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197-198
.. STATE OF ALASKA . ALASKAleIL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: D Oil DGas D Plugged !HI Abandoned D Suspended DWAG 1b. Well Class: 20AAC25.105 20AAC 25.110 !HI Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/28/2005 197-198 305-306 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12/08/1997 50- 029-20577-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/16/1997 PBU E-21 A 1633' FNL, 883' FEL, SEC. 06, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 387' FNL, 3830' FEL, SEC. 07, T11 N, R14E, UM 65.12' Prudhoe Bay Field / Prudhoe Bay - Pool Total Depth: 9. Plug Back Depth (MD+TVD), ~: '::¡:: ¡ I h. 1849' FNL, 4547' FEL, SEC. 07, T11N, R14E, UM 13401 + 9022 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) .orfc 26. r mlll::ignation: Surface: x- 664100 y- 5975423 Zone- ASP4 13487 + 4~j>_q7 .9 ?n~"""~DL028304 -- ---~ 11. Depth where SSSV Sêt"1If Y/l ~ G 17. Dtr'fEI..1Jse Permit: TPI: x- 661256 y- 5971326 Zone- ASP4 Total Depth: x- 660576 y- 5969849 Zone- ASP4 N/A MD '/1 !I~ CQn.. ,.. ~ __~_ ___n____n____ _n____. .. -- . 19. Water depth, if offshore ''''C/1 ~e Tf1~4i~f Permafrost 18. Directional Survey DYes !HI No N/ A MSL . WòO' (Approx.) 21. Logs Run: MWD, LWD, GR, RES, NEU, DEN ~2. CASING, LINER AND CEMENTING RECORD CASING SETTING EPTH MD I SETTING I EPTH TVD HOLE . A~()lJNT SIZE WT.PERFT. GRADE lOP tsoTTOM lOP ItsoTTOM SIZE CgMENTINGRECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 36 cu yds Concrete 13-3/8" 72# L-80 Surface 2691' Surface 2691' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 9875' Surface 8412' 12-1/4" 1351 cu ft Class 'G', 130 cu ft AS I 7" 26# L-80 2419' 9945' 2419' 8472' 8-1/2" 1414 cu ft Class 'G' 4-1/2" 12.6# L-80 9794' 13487' 8342' 9037' 6" 1520 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 9798' 9741' MD TVD MD TVD 25. AcID,FRActlJRE GEMEN1'SQUE~e,ETc. f¡ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ïC!\~~t\~~";" 1 0450' Set CIBP ~~,j>... '0'Cc...\·· 1 0400' Set Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMs 8Ft )[¡itI fì 6 iDD6 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS NAME MD Sag River 9940' Shublik 9991' Top of Sadlerochit 10072' Zone 4A 10125' Zone 3 10218' Zone 2C 1 0302' Zone 2B 10382' Zone 2A 10752' Zone 1 B 11642' 29. FORMATION 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". 8468' None 8511' 8579' 8621' 8689' 8743' 8789' 8923' 8963' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ . Title Technical Assistant Date ¡::l..(:J....O¡(OS PBU E-21A 197-198 305-306 Prepared By NameINumber: Terrie Hubble, 564-4628 Well Number Permit No. / A roval No. Drilling Engineer: Barbara Holt, 564-5126 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 18: 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 10-407 Revised 12/2003 Submit Original Only e e Well: Field: API: Permit: E-21 B Prudhoe Bay Unit 50-029-20577 -02-00 205-147 Accept: Spud: Release: Rig: 1 0/29/05 1 0/30/05 11/09/05 Nordic #1 PRE-RIG WORK 10/06/05 DRIFT W/ 3.70 DUMMY WHIPSTOCK TO 10,074' (SLM). RIH W/ 3.685 CENT. AND SB. 10/07/05 DRIFT WITH 20' X 3.70 DUMMY WHIPSTOCK TO 10,062' (SLM). RAN 3.63 GAUGE RING, 3' STEM, B. BRUSH, 2' STEM, 3.685 CENT. TO 10,400 (SLM). DRIFT WITH 3.68 X 13' 10" LOW SIDE WHIPSTOCK TO 10500' SLM. 10/26/05 ATTEMPT TO SET CIBP AT 10450'. SAT DOWN AT 10248'. SUSPECT DUE TO DOGLEG SEVERITY. WORKED DOWN AT DIFFERENT SPEEDS BUT COULD NOT GET TO SET DEPTH. POOH AND RIG DOWN. DRIFT W/ 3.70" GAUGE RING TO 10,500' SLM. DRIFT WI 3.70" DUMMY WHIPSTOCK TO 10,070' SLM. 10/27/05 RUN 3.68" JUNK BASKET W/ BLB WHILE LRS PUMPED 65 BBLS DIESEL DOWN TBG. RUN 3.680 DUMMY WHIPSTOCK TO 10500' SLM, NO RESTRICTIONS. 10/28/05 SET BAKER CIBP WI HES EDT, CENTER OF ELEMENT AT 10450' SLM. RDMO. BAKER CIBP OAL = 1.71 '. TOP OF CIBP TO CENTER OF ELEMENT = .59'. (IAA K-1 CIBP). BPEXPLORATION Page 1 _ Qperati'ønsSummary Report ... .. Legal Well Name: E-21 Common Well Name: E-21 Spud Date: 11/4/1981 Event Name: REENTER+COMPLETE Start: 10/28/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 11/9/2005 Rig Name: NORDIC 1 Rig Number: N1 Date From -To Hours Task Code NPT Phase Description of Operations 10/28/2005 11 :30 - 12:00 0.50 RIGD P PRE Rig released from P-06B @ 11 :30Hrs on 10/28/2005. Prep to move rig to E-pad. 12:00 - 12:15 0.25 MOB P PRE PJSM for moving rig off well. 12:15 - 12:30 0.25 MOB P PRE Held pre-move safety meeting with crew, security & tool services. 12:30 - 13:00 0.50 MOB P PRE Jack-up rig & pull rig off well. Conduct post-operations pad inspection. 13:00 - 00:00 11.00 MOB P PRE Move rig from P-pad to E-pad. 10/29/2005 00:00 - 00:30 0.50 MOB P PRE Move rig from P-pad to E-pad, spot rig over Well E-21, Accepted rig at 00:30 hours on 10/29/05 00:30 - 02:30 2.00 BOPSUF P PRE NU BOP's, level rig 02:30 - 03: 15 0.75 BOPSUF P PRE RU test equipment, attempt to Test BOPS, tree valves not holding 03:15 - 04:00 0.75 BOPSUF N SFAL PRE Waiting on grease truck to service valves, Spot and RU tiger tank, PiT lines 04:00 - 10:00 6.00 BOPSUF P PRE Testing BOPS, all rams, lines and valves f/300 - 3500 psi for 5 min each, Annular 250 - 2500 psi, for 5 mins each, Performed Koomey test. BOPE PT witnessed by BPXA WSLs. John Spaulding w/ AOGCC waived witnessing BOP test. 10:00 - 10:15 0.25 WHIP P WEXIT SLB insert 2 RA pip tags into WFD LSXN 4-1/2" monobore whipstock. RA PIP tag to TOWS = 8.88'. 10:15 - 10:30 0.25 WHIP P WEXIT Install WFD CTC & Pull test to 35k - OK. 10:30 - 11 :45 1.25 WHIP P WEXIT Install dart catcher. Load wiper dart. Launch & chase with 2% KCL. Dart hit @ 55.4bbls. Press test inner reel valve & CTC to 3500psi - OK. Open up well & observe Opsi WHP. lAP = 38psi. OAP = Opsi. 11 :45 - 12:00 0.25 WHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards & WS setting BHA M/U procedures. 12:00 - 12:45 0.75 WHIP P WEXIT M/U WS setting BHA #1 with WFD LSXN 4-1/2" monobore whipstock, setting adapter, hyd setting tool, BKR FAIV, Sperry MWD/GR, orientef & WFD MHA. Scribe WS tray to MWD & M/U injector. 12:45 - 13:00 0.25 WHIP P WEXIT RIH WS setting BHA #1 to 450'. Observe SLB powerpack throttle not dialing well. 13:00 - 13:15 0.25 WHIP N SFAL WEXIT Found loose Allen screw behind power pack throttle. Tighten screw & fix throttle problem. 13:15 - 16:30 3.25 WHIP P WEXIT RIH to 3000'. SHT orienter & MWD @ 1.6bpm/1150psi - OK. Continue RIH WS setting BHA #1 taking diesel returns to outside tank. Wt check @ 10000' - Up = 48k, Down = 23k. RIH & lightly tag CIBP @ 10474'. P/U to up wt & correct CTD to 10450' (SLMD). PUH to 10105' for MWD tie-in. 16:30 - 17:00 0.50 WHIP P WEXIT Log up from 10105' to 10080' @ 1.7bpm/1520psi & tie-into Geology PDC log. Add 11' to CTD. 17:00 - 17:15 0.25 WHIP P WEXIT RBIH to 10450'. 17:15 - 17:40 0.42 WHIP P WEXIT Check TF - @ 153L. Orient TF around to 157R. PUH to 10390'. RBIH to 10413.18' with TOWS @ 10400',4-1/2" Lnr collars @ 10396' & 10436'. 17:40 - 17:50 0.17 WHIP P WEXIT Circ @ 2.93bpm/4270 psi for 2mins. Drop pump to Obpm. Wait 3mins. Bring on pump to 1.8bpm, pressure up & shear off WS @ 1800psi. Continue pumping & observe TF of 179R. SID pumps. Set down 2k @ 10416.1' - WS held. 17:50 - 20:00 2.17 WHIP P WEXIT POOH with WS setting BHA#1 filling the hole via the backside. Paint EOP flag @ 10000', POH to BHA Printed: 11/11/2005 2:10:48 PM " BP EXPLORATION Operations.Summary Report Page 2_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-21 E-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 10/28/2005 11 /9/2005 N1 Spud Date: 11/4/1981 End: Date From - To Hours Task Code NPT Phase Description of Operations 10/29/2005 20:00 - 21 :00 1.00 WHIP P WEXIT LD BHA # 1 21 :00 - 21 :30 0.50 STWHIP P WEXIT M/U window milling BHA #2 with a 3.80" HC DP0261 DWM, 3.80" diamond string reamer, Weatherford PDM, MHA & 2 jts of PH6 tbg (OAL - 81.16'). M/U injector. 21:30-23:10 1.67 STWHIP P WEXIT RIH to XN nipple, Displacing well over to Blo-KCL milling fluid wI .64 bpm at 180 psi, Tag at 9801'. Up wt 42 K, SO wt 22 k 23:10 - 00:00 0.83 STWHIP P WEXIT Milling XN nipple at 9798' to 9799' CTM wI 2.52 bpm at 1375 - 1600 psi 10/30/2005 00:00 - 00:30 0.50 STWHIP P WEXIT Milling XN nipple to 9800' CTM wI 2.52 bpm at 1375 - 1600 psi, worked through nipple several times with no overpulls 00:30 - 01 :30 1.00 STWHIP P WEXIT RIH to TOWS at 10400', EOP at 10000' - correction -11', 01 :30 - 06:30 5.00 STWHIP P WEXIT Milling 3.8" window fl 10400' to 10406' wI 2.42 bpm at 1725 psi I At 02:00 hours on 10/30/05, set clock back 1 hour for daylight savings time. 06:30 - 07:30 1.00 STWHIP P WEXIT Controll mill window from 10406' to 10407' with 2.4/2.4bpm, 1550/1750psi & 5k WOB, Exit into formation @ 10407'. Inspected wellhead bolts and found no loose bolts/nuts. 07:30 - 11 :35 4.08 STWHIP P WEXIT Mill 1 0' formation to 10417' with 2.4/2.4bpm, 1550/1750psi, 2.5fph ave ROP & 7k WOB. Meanwhile swap the well bore to reconditioned (80% used/20% new) 8.6 ppg Flo-Pro mud with 3% L-T & 10ppb K-G. 11 :35 - 12:35 1.00 STWHIP P WEXIT Backream/dress windowlrat hole 3x & drift 2x. Window looks clean. Tentative window depths are: TOWSfTOW = 10400', BOW = 10407', RA PIP Tag = 10408.88'. 12:35 - 14:25 1.83 STWHIP P WEXIT Paint EOP flag @ 10000' & POOH window milling BHA #2, while displacing well to mud. 14:25 - 15:00 0.58 STWHIP P WEXIT PJSM. UD BHA #2 & inspect mills. Window mill gauge 3.80" go I 3.79" no-go & string mill gauge 3.79" go I 3.78" no-go. Wear on window mill face indicated center crossed the liner wall. 15:00 - 15:45 0.75 DRILL P PROD1 Rehead & M/U SLB CTC. Pull test to 35k & pressure test to 3500psi - OK. 15:45 - 16:00 0.25 DRILL P PROD1 Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. 16:00 - 16:30 0.50 DRILL P PROD1 M/U drilling BHA #3 with 3.3deg X-treme motor, MWD/GR, orienter & used Hycalog 3-3/4" x 4-1/4" DSX304 bicenter bit #2. Scribe tools & M/U injector. 16:30 - 17:15 0.75 DRILL N RREP PROD1 Changeout HCR control regulator in Kommey. 17:15 - 19:30 2.25 DRILL P PROD1 RIH drilling BHA#3, EOP at 10000' - -11' correction, RIH to 10360', orient to 160 degree TF, RIH through window to btm at 10417' 1.50 DRILL P PROD1 Orient around TF 155 L 3.00 DRILL P PROD1 Drill wI a 3.3 deg mtr, survey and log wI MWD-GR fl 104 10427' wI 2.51 bpm at 3900 psi 10/31/2005 PROD1 Dir Drill wI a 3.3 deg mtr log wI MWD-GR fl 10427' - 10450' pm at 3800 psi, zone 2b lithology - 90% , 1-2% pyrite, rest cmt'd quartz o 11 OL. P/U wt = 41 k, Run-in wt = 21 k, lAP = 74psi, lAP = 88psi, P s. PROD1 Drill to 10470' with 110L TF, 3250/3550psi,3.5k Printed: 11/1112005 2:10:48 PM e e 1-::::1 J ¡ r~ 'I ¡ U FRANK H. MURKOWSKI. GOVERNOR AI.A.SKA OIL AND GAS CONSERVATION COMMISSION Barbara Holt CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~C~WEL í',~m~ 0 S 2005 Re: PBU E-21A Sundry Number: 305-306 Dear Mrs. Holt: 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 '1 day of October, 2005 Enc!. "" C/1r¡O·-b--oS- ~êÊ'~D e STATE OF ALASKA l)~dI7IS' ALASKA Oil AND GAS CONSERVATION COMMISSION OCT 0 4: 2005 APPLICATION FOR SUNDRY APPROVA~skaOiI&GasCons.Commìssìon 20 MC 25.280 AnchOfsge 1. Type of Request: 181 Abandon / o Alter Casing o Change Approved Program o Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate 0 Other o Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o 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): 65.12' 9. Well Name and Number: 5. permit,J;Q~illNunWer 197-1.....·· . 6. API Number: 50-029-20577-01-00 /" PBU E-21A / 4. Current Well CI~S: IBI Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 8. Property Designation: 10. Field / Pool(s): ADL 028304 Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELLCONOITION $UMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 13401 9022 110' 20" x 30" 110' 110' 2691' 13-3/8" 2691' 2691' 4930 2670 9875' 9-5/8" 9875' 8412' 6870 4760 7526' 7" 2419' - 9945' 2419' - 8472' 7240 5410 3693' 4-1/2" 9794' - 13487' ~ 8342' - 9037' 8430 7500 Perforation Depth MD (ft): 11850' - 13350' Packers and SSSV Type: Perforation Depth TVD (ft): Tubing Size: 8968' - 9014' 4-1/2", 12.6# ~ 7" x 4-1/2" Baker 'S-3' packer; 7" x 4-1/2" Baker 'ZXP' packer; 4-1/2" x 2-7/8" Baker 'FAB-1 Straddle packer Tubing Grade: Tubing MD (ft): L-80 9798' Packers and SSSV MD (ft): 9741'; 9794'; 11800' & 12327' ,/ 12. Attachments: IBI 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 Barbara Holt Title CT Drilling Engineer 005 15. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ IBI Abandoned o WDSPL Contact Barbara Holt, 564-5126 Phone 564-5126 Commission Use Only Date I" Prepared By Name/Number: ~ Terrie Hubble, 564-4628 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: Ap 11 Iv lie d ... 4 C' I r-< ~Vl..o~d -e, I ç:.. Jcìv~~~ f,l,W'I/ £. - 1--/ e, u !RBDMS 8Ft OCT! 0 Z005 Approved Form 10-403 COMMISSIONER APPROVED BY THE COMMISSION Date ORIGINAL e e Obp To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Holt, CTD Engineer Date: September 29, 2005 Re: Prep Prudhoe E-21A for CTD sidetrack Sundry approval is requested to prepare E-21A for a sidetrack. E-21A was a horizontal sidetrack. This well has add-perfs that resulted in gas and subsequently shut off. Acid treatments were attempted; the benefits were short-lived, thus sin -21A to become a cycle well. The well cycled with its twin, E-19A, until 10/04 when the wells wer de-twO n~ed, each well flowing separately. E-21A's cycle behaviour was poor with minimal on- time. The we /" mained a cycle well to date. The sidetrack, E-21B, is scheduled to be drilled by Nordic 1 during the last week of October. The plan calls for running a cmp above the existing perforations prior to setting a whipstock for an exit into Zone 2. E-12B will target Zone lA production. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-IDe: Work 1. Set DGL V Done 12/09/03 2. Confirm pressure integrity. Done 09/20/05 3. Dummy whipstock drift . 4. Set cmp ~ 10,450' MD. Well bore de~on at 58 deg. / 5. Set WFD LSXN 'hipstock with TOWS at 10,400', low side exit. 6. Bleed gas lift and production flowlines down to zero and blind flange 7. Remove wellhouse, level pad. The pre CTI?. w~rk is slated to begin approximately Oct. 10.2005. \ \;vV.. I 0 - A 0 .~ ~ f kì\l C\.. t . IDe: Work 1. MIRU Nordic 1 and test BOPE. 2. Mill 3.725' XN nipple to 3.8" 3. Mill 3.80" window in Zone 2. 4. Drill sidetrack into Zone lA target with Resistivity logging. 5. Run solid liner and cement. 6. Cleanout liner, cased-hole log, and perforate. 7. Freeze protect well and RDMO. Post-IDe: Work 1. Install well house. Hook up flow line. cl,~~~ CTD Drilling Engineer 564-5126 CC: Well File Sondra Stewmanfferrie Hubble PS"FORATION ~!\'( fIEF LOG SPIR'\Y Mtvr:; ON 12117197 ANGlEATTOPP£RF: 10620' 10615' E ...21 SAfETY NOTES: HORIZONTAL WelL 701> 010617' Ut810' WItÐON 9945'·9951' mUCHŒ !!A Y UNir WELL: f·21A ~rr 140: 1971ge;() SEC 8P Expioratioo A/øk") '" SAÆTV NOTES: HORIZONTAL WEll. 70" @ 10617' AND 90" @ 10870' 9·5/8' CSG, 47#, L·80, 10 = 8.681" 4-1/2" SSSV LANDING NIP, 10= 3.813" 13·3/8" CSG, 72#, 1..-80, 10= 12.347" TOP OF 4·1/2" LNR 4-1/2" TBG, 12.6#, L·80, .0152 bpi, 10=3.958' 7" LNR, 26#, L·80, .0383 bpi, 10 = 6.276" MILLOUTWINDOW 9945' - 9951' PERFORA llON SUMMARY AEFLOG: SPERRY SUNMWDON12117/97 ANGLE AT TOP PERF: 90 @ 11850' Note: Reier to PRUDHOE BA Y UNIT WELL: &21A PERMIT No: 1971980 API No: 50-029-20577-01 SEe 6, T11 N, R14E, 1633' FNL .& 883' WEL SF' Exploration (Alaska) I approval Dâe PRlDŒBAY, PRlDŒQL E·21A - Oil Rate (CD) (bbl/d ) - Water Rate (CD) ( Mbbl/d ) Gas Rate (CD) ( MMcfld ) Cum Oil Prod ( Mbbl ) Gas I Oil Ratio ( Mcflbbl ) Water Cut &I 1006 99 19'7-J~Y £~Ji+- 03/15/05 Schlumberger NO. 3363 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATIN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ~ Well Job # Log Description Date Blueline Prints CD ! '16 -(f1ý. C-39 10715421 MCNL 08/19/04 1 'Ý n7-H<? E-21A 10670030 MCNL 08/22/04 1 t9tr /?c· C-29A .- 10715422 MCNL 08/22/04 1 Y ).Cd - í/.?-DS 07-338 10715361 MCNL 11/04/03 1 1 ¡9J-153-07-01A 10889151 RST 08/18/04 1 1 ~f.,~9 X-27 10724364 RST 03/10/04 1 1 .~ "" E-18A 10621786 RST OS/22/04 1 1 !~7-C.·~· 7 DS 01-24A 10563108 RST 10/09/03 1 1 ! ).- ¡'!Z. E-10A 10621797 RST 06/16/04 1 1 1'7;9 Z-12 10704020 RST 07/06/04 1 1 ,l -/01- 10704021 RST 07/07/04 1 1 ZtJl-OO¡, X-15A 1:Þ1.-{;) 1 P1-07A 10831301 RST 07/03104 1 1 . q ;7- 07{);G-03A 10889210 LDL 02/13/05 1 441- 1.1., L5-17 A 10942195 PSP PPROFIDEFT/GHOST 02/28/05 1 : ~i':; -W1 P1-05 10687701 PPROF PSPIDEFT/GHOST 08/13/04 1 ~lf-()¿'i MPC-42 10889141 RST 07/26/04 1 2(;4.{J!3 MPC-42 10621815 RST 08/07/04 1 --- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCAi\H\JEn APR 1 8 2005 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 995.03-28}8 r A TIN: Beth I!... /!. Receiv~1 i~ja/í#.iflH--' Date Delivered: Jj(p /05 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# 10928608 10715445 10964105 10830819 10928610 10670030 (crs:ri3 D-11A :20)-oZODS 07-30A 1Ø2-() j/.{ DS 14-098 Fr5 ,,/62- P2-56 ')r; "'_~ DS 11-06A l'f1--ffð E-21A Log Description MEM PRODIINJECTION PROFILE MEM PROF & IPROF LEAK DETECTION RST MCNL (PRINT ONLY-NO CD) MCNL (PRINT ONLY-NO CD) Date 12/16/04 12/09/04 12/23/04 06/20/04 12/24/04 08/22/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ 900 E. Benson Blvd. c1t Anchorage, Alaska 99508 . / # Date Delivered: Y' ./ tM. S¡O'ANNE?"ì Jj-~ " vò ,i. ~_Jj ~PR .L 9 ?nt1hJ' U s"~",, Blueline 1 1 1 1 1 1 ttj7 - 117~," ~:~iJt~,.,. NO. 3307 ~...,~ 01/18/05 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD --- ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99;7;03_28 A TIN: Beth r t Received by: ~ r¡'l~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 09/30/03 NO. 2981 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 4 00 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD D.S. 5-16B ~ q q --[ ~ LDL 09110103 P2.60. I - PROD PROF,LE W/DEFT 09/13/03 NK-29 - PROD PROFILE W/DEFT 09~09~03 D.S. 3-29 '~ ~ ~ ~ ~q PROD PROFILE W/DEFT 09119103 D.S. 15-18 ~ ~'O('~ SBHP SURVEY 09/19/03 U-08A I ~- ~~ SBHP SURVEY 09~20~03 W-24.. I ~ ~~ ~ / LOL 09/23/03 D.S. 9-06 I ~ I~~ ~ PROD PROFILE W/DEFT 09120103 D.S. 2-08a '1~ ~'~ 23375 CHEDITMCNL 05131/03 ~-23A ~ .... ' 23373 OH EDIT EWE IMPULSE DATA 04/30103 W-23A ~ ~~(~ 23373 MD VISION RESlSTIVI~ 04~30~03 W-23A ~ - ~3373 ~D VISION RESISTIVI~ 04/30/03 ~-23A ~ 23373 MD BOREHOLE PROFILE 04~30~03 MPS-0~ ~,_1~ 10624637 CH EDIT SCMT GR (PDC) . L 08/09/03 MPS-02~~ ~ I 23435 SCMT 08/09/03 MPS-~8X.~.~ ~0999239 CHEmTSCMT~R(PDC) 03/03~03 MPS-18/~ ~ ~ 10559235 SCMT 03103103 .............. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth bp July 29, 2004 Hand -delivered j L John K. Norman, Chairman ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Ave., Ste. 100 Anchorage, Alaska 99501-3539 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Re: Defeated Surface Safety Valves at Wells M-23, E-16 and E-21 Well A-01 Pilot Not Correctly Reset Z ANNEX AUG 2 V, 200 Dear Mr. Norman: This letter is in response to the Commission's June 30, 2004 letter regarding the surface safety valves observed on Wells M-23, E-16 and E-21 during June field inspections. You requested an explanation for why the surface safety valves (SSVs) on these three wells were defeated and our action plan to prevent reoccurrence. BPXA assembled a team of 13 operators and maintenance technicians to review events, possible causes, and develop preventative action plans. Preventative actions include: • Strict enforcement of accountability regarding adherence to SVS practices and administration of disciplinary action in each of these events. • Change -out of valve type to improve visual identification of valve position. • Stringent controls to ensure that SSV systems are correctly set and either secured in the proper position or clearly marked when they are closed. A summary of the team's investigation and findings into the specific events, and an action plan follows: Blocked SSV at Well M-23 One of the needle valves on the main hydraulic line between the hydraulic panel and the actuator of the SSV was found closed during miscellaneous State Testing on June 12, 2004. This prevented the hydraulic oil pressure from being bled -off when the pilot was tripped, thereby preventing the SSV from closing. The hydraulic valve was tie -wrapped in the closed position. Chairman John Norman July 29, 2004 Page 2 Explanation: M-23 was shut in as part of an M -Pad shut down on May 9, 2004, to perform various maintenance activities. While the hydraulic needle valve in question would not typically be closed when the well is shut in, we suspect that it was closed during this time. Activities that could have required the closure of the needle valve include well servicing, valve maintenance, and corrosion monitoring work or use of the well to blow down header pressure. The exact reason for, or date of, closure of the hydraulic needle valve is not known. It is apparent that the needle valve was inadvertently tie -wrapped in the closed position. There are a number of different styles of needle valves used in this service. The length of the stem varies significantly; so an operator cannot tell by looking whether valve is open or closed. Black cable ties are often used to secure the valve in an open position, so if a valve has a black cable tie, an operator can tell by looking that the valve is in the in the proper (open) position. In this case, the valve was erroneously tie -wrapped in the closed, instead of open, position. This indicated (incorrectly) to the operator that the valve was open, and the operator likely did not believe that further verification was needed. Blocked SSVs at Wells E-16 & E-21 During miscellaneous State testing on June 18, 2004, the hydraulic supply block valves on two control panels were found in the closed position, preventing the surface safety valve from closing when the pilot was tripped. Explanation: The valves in question are located on the control panel and are not used by operators on a routine basis. As in the case of the M-23 well, there are a number of other groups that may have used these hydraulic valves to isolate the SVS during their work. While the cause of the inadvertent valve closures remains uncertain, it is apparent that the valves were not verified to be in the proper open position by the operator as is required by the operator during daily rounds. The defeated valves, however, were not tie wrapped nor had they been flagged to indicate they were in the closed position. As in the scenario with Well M-23, the design of the valve is such that visual observation of the valve does not allow for clear indication of the valve position. A-1 Well On July 16, 2004, while testing well A-01, it was discovered that the pilot was not properly reset which resulted in an additional defeated surface safety valve. As discussed with AOGCC staff on July 26th, we are including the explanation and preventative actions for this event as part of our overall action plan. Chairman John Norman July 29, 2004 Page 3 Explanation: The reset switch on A-01 had a "toggle" feature that required the operator to pull the switch and "toggle" the switch open until the nitrogen supply pressure reset the pilot. Once the pilot had been reset, the operator was required to close the toggle switch. The reset switch was inadvertently left in the "toggle -on" position defeating the SVS. A -Pad had been shut down during the GC -3 turnaround, July 9 — 13, 2004. Several operators assisted in bringing A- Pad back onto production, some of which were not familiar with the unique requirements of this toggle switch. With the number of operators involved and the primary operator's attention divided among a number of priority items requiring verification, the reset switch was overlooked. Preventative Actions: These incidents indicate a need for reinforcement and improvement in 3 areas: 1) accountability for SVS practices, 2) improving the ease of identification of hydraulic and control valve position, and 3) the control of operations of the valves to prevent the improper movement of the valves by someone other than the responsible operator. This will be accomplished through the following actions: 1. Accountability will be reinforced through disciplinary action. Documented verbal warnings to the 3 responsible pad operators have been administered and BPXA's expectations regarding the need and importance of proper SVS procedures were reinforced. 2. Identification of valve position will be improved through change -out of hydraulic needle valves to quarter -turn valves. The two needle valves on the main hydraulic lines of M Pad wells will be evaluated for replacement with a single quarter -turn plug valve. This change will reduce the number of valves that could potentially be left in the incorrect position and provides an easily conclusive visual indication of the correct valve position. A Management of Change (MOC) evaluation will be conducted to ensure that one valve is an acceptable modification to the system. 3. Pending completion of the MOC, this modification will be implemented at M Pad and a schedule established for implementation at remaining well pads in the western operating area where similar SVS configurations exist. 4. Availability of a locking device that can be applied to the quarter -turn valves will be evaluated to ensure operators can retain control of the valves. A Chairman John Norman July 29, 2004 Page 4 5. Control and identification of valve position will be improved on control panel valves (similar to those on E-16 and E-21) either through application of tie -wraps or use of flagging. 6. All pilot configurations similar to A-1 have been inspected and all toggle pilots (two were identified) have been replaced with the more common reset switches. Finally, your letter stated that that the failure rates for the (June) tests of M and E -pads resulted in a component failure rate in excess of 10% and that increased testing frequency would be required. As discussed with AOGCC staff, the tests on these pads in June were comprised of a small number of wells (4 at E -pad, 7 at M -pad) that had been shut in during the prior months "routine" scheduled tests. When the results of these "miscellaneous" tests are combined with the routine tests (15 wells at E -Pad in April, and 13 wells at M -Pad in May) a more representative measurement of overall performance is obtained. The resulting combined failure rate at E -Pad is less than 10%, while it is greater than 10% at M -pad. Following discussion with AOGCC staff on this issue, we recommend that the E -pad well testing program remain on the existing 180 day test frequency while the M -pad test frequency is increased to 90 days until acceptable performance is achieved If you have any additional questions, please do not hesitate to contact me at 564-5671 or Bruce Williams at 564-4632. BJW/pj Greater Prudhoe Bay Performance Unit Leader A14A KA. 0IL AND GAS CONSERVATION CODMSSION June 30, 2004 CERTIFIED M 4IL — RETURN RECEIPT REQUESTED 7002 3150 0005 3521 1089 Ms. Maureen Johnson Vice President, Greater Prudhoe Bay BP Exploration Alaska, Inc. P.D. Box 196612 Anchorage, AK 99519-6612 Subject: Defeated Surface Safety Valves at Prudhoe Bay Unit Dear Ms. Johnson: FRANK N. MORKOWSKI, GOVEPIVOR 333 W. 7r' AVENUE, SUITE 100 Ar CHORAGE, ALASKA 99541-3539 PHONE (807) 279-1433 FAX (967) 276.7542 On June 12 and 18, 2004, Alaska Oil and Gas Conservation Commission ("Commission") inspectors, accompanied by a BPXA representative, performed safety valve system ("SVS") inspections at Prudhoe Bay M- and E -pads, respectively. Commission inspectors noted that the surface safety valve ("SSV") on `]yells M-23, E-16 and E-21 had been blocked at the control panel some time prior to the inspections, preventing each well's SSV from operating. Copies of the inspection reports are attached. You are reminded that Conservation Order No. 363 (Prudhoe Oil Pool), Rule 5 modifies the requirements of 20 AAC 25.265 ("Automatic Shut-in Equipment") as follows: (a) Each well shall be equipped with a Commission approved fail-safe automatic surface safety valve system (SYS) capable of preventing uncontrolled flow by shutting of) flow at the wellhead and shutting down any artificial lift system where an over pressure of equipment may occur. (b) The safety valve system (SYS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned. ff the SYS cannot be returned to service within 24 hours, the well must be shut in at the wellhead and at the manifold building. 1. Wells with a deactivated SYS shall be identified by a sign on the wellhead stating that the SUS has been deactivated and the date it was deactivated. 2. A list of wells with the SYS deactivated, the dates and reasons for deactivating, and the estimated re -activation dates must be maintained current and available for Commission inspection on request. t&ANNEt JvI_ I' 200: Ms. Maureen Johnson June 30, 2001 Page 2 of 2 Conservation Order No. 363 replaced the requirements of earlier Conservation Order No. 341 (Prudhoe Oil Pool) pool rules by providing for the elimination of subsurface safety valves ("SSSV") in certain wells. The elimination of the SSSV in Prudhoe Bay wells increases the reliance on the surface safety equipment. The facts reported by our inspectors appear to indicate a failure to maintain an operable SVS in each well, which is a violation of Commission regulations. Within 30 days of receipt of this letter, you are requested to provide the Commission with an explanation of how these events happened and what will be done in the future to prevent its occurrence in BPXA-operated fields. We note that this is the fourth such letter sent to BPXA since July 2003 regarding defeated safety valve systems at BPXA-operated fields. Also noted during the inspections of M- and E -pads were SVS component failure rates of 21 and 25 percent, respectively. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. Effective the date of inspections, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU M- and E -pads must be tested every 90 days. When testing is scheduled, you must notify the Commission field inspector at 907-659- 2714 to provide an opportunity to witness the SVS test. The Commission reserves the right to pursue enforcement action in connection with these apparent violations as provided by 20 AAC 25.535. Should you have any questions regarding this correspondence, please contact Mr. James Regg at ( 907) 793-1236. Attachments Reviewed By: Safety Valve & Well Pressures Test Report P.I.Supry, Comm Pad: PBLI_E Insp IN 6/18/2004 Inspected by Chuck Scheve Interval InspNo sysC5040618204253 Related [nsp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Mery Liddiow Reason Miscella Src: Inspector Well Data ---._.... -- --- _... _ _ .._..._.._ Pilots _ �_._._..—._.—:....W SSTf` : Shutln De Wel! Type Well Pressures Gas L{fI . Walver Cartamet7ts Well Permit Separ Set Lip Test Test Test Date SI Oil,WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Cade Code Code GAS,CYCL.E, SI PSI PSI PSI Yes/No Yes/No E-16 _ 1800630 160 125 130 P p - _ -- - y.- I-OIL E-21A 1971980 670 550 550 P 50--- E-27A 1990590 160 125 125 P P 1.011„ — E-36 1950730 -670 550 505 P P - -- I -OIL -- - - Comments Performance The Surface Safety Valve on Wells E- 16 and E-21 were blocked at the panel rendering them useless. W[Ig Components Failures Failure Rate Both systemep s passed their tests when lined up properly. 4 8 2 25% Tuesday, June 29, 2004 t" STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE] SuspendE~ Operation ShutdownE] Perforator'-] VarianceE] Annuar DisposalE] After casinqE] Repair WellE] Plu.q PerforationsE~] stimulate[] Time Extension E] Otherr-I Change Approved ProgramE] Pull TubingF-~ Perforate New PoolE] Re-enter Suspended WellE] ACID TREATMENT 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development ~ ExploratoryE] 197-198 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic E] Service E] 50-029-20577-01-00 7. KB Elevation (ft): 9. Well Name and Number: 65.12 E-21A 8. Property Designation: 10. Field/Pool(s): ADL 028304 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 13487 feet true vertical 9038 feet Plugs (measured) Effective Depth measured 13401 feet Junk (measured) true vertical 9022 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 137' 137' 40K 520 Surface 2664' 13-3/8" 2691' 2691' 80K 2670 Intermediate 9848' 9-5/8" 9875' 8410' 80K 4760 Liner 7526' 7" 2419'-9945' 2419'-8472' 80K 7020 Sidetrack Liner 3693' 4-1/2" 9794'-13487' 8342'-9037' 80K 7500 Perforation depth: Measured depth: Open Perfs 12750'~13100', 13150'-13350'. Open Perfs Covered with Straddle PKR Assembly 11850'-12170', 12200'-12260'. True vertical depth: Open Perfs 8973'-8977', 8982'-9014'. Open Perfs Covered with Straddle PKR Assembly 8968'-8968', 8968'-8968'. Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 9798'. 4-1/2" x 2-7/8" Straddle PKR Assembly @ 11800'- 12327'. Packers & SSSV (type & measured depth) 7" x 4-1/2" BKR S-3 Packer @ 9741'. 7"x 4-1/2" HES SSSV Landing Nipple @ 2219'. 12. Stimulation or cement squeeze summary: JUL 0 ~ L003 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Avera,qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: 506 10154 39 787 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development~ servicer-] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Oil~ GasD WAGr-I GINJI'"I WlNJI-'I WDSPLD Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact DeWayne R. Schnorr I NIA Printed Name__ , ~, ,,~ ,,)DeWa)/ne R. Schnorr Title Techical Assistant Signature ~'~,,~2,-~,~~~~ Phone 907/564-5174 Date June1612003 //- ~_. ~ ~ I F" i ix i Form 10-404 Revised ANNED' :JUL 0 9 2.003 E-21A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/18/2003 ACID: AC-TIFL 05/20/2003 ACID: DRIFT/TAG 05/25/2003 ACID: AC-MONITOR 05/26/2003 ACID: AC-MONITOR 05/28/2003 ACID: ACID TREATMENT 06/11/2003 TESTEVENT --- BOPD: 436, BWPD: 53, MCFPD: 9,485, AL RATE: 0 EVENT SUMMARY 05/18/O3 T/I/O=1920/1340/0. WELL IS SI. TIFL PASSED FOR (ACID STIMULATION). INITIAL IA FL @ 7613' (STATION #1 @ 7837'). BLED IA FROM 1340 PSI TO 330 PSI IN 1.5 HOURS. POST IA BLEED FL @ 7613. MONITORED lAP FOR ONE HOUR. NO INCREASE IN lAP. NO AL LINE ON THIS WELL. FINAL W H P's= 1920/330/0. O5~20/O3 ***WELL SHUT IN UPON ARRIVAL*** (PRE ACID STIM). TAG HYDRATES @ 2' SLM W/3.5" CENT., CHANGED TO 2.25" CENT AND MADE DOWN TO 10620' SLM (STOPPED DUE TO DEVIATION). ***WELL LEFT SHUT IN*** 05/25/03 T/I/O = 2000/480/0. ATTEMP TO SAMPLE. WELL IS SHUT-IN. O5/26/O3 T/I/O = 360/670/120. TEMP = 81. E-25 SAMPLE FOR DOWELL LAB. (PREP FOR E-21 ACID STIM). O5/28/O3 ACID TREATMENT, MIRU DS CTU #9. LOAD WELL WITH 195 BBLS KCL +5 BBLS 50/50. RIH WITH 2" JSN. TAGGED @ 13367' CTM. PUMPED 51 BBLS 12% DAD ACID WHILE RECIPROCATING PIPE ACROSS PERFS. OVERFLUSH ACID WITH 100 BBLS FILTERED 2% KCL. INITIAL INJECTION 1.5 BPM/150 WHP/2100 CTP - FINAL - 1.5 BPM/52 WHP/2035 CTP. POOH. WELL APPEARED TO BE BUILDING WHP. ARRANGE FOR PBGL TO HELP POP. NOTIFY PAD OP AND REQUEST TO POP, LET WELL CLEAN UP AND PUT IN TEST. RDMO. <<< JOB COMPLETE >>> 06/11/03 TESTEVENT --- BOPD: 436, BWPD: 53, MCFPD: 9,485, AL RATE: 0 FLUIDS PUMPED BBLS 46 50/50 METHANOL 295 2% KCL WATER 50 12% DAD ACID 391 TOTAL Page I TREE= 4-1/2" 5M CIVV SAFETY NOTES: HORIZONTALWELL. 70° E 21A -,~'~Ti. AY-O~R-~ ....... B~K-¢:~ m @ 10617' AND 90° @ 10870' 2219' I--JJ4-1/Z' SSSV LANDING NIP, 19 = 3.813" I 3006' I I Datum MD = 10528' Datum TVD = 8800' SS ITOPOF7''TIEBAcKLi'~R H 2419' GAS LIFT MA t~DRELS I 13-3/8"CSG'72#'L-~0'~D=~2'347"H 2691' ST MD TVDD~VTYPEVLV LATCHPORTDATE 2 44354200 38 CAM DO~ BTM 1~ 01/13/98 ! 1 78376748 46 CAM S/O BTM 20 01/13/98 Minimum ID = 2.375" @ 12315' BKR FAB-1 STRADDLE PKR I*c~ o~ 7" LNR H 937O' I I 9741' I-~ 7" X 4-1/2" BKRS-3PKR, ID =3.875" I ~ - I I I I - --1 ~7~4' Ifl~-~' H~S x N,,. ,~ = ~.~" I I I- I 9785', H4'l/2""mXNNIP, ID=3.725"I I TOPOF4-1/2" LNR Iq 9794' I IJ I ~ x ~ ~ 9794' i~ 7" x 4-1/2" BKR ZXP PKR, ID = 4.438" i I I/ ~-~,~"~,~.~,,-~o,o.o~,,D=~.~" H 9798' '1 I1 9798' H*I/2WLEGI MILLOUTWINDOW @@45'- ~51'I PI~FORATION SUMMARY REF LOG: BHC8 on ..... (date) ANGLEATTOP FERF: 84@ 13150'perf X ~ / ~ . Note: Refer to Production DB for historical data 11800 ~4-1/2" X 2-7/8" BKP, FA B-1 STRADDLEI SIZE SPF INTERVAL Opn/Sqz DATE Cc 2-7/8" 4 12200- 12260 12327. I~1 I---~1 2-3/4" 4 12750 - 13100 O 12/22/97 2-3/4" 4 13150 - 13350 O 12/22/97 13401' J H , I I 4-1/2" LNR, 12.6~, L-80, 0.0152 bpf, ID = 3.953" 13487' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ? ORIGINAL COIVPLErlON WELL: E-21A 12/22/97 JLM SIDETRACK COMPLETION PERMIT No: 1971980 01/10/02 RN/TP CORRECTIONS APINo: 50-029-20577-01 01/21/02 JAF/tlh ADDPERFS SEC6, TllN, R14E 1633'FNL&883'WEL 02/26/03 CMO/KK MAX ANGLE CORRECTION 02/28/03 KSB/KK SETSTRADDLEPKR BP Exploration (Alaska) , SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11850 - 12170 C 01/21/02 2-7/8" 4 12200 - 12260 C 01/21/02 2-3/4" 4 12750 - 13100 O 12/22/97 2-3/4" 4 13150 - 13350 O 12/22/97 AOGCC Geological Materials Inventory TD i~,. PERMIT 97-198 BP EXPLORATION Log Data Sent Received Box 8218 6[~51,52 SPER MPT/GR/EWR4/CNO/SLD 1/21/1998 1/21/1998 DGR/CNP/SLD-MD ~88-13485 1/21/1998 1/21/1998 DGR/CNP/SLD-TVD ~ 8496-9036 1/21/1998 1/21/1998 DGR/EWR4-MD ~¢988-13485 1/21/1998 1/21/1998 · NGP/DGR/EWR4-TVD cL--~'~8496-9036 1/21/1998 1/21/1998 PLUG SET ~w~9850-9992 1/12/1998 1/16/1998 / 40. Completion Date )~/~_/c[ ) Daily well ops /~//~16/cl7_ ,]olj.~3,/q ~ Are dry ditch samples required? Was the well cored? Are tests required? Well is in compliance Comments yes ~no And reee~ ~ yes :- no yes ~_~_ no ,~.,,_..~jes~ - - ~'-""II'~-" Received? y e?_~.~_~.~__llll~ ...... Initial Analysis _description received? ~' no Wednesday, October 13, 1999 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION " ' ..... -, WELL COMPLETION OR RECOMPLETION REPORT AND"EOGi.. ' ' .... " 1. Status of Well Classification of Service W~ll [~ Oil E~ Gas E~ Suspended ~--~ Abandoned E~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-198 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20577-01 4. Location of well at surface i~ '~i.; .-:i :. 9. Unit or Lease Name 1633' SNL, 883' WEL, SEC. 6, T11 N, R14E, UM ~"~' ':"~-- Prudhoe Bay Unit At top of productive interval ~ ~ '---.~,,,.,.-~._.-., ~~.~¢.. ~ i0. Well Number ~ .... E-21A 385' SNL, 3816' WEL, SEC. 7, T11N, R14E, UM:::,.: :;i At total depth !'~ ~ ''*~ ¢~:¢]~ i 11. Field and Pool 1847' SNL, 4528' WEL, SEC. 7, T11 N, R14E, UM ............ :.~ : Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Pool KBE = 65.12' ADL 028304 12. Date Spudded I 13. Date I.D. Reached I 14. Date Comp., Susp., °r Aband. I15. Water depth, if offshore I16. No. of Completions 12/8/97 12/16/97 12/22/97 N/A MSLI One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost ' 13487 9038 FTI 13391 9020 FTI [~Yes E~No (Nipple) 2219' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR, RES, NEU, DEN 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20"X 30" Insulated Conductor Surface 110' 36" 8 cu )/ds concrete 13-3/8" 72# L-80 Surface 2691' 17-1/2" :~720 cu ft Arctic Set II 9-5/8" 47# L-80 Surface 9875' 12-1/4" 1351 cu ft Class 'G', 130 cu ft Arctic Set I 7" 26# L-80 2419' 9945' 8-1/2" 414 cu ft Class 'G' 4-1/2" 12.6# L-80 9794' 13487' 6" 520 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9798' 9741' MD TVD MD TVD 12750' - 13100' 8973' - 8977' 13150' - 13350' 8982' - 9014' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 140 Bbls of Diesel Date First Production I Method of Oparation (Flowing, gas lift, etc.) Februar! 1, 1998 I Fl°win9 Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure [CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate I 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 9940' 8468' Shublik 9991' 8511' Top of Sadlerochit 10072' 8579' Zone 4A 10125' 8621' Zone 3 10218' 8689' Zone 2C 10302' 8743' Zone 2B 10382' 8789' Zone 2A 10752' 8923' , , Zone 1 B 11642' 8963' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certif~that the foregoin~i)s true and correct to the best of my knowledge Signed :kC~;,x..¢,~ ~'~- ,~,~~:~ Jame/~ lA, E//2 - 97-198 Title Engineering Supervisor Date .. Prepared By Name/Number: Terrie Hubble, 564-4628 Wetl Number Permit No. / Approval No. ~NSTRUCTIONS 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 Facility Date/Time 30 Nov 97 01 Dec 97 02 Dec 97 03 Dec 97 04 Dec 97 PB E Pad 12:00-12:30 12:30-15:30 15:30-22:00 22:00-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-16:00 16:00-20:30 20:30-22:00 22:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-15:00 15:00-16:00 16:00-16:30 16:30-23:00 23:00-00:00 00:00-00:30 00:30-01:30 01:30-06:00 06:00-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-17:00 17:00-18:00 18:00-19:00 19:00-19:30 19:30-22:00 22:00-22:30 22:30-00:00 00:00-00:30 00:30-04:30 04:30-05:00 05:00-06:00 06:00-08:00 08:00-09:30 09:30-12:00 Duration 1/2 hr 3hr 6-1/2 hr 2hr 1/2 hr 4hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr 4-1/2 hr 1-1/2 hr 1/2 hr lhr 1/2 hr 1/2hr 4-1/2 hr lhr 1/2 hr lhr 1/2 hr 3hr lhr 1/2 hr 1/2 hr 2hr lhr 1/2 hr 6-1/2 hr lhr 1/2 hr lhr 4-1/2 hr 3hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2hr 4hr lhr lhr 1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2hr 4hr 1/2 hr lhr 2hr 1-1/2 hr 2-1/2 hr Progress Report Well E-21a Rig Doyon # 9 Page Date Activity Held safety meeting Rig moved 100.00 % Rig moved 100.00 % Retrieved Hanger plug Held safety meeting Circulated at 9328.00 ft Circulated at 9328.00 ft Circulated at 9328.00 ft (cont...) Investigated pressure change Held safety meeting Installed Hanger plug Removed Xmas tree primary components Rigged up BOP stack Rigged up Pipe ram Rigged up BOP stack Rigged up High pressure lines Tested BOP stack Held safety meeting Tested Well control Retrieved Hanger plug Retrieved Hanger plug (cont...) Installed Tubing retrieval string Pulled Tubing on retrieval string to 9300.00 ft Circulated at 9300.00 ft Circulated at 9300.00 ft Held safety meeting Serviced Draw works Laid down 2000.00 ft of Tubing Rigged down Handling equipment Laid down 1068.00 ft of Tubing Laid down 6232.00 ft of Tubing Made up BHA no. 1 Held safety meeting Made up BHA no. 1 R.I.H. to 6000.00 ft R.I.H. to 6000.00 ft (cont...) Fished at 9341.00 ft Circulated at 9341.00 ft Held safety meeting Serviced Drillfloor / Derrick Pulled out of hole to 835.00 ft Pulled BHA Installed B ore protector Made up BHA no. 2 R.I.H. to 9332.00 ft Fished at 9355.00 ft Circulated at 9355.00 ft Held safety meeting Pulled out of hole to 835.00 ft Pulled BHA Laid down fish Laid down fish (cont...) Rigged down Handling equipment Conducted electric cable operations 1 13 January 98 Facility Date/Time 05 Dec 97 06 Dec 97 07 Dec 97 08 Dec 97 PB E Pad Progress Report Well E-21a Rig Doyon # 9 Page Date Duration Activity 12:00-12:30 12:30-13:00 13:00-13:30 13:30-15:30 15:30-18:30 18:30-19:30 19:30-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-03:30 03:30-05:30 05:30-06:00 06:00-07:00 07:00-07:30 07:30-09:30 09:30-10:30 10:30-11:00 11:00-11:30 11:30-12:00 12:00-12:30 12:30-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-03:00 03:00-06:00 06:00-12:00 12:00-12:30 12:30-22:00 22:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-03:30 03:30-05:00 05:00-06:00 06:00-10:30 10:30-11:30 11:30-12:30 12:30-13:00 13:00-13:30 13:30-17:00 17:00-18:30 18:30-19:30 19:30-21:30 21:30-00:00 00:00-00:30 00:30-02:00 02:00-02:30 02:30-06:00 06:00-12:00 12:00-12:30 1/2hr 1/2 hr 1/2 hr 2hr 3hr lhr 2-1/2 hr lhr lhr 1/2 hr 3hr 2hr 1/2 hr lhr 1/2hr 2hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 10hr lhr 1/2 hr 1/2 hr 1/2 hr 2hr 3hr 6hr 1/2 hr 9-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 3hr 1-1/2 hr lhr 4-1/2 hr lhr lhr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr lhr 2hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 6hr 1/2hr Held safety meeting Conducted electric cable operations Monitor pressures Rig waited · Orders Conducted electric cable operations Retrieved B ore protector Ran Drillpipe to 4000.00 ft (3-1/2in OD) Removed BOP stack Removed Tubing head spool Held safety meeting Installed Seal assembly Rigged up BOP stack Tested BOP stack Tested BOP stack (cont...) Installed B ore protector Pulled Drillpipe in stands to 0.00 ft Tested Casing Made up BHA no. 3 Rig waited · Equipment Made up BHA no. 3 Held safety meeting R.I.H. to 9928.00 ft Set tool face Rig waited · Materials Held safety meeting Functioned Downhole tools Circulated at 9946.00 ft Milled Casing at 9951.00 ft Milled Casing at 9958.00 ft (cont...) Held safety meeting Milled Casing at 9973.00 ft Reamed to 9973.00 ft Pulled out of hole to 8000.00 ft Serviced Drillfloor / Derrick Held safety meeting Pulled out of hole to 900.00 ft Pulled BHA Made up BHA no. 4 R.I.H. to 9901.00 ft Serviced Block line R.I.H. to 9971.00 ft Held safety meeting Circulated at 9973.00 ft Pulled out of hole to 860.00 ft Pulled BHA Serviced BOP stack Made up BHA no. 5 R.I.H. to 6000.00 ft Held safety meeting R.I.H. to 9927.00 ft Washed to 9973.00 ft Drilled to 10055.00 ft Drilled to 10226.00 ft (cont...) Held safety meeting 2 13 January 98 Facility Date/Time 09 Dec 97 10 Dec 97 11 Dec 97 12 Dec 97 13 Dec 97 14 Dec 97 PB E Pad Progress Report Well E-21a Rig Doyon # 9 Page Date 12:30-00:00 00:00-00:30 00:30-06:00 06:00-07:00 07:00-08:30 08:30-12:00 12:00-12:30 12:30-14:00 14:00-15:00 15:00-16:00 16:00-20:00 20:00-20:30 20:30-23:30 23:30-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-02:30 02:30-03:30 03:30-06:00 06:00-07:00 07:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-17:30 17:30-19:30 19:30-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-12:00 12:00-12:30 12:30-13:30 13:30-15:30 15:30-16:00 16:00-16:30 16:30-18:00 18:00-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-22:30 22:30-00:00 00:00-00:30 00:30-01:00 01:00r02:30 Duration 11-1/2 hr 1/2 hr 5-1/2 hr lhr 1-1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr lhr lhr 4hr 1/2 hr 3hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr lhr 2-1/2 hr lhr 5hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 5hr 2hr 4hr 1/2 hr 1/2 hr 1-1/2 hr 1/2hr 3-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr lhr 2hr 1/2hr 1/2 hr 1-1/2 hr 6hr 1/2hr 5-1/2 hr 6hr 1/2 hr 10hr 1-1/2 hr 1/2hr 1/2 hr 1-1/2 hr Activity Drilled to 10576.00 ft Held safety meeting Drilled to 10675.00 ft Drilled to 10687.00 ft (cont...) Circulated at 10687.00 ft Pulled out of hole to 6380.00 ft Held safety meeting Pulled out of hole to 790.00 ft Pulled BHA Made up BHA no. 6 Tested BOP stack Made up BHA no. 6 R.I.H. to 6000.00 ft Serviced Drillfloor / Derrick Held safety meeting R.I.H. to 9891.00 ft Laid down 280.00 ft of 3-1/2in OD drill pipe Tested Kelly cocks R.I.H. to 10273.00 ft Reamed to 10635.00 ft Reamed to 10687.00 ft (cont...) Drilled to 10954.00 ft Held safety meeting Drilled to 11527.00 ft Held safety meeting Drilled to 11760.00 ft Drilled to 11941.00 ft (cont...) Held safety meeting Drilled to 12069.00 ft Circulated at 12069.00 ft Pulled out of hole to 9850.00 ft Serviced Drillfloor / Derrick Held safety meeting Pulled out of hole to 789.00 ft Pulled BHA Made up BHA no. 7 Made up BHA no. 7 (cont...) R.I.H. to 9945.00 ft Held safety meeting Serviced Block line R.I.H. to 11516.00 ft Reamed to 11560.00 ft R.I.H. to 11866.00 ft Reamed to 12069.00 ft Drilled to 12260.00 ft Held safety meeting Drilled to 12430.00 ft Drilled to 12579.00 ft (cont...) Held safety meeting Drilled to 12928.00 ft Circulated at 12928.00 ft Held safety meeting Circulated at 12928.00 ft Pulled out of hole to 11421.00 ft 3 13 January 98 Facility PB E Pad Progress Report Well E-21a Page 4 Rig Doyon# 9 Date 13 January 98 Date/Time 15 Dec 97 16 Dec 97 17 Dec 97 18 Dec 97 02:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-15:00 15:00-17:00 17:00-19:30 19:30-20:30 20:30-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-03:00 03:00-03:30 03:30-04:00 04:00-06:00 06:00-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-02:30 02:30-05:00 05:00-06:00 06:00-07:30 07:30-12:00 12:00-12:30 12:30-18:00 18:00-19:00 19:00-20:30 20:30-21:00 21:00-23:00 23:00-02:00 02:00-02:30 02:30-06:00 06:00-08:00 08:00-08:30 08:30-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-17:30 17:30-01:30 01:30-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-i2:00 12:00-12:30 12:30-13:30 13:30-13:45 13:45-14:15 14:15-14:30 14:30-15:00 15:00-15:30 Duration 3-1/2 hr 3hr 3hr 1/2 hr 2-1/2 hr 2hr 2-1/2 hr lhr 3hr 1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2hr 2hr 6hr 1/2 hr 11-1/2 hr 1/2 hr 2hr 2-1/2 hr lhr 1-1/2 hr 4-1/2 hr 1/2 hr 5-1/2 hr lhr 1-1/2 hr 1/2hr 2hr 3hr 1/2 hr 3-1/2 hr 2hr 1/2 hr 2hr 1/2 hr lhr 1/2hr 5hr 8hr 4-1/2 hr 1/2 hr lhr 2hr 2-1/2 hr 1/2hr lhr 1/4 hr 1/2 hr 1/4 hr 1/2 hr 1/2 hr Activity Logged hole with LWD: DIR/FE from 10600.00 ft to 11421.00 ft Logged hole with LWD: DIR/FE from 11421.00 ft to 10593.00 ft (cont... Pulled out of hole to 5154.00 ft Held safety meeting Pulled out of hole to 822.00 ft Pulled BHA Downloaded MWD tool Made up BHA no. 8 R.I.H. to 8840.00 ft Serviced Drillfloor / Derrick Held safety meeting R.I.H. to 12173.00 ft Reamed to 12196.00 ft R.I.H. to 12821.00 fl Reamed to 12928.00 ft Drilled to 12972.00 ft Drilled to 13119.00 ft Held safety meeting Drilled to 13406.00 ft Held safety meeting Drilled to 13480.00 ft Circulated at 13480.00 ft Pulled out of hole to 13200.00 ft Pulled out of hole to 11166.00 ft (cont...) Logged hole with LWD: DIR/FE from 11166.00 ft to 10847.00 ft Held safety meeting Logged hole with LWD: DIR/FE from 11290.00 ft to 10847.00 ft Pulled out of hole to 9923.00 ft R.I.H. to 13440.00 ft Reamed to 13480.00 ft Circulated at 13480.00 fl Pulled out of hole to 9635.00 ft Flow check Pulled out of hole to 3400.00 ft Pulled out of hole to 200.00 fl (cont...) Pulled BHA Downloaded MWD tool Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 3580.00 ft (4-1/2in OD) Ran Tubing to 3550.00 ft (2-7/8in OD) Ran Liner on landing string to 9400.00 ft Ran Liner on landing string to 9918.00 ft (cont...) Circulated at 9918.00 fl Ran Liner on landing string to 13487.00 ft Circulated at 13487.00 ft Held safety meeting Batch mixed slurry - 92.000 bbl Pumped Water spacers - volume 20.000 bbl Tested High pressure lines Pumped Water spacers - volume 50.000 bbl Mixed and pumped slurry - 92.000 bbl Displaced slulTy - 84.300 bbl Facility Date/Time 19 Dec 97 20 Dec 97 21 Dec 97 22 Dec 97 Progress Report PB E Pad Well E-21a Page 5 Rig Doyon # 9 Date 13 January 98 15:30-19:00 19:00-21:30 21:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-12:30 12:30-13:00 13:00-17:30 17:30-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-07:30 07:30-08:30 08:30-09:30 09:30-10:15 10:15-10:30 10:30-12:00 12:00-12:30 12:30-23:00 23:00-00:00 00:00-00:30 00:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-14:30 14:30-15:30 15:30-17:15 17:15-21:30 21:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-02:15 02:15-03:00 03:00-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-14:00 Duration 3-1/2 hr 2-1/2 hr 2hr 1/2 hr 1/2 hr 1/2 hr lhr 3hr lhr 1/2 hr 1-1/2 hr 2hr 2-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1-1/2 hr 4hr 1-1/2 hr lhr lhr 3/4 hr 1/4 hr 1-1/2 hr 1/2 hr 10-1/2 hr lhr 1/2 hr 5hr 1/2 hr 1/2hr 1/2 hr 7-1/2 hr lhr 1-3/4 hr 4-1/4 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2hr 3/4 hr 3/4 hr 1/2 hr 1/2hr lhr lhr lhr 7hr Activity Circulated at 13390.00 ft Pulled Drillpipe in stands to 9792.00 ft Circulated at 9792.00 ft Serviced Drillfloor / Derrick Held safety meeting Tested Liner - Via string Serviced Block line Pulled Drillpipe in stands to 3600.00 ft Laid down 3600.00 ft of Tubing Held safety meeting Laid down 3600.00 ft of Tubing Serviced Drillfloor / Derrick Laid down 3600.00 ft of Tubing Retrieved Wear bushing Tested BOP stack Installed Wear bushing Held safety meeting Ran Tubing to 3640.00 ft (2-7/8in OD) Held safety meeting Ran Tubing to 3640.00 ft (2-7/8in OD) Ran Drillpipe in stands to 11400.00 ft Ran Drillpipe in stands to 13391.00 ft (cont...) Tested Completion equipment Perforated Reverse circulated at 13351.00 ft Flow check Laid down 930.00 ft of Drillpipe Held safety meeting Laid down 12500.00 ft of Drillpipe Rigged down sub-surface equipment - Perforating tools Held safety meeting Rigged down sub-surface equipment - TCP Rigged up Tubing handling equipment Rigged up Tubing handling equipment (cont...) Held safety meeting Ran Tubing to 7575.00 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 9802.00 ft (4-1/2in OD) Installed Hanger assembly Reverse circulated at 9784.00 ft Held safety meeting Ran Tubing on landing string to 9798.00 ft Functioned Packer assembly Tested Tubing Tested Tubing Retrieved Tubing landing string Rigged down sub-surface equipment - SCSSSV control line Rigged down BOP stack Installed SCSSSV control line Installed Wellhead primary components Installed Accessories SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING PBU / E-21A 500292057701 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121697 MWD SURVEY JOB NUMBER: AKMM80035 KELLY BUSHING ELEV. = 65.12 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9905.94 8438.47 8373.35 30 31 S 61.20 W .00 2623.35S 3254.02W 2952.22 9945.00 8472.15 8407.03 30 20 S 61.'00 W .53 2632.91S 3271.34W 2963.55 9958.00 8483.37 8418.25 30 16 S 60.94 W .50 2636.09S 3277.08W 2967.32 9979.83 8502.01 8436.89 32 30 S 55.78 W 15.96 2642.07S 3286.74W 2974.28 10011.91 8528.89 8463.77 33 43 S 48.79 W 12.50 2652.79S 3300.57W 2986.40 10043.93 8555.45 8490.33 34 13' S 42.18 W 11.63 2665.32S 3313.31W 3000.21 10076.17 8582.07 8516.95 34 32 S 35.83. W 11.17 2679.45S 3324.75W 3015.47 10106 94 8607.01 8541.89 37 8 S 30.'19 W 13.63 2694.56S 3334.54W 3031.53 10139.02 8632.11 8566.99 39 53 S 26.06 W 11.73 2712.18S 3343.93W 3050.04 10170 92 8656.09 8590.97 42 39 S 21.71 W 12.50 2731.42S 3352.42W 3070.07 10200 09 8677.12 8612.00 45 7 S 16.24 W 15.49 2750.54S 3358.97W 3089.77 10233.27 8699.89 8634.77 48 13 S 11.83 W 13.46 2773.94S 3364.80W 3113.66 10265 38 8720.51 8655.39 51 52 S 6.43 W 17.18 2798.23S 3368.67W 3138.23 10297.37 8739.84 8674.72 53 49 S 1.06 W 14.69 2823.66S 3370.32W 3163.69 10329 50 8758.66 8693.54 54 28 S .82 E 5.16 2849.70S 3370.37W 3189.58 10361 56 8777.05 8711.93 55 31 S 2.86 E 6.16 2875.94S 3369.53W 3215.59 10393.70 8795.33 8730.21 55 7 S 2.95 E 1.23 2902.34S 3368.19W 3241.70 10425 86 8813.56 8748.44 55 48 S 4.35 E 4.16 2928.78S 3366.50W 3267.81 10457.85 8830.93 8765.81 58 26 S 6.64 E 10.18 2955.51S 3363.92W 3294.13 10489.84 8847.15 8782.03 60 35 S 8.05 E 7.75 2982.85S 3360.39W 3320.94 10521.89 8862.32 8797.20 62 52 S 9.84 E 8.65 3010.73S 3356.00W 3348.20 10553.94 8876.39 8811.27 65 1 S 11.01 E 7.47 3039.05S 3350.79W 3375.80 10584.69 8888.44 8823.32 68 49 S 11.98 E 12.66 3066.76S 3345.15W 3402.77 10616.62 8898.89 8833.77 72 58 S 13.56 E 13.84 3096.18S 3338.47W 3431.32 10647.66 8907.30 8842.18 75 34 S 13.98 E 8.45 3125.20S 3331.36W 3459.42 10679.82 8914.27 8849.15 79 24 S 14.70 E 12.11 3155.61S 3323.59W 3488.84 10711.91 8919.07 8853.95 83 23 S 16.96 E 14.25 3186.12S 3314.93W 3518.27 10742.90 8922.07 8856.95 85 30 S 19.42 E 10.43 3215.42S 3305.30W 3546.39 10775.12 8923.68 8858.56 88 46 S 23..81 E 16.97 3245.33S 3293.45W 3574.88 10807.16 8924.04 8858.92 89 58 S 24.99 E 5.25 3274.50S 3280.22W 3602.49 10870.36 8923.83 8858.71 90 24 S 25.36 E .90 3331.70S 3253.33W 3656.53 10934.29 8924.33 8859.21 88 42 S 26.05 E 2.86 3389.29S 3225.61W 3710.88 10999.05 8926.34 8861.22 87 43 S 25.93 E 1.54 3447.47S 3197.25W 3765.74 11062.12 8929.24 8864.12 87 0 S 26.58 E 1.53 3503.97S 3169.38W 3818.98 11125.60 8932.67 8867.55 86 48 S 26.44 E .40 3560.69S 3141.08W 3872.40 SPERRY-SUN DRILLING sERvICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU / E-21A 500292057701 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121697 MWD SURVEY JOB NUMBER: AKMM80035 KELLY BUSHING ELEV. = 65.12 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11189.31 8936.66 8871.54 86 1 S 24.00 E 4.01 3618.20S 3114.00W 3926.73 11253.27 894i.26 8876.14 85 44 S 23.32 E 1.15 3676.63S 3088.39W 3982.13 11316.65 8946.20 8881.08 85 18 S 22.41 E 1.58 3734.85S 3063.84W 4037.43 11381.02 8950.65 8885.53 86 45 S 22.94 E- 2.40 3794.10S 3039.09W 4093.74 11443.63 8954.26 8889.14 86 38 S 23.18 E .43 3851.61S 3014.61W 4148.34 11507.31 8957.37 8892.25 87 45 S 23.34 E 1.76 3910.04S 2989.49W 4203.79 11571.45 8960.06 8894.94 87 26 S 24.55 E 1.95 3968.61S 2963.48W 4259.29 11635.23 8963.07 8897.95 87 9 S 25.91 E 2.17 4026.24S 2936.33W 4313.73 11699.13 8966.19 8901.07 87 15 S 24.42 E 2.33 4084.00S 2909.19W 4368.30 11763.05 8967.77 8902.65 89 54 S 22.27 E 5.35 4142.66S 2883.87W 4423.96 11826.64 8967.97 8902.85 89 43 S 24.33 E 3.25 4201.05S 2858.73W 4479.37 11890.30 8967.97 8902.85 90 16 S 22.49 E 3.02 4259.46S 2833.44W 4534.79 11922.19 8967.85 8902.73 90 9 S 23.25 E 2.42 4288.85S 2821.04W 4562.70 11954.00 8968.00 8902.88 89 19 S 21.05 E 7.39 4318.30S 2809.05W 4590.72 11985.98 8968.37 8903.25 89 20 S 16.59 E 13.95 4348.56S 2798.74W 4619.73 12014.77 8968.04 8902.92 91 58 S 12.91 E 15.69 4376.39S 2791.41W 4646.63 12046.57 8967.03 8901.91 91 39 S 9.34 E 11.26 4407.58S 2785.28W 4676.99 12078.53 8966.47 8901.35 90 22 S 5.39 E 13.00 4439.26S 2781.18W 4708.06 12110.47 8966.65 8901.53 88 58 S .72 E 15.25 4471.15S 2779.48W 4739.59 12142.18 8967.26 8902.14 88 48 S 3.'62 W 13.70 4502.83S 2780.29W 4771.18 12173.92 8968.04 8902.92 88 24 S 9.32 W 18.00 4534.35S 2783.86W 4802.90 12205.90 8968.53 8903.41 89 50 S 13.41 W 13.57 4565.69S 2790.16W 4834.73 12239.26 8968.31 8903.19 90 53 S 18.88 W 16.69 4597.72S 2799.43W 4867.56 12269.78 8967.50 8902.38 92 9 S 23.89 W 16.93 4626.12S 2810.55W 4896.98 12301.70 8965.78 8900.66 94 0 S 28.53 W 15.63 4654.71S 2824.62W 4926.89 12333.64 8963.73 8898.61 93 21 S 33.50 W 15.66 4682.01S 2841.04W 4955.78 12365.51 8962.60 8897.48 90 40 S 36.97 W 13.75 4708.02S 2859.41W 4983.58 12397.52 8962.54 8897.42 89 32 S 38.15 W 5.13 4733.40S 2878.93W 5010.87 12429.32 8962.87 8897.75 89 15 S 37.57 W 2.03 4758.50S 2898.44W 5037.90 12461.21 8963.78 8898.66 87 30 S 38.07 W 5.74 4783.68S 2917.98W 5065.00 12493.13 8966.00 8900.88 84 29 S 38.55 W 9.55 4808.66S 2937.72W 5091.92 12526.19 8969.36 8904.24 83 50 S 38.20 W 2.20 4834.44S 2958.14W 5119.72 12548.37 8971.65 8906.53 84 19 S 38.12 W 2.15 4851.79S 2971.77W 5138.41 12579.93 8973.53 8908.41 88 49 S 38.05 W 14.29 4876.58S 2991.20W 5165.11 12611.57 8973.88 8908.76 89 54 S 38.22 W 3.46 4901.47S 3010.73W 5191.92 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU / E-21A 500292057701 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121697 MWD SURVEY JOB NUMBER: AKMM80035 KELLY BUSHING ELEV. = 65.12 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 12644.13 8973.71 8908.59 90 40 S 38.23 W 2.37 4927.04S 3030.88W 5219.48 12675.44 8973.36 8908.24 90 37 S 38.39 W .55 4951.61S 3050.29W 5245.96 12707.93 8973.17 8908.05 90 3 S 41.01 W 8.25 4976.60S 3071.04W 5273.00 12738.68 8972.94 8907.82 90 46 S 41.29 W' 2.48 4999.76S 3091.27W 5298.16 12769.08 8972.90 8907.78 89 24 S 40.44 W 5.28 5022.75S 3111.16W 5323.12 12801.19 8973.16 8908.04 89 39 S 42.13 W 5.32 5046.'87S 3132.34W 5349.35 12833.03 8972.84 8907.72 91 28 S 47.64 W 18.22 5069.42S 3154.80W 5374.14 12864.56 8971.96 8906.84 91 41 S 51.08 W 10.93 5089.94S 3178.71W 5397.08 12905.83 8970.69 8905.57 91 50 S 51.56 W 1.22 5115.73S 3210.92W 5426.11 12937.83 8969.83 8904.71 91 13 S 51.'76 W 2.04 5135.57S 3236.01W 5448.49 12970.09 8969.62 8904.50 89 30 S 51.65 W 5.34 5155.56S 3261.32W 5471.04 13001.97 8970.60 8905.48 86 56 S 50.91 W 8.36 5175.49S 3286.18W 5493.49 13034.05 8972.61 8907.49 85 51 S 49.62 W 5.26 5195.95S 3310.80W 5516.44 13065.89 8974.91 8909.79 85 52 S 49.93 W .97 5216.46S 3335.05W 5539.39 13087.90 8976.47 8911.35 86 1 S 50.29 W 1.77 5230.54S 3351.89W 5555.17 13129.47 8979.73 8914.61 84 58 S 49.79 W 2.80 5257.15S 3383.65W 5584.99 13161.44 8982.98 8917.86 83 20 S 48.75 W 6.01 5277.90S 3407.75W 5608.16 13193.27 8986.80 8921.68 82 52 S 47.98 W 2.84 5298.90S 3431.37W 5631.53 13225.24 8991.41 8926.29 80 33 S 47.42 W 7.46 5320.18S 3454.76W 5655.17 13257.28 8996.81 8931.69 80 3 S 47.23 W 1.67 5341.59S 3477.98W 5678.91 13289.02 9002.40 8937.28 79 39 S 47.76 W 2.07 5362.70S 3501.01W 5702.33 13320.93 9008.23 8943.11 79 17 S 46.98 W 2.65 5383.95S 3524.10W 5725.90 13352.79 9014.03 8948.91 79 44 S 47.72 W 2.69 5405.17S 3547.14W 5749.44 13384.79 9019.46 8954.34 80 44 S 47.21 W 3.50 5426.49S 3570.38W 5773.09 13416.72 9024.62 8959.50 80 39 S 48.13 W 2.85 5447.71S 3593.67W 5796.65 13426.06 9026.18 8961.06 80 7 S 47.65 W 7.69 5453.88S 3600.50W 5803.51 13485.00 9036.29 8971.17 80 7 S 47.65 W .00 5493.00S 3643.41W 5846.94 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6591.47 FEET AT SOUTH 33 DEG. 33 MIN. WEST AT MD = 13485 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 186.06 DEG. TIE-IN SURVEY AT 9,905.94' MD WINDOW POINT AT 9,958.00' MD PROJECTED SURVEY AT 13,485.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU / E-21A 500292057701 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121697 JOB NUMBER: AKMM80035 KELLY BUSHING ELEV. = 65.12 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9905.94 8438.47 8373.35 10905.94 8923.69 8858.57 11905.94 8967.90 8902.78 12905.94 8970.68 8905.56 13485.00 9036.29 8971.17 2623.35 S 3254.02 W 3363.83 S 3238.06 W 4273.91 S 2827.45 W 5115.79 S 3211.00 W 5493.00 S 3643.41 W 1467.47 1982.25 514.78 2938.04 955.79 3935.26 997.22 4448.71 513.45 THE CALCULATION PROCEDURES A~RE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING PBU / E-21A 500292057701 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 121697 JOB NUMBER: AKMM80035 KELLY BUSHING ELEV. = 65.12 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9905.94 8438.47 8373.35 9936.86 8465.12 8400.00 10055.63 8565.12 8500.00 10183.33 8665.12 8600.00 2623.35 S 3254.02 W 2630.92 S 3267.74 W 2670.36 S 3317.56 W 2739.41 S 3355.36 W 1467.47 1471.74 4.27 1490.51 18.78 1518.21 27.69 10340.63 8765.12 8700.00 10528.09 8865.12 8800.00 11676.95 8965.12 8900.00 13485.00 9036.29 8971.17 2858.76 S 3370.24 W 3016.18 S 3355.04 W 4063.83 S 2918.37 W 5493.00 S 3643.42 W 1575.51 57.30 1662.97 87.46 2711.83 1048.86 4448.71 1736.89 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Cl I::t I I--I__ I I~l O S ~ F:t ~./I I-- I~ S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs E-21A, AK-MM-80035 January 21, 1998 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20577-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ri Ft I I_1_1 N ~ S I:::: F::I ~/I r' I~ S 'vVELL LOG TRANSMITTAL To: State of Alaska January 21, 1998 Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 '~,'~ - RE: MWD Formation Evaluation Logs - E-21A, AK-MM-80035 The technical dam listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 E-21A: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-20577-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20577-01 2" x 5" MD Neutron & Density Logs: 50-029-20577-01 2" x 5" TVD Neutron & Density Logs' 50-029-20577-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company [! I Iii ~I:~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO.11707 Company: Field: Alaska OII & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 1/12/98 Well Job # Log Description Date BL RF Sepia LIS Tape B-05A · PRODUCTION PROFILE 971 21 8 I 1 B-05A~ PERFORATION RECORD 9 71 2 2 5 I 1 B-10. TUBING PUNCHER RECORD 9 712 01 I 1 E-21 A PLUG SETTING RECORD 9 712 0 4 I 1 M-0gA TEMPERATURE/FLUID DENSITY 9 71 214 I 1 M- 23 PERFORATION SUMMARY 9 712 0 2 I 1 P-03 WHIPSTOCK SET RECORD 9 712 2 0 I 1 P-6 WHIPSTOCK SET RECORD 9 71 2 0 9 I 1 R- 15 INJECTION PROFILE 9 71 2 0 7 I 1 S-22B PERFORATION RECORD GR/CCL 9 71 2 2 4 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Al.~.ka 99618-1199 f MEMORANDUM State of Alaska TO: David JohnS .~ Chairman THRU: Blair Wondzell ~ ' P. I. Supervisor Alaska Oil and Gas Conservation Commission DATE: December 9, 1997 FILE NO: AHFJLIEE.DOC FROM: Lou Grimaldi, ~ SUBJECT: Petroleum InSpector BOPE Test Doyon 9 PBU E-2 lA PTD #97-198 Tuesday, December 9, 1997: I witnessed the weekly BOPE test on Doyon rig #9 which was drilling BP× well #E-21A in the WOA of the Prudhoe Bay field. I arrived to find the rig ready to test. All BOPE equipment was tested and passed with the exception of the isolation valve for the choke panel sensor, which leaked and had to have the valve changed. The rig and its surrounding area were well kept and provided good access. Tim Krupa (Doyon Toolpusher) uses a sure and methodical test procedure that provides for a good test of the rigs BOP equipment. SUMMARY: ! witnessed the initial test of the BOPE on Doyon rig #9 drilling BPX well #E-21A in the WOA of the Prudhoe Bay field. There was one failure observed. Test time 4 hours. Attachments: AHFJLIEE.XLS CC: John Rail/Steve Walls(Prudhoe Bay drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DATE: 12/9/97 Doyon Rig No. 9 PTD # 97-198 Rig Ph.# 659-4831 (fax 4833) BPX Rep.: Mike Whitely E-2 lA Rig Rep.: Tim Krupa Set @ Location: Sec. 8 T. 11N R. 14E Meridian Umiat Weekly X Other Test MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly /IBOP Ball Type Inside BOP Quan. Pressure P/F 1 300/5,000 P 300/5,000 P 300/5,000 P P 300/5,000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F P 250/3000 300/5,000 300/5,000 300/5,000 300/5,000 300/5,000 300/5,000 N/A P P P P 2 F P MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves 15 No. Flanges Manual Chokes 1 Hydraulic Chokes 1 Test Pressure P/F 300/5,000 F 38 300/5,000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attai ned 2 Blind Switch Covers: Master: Nitgn. Btl's: Five Bottles 2150 3,100 I P 1, 750 P minutes 24 sec. minutes 15 sec. P Remote: P Psig. Number of Failures: 1 ,Test Time:'4.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within N/A days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Isolation valve for choke panel gauge sensor leaked. Otherwise outstanding test. Well permited at 3000 psi, BOP's tested to 5000 ps£ All rig personel ac~vely involved in monitefing stack and BOPE for integrity. TOP RIG. Distribution: orig-Well File c - Oper./Rig c- Database C - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grimaldi F1-021L (Rev. 12/94) Ahfjliee.xls TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 29, 1997 Dan Stoltz Senior Drilling Engineer, Acting BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re.' Prudhoe Bay Unit E-2 lA BP Exploration (Alaska) Inc. Permit No. 97-198 Sur. Loc. 1633'SNL, 883'WEL, Sec. 6, TllN, RI4E, UM Btmnhole Loc. 1790'SNL, 4469'WEL, Sec. 7, T11N, R14E, UM Dear .:Mr. Stoltz: Enclosed ' ?he approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by la~v from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman xx~~} BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ,.,,L AND GAS CONSERVATION CONIMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work l--I Drill I~Redrill lb. Typeofwell I--IExploratory I--IStratigraphicTest [~DevelopmentOilj [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 67.9' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation. Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028304 / 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1633' SNL, 883' WEL, SEC. 6, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 1150' SNL, 3830' WEL, SEC. 7, T11N, R14E, UM E-21A At total depth 9. Approximate spud date Amount $200,000.00 1790' SNL, 4469' WEL, SEC. 7, T11N, R14E, UM 10/17/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MI:) and TVD) ADL 028280, 443'I No Close Approach 2560 13397' MD /8950' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 9950' MD Maximum Hole Angle 9o° Maximum surface 2595 psig, At total depth (TVD) 8950' ss/3490 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-Mod 3597' 9800' 8287' 13397' 8950' 443 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10675 feet Plugs (measured) I ;;:; 1997 true vertical 9110 BKB feet.~ o~,~j,...,- "', '"; ~' Effective depth: measured 10633 feet Junk (measured) fill at 10633' MD (02/89~laS~,.v~//~" true vertical 9073 BKB feet ..... . ~i~C~0~'¢,__q.~. ' Casing Length Size Cemented ,,~/~L,~ ~ ' TVD Structural BKB Conductor 110' 20x30 8 c.y. concrete 137' 137' Surface 2664' 13-3/8" 3720 c.f. Arcticset II 2691' 2691' Intermediate 9848' 9-5/8" 1351 c.f. 'G', 130 c.f. Arcticset I 9875' 8410' Production 6951' 7" tie back string 2419'-9370' 2419'-7983' Liner 1305' 7" 414 c.f. Class 'G' 9370'-10675' 7983'-9110' Perforation depth: measured 10449'-10455', 10480'-10492', 10510'-10578' - Sqzd: 10421 '-10449', 10455'-10459', 10472'-10480', 10497'-10510' true vertical subsea 8851 '-8965' (three intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Gre~eCcV~st 564-4803 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that thCforeC'oing is tr[ie-~md co~ect to the best of my knowledge Signed ! .¢ ~-.,-¢-.~ / Dan Stoltz ¢~ ~... ' ~'~,-:~-i %~?; ~'f?~ Title Senior Drilling Engineer Date Commission Use Only Per'ncC Number I APl N~)m~be~ I Appr~)val [)ate See cover letter __ ,/c~ ~ 50- - ~ 0.~ 7 '~ "' 0 ~/ ~t~ ~;:~ h3 for other requirements Conditions of Approval: Samples Required []Yes [~No Mud Log Required'"'/-- []Yes [~No Hydrogen Sulfide Measures [~Yes []No Directional Survey Required [~:Yes [] No Required Working Pressure for BOPE 1-12M; I~3M; [-]EM; n 10M; I-I 15M Other: Orig~na! $~gneo dy by order of Approved By David W, Johnston Commissioner the commission Date "~ Form 10-401 Rev. 12-01-85 SubmiJ :ate I Well Name: I E-21A Sidetrack Plan Summary Type of Redrill (producer or injector): Shut in Producer Surface Location: 1633' FNL, 883' FEL, T11N, R14E, S6 X = 664100, Y = 5975423 Target Location: 1150' FNL, 3830' FEL, T11N, R14E, S7 X = 661275, Y = 5970563 Bottom Hole Location: 1790' FNL, 4469' FEL, T11 N, R14E, S7 X = 660653, Y --- 5969910 I AFE Number: I 4P1050 I Estimated Start Date: I 10/17/97 IMD: I13397, I ITVD: I Well Design (conventional, slimhole, etc.): I Rig: I Doyon9 Operating days to complete: 1895o' ss I 124 IRKB 167.90' I Conventional ultra-slimhole horizontal sidetrack Objective: I Access zone 1 reserves of 1220 MSTB Mud Program Production Mud Properties:I Solids Free Quikdriln Density Viscosity LSR LSRV Filtrate pH (PPG) YP 8.7-8.9 55-65 14-24 35000-55000 NC 8.5-9.0 Keep Sand content at less than 0.25% in the production interval Directional KOP: Maximum Hole Angle: Close Approach Well: __9,950' MD (estimated), within Sag River __90° None Formation Markers Formation Tops MD TVD (SS) Tsag 9,927' 8,395 Sag River 9,950 8,408' KOP out of 7" casing Tshublik 9,985' 8,439' Z3 10,215' 8,622' Z2C 10,320' 8,695' 24N 10,503' 8,802' GOC 10,628' 8,848' 14P 11,800' 8,890' 12,491' 8,900' Target Polygon Begins 13P 13,233' 8,918' TD 13,397' 8,950' Target Polygon Ends Casinc /Tubinc Proc ram Hole Size Csg Wt/Ft Grade Conn Length Top Btm MD/TVDss MD/TVDss Existing 9-5/8" 47# L-80 BTRS 9,848' surface 9,875'/'8,410' 6" 4.5" 12.6# L-80 I BT-M O D 3,597' 9,800'/8,287' 13,397'/8,950' Tubing 4.5" 12.6# L-80 IBT-MOD 9,800' surface 9,800'/8,287' Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments P&^ 122/15.8/1.15 Rig will pump through EZSV bridge plug, EZSV at 9,970'md, will pump sufficient cement to fill well bore from retainer to PBTD at 10,620'MD, class "G" 4-1/2" 443/15.8/1.15 Soild Cemented Liner, Class "G", TOC to 200' above liner top Volume assumptions: Gauge hole + 50% excess; 80' shoe joints; TOC as listed. Lo_a_ain_a Pro_qram ILogs: 6" Hole DPC Logs: None Planned MWD/GR to GOC, MWD/GR/RES/NEU from GOC to TD GR/RES/DEN/NEU depending on quality of LWD results Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Bottom hole pressure is expected to be 3490 psi. Maximum expected surface pressure at 8950' tvdss is 2595 psi (assuming gas column of 0.1 psi/fi) Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards Sag River pressures could be as high as +3,490 psi at 8,950' TVDss or +7.5 ppg EMW. E Pad is not a designated H2S pad; the last sample taken was 16ppm (12/95) The well bore is expected to penetrate two large faults (>20' throw) and four minor faults (<20' throw) prior to entering the target polygon. No faults are expected within the target polygon. Disposal Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal. E-21A Short Well Summary Pre-Rig Operations: Note: original KBE was 59.18', BF elevation was 32.08' 1. Check and service the wellhead. Pressure test the 9-5/8" packoff to 3500 psi, please contact Greg West at 564-4803 with results of the packoff test. 2. R/U wireline and retrieve the 3-1/2" XX plug set in the SWS nipple at .-.9336'md. (ball set on 12/10/93) 3. Circulate and kill the well with seawater. 4. Make a chemical cut on the 3-1/2" 9.2# L-80 tubing in the middle of a joint at .-,10,300'md. (the planned KOP is 9950'md). Do not for any reason make the cut higher than 9970'md. Circulate well again at deep depth to ensure dead. 5. Make a chemical cut on the 3-1/2" 9.2# L-80 tubing in the middle of the first joint of tubing below the 7" TIW HBBP-R Packer. 6. Make a chemical cut on the 3-1/2" 9.2# L-80 tubing in the middle of the pup joint above the SWS nipple (tubing tally from 4/13/91). 7. Kill well dead, circulate well to seawater, bleed tubing and IA pressure to zero psi. Freeze protect well to +2000'MD with diesel. 8. Install BPV and test to 1000 psi. Secure well. 9. Remove all electrical lines, well house and flow lines. Level pad and dig out cellar. Rig Work: 1. MIRU. 2. Circulate out freeze protection and kill well with seawater. 3. Set TWC, ND/NU and test BOPs. 4. Pull TWC. 5. Pull 3-1/2" 9.2# L-80 tubing from tubing cut above the SWS nipple. 6. Retrieve the 7" HBBP~R packer and the tubing to the cut below the packer. 7. Pull the 3-1/2" 9.2# L-80 tubing from the cut at.--10,300'md. 9. Run and set a 7" EZSV on Baker 20 setting tool (w/CCL). Set the EZSV at 3' below a casing collar as near as possible to 9970'md (planned KOP is 9950'md) Once the EZSV is set perform a casing integrity test to 3500 psi for 30 minutes. PU EZSV stinger (plug catcher just above EZSV stinger) on 3.5"D RIH to EZSV and sting in. Establish injection rate into casing/perforations. Mix and pump 25 bbls - 122 sacks - of class "G" cement (calculated as 7", 26# casing capacity from PBTD to EZSV). Sting out, reverse any excess cement then pump dart into plug catcher to clean DP. POOH. 10. PU Baker anchor/whipstock assembly with MWD for 7" casing. RIH and set whipstock on top of EZSV at 30 degrees left of high side. 11. Mill window. 12. Trip for 6"" steerable BHA and drill ahead with MWD/GR as per directional building and turning at 12°/100 to high sail angle of 88°. P/U MWD/GR/RES/DEN and drill as per plan to TD. 13. Log with DPC (GR/RES/DEN/NEU) to TD (contingent on quality of LWD logs). 14. Run and cement 4-1/2" 12.6# L-80 liner to TD with 150' lap into the 7" casing. 15. Test liner top packer and liner to 3500 psi for 30 minutes. 16. Perforate liner on DP per Asset specifications. 17. Run 4-1/2" 12.6#, L-80 tubing and completion with 2-GLM's. 18. ND stack, NU tree and test. Set BPV. 19. Secure well, release rig. ~cr-voy 13 5/8' 5M FMC SSH )R: OTIS TIEBACK-HANGER 9~ D.V."ACKER 13 3/8' 72# L-80 BTRS I 2691'J -- 4 1/2', 12.6#/ft, L-80, IBT TBG TUBING I.D.: 3.958' CAPACITY: 0.01522 BBLJFT KB. ELEV= ' BF. ELEV = ' 4 1/2' SSSV LANDING NIPPLE 1/2 x 1' GAS UFT MANDRELS ( CAMCO w/?? LATCH} 21 I 4~'/ IKOP: 2800' i MAX ANGLE: 48° @ 8000' · TOPOF I 9370' I · 7'" UNER L-80 BTRS 7" Window @ 9950' MD PERFORATION SUMMARY REF LOG: SWS - BHCS 11-19-81 TIE-IN LOG: SWS - CBL 11-23-81 ~ INTERVAL 5' 2 12,~8'1 8 121~83 4 10,421 ° 10,449' 10,449 - 10,455' 10,455 - 10,459' 10,472- 10,480' 10,480- 10,492' 10,497- 10,510' 10,510- 10,540' 10,540- 10,552' 10,552- 10,578'~ =EN/SQZ'D SQZ'D/STR. SQZD/STR. SQZD/STR. SQZD/4-13-91 SQZD/ · SQZD/ · -, SQZD/ · OPEN/4-15-91 SQZD/4-13-91 4-1/2" "X" NIPPLE "XN" NIPPLE Uner top Packer @ 9800' MD 4-1/2" 12.6# L-80 Liner @ 13,397' MD 7" Cement Retainer @ ~ ~ MD ~7a' PBTD 110,620' 7", 26#/ft, L-80, IJ4S 110,675' DATE REV. BY 11-25-81 N/A 1-5-89 D F 5-3-91 H F 8/19/97 FH COMMENTS INITIAL COMPLETION RWO RWO Proposed Sidetrack Completion .PRUDHOE BAY UNIT WELL: E-21A (14- 06-11-14 APl NO; 50-029- .SEC 6; T ;llNi RG 14E . BP Exploration (Alaska) .. N -3: -34q /k -44( -- 1 --4~ -50( o · "' -540t ::ls~ru.~tur,,: P, Epod' :' :.'.i ".:. Wo,,:~:.2,A. ' I 'J' Field: Prudh'oe Bay ' ' - ' - Location: Alcl,ka' ' "1 -4400 -4200 -4000'---3800 -3600 -5400 '-3200-3000 -2800 .-2600'-24.00. · · , .. Scale-1 ' 200,00 ' --2400 -- --2600 --2800 --3000 --3200 --3400 --3600 --3800 t-4000 -4200 ---4400 --4600 --4600 ---5000 --5200 --5400 -5600 I ~'-X,A W,~ I x: Y: I[~fl .... TAROrT DATA PRELIMINARY 21A71 East -'> -4400 -4200 -4000 -3800 -5600 -3400 -3200 -3000 -2800 -2600 -2400 o 8000 - 0 ~ - :" 8200 0 - 03. 8400 - · 8600.- o 88OO - ®,,,~ .'1~ _ ~. · > 9000- F- '9200 - II V 9400 9600 · 9800. Shared Services Drilling $trucfure: PB £ Pad Well: E-21A Field: Prudhoe Bay Location: Alaska ~'.-,.-,-, pRO i x:,.,~ , WELL FILE DATA ---- I ~:~ I r~ ~ ~ ~.~ 2~.29 84~ -2r~4 -3272 0.~ ~ ¢ 8¢1d' ~84 3[~ 237~ a~G -26~ -5~7 I0.00 ~ ~B~14' IO7~ t0.75 1~.~2 ~3~ -3219 -~ II.~ ~ ~H~ 11914 ~.7~ 1~.52 5961 -42~ -28~ O.00 Io~ 124g I gO.~ 224.82 Eh4 ~ O~ 133~7 '~.~ 224.~2 PRELIMINARY o,. j. :, ' . ., .... ,'-. ,.. , , : ._ C - .... "· ' ~ ':?-'..~ · ..~ ~., ., , . - i I I I I' '1 $ I I I i I I I I i I l' I [ I I I I I I I I I . I I · I 2800 5000 3200 .3400 ,:3600 3800 4000 4-200 4400 4600 4800 5000 5200 5400 .5.600 5800 6000 ' · '.. .. .. . ;, Z i.;,-~ IR Ill, JO Verdcal section I~.98 nlQ3 67.9O' MD Inc. Ad. TVDss TVOrkb Rect Coordinates Grid Coo~dlnales DLS Vert~l Norlhin9 Easling Easflng . Northing degJlgOllSection 9950.00 '30.33 240,99 ,8408,94 8476.84 2634.148 3271.78w 660886.30 5972718.78 9983.94 '33.00 237.00 8437,83 8505.73 2643.338 3287.02W 6.6087126 5972709.26 9985.33 /33.02 236.69 '8439.00 8506;90 2643,748 -3287.66W 660870,63 5972708.83 10000,00'~33,22 233.49 .8451,29 8519.19 2648,338 3294,23W 660864.17 5972704.10 10059.92,34.87 220.97 .8501,00 8568.90,2671.O08 3318.69W 66084021 5972680.85 10100,00 36.64 213,31 '8533.54 8601.44 . 2689,718 3332.77W 660826.53 5972661.90 0.00 2960.66 Tie on point 10.00 2971.39 12.0b 2971.87 TShubllk 12.00 2977.11 12,00 3082.27 TS,sd 12,00 3022.29. 10200.00 42,84 197.17 8610.61, 6678.51 2747,348 3359.29W 660801.27 5972603,71 .12,00 3082.36 10215.69.44.O0' 195.01 ,8622.00 8689.90 276'/.708 3362,28W 660798,51 5972593.29 12.00 3092.97 ;Z3 107, t.~.74 44.00 195.00 8622.04 8689.94 2757.738 3362,29W 660798.50 597259328 12.00 3093.01 1~ ~0 47.10 189.41 8681.05 8748.96 2816.498 3374.91W 660787.15 597263425. 6.00 3152.76 10320.63 47.90 !88.12 8695.00 676~90 2631528 337723W 660766.16 5972519.17' 6.00 3167.66 Z2C 10373.19 50.00 185.00 8729.52 8797.42 2870.695 3381.74w 660781.60 5672479.71' 6.00 3207.58 10400.00 52,42 1.82.27 8746,31 8814.21, 2891:,748 3383,0~, 660780.64 5972458.84. 12`00 "3228,45 10500.00 61.88. 173.47 8800.57, .8868.47 2975,468 3379;60W 660785.90. , 5972375.23 12.00 .33.11.35 10503.0462.18 173,23 8802.00 8869,90 2978,128 :3379.29W 66078627 :5972372.57 12.00 3313.97 241t 10600,00.71.82 166;14 8839.88 ' 8907.78 3065.718 . 3363.15W 660804;31 5972286.35 12.00 3399.41 10628.16' 74,67' 164.24 8848.00 8915.90 3091,788 3356.25W 680811,77 5972259.44 12.00 3424,62 cGoc 82.00 !59.61 8862.52- 8930.42 3158.568 3334.41w 660835.05 5972193.1.3 12.00 .3488.78' 88.75 155,52. 8867.81' . 8935.71 3219,058 3309.44w .680861..33 597213322 ' ~12.00 3546.32 108(x)700 .88.75 155.52' 8868.56' '8936.46'3250.288 3295.23w 660876.21 5972102.32 0.00 3575.89' 1'0900.0068.75 155.62 6870.74 8938.64 334'1.268 3263.60W 66091956 597201224. 11000.00 68.75 155.52 6872.92 8940.62 3432.27S 3212~IBw 660962.96 5971922.17 111O0.00 68.75 1.55.52 .6875.09 8942.69 3523.278 3170.96W 661006.36 6971832.10 11200.00 68;75 155.52 687727 8945.17 '3614278. 3129.53W .661049.74 567~7.42.03 .... 113~.00 68.75 155.52 6879;45 8947.35 3705.275 3088.11W 661093.12 59'/1631.96 11( 0 88.75 .155.62 8881..63 894953 3796278 '3046;69W 68!136.51 5671561.88 11417 'es.75 15552 6882-00 8949.90 811 08303e.61w r 14 .915971 11600.00...66.75.15552 8~3.81 8951.71 3687268 300526w 661179.89 6971471.81 11600.O0 68.75 !65;52 8885..~ 8953.6a 3~78268 2963..64w 66122327 59'/.1381.73 0.00 37 827 0.00 3834.45 0.00. 3920.64' 0,00 400 63 'O,QO 4093.02 0.00 4107.73 73OO 0.00 41792O .0.00 426539 C~nment 11700.00.88.75 155.62 8888.16 8,9,56.054069.2~ 2922.42W 661266.65 5971291;66 .0.00 4351.58 ' 11800.00 88.75..-155.52 8890.34 8,95824 4160268 2881.00w 661310.03 5971201,59 0,00 4437.77 11876,25 88:75 155.52 8892,00 89,59.90 ~1229,658 2849.41w 661343.12 5971132.90 0.O0 4503.49 7400 ...... 11900,O0 88,75 155.52 8892.52 8,960.42 425126S 2839.57W 661353,42 5971111.52 0.O0 4523.95 , 11.913~ 88,75 155.52 8892,81 8~0.71 ~~ glB3.~l~ C~1a~9.,,~ 597100927 0.00. 4~15.67 i~..~- .... 12100,00 89.03 177,90 8896.47 8964.37 4443.868 2791.37W 661405.78 5970920.02 12.00 4710.48 12200,00 8924 189,90 8898,00 8965.90 4543.438 '2798;15W 661401.16 56708~,33 12.00 481022 12400J30 89:75 213.89 8899.80 8967.70. ~7.65S 2872.18W .661331.14 5970634.57 12.00 5001.15 I 8/13/97 8~t5 AM .' ~ '" Page 1 of 2 ': ', · _,.LJ E-21A Wp8 Yertical Sectim I65,98 RKB 67.90' &ID Inc. .4~TL 'l'Vl~s TT'Orkb ReCt. Co(xdlnates Grid Coordinates DL$ Vel-tical Northin§ Fasting Eastln9 Northing deg/10OftSection 12491.10 90.00 224.82 89(}0.00 8967.90 4797,998 2929.86W 661275.00 5970563,00 12,00 5077.11 E-21AT1 12500.00 90.00 224.82 8900,00 8967,90 4804.308 2936.13w 661268.87 5970556.55 0,00 5084.04 12600.00 90,00 224,82 8900.00 8967.93 4575238 '-3006.62w 661199.94 5970464,12 '0,00 5161.93 12700,00 90.00 '224.82 8900.00 8667,90 4946.168 3077,11w 661131.01 5970411,68 12600.00 90.00 224.82 8900.00 8967~ 5017.098 3147,60w .661062,08 5970339,24 12900.00 90,00 224,82. 8900,00 '8967.90 5088,028 3218,09w .660993.15 5970266.80 12991.10 90,00 224,82 8900.00 8967.90 5152,648 3282,30w 660930~ 5970200,81 13062.53 87,50 224.82 8,901,56 IL~69,46 5203.298 '3332.84w '.660681:!'3,5970~149,09 1,q*c'~,53 84.00 224,82 8908.97 8976,87 .5274.07,s 3402.92w 660812,40 5970076,66 1{.i .08 81,50 224,82 .8918.00 '8985,90 5324,378 3452.96w 660763,48 5970025,45 13262,53' 80,50....'224.82 8922.45 8990.35' 5344,298 3472.75w, 660744:12 .5670005.10 13363;73.77.31 224,82 8940.00 9007.90 5407,.778'.3535,83w 660682.44 596994028 13362,53 "'TI/X)' 224.82 8941.96 9009.86 5413,658 3541.87w 660676:52 '5969934.06 . , 13396.74 75.80, 224.82 8950,00 9017.90 5437,448 3565.31W 660653,60 596990'9.97 0.00 5239,82 0,00 5317.71 0.00 5395,60 0,00 5466,56 ' 3,50 5622.18' " 3,50 5599.84 350. 5655.12 13P f7500 3.50 5677.01 '. ,' 3.50 5746.70 760O 3,50 5753,39 3,50 '57'/9,29, TO 4'I/2" Uner Commenl 8/13/97 8:35 AM. Page2d2 ......... . ':::::- :-__: - . ': :-:7 ................. H.127937 00127c237/ VENDOR ALASI~AST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 0c22297 CKO922c27B 100. O0 100. O0 HANDLINO INST: s/h teeei hubble x 4528 THE A'rrACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ml[l]lllYilll ~ I OO CiO 1 OO_ OO WELL PERMIT ,CHECKLIST COMPANY oo, co 1 'o WELL NAME ~ - ~ J A PROGRAM: exp [] dev/B[ redrll,l~serv [] wellbore seg E, ann. disposal para req [] GEOL AREA ~ O_,~ f~ UNIT# // ~ ,~" ~ ON/OFFSHORE 0v~ ADM I N I STRATI O N A~, DATE ,__ 1. Permit fee attached ....................... ,,~',N.'~ 2. Lease number appropriate ................... L,~'~ 3. Unique well name and number .................. 4. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... N . 6. 7. Sufficient acreage available in drilling unit ............ ~ N 8. If deviated, is wellbore plat included ............... ~) N 9. Operator only affected party ................... f,~ N 10. Operator has appropriate bond in force ............. ~' 11. Permit can be issued without conservation order ........ /~!N 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... Y N%_~ 15. Surface casing protects all known USDWs ........... y 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ ,~N 18. CMT will cover all known productive horizons .......... (~N 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... ,~N ~"-~ 22. Adequate wellbore separation proposed ............. 23. If diverter required does it meet regulations ......... 24. Drilling fluid program schematic & equip list adequate ..... '~Y~ N 25. BOPEs, do they meet regulation ................ CY~ N 26. BOPE press rating appropriate; test to _?,O © c__) psig. ~'~? N 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~Y~ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. .'~N REMARKS GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measu~ Y N 31. Data presented on potential overpressure ~ ...... Y N 32. Seismic analysis of shallow gas zone~s,,~.. .......... Y N 33. Seabed condition survey (if offS) ............. Y N 34. Contact name/phone for wee~. lyprog, ress repo, rts ....... Y N lexp~orarory omyj ~'- (,,ri RPC ~ ENGINEERING: COMMISSION: BEV~Cc,~.~/~Z DWJ ,~~ g D H_.~:~:/-~- RNC CO ¢-O Corn ments/I nstructions: HOW/lit - A:\FORMS\cheklist rev 09~97 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. Sperry-Sun Drilling Services LIS Scan Utility Mon Jan 19 09:19:00 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/19 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 ..................... 98/01/19 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: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-80035 R. MCNEILL M. WHITELEY M]CffOF LM g E-21A 500292057701 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 19-JAN-98 MWD RUN 3 AK-MM-80035 B. HENNINGSE P. EASTWOOD MWD RUN 4 AK-MM-80035 B. HENNINGSE P. EASTWOOD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-80035 B. HENNINGSE P. EASTWOOD MWD RUN 5 AK-MM-80035 B. HENNINGSE P. EASTWOOD MWD RUN 51 AK-MM-80035 B. HENNINGSE P. EASTWOOD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: MWD RUN 52 AK-MM-80035 B. HENNINGSE P. EASTWOOD TOWNSHIP: liN RANGE: 14E FNL: 1633 FSL: FEL: 883 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 65.10 DERRICK FLOOR: 62.30 GROUND LEVEL: 34.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.375 2691.0 2ND STRING 9.625 9875.0 3RD STRING 7.000 9958.0 PRODUCTION STRING 6.000 13480.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. MWD RUNS 4 AND 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) IS PRESENTED ON A SEPERATE LOG. 5. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 12013'MD, 8968'TVD. 6. NO COMPENSATED NEUTRON POROSITY (CNP) DATA WAS ACQUIRED DURING RUN 5 DUE TO DOWNHOLE TOOL DAMAGE. 7. THREE MEASUREMENT AFTER DRILLING (MAD) PASSES WERE PERFORMED AFTER MWD RUNS 4 AND 5. THESE ARE PRESENTED AS A TAIL TO THIS LOG. 8. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M. MUNYAK OF SPERRY-SUN DRILLING SERVICES AND TRACY LOVE OF BP EXPLORATION (ALASKA), INC. ON 06 JANUARY, 1998. 9. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13485'MD, 9036'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SBDC = SMOOTHED BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTIC ABSORPTION FACTOR. CURVES WITH THE EXTENTION "M" ARE MEASURED AFTER DRILLING. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = 6.0" FORMATION WATER SALINITY = 11500 PPM. FLUID DENSITY = 1.0 G/CC MATRIX DENSITY = 2.65 G/CC MUD WEIGHT = 8.6-8.7 PPG. MUD FILTRATE SALINITY = 20000 PPM. LITHOLOGY = SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9926.5 13440.0 ROP 9988.0 13485.0 NPHI 11843.0 12842.5 PEF 11843.5 13410.0 DRHO 11843.5 13410.0 RHOB 11843.5 13410.0 FET 11876.0 13446.5 RPD 11876.0 13446.5 RPM 11876.0 13446.5 RPS 11876.0 13446.5 RPX 11876.0 13446.5 $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE'TOP MERGE BASE 2 9988.0 10686.0 3 10686.0 12070.0 4 12070.0 12929.0 MW/) 5 12929.0 $ REMARKS: 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 13485.0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD AAPI 4 1 ROP MWD FT/H 4 1 RPS MWD OHMM 4 1 RPD MWD OH~M 4 1 RPX MWD OHMM 4 1 RPM MWD OHMM 4 1 FET MWD HOUR 4 1 RHOB MWD G/CC 4 1 PEF MWD BARN 4 1 DRHO MWD G/CC 4 1 NPHI MWD P.U. 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 Name Min Max Mean DEPT 9926.5 13485 11705.8 GR 15.4453 651.993 45.483 ROP 7.7253 2203.09 93.8899 RPS 1.8173 56.76 25.2116 RPD 2.4648 66.2615 30.0595 RPX 1.7075 48.7556 21.6231 RPM 1.6912 53.8675 25.6115 FET 0.5987 31.4268 5.20423 RHOB 2.0719 3.0414 2.34428 PEF 1.1808 7.8366 2.16436 DRHO -0.185 0.2308 0.0243865 NPHI 20.22 38.28 25.7454 First Last Nsam Reading Reading 7118 9926.5 13485 7028 9926.5 13440 6995 9988 13485 3142 11876 13446.5 3142 11876 13446.5 3142 11876 13446.5 3142 11876 13446.5 3142 11876 13446.5 3134 11843.5 13410 3134 11843.5 13410 3134 11843.5 13410 2000 11843 12842.5 First Reading For Entire File .......... 9926.5 Last Reading For Entire File ........... 13485 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 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 ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NPHI PEF DRHO RHOB GR FET RPX RPD RPM RPS RAT $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: .5000 START DEPTH STOP DEPTH 10512.0 11335.5 10527.0 11350.5 10527.0 11350.0 10527.0 11350.0 10556.0 11379.5 10562.5 11386.5 10562.5 11386.5 10563.0 11386.5 10563.0 11386.5 10563.0 11386.5 10598.0 11425.0 MAD RUN NO. MAD PASS NO. MERGE TOP 4 1 12070.0 51 10783.0 52 10862.0 MERGED MAD 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 12929.0 11168.0 11293.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MAD AAPI 4 1 68 RAT MAD FT/H 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OH/~M 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 NPHI MAD P.U. 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 PEF MAD BARN 4 1 68 0 4 8 12 16 20 24 28 32 36 40 44 1 2 3 4 5 6 7 8 9 10 11 12 Name Min Max Mean DEPT 10512 11425 10968.5 GR 10.9695 65.5872 26.2487 RAT 59.9415 2033.09 160.98 RPX 0.169 30.9425 9.16398 RPS 0.2902 43.8578 12.8813 RPM 0.2599 2000 21.3669 RPD 0.3193 2000 26.3194 FET 78.3797 129.71 93.7609 NPHI 14.1 33.88 22.4815 RHOB 2.0003 3.4104 2.24906 DRHO -0.106 0.4909 0.0182431 PEF 0.9702 11.0747 1.91513 Nsam 1827 1648 1655 1649 1648 1648 1648 1649 1648 1647 1647 1648 First Reading 10512 10556 10598 10562.5 10563 10563 10563 10562.5 10512 10527 10527 10527 Last Reading 11425 11379.5 11425 11386.5 11386.5 11386.5 11386.5 11386.5 11335.5 11350 11350 11350.5 First Reading For Entire File .......... 10512 Last Reading For Entire File ........... 11425 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 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 ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 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 GR 9926.5 ROP 9988.0 $ LOG HEADER DATA DATE LOGGED: 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: 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: STOP DEPTH 10625.0 10686.0 09-DEC-97 ISC 5.07 DEPII 2.17F / SPC 5.74 MEMORY 10686.0 9988.0 10686.0 30.3 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER NGP SPC 176 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 6.000 6.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 4% KCL 8.70 53.0 8.9 21000 9.9 .000 .000 .000 .000 56.1 .0 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9926.5 10686 10306.2 1520 9926.5 GR 17.9943 651.993 55.7499 1398 9926.5 ROP 7.7253 747.122 62.4497 1397 9988 Last Reading 10686 10625 10686 First Reading For Entire File .......... 9926.5 Last Reading For Entire File ........... 10686 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 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 ....... 98/01/19 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 10620 . 0 12013 . 5 ROP 10681 . 0 12069 . 5 $ LOG HEADER DATA DATE LOGGED: 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: 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 il-DEC-97 ISC 5.07 DEPII 2.17F / SPC 5.74 MEMORY 12070.0 10686.0 12070'.0 85.3 92.3 TOOL NUMBER NGP SPC 317 6.000 6.0 4% KCL 8.80 54.0 8.5 20500 6.1 .000 .000 .000 .000 -17.7 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 3 AAPI 4 1 68 ROP MWD 3 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 10620 12069.5 11344.8 2900 GR 15.4453 139.716 36.5201 2788 ROP 14.7804 2028,06 102.602 2778 First Reading 10620 10620 10681 Last Reading 12069.5 12013.5 12069.5 First Reading For Entire File .......... 10620 Last Reading For Entire File ........... 12069.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name,.. Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 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 ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SErMMARY VENDOR TOOL CODE NPHI PEF DRHO RHOB FET RPD RPM RPS RPX GR ROP $ 4 .5000 START DEPTH 11843 0 11843 5 11843 5 11843 5 11876 0 11876 0 11876 0 11876 0 11876 0 12010 0 12065 0 STOP DEPTH 12842.5 12859.0 12859.0 12859.0 12895.5 12895.5 12895.5 12895.5 12895.5 12888.0 12928.5 LOG HEADER DATA DATE LOGGED: 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: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 ....................... 13-DEC-97 ISC 5.07 DEPII 2.17F / SPC 5.74 MEMORY 12929.0 12070.0 12929.0 83.8 94.0 TOOL NUMBER P0883SP4 P0883SP4 P0883SP4 P0883SP4 6.000 6.0 QUIKDRIL-N 8.80 50.0 8.6 22500 6.2 .220 .105 .180 .220 65.6 .6 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 4 AAPI 4 1 68 RPX MWI) 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHM/~ 4 1 68 RPD MWD 4 OHMM 4 1 68 NPHI MWD 4 P.U. 4 1 68 RHOB MWD 4 G/CC 4 1 68 DRHO MWD 4 G/CC 4 1 68 PEF MWD 4 BARN 4 1 68 FET MWD 4 HOUR 4 1 68 ROP MWD 4 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 11843 12928.5 12385.8 2172 GR 20.4984 454.519 47.5118 1757 RPX 1.7075 48.7556 22.4846 2040 RPS 1.8173 56.76 26.3272 2040 RPM 1.6912 53.8675 27.0749 2040 RPD 2.4648 66.2615 31.9432 2040 NPHI 20.22 38.28 25.7454 2000 RHOB 2.0719 3.0414 2.32939 2032 DRHO -0.185 0.2005 0.0201522 2032 PEF 1.1808 7.8366 2.13923 2032 FET 0.5987 31.4268 6.35741 2040 ROP 8.0113 2144.53 112.089 1728 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 First Reading 11843 12010 11876 11876 11876 11876 11843 11843.5 11843.5 11843.5 11876 12065 Last Reading 12928.5 12888 12895.5 12895.5 12895.5 12895.5 12842.5 12859 12859 12859 12895.5 12928.5 First Reading For Entire File .......... 11843 Last Reading For Entire File ........... 12928.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 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 ....... 98/01/19 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH PEF 12855.0 DRHO 12855.0 RHOB 12855.0 GR 12885.0 FET 12890.0 RPD 12890.0 RPM 12890.0 RPS 12890.0 RPX ~2890.0 ROP 12925.0 $ LOG HEADER DATA DATE LOGGED: 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: MAXIMUM ANGLE: STOP DEPTH 13410.0 13410.0 13410.0 13440.0 13446.5 13446.5 13446.5 13446.5 13446.5 13485.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 15-DEC-97 ISC 5.O7 DEPII 2.17F / SPC 5.74 MEMORY 13485.0 12929.0 13485.0 79.3 91.2 TOOL NUMBER P0883SP4 P0883SP4 P0883SP4 P0883SP4 6.000 6.0 QUIKDRIL-N 8.70 56.0 8.5 19500 5.4 .240 .128 .250 .340 67.9 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 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 5 AAPI 4 1 68 RPX MWD 5 OHMM 4 1 68 RPS MWD 5 OHMM 4 1 68 RPM MWD 5 OHMN 4 1 68 RPD MWD 5 OHMM 4 1 68 ROP MWD 5 FT/H 4 1 68 FET MWD 5 HOUR 4 1 68 RHOB MWD 5 G/CC 4 1 68 DRHO MWD 5 G/CC 4 1 68 PEF MWD 5 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 Name Min Max Mean Nsam DEPT 12855 13485 13170 1261 GR 25.0436 121.037 51.5712 1111 RPX 8.3257 38.9744 19.9351 1114 RPS 12.1592 38.7174 23.0865 1114 RPM 11.1407 35.7922 22.921 1114 RPD 12.8992 40.3984 26.6543 1114 ROP 8.1973 2203.09 85.5899 1121 FET 0.7337 30.71 3.35682 1114 RHOB 2.1772 2.9127 2.37076 1111 DRHO -0.109 0.2308 0.032172 1111 PEF 1.2348 6.6613 2.20932 1111 First Reading 12855 12885 12890 12890 12890 12890 12925 12890 12855 12855 12855 Last Reading 13485 13440 13446.5 13446.5 13446.5 13446.5 13485 13446.5 13410 13410 13410 First Reading For Entire File .......... 12855 Last Reading For Entire File ........... 13485 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 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 ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RLrN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 4 1 VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10512.0 11335.5 PEF 10527.0 11350.5 DRHO 10527.0 11350.0 RHOB 10527.0 11350.0 GR 10556.0 11379.5 FET 10562.5 11386.5 RPX 10562.5 11386.5 RPD 10563.0 11386.5 RPM 10563.0 11386.5 RPS 10563.0 11386.5 RAT 10598.0 11425.0 $ LOG HEADER DATA DATE LOGGED: 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: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 CNP ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON 13-DEC-97 ISC 5.07 DEPII 2.17F / SPC 5.74 MEMORY 12929.0 12070.0 12929.0 83.8 94.0 TOOL NUMBER P0883SP4 P0883SP4 P0883SP4 SLD $ STABILIZED LITHO DEN 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 P0883SP4 6.000 6.0 QUIKDRIL-N 8.80' 50.0 8.6 22500 6.2 .220 .105 .180 .220 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 4 AAPI 4 1 68 4 2 RPX MAD 4 OHMM 4 1 68 8 3 RPS MAD 4 OHMM 4 1 68 12 4 RPM MAD 4 OHMM 4 1 68 16 5 RPD MAD 4 OHMM 4 1 68 20 6 NPHI MAD 4 P.U. 4 1 68 24 7 RHOB MAD 4 G/CC 4 1 68 28 8 DRHO MAD 4 G/CC 4 1 68 32 9 PEF MAD 4 BARN 4 1 68 36 10 FET MAD 4 HOUR 4 1 68 40 11 RAT MAD 4 FT/H 4 1 68 44 12 65.6 First Name Min Max Mean Nsam Reading Last Reading DEPT 10512 11425 10968.5 1827 GR 10.9695 65.5872 26.2487 1648 RPX 0.169 30.9425 9.16398 1649 RPS 0.2902 43.8578 12.8813 1648 RPM 0.2599 2000 21.3669 1648 RPD 0.3193 2000 26.3194 1648 NPHI 14.1 33.88 22.4815 1648 RHOB 2.0003 3.4104 2.24906 1647 DRHO -0.106 0.4909 0.0182431 1647 PEF 0.9702 11.0747 1.91513 1648 FET 78.3797 129.71 93.7609 1649 RAT 59.9415 2033.09 160.98 1655 10512 10556 10562.5 10563 10563 10563 10512 10527 10527 10527 10562.5 10598 11425 11379.5 11386.5 11386.5 11386.5 11386.5 11335.5 11350 11350 11350.5 11386.5 11425 First Reading For Entire File .......... 10512 Last Reading For Entire File ........... 11425 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 51 MAD PASS NUMBER: FILE SLFMMARY VENDOR TOOL CODE START DEPTH PEF 10792.0 DRHO 10792.0 RHOB 10792.0 GR 10821.5 FET 10828.5 RPD 10828.5 RPM 10828.5 RPS 10828.5 RPX 10828.5 STOP DEPTH 11223 5 11223 0 11223 0 11251 0 11258 0 11258 5 11258 0 11258 0 11258 0 RAT 10862.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 11293.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/MANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 (OH/V~4) 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 Loggin9 Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 15-DEC-97 ISC 5.07 DEPII 2.17F / SPC 5.74 MEMORY 13485.0 12929.0 13485.0 79.3 91.2 TOOL NUMBER P0883SP4 P0883SP4 P0883SP4 P0883SP4 6.000 6.0 QUIKDRIL-N 8.70 56.0 8.5 19500 5.4 .240 .128 .250 .340 67.9 .6 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 51 AAPI 4 1 68 RPX MAD 51 OHMM 4 1 68 RPS MAD 51 OHMM 4 1 68 RPM MAD 51 OHMM 4 1 68 RPD MAD 51 OHMM 4 1 68 RHOB MAD 51 G/CC 4 1 68 PEF MAD 51 BARN 4 1 68 DRHO MAD 51 G/CC 4 1 68 FET MAD 51 HOUR 4 1 68 RAT MAD 51 FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 Name Min Max Mean DEPT 10711 11168 10939.5 GR 14.2816 49.0721 25.7191 RPX 3.9899 20.028 8.56035 RPS 5.005 27.4233 12.4032 RPM 5.7837 45.559 18.0646 RPD 7.3415 67.5568 27.4161 R_HOB 2.0561 2.9194 2.24389 PEF 1.0236 6.2194 1.80355 DRHO -0.144 0.1447 0.0149184 FET 137.836 148.346 143.19 RAT 36.8027 1115.77 143.087 Nsam 915 767 767 766 766 766 765 766 765 766 770 First Reading 10711 10740 10747.5 10747.5 10747.5 10747.5 10711 10711 10711 10747.5 10783.5 Last Reading 11168 11123 11130.5 11130 11130 11130 11093 11093.5 11093 11130 11168 First Reading For Entire File .......... 10711 Last Reading For Entire File ........... 11168 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NIIMBER: FILE SUMMARY .5000 52 VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 10711.0 11093.5 DRHO 10711.0 11093.0 RHOB 10711.0 11093.0 GR 10740.0 11123.0 FET 10747.5 11130.0 RPD 10747.5 11130.0 RPM 10747.5 11130.0 RPS 10747.5 11130.0 RPX 10747.5 11130.5 RAT 10783.5 11168.0 $ LOG HEADER DATA DATE LOGGED: 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: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR EWR4 CNP SLD $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN 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: 15-DEC-97 ISC 5.07 DEPII 2.17F / SPC 5.74 MEMORY 13485.0 12929.0 13485.0 79.3 91.2 TOOL NUMBER P0883SP4 P0883SP4 P0883SP4 P0883SP4 6.000 6.0 QUIKDRIL-N 8.70 56.0 8.5 19500 5.4 .240 .128 .250 .340 67.9 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 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 52 AAPI 4 1 68 RPX MAD 52 OHFIM 4 1 68 RPS MAD 52 OHMM 4 1 68 RPM MAD 52 OPIMM 4 1 68 RPD MAD 52 OHMM 4 1 68 RHOB MAD 52 G/CC 4 1 68 DRHO MAD 52 G/CC 4 1 68 PEF MAD 52 BARN 4 1 68 FET MAD 52 HOUR 4 1 68 RAT MAD 52 FT/H 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 Name Min Max Mean DEPT 10792 11293 11042.5 GR 13.4384 65.1002 26.4218 RPX 4.0081 21.7719 8.87312 RPS 5.0009 29.0545 12.6376 RPM 5.8881 52.0187 18.14 RPD 7.9674 71.7427 26.8896 RHOB 2.0364 2.7829 2.23301 DRHO -0.038 0.0907 0.0133519 PEF 1.1246 5.5924 1.88549 FET 139.173 153.038 146.407 RAT 50.6748 365.152 134.815 Nsa/n 1003 860 860 860 860 861 863 863 864 86O 863 First Reading 10792 10821.5 10828.5 10828.5 10828.5 10828.5 10792 10792 10792 10828.5 10862 Last Reading 11293 11251 11258 11258 11258 11258.5 11223 11223 11223.5 11258 11293 First Reading For Entire File .......... 10792 Last Reading For Entire File ........... 11293 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/01/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/01/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
