUM MCNL CH Daily Well Ops __ -- __ Are Dry Ditch Samples Required? yes Was the well cored? yes no Analysis Description Received? yes no Comments: Sent Received T/C/I) 3/30/99 3/30/99 11/30/98 12/3/98 T 3/30/99 3/30/99 3/30/99 3/30/99 11/30/98 12/3/98 no And Received? yes no Sample Set/4 Wednesday, November 08, 2000 Page 1 of 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3 001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs C-03A March 30, 1999 AK-MW-80398 1 LDWG formatted Disc with verification listing. API#: 50-029-20124-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIlgS OF THE TRANSM1TYAL LETYER TO TltE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. ~ .~c~ [~&laska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signe 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company To,' WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs C-03A, AK-MW-80398 March 30, 1999 C-03A: 2"x 5" MD Gamma Ray Logs: 50-029-20124-01 1 Blueline 1 Rolled Sepia 2"x 5" TVD Gamma Ray Logs: 50-029-20124-01 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE AI'rACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATYENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMNh¢,~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG CT Sidetrack well 1. Status of Well Classification of Service Well C~ Oil i--] Gas I--] Suspended I--I Abandoned E~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 98-184 3. Address 8. APl Number P.O. Box196612, Anchorage, Alaska 99519-6612 ~- 50-029-20124-01 4. Location of well at surface ~-;~'~-'~:~:'~ 9. Unit or Lease Name 1316' SNL, 879' WEL, Sec. 19, T11N, R14E, UPM.;!~'~"~:";"-Z~-///:'_/_~/ ~'~:~';"~;'~':~_'~3 ~ Prudhoe Bay Unit At top of productive interval .. ._..:~~. 10. Well Number 503' NSL, 2088' EWL, Sec. 17, T11N, R14E, UPM ~'~-~:~, .' ¢~, ~.--r~_-.-~- ,,~ C-03A At total depth .¢ ¢ 11 Field and Pool 3851' SNL, 1348 WEL, Sec. 17, T11N, R14E ....... 7: ':;~.-T~ ........... ' Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 54.46I ADL 028305 12. Date Spudded10/6/98 113' Date T'D' Reached ! 14' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re 116' N°' °f C°mploti°nsl 0/12/08 10/14/08 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)119. Directional SurveyI 20. Depth where SSSV set[21. Thickness of Permafrost 12153 8880 FT 12,086 8879 FTI [~Yes [] No I 2131 MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run GR CNL 23. CASING~ LINER AND CEMENTING RECORD CASING ,~E'FrlNC~ DEPTH HOLE S~ZE WT. PER FT. GRADE TOP BO'FrOM SiZE CEMENTING RECORD AMOUNT PULLED 2 7/8" 6.16# L-80 9218 12,153 3-3/4" 126 c.f. 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) MD TVD 10,800-10,980 8929-8920 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11,100-11,300 8917-8909 11,470-11,570 8904-8891 DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED 11,690-11,840 8887-8888 11,890-11,920 8888-8889 ¢'~ !'~ I f'~ I i~ I /~ i 11,960-12,070 8887-8880 U fl Ita i!X!/& L · 27. PRODUCTION TEST 3ate First Production IMethod of Operation (Flowing, gas lift, etc.) Oct 18,1998 I Flowing Date of Test Hours Tested PRODUCTION OIL-BBL iGAS-MCF WATER-BBL CHOKE S~IZEI]GAS-OIL RATIO FOR TEST Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) · Press. ~_4-HouR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Na$,~ Oil & 8as Cons. Anchor~r/~ Form 10-407 Rev. 07-01-80 Sub'mit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. TZ2 98O0 8661 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby c~a~/~o~rue and correct to the best of my knowledge Signed Prepared By Name/Number: Theresa Mills 564-5894 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 TREE: 6" CAMERON WELLHEAD: McEVOY ACTUATOR: OTIS 20" SHOE J 80' 1 1/4" Tubing J 10-3/4, 55~, N-80, BTRS Bottom 10 3/4, 55#, N-80 9 5/8 FOC TOP 9-5/8" LINER 9 5/8 Bottom Seal Ass'y 9 5/8 FOC 13 3/8 FOC 13 3/8 FOC 18-5/8" SHOE 9 5/8 FOC 13-3/8", 72~ SHOE ,951' 1,993' ,043' ,054' 2,074' 2,138' 2,332' ,524' 4,303' ,331' KOP: 2700' MAX ANGLE: 43 DEG @ 4300' 5-1/2", 17#/ft, L-80, TUBING ID: 4.892" CAPACITY: 0.0232BBL/FT TOP OF 7" I 9,218' TOP OF 2-7/8" LINER I 9,219' Min ID=2.372" 9-5/8", 47#/ft, N-80, BTRS I 9'749'1 "---' C-03a KB. ELEV = 54.46' BF. ELEV = 35.16' 9-5/8 X 11-3/4 I 142' THERMOCASE II 13-3/8", 68 / 72 #/FT SSSV LANDING NIPPLE I 2,131' ( OTIS X 4.562" ID) GAS LIFT MANDRELS ( OTIS LBD W/IRA LATCH NO MD(BKB) 'l'VDss 3023' 2968 5786' 5282 811'9' 7228 8808' 7814 8990' 7965 5-1/2" OTIS SLIDING SLEEVE (4.562" ID) 9-5/8 PACKER (GUIB)(4.75"ID) 4.5" 12.6# TAIL PIPE 4.5 ....X" NIPPLE ( OTIS ) ( 3.813" ID) 4.5 .... XN" NIPPLE 9,097'I 9,155'I I9'170'I 9'217'I 9,256' 9,292' 9,279' PERFORATION SUMMARY REF: LOG: GR/CNL 10/13/98 ISbze I SPF I InterVal ! Open/Sqz 1.691 4 I 10800-10980 Open 1.691 4 I 11100-11300 Open 1.691 4 I 11470-11570 open 1.69[ 4 I 11690-11840 Open ~.~1 44 I 11890-11920 Open 11960-12070 Open Abandoned Wellbore Cement was downsqueezed past 7" whipstock top at 9840' and tested. Original PBTD @ 10208' 7" 29#-/ft N-80 BTRS @ 10250' CTD HORIZONTAL SIDETRACK PBTD 2-7/8"6.16#L-80STL DATE REV. BY 10/5187 cJs 12,086' 12,153' COMMENTS RWO CT Sidetrack PRUDHOE BAY UNIT WELL:C-3a(17-11-14) APl NO: 50-029-20124-01 SEC 19 :Tll N · RGE 14E BP Exploration (Alaska) Well: C-03A Accept: 10~5~98 Field: Prudhoe Bay Spud: 10/6198 APl: 50-029-20124-01 Release: 10/15/98 Permit: 98-184 CTD Unit: Nordic #1 Date Day Depth 10/5/98 t Accept Rig: 13:30 hrs. 10/5/98. NU BOPE. Pressure test wavied by AOGCC. Grease Crew serviced SV. PT BOPE. PT Casing 1500 psi 30 min, (charted) OK, Installed Bakers CTC and Loaded CT with 63 bbl SW. PT OTC to 3000 psi. PU Widow Milling BHA. RIH. Tagged XN Nipple at 9280' CTM. Corrected back 37' to 9243'. Milling out XN nipple. 10/6/98 2 TIH and tagged up on XN Nipple and milled out. (1 stall). RIH and tagged top of 9743' Work at trying to cut window. Worked for 5 hrs and unable to mill 0.1'. Unable to get past 9843.6' POOH. Mill had broken cutright on the top side of the dimple mill, no wear on the face of the Dimple mill. Changed out mill and RIH Corrected at flag (46') RIH and tagged the WS at 9843' Unable to mill window. POOH and called for wireline to run TEL and 3.8 LIB with 3.8" TS. Mill #2 had broke cutright on the gauge and nothing on the cutting shoulder. RIH with WL. Located something at 9279' Tagged at 93t0' worked through, TIH, tagged the top of WS at 9843'. TIH with WL (3.5" LIB, TEL and 3.6" TS) to located TT better Located at 9279' and tagged the top of the WS at 9843'. POOH and RD WL, RU SWS to run Jewelry Log. All Jewelry in place. Logged to 10' from whipstock at 9840' POOH and RD Loggers. PU new Baker motor and dimple mill and TIH. 10/7/98 3 9853 TIH w/dimple mill. Had trouble getting mill started. Milled smoothly after getting started. Work thru window with and without pump-window smooth. POOH for Formation Mill Assembly. LD dimple mill. MU formation mill and string reamer. RIH w/BHA. Finish mill window and dress with string reamer to 9853'. Displace seawater to used FIo Pro mud. POOH for drilling BHA. LD milling BHA. Rehead CTC. PT 35K, 3500 psi. MU drilling BHA. RIH with drilling BHA #1 (0.8 deg motor). RIH thru window to TD and footage counters quit working-repair. Begin downtime at 0315 hrs 10/7/98. '10/8/98 4 t 0336 Repaired electrical counter. Back on clock at 0615 hrs. Orient TF. Drilling. MWD went to Gamma Loop. POOH at 0730 hrs (NE Time) Changed MWD and TIH. Tagged bottom and corrected (-16'). Orient TF and drilling (back on clock at 1200 hrs). Trying to maintain High side TF Several stall from 9850' to 9940'. Trouble sliding. Drilling. Drilled from 9853' to 9941'(88') BR not sufficient to land. POOH and changed out BHA. TIH. Ddll from 9941-10135' building angle. Backream to window. Tie-in at RA marker, add 3.0'. RIH drill from 10135-249'. Backream to window. Orient TF to right. Drill from 10249-336' (86 deg @ 8922' TVD). '10/9/98 5 '1 ~ 806 Drilling, Orient, Drilling. Drilled to 10446' (Landed) POOH for motor and bit change. Changed Motor setting to 0.8 deg and Bit. Till and Tie-In RA Marker (+2'). TIH, Tagged 'bottom at 10446'. Drilled from 10446' to 10583' (137'). Wiper trip to window. Drill from 10583-718' building angle from 8935' TVD looking for sand. Wiper trip to window. Tie-in, add 5.0'. Drill from 10718-752' (8931' TVD) where penetration rate increased to 100'/hr. Swap to new FIo Pro mud while drilling to 10794'. Wiper trip to 10300' while checking MWD azimuth readings. Drill at 92 deg from 10794-10950' (8922' TVD). Wiper trip to window. Drill at 92 deg from 10950-11086' (8917' TVD). 10/10/98 6 11435 Drilling, Backed ream to window at 11103'. Tie-In and corrected (+3'). TIH and tagged shale at 10763' (180° out of phase). Orient around, TIH. Tagged bottom at 11103' Orient to 80L and drilled. Getting no surveys, Pump up survey. Drilling. Drilled to 11190' POOH with possible survey uncertainty.(fault or bad MWD data). Changed BHA and TIH (Clean). Tagged bottom at 11190'. Drill to 11202'. Pumped up survey. Lost Pulse, work to regain and patient is terminal. POOH for MWD tool at 1630 hrs. At 10500' MWD started to work again. TIH to bottom. Tagged Pumped up survey and lost MWD signal. POOH for MWD (NE time starts at 1630 hrs). Change out MWD probe. RIH with same BHA (0.75 deg motor). Drill from 11202- 302' and stuck pipe. Work free. Backream to window. Tie-in, add 11.5'. RIH Perform MADD pass at 10830' to check GR, ok. RIH to corr TD. Drill ahead building angle at 93 deg from 11307-435' (8905' TVD). Entered shale at 11315' at 8910"TVD. Backream to window. 0/11/98 7 11874 Finish wiper trip to window from 11434'. Drilled from 11434' to 11597'. Wiper trip to window. Gained 500 psi pump pressure (solids) in 6 hrs. Drilling. Orient TF to 3 Q and drilling. Found sweet spot at 8890' TVDss. Drilled from 11597 to 11744' Wiper trip to 10700' and start mud swap. Drill 180 FPM with new mud. Drill to 11865'. Wiper tdp to 9600'. Tie-in, add 8.0'. RIH. Set down at 11620'. Clean up tire hole from 11580-660' (2.5 hrs). RIH to TD. Drill to t1874' and attempt to orient, but locking orientor was locked up at 80L. Backream to window, clean. POOH for MWD. NE starts at 2330 hrs 10/10/98. Change bit, motor, orientor, MWD probe and drlg connector assy. Cut off 32' CT. Rehead CT. PT 3500 psi, 35K. RIH with BHA #5 (0.9 deg motor). Projected end of polygon at 12130', est TD 12200' 10/12/98 8 '12'153 TIH and Tied in at RA Marker. Corrected -7.5'. TIH, tagged bottom at 11874'. DS on clock at 0900 hrs 10/11/98. Drilling. Turned TF to 50Land drill ahead. Built to 92.8° and orient around to hold. ROP @ 200 FPH. Drilled from 11874' to 12025'. Wiper trip to 11500' TIH and tagged at 11600' (turn area). TIH. Tagged bottom at 12025'. Drilling at 190 FPH. Drilled to 12075'. Wiper trip to window. Some tight spots on trip out. Tie-in and corrected +5.5' TIH and tagged bottom at 12076' Drilling. TD well at 12153' POOH and tie-in, no corr. Finish POOH. LD " drilling BHA. MU 90 jts 2-7/8" 6.16# L-80 STL liner. Install Baker CTLRT. Install CTC. PT 3500 psi, 35K. RIH with liner on 2-3/8" CT. Note: Liner at TD at 0610 hrs 0/13/98 9 RIH with 2 7/8" Liner. Tagged TD at 12160' CTD. Corrected back to 12153'. Displace FIo-Pro with 2% KCL. Pp cycling at 500 psi through entire circulating time. Liner released while displacing. Dropped ball and sheared seat at 2800 psi. Cir and monitored CT pressure. Still cycling at 500 psi. Held Safety and Operational meeting. Pumped 5 bbl ahead. 24.5 bbl cement, dropped dart. Displaced cement. Bumped LWP, displaced cement to latch collar using 77.6 bbl. Calculated = 77.7 bbl. Floats held, unstung POOH chasing fluid to surface. MU jetting nozzle on CSH and RIH on 2-3/8" CT. Cement at 700 psi. RIH thru TOL jetting to PBD at 12086'. POOH jetting to surface. Standback CSH workstring. MU SWS Memory CNL. RIH on CSH. RIH with CT. 10/14/98 10 RIH through TOL. Logging down at 30 Ft/min from 9700' to 12086'. Made 200' repeat section. PUH logging at 30 fi./min from 12086' to 9700'. POOH with Logging tools. Stand CSH in derrick on different break. Safety Meeting about CNL Source & Perforating. LD Logging tools. PT liner lap to 1000 psi. 30 min (OK). Load Pipe shed with perf guns. Safety mtg. MU 1280' of perf guns and blanks to shoot 770'. PU 27 stds CSH workstring. RIH on 2-3/8" CT to PBD. Park at set depth. Load and pump 5/8" ball to seat. Perforated as shown below and lost 1 bbl mud. POOH with CT. Stand back 26 STDS of CSH workstring. Held Safety meeting with crew. POOH with 60 perf guns and blanks. All shots fired. PERFORATED INTERVAL: 10,800 - 10,980, 11,100 - 11,300, 11,47'0 - 11,570, 11,690 - 11,840, 11,890 - 11,920, 11,950 - 12,070 FT BKB. RIH with nozzle and freeze protect 5 %" tubing with MEOH from 2000 fi. to surface. Close swab valve and purge CT with N2. Bleed down N2 press. Empty and clean rig pits for rig move. 10/15/98 11 Clean rig pits. Secure injector head on rig floor. Nipple down BOPE. Install tree cap and test. Move rig off well. Clean location. Move to J-15 for sidetrack. TT 9 days, 9.5 hrs ~Bp Exploration, Inc. Well: C-03A Prudhoe Bay North Slope, Alaska ,~Rig: Nordic #1/CTU #7 End of Well Survey Report Provided in: True - Grid - ASP BHI Rep: M. Miller, H. Wagoner Job Number: AFE Number: 101655 4P1208 Reviewed by: Date: //-5;- ~',,.¢ BAKER HUGHES INTEQ B.P. ExploraHon Structure · Pod C Field : Prudhoe Boy Well: C-03 Location · North Slope, Alaska East (feet) -> 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 4050 4200 4350 4500 4650 4800 4950 I I I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I I 8500- ~.~ 8600- O) 8700 - 0 8800 > 8900 !-'- 9000 I 9100 Kick off Point - 9850 MD, 8705.06 TVDss Tie in Position - 9800 MD, 8661.19 TVDss ' ,Tie in Position - 9800 MD, 8661.19 TVD.ss ... I '1 ' I I I I I I I I I I I I I ..... I' lC-°3'A I ..... I I I I I I I I I I I I I I i i I I i I i I II I I I 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 Vertical Section (feet) -> Azimuth 59.52 with reference 1905.35 N, 3009.17 E from C-03 3000 2850 · , ,, 2700 2550 A I 2400 2250 2100 1950 1800 1650 B.P. Exptoration Pad C C-03 C-03 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : C-03A Our ref : svy355 License : Date printed : 27-0ct-98 Date created : 27-0ct-98 Last revised : 27-0ct-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 665344.790,5961240.590,999.00000,N Slot location is n70 17 48.375,w148 40 4.275 Slot Grid coordinates are N 5959906.000~ E 664500.000 Slot local coordinates are 1334.59 S 844.79 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is Grid North B.P. Exploration Pad C,C-03 Prudhoe 8ay,North Slope, Alaska Measured Inclin Depth Degrees 9800.00 28.63 9840.00 30.15 9862.00 31.02 9894.70 32.32 9923.20 33.25 9957.90 37.44 9989.30 42.89 10022.20 49.39 10057.50 55.72 10088.60 61.70 10119.80 68.03 10151.80 74.53 10190.10 81.39 10222.00 85.62 10260.60 86.50 10290.50 86.60 10319.30 87.40 10353.20 87.80 10384.40 85.60 10417.00 85.80 10454.30 86.70 10486.30 87.00 10522.30 87.90 10555.10 88.70 10583.20 88.70 10614.40 89.10 10677.00 92.00 10716.50 92.10 10774.10 93.70 10813.80 92.00 Azimuth True Vert R E C T A N G U L A R Degrees Depth C 0 0 R D I N A T E S 79.18 8661.19 1905.35N 3009.17E 0.20 79.00 8696.04 1909.07N 3028.45E 3.81 79.00 8714.98 1911.21N 3039.43E 3.95 78.90 8742.81 1914.50N 3056.28E 3.98 78.90 8766.77 1917.47N 3071.43E 3.26 72.90 8795.07 1922.40N 3090.86E 15.67 73.90 8819.06 1928.18N 3110.26E 17.48 76.90 8841.85 1934.12N 3133.21E 20.82 75.10 8863.30 1940.91N 3160.38E 18.38 74.80 8879.44 1947.81N 3186.04E 19.25 73.40 8892.69 1955.56N 3213.18E 20.69 70.60 8902.96 1964.93N 3241.98E 21.94 65.60 8910.95 1978.91N 3276.70E 21.99 60.30 8914.56 1993.32N 3304.91E 21.17 58.80 8917.21 2012.83N 3338.10E 4.50 64.10 8919.01 2027.09N 3364.31E 17.70 69.30 8920.52 2038.46N 3390.72E 18.24 76.00 8921.94 2048.56N 3423.03E 19.78 80.40 8923.74 2054.93N 3453.51E 15.75 86.70 8926.18 2058.58N 3485.79E 19.28 93.10 8928.62 2058.64N 3522.99E 17.29 97.30 8930.38 2055.75N 3554.81E 13.14 100.10 8931.99 2050.31N 3590.35E 8.16 103.10 8932.96 2043.71N 3622.46E 9.46 107.50 8933.60 2036.30N 3649.55E 15.65 105.40 8934.20 2027.47N 3679.47E 6.85 100.30 8933.59 2013.55N 3740.47E 9.37 98.30 8932.18 2007.17N 3779.43E 5.07 94.10 8929.27 2000.96N 3836.60E 7.79 93.60 8927.29 1998.30N 3876.16E 4.46 SURVEY L[ST[NG Page 1 Your ref : C-03A Last revised : 27-0ct-98 Dogleg Vert G R ! D C 0 0 R D S Deg/lOOft Sect Easting Northing 0.00 667509.17 5961811.35 18.50 667528.45 5961815.07 29.05 667539.43 5961817.21 45.24 667556.28 5961820.50 59.80 667571.43 5961823.47 79.05 667590.86 5961828.40 98.70 667610.26 5961834.18 121.49 667633.21 5961840.12 148.35 667660.38 5961846.91 173.96 667686.04 5961853.81 201.28 667713.18 5961861.56 230.86 667741.98 5961870.93 267.86 667776.70 5961884.91 299.48 667804.91 5961899.32 337.99 667838.10 5961918.83 367.81 667864.31 5961933.09 396.33 667890.72 5961944.46 429.30 667923.03 5961954.56 458.80 667953.51 5961960.93 488.47 667985.79 5961964.58 520.57 668022.99 5961964.64 546.51 668054.81 5961961.75 574.39 668090.35 5961956.31 598.72 668122.46 5961949.71 618.31 668149.55 5961942.30 639.61 668179.47 5961933.47 685.12 668240.47 5961919.55 715.46 668279.43 5961913.17 761.58 668336.60 5961906.96 794.32 668376.16 5961904.30 10863.50 92.60 10891.80 92.70 10934.60 91.30 10978.10 93.80 11008.50 92.90 88.60 8925.30 1997.35N 3925.80E 10.12 836.61 668425.80 5961903.35 88.80 8923.99 1997.99N 3954.06E 0.79 861.30 668454.06 5961903.99 85.20 8922.49 2000.23N 3996.77E 9.02 899.24 668496.77 5961906.23 80.80 8920.56 2005.52N 4039.88E 11.62 939.08 668539.88 5961911.52 77.10 8918.78 2011.34N 4069.66E 12.51 967.70 668569.66 5961917.34 11043.20 90.80 11091.90 90.40 11138.60 90.80 11178.70 92.60 11211.60 92.20 73.40 8917.66 2020.16N 4103.20E 12.26 1001.07 668603.20 5961926.16 68.60 8917.15 2036.01N 4149.23E 9.89 1048.78 668649.23 5961942.01 64.10 8916.66 2054.74N 4191.99E 9.67 1095.14 668691.99 5961960.74 63.20 8915.47 2072.53N 4227.91E 5.02 1135.11 668727.91 5961978.53 61.10 8914.09 2087.89N 4256.97E 6.49 1167.95 668756.97 5961993.89 11238.30 93.00 11280.50 92.30 11313.90 91.50 11339.60 92.10 11398.20 92.80 11434.30 94.60 11482.10 94.60 11517.60 96.60 11552.10 95.30 11588.60 94.90 59.50 8912.88 2101.10N 4280.14E 6.69 1194.62 668780.14 5962007.10 55.40 8910.93 2123.78N 4315.66E 9.85 1236.73 668815.66 5962029.78 54.90 8909.82 2142.85N 4343.06E 2.82 1270.02 668843.06 5962048.85 53.30 8909.01 2157.91N 4363.86E 6.65 1295.59 668863.86 5962063.91 48.40 8906.51 2194.87N 4409.25E 8.44 1353.45 668909.25 596~'100.87 46.30 8904.18 2219.27~ 4435.75E 7.65 1388.66 668935.75 5962125.27 43.20 8900.34 2253.10N 4469.29E 6.46 1434.73 668969.29 5962159.10 42.80 8896.88 2278.94N 4493.38E 5.74 1468.60 668993.38 5962184.94 40.70 8893.30 2304.54N 4516.23E 7.13 1501.27 669016.23 5962210.54 37.90 8890.06 2332.67N 4539.25E 7.72 1535.38 669039.25 5962238.67 All data in feet un[ess otherwise stated. Calculation uses minimum curvature method. Coordinates from C-03 and TVD from Mean Sea Level. 8ottom hote distance is 5529.21 on azimuth 58.97 degrees from wellhead. Vertical section is from tie at N 1905.35 E 3009.17 on azimuth 59.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration Pad C,C-03 Prudhoe Bay, North S[ope,'Ataska SURVEY LISTING Page 2 Your ref : C-03A Last revised : 27-0ct-98 Measured Inc[in Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 11626.80 92.70 35.50 8887.53 2363.23N 4562.03E 8.51 1570.51 669062.03 5962269.23 11673.70 89.80 33.00 8886.50 2401.98N 4588.41E 8.16 1612.90 669088.41 5962307.98 11706.60 89.40 31.40 8886.73 2429.82N 4605.94E 5.01 1642.13 669105.94 5962335.82 11746.40 89.40 29.30 8887~15 2464.16N 4626.05E 5.28 1676.88 669126.05 5962370.16 11783.00 89.40 28.20 8887.53 2496.24N 4643.65E 3.01 1708.33 669143.65 5962402.24 11812.20 89.40 26.40 8887.84 2522.19N 4657.04E 6.16 1733.03 669157.04 5962428.19 11852.40 89.00 24.70 8888.40 2558.45N 4674.38E 4.34 1766.36 669174.38 5962464.45 11887.00 89.00 20.80 8889.00 2590.35N 4687.73E 11.27 1794.07 669187.75 5962496.35 11918.30 90.97 18.50 8889.01 2619.82N 4698.28E 9.67 1818.09 669198.28 5962525.82 11960.30 94.00 15.20 8887.19 2659.97N 4710.44E 10.66 1848.93 669210.44 5962565.97 11995.30 93.40 12.00 8884.93 2693.92N 4718.65E 9.28 1873.23 669218.65 5962599.92 12031.10 93.80 9.80 8882.68 2729.00N 4725.41E 6.23 1896.85 66922S.41 5962635.00 ' 12064.40 93.40 8.40 8880.59 2761.81N 4730.66E 4.36 1918.02 669230.66 5962667.81 12100.90 90.70 5.70 8879.29 2798.01N 4735.14E 10.46 1940.24 669235.14 5962704.01 12128.10 89.20 2.40' 8879.31 2825.13N 4737.06E 13.33 1955.65 669237.06 5962731.13 12153.00 89.20 2.40 8879.66 2850.01N 4738.10E 0.00 1969.17 669238.10 5962756.01 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from C-03 and TVD from Mean Sea Level. Bottom hole distance is 5529.21 on azimuth 58.97 degrees from wellhead. Vertical section is from tie at N 1905.35 E 3009.17 on azimuth 59.52 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes [NTEQ EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Company: BP Exploration Rig: Nordic #1/CTU #7 Job No: 101655 Well: C-03A Field: Prudhoe Bay, Alaska AFE No: 4P1208 Calculation Method: Minimum Curvature Mag. Declination: 27.900 API No: Vertical Sect. Plane: 60.780 TRUE Grid Correction: 1.260 BHI Rep: H. Wagoner, M. Miller Vertical Sect. Plane: 59.520 GRID Total Correction: 26.640 Job Start Date: 05-Oct-98 ,,,:,' Measured Depth from: RKB RKB Height: 54.500 Job End Date: 11-Oct-98 True Vertical Depth: Sea level Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) (del~) (deg) (ft) (TIP) °/100ft. Lat. (Y) Dep. (X) (del~) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) 9800.00 28.63 80.36 8661.19 0.00 0.00 1838.72 3050.34 79.10 1905.35 3009.17 5961811.35 667509.17 9840.00 30.15 80.26 8696.04 18.50 3.80 1842.02 3069.69 79.00 1909.08 3028.44 5961815.08 667528.44 .. 9862.00 3 ! .02 80.26 8714.98 29.05 3.95 1843.92 3080.72 79.00 1911.21 3039.43 5961817.21 667539.43 9894.70 32.32 80.16 8742.81 45.24 3.98 1846.84 3097.64 78.90 1914.51 3056.28 5961820.51 667556.28 9923.20 33.25 80.16 8766.77 59.80 3.26 1849.47 3112.84 78.90 1917.48 3071.42 5961823.48 667571.42 9957.90 37.44 74.16 8795.08 ' ' 79,05 15.67 1853.98 ' 3132.38 72.90 1922.41 3090.85 5961828.41 667590.85 9989.30 42.89 75.16 8819.06 98.70 17.48 1859.33 3151.91 73.90 1928.19 3110.26 5961834.19 667610.26 10022.20 49.39 78.16 8841.85 121.49 20.82 1864.77 3174.98' 76.90 1934.13 3133.20 5961840.13 667633.20 10057.50 55.72 76.36 8863.30 148.36' 18.38 1870.96 3202.29 75.10 1940.92 ' 3160.38 5961846.92 667660.38 ! 0088.60 61.70 76.06: 8879.45 ! 73.96 19.25 ! 877.29 3228.09 74.80 1947.82 3186.03 5961853.82 667686.03 , . . 10119.80 68.03 74.66 8892.69 201.29 20.69 1884.44 3255.40 73.40 1955.57 3213.18 5961861.57 .66771~' ~ __ 10151.80 74.53 71.86 8902.96 230.86 21.94 1893.18 3284.40 70.60 1964.94 3241.98 5961870.94 66774~ , 10190.10 81.39 66.86 8910.95 267.87 21.99 1906.39 3319.42 65.60 1978.92 3276.69 5961884.92 667776.69 10222.00 85.62 61.56 8914.56 299.49 21.17 1920.17 3347.93 60.30 1993.33 3304.90 5961899.33 667804.90 , 10260.60 86.50 60.06 8917.21 338.00 4.50 1938.95 3381.55 58.80 2012.84 3338.10 5961918.84 667838.10 10290.50 86.60 65.36 8919.01 367.81 17.70 1952.63 3408.07 64.10 2027.10 3364.30 5961933.10 667864.30 10319.30 87.40 70.56 ~ 8920.52 396.34 18.24 1963.42 3434.72 69.30 2038.47 3390.71 5961944.47 667890.71 10353.20 87.80 77.26 8921.94 429.31 19.78 1972.80 3467.24 76.00 2048.57 3423.02 5961954.57 667923.02 i 0384.40 85.60 81.66 8923.74 458.80 15.75 t 978.50 3497.85 80.40 2054.94 3453.50 5961960.94 667953.50 10417.00 85.80 87.96 8926.19 488.48 19.28 1981.44 3530.21 86.70 2058.59 3485.79 5961964.59 667985.79 10454.30 86.70 94.36 8928.63 520.57 17.29 1980.68 3567.40 93.10 2058.65 3522.99 5961964.65 668022.99 10486.30 87.00 98.56 8930.39 546.52 13.14 1977.09 3599.15 97.30 2055.75 3554.80 5961961.75 668054.80 10522.301 87.90 101.36 8931.99 574.39 8.16 1970.87 3634.56 100.10 2050.32 3590.35 5961956.32 668090.35 10555.10! 88.70 104.36 8932.96 598.72 9.46 1963.57 3666.52 103.10 2043.72 3622.46 5961949.72 668122.46 10583.20: 88.70 108.76 8933.60 618.31 15.65 1955.57 3693.44 107.50 2036.31 3649.55 5961942.31 668149.55 10614.40 89.10 106.66 8934.20 639.61 6.85 1946.08 3723.16 105.40 2027.48 3679.47 5961933.48 668179.47 , 10677.00 92.00 101.56 8933.60 685.13 9.37 1930.83 3783.84 100.30 2013.56 3740.47 5961919.56 668240.47 , , Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - AS~' Depth Angle Azi. TVD Section N(+VS(-) E(+)/W(-) Azi. N(+VS(-) E(+)/W(-) N(+VS(-) E(+)/W(-) (de~) (de~) (ft) (TIP) °/100fL Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) I0716.~ 92.10 99.56 8932.18 715.46 5.07 1923.59 3822.64 98.30 2007.18 3779.42 5961913.18 668279.42 10774.10 93.70 95.36 8929.27 761.58 7.79 1916.12 3879.67 94.10 2000.97 3836.60 5961906.97 668336.60 ,, 10813.80 92.00 94.86 8927.30 794.33 4.46 1912.59 3919.16 93.60 1998.31 3876.16 5961904.31 668376.16 10863.50 92.60 89.86 8925.30 836.62 10.12 1910.55 3968.76 88.60 1997.36 3925.79 5961903.36 668425.79 I0891.80 92.70 90.06: 8923.99 861.30 0.79 1910.57 3997.03 88.80 1998.00 3954.05 5961904.00 668454.05 10934.60 91.30 86.46 8922.50 899.24 9.02 1911.87 4039.78 85.20 2000.24 3996.76 5961906.24 668496.76 10978.10 93.80 82.06 8920.56 . 939.09 11.62 1916.21 4083.00 80.80 2005.53 4039.88 5961911.53 668539.88 11008.50 92.90 78.36 8918.78 967.70 12.51 1921.37 4112.90 77.10 2011.34 4069.66 5961917.34 668569.66 11043.20 90.80 74.66 8917.66 1001.08 12.26 1929.46 4146.62 73.40 2020.17 4103.19 5961926.17 668603.19 11091.90 90.40 69.86 8917.15 1048.79 9.89 1944.29 4192.99 68.60 2036.02 4149.22 5961942.02 66864 11138.60 90.80 65.36 8916.66 1095.14 9.67 1962.08 4236.16 64.10 2054.75 4191.99 5961960.75 668691.99 I1178.70 92.60 64.46 8915.47 1135.12 5.02 1979.07 4272.45 63.20 2072.54 4227.90 5961978.54 668727.90 11211.60 92.20 62.36 8914.10 1167.95 6.49 1993.78 4301.85 61.10 2087.90 4256.96 5961993.90 668756.96 11238.30 93.00 60.76 8912.89 1194.62 6.69 2006.49 4325.30 59.50 2101.11 4280.13 5962007.11 668780.13 11280.50 92.30 56.66 8910.93 1236.74 9.85 2028.37 4361.31 55.40 2123.79 4315.66 5962029.79 668815.66 11313.90 91.50 56.16 8909.83 1270.02 2.82 2046.84 4389.12 54.90 2142.86 4343.05 5962048.86 668843.05 11339.60 92.10 54.56 8909.02 1295.59 6.65 2061.44 4410.25 53.30 2157.92 4363.86 5962063.92 668863.86 11398.20 92.80 49.66 8906.51 1353.45 8.44 2097.39 4456.45 48.40 2194.87 4409.25 5962100.87 668909.25 .... i'1'43~.~0 " 94.60 47.56 " 8904.18 1388.66 7.65 2121.20 4483.47 46.30 2219.28 4435.74 5962125.28 668935.74 11482.10 94.60 44.46 8900.35 1434.73 6.46 2154.29 4517.74 43.20 2253.11 4469.28 5962159.11 668969.28 11517.60 96.60 44.06 8896.88 1468.60 5.74 2179.59 4542.40 42.80 2278.95 4493.38 5962184.95 668993.38 11552.10 95.30 41.96 8893.31 1501.28 7.13 2204.68 4565.81 40.70 2304.55 4516.22 5962210.55 669016.22 11588.60 94.90 39.16 8890.06 1535.39 7.72 2232.30 4589.44 37.90 2332.68 4539.25 5962238.68 669039.25 11626.80 92.70 36.761 8887.53 1570.51 8.51 2262.35 4612.88 35.50 2363.24 4562.02 5962269.24 669062.02 11673.70 89.80 34.26 8886.51 1612.91 8.16 2300.51 4640.1 i 33.00 2401.99 4588.41 5962307.99 669088.41 i i 706.60 89.40 32.66 8886.74 1642.14, 5.01 2327.96 4658.25 31.40 2429.83 4605.94 5962335.83 669105.94 11746.40 89.40, 30.56 8887.15 1676.89i 5.28 2361.85 4679.11 29.30 2464.17 4626.04 5962370.17 66912~ ~ ....... 1"1783.00 89.40 29.46 8887.54 1708.33 3.01 2393.54 4697.42 28.20 2496.25 4643.65 5962402.25 66914~ -- ......... i'i812.20 89.40 27.66 8887.84 1733.03 6.16 2419.18 4711.37 26.40 2522.20 4657.04 5962428.20 669157.04 11852.40 89.00 25.96 8888.40 1766.37 4.34 2455.06 4729.50 24.70 2558.46 4674.37 5962464.46 669174.37 .... 1'1887.00 89.00 22.06 8889.01 1794.07 11.27 2486.65 4743.58 20.80 2590.36 4687.75 5962496.36 669187.75 11918.30 90.97 19.76 8889.02 1818.09 9.67 2515.89 4754.75 18.50 2619.83 4698.27 5962525.83 669198.27 11960.30 94.00 16.46 ~ 8887.19 1848.94 10.66 2555.76 4767.79 15.20 2659.98 4710.43 5962565.98 6692'10.43 11995.30 93.40 13.26 8884.94 1873.23 9.28 2589.51 4776.74 12.00 2693.92 4718.65 5962599.92 669218.65 12031.10 93.80 11.06 8882.69 1896.85 6.23 2624.44 4784.27 9.80 2729.01 4725.40 5962635.01 669225.40 12064.40 93.40 9.66 8880.60 1918.02 4.36 2657.13 4790.25 8.40 2761.82 4730.66 5962667.82 669230.66 ,,, 12100.90 90.70 6.96 8879.29 1940.24 10.46 2693.22 4795.52 5.70 2798.02 4735.13 5962704.02 669235.13 12128.10 89.20 3.66 8879.31 1955.66 13.33 2720.30 4798.03 2.40 2825.14 4737.05 5962731.14 669237.05 12153.00 89.20 3.66 8879.66 1969.17 0.00' 2745.14 4799.62 2.40 2850.02 4738.10 5962756.02 669238.10 11/30/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12108 Company Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia LIS Tape C-03A 45- ~l~j ~" 98609 MCNL 981013 1 i 1 J- 15A ~ '~/~j *"J. 98610 MCNL 981020 1 1 1 K-19A ,~,E~ ~ ~ 98606 MCNL 980918 I 1 1 Z-01 ',ItL~t-J 98612 RST-SIGMA 981022 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson BIvd. Anchorage, Alaska 99519-6612 Date Delivered: DEC 0-4 1998 Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK 99503 AT[N: Rece ved b~: ~ _/'",(d% TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 23, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg Coiled Tubing Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit C-03A BP Exploration (Alaska) Inc. Permit No: 98-184 Sur Loc: 1316'SNL? 879"vVEL. Sec. 19, TllN, R14E, UM Btmhole Loc. 1400~NSL. 3932'EWL. Sec. 17, TI 1N. R14E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting thc Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnsto.,n Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. STATE OF ALASKA , ALASKA _ AND GAS CONSERVATION CC /IlSSION PERMIT TO DRILL CT $idetrackwell 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone :2. Name of Operator 5. Datum Elevation (DF or KB) ~,10. Field and Pool BP Exploration (Alaska) Inc. KBE = 54.46 Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 028305 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1316' SNL, 879' WEL, Sec. 19, T11N, R14E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 503' NSL, 2088' EWL, Sec. 17, T11N, R14E, UPM C-03A Attotal depth 9. Approximate spud date Amount $200,000.00 1400' NSL, 3932' EWL, Sec 17, T11N, R14E, UPM 9/22/98 1''2. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028306 @ 1346'I No Close Approach 2560 12050': 8890'TVD 1'6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depfh 9850' Maximum Hole Anqle 95° Maximum surface 3350 psig, At total depth (TVD) 3788 (8800') psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2 7/8" 6.16# L-80 ST-L 2813' 9237' 8172' 12,050 8890 i112 c.f. 19. To be completed for Redrill, Re-entry, and Deepen Operations. '~ 0 ~ Present well condition summary ¢j~"%~'~~%~ RI G! NA L Total depth: measured 10250 feet Plugs (measure~t~, ' t ruevertical 9107 feet d~;~'10'0'0'~M~~ Effective depth: measured 10179 feet Junk (measure (06/88) true vertical 9045 feet Casing Length Size Cemented MD TVD Structural BKB Conductor 80 20x30 99 99 Surface 2505 18 5/8" 4700 sx 2524 2524 Intermediate 4312 13-3/8" 1210 sx 4331 4180 Production 9730 10 3/4x9-5/8" 3030 sx 9749 8653 Liner 1032 7" 155 c.f. 9218-10250 8194-9086 Perforation depth: measured 10067'-10087', 10092'--10144', 10150'-10188' Sqzd: 9990'-10008', 10012'-10019', 10030'-10049' true vertical (subsea) 8896'-9000' (four intervals) 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth Pict [] BOP Sketch [] Retraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 21. I hereby certify that the foregoing is true and correct to the 'best of my knowledge Signed ~,/~ ¢///~/? ¢ Ted Staqq Title Coiled Tubing Drilling Engineer Date ~'/~' Commission Use Only Permit Number APl Number t _Approval Dat~ See cover letter ~2'~/~y 50- 0 2-. ~ - .2. 0/.2. ~' .-' ~ /I ~""c~,.~-'~'~ for other requirements . Conditions of Approval: Samples Required [] Yes ,'~ No Mud Log Required [] Yes..~ No Hydrogen Sulfide Measures j~Yes [] No Directional Sun/ey Required J~ Yes [] No Required Working Pressure for BOPE [] 2M; [] 3M; [] 5M;~l~ 1OM; [] 15M Other~)rJglRal 5igrluu ~., Commissioner byorderof~ Approved By Pm,!d '~^1 I~r~c,-I'~r, the commissiorl Date Form 10-401 Rev. 12-01-85 Submit In Triplicate ALASKA r",L AND GAS CONSERVATION COI~*~/IISSION -- PERMIT TO DRILL CT Sidetrack well 20 AAC 25.OO5 [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [~] Deepen [] Service BI Development Gas [] Single Zone [] Multiple Zone i2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 54.46 Prudhoe Bay Field / Prudhoe i3. Address 6. Property Designation Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 028305 i4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1316' SNL, 879' WEL, Sec. 19, T11 N, R14E, UPM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 503' NSL, 2088' EWL, Sec. 17, T11N, R14E, UPM C-03A At total depth 9. Approximate spud date Amount $200,000.00 1400' NSL, 3932' EWL, Sec 17, T11N, R14E, UPM 9/22/98 i12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028306 @ 1346'I No Close Approach 2560 12050': 8890'TVD il 6. To be completed for deviated wells :17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9850' Maximum Hole Anqle 95° Maximum surface 3350 psig, At total depth (TVD) 3788 (8800') psig il 8. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2 7/8" 6.16# L-80 ST-L 2813' 9237' 8172' 12,050 8890 112 c.f. 19. To be completed for Redrill, Re-entry, and Deepen Operations. summary Present well condition Total depth: measured 10250 feet Plugs (,,,e'asured) true vertical 9107 feet Effective depth: measured 10179 feet Junk (measured) fill at 10179' MD (06/88) true vertical 9045 feet Casing Length Size Cemented MD TVD Structural BKB Conductor 80 20x30 99 99 Surface 2505 18 5/8" 4700 sx 2524 2524 Intermediate 4312 13-3/8" 1210 sx 4331 4180 Production 9730 10 3/4x9-5/8" 3030 sx 9749 8653 Liner 1032 7" 155 c.f. 9218-10250 8194-9086 Perforation depth: measured 10067'-10087', 10092'--10144', 10150'-10188' Sqzd: 9990'-10008', 10012'-10019', 10030'-10049' true vertical (subsea) 8896'-9000' (four intervals) 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Timevs Depth Pict [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. ~_ /¢,~.. ~' Ted Staqq ,,~.~,-~.--,~ /~ "mc~.:r- Title Coiled Tubing Drilling Engineer Date ~/~/ Commission Use Only Permit Number I APINumber I ApprovalDa~.,~ I Seecoverletter ~ ..-- ,,/ coy 50- ~ ~ ~.~ ~.O//..~- ~/- ~ ,2 ~-"¢,~,,~'~ ,~'~¢:~ for other requirements Conditions of Approval: Samples Required ~ Yes ,~ No Mud Log Required [] Yes~ No Hydrogen Sulfide Measures ~/~es [] No Directional Survey Required ~ Ye~ No Required Working Pressure for BOPE [] 2M; [] 3M; ~ SM; ~ 10M; © 15M · Oth,er: by order of t,h'i[jlRal ,Slgrled l:ly Commissioner Date --" Approved By r,-,::::: ,., : ~ , the commission f',,..,..'. _, LAA' * Form 10-401 Rev.'~i¢~J~lYeV5 o0nnst0n Submit In Triplicate BPX C-03A Sidetrack Summary of Operations: C-03 is a poor cycle performer with fault related high GOR. The sidetrack, C-03A, will target Zone 1 (14P- 13P, ) reserves. This sidetrack will be conducted in two phases. Phase 1: Lay abandonment cement and set whipstock: Planned for 9116/98. C-03 will be tested for tubing integrity, drifted for the whipstock and a Kinley caliper will be run to evaluate liner and tubing condition. Existing perforations will be abandoned with approx. 20 bbls cement. Abandonment cement will be downsqueezed past a mechanical whipstock set at approx.9,850'. Abandonment cement will be pressure tested to 1500 psi with AOGCC witness. This procedure is described in more detail in the Form 10-403. Phase 2: Mill Window and Drill Directional Hole: Planned for 9~22~98. Directional drilling coil tubing equipment will be rigged up and utilized to mill the window and drill the directional hole as per attached plan. Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,237' MD and cemented with approx. 20 bbls. cement. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9,850' MD (8,705' TVD ss) - TD: 12,050' MD (8,890' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory CNL will be run in the 2 7/8" liner. TREE: 6" CAMERON WELLHEAD: McEVOY ACTUATOR: OTIS 180' I2°'' sH°E I 1814 11 1/4" TUBING 10-3/4, 55#, N-80, BTRS ~ Proposed Completion 1951' I BOTTOM 10 3/4 55#, N-80 KB. ELEV =54.46' BF. ELEV = 35.16' 9-5/8 X 11-3/4 I 142' 1 THERMOCASE II 13-3/8", 68 / 72 #/FT SSSV LANDING NIPPLE ( OTIS )( 4.562" ID) I 2131' I I 2043' I OP 9-5/8" LINER I I OTTOM9 2054'SEAL ASS'Y 12524' I 18-5/8" SHOE 4331' ] 13-3/8", 72# SHOE KOP: 2700' MAX ANGLE: 43 DEG @ 4300' 5-1/2", 17#/ft, L-80, AB MOD BUTTBG-IPC TUBING ID: 4.892" CAPACITY: ..0232BBL/FT 7" LINER 9-5/8", 47#/ft, N-80, BTRS I 9749' PERFORATION SUMMARY REF: LOG: BHCS 3-26-78 SIZE SPF INTERVAL ( PEN/SQZ'D 4 4 9990-10008' SQZ'D 4 4 10012-10019' SQZ'D 4 4 10030-10049' SQZ'D 3-3/8 6 10053-10063 OPEN 2-7/8 4 10067-10087' OPEN 2-7/8 4 10092-10114' OPEN 2-7/8 4 10120-10144' OPEN 2-7/8 4 10150-10188' OPEN 3-3/8 6 10015-10017' GEL SQZD . PBTD I 10208' 7", 29 #/ft, N-80, BTRS I 10250' 9-5/8 I 13 3/8 I 2138, 2332' FOC's GAS LIFT MANDRELS ( OTIS LBD WI RA LATCH) NO MD(BKB' TVDss 023' 2968 786' 5282 119' 7228 808' 7814 990' 7965 5-1/2" OTIS SLIDING SLEEVE (4.562" ID) ;-1/2" SEAL ASS'Y 9-5/8 PACKER (GUIB)(4.75"ID 4.5" 12.6~ TAIL PIPE 4.5 .... X" NIPPLE I ( OTIS ) ( 3.813" ID) I 9097' 9155' 9170' 9217' 4.5 .... XN" NIPPLE I (OTIS) ( 3.725" ID)I 9256' 4.5" WEG ( ?" ID) (ELMD) 9292' 9279' Whipstock approx. 9850'. 2 7/8" Cemented Liner with cement approx. 200 ft above top Whipstock Abandonment cement downsqueezed past whipstock NOTE: FISH PERF GUN BULLNOSE ADAPTER 3-3/8" X 1.2' C-03 Vertical Section o 8300 8350 8400 TSAD 8450 8500 8550 86OO 8650 8700 875O 8800 8850 8900 8,930 8950 9O0O Path Distance (Feet) 500 1,000 1,500 2,000 TSGR 8311ss, 9400 MD I top liner cement approx. 9650' leaving adequate room for future sidetrack above th s one. Angle @ K.O.= 29 deg MD:9850 2,500 3,000 Tot Drld:2200 ft 12050 TD Marker Depths ~Orig Wellbore TZ3 TZ2C TSAD 8,890] 8,8901ff TVD I 8,5791, TVD S,4 91,TVD IKick Off 8,705 ft TVD 9,850 ft MD IDeprtr @KO 3,599 ft MD KO Pt 9,850I MD New H°IO 2200I Total MD_ ~2,050I TVD TO s,--~-~I DLS deg/100 Tool Face Length Curve 1 6 0 30 Curve 2 14 -10 419 Curve 3 8 90 199 Curve 4 8 84 199 Curve 5 8 -90 999 Curve 6 6 90 354 2,200 Drawn: 9/8/98 15:17 Plan Name: Case 101 3,500 C-03 3,000 P 2,500 2,000 1,500 2,500 3,000 3,500 4,000 4,500 X distance from Sfc Loc 5,000 IWellName C-03 I CLOSURE Distance 5,518 ft I Az 59 deg ~IEW HOLE E/W (X) N/S (Y)' Kick Off 3,033 1,91 0 TD 4,741 2,823 State Plane 669,241 5,962,729 Surface Loc 664,500 5,959,906 DLS deg/100 Tool Face Length Curve 1 6 0 30 Curve 2 14 -10 419 Curve 3 8 90 199 Curve 4 8 84 199 Curve 5 8 -90 999 Curve 6 6 90 354 2,200 Drawn: 9/8/98 15:17 Plan Name: Case 101 (5~-0 3A CT Drilling & Completion BOP LU 12" 36" 22.5" 18" 38" 2 3/8" CT t I I 10,000 psi Pack-Off Lubricator~ ___ 7 1/16" Annular 7 1/16"5000 psi I i i i i ..... I 7 ~/~o" I I~ I Pipe/Slip I ~ ~'~ 2 3/8" r _~ - i ~__1 SWAB OR MASTER VALVE I · WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1 COMPANY ,ffi/O INIT CLASS _~_e. / ENGINEERING APPI~ DATE . Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. cMr vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMl' 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 ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to /-¢Oc~C:3 . psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports ....... [exploratory only] ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contarninate 'freshwater; or cause drilling waste... to surface; APPR DATE WELL NAME /O_/G{__.p/, C-c~,,,G PROGRAM: exp [] devyredr~-~ serv [] wellbore seg,I ann. disposal para req,, ~/) GEOL AREA .. ,/~/~') UNIT# ,//_,,~'_~"_~ ON/OFF SHORE __._O__"~_.__ ........... . NN N ................................................................................................................................................ ~ N ~N N (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (,E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOL,~,~¥: ENGINEE_RING: . JDH,,-.--~ COMMISSION' RNC , ~,/~ co Comments/Instructions: M,che, ld~sl i,~v (]5/29/9R dlfC \u i.:.('~fh(., ~\w( )u:h;-'. i\(tu in;l\, .h, ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 866t, ~ 0 03(3 * ALASKA COMPUTING CENTER . * * ....... SCHLUFfl3ERGER ....... * COMPANY NAlVlE : BP EXPLORATION WELL NAME : C-03A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 500292012401 REFFfAF~CE NO : 98609 RECEIVED D[C O~ 1998 * ALASKA COMPUTING CENTER * . ....... SCHLUMBERGER ....... COMPANY NAFiE : BP EXPLORATION WELL NAME : C-03A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NTJIVIBER : 500292012401 REFERENCE NO : 98609 LIS Ta~- ~Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 10:39 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/25 ORIGIN : FLIC REEL NAFIE : 98609 CONTINUATION # : PREVIOUS REEL : COMFIENT : BP EXPLORATION, PRUDHOE BAY, C-03A, API #50-029-20124-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/25 ORIGIN : FLIC TAPE NAME : 98609 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, C-03A, API #50-029-20124-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAMe: C-03A API NUMBER: 500292012401 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 25-NOV-98 JOB NUMBER: 98609 LOGGING ENGINEER: R. HERRMANN OPERATOR WITNESS: CHUCK SEVCIK SURFACE LOCATION SECTION: 19 TOWNSHIP: 1 IN RANGE: 14E FNL: 1316 FSL: FEL: 879 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 54.46 DERRICK FLOOR: 53.46 GROUND LEVEL: 35.16 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) LIS Ta~erification Listing Schlumberger Alaska Computing Center 25-NOV-19~:"lO: 39 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CNT ....... CONTAINED HEREIN IS LDWG FORMATTED DATA ACQUIRED ON BP EXPLORATION'S C-03A WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUB, VARY LDWG TOOL CODE START DEPTH STOP DEPTH CNT 12072.0 9669.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEAStrRED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUPi~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... CNT ....... REMARKS: THIS FILE CONTAINS THE MAIN LOG MEMORY CNL DATA. NO DEPTH CORRECTIONS HAVE BEEN MADE AS THIS IS LIS Tap~'~Verification Listing Schlumberger Alaska Computing Center PAGE: THE PRIMARY DEPTH CONTROL LOG. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNT V O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12072.000 GRCH. CNT -999.250 FCNT. CNT 367.482 NRAT. CNT 17.801 DEPT. 9669.000 GRCH. CNT 12.028 FCNT. CNT -999.250 NRAT. CNT -999.250 CCL . CNT - 999. 250 NCNT. CNT CCL. CNT -999.250 NCNT. CNT 7169. 222 -999.250 LIS Tap=e~erification Listing Schlumberger Alaska Computing Center 25-NOV-1998 10:39 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREFZENT: 0.1000 FILE SUFff~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12072.0 9669.0 MCNL LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO)'. TOOL STRING (TOP TO BOTTOM) VEiVDOR TOOL CODE TOOL TYPE 13-0CT-98 RELOO35D 12072.0 9669.0 12072.0 TOOL NUMBER LIS Ta~"~erification Listing Schlumberger Alaska Computing Center PAGE: MCNL 14EMORY CNL MCNL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 1750 NEAR COUNT RATE HIGH SCALE (CPS): 34250 TOOL STANDOFF (IN): REMARKS: THIS FILE CONTAINS THE RAWMAIN LOG FOR THE MEMORY CNL. DATA SAMPLE RATE IS 0.1'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Ta~'p~''jVerification Listing Schlumberger Alaska Computing Center 25-NOV-1998 10:39 PAGE: 6 TYPE REPR CODE VALUE 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~q CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR CNT GAPI O0 000 O0 0 2 1 1 4 68 0000000000 CCLD CNT V O0 000 O0 0 2 1 1 4 68 0000000000 CVEL CNT F/HR O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12080.533 GR.CNT -999.250 CCLD. CNT -999.250 CVEL.CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 DEPT. 9666.234 GR.CNT -999.250 CCLD.CNT 85.000 CVEL.CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250 NRAT. CNT -999.250 ** END OF DATA ** LIS Ta~JVerification Listing Schlumberger Alaska Computing Center PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE . FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12077.0 11800.4 MCNL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MCNL MEMORY CArL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) 13-0CT-98 RELOO35D 12072.0 9669.0 12072.0 TOOL NUMBER ........... MCNL LIS T~p~'~"Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 10:39 PAGE: LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): THERMAL BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2200 NEAR COUNT RATE LOW SCALE (CPS): 1750 NEAR COUNT RATE HIGH SCALE (CPS): 34250 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS THE RAW REPEAT FILE. ALL DATA IS SAMPLED AT O. 1 '. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 O. 1 9 65 FT LIS TapS'Verification Listing Schlumberger Alaska Computing Center 25-NOV-1998 10:39 PAGE: TYPE REPR CODE VALUE 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 GR CNT GAPI O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12077. 033 GR. CNT - 999. 250 NRAT. CNT 17. 004 DEPT. 11800.434 GR.CNT -999.250 NRAT. CNT -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/25 ORIGIN · FLIC TAPE NAME : 98609 CONTINUATION # : 1 PREVIOUS TAPE CO~94ENT ' BP EXPLORATION, PRUDHOE BAY, C-03A, API #50-029-20124-01 LIS Tap~Verification Listing Schlumberger Alaska Computing Center 25-NOV-19~"l 0: 39 PAGE: 10 **** REEL TRAILER **** SERVICE NAFiE : EDIT DATE : 98/11/25 ORIGIN : FLIC REEL NAM~ : 98609 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, PRUDHOE BAY, C-03A, API #50-029-20124-01 Sperry-Sun Drilling Services LIS Scan Utility Fri Mar 26 09:45:15 1999 Reel Header Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPEP~ATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-80398 B. JA}{N SEVCIK/HILDR RECEIVED 1999 A IIi Oil & Oons. Oomn,Jmbn C-03A ~ 500292012401 BP EXPLOP~ATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 26-MA/~-99 MWD RUN 2 AK-MW- 80398 B. JAHN SEVCIK/HILDR MWD RUN 3 AK-MW-80398 B. JA}{N SEVCIK/HILDR JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MW-80398 B. JAHN SEVCIK/HILDR MWD RUN 6 AK-MW-80398 B. JAHN SEVCIK/HILDR 19 liN 14E 1316 MWD RUN 7 AK-MW-80398 B. JAHN SEVCIK/HILDR FEL: 879 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 54.50 DERRICK FLOOR: .00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 10.750 2074.0 2ND STRING 9 . 630 9749 . 0 3RD STRING 7 . 000 9849.0 PRODUCTION STRING 3.750 12153.0 REM_ARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1,2,3,4,6 AND 7 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY. 3. MWD RUN 5 CONTAINS NO VALID DATA AND IS NOT PRESENTED. 4. MWD DATA IS DEPTH SHIFTED/CORRECTED USING "MAIN LOG- GAMMA RAY FROM MNCL TOOL" LOGGED ON 13 OCTOBER, 1998. THIS WL-GR WAS PROVIDED BY DAVE DOUGLAS OF BP EXPLORATION (ALASKA), INC. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12153'MD, 8880 ' SSTVD. SROP = SMOOTHED RATE OF PENETP~ATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9841.0 12128.0 ROP 9849.5 12152.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE 9841 0 9847 5 9849 5 9851 0 9867 0 9869 5 9872 0 9874 0 9876 5 9908 5 9910 0 9911 0 9914 5 9918 0 9942 0 9948 0 9950 5 10016 0 10020 5 10022 5 10025 0 10028 0 10031 5 10039 0 10041 5 10048 0 10050 0 10061 5 10063 0 10066 5 10068 0 10077 0 10078 5 10080 5 10082 5 10086 5 10089 0 10091 0 10094 5 10103 0 10106 0 10109 0 10110 5 10113 0 10118 0 10120 0 10123 5 10126 5 10133 0 10137 5 10142 5 10146 0 10151 5 10162 0 10166 0 DEPTH GR 9839 9846 9848 9850 9866 9867 9870 9872 9875 9905 9908 9909 9912 9916 9941 9946 9948 10016 10018 10020 10022 10026 10029 10037 10040 10045 10048 10059 10061 10065 10067 10075 10077 10079 10081 10084 10087 10089 10092 10101 10104 10106 10109 10112 10117 10120 10123 10125 10132 10136 10140 10145 10151 10161 10165 5 0 5 0 0 0 0 0 0 5 0 0 5 0 0 0 0 0 5 0 5 5 5 5 0 5 0 5 5 0 5 5 0 5 5 5 5 5 5 5 5 5 5 0 0 0 0 5 0 0 5 0 0 5 0 EQUIVALENT UNSHIFTED DEPTH 10174 10189 10191 10194 10196 10223 10230 10232 10239 10241 10242 10246 10249 10251 10253 10255 10257 10263 10267 10272 10273 10279 10287 10295 10346 10349 10373 10374 10379 10399 10422 10427 10431 10436 10453 10456 10462 10465 10470 10473 10475 10479 10482 10500 10529 10551 10573 10592 10603 10610 10627 10628 10638 10662 10664 10669 10671 10173 10189 10191 10193 10194 10223 10228 10231 10238 10240 10241 10244 10248 10250 10252 10254 10256 10263 10267 10269 10271 10277 10285 10291 10345 10348 10372 10373 10378 10397 10418 10422 10427 10431 10447 10450 10456 10467 10470 10473 10475 10481 10484 10499 10530 10553 10574 10594 10604 10611 10626 10628 10637 10662 10664 10669 10670 10694 10700 10715 10734 10738 10759 10785 10868 10884 11001 11022 11051 11072 11314 11321 11329 11332 11334 11335 11339 11342 11345 11370 11374 11412 11426 11428 11433 11442 11445 11447 11461 11464 11466 11470 11473 11475 11478 11594 11597 11599 11603 11604 11609 11613 11644 11647 11651 11653 11656 11661 11673 11712 11715 11718 11721 11735 10694 10699 10717 10736 10739 10761 10787 10869 10884 11002 11023 11049 11073 11315 11321 11329 11333 11334 11335 11340 11342 11347 11373 11376 11412 11426 11428 11433 11441 11445 11447 11460 11464 11466 11472 11473 11476 11479 11593 11595 11598 11600 11605 11607 11611 11643 11646 11649 11651 11655 11660 11671 11710 11715 11717 11721 11733 11737 0 11743 11747 11751 11754 11774 11779 11781 11783 11784 11788 11860 11874 11878 11881 11883 11927 11938 11941 12041 12044 12048 12055 12152 $ MERGED DATA SOURCE PBU TOOL CODE MWD 1 MWD 2 MWD 3 MWD 4 MWD 6 MWD 7 $ REMARKS: 11734 0 11742 0 11744 5 11747 5 11752 5 11774 5 11778 5 11780 5 11784 0 11785 0 11788 5 11862 0 11877 0 11878 5 11880 0 11883 5 11931 0 11940 5 11945 0 12044 5 12047 5 12050 5 12055 0 12152 5 BIT RUN NO MERGE TOP 9849 0 9890 0 9941 0 10446 0 11200 0 11874 0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9890 0 9941 0 10446 0 11190 0 11874 0 12153 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 9841 12152.5 10996.8 4624 9841 12152.5 ROP 20.81 8622 117.059 4607 9849.5 12152.5 GR 17.18 1127.93 70.068 4575 9841 12128 First Reading For Entire File .......... 9841 Last Reading For Entire File ........... 12152.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9839.5 9866.0 ROP 9848.5 9889.0 $ LOG HEADER DATA DATE LOGGED: 07-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : MSC 1.32 INSITE 4.0 5.74, 3.01e MEMORY 9890.0 9849.0 9890.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP_ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL FLATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA1YDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 28.6 32.3 TOOL NUMBER NGP SPC 264 3.750 3.8 FLO-PRO 8.90 .0 9.3 5.6 .000 .000 .000 .000 65.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 9839.5 9889 9864.25 100 GR 17.18 251.78 32.2951 54 ROP 20.82 8622 1344.32 82 First Last Reading Reading 9839.5 9889 9839.5 9866 9848.5 9889 First Reading For Entire File .......... 9839.5 Last Reading For Entire File ........... 9889 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9867.0 9918.0 ROP 9891.5 9940.5 $ LOG HEADER DATA DATE LOGGED: 07-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : MSC 1.32 INSITE 4.0 5.74, 3.01e MEMORY 9941.0 9890.0 9941.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 32.3 33.3 TOOL NUMBER NGP SPC 308 3.750 3.8 FLO-PRO 8.90 .0 9.3 5.6 .000 .000 .000 .000 58.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam DEPT 9867 9940.5 9903.75 148 GR 23.46 158.67 48.4336 103 ROP 34.82 72.53 49.6416 99 Reading Reading 9867 9940.5 9867 9918 9891.5 9940.5 First Reading For Entire File .......... 9867 Last Reading For Entire File ........... 9940.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9918.5 10422.0 ROP 9943.0 10445.5 $ LOG HEADER DATA DATE LOGGED: 08-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MSC 1.32 INSITE 4.0 5.74, 3.01e MEMORY 10446.0 9941.0 10446.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUR3~L GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 35.4 87.0 TOOL NUMBER NGP SPC 308 3.750 3.8 FLO-PRO 8.90 .0 8.9 .0 .000 .000 .000 .000 63.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Reading DEPT 9918.5 10445.5 10182 1055 GR 21.41 155.56 48.1709 1008 ROP 20.81 158.32 73.0386 1006 9918.5 10445.5 9918.5 10422 9943 10445.5 First Reading For Entire File .......... 9918.5 Last Reading For Entire File ........... 10445.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10422.5 11166.0 ROP 10446.0 11189.5 $ LOG HEADER DATA DATE LOGGED: 09-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MSC 1.32 INSITE 4.0 5.74, 3.01e MEMORY 11190.0 10446.0 11190.0 MAXIMUM A/~GLE: 92.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 308 3.750 3.8 FLO-PRO 8.90 .0 8.9 8.0 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10422.5 11189.5 10806 1535 10422.5 Last Reading 11189.5 GR 53.73 167.79 83.545 1488 ROP 38.49 803.36 91.0486 1488 10422.5 11166 10446 11189.5 First Reading For Entire File .......... 10422.5 Last Reading For Entire File ........... 11189.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11166.5 11847.5 ROP 11203.5 11873.5 $ LOG HEADER DATA DATE LOGGED: 10-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVA3~ (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 96.6 MSC 1.32 INSITE 4.0 5.74, 3.01e MEMORY 11874.0 11200.0 11874.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUR3~L GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (CB): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER~TURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 264 3.750 3.8 FLO-PRO 8.90 .0 9.0 7.2 .000 .000 .000 .000 72.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11166.5 11873.5 11520 1415 11166.5 GR 33.36 1127.93 70.5692 1363 11166.5 Last Reading 11873.5 11847.5 ROP 30.94 465.06 101.013 1341 11203.5 11873.5 First Reading For Entire File .......... 11166.5 Last Reading For Entire File ........... 11873.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 R/kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11849.0 12128.0 ROP 11874.0 12152.5 $ LOG HEADER DATA DATE LOGGED: 11-0CT-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 89.2 MAXIMUM ANGLE: 93.8 MSC 1.32 INSITE 4.0 5.74, 3.01e MEMORY 12153.0 11874.0 12153.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 264 3.750 3.8 FLO-PRO 8.80 .0 8.9 8.5 .000 .000 .000 .000 75.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11849 12152.5 12000.8 608 11849 GR 41.65 267.96 80.4675 559 11849 ROP 41.8 295.51 134.83 558 11874 Last Reading 12152.5 12128 12152.5 First Reading For Entire File .......... 11849 Last Reading For Entire File ........... 12152.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/03/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/03/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File