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Home My WebLink About186-035 by Date 20-MAY-2015 Transmittal Number:93426 • ,:4- BPXA WELL DATA TRANSMITTAL RECEIVED Enclosed are the materials listed below. MAY 2 0 2015 (BPXA LOG DATA) AOGCC If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing OPEN HOLE Digital Log Data: 04-21, 04-22, 04-33, C-01, C-31, L1-09, L2-03, L3-15, L3-31, L4-30, L5-01, L5-15, L5-16A, L5-16AL1, L5-16AL2, L5-31, L5-33, L5-36 04-21 185-212 251yy• L -ir/L /� 04-22 185-233 f25445, �//� 94-33 186-035 025�t(o. Please Sign and Return ne copy of this transmittal to; C-01 172-030 254 4'• C-31 188-006 251Lifs gancpdc@bp.con L1-09 185-001 25 4t4 9 L2-03 185-247 )5 7.60. Doug Dortch L3-15 185-266 ,75-4-5I Petrotechnical Data Center SCANNED MAY 2 7 2015 L3-31 186-034 ,257+852 L4-30 188-101 25453. L5-01 189-009 251-54• Attn: State of Alaska - AOGCC Attn: L5-15 188-109 d515555 Makana Bender L5-16A 206-083 25-4 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 L5-16A L1 206-084 Z�j�5'�• L5-16A L2 206-085 25 X58' L5-31 190-130 2515/ L5-33 189-047 254t00• L5-36 189-036 Z5 4(,I Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: Other: ~ '~/" J~ ~· DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: I I? NOTES: ORGANIZED BY: ~BREN VINCENT SHERYL MARI~ LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: /O'i~"~O.,~ /S/ ~[j~ By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ Scanned (done) PAGES: I SCANNED BY: III IIIIIIIIIII II II J C'~ (at the time of scanning) BEVERLY BREN VINCE~MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /SI General Notes or Comments about this file: ~, Quality Checked (done) Rev1 NOTScan~:l.wpd • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~i~~ErV~~ 5 E P 3 0 2009 WELL COMPLETION OR RECOMPLETIOIV REPORT ~l~l~sCons.Comndsaia 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Plugged ~ Abandoned '` ~ Suspended zofwczs.~os zoanczs.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Gompletions Zero 1b. Well Class: A~CItOfBQ$ ~ Developme~t/ ^ Explorafory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5 D te Comp., Susp., or Aband.: ~66`,~s~~~ 12. Permit to Drill Number: 186-035 ~` 309-255 .~' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 02/14/1986 ~' 73. API Number: 50-029-21545-00-00 w 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 03/12/1986 14. Well Name and Number: PBU 04-33 m'" FSL, 304 678 FWL, SEC. 26, T11 N, R15E, UM Top of Productive Horizon: 1445' FSL, 1156' FWL, SEC. 24, T11 N, R15E, UM g, KB (ft above MSL): 62~ .,~ GL (ft above MSL): 15. Field ! Pool(s): Prudhoe Bay Field / Prudhoe Bay ~ Total Depth: 1525' FSL, 1242' FWL, SEC. 24, T11N, R15E, UM 9. Plug Back Depth (MD+ND): 8197' 5849' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 713115 y_ 5952558 Zone- ASP4 10. Total Depth (MD+ND): 12845' 8796' 16. Property Designation~/: - ,: ADL 02832~ & 028323 TPI: x- 719064 y- 5958779 Zone- ASP4 Total Depth: x- 719148 Y- 5958862 Zone- ASP4 11. SSSV Depth (MD+T/D): N/A 17. Land Use Permit: 18. Directional Survey: ^ Yes ~ No Submit eledronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: Nh4 ft MSL 20. Thickness of Permafrost (ND): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL / BHC / GR / SP, FDC / CNL / GR / CAL, CBL, Gyro 22. Re-Drill/Lateral Top Window MD/FVD: 8197' 5849' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTfOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 SurFace 120' Surfa 12 ' 1775 # P I set 1-/" #/ # / K- rf 74T ' 7-1 /2" 3500 sx CS III 400 sx CS II To Job: 200 sx CS II -/8" 47# L-8 Surface 12 82' rf 67 ' 12-1/4" 500 x Clas 'G' 7" 29# L-8 12 2' 12 43' 84 5' 8794' -1/2" 3 0 sx Clas ' -/" 2.7# ' 12 2' 7' 84 ' N/ ''11 x '' 24. Open to production or injection? ^ Yes ~ No 25. TueiNC RecoRa If Yes, list each interval open (MD+ND of Top & Bottom; Perforation Size and Number): S¢e DePTH SeT MD PACKER .SET MD ~ ND 4-1/2", 12.6#, 13Cr80 8222' - 12312' 12249' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~;~,,.~` ~~~ ~~I (1 ~/ r~9 u~~U~ DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERfAL USED 10725' P&A Perfs w/ 42 Bbls Class 'G' Cement 8209' Set EZSV 8197' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press• Casing Press: Calculated 24-Hour Rate • OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORR~: 28. CORE DATA Conventi onal Core(s) Acqui red? ^ Yes ~ No Sidewall Core(s) Acquired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resufts per 20 AAC 250.071. None ,}~,~.. `. .~ ~~~. ~~ ,R ~ : ~?~~~ Form 10-407 Revised 07/2009 CONTINUED ON REVERSE Submit Original Only G ~ 29. GEOLGGIC MARKERS (List ail formations and m encountered): 30. ORMATION TESTS NAME MD ND Well Tested? ^ Yes ~ No Permafrost Top If yes, list intervals and formations tesfed, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Sadlerochit 12671' 8668' None Base Sadlerochit 12729' 8710' Formation at Total Depth (Name): 31. List ofAttachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoir~g is true and correct to the best of my knowledge. ~(~/~ 7 / Signed: Terrie Hubble ~ Title: Drilling Technologist Date: PBU 04-33 186-035 309-255 Prepared sY/vame~roumber. Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: John Rose, 5645271 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: 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 ftom each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only • ~ 04-33, Well History (Pre Rig Sidetrack) Date Summary 8/2/2009 T/I/0=640/620/90 Temp.=S/I MITOA to 2000 psi PASSED (RWO prep) Pumped 9 bbls 60° crude down OA to reach test pressure. First 15 mins OA lost 100 psi, second 15 min lost 20 psi for a total of 120 psi in 30 min. Bied OAP down (-2 bbls). Tags hung on WV and OA. Valve positions upon departure: SV,WV = closed, SSV, MV, IA, OA = open, operator notified. Final WHP's=640/700/90 8/19/2009 T/1/0=S1/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (0 psi), bled to 0 psi. Functioned LDS ET style, all moved freely (3/4"-1 "). Flagged (2) LDS ~ 3 and 4 O'clock position that would move less than 1/2". Pressured void to 5000 psi for 30 min test, lost 250 psi in 15 min, lost 100 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi), bled to 0 psi. Functioned LDS ET style, all moved freely (3/4"-1 "). Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 8/19/2009 T/I/O 0/0/0 Injectivity test (Pre CTD) Pump 5 bbis 60/40 meth spear followed by 290 bbls 1% KCL at 5 bbls per min. Pumped 102 bbls crude at 5 bbls per min. Never saw pressure increase. Tbg on vac. FWHP vac/0/40. Swab = closed, Wing = closed, SSV = closed, Companion = closed, Master = open, IA and OA open to gauges. 8/19/2009 DRIFTED W/ 3.80" CENT., 1-1/2" S. BAILER TO XXN PLUG @ 12303' SLM (NO SAMPLE). RAN 3.80" CENT., 4- 1/2" GS CORE W/ 4-1/2" X-EQ PRONG TO XXN PLUG @ 12303' SLM. PULLED 4-1/2" XXN PLUG FROM 12303' SLM. WELL LEFT S/I, DSO NOTIFIED. 8/22/2009 T/I/0=0/0/0 Fullbore P&A with SLB Cementers (Pre Sidetrack) Pumped down Tbg with 400 bbls 1% KCi, 10 bbls chemical wash, 5 bbls neat 15.8 ppg "G" cement, 32 bbls 15.8 ppg cement with 15 ppb aggregate, 5 bbls neat 15.8 ppg "G" cement, followed by 2 bbls fresh water. Diverted flow through ball launcher and pumped down Tbg with 5 bbls fresh water to launch foam wiper balls (6"), foilowed by 225 bbls diesel to dispface cement. Tbg pressured up to 90 psi, shut down pump tbg. fell to 0 psi. Possible TOC 10,800'. Shut- in well, RDMO. FWHP's = 0/0/300. 8/23/2009 WELL S/I ON ARRIVAL. TAG TOC AT 10,712' SLM W/3.70" CENT, 2.5" S.BAILER (1/2 GAL OF CEMENT REC.). TAG TOC AT 10,725' SLM W/ 1.90" CENT, 1.5" S.BAILER (1 CUP CEMENT REC.). LEFT WELL S/I, NOTIFY DSO ON DEPARTURE. 8/23/2009 T/I/0=400/100/40 MIT Tubing 2200 psi FAIL, Attempt to load IA Rigged up to Companion valve and pumped 4 bbls crude down tubing to reach test pressure of 2200 psi. Tubing lost 250 psi in 15 min's, Attempted 2 more tests with similar results. Bled back 3 bbls. Rigged up to IA and pumped 29 bbls crude while attempting to load. 8/24/2009 WELL SHUT IN UPON ARRIVAL. CUT 4.5" TUBING 10' BELOW 1ST FULL JOINT BELOW THE 4.5" TO 5.5" CROSSOVER AT 8209 MD. TUBING TALLY DATED 4/16/1994 USED FOR CORRELATION. TUBING CUT AT 8222'. FINAL T/I/0=250/180/0 SWAB, SSV, MASTER = C; WING = 0; CASING = OTG. JOB COMPLETE. 8/24/2009 CMIT Tx IA 2200 psi. PASS. Pumped additional 20.6 bbls crude (49.6 total) down IA to reach test pressures 2350/2120. T/IA lost 90/20 psi in first 15 min's, 0/0 psi in second 15 min's, for a total loss of 90/20 psi in 30 min's. Bled back 6 bbls. Swab, companion, wing, ssv valves - ciosed. Master, IA, OA vaives open on departure. FWHP's = 460/300/50. 8/25/2009 T/I/0=200/160/40 Temp=S/I Circ well, CMIT TxIA to 2170 PSI, PASSED (Pre RWO) Speared into TBG w/ 5 bbis neat meth followed by 947 bbls 1% KCL taking returns up IA & through jumper to F/L of well 16. Pumped 148 bbls diesel into TBG & U-tubed for 1 hour to place freeze protect. Pumped 3 bbis diesel through jumper line to F/P. Pumped 6.2 bbls 40° diesel to test. 1st 15 min loss Txl of 25/20 PSI & 2nd 15 min loss Txl of 20/20 PSI for a total loss T/I of 45/40 PSI. Bled TBGP & IAP down. (Apr.7 bbls) FWHP's=0/0/30 8/26/2009 T/IA/OA= SI/0/0 Temp=cold PPPOT-T (PASS) W/H Repair (Replace damaged LDS ET style) PPPOT-T: RU 1 HP BT onto THA 0 psi, verified 0 psi on annuli. Removed (2) damaged LDS on tubing spool, (1) @ 3:00 (1) ~? 4:00, replaced both with new equipment. RU 2 HP BT onto THA test void 0 psi, flushed void untii clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment. R& R(2) Alemite test fittings on tubing spool. LDS cycled RWO Prep 08-19-09. Page 1 of 1 u • ~ BP'~~ EXPL.ORATfON ~ Page 1-ai~ ~~~ Operations Sumrnary RepQrt Legal Well Name: 04-33 Common Well Name: 04-33 Spud Date: 2/14/1986 Event Name: REENTER+COMPLETE Start: 9/2/2009 End: 10/11/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 7ES Rig Number: Date' From - To Hours Task Code NPT Phase Description of Operations 9/1/2009 17:00 - 21:30 4.50 MOB P PRE PJSM. Release from 01-18A ~ 17:OOhrs. Mobilize and move satelite camp, truck shop and pits to DSO4; on location ~ 20:OOhrs. 21:30 - 00:00 2.50 MOB P 9/2/2009 00:00 - 04:00 4.00 MOB P 04:00 - 06:00 2.00 MOB P 06:00 - 09:30 3.50 RIGU P 09:30 - 12:00 I 2.50I RIGU I P 12:00 - 18:00 I 6.001 RIGU I P 18:00 - 20:30 I 2.501 WHSUR I P 20:30 - 22:30 I 2.001 WHSUR I P 22:30 - 23:30 1.00 WHSUR P 23:30 - 00:00 0.50 WHSUR P 9/3/2009 100:00 - 02:30 I 2.501 WHSUR I P 02:30 - 03:30 1.00 WHSUR P 03:30 - 05:30 2.00 WHSUR P 05:30 - 08:00 2.50 BOPSU P 08:00 - 11:00 3.00 BOPSU P 11:00 - 17:00 I 6.001 BOPSUR P 17:00 - 18:00 1.00 BOPSU~ P 18:00 - 21:00 3.00 PULL P 21:00 - 22:00 I 1.001 PULL I P 22:00 - 23:00 ( 1.001 PULL I P 23:00 - 00:00 I 1.00 I PULL I P Bridle up; RU and LD derrick. PRE Move Nabors 7ES from DS 01-18A to DS O4-33A down West Dock road past MCC and PBOC. Sub off DS 01 ~ 22:OOhrs. PRE Move Nabors 7ES from DS 01 to DS O4-33A. PRE Prep well to spot sub, hang tree in cellar. PRE Lay rig mats over freshly placed gravel around cellar. Lay herculite, plywood and cellar grating around wellhead. Stage wellhead equipment in cellar. PRE Spot sub over DSO4-33A; tight location due to GNI plant located directly across from well slot, PRE Raise derrick and berm around rig. Spot pits and raise cattle chute. Prep rig floor and connect pits. DECOMP Rig accept ~ 18:OOhrs. Prep cellar and wellhead; install auxiliary annular valves on tubing and casing heads for pressure testing; RU lines to test. DECOMP Pressure test OA w/ test pump and diesel. PT to 2000psi for 10min; good. Pressure test Tbg/IA w/ 8.5ppg seawater. PT to 2000psi for 10min; good. DECOMP RU DSM; test lubricator to 500psi and pull BPV with same. DECOMP Circulate out diesel freeze protect from the tubing. Pump 3bpm, 280psi; 5lbbls circulated out. DECOMP PJSM. Circulate out diesel freeze protect from the annulus, displacing with 8.5ppg seawater. Pump ~ 255gpm, 625psi. Recover a total of 96bbls diesel from the IA; total diesel recovered = 148bb1s. Blow down lines and RD from circulation. DECOMP Install BPV and test from below to 1000psi for 10minutes. DECOMP ND tree and adaptor. Install blanking plug in prep for BOP testing. DECOMP NU BOPs. DECOMP Change out saver sub, prep IBOP to 4.5" IF, stabbing guide. PU test tools to test BOPs w/ 4" and 5.5" test joints. DECOMP Test BOPE to 3500psi high, 250psi low for 5min w/ 4" and 5.5" test joints; chart all tests. Test annular to 2500psi high, 250psi low w/ 4" test joint only. All tests good. Did not test bottom rams; will test after tubing has been pulled (blanking plug/crossovers interfere with rams closing). BOPE test witnessed by AOGCC rep Bob Noble, WSL Mike Dinger, NAD TPs Chris Weaver and Jon Castle. DECOMP RD BOP test joints and testing equipment. Pull blanking plug and blow down choke manifold, choke and kill lines. DECOMP RU DSM and lubricate out BPV; had to attempt twice to latch onto BPV before successfully pulling. DECOMP MU crossover to pull tubing hanger to single joint of DP. Back out lock down screws; pull tubing hanger and tubing free from cut ~ 8222'MD. Hanger came free easily; no overpull; 137k up (anticipated upweight w/ bouyancy = 137k). DECOMP Circulate 626bb1s of seawater with Safe-O-Surf; 514gpm, 300psi. DECOMP Prep to LD tubing; RU double-stack tongs, SLB spooler for Printed: 9/14/2009 10:52:24 AM • ~ BP E?~ ~perations Legal Well Name: 04-33 Common Well Name: 04-33 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 7ES Date From - To Haurs Task G€~de NPT 9/3/2009 23:00 - 00:00 1.00 PULL P 9/4/2009 00:00 - 08:30 8.50 PULL P 08:30 - 09:30 I 1.001 PUL~ I P 09:30 - 12:00 ( 2.50 I BOPSUR P 12:00 - 15:30 f 3.50 I CLEAN I P 15:30 - 18:00 I 2.50I CLEAN I P 18:00 - 20:00 I 2.001 CLEAN I P 20:00 - 00:00 I 4.001 CLEAN I P 9/5/2009 I 00:00 - 00:30 I 0.501 CLEAN I P 00:30 - 04:00 I 3.50 I CLEAN I P 04:00 - 05:30 I 1.501 DHB I P 05:30 - 09:30 I 4.001 DHB I P 09:30 - 10:30 I 1.001 DHB I P 10:30 - 11:00 0.50 DHB I P 11:00 - 16:00 5.00 BOPSUb P 16:00 - 18:00 I 2.001 BOPSUFi P 22:00 - 23:30 1.50 BOPSU~ P 23:30 - 00:00 I 0.501 BOPSUR P _OR~4TlQN ' umrn~ry R+epc~rt Spud Date: 2/14/1986 Start: 9/2/2009 End: 10/11/2009 Rig Release: Rig Number: Phase ~ Descrintion of aqeratians DECOMP controlline. DECOMP PJSM. POOH, laying down 5-1/2", 13Cr-NSCC tubing. Spool control line and utilize pneumatic impact tool to cut stainless steel bands. Recover SSSV; no control bands on SSSV (normally 2 on this piece of equipment). Total of 54 control bands recovered; records indicate 56 were run. LD 2 GLMs, 206jts 5-1/2" tubing, 10' pup joint, and cut joint of 4-1/2" tubing; cut joint length = 12.58'. DECOMP RD tubing handling equipment; remove from pipe shed to be NORM'd. DECOMP RU and test lower VBRs. Test to 3500high, 250psi low w/ 4" and 5" test joints; chart all tests, good. RD test joints and install wear ring. DECOMP Make up cleanout BHA; used 8-1/2" bit, two full gauge string mills, 5" HWDP, float sub and drill collars. C/o float sub; threads damaged on joint of HWDP and would not make up properly. DECOMP RIH w/ cleanout BHA, picking up joints of 5" DP to 2832' MD. Fill pipe and break circulation; 5bpm, 150psi. DECOMP Safety stand-down with Castle crew, NAD safety personnel Cleve Coyne and Paul Holley, BP Field Supervisor Richard Watkins, 7ES TPs and WSLs. Discuss importance of in-depth risk assessment and thorough pre-job safety meetings. DECOMP Continue in the hole with 5" DP singles from 2832' to 8200' MD. 170k up, 130k down; no rotation. Fill pipe and break circulation; 13bpm ~ 1480psi. DECOMP PJSM. Circulate bottoms-up to clean casing and prep for EZSV run. Pump 435bb1s ~ 570gpm, 1500psi, reciprocate in 50' strokes. Tag tubing stump ~ 8222' MD. 170k up, 130k down. DECOMP Monitor well; static. POOH, racking back 5" DP from -8222' MD to surface. Rack back collars, HWDP and LD string mills and bit in prep for whipstock run. DECOMP PJSM w/ SLB E-line crew; RU E-line unit, bring EZSV and setting tools in preparation for setting plug. DECOMP RIH w/ EZSV on wireline from surface to 8212' and log up. Set EZSV w/ top of plug ~ 8209' MD; depth to allow for kickoff into sand without milling through a casing collar. POOH w/ wireline. DECOMP Test 9-5/8" casing to 3500psi for 30min; chart test, good. Omin = 3500psi 15min = 3500psi 30min = 3500psi DECOMP RD SLB E-line. DECOMP Break stack and ND BOPs to change out tbg spool. Remove old tubing spool w/ 9-5/8 packoff. Bring new spool and pack-off into cellar. DECOMP Install new spool and pack-off as per FMC hand; test pack-off to 5000psi for 30min. Test witnessed by WSLs Mike Dinger and Amanda Rebol. DECOMP NU BOPs. DECOMP RU and test breaks on stack after changing out pack-off, Chart test; good. RD test equipment. DECOMP Service rig and topdrive. Printed: 9/14/2009 10:5224 AM . ~ ~ ~ ~ ~ BP E Operations Legal Well Name: 04-33 Common Weil Name: 04-33 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 7ES Date ' From - To Hours Task Code NPT 9/6/2009 00:00 - 02:00 2.00 STW H I P P XPL~RATION ' ~'a~~ ~ Summary Repart W EX 02:00 - 05:30 I 3.50I STWHIPI P I I WEX 05:30 - 06:00 0.50 STWHIP N RREP WEX 06:00 - 07:30 1.50 STWHIP P WEX 07:30 - 08:30 I 1.OOI STWHIP~ P I I WEX /~_ ~ VV.JV ' ~Sw~4' ~'.~ PI' 13:30 - 20:00 I 6.50I STWHIPI P I I WEXI 20:00-21:00 I 1.OOISTWHIPIP I IWEXI 21:00 - 00:00 I 3.001 STWHIPI P I I WEXI I9/7/2009 I00:00 - 02:30 I 2.50I STWHIPI P I I WEXI 02:30 - 03:30 I 1.001 STWHIPI P I I WEXI 03:30-07:00 I 3.501STWHIPIP I IWEXI 07:00 - 13:00 I 6.00 I STWHIPI P I I WEXI 13:00-14:00 I 1.OOISTWHIPIP I IWEXI 14:00 - 16:00 2.00 STWHIP P WEXI 16:00 - 17:30 1.50 STWHIP P WEXI 17:30 - 00:00 I 6.501 DRILL I P I I INT1 19/8/2009 100:00 - 07:00 I 7.001 DRILL I P I I INTi Spud Date: 2/14/1986 Start: 9/2/2009 End: 10/11/2009 Rig Release: Rig Number: ~se Description of Operations IT PJSM. RU whipstock assembly; Baker 9-5/8" whipstock anchor and slide, 8-1/2" window mill, 8-3/8 lower string mill, two 8-1/2" upper string mills, float sub, 5" HWDP and MWD tool. Anchor set to shear ~ 20k, mill/slide bolt set to shear @ 50k. IT RIH w/ whipstock assy on 5" DP from surface to 7000' MD. Shallow test MWD ~ 1121' MD; good. IT Change out die block on back-up wrench. IT Continue to RIH from 7000' MD to 8105'. Tag plug ~ 8219' MD. Orient whipstock and set down to shear anchor; anchor sets ~ 15k. PU 5k over to confirm set. Set back down w/ 50k to shear slide. 175k up, 135k down. Window: top ~ 8197', bottom C~ 8214'. IT Swap wellbore over to 9.3ppg LSND drilling mud. Pump 500bbis ~ 550 m 1350 si. IT Mill window in 9-5/8" casing as per Baker rep. Mill window from 8197' to 8214' MD. 175k up, 125k down, 145k rotating. Torque = 12k off, 15k on, at 100rpm. Start w/ WOB @ 6k, finish milling window ~ 12k. Pump 1020psi, 420gpm; pump sweeps as necessary to clean cuttings from the wellbore. T Continue to mill formation from 8214' to 8245' MD. 175k up, 125k down, 145k rotating. Torque: 12k on, 10k off ~ 100rpm. WOB: 15k - 18k. Pump 1036psi ~ 402gpm; circulate hole until clean. Recovered -3011bs of inetal. T PU 1 stand so that bottom mill is inside window C~3 8173' MD. Perform LOT test to 11.2ppg EMW. MW = 9.3ppg, ND = 5848', surface pressure = 579psi. Record test on chart, bleed off after 10min hold. T Monitor well: static, 9.3ppg in and out. POOH, racking back stands of 5" DP. T PJSM. POOH to milling BHA. LD two 8-1/2" string mills, one 8-1/4" lower string mill, and window mill. All mills in gauge and in good condition. Clean and clear rig floor of third party tools. T Pull wear ring, jet stack and blow down mud cross. Install wear ring. T MU 8-1/2" drilling BHA: 8-1/2" Hycalog MSR616M, PowerDrive RSS, ARC/MWD logging tools, drill collars, jars, cire sub, and 5" HWDP. Surface test PowerDrive and MWD tools; good. T RIH w/ drilling BHA from surface to 5587' MD, picking up 4" DP singles from pipe shed. T Continue to RIH from 5587' to 8043' MD with stands of 5" DP from the derrick. T Cut and slip 89' of drilling line. Service topdrive and crown. T MAD pass while RIH from 8047' to 8197' MD C~ 300ft/hr to tie-in to previously logged depth. Obtain baseline ECDs and drilling parameters before drilling ahead in new formation. 160k up, 110k down, 130k rotating. 2070psi ~ 554gpm, 228spm. Torque: 11 k off ~ 80rpm. Drill 8-1/2" intermediate hole w/ PowerDrive RSS and drilling BHA from 8245' to 8315' MD. Time drill C~ 10-20fph in order to adequately kick off from window and avoid tracking the 9-5/8" casing. Torque: 12k C~ 80rpm and 3k WOB. 2170psi ~ 580gpm. PJSM. Drill ahead in 8-1/2" intermediate hole w/ PowerDrive Printed: 9/14/2009 10:5224 AM I TREE = CM7' 4-1 /8" 5 K WELLSiEAD = FMC Gen 4 ACTU,470R = Hyd K8. ELEV = 49.5 BF. QEV _ 2~~ KOP = 6000' MD Max Angle = 99 deg Datum MD = 12935 Datum TV D = 8862 ~ ~ 13~3~8" C,~JC 72/# L-80, 6i~ 1234T' ID ~ I I 9-5/S" x 7" BAI~2ZXPLN~H2TOPPACKH2 I I I ~5~g' ~ ~ s-s~s° aeP 274T 4-33A I SQFETYNOTES:4-1/2" 13CR-80 TBG& LNR 1 2111~ ~4.5" HES X NIPPLE, 3.813" ID GAS LIFf MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 4589 3605 54 MMG DCR RKP 0 09/24/09 4 7937 5691 53 MMG DMY RK 0 09/24/09 3 10065 6918 54 KBG DMY BK 0 09/24/09 2 11402 7782 47 KBG DMY BK 0 09/24/09 1 12195 8293 56 KBG DMY BK 0 09/24/09 I 8019' I Minimum ID = 3.725" @ 12,612' I 4-1/2" XN NIPPLE 7" LNR, 26#, L-80, BTC X TGII CROSSOV ER JT 9172~ 4-1/2 TBG, 12.6# 13CR-85/80, VT, .01522 bpf. H 12625~ ~ 7" X 5" BAKER, ZXPN, LINFR TOP PACKER 12619~ ~ 7" LNR, 26# L-80, BTC/TGII, 6.276" ID ~ 12478~ ~4.5" HES X NIPPLE, 3.813" ID I 12509~ 7" X 4.5 BAKER, S-3 PACKER, 3.875" ID ~2542' 4.5" HES X NIPPLE, 3.813" ID 12612~ 4.5" HES XN NIPPLE, RHC -M PLUG, 3.725" ID - 12625~ 4.5" WLEG I 12783' I ~ PBTD, LANDING COLLAR ~ I 15842' I 4-1/2" LNR, 12.6# 13CR-80, VAM TOP, 3.958" ID H 15925~ PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 27/8 6 14050-14160 0 09/21/09 27/8 6 14200-14310 0 09/21/09 27/8 6 14370-14430 0 09/21/09 2718 6 15130-15160 0 09/21/09 27/8 6 15195-15350 0 09/21/09 27/8 6 15380-15420 0 09/21/09 27/8 6 15500-15520 0 09/21/09 27/8 6 15540-15650 0 09/21/09 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/86 ORIGINAL COMPLETION 04/18/94 LAST WORKOVER 02/18/01 CJS/TP CWKAK CORRECTIONS 09/23/05 KSB/TLH XXN TTP SET (02/12/03) 09/24/09 BJB 04-33A ACTUAL Sidetrack PF2UDHOE BAY UNff WELL: 04-33A PERMfT No: # 209080 API No: 50-029-21545-01 SEC 24, T11 N, R15 E, 4034.36 FEL 3752.62 FNL BP 6cploration (Alaska) • • ~~ ..~ ~ ~. 3~ ~ ~r==~~ ~ ~ ~ :. ~ ~ '~ ~ ~ p E ~ k ~ ~ ~ ~ ~ ~~ ~~ ~~~~ ~~ ~.- ~~~~ E~ '~~' ~ ~~ ~ ~ SEAN PARNELL, GOVERNOR ~~ ~~ : ~~ ~;: ~w~: _~ ~ ,~~~~~ ~~ ~~ ~ ~ ~ ~ . ~ ~ .~ ~. ~S~ ~I~ ~ Vrv-7 ~ 333 W. 7thAVENUE, SUITE 100 CO1~T5ERQATI011T COMDIISSIO~T ~ ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 :' FAX (907) 276-7542 Mr. Robert Tirpack Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 zJRmi+. ij ~; , S ~"; y ~`~4~~~1~~ /~ '~ ~~ ~~0 Anchorage, Alaska 99519-6612 ~ ~~f ~ t Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-33 Sundry Number: 309-255 Dear Mr. Tirpack: 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. When providing 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, Daniel T. Seamount, Jr. ~ ~ j' Chair DATED this ~ day of August, 2009 Encl. . ~~.J /~ ~ ` ~~~ STATE OF ALASKA "~ 'g , -D~ ALAS~OIL AND GAS CONSERVATION COMII~ON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ,,<:,~. ~ ~ , _ ,;r.~ ~:".~~~G~I ~~"~~~~~~~ ~+:_~ E.. ~ ~ ~~t?~; 1. Type of Request: ~ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^~~~~~~~; ~~. ~,~ ~~~ rd. , s s~ ~ ~; ~p r., < a. S ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Sus~IQE~•1~Y~dl ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 186-035 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21545-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 04-33 - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: , , 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028324 & 028323 62' ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12845' ~ 8796' - 12754' 8729' 12754' Yes, Multiple Ca i L n h iz MD ND B rst oll e Structural n r 1' 20" 12 ' 120' 14 470 Surf ce 2747' 13-3/8" 2747' 2490' 3090 154 Int rmediat 12682' 9-5/ " 12682' 8676' 6 70 4760 Pr d 'on Liner 498' 7" 12332' - 12843' 8425' - 8794' 8160 7020 Li er Tieback 3964' 7-5/ " 8368' - 12332' 5957' - 8425' 68 0 4790 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 12686' - 12728' 8679' - 8710' S-1/2", 17# x 4-1/2", 12.6# 13Cr80 12312' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker'SABL-3' packer Packers and SSSV MD (ft): 12249' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ~ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 10, 2009 ^ Oil ^ Gas ^ Plugged ~ Abandoned 17. Verbal Approval: Date: ^ wAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 56a-5271 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Signature ~',~pP~.~ Phone 564-4166 Date ~~Y Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: r ~5 Conditions of approval: N Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance 3`S~~S~F~.M~S-~~as~~ ps~ ~.,.~~.~~ ~~~~~ Other: `-~ ~~ `_ ~a ~a~~~~~ ~`~:~~I f~ ~-~S" ~i r~`p ~~~ ZG CCf.Q~0. V~~c 1~~~ 1 J Subsequent For Required: ~(~ - ~Q Z ~ ~ ~~i~~'~a ~x ~" .~ APPROVED BY ~ ~~~ ~ A roved B~ ~ ~ COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 ~RIGI~IAI~ ~~~~~e~~~~ ~~~s , ~~ ~: ,~,o~ Submit In Duplicate ~-~~~`~~~~1~ ~ ?/30~~~ ~ ~ ~ ~~ ~ 04-33 Sundry Request Well Type: Producer Current Status: This well is completed with 4-1/2" x 5-1/2" L-80 tubing and is currently shut-in. Request: Plug and abandon wellbore in preparation for Ivishak sidetrack. Well History: Well 04-33 was drilled and completed in April 1986. Zone 14P perforations were shot in Sept. 1986 and the well initially produced = 2000 BOPD with 2% WC and solution GOR. Several hot oil treatments were done due to paraffin problems. A fracture stimulation was completed 5/90 and placed = 18.5M# of proppant into the formation. The oil rate was 1500 BOPD but water cut increased quickly after the frac. In Sept. 1993, a production casing leak in the cretaceous zone was confirmed with a water sample and LDL. This well is near the Grind and Inject wells that inject drilling solids into the cretaceous zone. The scale in the tubing from cross flow was milled with coiled tubing from 8450-12350' MD with no major problems and a scab liner set over the PC leak in April 1994. The well produced 1000 BOPD at 80% WC after the workover which declined to 500 BOPD at 15,000 GOR by 2002 as the WC increased to 95%. The well was shut-in in Feb. 2003 due to a production casing leak in the cretaceous zone. In Dec. 2003, the well's flowline was inspected and found not fit for service due to extensive corrosion. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: The pre-drilling rig work on this well will include the P&A the existing 04-33 well perforations per AOGCC regulat+ons and cutting the existing 5-1/2" x 4-i/2" completion at ~8189' MD in preparation for the planned 04- 33A sidetrack. With a drilling rig on the well, the planned work will include pulling the 5-1/2" tubing above the cut at 8189' and change-out the 9-5/8" pack-off prior to installing a CIBP and 9-5/8" whipstock just above the tubing stub which will be used to sidetrack the well to the 04-33A BHL. MASP: 2492 psi 04-33 Sundry Application 1 7/22/2009 ~ Pre-riq prep work: • S 1. Drift tubin to 12,300' MD in re aration to ull the XXN lu from the tubin tail. S 2. Pull the XXN TTP from 12,300' in re aration to P&A erforations. F 3. Confirm in~ectivit into the o en erforations as re uired for the cement work to follow. C/F Lay-in or "bullhead" 13.2 bbl 15.8 ppg G cement to plug and abandon the current well perforations (see details below / this well may be a candidate for FB cementing): Casing Size 29# 7" (.0371 bpf) Bottom of plug 12,843' MD Top of plug 12,486' MD Total Footage 357' (~13.2 bbls) Top Perf 12,686' MD Bottom Perf 12,728' MD ~ ~ ss 4~ SBHP: 3371 si SBHT: 190 °F F 4. WOC to 500 si com ressive stren th and ressure test the cement lu to 2170 si. F 5. MIT-IA to 3000 si ex ect ass . MIT-OA to 2000 si ex ect ass . E 6. Drift for tubin for lanned 'et cut to 8200'. E 7. Jet cut 5-'/2" tubing at mid-joint #121 at ~8189' MD (1S full joint of 5-1/2" tubing above the 4- 1/2" to 5-1/2" crossover at 8209' MD - see 4/16/94 tubin tall . F 8. IF ALL MIT's good in Step #5, circulate well to seawater thru the tubing cut, CMIT-TxIA to 2170 si, freeze rotectin the to 2000' of the well with diesel. W 9. Bleed OA, IA and T to 0 si. W 10. PPPOT-T to 5000 psi, PPPOT-IC to 3500 psi. Function tubing and casing lock down screws. Re air and re lace as needed. V 11. Set a BPV in the tubin han er. Secure Well O 12. Remove the well house and flow line. Level the pad as needed for the rig. Provide total well re aration cost on the handover form. Proposed Drillinq Riq Operations: 1. MI/RU. 2. CMIT-TxIA to 2000 psi and MIT-OA to 2000 psi to confirm barriers (10 minute tests - expect both test to pass). 3. Pull BPV w/tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and re-test TWC to 2000 psi from below and 3500 psi from above for 10 minutes. 5. As there is path-forward wellhead work to be completed, begin the OA monitoring process (RU to bleeder tank). 6. Nipple down tree. Nipple up and test BOPE to 3500psi. Pull TWC w/tested lubricator. 7. R/U & pull 5'h" tubing from the cut depth at 8189' MD. 8. Test lower set of rams if required. 9. PU drill-pipe (this well may require a 5" or 4" x 5" tapered string) and make bit and scraper run to the top of the tubing stub and test well to 3500 psi f/30 min and chart. (NOTE: If well does not test to 3500 psi, an RTTS will be RIH to isolate/locate the leak.) 10. Assuming a good pressure test in the previous step, RU E-line and RIH w/EZSV and CCL and set the EZSV at --8189' MD given the location of the nearest casing collar and re-test well to 3500 psi for 10 minutes. 11. With 2 down-hole barriers in place, "split" the stack and change out the 9-5/8" pack-off and "tesY' per the FMC weNhead representative. 12. NU Wellhead/BOPE test breaks to 3500 psi. 13. P/U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug at 8189' MD. Shear off of whip stock. 14. Displace the well to LSND based milling fluid per mud program. (End Work Under Sundry Approval #xxx-x~cx / Begin Work Under PTD #xxx-xxx) 04-33 Sundry Application 2 7/22/2009 • ~ 15. Mill window in 9-5/8" casing at ~8178' MD, plus approximately 50' of new hole beyond middle of window and circulate well-bore clean. 16. Pull up into 9 5/8' casing and conduct a FIT. POOH. 17. M/U 8-'/z" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8-'/z" intermediate section to the top Ivishak target at 12,600' MD, per directional plan. 18. Circulate, short trip and POOH to run the 7" drilling liner (manage drill-pipe as required). 19. Run and cement a 7", 26.0#, L-80, TC-II intermediate drilling liner (fully cemented liner w/--150' liner lap to 12,450' MD TOL). 20. After cement has reached a minimum 500 psi compressive strength, test the 9-5/" casing X 7" liner to 3,500psi for 30 minutes and record the test. 21. M/U 6 1/8" motor assembly w/Dir/GR/Res + insert bit to drill-out the shoe track, displace to the well to the planned drill-in fluid, drill 20' of new hole and run FIT. 22. Drill ahead per the directional plan and land the well in the Ivishak target sands and POOH for bit / BHA change. 23. M/U 6-1/8" PDC bit on motor or RSS assembly w/Dir/GR/Res/Neu/Den and drill the horizontal section to planned the planned final well TD at 15,886' MD. 24. Circulate, short trip, spot liner running pill. POOH to run the production liner. 25. Run and fully cement a 4-'/2", 12.6#, Vam Top, chrome production liner. 26. After cement has reached a compressive strength of 500 psi, test the well to 3500 psi f/30 minutes and chart. 27. MU perforating assembly on drillpipe per the final perf plan and RIH and perforate well. 28. POOH VD all drill pipe. 29. R/U and run 4-'/z", 12.6#, 13 Cr-80, VamTop completion tubing. 30. Land the tubing RILDS. 31. Reverse the well to clean seawater to include inhibited seawater to the production packer depth per the plan. 32. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes and record each test. 33. Shear the DCK valve and pump each way to confirm shear. 34. Set a TWC and test to 1000 psi from above and below. 35. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi with diesel (new adapter flange required). 36. Pull TWC w/lubricator. 37. Freeze protect the well to 2,200' TVD with diesel. 38. Install BPV and secure the well. 39. Rig down and move off. Post-Riq Operations: (S-Riser Modification will be Requiredl 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. Install gas lift valves. 4. Install well house and instrumentation. Estimated Pre-rig Start Date: 08/10/2009 Estimated Spud Date: 09/10/2009 Drilling Engineer: John Rose Production Engineer: Robert Chivvis Geologist: Daniel Schafer ATTACH: Current Well Schematic Post P&A Well Schematic (907) 564 - 5271 (907) 564 - 5412 (907) 564 - 5098 04-33 Sundry Application 3 7/22/2009 'VELLHEAD = FMC \CTUA~OR = OTIS :6. E1EV = 62 3F. ELEV = 24.65' :OP _ 1300' Aax Angle = 55 @ 4000' )atum MD = 12943' )atum ND = 8800' SS ~ • 04 33 HS~~2S0 PPMCAXOAC4~t~UNIGATION 13-3/8" CSG, 72#, L-80/K-55, ID = 12.347" ~-~ 2747' Minimum ID = 3.725" @ 12300' 4-1/2" OTIS XN NIPPLE 5-1/2"TBG, 17#, 13-CR-80 NSCC, 8209' .0232 bpf, ID = 4.892" TNV S6 7-5/8" X 9-5/8" LNR TOP PKR 8368~ TOP OF 7-5/8" LNR - SCAB, ID = 6.86" 2109~ J-~ 5-1/2"HES HRQ SSSV NIP, ID = 4.562" GAS LIFT MANDRFIS ST MD TVD DEV TYPE VLV LATCH POR' 1 3670 3066 52 M GFMHO RK 2 6886 5048 52 MGFMHO RK 3 8785 6208 53 CA-KBMG BKP 4 5 6 7 8 9 9591 10397 11158 11573 11988 12188 6699 7207 7698 7948 8198 8328 51 51 51 54 52 51 CA-KBMG CA-KBMG CA-KBMG CA-KBMG CA-KBMG CA-KBMG BK BK BK BK BK BK 8209' S-1/2" X 4-1/2" XO, ID = 3.958" 12216~ - ~4-1/2" OTIS X NIP, ID = 3.813" I 12249~ 7-5/8" X 4-1/2"BKR SABL-3 PKR, ID = 3.875" 12283~ 4-1/2"OTIS X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, 13-CR-80 FOX, I 12311' .0152 bpf, ID = 3.958" BTM OF 7-5/8" LNR SCAB, 29.7#, 12332' L-80, .0459 bpf, ID = 6.875" TOP OF 7" LNR 12332' 9-5/8" CSG, 47#, L-80, ID = 8.681" 12682' PERFORATION SUMMARY REF LOG: BHCS ON 03/13/86 ANGLE AT TOP PERF: 43 @ 12686' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12686 - 12692 C 11/28/94 3-3/8" 4 12697 - 12702 C 11/28/94 3-3/8" 4 12702 - 12704 C 11 /28/94 3-3/8" 4 12704 - 12710 C 09/26/86 3-3/8" 4 12710 - 12728 C 09/26/86 7"LNR, 29#, N-80, .0371 bpf, ID = 6.184" ~~ 12843' TD 12300~ 4-1/2" OTIS XN NIP, ID = 3.725" 12300' 4-1/2" XXN TTP (02/12/03) ( 12311~ 4-1/2"TBG TAIL WLEG 12312' ELMD TT LOGGED 11/28/94, ~ 2754" ELM PBTD 11 /02/97 12830~ MGVR-STaRK, 03/18/86 12835~ 2-1/4" X 3/8" ROLLER FROM ROLLER STEM, 03/18/86 12840~ MGVR STD-RK, 03/18/86 DATE REV BY COMMENTS DATE REV BY CAMMENTS 03/18/86 ORIGINAL COM PLETION 04/18/94 LAST WORKOVER 02/18/01 CJS/TP CWKAK CORRECTIONS 09/23/05 KSB/TLH XXN TTP SET (02/12/03) PRUDHOE BAY UNIT WELL: ~04-33 PERMIT No: ~1860350 API No: 50-029-21545-00 SEC 24, T11 N, R15 E, 4034.36 FEL 3752.62 FNL BP F~cploration (Alaska) TREE = CNV WELLHEAD = FMC ACTIATOR = OTIS B. E1EV = 62 BF. ELEV = 24.65' KOP = 1300' Max Angle = 55 @ 4000' Datum MD = 12943' Datum TV D= 8800' SS ~ 0~-33 (POST PRE IDETRACKWFIL WORK) 13-3/8" CSG, 72#, L-80/K-55, ID = 12.347" ~-~ 2747~ Minimum ID = 3.725" @ 12300' 4-1/2" OTIS XN NIPPLE Jet Cut 5-1/2" Tubing at -8189' MD 5-1/2"TBG, 17#, 13•CR-80 NSCC, 8209' .0232 bpf, ID = 4.892" TNV S6 7-5/8" X 9-5/8" LNR TOP PKR 8368' TOP OF 7-5/8" LNR - SCAB, ID = 6.86" 4-1/2" TBG, 12.6#, 13-CR-80 FOX, I 12311' .0152 bpf, ID = 3.958" BTM OF 7-5/8" LNR-SCAB, 29.7#, 12332' L-80, .0459 bpf, ID = 6.875" TOP OF 7" LNR 12332~ 9-5/8" CSG, 47#, L-80, ID = 8.681" 12682' PERFORATION SUMMARY REF LOG: BHCS ON 03/13/86 ANGLE AT TOP PERF: 43 @ 12686' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12686 - 12692 S 11 /28/94 3-3/8" 4 12697 - 12702 S 11/28/94 3-3/8" 4 12702 - 12704 S 11/28/94 3-3/8" 4 12704 - 12710 S 09/26/86 3-3/8" 4 12710 - 12728 S 09/26/86 7"LNR, 29#, N-80, .0371 bpf, ID = 6.184" 12843' TD I " I .~. •• y~ ~ , ~ ; ' . :~ •• ~, " , ~ ` ,~~ ~ •+ 2109~ ~ 5-1 /2"HES HRQ SSSV NIP, ID = 4.562" GAS LIFf MANDREl.S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3670 3066 52 M GFMHO RK 2 6886 5048 52 MGFMHO RK 3 8785 6208 53 CA-KBMG BKP 4 9591 6699 51 CA-KBMG BK 5 10397 7207 51 CA-KBMG BK 6 11158 7698 51 CA-KBMG BK 7 11573 7948 54 CA-KBMG BK 8 11988 8198 52 CA-KBMG BK 9 12188 8328 51 CA-KBMG BK 820-~ 5-1/2" X 4-1/2" XO, ID = 3.958" 12216' - 14-1 /2" OTIS X NIP, ID = 3.813" ~ 12249' 7-5/8" X 4-1/2"BKR SABL-3 PKR, ID = 3.875" 12283~ 4-1/2"OTIS X NIP, ID = 3.813" 12300~ 4-1/2" OTIS XN NIP, ID = 3.725" 12311' 4-1/2"TBG TAIL WLEG 123~ ELMD TT LOGGm 11 /28/94 P&A Cmt Plug f/12,486` - 12,843` MD 12754~~ -i ELM PBTD 11 /02/97 ~ 12830~ -I MC-VR-STaRK, 03/18/86 12835~ 2-1/4" X 3/8" ROLLER FROM ROLLER STEM, 03/18/86 12$40' MGVR-STD-RK, 03/18/86 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/18/86 ORIGINAL COM PLETION 04/18/94 LAST WORKOVER 02/18/01 CJS/TP CH/KAK CORRECTIONS 09/23/05 KSB/TLH XXN TTP SET (02/12/03) PRUDHOE BAY UNIT WELL: ~04-33 PERMIT No: ~1860350 API No: 50-029-21545-00 SEC 24, T11 N, R15 E, 4034.36 FE1 3752.62 FNL BP Exploration (Alaska) • • Review of Sundry Application 309-255 BP Exploration (Alaska) Inc. Well PBU 04-33 AOGCC Permit 186-035 Re~uested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to abandon the existing wellbore to prepare the well for sidetracking. Recommendation: I recommend approval of Sundry Application 309-255 to allow BPXA to perform this operation. Discussion: The current well (04-33) was first produced in February 1987 with a production rate of 1,814 bopd, a GOR of 0.9 Mcf/bbl, and a water cut of 0.5%. These numbers continued until the middle of 1990 where the oil production took a sharp decrease to less than 700 bopd and water cut jumped from 11% to 38.3%. Water cut continued to be a problem for 04-33 and by June 1993 increased past 90%. In September 1993 a work over was completed because of a production casing leak and production ceased for seven months. When 04-33 came back online, production was above 1,000 bopd and water cut was down to about 80%. These rates did not last and in August 1996 production was again below 500 bopd and a water cut of over 90%. This continued until its last production in June 2003. See appendix B for results. The 04-33 has currently produced 4,199 Mbbls and has been shut in since June 2003. By using the decline curve analysis and an economic limit of 100 bbls, there is an estimated 471.5 Mbbls of reserves which would be reached by November 2018, see appendix A. The trend that was used took into consideration most of the production dates except the extreme outliers. GOR was never a problem for 04-33 with the highest being 14.8 Mcf/bbl and ended with 9.9 Mcf/bbl on its last production month. The 04-33 was never cycled having greater than 24 days since the work over in 1993. After talking with BP, it was apparent that 04-33 was penetrating the Ivishak formation and the sidetrack of the well would enter the same formation, thus producing the same reserves but attempting to reduce the water production. Conclusion: 04-33 is both a low oil producer and high water producer. By plugging the current well and sidetracking to the Ivishak, it seems to be a sound choice for this well. I recommend approving BPXA's request. ~ • College Intern AOGCC Aaron Kohring I concur with this statement f/` ' ,,,, Reservoir Engineer AOGCC .~'~ . r 7 David Roby ~ ;''`~~ ,,-%' -~ `~C ~ ,.~.:~.~ ~'~=~'- . c~j~~~ `~ ~ • Appendix A a ~ ~ a 100 ~ ~ O 10 88~89~90~91~92~93~94-95~96~97-98-99 2000 01~02~03~04~05 O6 07 OB 09 10 11 12 13 14 15 i6 17 18 DATE Appendix B ~ ~ 029215450000:150 10000 1000 100 10 0.1 0.01 1987 86 89 90 91 9"L 53 94 95 96 9/ 9B 9y ZWU Ui UL U;S U4 U5 Uti ul un ua DATE 07/20/09 $~~I~b~t~g~l' , ~ ~,~r,~~s Alaska Data & Consultin Services ~. °~~" +~ ; f `z ~1+'; Com an State of Alaska 2525 Gambell Street, Suite 400 ~' `' ~ x~~`°'"`. t~ ~"r ~' k~~`J~i`, p Y~ Alaska Oil & Gas Cons Comrrr Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 4-04A/T-30 AYTO-00023 PRODUCTION PROFILE O6/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE / 07/01/09 1 1 G-31B ANHY-00100 LDL ( 07/07/09 1 9 Z-32BL1 AViH-00018 SBHP RVEY 07/02l09 1 1 14-10 AY3J-00033 PRODUCTION PROFILE (~ ~ (0 07/01/09 1 1 A-20 AV1H-00021 SBHP SURVEY '~ 07/07/09 1 1 01-30 AY3J-00034 LDL 07/04/09 1 1 M-26A BOCV-00021 PRODU TION LOG ^ 07/12/09 1 1 06-23C AXBD-00031 MEMORY PROD PROFILE - 07/03/09 1 1 L3-31 BOCV-00019 PRODUCTION LOG 07/09/09 1 1 L2-20 AYKP-00031 LDL / - 07/10/09 1 1 E-09B B04C-00064 SCMT - 07/01/09 1 1 04-33 AY3J-00036 USIT 1 07/07/09 1 1 WGI-07 BOCV-00020 USIT p~/~1/pg ' 1 1-31/M-21 B14B-00063 PRODUCTION PROFIL~• O6/i6/09 1 1 L3-02 AZCM-00028 RST - 06/15/09 1 1 1-31/M-21 B14B-00063 RST ' pg/~7/pg ~ 1 18-188 ANHY-00097 RST 'a - 06/09/09 1 1 a~ FecF errunwi Gnr_c o~ rc~~T Qv cir_.u .~r_ A\1~1 OOT~I~LUUn .,.~~ ...,.,.. ~.,.....,._ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. f,, } _, ,_, J 1....,.} _ ~._--~ ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 u ~ MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE ' STATE OF ALASKA ALASF 31L AND GAS CONSERVATION ( 'vlMISSION REPOR'il OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 677' NSL, 303' EWL, Sec. 26, T11N, R15E At top of productive interval 1320' NSL, 1320' EWL, Sec. 24, T11N, R15E At effective depth 1506' NSL, 1231' EWL, Sec. 24, T11N, R15E At total depth 1531' NSL, 1258' EWL, Sec. 24, T11N, R15E 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 62 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-33 9. Permit number/approval number 86-35 10. APl number 50 - 029-21545 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 12845 feet 8793 feet Plugs(measured) PBTD Tagged @ 12706' MD (11/28/94) Effective depth: measured 12706 feet true vertical 8690 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 120' 20" 1775 sx Poleset 120' 120' Sudace 2685' 13-3/8" 3500 sx CS III & 400 sx CS II 2747' 2490' Production 12620' 9-5/8" 500 sx CIG & 300 sx CS I 12682' 8673' Scab Liner 3964' 7-5/8" 73.5 bbls CIG 8368-12332' 5956-8423' Liner 511' 7" 300 sx CL G 12332-12843' 8423-8791' Perforation depth: measured 12686-12692'; 12697-12728' true vertical 8676-8680'; 8684-8707' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR Tbg @ 8209' MD, 4-1/2", 12.6#, 13CR Tbg @ 12311' MD Packers and SSSV (type and measured depth) Baker SABL-3 packer @ 12249' MD; Otis SSSV @ 2109' MD 13. Stimulation or cement squeeze summary RECEIVED 14. Intervals treated(measured) See Attached JAN 'l 7 1995 Treatment description including volumes used and final pressure /~ka Oil & Gas Cons. Commission Representative Daily Average Production or Injection Data Anchora '~ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 758 2165 5326 1443 ......... 558 6233 I16. Status of well classification as' Oil X Gas Suspended 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 325 48O Service Signed ¢.~, "]'1/I · ~ Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE "~' cc: KZ, JWP 4-33 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I I/2 8/9 4 · MIRU & PT equipment. 13' of perforations as follows: Added pedorations: 12686 12697 Reperforated: RIH w/perforating gun & tagged PBTD at 12706' MD, then PU & shot 12692' MD (Zl) 12702' MD (Zl) Ref. Log: BHCS 3/13/86. 12702 - 12704' MD (Zl) Ref. Log' BHCS 3/13/86. Used a 3-3/8" carrier & shot 4 spf at 60/120 degree phasing at underbalanced pressure. POOH w/perf gun; noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED JAN 1 7 ]995 Aiaska. OJJ & Gas Cons. Commission /~nchor~ , GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9149 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/15/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar Floppy Disk D.S.. 1-03 7 ~/(~o PERF RECORD (11-23-94) I 1 , 2-31 C~/,,--( "~,~ IBP SETTING RECORD (11-29-94) I 1 D.s. 3-12 ~ ~ .- _~-~ DUAL BURST TDT-P (11-24-94) I 1 D.S. 4-3 --7 / .- ~ ~ ,~-"~ PERF RECORD (11-24-94) I I ... D.S. 4-33~'/'~('-~ _'~ _~ PERF RECORD (11-28-94) I 1 D.S, 4-35 ~c~ RST (11-27-94) I 1 .. D:S. 4-48 ~' ~-~',.-/'~ '~_ . PERF RECORD (11-24-94) I 1 D.S. 9-30 ST1 i~,~"--- ~.~ ~,,, PERF RECORD (11-30-94) ' I 1 D.S. 9-31B ? ~- (3 ~"_'~ PROD PROFILE (11-29-94) I 1 D.S. 15-37 c~ ~-~/--. C~ 7 ~ STATIC PRESS SURVEY (11-22-94) 1 1 ..... ....... SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ~_~_ STATE OF ALASKA ALASKA _AND GAS CONSERVATION CC .41SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 677' FSL, 303' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 24, T11 N, R15E, UM At effective depth 1506' FSL, 1231' FWL, Sec. 24, T11N, R15E, UM At total depth 1531' FSL, 1258' FWL, Sec. 24, T11N, R15E, UM 5. Type of Well Development X Exploratory Stratigraphic Service RECEIVED JUL 2 5 1994 Alaska 0il & Gas Cons. Commission Anchorage; 6. Datum of elevation(DF or KB) 62' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-33 9. Permit number/approval number 86-35 10. APl number 50 - 029-21545 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12845 feet Plugs(measured) Tagged Fill @ 12693' MD (6/8/94) true vertical 8793 feet Effective depth: measured 12693 feet _., ~"~ 'ki ~' £'" ! i~'""~ i [ ',;i .~;~'.i~'~6 ~ true vertical 8681 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1775 # Poleset 120' 120' Surface 2685' 13-3/8" 3500 sx CS III & 600 sx CS II 2747' 2490' Production 12620' 9-5/8" 500 sx Cl G & 300 sx CS I 12682' 8657' Liner 498' 7" 300 sx CIG 12843' 8791' Perforation depth: measured 12702-12728' true vertical 8688-8702' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCC Tbg @ 8209' MD; 4-1/2", 12.6~, 13 CR-80, Fox Tbg @ 12311' MD Packers and SSSV (type and measured depth) Baker SABL-3 packer @ 12249' MD; Otis HRQ SSSV @ 2109' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 297 ~/ 2310 3839 .~' 1423 2444 5577 Tubing Pressure 1309 305 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas__ Suspended.__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~iogr nj~0_404 ev~06/15/8~8 1150/11 MJB cc: JED, JWP Title Engineering Supervisor Date "~///~/~ ~'~ SUBMIT IN DUPLICATE 4-33 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF ZONE I 5/2 RIH 5/3 RIH 5/3 RIH 5/94: & tagged PBTD at 10627' MD. 0/94: w/CT & jetted a fill cleanout to 12770' MD. 1/94: & tagged PBTD at 12764' MD. 6/6/94: MIRU & PT to 8300 psi. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the perforations located at: 12702' - 12728' MD (Z1B) Ref. Log: BHCS 3/13/86. 400 bbls 20# Pre Pad Gel @ 15 - 25 bpm, followed by Shutdown. ISIP @ 1447. pumping Fracture Treatment: 300 bbls 45# Crosslinked Pad @ 25 bpm, followed by 893 bbls Slurry w/proppant stages @ 1 - 10 ppg, followed by Pumped: a) b) Resumed c) d) e) 186 bbls 20# Flush @ 5 - 25 bpm, followed by f) Shutdown. Placed a total of 124,000 lbs of proppant into the formation. 6/7/94: RIH w/CT & jetted a proppant fill cleanout to 12726' MD. 6/8/94: RIH & tagged top of proppant fill at 12693' MD. Rigged down. Returned the well to production through the proppant fill w/gaslift & obtained a valid welltest. ARCO Alaska, Inc. Date- Subject: From/Location- Telephone: To/Location: P.O. Box 100360, Anchorage, AK May 10, 1994 Transmittal #: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 94037 99510~ ~ '.",; A './ ', .:'~las,~a 0]] & Eas Cons. ~qncharaga . Distribution Well Number OWDW- NW OWDW- SE i- 1-2 1-4 1-17 2-18 2-19 2-25 2-34 2-35 Log Date} Tool Type (M-D-Y)! 04-30-94 Pump-in Temp 04-30-94 !~--Pump-in Temp 04-19-94 ] f CNL 04-20-94 ] / TDT-P 04-07-94I f TDT-P 04-08-94 04-16-94 Per[ Record Per[ Record 04-17-94 i/ Prod Profile 04-18-94 i/' Bridge Plug 04-19-94 I¢ Prod Locj 04-12-94 ~' Prod Profile Run, ! 5II Contractor Scale Sch 1, 5" Sch 1, 5" Sch 11 5II Sch Sch Per[ Record Sch 11 5II 1, 5" { Sch : 1, 5"t Sch 1, 5" { Sch 1, 1"&5" ! Sch ; 1, 5" ! Sch 3-17 04-27-94 -"injection Profile 1, 5" Sch 3-17 04-19-94 !f Per[ Record i 1, 5" Sch 04-20-94 04-14-94 .. 04-29-94 04-12-94 04-14-94 Leak Detect -'Injection Profile f USIT .~' TDT-P 3-21 3-29 4-29 4-33 4-44 4-44 04-14-94 /" CNTG 4-45 04-24-94 .. CNTG 04-24-94 ~' TDT-P 4-45 4-46 5-10 5-15A. 5-15A 5-35 6-6 6-14.~ 6-14A · 6-22A 07-23 07-23 04-22-94 f Perf Record Leak Detect ~-CTU Prod Log f TDT-P Leak Detect Completion .~ TDT-P Completion ~Perf Record ~Patch Record ..~Leak Detect "~ TDT-P 04-13-94 04-25-94 7-24 7-24 9-1 9-9 9-19 04-26-94 04-16-94 04-17-94 04-08-94 O4-19-94 O4-27-94 04-13-94 04-16-94 ! 5II 1 "&2"&5" I 5" ~ 511 ~ 1 1 5" ; 1 5" 1 5" 1 5" 1 5" 1, 2"&5" 1 5" 5" 5" 5" 5" 5" 5" 1, 2"&5" ~ 1,5" ! 5II 1, 5" 12-09-93 04-18-94 --- Inj Profile Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch ~ Sch : Sch Sch 04-12-94 ]~' Patch ~ 04-~3-94i ~atch Record 04-20-94 I ,-'-Inject Profile ARCO Alaska, Inc. is a S,,hsldlary of AflantlcRIchfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 677' NSL, 303' EWL, SEC. 26, T11N, R15E At top of productive interval 1320'NSL, 1320'EWL, SEC. 24, T11N, R15E At effective depth 1506' NSL, 1231' EWL, SEC. 24, T11N, R15E At total depth 1531'NSL, 1258' EWL, SEC. 24, T11N, R15E 6. Datum elevation (DF or KB) KBE = 62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 4-33 9. Permit number/approval number 86-35~Conservation order #258 10. APl number 50- 029-21545 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 12845 8793 12793 8755 Size feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth Bas Cons. Commis~lOn N~ch0rage Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR tubing to 8209'MD; 4-1/2", 12.6#, 13CR tubing to 12312'MD Packers and SSSV (type and measured depth) Baker "SABL-3"packer @ 12249' MD;Otis SSSV @ 2109"MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Re.oresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that,,the foregoing is true and correct to the best of my knowledge. Si(~ned /~ r~~/~ TitleDrillini~Eni~ineerSupervisor Form 10-404 Rev 05/1~W..8~ SUBMIT IN DUPLICATE _/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 4-33 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/05/94 12:01 SPUD: RELEASE: 04/18/94 04:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 2ES 04/05/94 ( 1) TD:12843 PB:12793 04/06/94 ( 2) TD:12843 PB:12793 04/07/94 ( 3) TD:12843 PB:12793 04/08/94 ( 4) TD:12843 PB:12793 PREPARING TO KILL WELL MW: 0.0 MOVED RIG TO DS 4-33. COULD NOT SPOT RIG OVER WELL DUE TO CLEARANCE PROBLEM W/ DS 4-47 WELL HOUSE. ACCEPTED RIG AT 0001 HRS 04/05/94. HAD DSM REMOVE WELL HOUSE ON DS 4-47. SPOTTED RIG OVER DS 4-33. SPOTTED PIT COMPLEX AND RU. TAKE ON SEAWATER AND KILL WEIGHT MUD. RU TO KILL WELL. RU LUBRICATOR. CHECKED F/ PRESSURE BELOW BPV, 400 PSI. WING VALVE LEAKING. GREASING WING VALVE TO STOP LEAK. CBU MW: 0.0 REPLACED WING VALVE W/ BLIND FLANGE. CIRCULATED DIESEL CAP FROM WELL UNTIL SEAWATER RETURNED. DISPLACED WELL TO 10 PPG GEL MUD. MONITOR WELL, WELL DEAD AND STABLE. SET BPV. ND TREE AND ADAPTER FLANGE. NU BOPE. RE AND ATTEMPTED TO TEST BOPE. FLUID LEAKING PAST HANGER/TEST PLUG PREVENTED TEST. RU LUBRICATOR, ATTEMPTED TO PULL BPV. DAMAGED 3 BPV RETRIEVING TOOLS IN 5 ATTEMPTS TO PULL BPV. PULLED BPV ON 6TH ATTEMPT. RD LUBRICATOR. MU LANDING JOINT, BOLDS. PULLED HANGER TO RIG FLOOR W/ 190K# PUW. LD HANGER AND LANDING JOINT. CBU. RU NCS AND PREPARED TO LD COMPLETION. PICK UP DRILL PIPE MW: 0.0 CBU, BUILD MUD VOLUME, LOWER WT. LOWER WT. PUMP DRY JOB. LAY DOWN 275 JTS 5 1/2" TBG, 1 PUP JT, 7 GLM, SSSV, SEAL ASSY, 25 CLAMPS 3 SS BANDS. EXTERNAL SCALE ON JTS 200 TO 220. LOW SIDE I D CORROSION MOST JTS 1/2" SCALE BUILD UP ON ID FROM JT 270-275. TEST BOPE, FLOOR AND SAFETY VALVES. INSTALL WEAR BSG. MU FTA. PICK UP DRILL PIPE. POH MW: 0.0 RIH W/ BHA #1. SLIP LINE. RIH W/ BHA #1. KELLY UP. ATTEMPT TO SWALLOW PKR, COULD NOT GET OVER. ATTEMPT TO ROTATE. APPEARED TO CATCH A FEW TIMES, BUT WOULD COME LOOSE WHEN GOT TO 20K OVER. PUMP PILL. SET BACK KELLY. POH. LAY DOWN OVERSHOT. OVER SHOT GUIDE EGG SHAPED. DAMAGED FROM ROTATING LOOKS LIKE THE PBR IS LAYED TIGHT AGAINST CSG. MU BHA #2, WASHPIPE AND SHOE. RIH W/ BHA #2. KELLY UP, TAG FISH @12264'. PUMP PILL, POH. Anchorage : DS 4-33 OPERATION: RIG : NABORS 2ES PAGE: 2 04/09/94 (5) TD:12843 PB:12793 04/10/94 ( 6) TD:12843 PB:12793 04/11/94 ( 7) TD:12843 PB:12793 04/12/94 ( 8) TD:12843 PB:12793 POH W/ BHA #4 MW: 0.0 POH W/ BHA #2. LAY DOWN SHOE & BUSHING. CLEAN JUNK BASKET. CLEAR FLOOR. MAKE UP 8 1/2 X 7" BURNING SHOE. RIH TO 1904', SLOW, PIPE TRYING TO RUN OVER. PUMP PILL 1 TO DRILL PIPE. CUT AND SLIP LINE. RIH W/ BHA #3 TO 12264'. KELLY UP. TRIED VARIOUS WT, UP TO 20000 FOR 1 3/4 HR. DID NOT DRILL OFF. TORQUE DROPPED TO 400 AMPS AND STAYED THERE. PUMP DRY JOB. POH W. BHA #3, LAY DOWN WASHPIPE, CLEAN JUNK BASKET. MU BHA #4. 5 3/4" SPEAR. RIH W/ BHA #4 TO 12264' KELLY UP, STING INTO FISH. ATTEMPT TO RELEASE ANCHOR, COULD NOT ROTATE, SO HAD TO WORK TORQUE DOWN. TRIED TO ROTATE @ NEUTRAL WT. WOULD NOT ROTATE. WORKED PIPE CAME FREE. CBU. POH W/ BHA #4. TRIP IN HOLE MW: 0.0 POH W/ BHA #4. NO RECOVERY. CHECK OUT SPEAR. ADD 6' EXTENSION TO BHA ABOVE SPEAR. RIH W/ BHA #5. TAG FISH @12264'. KELLY UP. STING INTO FISH. SET SPEAR, ATTEMPT TO WORK TORQUE DOWN W/ KELLY ABOVE TABLE. RELEASE SPEAR, LAY DOWN JOINT OF DP. STING INTO PBR, SET SPEAR, ROTATED, RELEASED ANCHOR. SET DOWN TO VERIFY ANCHOR RELEASED, LATCHED BACK IN. ROTATED ANCHOR FREE AGAIN. CBU. PUMP DRY JOB. SLIP LINE. POH, LAY DOWN PBR AND FISHING ASSY. MU PRT AND PKR MILLING ASSY. RIH. POH MW: 0.0 KELLY UP. TAG TOP OF PKR @12284' MILL PKR F/ 12284-12287' FELL FREE, PUSHED ~OWN HOLE TO VERIFY FREE. PICKED UP HAD 15K DRAG. CBU. PUMP DRY JOB. POH W/ BHA #6, INTERNITENT DRAG FIRST ROW OFF BTM, NO FISH, LAY DOWN PRT. CLEAR FLOOR. MAKE UP SPEAR. TRIP IN HOLE W/ BHA #7. CUT AND SLIP LINE. TRIP IN HOLE W/ BHA #7. TAG SPEAR INTO FISH @12329'. POH. INTERMITTENT HANGING UP TO 15/20. LAST SEEN ON STAND #54 OFF BTM. RIH W/ TEST PKR MW: 0.0 POH. PKR HANGING UP IN WEAR BUSHING, BOLDS, PULL FISH TO FLOOR, LAY DOWN PKR AND TAIL ASSY. CLEAR FLOOR. LAY DOWN 6 1/4" COLLARS AND FISHING TOOLS. PICK UP AND MAKE UP BHA #8 AND RIH, TAG FILL @12554'. KELLY UP, CLEANED OUT. CBU. POH, CLEAN OUT REVERSE CIRC JB AND BOOT JB. RECOVERED LARGE CUP OF PKR MATERIAL. MAKE UP 9 5/8" RETRIEVAMATIC TEST PKR, RIH. SLIP DRLG LINE. RIH W/ TEST PKR. N~A~ -' ,5 199~ Gas Cons. CommissioD Anchorage : DS 4-33 OPERATION: RIG : NABORS 2ES PAGE: 3 04/13/94 ( 9) TD:12843 PB:12793 04/14/94 (10) TD:12843 PB: 12793 04/15/94 (11) TD:12843 PB:12793 04/16/94 (12) TD:12843 PB:12793 POH MW: 0.0 SET PK @8700', TEST CSG, PUMP AWAY @ 800 PSI. PULL UP AND ISOLATE LEAK BETWEEN 8573-8605'. TESTED. POH, W/ RETRIEVAMATIC TEST PACKER. RIG UP SCHLUBERGER. RIH W/ WIRELINE. LOW W/USI/GR/CCL FROM 8800 TO SURFACE. RD WL. MU TIW 7" POLISH MILL. RIH, TAG LINER TOP @12332'. KELLY UP. POLISH TIE BACK RECEPTICLE. PUMP DRY JOB, POH W/ POLISH MILL, LAY DOWN 126 JTS DP. DROPPED 2 3/8" DRIFT W/ 8350' DP IN HOLE. CUT AND SLIP LINE. POH. RIH W/LINER MW:10.0 KC1 RU NCS. PU TIW SEAL ASSY, SHOE JTS, LNDG COLL. RIH W/39 JTS 7-5/8 29.7# SFJP, 12 JTS SLX, 45 JTS STL. RAN SLOW, MUD RUNNING OVER @ TOP. TURBULATORS PLACED ON EA. SIDE OF THE 1ST 10 JTS. 1 EV.3RD JT. AFTER THAT. MU HNGR, LINER TOP PKR & RUNNING TOOL. RD CASG TOOLS, CLEAN FLOOR, PUMP WT. PILL. TIH W/LINER ON DP. INEFFECTIVE PILL. PIPE RUNNING OVER 20' BELOW THE BOARD. RU DP PLUG. REV. CIRC. VOL. CON'T. RIH W/LINER, CK'D PRESS ON PLUG / 300PSI TEST BOPE MW:10.0 KC1 RIH W/7-5/8 LINER, MU CMT HEAD. STING INTO TBR @ 12332. PU 'TIL PORTS OUT OF TBR. CBU. MIX CMT. ll00PSI. TEST LINES W/4000 PUMP 5 BBLS H20, 50 BBLS CLASS G llPPG CMT. FOLLOWED W/23.6 BBLS CLASS G 15.8 PPG TAIL CMT. DROP PLUG, KO W/5 BBLS H20. DISPLACE W/RIG PUMP @ 3BPM. 1500 MAX. BUMP PLUG. CIP @16:00 SET HNGR W/3500, SET LTP, RELEASE RUN'NG TOOL. REV. CIRC @ 6 BPM. 75 BBLS CMT CONTAM. MUD RETURNED. LD CMT HEAD LD 6 JTS DP. POOH 15 STNDS. MU STORM PKR. HANG OFF DP. PULL WEAR RING. ND BOPS. CHANGE OUT 9-5/8 PACKOFF (2WICE) TEST T/5000 OK. NU BOPS. INSTALL TEST PLUG. TEST BOPE. PULL OUT OF HOLE MW: 9.7 KC1 TEST BOPE. WITNESS WAIVED BY AOGCC REP J. SPAULDING. RETRIVE STORM PKR. LD. CLEAR FLOOR. POOH. LD LINER RUNNING TOOL. MU BHA #8. 6.75 BIT & 7-5/8 SCRAPER. PU 114 JTS 3.5 DP. RIH T/8360. KELLY UP. TAG PACKOFF @ 8381. DIDN'T SEE LINER TOP. CLEAN OUT PACKOFF, SET BK KELLY. RIH T/12810. HAD T/USE PLUG. KELLY UP WASH T/PLUG @12243. CIRC CLAB. MUD. STARTED @ 8.3 BPM/2950, SLOWED T/5.8 BPM/2000, FOR SHAKER T/HANDLE. TEST 7-5/8 CASG & LAP W/3500/30 MIN. 0 LOSS. C/O PLUG & LC @ 12243. WASH T/12331. NO HARD CMT UNDER LC. CBU 140 SPM, 3100PSI. POOH. RECEIVED MAY -'5 199'~ ~sk~ O~ & Gas Cons. Commission" Anchorage : DS 4-33 OPERATION: RIG : NABORS 2ES PAGE: 4 04/17/94 (13) TD:12843 PB:12793 04/18/94 (14) TD:12843 PB:12793 04/19/94 (15) TD:12843 PB:12793 RUN TBG MW: 8.5 Seawater POOH, MU BHA #9. RIH TAG SEAL ASSY @12331. RIH T/12594. KEL. UP CLN OUT SAND F/12594 T/12600. SLIP LINE. CIEC, LONG 15 MIN. REV CIRC. 'TIL HOLE IS CLEAN. DISPLACE WELL W/INHIB. 8.5 SEAWATER @ 6 BPM/2500. PUMPED TOTAL OF 1100 BBLS. TEST CASG W/3500/30 MIN. 0 LOSS. LD DP. PULL WEAR RING. RU NCS. RIH W/COMP. STRING. NU ADAPTOR FLANGE MW: 8.5 Seawater RUN 4.5 13CR FOX. (88 JTS) & 5.5 13CR NSCC. MU SSSV, TEST CL. CON'T T/RUN TBG. (206 JTS). DROP BALL, SET 2-WAY CHK VALVE, MU LNDG JT. HOOK UP CL T/HNGR & TEST W/5000 15 MIN. LAND TBG. LD LNDG. JT. ND BOPE. & DRILLING SPOOL. NU ADAPTOR. RIG RELEASED MW: 8.5 Seawater NU TREE. TEST CNTRL & BAL. LINES. 5000/15 MIN. OK. TEST TREE W/250/5000. PLUG WAS LEAKING. CHANGE OUT TEST PLUGS. TEST TREE 250/5000. RU HOSES, SET PKR. TEST TBG. W/4000/30 MIN. 50 PSI LOSS. BLEED T/1800, SHUT IN. TEST ANNUL. W/3500/30 MIN. 50PSI LOSS. BLEED OFF TBG. SHEAR RP VALVE W/3200. FRZ PROTECT. WELL W/135 BBLS DIESEL, PUMP DOWN ANNUL @ 4BPM, 1000PSI. U-TUBE T/TBG. RD HOSES/SET BPV/SECURE TREE. RIG RELEASED @16:00 HRS. 4/18/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED MAY -5 1994 ataska Oil & Gas Cons. Commission Anchorage P.O2~ox 1O0360 Anchorage, Alaska 99510 DATE: 12-1-93 REFERENCE: ARCO CASED HOLE FINALS ~-33 10-16-93 ~2-17 10-16-93 ~ 10-22-93 2-25 10-15-93 ~.~3-18A 10-25xj3 ~/4-23A 1~93 x~2~ 1~1~93 ~~ 1~21~3 ~~~ 1~21~3 7~ 11 1~~3 7~13 1~~3 ~~19~ 1~7-93 ~12-1~ 1~1~93 ~ 1~1~93 ~~ 1~1~3 ~~ 1~22-93 PerfRecord ~o-~:~qq,:::{ ,..,.Run 1, ~' Sch Prod Profllel~lo]rc-m?]pe~lhm 1, 5"%2q-~0'~'7S Sch Dual Burst TDTP ~-q~?~ Run 1, ~' Sch Prod Profile ~?,~ I-raa?)?~aa>~ 1,/~'~-57z~ Sch Gas Lift [ ~-~ }-r~-me] b~a~ Run 1, 1~ '&i~' O- ii 0o0 Sch MI InJ Proflle/~e~ 17eaSJ~ Run ~'w~00-~os~ Sch Prod Profile l~ao tre-~i~r~ Run Collar Log ~ ~'~ ~ ~0 ~-0 Run USIT[¢e~ ~.~'~ Color ~ ~m Pelf Record q~6o --q6'oo Run Baker IBP I 0~v -~6o Run ~P~t lz~o - I~qo7 ~ USIT (~ToSt~ ~ Color ~ ~Pe~ R~o~ ~0- 10~o ~ xPe~R~ ff~5o-tooSo ~ Co,ar i~) ~ C~ ~ckefl a~- ~z5 ~ Completion ~i ~ -~oo ~ 1, Please sign and re~rn ~~l~h~d ~ ~ receipt of data. RECEIVED BY Have A Nice Day! Sonya Wallace ATO-1529 9 1, 1, l"&ff'0- ~'too Sch 1, ~" Atlas 1, [~' ~zoo - q-~0 Sch 1, 2" I%-?D-~za~ Sch 1, ~" Sch 1, ,~' Sch 1, ~"%~0 0-~0 ~h 1, ~' ~h 1, ~' ~h 1, 1"~' 0-9o5~ ~h 1, ~' ~h 1, ~' ~h 1, ~' 11%~o ~1~'5~ ~h 1, ~' 5500 ~1 o~oo ~h ~h ~h ~h Atlas 1"~' eo-i~7~ ~h ~h ~h 1' 'zo-5 ~75 ~h # C~'raAL FILES #~N #BPX # STATE OF ALASKA * The correct APl# for 9-7 is 50-029-20223-00. ARCO Ahska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-9 3-29-93 1-11 -7"~"( 4-2-93 1-19 3-22-93 1-22 ~--19~ 4-6-93 1-29 4-6-93 1-33 ~--~ 4-4-93 U~-~2;8 3-27-93 2-'11 ~%~ 4-9-93 3-8 3-28-93 3-10 3~-~k 3-28-93 4-2 3-20-93 4-29 ~r ~?-.3-26-93 4-33 3-25-93 5-11 '7'~O 3-29-93 6-3 4-5-93 6-9 -/~- 79 4-5-93 6-1s 3-30-93 6-22 ~~ 3-26-93 -4A ~-4A 3-22-03 4-3-93 --9-35A 4-1-93 -11-13A 4-9-93 12-11 ~9~ 3-31-93 ~~3-20 3-21-93 q ~~4-22A 4-2-93 ~4-22A 4-2-93 16-30 ~-9~ 3-21-93 ~7-20 4-3-93 ~ 8-26 3-23-93 ~8-26 3-24-93 ff18-27 3-23-93 8-27 3-24-93 Leak Detect Run 1. 1".5"&25' Sch Production Run 1. 5" Sch Production Run 1. 5" Sch Perf Record Run 1. 5" Sch Production Run 1, 5" Sch Perf Record Run 1. 5" Sch InJ Profile Run 1, 5~' Sch Perf Record Run 1. 5" Sch Production Run 1. [~' Sch Tubing puncher Run 1.5" Sch CNL Run 1. 5" Sch Static Pressure Run 1, 5" Sch Press/Temp/Spin Run 1, 2~'&5' Sch Static Pressure Run 1, 5" Sch Production/Gas Entry Run 1, I~' Sch Perf Record Run 1, 5" Sch Leak Detect Run 1, 1"&5' Sch Production Run 1. 5" Sch Perf Record Run 1. 5" Sch Perf Record Run 1. 5" Sch Static Pressure Run 1, 5" Sch Perf Record Run 1.5" Sch Production Run 1. 5" Sch Perf Record Run 1. 5" Sch Production Run 1, 5" Sch PITS Run 1, 5" Sch Perf Record Run 10 5" Sch Perf Record Run 1. 5" Sch Perf Record Run 1. i~' Sch Perf Record Run 1.5" Sch Static Pressure Run 1. 5" Sch GR/CCL Run 1. 5" Sch Static Pressure Run 1. 5" Sch GR/CCL Run 1. 5" Sch Please sign and rettwn the~ attached copy as receipt ,of data. Sonya Wallace ~,~ APPROVED ATO-1529 -~"'~- ~, Trans# 93050 # C~CNTRAL lq'lT~ ' :,,ee. ' ~_ F_.,-" # :I:~q'TT.T~ # ~ CHAPMAN "~. #BPX # EXXI)N '~'~ ~ ~I'ATE OF ALASKA ARCO ALASKA, INC, I'"', O, BOX ANCHORAGE, ALASKA 995i DATE' 4-23-9i I~EFEI;:ENCE' ARCO CASED HOI_tF I=INAI_S '.')-":~ 4-t "~-°t COLL..AF(/PERF RUi'~ t , 2-t 3 ;~-25-9f PRODUCTION RIJN t, ,..--.:~ 4-2-9I TBG CUTTER I:(UN t, 4 t "~-'~'~-"o i F I-, OD ROFIL. E/PITS RUN 4'"'6 3-,=4-"9i TEHPEF:AI'UI:~ti:J RUN t 4-24 3-24'"'9i STATIC TEMF:'Ei;:A'¥LJl:;:Ii': RUN t , 4-'33 3-2t .... 9t i=']:l'S I:(Ut'~ t, ~q~?--..q7 3-20-9t. [~AMMA/CCL RLJN i , ''?-48 4-5-9t COLLAF,:/F:'EI:~F RLIN i t 2-22 4=t "'91 COLLAR/PERF" RUN t , g, ~4 2-3t 3-2t -;7t INJIECTION RUN t , ID1 ,-..-3=~ 3-2t i INJEL, I'ION RUN t, i~--98 S-20-9i FLtJID I,D. RtJN i, t4-i6 S-i8--9i PRODUCTION RUN i, i 5--~'5 '~.-"~"~-°t PZTS F.'.IJN i &'. ~. I I ..' - · '1 '" '~ i 5-3 2'28""9i FI:--RF BI:RI"."iAKDOWN RtJN t , i 6-6 4-t i-9t COI_LAI;t/F'EIqF RUN t · 5 ' 5' 2' &5 · 5 · 5" 5" 5' 5" 5" 5 · 5" 5' 5" 5" F:'I...EASE SIGN AND REI'URN THE AT"I"ACHED COPY AS' RIECEIF:"f' 01::" I;'ATA, I::li:CE I VED BY HAVE A NICE DAY! SI.'IARON WILYON A'¥O- t 529 A P P R 0 VIE D ..'~.. "J TRANS:~ 9 i A 'I'L.A;% C A M C 0 A l'L A .? CAMCO CAMCO C A M C 0 C A M C 0 A'I'I..AS H R ATI_nS A '1'1_. ~,~' C A i't C 0 C A M C 0 H R S C A H C 0 I..I R S I..II:<.S' ~:, ii_AS D I ~' T R I B U 'l' I 0 N · ,.'"' r' .,I:.NTRAI.." ' !:: tLE$ C,~ H li:] V I'"< [) i",!. 11' D & H "'~1" ..... i "' '~ · "' [:.,, 1 [:. N,S I 0 i"'l I:. X F' L. 0 R A l" I 0 N '11' '"' E X X 0 N ' · H A R A T I.'10 N '"' HOB I L. '11' ..... ' ........... F:'OR t4 t6 IS 50 0')9 20608 :~.' "f' I"1E. C, O I ~ K [:. C f E D A F:' ]:~,."" ' ...... .. ,.. - __ STATE OF ALASKA -. _ ALASK/ . AND GAS CONSERVATION C /IISSION REPORT SUNDRY WELL OPP_.RATIONS _,perations perform ed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well ,,,,,, Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 677' FSL, 303' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 24, T11 N, R15E, UM At effective depth 1506' FSL, 1231' FWL, Sec. 24, T11N, R15E, UM At total depth 1531' FSL, 1258' FWL, Sec. 24, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 62 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-33 9. Permit number/approval number 86-35/90-289 10. APl number 50 - 029-21545 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12845 feet Plugs(measured) 8793 feet Effective depth: measured 12793 feet true vertical 8755 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1775# Poleset 120' 120' Surface 2685' 13-3/8" 3500 sx CS III & 600 sx CS II 2747' 2490' Produuction 12620' 9-5/8" 500 sx CI 'G' & 300 sx CS I 12682' 8657' Liner 498' 7" 300 sx CI 'G' 12843' 8791' Perforation depth: measured 12702-12710'; 12710-12728' true vertical 8688-8692'; 8692-8702' Tubing (size, grade, and measured depth) 5-1/2", 17~, L-80, PCT ~ 12293' MD; 4-1'/2'"~2.~, L-80, PCT tail ~ 12393' MD Packers and SSSV (type and measured depth) BeT 3-H packer ~ 12283' MD; Camco Bal-0 SSSV ~ 2215' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Averaqe Production or In!ectign Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 597 309 43 -- Tubing Pressure 233 Subsequent to operation 1418 2002 1560 337 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby ~ertify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 539 DRR c: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE DS 4-33 FRACTURE TREATMENT OF IVISHAK DESCRIPTION OF WORK COMPLETED 5/14/90: RIH & changed out DGLV w/LGLV. 5/19/90' Performed a Non Reactive Perforation Breakdown Treatment as follows: MIRU, & PT equipment to 4000 psi. Treated perforations at: 12702 - 12710' MD Ref. Log: BHCS 3/13/86. 12710 - 12728' MD Pumped: a) 10 bbls Gel w/surfactant, @ 10 bpm, followed by b) 190 bbls Gel, w/230 ball sealers, followed by c) 260 bbls Seawater, @ 3500 psi, followed by d) Shutdown. Surged well. Resumed pumping, e) 240 bbls Seawater, followed by f) Shutdown. Ran Temperature Log. No channel detected. POOH. Rigged down.. 5/21/90' MIRU, & PT equipment to 8500 psi. Pumped a propped fracture treatment through perforations at: 12702 - 12710' MD Ref. Log- BHCS 3/13/86. 12710 - 12728' MD Pumped: a) 100 bbls 40# Gel Pre Pad, @ 30 bpm, followed by b) Shutdown. ISIP @ 2400 psi. Resumed c) d) e) f) pumping: 350 bbls Cross Linked Water Pad, @ 30 bpm, followed by 118 bbls Slurry w/proppant concentrations of 1 to 12 ppg, followed by 289 bbls Flush. Shutdown. ISIP @ 2400 psi. Placed a total of 18,500 lbs of proppant into formation, at an average treating pressure of 4100 psi. Rigged down. 5/24/90 - 7/28/90- Performed three proppant fill cleanouts. Intermittently produced well. 9/1/90' Replaced DG LV's w/LGLV's. Returned well to production, and obtained a valid production test. A I:;..' C 0 A L. A ~';.' K A .. I N (3, F' ,. O, B 0 ';K i '::) ;:.2:56 ':') ANCHrlF,'AGE, ALA~'KA 99"'.7t O DATE' 6/7/9G REF-ERENCE' ARCO CA$[-"D HOLE FINAL_:;' F'WDWi-2 _,~--':."":;'--on.,.., , .., ....~.'r.,.'~l IEEZE:. ...... F'ERF RttN i, ";"", t:'WDW'~-'.~ 5-'~'':'--~''-''' BRIDE,E F'L!JE, SET'FINE, REu""'"' RUN i '::," i-ti ,5-2--oF) COHP NELITRON G/R F;:UN ~ ":" i-2,::) 6-2-9G COMP NEUTRON G/F,: RUN i-29 6-3---'-;'n cr~HF' NELITRON G/R RUN ....; ..... . ! ...,' :3-27 5'- 24- 9'.') COHF' NEUTF:ON RUN '4-'-r''':' ~-tc~-°O F'O2T INJ TEMF' RLJN t 6-2 5-2.'5-9~.') COMP NEUTR. ON RUN W, 5' ?-i 6 _,':'~'-':.~4-°¢~,... , ~ COMF' NEUTRON RUN,,-~, _,~'" t 2-t 8 5-3(')-9".D COLLAR I;:UN t , 5 · i8-t7 5-2S-90 COMP NEUTRON RUN t , 5 · 18-t9 5-25-9¢ COMP NF'UTF,'ON RUN t , 5· F'I_EASE 2IGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA, HAVE A NICE DAY! JUN 1 4 1990 ~ALLY HOFFECKER Alas~ 0il & Gas Cons. Com~~°~ ATO- ~ ~'~ ~ ~9 Anchorage AF'F'ROVE~ TRAN$~ 902t3 .~;: C: I..I ;£CH A 'f L. A ,'_'.;: A 'F I... A &': RTL. AZ H R ;;'.'.' Y C H A f'l.. A::_,;' 5' C I--t 2 C H DI2TRIBUTION CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO ARCO Alaska, Ir Prudhoe B,.~, ~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 1, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-33, Permit No. 86-35 Dear Mr. Chatterton: Attached is the Application for Sundry Approval in triplicate detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DRR/jp Attachment CC: J. Gruber, ATO-1478 r~r-~,'-r',~.,~'-,- PI(DS 4-33)Wl-3 Gas Cons. Commissior~ Anchorag9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B 6132-C STATE OF ALASKA ALAStf~ IL AND GAS CONSERVATION APPLIC TION FOR SUNDRY A PROVALS , ype of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 677' FSL, 303' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, ,Sec. 24, T11N, R15E, UM At effective depth 1506' FSL, 1231' FWL, Sec. 24, T11 N, R15E, UM At total depth 1531' FSL, 1258' FWL, Sec. 24, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 62 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-33 9. Permit number 86-35 10. APl number 50 - 029-21545 11. Field/Pool Prudhoe E~ 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Conductor Sudace Plugs(measured) Production Liner Perforation depth: 12845 feet 8793 feet i"~k¥ 0 219!{!~"! measured 12793 feet ~t!;~Si(~ 0ii & Gas Coils. C0~lT~iSSi0i true vertical 8755 feet Junk(measured) ~ ;~nch0ral~ Length Size Cemented Measured depth True vertical depth 80' 20" 1775# Poleset 120' 120' 2685' 13-3/8" 3500 sx CS III & 400 sx CS II 2747' 2490' To p job performed w/200 sx CS II 12620' 9-5/8" 500 sx CI 'G' & 300 sx CS I 12682' 8657' 498' 7" 300 sx CI 'G' 12843' 8791' measured 12702-12710'; 12710-12728' true vertical 8688-8692'; 8692-8702' Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80, PCT@ 12293' MD; 4-1/2", 12.6#, L-80, PCT tail @ 12393' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 12283' MD; Camco Bal-0 SSSV @ 2215' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1990 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereby..~certify that the foregoing is true and correct to the best of my knowledge. Signed ,~~_~~)~'~---'~ Title Operations Engineering Manager Date ~//,,.~Z~/?Zg 15. Status of well classification as: Gas Suspended FOR COMMI~.~ION U.e,l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test __ Subsequent form required lO- David W. Johns~ '~ Approved by order of the Commissioner J Approva, No. 2(.) Commissioner Date ~:~' ;~ --0'1'0 Form 10-403 Rev 06/15/88 370 D. R. Reimers Approved Cop) Returned $-"t SUBMIT IN TRIPLICATE Drill Site 4-33 Ivishak Formation Hydraulic Fracture Treatment PRELIMINARY PROCEDURE Arco Alaska intends to pump a hydraulic fracture treatment on well 4-33 as outlined below: , . . . Pull gas lift valves and replace with dummy valves. Pressure test tubing / casing annulus. Pump a perforation breakdown treatment with ball sealers in water. A post treatment temperature survey will be taken to determine the interval taking fluid. Rig up fracturing service company, Pump propped fracture treatment at 30 BPM using a cross linked water system with approximately 26,000 lbs of 16-20 proppant. The interval to be fracture stimulated is Zone I (Romeo) from 12,702-12,728' . The pump schedule is outlined as follows: A. 250 Bbl cross linked water pad B. 16 Bbl 2 PPG proppant C. 18Bbl 4PPG " D. 19 Bbl 6 PPG " E. 20 Bbl 8 PPG " F. 22 Bbl 10 PPG " G 23 Bbl 12 PPG " If necessary rig up CTU and cleanout to PBTD. Install gas lift valves. Open well to flow gradually increasing the drawdown to allow proper fracture healing. 6 5 4 3 2 C0]:LED TUBING UN~.T BOP EOU ! PIlE N~ 1. 5000 PSI 7" WELLHEAD CONNECTOR IrLANOE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS q. :50(0 PSI ~ 1/§" 5. 5000 PSI 4 1/6" BLIND RAIDS 6. 5000 PSI 4 ~/16" STUlrrlN¢ BOX 3 H]REL ]NE BOP EOU ] PHENT 1. 5000 PSI ?" WELLHEAD OONN£CIOR FLANGE 2. 5000 PSI WIRE:LINE RAMS (VARIABLE S~ZE) 5. 5,000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Almska, Inc· P,O, B.o× t00360 Anchormge, Alaska 9951 0 DATE' t 0-t 3-87 REFERENCE' ARCO F'r e.~sur e 4-:33 9-2t-87 Ytat ic Gradien~ S'u. rvey Camco F'l. ea~e ..~ign and re~curn ¢he a¢'l'ached copy a..~ roceipt o'~' clat'a. Received By ...................................... HAVE A NICE DAY! Records Pr oc e_c.sor ATO- 1 5,... 9 TRANY -~875~'~7 ~ Ap p r oveci ............ ~} .................................. DI,?TRIBUT!ON Central Fi [e.s ~ F'hi LI. Chevron F'B Wet l Fi re.'.-:..' I) &,, M ~ R & 1.) Extension Exp tora~ion $ SAPC Exxon ~ Sta~e of A~as'ka Marathon ~ Texaco Mob i [ ,::.:, ,::) c:: "i A o..,.....; ...- C: a m c o STATE OF ALASKA ALASKA ~)IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well -~// ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] OIL 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 86-35 3. Address 8. APl Number P. O. Box 100~)60, Anchorage, AK 99510 50- 029-21545 4. Location of well at surface 9. Unit or Lease Name 678' FSL, 304' FWL, Sec.26, T11N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1448' FSL, 1150' FWL, Sec.24, T11N, R15E, UM 4-33 At Total Depth 11. Field and Pool 1528' FSL, 1237' FWL, Sec.24, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool RKB 62'I ADL 28323, ALK 2321 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 02/14/86 0l)/12/86 09/26/86*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 12,845'MD 8793'TVD 12,793'MD 8755'TVD YES [~ NO []I 2215' feet MD 1850' (Approx) 22. Type Electric or Other Logs Run D IL/BHC/GR/SP, FDC/CNL/GR/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 120' 30" 1775# Pol eset 13-3/8" '2.0#/68.0# L-80/K-55 Surf 2747' 17-1/2" 3500 sx CS Ill & 400 ,sx CS II Top job performed w/200 sx CS II 9-5/8" 47.0# L-80 Surf 12,682' 12-1/4" 500 sx Class G & 300 sx CS I 7" 29.0# L-80 12,:345' 12,843' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 1 2,702'-1 2,710'MD (8688 ' -8693 'TVD) 5-1/2" 12,393' 12~28~,' w/½ spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 12,710'-12,728'MD (8693 '-8707 'TVD) Pluq f/1270'-1999' 1545 sx CS II (1st); ~6.5 .~x £.~ Ill w/4 spf, 120° phasing & 2600 sx AS II (2nd) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 02/02/87I F1 owl ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 02/14/87 6.04 TEST PERIOD I~ 522 319 0 71° 744. Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.244 10 24-HOUR RATE I~ 1 899 1 41 3 0 27,1 ,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Drilled RR 03/17/86. Tubing run 04/13/86. Well perforated 09/26/86. WC2:043 :DAN I st) Form 10-407 Submit in duplicate _ Rev. 7-1-80 CONTINUED ON REVERSE SIDE . ~)/ 29. NAME Top Sadlerochit (Truncated) Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 12,671' TRUE VERT. DEPTH 8665' 8708' 30. FORMATION TESTS 12,729' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (da~ed 08/06/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item I6 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, ShuT-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 7/11/86 8~5~86 4-33 Pmp'd 100 bbls lease crude oil dn 9-5/8" x 13-3/8" ann f/freeze protection. Well not Arctic Pak'd. Arctic Pak w/300 sx CS I, followed by 125 bbls Arctic Pak. Drilling Supervisor Date SUB-SURFACE DIRECTIONAL $URVEY F'~UIDANCE ~'iONTINUOUS r-~'loo L MAY 2 i 198,6 Oil & 6~.s Cons. 6ommi;~; Company Well Name Field/Location ARCO ALASKA INCORPORATED WELL DS 4-33 (678'FSL, 304'FWL, S26, TllN, R15E) I II PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference N,o,; 71448 voss I Date o 1-MAY- 1986 Computed BY; KRUWELL GCT DZR.jCTI3NAL SURVEY 'USTCMER LZSTZNS :~RCJ ALASKA, IN ~. gS :,-33 METHJ]S O' C TI C.'L u S'- .~T.T. 3',J ',. . Ti'q' -;-IT '~ ;,L-, iNT-:~P]LITZJN: L .T. :q -.-1~ V:qTZC~L S 'CTZGN: -1C.q:'o 3ZST. D~VZ~TIDN ~ND r.S~TS A T/1RGET ~ZZ~JTH ~ZIMUTd OF NgRTH ~6 DES MIN EAST ARCO ALASK, A~ 'iNC. DS 4-33 PRUDHOE NORTH SLOPE,ALASKA D~F~' 1 'AY ;35 MEASUR,ED DEPT~ ~NTERP3L~T~D V&LUES FCR ~VNN 100 ;EET CF 0.00 lO0.O0 200.00 300.00 400.00 500.00 500.00 790.00 gO0.O0 :300.99 TRUE 3JB-S~ CCJRS:5 VERTICAL V' RTTSAL~ DsVIATT~N_ ~.? AZi:~OTm:~ DEPTq DEPIH OEG MIN DES ~,I~N O00.OO lO0.O0 200.00 300.00 400.00 500.00 500.00 700.00 BO0.O0 900.00 O.OO -52.00 0 0 N 0 3 = lO0,O0 3B,O0 0 15 S :,S 27 ~ 230.00 135.00 0 5 S 13 40 w '~00 O0 '~ ''~ ~B.O0 0 15 ~ 25 5'~ ~O0.O0 33~.00 0 21 5 23 2g E 500.00 ~.3:~.00 0 20 N 55 2 =. 599.97 537.97 2 21 N ~2 35 = 89~.'72 637.72 5 24 N ~2 31 = 7'99.03 -737.03 B 10 N ~I 50 ~ 897 ~3 335 B3 9 15 h ~ I" : 000.00 100.00 200.00 300.00 ~00.00 500.00 600.00 700.00 300.06 900.00 995.51 934.51 1095.22 1033.22 9 i1 N 11'93.9~ 1131.94 9 3~ N 5i 2C '" 1Z92.J2 1230.02 13 12 N 53 I c 1338.47 1BZ~.47 I6 51 14B3.40 142i.4~ 19 31 1576.99 15i4.9~ 2! 33 N 1069.22 1~07~ .__?~ 1759.53 15)7.5~ 25 ~i iN ~2 5i ' 1848.03 17:3x.O=~ -°9 O00.OO 100.00 200.00 300.00 *00.00 500.00 500.00 700.00 300.00 300.00 1934.3=~ 1'72, .35 ~018.i~ 1955 14 2098.~6 2025.4o 3B i~ N 37 4 - 2175.52 Zl1~.52 43 LO cq ~7 7 -. 2251.14 2i$~.I~ 41 41 N 53 2~ - 2324.53 2252.53 23~3. ~5 2'J3!.')5 2459. 35 23 ~7. B5 P523 09 ~4~1 O~ :' ~ >',l ~ ~0 5 2555.77 2523.77 51 il 20.8.~4 Z5~$~.5~ 50 5,5 q 4:+ i5 : 2711.54 254~.5~ 51 ~ q ~ 47 E 2774.~2 2712.42 51 ~ ~ 45 ~ E 2837.15 £775.!= 51 i~ N 45 _i - 2961.;2 Z39%.42 51 5a "J ~5 B~ = 3022.73 29:5~.75 ~2 10 "~ 45 50_ 5 30~4.3~ 30ZZ.= ~ 5i 57 '~ ~7 4 ~ . 3145.-6 3nR~ c- 52 wA ' v ...... ~ _, ".i ~, 1~ L 3205.i6 31'~3.15 5~ £ W ,';7 2~ 2 V-RTICAL 03SLEG $5CTiDN S"V~ITY !=~ET D~G/!O0 0.00 3.00 -0.03 3.24 -0.03 S. 29 -0.34 0.22 -0.75 3.39 -0.54 1.45 1.48 4.05 ~ 41 o ~0 .' .e . . i 3.94 1 · 9 O 35.31 1.00 51.51 0.57 57.50 83.4~ 2.43 102.70 4.57 12B.93 3.14 160.36 2.31 195.47 1.71 233.97 ~.~7 -- 275.5B 2.5,3 32.3.15 2.87 PAGE DATE 3F SURVEY: l~-APR-86 KELLY BUSHING ELEVATION: ENGINEER: VOSS R:STANg 0 0 0 1 1 0 5 13 25 37 53 69 108 134 163 1 ':2 ~. 229 37~.~ ~ ~ 26.~ 427.21 ~.15 310 4~.9,~ 3.76 357 q~3.65 1.25 ~0~ 513.36 2.75 460 6{ 0.79 ~. 21 512 752.55 £. 35 555 ~2?. , .55 ~.° 0s 520 902.~9 0.44 676 ~52.9! 3.43 732 13o3.50 0.45 733 113B.I,5 :3.35 843 iPlE.$O_ 0.:-=) m~9~ 1293.75 3.25 953 !371.90 0.39 lOOB 1450.44 0.72 1062 152~.3~ 0.61 1115 i60{.1~ 0.53 1170 15~7.27 0.90 !223 i757.56 1.15 1278 62. O0 FT DEPTH ULAR CO'3ROINAT~S HDRtZ. DEPARTURE OUTH EAST/WEST DIST, AZIMUTH FEE'T FEET DEG MIN · 00 N O.O0 E 0.00 ~2 S 0.15 ~ 0.27 .44 S 0.38 E 0.58 .73 S 0.22 ~ 0.76 .2B S 0.16 E 1.29 .50 S 0.54 E 1.60 .12 N 1.92 E 1.92 .i:3 N ,5.65 E 8.45 .73 N 14.42 E 19.94 .31 N 24.67 ~ 35.34 .05 N 35,85 E 51.57 · ~7 N 47.55 E 67.54 · i3 N 59.87 E 83.45 .79 N 75.35 E 102.70 .57 N 95.64 E 129.00 · 58 N llB.O1 E 160.37 · 5! N 141.'73 E 195.47 · I0 N 167.30 E 234.01 · 33 N 196.92 E 276.66 · 16 N 228.39 E 323.33 ,O0 ;1 260.30 E 373,60 .70 N 294.26 E 421.92 .93 N 330.51 E 487.19 .75 N 36~.75 E 550.50 .71 N ~08.70 E 515.87 · 72 N 452.35 E 583.74 .52 N 501.25 ~ 755.69 .09 N 552.98 E 330.84 .27 N 605.31 E 90B.27 .40 N 660.35 E 985.14 · 12 N 714.60 E 1363.36 · ~3 N 769.21 E 1141.52 .49 N 824.13 E 1219.21 .35 N 579.39 E 1297.00 .05 N 935.23 E 1375.07 .37 N 991.36 E 1~53.49 .28 N 1049.45 E 1532.28 · 26 N 1107.04 E 1610.91 .9~ N 1165.08 5 1689.84 .w2 N 122~.11 ~ 1769.97 N 0 0 E S 36 38 E S 40 33 E S 16 22 E S 7 4 E S 19 38 ' N 85 27 N 52 3 E N 45 17 E N 44 16 E N 44 3 E N 44 44 E N 45 50 E N 47 11 E N 47 50 E N 47 22 E N 45 28 E N 45 48 E q 45 22 E N 44 51E N 44 9 E N 43 26 E N 42 43 E N 42 3 f N 41 34 E N 41 25 E N ~1 33 E N 41 43 E N 41 52 E N 42 2 E N 42 11 E N 42 21 E N 42 31 E N 42 41 E N 42 51 E N 43 2 E N 43 13 E q 43 24 E q 43 35 E N 43 45 E ARCO ALASKA, ZNC. DS 4-33 PRUOH]~ ~Y NO2TM SLOPE,ALASKA TRd~ ~EASUR~D VERTICAL DEPTH DEPTI 4300.03 3253.27 4100.00 3321.26 4200.00 3379.93 4300.00 343~.)1 4490.00 34~.00 ~500.00 3556.56 4500.3} 3515.14 4700.30 36~3.~3 430~.DO 3732.91 ~900.00 3792.7~ 5000.00 3~53.Z3 5100.00 391~.3£ 5200.00 3976.30 5300.00 5~00.00 41~0.13 5500.00 4152.~3 5500.00 ~225.50 5700.00 4289.13 5800.00 4353.27 5909.00 441g.16 6000.02 6100.00 ~548.~0 6200.00 4613.51 6300.00 6400.00 47~7.00 6590.00 ~80~.~ 6500.00 ~870.~0 $730.00 4931.22 6800.00 6900.00 5055.~ 7000.00 5i19.3S 7100.00 5182.22 7230.00 52,4.53 7300.00 5307.14 7400.33 535~.~3 7500.00 5430.33 7600.03 5490.57 7700.00 5530.73 7~00.00 5511.55 7900.00 5672.33 -.],iPuT&T!DN C~TE: 1-M~Y-~5 SJB-S ~ V~RT!C~L ~PTH Cqd2S= V':RTirAL. JJGL.~G DEVIATION A" !~'!dT~ 5=CTZON S=V,ERiTY DEG MIq O~'S M!'4 ~-/ZT 3201.27 3259.26 3317.~3 3375.91 3435.00 3494.55' 3553.14 5611.75 3570.91 3730.7~ 54 39 >~ a7 31 : i~'~.94 .54 17 !J 47 36 ~,~ !)30.40 0.57 53 57 N ~7 40 = i011.37 0.24 53 ~ '~ N "7 55 ,., * !092 11 J.7 '~ I 54 0 N 4~ ')9 = ~i72 75 0 65 54 9 N 4~ 3 : 2253.76 $.42 54 11 N ~'9 ~'~ *_= .... :~'~3a.73 0.25 53 39 N 49 41 ,. 2~i5.65 0.41 ..~c3 -PS ?~ 50 0,, c_ 24),q.17,. Q.SA ', 5j 0 N FO i~ : 2375.15 0.93 37~1.23 3~52.32 4333.13 ~!03.53 4153.50 ~227.15 ~29t.27 ~35~.I~ 52 29 N fJ 3~ ~. 13:55.53 0.50 5~ S ~',l ~O 57 '~73~ AO J 75 5! ~! N 51 22 E 1~13.07 0.44 51 34 q 51 Z ~ 2S'91. 13 O. 54 31 IO~ ~ ~i 2 z. :3047. .... ~ ~. 5~ 5S 3'~ N ~1 34 - 31~4 BP 0.8~ :5.3 23 N 51 4~ ~ 3201.65 0.10 4421 4553.61 4.7*7 . ~21.1-~ ~ 9 ~ 5.93 .. _~1 _ '~42~.1~ 0.$0 ~ SS N fi2' 51 c_ 3504.59 1.73 47 30 t,,] 53 L2 ._ 3573.55 '0.~5 ~.:: 55 5~ HZ ~ . 3552.74 1.6~ ~0 14 '~ 51 15 ~_ 372~.61 1.,83 HZ ~ ~ ~+5 ~ 3'aG~ 23 ~ 5~ 52 ~'3 ", ;~ 3:~ = 39~5.77 0.43 5120.22 5182.~3 5245.14 53o3.03 5435.73 5510.33 51 I N ~5 ~ s ~275.33 1.46 5i :L3 t,~ ~ i1 'f +354.3~ 1.!3 51 33 'i 4-~ 2~9, : ~432.~0 0.80 52 5 :~ ~9 4~ E ~5!1.05 0.53 52 31 N 49 ~5 - ~590.07 ~.77 5~ ') l',~ 50 20 : .66n.51 0.65 ..... ~,49 2o 1.87 ,,, ., :~ ~2~.$$ 3.94 M~SURE R~CTAN NORTH/ FSE 13183. 1%42. 1~97. 1551. 1504. 1557. 1709. 17.51. 1813. 1864. 1914. 1~63. 2012. 2061. 21!1. 2159. 2207. 2254. 2301. 2345. 2394. 243). 2484. 2531. 2581. 2534. 25~6. 2740. 2794. PAGE ATE ~F SURVEY: 14-APR-86 ~LLY HUSHING ELEVATION: ENGINEER: VDSS D DEPTH 62.00' FT StJLAR COORDINATES H]RIZ. SOUTH EAST/WEST DIST. T FEET FEET 46 ~ 128~.05 42 N 1344.20 98 N 1404.04 27 N 1463.~2 03 ~l 1523.98 43 N 1584.95 35 N 1646.34 ~3 N 1707.98 92 N 176~.60 2~ N 1831.10 DEPARTURE AZIMUTH OEO MIN 06 N 1892.45 17 N 1953.73 43 N Z015.13 44 N 207,5.19 97 N 2137.11 34 ~'1 2197.68 91 N 225.3.31 64 N 231~.39 35 :q 2379.38 36 N 2439.50 1851.20 1932.51 2013.34 2093.94 2174.44 2255.27 2336.07 2~16.83 2497.17 2577.00 N 43 55 E N 44 4 E N 44 12 E N 44 21 E N 44 29 E N 44 38 N 44 48 N 44 58 ~ N ~+5 7 E N 45 16 E O0 N !499.18 53 N 2558.90 35 N 2618.37 34 N 2677.72 65 N 2737.55 ~1 N 2797.33 10 N 2856.97 49 N 2916.59 03 N 2974.00 ~9 N 3029.17 2656.33 2733.16 2513.50 2891.45 2969.57 3047.35 3124,93 3201.71 3278.08 3353.79 N 45 25 E N 45 35 E N 45 44 E N 45 53 E N 45 1 E N 46 BE N 46 16 E N 45 24 E N ~6 32 E N 46 40 E 2350.56 N 3083.19 2905.23 N 3138.14 2958.22 N 3195.37 300'9.59 N 3254.35 3060.~6 N 331~.36 3111.54 N 3374.79 3152 45 N 3435 196 3213.34 N 3497.11 3256.84 N 3555.08 3321.10 N 3514.17 3429.14 N 45 47 E 3504.50 N 45 53 3573.59 N 47 1 3652.83 N 47 8 E 3728.74 N 47 3~05.41 3885.97 N 47 19 3965.32 4043.81 N 47 20 E 4121.56 N ~7 18 E 4199.02 4275.51 4354.48 4432.66 4511.25 4590.30 4669.79 4749. 59 ~828.87 490,3.35 N 47 14 E N 47 12 E N 47 12 E N 47 14 E N 47 16 E N 47 lg E N 47 22 E N 47 25 E N 47 25 E N 47 25 E CGMPOTATZ]'v, :OAT:: ARCO ALASKAt INC. DS 4-33 PRJDHOE NORTH T MEASURED VER DEPTH D 8000.00 57 8100.30 57 8200.00 58 8300.00 59 8400.00 59 8500.00 6O 3600.00 60 8700.03 51 8~00.00 62 8900.00 52 9000,09 9100,00 9200,00 9300,09 94O0,0O 9500,00 9500,00 9700,00 9800,00 9900,00 iNT=,,RPOLATED VALUES ,~OR %VEN 100 =':ET ~UE SOS-SEA CCUDS;: v' ~ ;~ T i" ,& L TIC&L V~iRTI~'AL DEVI~TI3N aZIMUTd S~CTI!]N EPTH OEPTH OEG ~iN 3~6 MIN 32.~3 5.573 43 53 1 92.70 5730.70 52 38 N 42 4J .: 5067,47 53. 33 57~i · 33 14.06 5~5~.0,5 52 35 ~".J 43 .5~ g 52Z6.0~ 74. 5.8 591~ . 68 52 ~7 N 4~'~ 57 : 5305.45 35, 17 59'7Z.17 52 95.~3 0033.4~ 52 57 N ~'2 46 j J4~4.5~ 15.77 515~.77 53 19 N 75.51 5213.61 ~3 8 N 42 ~4 = 5703.30 5335.7'~ ~ ', -- ~,73.7'_ 152 50 N 42 4P. .... '~ 575~_,.5~ 6395.15 ~334.15 5~ 49 N 42 37 ~! 5~63.00 6456.53 53~4..5:~ 52 ~3 N ~.2 2'~ ~ 5942.39 651/.37 54J5.37 ~2 29 ;"~ ~Z '~ ~ 5021.54 '557.B,~3 551~.45 52 4 N 41 3~ E o103.54 5640,~6 557~.45 51 L9 N ~1 i~ ~ ~17;~.55 5703. iTHC 554~. · 13 50 ~9 N ~I 1:~ -~ ~P55~ _ . 20 6766.39 573~ 3~ 50 52 t,~ ~i o~ = 5333._P8 58:~2.~2 5533 62 ~v 54 N 40 ~7 ~ 5&~7.63 10000,00 10100,03 70 10200.00 70 10300,00 71 10~00.00 72 10500,00 72 10500.00 10700.00 10800,00 74 10~00,30 75 55. 5 '~ 18.25 '~ .... .! "' 57!~. 43.72 705!.72 53 4~ ~ ~3 25 E ~7~7.15 07.24 7!4~.2~ 50 ZO N ~0 £~ : 5~73.93 71.4,9 72~.4~ 4:~ 5~ N 43 30 ~ 5950.16 35.~7 7273.g7 4~ ~? N ~,3 35 : 7325.05 J1.39 733~.0~ 4) i2 N ~O ~ - 7!01.53 66.=3 7404.55 4~ 4 N ~! ! = 7!75.66 31.55 740~.5j 4~ ~5 ',~ 41 3:~ - 7252.36 96.03 753-~.33 50 5 !4 :,2 12 : 7328.53 59.73 75~7.73 5,3 +5 N ~," 31 ~ 7~+35.39 ~2.~0 76~3.40 51 ~'~ .... ~ ~ . 7433 .I~ 53.39 77~1 3~ *4.29 77~1.2'~ 53 i5 N 43 23 ~. 7641.37 03.~0 7~41.*j 5& 13 ~'~ 43 33 7721.90 61.55 7~-)).55 5, 15 ~", ~3. 3~ ' 7~,03.05 20 35 7~53 36 33 79. 31 0017.91 5 - .~ 7954.1~ -- ~0,53 ~07~.63 52 7 , 11000,00 15 lllO0,OJ 76 11200,00 77 11300,00 17 11400.00 78 11590.00 7~ 11000.00 7~ 11700.00 BO 11800.00 ~0 11)00.00 81 D.ATE 3F SURVEY: 14-A~R-86 K~LLY BUSHING ELEVATION: ENGINEER: VOSS OF MiEASURE3 DEPTH SEVERITY 3~5/100 0.70 0 .~+1 3,23 0.13 O .23 :3.28 O.lO !3 . 31 0.64 0.1~ 0.3t~ 0 · 19 O.14 0.37 9.93 0.35 0.49 0.39 0.57 0.37 1.02 3 · 30 0.35 3.58 0.30 3,55 ,].42 O. 82 0.52 RECTANGULAR CODRDINATES HDRIZ. NORTH/SOUTH EAST/WEST DIST, ~E~T F~ET FEET 62. O0 FT. DEPARTURE AZIMUTH DEG MIN 3378.42 N 3669.35 E 4988.14 N:'~47 3435.83 N 3724.22 E 5067.71N 47 3495.16 N 3778.27 E 514,5.98 N 47 3553.26 N 3832.47 ~ 5226.23 N 4T 3511.45 N 3886.67 E 5305.55 N 47 3669.73 N 3940.95 E 5384.98 N 47 3729.26 N 3995,20 E 5~64.58 N 46 37~5:$,84 N 4049,36 ~ 5544,15 N 46 3845.51 N 4103.67 E 5623.89 N 46 3904.35 N 4158.06 5 5703.80 N 46 3.93 0.89 0.85 0.,60 1.2R 3.82 0.54 0.27 0.62 1.15 22 E 13 E 9 E 6 E 2 58 , 55 E 51 E 6565.17 N 46 7 E 6542.83 N 45 4 E ,5720.46 N 46 0 E 6797.84 N 45 56 E 6874.70 ~ 45 52 E 6951.08 W 45 48 E 7027.10 N 45 45 E 7102.71 N ~5 42 E 7177.'98 N 45 39 E 7253.82 N 45 36 E 7330.08 N 45 34 E 7~07.05 N 45 32 E 7484.~9 N 45 30 E 7563.68 N 45 28 E 7643.31 N 45 27 E 7723.92 ~ 45 26 E 7505.16 N ,5 25 E 7886.0~ N 45 24 E 7966.39 N 45 23 E 8045.83 N 45 22 E 5131.36 N 5234.43 518~.31 N 5285.39 5245.61 N 5339.21 5303.29 N 5392.9~ 5361,34 ~1 5447.59 5~19.35 N 5503.11 547~.68 N 5559.19 5537,20 N 5615.14 55)5,C6 M 5670.37 5652.07 N 5725.21 4549.53 N 4733.11 4508.83 N 4733.91 4658.20 N 4834.52 4727.46 ~ 4884.~5 4786.29 N 4934.~7 4844.68 N 4984.53 4902.5'9 N 5034.26 4960.25 N 5053.74 5017.40 N 5133.13 5374.51 N 51~3.36 3963.05 N 4212.28 E 5783.52 4021.54 N 4266.29 E 5863.00 4980.28 N 4320.12 E 5942.40 4139.03 N 4373.67 E 6021.67 4197.95 N 4426.55 E 6100,59 4256.77 N 4478.46 E 6178.73 4315.37 N 4529,81 E 6256.32 4373.55 N 4580.79 E 6333.46 4432.22 N 4631.~0 E 6~10.78 4490.80 N 4682.51 E 6~87.93 N 45 4* E N 46 41 E N ~$ 38 E N 45 34 E N 46 31 E N 46 27 E N 45 23 E N 45 19 E N 46 15 E N 45 11E ARCO ALASKA, iNC. DS 4-33 PRUDHJE 5~Y NORTH SLDmE,ALAS~A TRUE MEASUkE3 V~RTICAL ~PTM DEPT~ 12000.00 ~202.95 12100.00 3257.18 12200.00 3333.38 12300.03 ~400.33 12400.00 8459.'39 12500.00 8540.50 12500.00 3612.73 12700.00 8a~6.15 12800.00 375'~.73 128~5.00 ~792. f9 SAT~: 1-MAY-~5 ZNT:DRPZLAT':J VALJ~S hiSR EVeN 103 SOD-SEA V~RTI-AL DEPTH 8140.95 B271.38 333~.B3 347~.50 ~530.73 8624.16 ~697.73 B73J.79 I · 5.25 0.63 0 · 57 qECTAN NORTH/ 5707. 5762 · 5816. 5868. 5919. 5~6~. 5017. 6063. 6109. 5130. PAGE 4 ~T~ OF SURVEY: 16-APR-86 ELLY BUSHING ELEVATION: 52.00 FT ENGINEER: VOSS O DEPTH GULAR COORDINATES HDRIZ. DEPARTURE SOlJTM EAST/WEST DIST. AZIMUTH T F-ET FEET' DEG MIN 98 N 5780.88 E 8124.01 N 45 21 E 71 N 5~B4.54 E 8200.65 N 45 21 E 10 q 5857.13 E 8275.59 N 45 20 E 56 N 5'939.05 E 8349.39 ' N 45 20 E 65 N 5990.12 E 8421.63 N 45 20 E 22 N .,5040.69 E 8~92.4~ N 45 20 03 N 6090.78 E ~561.67 N 45 20 17 N 6140.58 E 8529.52 N 45 21 h 29 N 6190.19 E 8597.23 N 45 22 E 11 N 6212.50 E 8727.74 N 45 22 E ARCO ALASKA, OS 4-33 PRUOHOE NORTH SLOPE,ALASK~ ME.~SURE3 2NT~RP3LAT'=3 VALj::S F3R :V'-'q lO0], =":ET 3F MEASUR CJUeSi~ V!.~RTiCAL DJSLEG RECTAN DEVIATION AZIHjTH SECTION .SEV"RZTY NORTH/ 3E3 qIN 3::' MI!.I F~_~T OES/100 ,=~E 0 000 000 000 000 000 000 000 000 TRU.~ SUE-S:A VERTICAL Vb~Ti~AL 0 0 :'~ 0 S = 0.00 O.O0 O. 9 15 N ,~ 42 '~ 51.51 0.57 ~7. 31 35 N 3~ 5' - ~73.22 i.53 268. 50 35 N ~4 2~ ~ 1160.50 3.45 75~. 54 39 b-j 47 31 ~ i34:~.9~ O.l~ 1333. 52 !9 N 50 34~. : 2655.63 0.50 1~54. 4~ 30 N 51 51:7 [{42~.14 0.~0 234:5. 50 ~7 N ~4 23 ' 419B.37 3.81 2850. 53 13 N 43 17 ( ~9:57.~5 3.70 337'3. 52 50 N 42 4'2 ~ '57~3.52 0.38 3953. 10 11 1g 12 000 000 000 845 .O0 O.O0 -62.00 .00 995.51 '934.51 · 33 1'934.35 1.872.35 .OO 2548.54 2586.64 · O0 3253.27 3201.27 · 00 3~53.23 3791.23 .00 4483.55 4421.55 · 00 5119.0~ 5057.~ .00 5732.~3 5570.43 .00 5335.73 ~273.73 51 2 N 40 &9 = 5554.79 i.02 4549. 50 5 iq 42 12 =_ 732:~.53 0.93 5!31. 50 ~2 f',! 44 21 -'1:51'21.,53 1.~,~ 5707. ~2 ~2 N 46 5~ ~ 5725.25 3.00 5130. .gO 5'953.5a · 03 7596.03 7534.33 · 00 5i02.95 · 00 5792.79 5730.79 DATE 3~ SURVEY: l~-APR-86 KELLY 3USdlNG ELEVATION: 52.00 FT 5NG!NEER: VOSS ED DL=PT GUL&R C03RDIN4TES H]RIZ. SOUTH EAST/WEST DIST. T FEET FEET OEPAR ~ZIMU DEG M TURE TH IN O0 N 0.]0 E 0.00 06 N 35.85 E 51.57~ 90 N =PGO.~O E 373.60 lg N 714.60 E 1053.86 4,5 N 12.~4.06 E 1351.20 06 N 1892.45 E 2656.33 O0 N 2499.18 E 3429.14 55 N 3083.19 E 4199.02 %2 q 3669.86 ~ 4988.14 05 ~1 4212.28 E 5783.52 N 0 0 N 44 3 N 44 9 N 42 11 N 43 55 N 45 25 N 46 ~7 N 47 14 N 47 22 N 46 44 E E E ff ) 5~ q 4733.11 5 5565.t7 35 N 5234.43'E 7330.08 98 ~ 57~0.$8 E 8124.01 11 N 5212.50 ff 8727.74 N 45 N 45 N 45 N 45 7 34 21 22 NORTH SLDPE,ALASKA £NT:2 ¢'JL:NT =i? v'.:~LUES ::,3R 'VEN !O0 TRU~ MEASURE3 VF:RTiSAL VERTICAL 0.00 0,00 -52,00 52.00 52.30 O.OO 1~2.00 162.00 lOO,O0 262.00 262.00 200.00 352.30 352.0D 200.00 462.00 ,62.03 400.00 552.01 562.}0 500.00 552.15 662.00 630.'30 752.53 $63.6:~ 802.00 300.00 ~55.03 952.00 903.00 1065.35 1062.30 1157.6~ ll6Z.OO 1103.00 1259.25 i2~2.00 1203.0j 1372.45 1362.00 1303.00 1477.32 146Z.00 1583.~8 1552.00 1509.0J 1592.12 1652,00 160~.~0 1892.65 1762.00 1916.01 1862.00 l~JO.O0 2032.53 1952.30 i~00.03 2154.10 2052.00 2282.15 2162.00 2100.0~ 2~14.55 2252.03 Z2O~.OO 2553.25 2352.00 2303.00 2703.35 2~52.00 2409.90 2802.0~ 2552.30 3021.20 2652.JC 2639.00 3180.23 2762.00 27C~.33 3339.78 2862.00 C3.j~S= 05G MIN 9£G 3500.93 2'J6g. OO Z~OO.OO 3553.72 3052.30 300).JO 3827.25 3162.00 3!O;O.O~ 3797.81 ~252.33 3200.00 ~169.51 3352.J9 3303.00 433~.97 3452.00 4539.29 3562.33 45~0.00 3~52.~ 5£30.00 4~48.71 3752.00 5014.39 3562.00 V:!'qTISAL O.O0 -0.02 0. O0 -0.20 -0.64 -0.77 O .29 5.25 15.00 2 '~. ~7 45.53 52.12 7 ~ 21 95.10 121.35 152.~8 1~.55 230.82 277. 78 730.92 3)0.37 45 .ES. 49 537.29 522.94 710.~2. 957. !4 i J 75. '~ 5 !200.52 i~+51.17 1579.61 172 9, O1 1347.15 !955.71 ,.~23.49 !751. 26 259 9. ~O >5~5.17 -- ' 567 · JO 3JGL~G S~VLRITY gE.S/10C 3. O0 0.21 0.35 0.42 Z.OC 1.85 3.9'2 !.21 S. 47 0,2.3 0.53 q.57 2.66 !.61 2.14 2,59 2.~5 2.99 3.22 1.50 3.1{ 3.5~ ! .91 0.53 ,D. 43 ,3.54 8.72 0.24 1.34 O. 23 J.11 0.65 0 0.35 0.51 0.37 P AGE K=LLY SUSdlNG ELEVATION: 62.00 FT. :NSIN:ER: VOSS SJE-S~ D=~TH RECT~NSULAN COORDINATES H]R!Z' HSRT-I,/SDUTH 7,aST/W:ST DIST. ,,=:,ET FEET FEET :D.3] ~1 0.00 E O..O0 0.10 S 0.07 E 0,12 0.37 S 0.35 = 0.51 0.50 S 0.29 ~ 0.67 1 05 S 0 1~ = 1 06 1.52 S 0.33 ~ 1.57 0.77 S 1.12 E 1.36 ~ 8 ~ N 4.51 = 5.35 10.05 N 11.12 5 15.00 20.95 't 20.76 E 29.~9 DEPARTURE AZIMUTH OEG MIN N 0 0 E S 32 25 E S 43 11 E S 25 59 E S $255 S 13 58 $ 55 38 N 57 2s N 47 48 E N 44 44 E 32.'-),~3 N 31.':~9 E 45.8,8 44.37 ~1 43.55 E 62.17 54.~5 N 55.'78 E 78.23 65.84 N 70.00 E 96.10 B1.50 N :~9.3~+ E 121.37 103.17 N 112.34 E i52.89 130.21 N 137.75 ~ 189.55 160.78 N, i65.55 ~ 230.~{5 125.21 ~'.l 197.74 E 177.36 235.11 N 233.16 E 331.12 N 44 2 F N 44 27 E N 45 29 E N 46 45 E N 47 45 E N ~7 33 E N 45 36 E N 45 51 E N 45 22 E N 44 45 E 251.51 N 271.13 335.75 N 313.63 399.55 N 361.30 ~58.29 N ~14.73 540.69 q 477.36 521.96 N 55~.74 711.12 N $79.78 799.{5 ~ 726.14 3~7.61 N 813.24 )75.16 N 901.52 390.84 N 43 55 459.45 N 43 2 539.02 N 42 9 525.54 N 41 31 721.59 N 41 28 833,41 N 41 43 956.56 N 41 58 1080.31 N 42 14 1203.84 N 42 29 132~.03 N 42 45 E E E E i E E E 1062."3 N 992.49 1153.79 ~ 1036.14 123~.74 N 1181.05 1332.25 N 1282.74 1~26.37 N 1385.31 151~,27 N 1437.15 1609,36 N 1590.64 1699.46 N 1695.54 17~6.99 ~q 1799.57 !~71.29 N 1901.26 E 1~54.22 N 43 2 E E 1582.41 N 43 20 E E 1711.54 N 43 33 E E 1~49.41 ~ 43 54 E ~ !98~.72 N 44 10 ~ E 2125.27 N 44 24 E E 2262.78 N 44 39 E E 2~00.70 N 4~ 56 E -_ ~36.10 N 45 1p E ~ 2567.69 N ~5 27 E C 2 ','lPd',r AT l ] N OS 4-33 PRUDHO=~ BAY NORTH SL2P~,AL~SKA OAT:: 1-MA¥-36 £NT'RPOL&TE3 V'ALUf. S FO& -~V~N lOO FFET 3= ~. ~_ ,,dT4 b:uTiCN .S V=RZTY EG ~iN iD-'$ 'ql'~l ~?:ET JEG/IO0 TRUE Sd5-S2.~ MEASURED '¢~RTICAL VZRTIgA1- D ,DEPTH OEPTq JL:PTH 5900.00 ~000.00 ~+100.00 ~200.00 ,303.00 ~,500.00 ~500 ~700.00 4.530.0:3 31 ~7 ".~ fl 2t = 2195,37 .,p ...... 16 3,40 31 12 N 51 1 = 30~5.72 O. 5a 50 26 N fl ~-~ i 31.5~.9~ 0.22 49 42 N 52 22 = 323~.32 49 ii N ¢I 53 E 3~04.10 i.0{ 4~ 20 N $2 47 ~ '3519.43 !.33 48 28 N 52 23 ~ 5629.,~3 1,71 $0 32 N ~0 53 E 374&,.63 2.15 5';_ ~9 N ~;9 32 ~ 357~.7I .~'.3'~_ 3177,39 3962.00 5338.39 4052.00 5499.13 4162.00 5557,40 4262.00 5313,51 4362.00 5966.8~ 4462,00 6119,92 4352,00 6269,38 4662.D0 6423.50 4762.00 6586.10 4862,00 49133.0,3 .SOOO.OO 51OO.O0 5300.00 540:3.00 5503.00 ~EOO.O3 5703.33 5800.00 51 ~1 N 46 ~5 ~= g334.15 i.51 .~ 5~ N ~5 25 E ~2~1.43 1.68 51 25 N 48 37 ~ 4375,94 1.2a 52 43 N 53 i6 E ,53!.84 0.5'3 52 35 ~..l &'3 39 E 4.7,64.0i 1.88 52 41 N go "2~ ~ ~3~g.42 2,27 ~2 ~3 i',j ~2 5~, :'! 5327.1~ 0.9~ 52 ~ .'l 4.3 2 - 515,~.14 0.21 674'9,73 4962,00 6909,55 5052.00 7067,88 5162,00 7227,52 5262.00 7388,82 5362.00 7552,66 5462,00 7718,56 5582.~0 7882.9Z 5662.00 8049,27 3762.00 ~214.29 5862,00 5.~OO.O0 5033.00 6100.00 o 2. 00.0 3 63:31.00 0490.03 55.}3 .O0 57 :} 3 · 3 J ~303.30 52 4.5 N 42 57 = 52~!~.77 O.2~ 52 57 '4 ~i 42 £ 5420,34 0,25 .--, .... '- . .~ ,., 53 1:3 N ~o 4~ : ~ - ~ ...58 0.19 ~ ~ N ~2 2~ . ~9'~9,3~ 0.14 51 lg r,~ 4i i4 : 520g.4~ 0.45 5J 5! N 4i = ,: 5327.~2 0.37 50 ;3 r: 42 5-~ ~ 5450.20 8379.02 5962.00 8544.52 5062,00 8710,43 5162.J0 8877.30 6262.00 9043.44 6362.J0 920~.78 5~62.]0 9373.20 SJ~2.O3 9534.52 5662.03 9693.05 6752.00 9351,~8 6852.~0 10.07 6952.00 69.89 7052.00 Z8.85 716Z.00 85.40 7252.30 ~0.03 7362.30 92.95 7462.00 47,13 7562.30 03.59 7662.J0 64.19 7752.00 29,74 7862,03 7000.00 710J.O0 7200.0J 7300.00 7400.00 7533.30 7503.03 77~3.0J 73~0 51 5 ~; ~0 ~3 5572.59 0.72 51 !7 N 40 2~ : 5695.53 0.12 :5J 53 !,i 40 22 ~ ~'3!).3~ 3.35 *) 55 :'~ ~3 23 -' og39.0,5 0.45 4~ 24 9 ~0 .i ~ 7,355.29 3.I~ 4~ 2 N ~0 59 = F171.37 :3.5~ 50 +7 >i ;2 ?i 7~03.i6 0.89 52 I} N 43 I 2 7533.52 0.92 53 35 N 43 2~ = 766~.21 0.9~ 100 101 103 104 105 107 109 111 112 114 P~GE DATE OF SURVEY: 14-APR-B6 KELLY ~USHING ELEVATION: ENGINEER: VOSS SOO-SEA OEPTH RECTANGULAR NORTH/SJUTH 1952.35 N 2031.41 N 2110.92 N 21,B7..35 N 2261.14 N 2332.49 N 2403.70 N 2470.44 N 2~42.9'7 N 252~.75 N 62.00 FT. 2712.39 2900.20 23~7.86 2972.50 305~.78 3133.37 3223.56 3~11.57 3407.18 3503.46 CODROINATES HDRIZ. DEP~RTU'RE EAST/WEST DIST. AZIMUTH FE~T FEET DEG MIN 3599.23 3695.76 3792,97 3891,01 3988,48 4085.~3 41~Z.15 4277.02 4369.52 4462,35 2001.25 E 2795.83 209'9.59 E 2921.45 2197.16 E 3046.88 2293.10 E 3169.04 2357.55 ~ 3283,34 2479,40 E 3404,10 2570,74 E 3519,~4 2659,53 E 3629,90 2751,66 E 3746,78 2848,67 E 3874.90 2945.37 ~ 4004.37 3034.35 E 4128,97 3120,27 E 4251.57 3211.46 5 4375.98 3307.63 E 4502.45 3406,90 E 4632,10 3508.21 E 4764.34 3604.37 E 4894,76 .~696,80 E 5327.45 3785.03 E 5158.32 N 45 42 E N 45 56 E N 46 8 E N 45 21 E N 46 33 F N 46 44 N 46 55 : N 47 6 : N 47 15 E N ~7 19 E N 47 21 E N 47 17 E N 47 12 E N 47 12 E N 47 16 E N 47 20 E N 47 25 E N 47 25 E N 47 20 E N 47 13 E 3875,28 E 52B~.88 N 47 6 E 3~65.11 E 5420,40 N 47 0 ~ 4055.02 E 5552,46 M 45 54 E 4145,73 E 5585,68 ~ 46 48 E 4235.74 E 5818.03 N 46 43 E 4324,34 f 5949,37 N 45 37 E 4412,47 E 6079,4~ N 46 32 ~ 4495,27 E 6205.59 N 46 25 ~ 4577,24 E 632~,09 N 46 19 E 4657,89 5 6450,47 N 46 13 E 4555.53 ,,J 4733.23 5 6572.98 4650.30 N 4819.28 E 6697.07 4744.46 N ~899.31 E 6820.05 4~36.20 N 4977.38 E 6939.97 4925.77 N 505~.08 E 7057.40 5013.39 N 5129.54 E 7172.5~ 5101.34 N 5207.32 E 7289.71 5193,35 N 5283.27 E 740'9.83 5282.59 N 5373.51 E 7535.34 5373,67 N 5464,02 E 7567,18 N 45 7 E N 45 1 E N 45 55 E N 45 49 E N 45 4~ E N 45 39 E q 45 35 E N 45 32 E N 45 29 E N 45 27 E ARCO 4LASKA, INC. DS 4-33 NORTH SLOPE~AL&SK~ TAUE ASURED VERTICAL DEPTH OEPT.t 11600,50 79~2.00 11770.20 ~062,00 11~34,55 3162.00 12092.01 5252.01] 122~2,55 3362,00 123a8.55 8462.OO 125Z9.90 8562.30 12567.22 3662.00 12503.10 8752.00 12845.00 879£.79 CSv, OUTAT']"~. nA'¥E:~ I-MAY-;~,. ~ iNT~R~OULAT~_3 VALUL~ ~3R ~:V~N 100 r-E'=T OF V~RTICAL O~PTH C2J:'S ' v'-;<T lC AL OOSL~G DEVIATiOn4 AZZMUT~ S~CTIOR S-'V~RITY OEG ~IN D:iS .~lIN F:.i::'.T O:G/IO0 7903.30 ~000.00 8100,00 8433.00 ,350J.00 3600.00 °700.33 8730.79 5~ 15 r.j ~3 !i~ : 7,~03.54 53 13 N ~3 5~ :._ 79~0.3~ 1.32 51 ~O h 4~ £0 ,~070.75 1.4~ 49 Il ~,.~ 44 2'0 ~ 61)2.14 2.01 47 Z8 N 4~ 5~ ] ~304.5.5 0.4.5 45 ~9 N ~5 5 - '3~I0.,33 1,2:) 4~ g N 46 I ~ 3510 7~ i 07 42 35 N 47 21 - 5504.85 0.9:{ 42 g2 N 46 )~ ~ ~{6~6.33 PAGE CATE OF SURVEY: 14-A~R-86 KELLY ~U.SHING ELEVATION: :NGIN:~R:.. ~ VOSS 62. O0 FT SU~-SEA R=CTA~ NO2, THI FEE 547:9. ,5577. 5571. 575B. .5 B38 · 5913. 5,:83. 6048 · 6110. ,5130 · %ULAR CO.]RDINATES SOUTq EAST/WEST T FEr-T H3RIZ. OIST. FEET O3 ~ 5559.52 92 N 5054.32 58 N 5745,27 37 ~ 5830.27 47 N 5909.28 ~6 N 5984.31 73 N 6055.69 18 N 5124.25 72 N 6191.73 I1 N 6212,50 7505.65 7942.58 8073.10 ~194.57 8307.06 8413.4B 8513.31 8607.38 8599.33 8727,74 DEPART AZIMUT DEG MI URE N N 45 25 E N 45 23 E N 45 22 E N 45 21 E N 45 2O E N 45 20 N 45 20 N 45 21 k N 45 22 E N 45 22 E O~ 4-33 P~OHOE 5~Y N]RTH SLJPE,AL~S~ MARKER TOP SAOLEROCHIT SASE SADLER3SHZT PBTD ZNTERO3LgTE9 VALU=S FiR (TRUNC,) ~EASUREC 9~PTd 8~LOJ Km 12~ll.O0 12729.00 12793.00 12345.00 SWOSEN HJRIZONS ORIGIN: TVS 3664.79 ~707.~3 8754.5.5 ~792.7~ 673 SJ~-SE~ 8502.79 ~545.53 8552.53 8730.79 PAGE DATE OF SURVEY: 14-APR-86 KELLY ~USHING ELEVATION: ~NGINEER: VOSS 52.00 304 SJRFACE LOCATION ~T. S~C. 25, T11N~ RI5E, U ~ECT~NGUL4R COORDINATES NORTH/SOUTM :~.EAST/WEST , 60~9.91 N 6126.,1~ E 6076.45 N 615~.99 E 5106.05 N 6186.72 E 5130.11 N 6212.50 E ARCD ALASK, A~ iN~. OS 4-33 PRJDHO~ BAY NORTH SLSDE~ALAS&,A SATE OF SURVEY: I~-APR-$5 KELLY ~DUSHZNG ELEVATION: ENGINEER: VOSS 62,00 FT. MA?,KER TOP S.A3~-.~qO''dlT~ PDTD TD (TRU~C.) FINAL MEASURED DEPTH N~LL LOCATIDN AT TO: VERTICAL VfRTiCAL 3fPTii DEPTH 12545.00 UF92.79 ~730.'F9 ME &SJP, E.S L,"P Th 67~ FSL, SU%-SEA 12~71. ]0 12729.30 127~3.00 12845.00 i]664.79 ~]707.53 3754.~9 3792. '79 8733.7:) MC~'iZ3NT~L 3NP'~ RTUR D l S T A NC ~ A Z I !.IdT M F,:~T 3~G ~,727.7q- N 45 2Z '?. 334 FWL~ SURFACE LOCATION ~T. SfC. '26, TllN~ R15E, U RgCT&NGULAR COORDINATES Ni]RTH/SOUT~ .EAST/WEST 50~9,9! N 6126,16 E 5076.45 N 6154.99 E 6106.05 N 6186,72 E 6130.11 N 6212.50 E SCHLUMBEROER 0 ~ REC T I ONAL SUR V E Y COMPANY ARCO ALASKA INC WELL OS 4-33 FIELD PRUOHOE BAY CJDUNTRY USA RUN 1 DATE LOOOEO iS - APR - 86 REFERENCE 000091448 WE~L DS 4- 33 (678'FSL, 304'FWL, S26, ~-~IN, R15E) HORIZONTAL PROJECTION NORTH 12000 REF lO000 8000 6000 4000 2000 -2000 SOUTH -4000 -4000 14EST 000071448 $CI:II.E = 1/2000 IN/FT -2000 0 2000 4000 SO00 BO00 10000 12000 · WELL DS 4-33 (678'FSL, 304'FWL, S26"~'11N, R15E) VERT1 , PROJECTION 226. -4000 -2000 0 0 2000 4000 6000 8000 ! 0000 ! 2000 ,,16, PROdECTION ON VERTICAL PLANE 46. - 2Z6. SCaLEO IN VERTICRL OEPTHS HORIZ SCALE = ]/2000 IN/FT STATE OF ALASKA ALASr,., OIL AND GAS CONSERVATION COM,,,.oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well Lq Alter casing ILl Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate [] Other 5. Datum elevation (DF or KB) 62' RKB 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchoraqe, AK 99510 4. Location of well at surface 677' FSL, 303' FWL, Sec. 26 T11N R15E UM At top of productive interval ' ' ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-33 8. Permit number 9. APl number 50- 029-21545 10. 'P°l¢~rudhoe Bay 0il Pool 1320' FSL, 1320' FWL, Sec. 24, At effective depth 1506' FSL, 1231' FWL, Sec. 24, At total depth 1531' FSL, 1258' FWL, Sec. 24, 11. Present well condition summary Total depth: measured true vertical T11N, R15E, UM (Approx.) T11N, R15E, UM (Approx.) T11N, R15E, UM (Approx.) 12845 feet Plugs (measured) 8773 feet Effective depth: measured true vertical 12793 feet Junk (measured) 8736 feet Casing Length Size Conductor 80' 20" Surface 2754' 13-3/8" Production 12644' 9-5/8" L i ner 498' 7" Perforation depth: measured 12702' - 12728' MD true vertical 8688' - 8707' TVD Tubing (size, grade and measured depth) 5½" L-80 tail @ 12393' MD Packers and SSSV (type and measured depth) 3H Hyd. pkr ¢_ 12283'. SS.~V ¢ 2215' 12.Attachments Description summary of proposal ~ Cemented Measured depth 1775# Poleset 120' 3500 sx CS 111 & 2747' 400 sx CS 11 Top job performed w/200 sx CS 11 500 sx Class G 12682' 300 sx Class G 12345' 12843' ~ue Vertical depth 120' 1495' 8657' 8420' 8772' Detailed operations program [~ BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved Signed ~/.,~/~// ~_~-'/'.,,,~~/~.~_,.~.. Title Operations Engineering Manager Date Commission Use Only Conditions of approval Approved by ~' Form 10-403 Rev ~-1--8-5' Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved Returned No. Commissioner by order of the commission Date JGA (263-4361) Submit in triplicate In accordance with Conservation Order No. 213, ARCO Alaska, Inc. requests the following: Permission to waive the production profile prescribed in Conservation Order 165, Rule 11a. Only 26' of perforations were shot in 4-33. All of the perforations were shot in Zone I a thereby negating the need for a spinner survey. Additional perforations in Zone I are planned. The timing of the perforations, however, is after the initial six month time period has passed. A production profile will be run subsequent to the additional Zone 1 perforations. STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COM .... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate~:'] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post 0ffice Box 100360, Anchoraqe~ AK 99510 4. Location of well at surface 677' FSL, 303' FWL, Sec. 26 T11N R15E UM At top of productive interval ' ~ ' 1320' FSL, 1320' FWL, Sec. 24, T11N, R15E, UM (Approx.) At effective depth 1506' FSL, 1231' FWL, Sec. 24, T11N, R15E, UM (Approx.) At total depth 1531' FSL, 1258' FWL, Sec. 24, T11N, R15E, UM (Approx.) 11. Present well condition summary Total depth: measured 12845 feet Plugs (measured) true vertical 8773 feet 5. Datum elevation (DF or KB) 62' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-33 8. Approval number 368 9. APl number 5O-- 029-21545 10. P°~rudhoe Bay Oil Pool Effective depth: measured 12793 feet Junk (measured) true vertical 8736 feet Casing Length Size 6onductor 80' 20" Surface 2754' 13-3/8" Production 12644' 9-5/8" Liner 498' 7" Perforation depth: measured true vertical Cemented Measured depth True Vertical depth 1775# Poleset 120' 3500 sx CS 111 & 2747' 400 sx CS 11 Top job performed w/200 sx CS 11 500 sx Class G 12682' 300 sx Class G 12345' 12843' 12702' - 12728' MD 8688' - 8707' TVD Tubing (size, grade and measured depth) 5½" L-80 tail @ 12393' MD Packers and SSSV (type and measured depth) 3H Hyd, pkr @ 12283' _. SSSV ~a 2215' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 120' 1495' 8657' 8420' 8772' 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 0 0 10 0 Not Yet On Production 10 1340 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~r~~,,. ~~~_~~- Form 10-404 Rev. 12-1-85 JGA (4361 ) Title Operations En§ineerin§ Manaqer Date Submit in Duplicate SUMMARY OF OPERATIONS Began perforating operations on 9/26/86. RU perforating unit, pressure tested equipment. RIH w/gun #1, shot interval 12710' - 12728' MD (4 spf), flowed well to cleanup. Shut-in well, POOH, all shots fired. RIH w/gun #2 shot interval 12702' - 12710'MD (1/2 spf), flowed well to cleanup. Secured well, RD. Depths referenced to CH-CNL 3/13/86. ARCO Alaska, Inc Prudhoe Ba~ .~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 16, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re' DS 4-25 DS 4-33 Permit No. 86-49 Permit No. 85-35 Enclosed are the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JGA/sd Enclosures CC' Standard Alaska Production Company File' PI(DS 4-25)W1-3 PI(DS 4-33)W1-3 ARCO Alaska, Inc. is a Subsidiary of AttanticRichfieldCompany ARCO AI. askm, Ii~c, I::'.0. Box t08360. ' Anchorage, A[mska [)ATE: Oct'ober '?, ~986 EEFERLNCE: ARCO Pressure Da'tm 3-5 9-20-86 Static Gradient Cmmco ~t -~.~ ?-28-86 4-33 t0-~-86 Stint'lc Grmdient Camco TRAN$ .~'.86622 of data. D I S T R I B U T I 0 N '* F:'hi L [ips Cen'trml. Fi [e~- Chevron F:'B WeI. L Fi I.e.s · ,,. D & H '~.,,. R & D E x '1.' e il"! .s i o 'l'! E x I:) I. o ~- a 't i (.-.I I"l :~: S o h J o o#o · '~' e x x o I'l .~. · ,~ ,.?¢a'te of A la~l<a Hmrmthon ~. Texaco · ,-" Hob J l ARCO Ala.~;ka, Inc. P.O. Box ~00S60 995 ~ 0 DATE° [)ct'ober 6, ~986 REF:'E"'RE:'NCE' ARCO Cas'ed FIoLe Final. C) 4--2'":; 9 .... °6-"~,6 CoLLar & I::'erf Log 4.--',.SS 9 .... ':26-'86 Co LI. ar ~, Per'F,. L_og 7 .... 9 9--t4--86 CoLLar ~ t::'erf, L. og I:~:u¥'~ 1 , 7-25 9--t4--86 CoL l. ar & Perf, LoG F;:un 1, t 6- t I 9 -.. o 7--.-o z. C o L L ~ r& F:'e r f 1... n g I:;'. u n I [i~e~ r [~ear Dear Eea r TRAN$ -..o''o 0 '1'" c:l a 'fa, I) I ~;' T R I B U T ]: 0 N '"' Cen ~' · ,- ,rat. Fi Les ~r"' Ch mVl-.. ]E.:, ~ M · ,.'"' Exte'n~'i_. or, Exp Lora't.' i o~'~ '"".' Ex XOl] Mara '~hon .IL ,,- Mob i L Phi t. Lip ..'..,' F'B WeLL F'i Le~ R & D · ?oh i o Y~mte of ALa_~.:ka Texaco ARCO Alaska, In¢ Prudhoe ~ ~ngineering Po~[ Of?ice ~o~; J00360 Anchorage,... A~ 995i0~03~0 Telephone 907 2~3 4248 August 18, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 4-33 Permit No. 86-35 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/PVL'sd Enclosure cc- Standard Alaska Petroleum Co. File PI(DS 4-33)W1-3 ARCO Alaska, !nc, is a',_ Subsidiary of Atlant cRichfieidCo 'hearty cc' J. G. Ambrose, ATO 1590 B. J. Nye, ATO 1584 P. V. Lantero, ATO 1507 STATE OF ALASKA ALA...,A OIL AND GAS CONSERVATION CO~,,,,,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown I~ Re-enter suspended well I~ Alter casing I I Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order lq Perforate lJXj Other I ] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 62' RKB feet 3' ACdo~C;s0ffi ce Box 100360, Anchorage, AK 99510 6. Unit or ~r~uP~enaBmaey Unit 4. Location of well at surface 677' FSL, 303' FWL, Sec. 26, TllN, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 24, T11N, R15E, UM (approx.) Atl~qtiVFeS~_e, pt~231' FWL, Sec. 24, T11N, R15E, UM (approx.) A~l~t'd~5~t~, 1258' FWL, Sec. 24, TllN, R1BE, DM (approx.) 7. Well number DS 4-33 8. Permit number 86-35 9. APl numob2e~_21545 50-- 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12845 feet Plugs (measured) 8773 feet 12793 feet Junk (measured) 8736 feet Casing Length Size Structural Conductor 80 ' 20" Surface 2754' 13-3/8" Intermediate Production 12644' 9-5/8" Liner 498' 7" Perforation depth: measured NONE true vertical NONE Tubing (size, grade and measured depth) '" L-80 tail @ 12393'MD Packers and SSSV (type and measured depth) 3H Hyd. pkr @ 12283', SSSV @ 2215' 12.Attachments Description summary of proposal [] Cemented Measured depth True Vertical depth 1775# Poleset 120' 3500 sx CS 111 & 2747' 400 sx CS 11 Top job performed w/200 sx CS 11 500 sx Class G 12682' 300 sx Class G 12345' 12843' 120' 2495' 8657' 8420' 8772' Detailed operations program [~_ BOP sketch 13. Estimated date for commencing operation September 1, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I here~certify th/~ t/~ f~egoing is true and correct to the best of my knowledge Signed ~/'~4~//~'~ Title Operations En~ineerin9 Manager Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI by order of [~[ ~. ~]~ Commissioner the commission Date Form 10-403 Rev 12-1-85 PVL (263-4217) Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 4-33 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref- BHCS 3/13/86 Proposed Perforation Intervals' 12670' - 12728' MD ARCO ALaska, Inc. F'.O· Box t00360 Anchorage, ALaska 995~ 0 DATE' July ~ 4,t986 REFERENCE' ARCO Cased HoLe Final 4--tf 3-26-86 CN/GR Mu[¢ispace Run t 5" 4-t~ 3-2-86 ACBLog VDL/$ign Run I ~" 4-23~ 4-9-86 ACBLog VDL/~ign Run ~ 5' 4-33 ~ 4-~-86 ACBLog VDL/~ign Run ~ 5" ~ 6-24 ~ 4-7-86 AC~Lo~¥DL/~ i gn Run ~ 5' -, , Received By HA~E A NICE~ Linda Hu~ce ATO-~ 529 TRAN$ ~8643~ of Dl'ess Dress Dress Dress daSa. DISTRIBUTION Cen~rm[ Fi [es Chevron D & M ' Extension Exp[ora$ion '~ . -1- Exxon Hara ~hon ~ Mob i [ Phi [lips F'B We[[ Fi les R & D $ohio S~a~e of Alaska Texaco STATE OF ALASKA ALASK,-, ~IL AND GAS CONSERVATION COMIv,,..~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other ~-X Complete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 1003,60 Anchoraq~, AK 9~).510 4. Location of well at surface 678'FSL, 3,04'FWL, Sec.26, T11N, R15E, UM At top of productive interval 1448' FSL, 1150'FWL, Sec.24, T11N, R15E, UM At effective depth 1504'FSL, 1211'FWL, Sec.24, T11N~ R15E, UM At total depth 1528'FSL, 123,7'FWL, Sec.24, T11N, R15E, UM 5. Datum elevation (DF or KB) RKB 62 ' 6. Unit or Property name Prudhoe Bav Unit 7. Well number 4-3,3 8. Approval number 72 9. APl number 50-- 029-21545 10. Pool Prudhoe Bay Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 1 2845 feet 8793, feet Plugs (measured) N o n e 12. Effective depth: measured true vertical Casing Length Conductor 80' Surface 2754' 12793, 8755 feet feet Junk (measured) Production 12644' Liner 498' Perforation depth: measured true Vertical None None None Size Cemented Measured depth 20" 1775# Poleset 120'MD . 13,-3/8" 3500 sx CS III & 2747'MD 400.sx CS II Top job w/200 sx CS II 9-5/8" 500 sx Class G 12682'MD 7" 3,00 sx Class G 12345'-12843,'MD Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail ~ 12,3,93,'MD Packers and SSSV (type and measured depth) 3,-H pkr ~ 12,283,' & SSSV ~ 2215' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and finaI pressure Rue Verticaldepth 120'TVD 2490'TVD 8673'TVD 8432'-8792'TV RECEIVED MAY 2 1 1986 Alaska 0il & Gas Cons. Comrni~s' · 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations Copies of Logs and Surveys RunxF~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Gyro Signed ~/¢(/)~,~V~' Title Associate Engineer Form 10-404 Rev. 12-1-85 (DAM) SW0/026 Date Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Prudhoe Bay Auth. or W.O. no. AFE AS0138 WWS #1 Operator ARCO Alaska, Inc. Spudded or W.O, begun Complete Date and depth as of 8:00 a.m. 4/11/86 4/12/86 th~u 4/13/86 ICounty or Parish Lease or Unit Title North Slope Borough ADL #28323 Comp let ion API 50-029-21545 IA.R.Co. W.I. 21.66% Date 4/10/86 Complete record for each day reported Accounting cost center code State Alaska IWell no. 4-33 7" @ 12,843' 12,793' PBTD, Prep to log 9.4 ppg NaC1 Accept rig @ 2200 hfs, 4/10/86. Model "G" BP, TOH. RU loggers. I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prtor status If a W,O. I 2200 Hrs. ND tree, NU & tst BOPE. Pull 7" @ 12,843' 12,788' PBTD, RR 9.4 ppg NaC1 Rn 6" gage ring/JB; unable to get thru lnr lap, POOH. w/5.7" gage ring/JB to 12,782' DPM, POOH. RIH w/CBL, log lnr w/1000 psi. Rn 8.375" gage ring/JB, POOH, LD DP. RU & rn 275 jts, 5½", 17#, L-80 AB MOD 8RD tbg, 2 jts, 4½", 12.6#, L-80 BTC csg & lz~" pup jt w/SSSV @ 2215', 3-H Pkr @ 12,283', TT @ 12,39~. Drop ball, set pkr, shear PBR. Tst tbg & ann. Set BPV./ND, ~OPE, ~ & tst tree. RR @ 1530 hfs, 4/13/86. Old TD [ New TD I Released rig ~ Date 1530 Hrs. I REC i'¥ED MAY 2 1 1986 Alaska 0il & Gas Cons. C0mmi::.i PB12,788 ' Depth Kind of rig 4/13/86 Rotary lype completion (~in~l~, dual, ~ S~ngle Classifications (oil, gas, etc.) Oil Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data ,,, Well no, Date Reservoir Producing Inte~al Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct 5/09/86 Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. STATE OF ALASKA ALASr,,,-, OIL AND GAS CONSERVATION COM~v~,,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~_ Suspend ~ Operation Shutdown ~ Re-enter suspended well i.:: Alter casing 1 Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate/'~ Other ' 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 100360 Anchoraqe, AK 4. Location of well at surface 677'FSL, 303'FWL, 5ec.26, T11N, R15E, UM At top of productive interval 1320'FSL, 1320'FWL, Sec.24, TllN, R15E, UM (approx.) At effective depth 1506'FSL~ 1231'FWL, Sec.24, T11N, R15E, UM (approx.) At total depth 1531'FSL, 1258'FWL, Sec.24, T11N, R15E, UM (approx.) 5. Datum elevation (DF or KB) 62 ' RKB 6. Unit or Property name Prudhoe Bay Unii; 7. Well number 4 -33 8. Permit number 86-35 9. APl number 50-- 029-21545 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical I 2,8 4 5 feet 8 7 7 3 feet Effective depth: measured 1 2 793 feet true vertical ' feet 8736 Casing Length Size Conductor 80 ' 20" Surface 2754 ' 13-3/8" P roducti on 12,644 ' 9-5/8" Liner 498 ' 7" Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 5-1/2", L-80, tail (~ 12,393'MD Packers and SSSV (type and measured depth) 3H Hyd. pkr @ 12,283', SSSV ~ 2215' Plugs (measured) N o n e Junk (measured) None Cemented Measured depth 1775# Poleset 120'HD 3500 sx CS III & 2747 'MD 400 .sx CS II Top job performed w/200 sx CS 500 sx Class G 12,682'MD 300 sx Class G 12,345'MD- 1 2 , 843 'MD True Vertical depth 1 20 'TVD 2495 ' TVD Il. 8657 ' TVD 8420 'TVD- 8772 'TVD RECEIVED MAY- 8 1986 Naska 011 & Gas Cons. Commission Anchorage 12.Attachments Wel 1 Hi story Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation June, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/0 ~ /~]jL~ Title Associ ate Engi neet Commission Use Only ( DAM ) SA/029 Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ~.p-proved ~¢urn-~. Approved by :7~' i, -~':: !;~ i¢~'~' (:,~: Form 10-403 Rev 12-1-85 ~,, Commissioner by order of ,~__/.,~_,~..~.~ the commission Date Submit in triplicate Well History - Initial Report - Daily P~-:.and SUbmit the "lnitle.l-Rel=orl'" on the first-Wednesday after a well is spudded or workover operations are started. Dally'wOrk prior to spudding snould be summarized on the form giving inclusive dates only. . District Alaska Field Prudhoe Bay Auth. or W.O. no. AFE AS0138 County. parish or borough North Slope Borough ILaa.e ADL #28323 or Unit I Title Drill JState Alaska lw'";°_'33 .Rowans33 AP1 50-029-21545 Operator : ARco Alaska, Inc. Spudded or W.O. begun IDate Spudded Date and depth aa of 8:00 a.m; . 2114/86 2/15/86' thru 2/18/86 2/19/86 2/20/86 2/21/86 Complete record for each day reported I Hour 2/14/86 0430 Hrs. 20" @ 120' 311', (191'), Drlg Wt. 9.7, PV 18, YP 37, PH 8.5, WL 18.2, Sol 10 Accept rig @ 0100 hfs, 2/14/86. NU diverter sys. 0430 hfs, 2/14/86. Drl 17½" hole to 311'. ARCO W.I. Pr or status Sp~ well @ 20" @ 120' 1722' PBTD, (1688'), PU 5" DP Wt. 9.6, PV 10, YP 45, PH 11.5, WL 73.2, Sol 10 Drl & surv 17½" hole to 1999'; circ, POOH to redrl. PU 5" DP, TIH, set cmt plug w/1400 sx CS II & 865 sx CS III & 145 sx CS II,-POOH, WOC. TIH w/BHA, drl cmt to 1722', POOH, cmt not firm enough to kick off. PU 5" DP, TIH to set 2nd plug. 572', 1.2°, N43.3E, 571.99 TVD, .68 VS, .70N, .28E 845', 9.5°, N36.3E, 843.72 TVD, 24.62 VS, 19.19N, 15.77E 1322', 13.2°, N56.3E, 1313.20 TVD, 107.87 VS, 77.00N, 75.60E 1950', 12.6°, N37.3E, 1916.11TVD, 282.63 VS, 196.88N, 202.86E 20" @ 120' 1325', Drlg Wt. 9.3, PV 8, YP 38, PH 12.25 WL 93.5, Sol 7 M&P 2600 sx AS II. Displ w/wtr. CIP @ 1030 hrs, 2/18/86. WOC. TIH w/BHA, tag cmt @ 1186', dress cmt to 1236', POOH. TIH w/Navi-Drl, drl f/1236'-1325'. 20" @ 120' 1870', DD Wt. 9.4, PV 15, YP 12, PH 9.0, WL 17.0, Sol 8 DD & surv 17½" hole to 1870'. 1598', 21.8°, N41.3E, 1575 TVD, 195 VS, 136N, 139E 1721', 24.5°, N42.3E, 1688 TVD, 243 VS, 172N, 172E 21.66% if a W.O. 20" @ 120' 2750', (880'), Rn'g 13-3/8" csg Wt. 9.8, PV 22, YP 30, PH 9.25, WL 12.4, Sol 11 DD, drl & surv 17½" hole to 2750', C&C, TOH. RU & begin rn'g 13-3/8" csg. 1850', 27.3°, N41.3E, 1804 TVD, 299 VS, 214N, 209E 2413', 41.6°, N39.3E, 2264 TVD, 618 VS, 463N, 413E 2663', 48.7°, N44.3E, 2441TVD, 794 VS, 593N, 533E RECEIVED MAY- 8 1986 Naska 0il & Gas Cons. Commission Anchorage The above is correct Signature /'1 For f~m preparation end,distributiOn. see Procedures Manual, Section 10. Drilling. Pages 86 and 87. Date 4/14/86 [Title Drilling Superintendent Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish JState Alaska North Slope Borough Alaska Field Itease or Unit IWell no. Prudhoe Ba, I . ADL #28323 I 4-33 Date and depth as of 8:00 a.m. 2/22/86 thru 2/24/86 2/25/86 2/26/86 2/27/86 2/28/86 Complete record for each day while drilling or workover in progress 13-3/8" @ 2747' 6732', (3982'), Drlg Wt. 9.6, PV 10, YP 7, PH 10.0, WL 14.6, Sol 10 Fin rn'g 69 jts, 13-3/8", L-80, 72# BTC csg w/FC @ 2664', FS @ 2747'. Cmt w/3500 sx CS III & 400 sx CS II. Displ using rig pmps, did not get cmt rtns. Perform 200 sx CS II top job. ND diverter. NU & tst BOPE. RIH w/12¼" BHA, DO cmt & flt equip + new hole to 2720'. Tst csg, drl 15' new hole. Conduct formation tst to 11.4 ppg EMW. Drl & surv 12¼" hole to 6732'. 2974', 51.6°, 3598', 52.3°, 4226', 54.1°, 4934', 53.0°, 5236', 51.7°, 5798', 50°, 6316', 49.5°, N43.3E, 2640 TVD, 1033 VS, 766N, 698E N46.3E, 3027 TVD, 1522 VS, illiN, 1045E N46.3E, 3399 TVD, 2028 VS, 1461N, 1410E N48.3E, 3816 TVD, 2600 VS, 1843N, 1836E N50.3E, 4016 TVD, 2861VS, 2013N, 2034E N52.3E, 4353 TVD, 3276 VS, 2274N, 2358E N52.3E, 4691TVD, 3665 VS, 2511N, 2670E 13-3/8" @ 2747' 7634', (902'), PU mtr Wt. 9.5, PV 10, YP 5, PH 9.0, WL 13.0, Sol 9 Drl & surv 12¼" hole to 7634'. 6748', 51.9°, N47.3E, 4958 TVD, 4005 VS, 2734N, 2927E 7247', 51.5°, N49.3E, 5270 TVD, 4395 VS, 3002N, 3209E 7554', 52.8°, N51.3E, 5458 TVD, 4636 VS, 3157N, 3396E 13-3/8" @ 2747' 8173', (539'), TIH Wt. 9.5, PV 14, YP 7, PH 9.25, WL 10.4, Sol 9 TIH, wsh 7583'-7634', drl & surv 12¼" hole to 8173'. 7787', 52.7°, N48.3E, 5600 TVD, 4821VS, 3277N, 3537E 8093', 53.1°, N43.3E, 5783 TVD, 5066 VS, 3449N, 3710E 13-3/8" @ 2747' 8173', (0'), Wrk stuck pipe W~. 9.4, PV 10, YP 6, PH 9~0, WL 7.8, Sol 8 PU 2 stab, TIH, tight @ 8080', wrk stuck pipe. freept, POH w/WL. Wrk stuck pipe. RECEIVED MAY- 8 1986 RU DA, rnAI;~L~l<:a 0il & Gas Cons. C0mmiss[0. Anchorage 13-3/8" @ 2747' 8173', (0'), POOH w/DP Wt. 9.4, PV 13, YP 6, PH 9.0, WL 7.4, Sol 7 Jar on stuck pipe. RU DA w/string shot @ 7985', lost torque but could not BO, POOH w/WL. C&C. TIH w/freept; unable to get accurate reading. TIH w/string shot, BO pipe w/TOF @ 7886', RD DA, POOH w/DP. Fsh in hole = 193.65'. The above is correct Signature For form preparation and"-distribution / see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate ITiUe 4/14/86 Drilling Superintendent .,,CO Oil and Gas Company Daily Well History--Interim Inst~uctiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and deptl~ as of 8:00 a.m. County or Parish Alaska North Slope Borough ILease or Unit Prudhoe Bay ADL #28323 Complete record for each day while drilling or workover in progress 3/01/86 thru 3/03/86 3/04/86 3/05/86 3/06/86 3/07/86 lState Alaska Well no. 4-33 13-3/8" @ 2747' 9615', (1442'), TIH Wt. 9.5, PV 16, YP 8, PH 9, WL 5.6, Sol 8 Fin TOH, retrv partial fsh. TIH w/fsh'g assy, pull fsh free, TOH, full rec'y. RD DA. TIH w/BHA to 7674', wsh & rm to 8173', drl & surv 12¼" hole to 9615'. 8288', 82.7°, N44.3E, 5901TVD, 5221VS, 3562, 3818 8899', 53.3°, N43.3E, 6268 TVD, 5708 VS, 3919, 4151 9175', 53.0°, N42.3E, 6434 TVD, 5929 VS, 4080, 4301 9585', 51.8°, N42.3E, 6684 TVD, 6253 VS, 4321, 4520 13-3/8" @ 2747' 10,725', (1110'), Drlg Wt. 9.6, PV 18, YP 7, PH --, WL 6.0, Sol 9 Drl & surv 12¼" hole to 10,725'. 9,837', 50.9°, N41.3E, 6841.17 TVD, 6448.82 VS, 4467.54N, 4651.17E 10,446', 50.3°, N41.3E, 7224.02 TVD, 6920.25 VS, 4823.35N, 4963.75E 13-3/8" @ 2747' 11,075', (350'), Drlg Wt. 9.7, PV 15, YP 9, PH 10, WL 6.0, Sol 10 Drl & surv 12¼" hole to 11,075'. 10,721', 49.3°, N41.3E, 7401.52 TVD, 7129.33 VS, 4981.15N, 5102.38E 10,894', 49.5°, N42.3E, 7514.10 TVD, 7260.17 VS, 5079.07N, 5189.93E 13-3/8" @ 2747' 11,567', (492'), Drlg Wt. 9.7, ?V 15, YP 8, PH 10, WL 5.8, Sol 10 Drl & surv 12¼" hole to 11,567'. 11,348', 52.6°, N44.3E, 7800 TVD, 7612 VS, 5336N, 5432E 11,502', 53.8°, N44.3E, 7892 TVD, 7736 VS, 5424N, 5518E 13-3/8" @ 2747' 11,831', (270'), Drlg Wt. 10, PV 20, YP 13, PH 10.5, WL 5.6, Sol 12 Drl & surv 12¼" hole to 11,831'. 11,651', 54.2°, N44.3E, 7980 TVD, 7856 VS, 5510N, 5602E RECEIVED MAY- 8 1986 Naska Oil & Gas Cons. Commission Anchorage The above is correct Signature For form preparation and distribution see Procedures Manuel Section 10, Drilling, Pages 86 and 87 JDate 4/14/86 JTit, Drilling Superintendent ,,.;0 Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, co'ring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska County or Parish ]State North Slope Borough LeaseADL #28323 or Unit Prudhoe Bay Alaska Well no. 4-33 Date and depth as of 8:00 a.m. 3/08/86 thru 3/10/86 3/11/86 3/12/86 3/13/86 3/14/86 Complete record for each day while drilling or workover in progress 13-3/8" @ 2747' 12,692', (861'), Rn'g 9-5/8" Wt. 10.2, PV 21, YP 12, PH 10, WL 5.8, Sol 14 Drl & surv 12¼" hole to 12,682', 30 std short trip. RIH, drl 10', circ, TOH. Chg rams to 9-5/8" & tst. RU & begin rn'g 9-5/8". ' 11,837', 53°, N43.3E, 8090 TVD, 8005 VS, 5618N, 5706E 12,141' 49° N45 3E, 8581TVD, 8241VS, 5788N, 5871E ' ~ ' 12,449', 45. o, N46.3E, 8491TVD, 8467 VS, 5945N, 6033E 12,602', 43.5°, N47.3E, 8600 TVD, 8574 VS, 6018N, 6111E 9-5/8" @ 12,682' 12,692', (0'), Wait on pack-off Wt. 10.1, PV 16, YP 10, PH 9.0, WL 6.6, Sol 11 Fin rn'g 289 ]ts, 9-5/8" csg w/FS @ 12,682', FC @ @ 12,595'. Cmt w/500 sx C1 "G" w/.75% D-31 & .20% R-5. CIP @ 1415 hrs, 3/10/86. Tst csg to 3000 psi. Att to tst pack-off w/o success. Repeated retrievals & art's. LD 12½" BHA. Pack-off @ machine shop being milled to reduce OD of junk ring. 9-5/8" @ 12,682' 12,692', (0'), TIH to DO Wt. 10.1, PV 18, YP 10, PH 9.0, WL 6.4, Sol 11 Set junk ring, compression seal & pack-off in place. NU BOPE; no tst. Pmp plastic in void bet lower hgr seal & compression seal, att tst w/o success. In] 120 bbls crude in 9-5/8" x 13-3/8" ann, filled stack w/diesel, close blinds & tst compression seal to ~3000 psi, tst rams to 5000 psi. TIH w/8½" BHA. 9-5/8" @ 12,682' 12,845', (153'), POOH to log Wt. 9.8, PV 19, YP 9, PH 11.0, WL 5.2, Sol 11 TIH, wsh to 12,597', DO FC & cmt, tst csg to 3000 psi. Drlg cmt, FS & 15' new hole. Conduct formation tst to 14.7 ppg EMW. Drl 8½" hole to 12,845', 5 std short trip, CBU, POOH. 9-5/8" @ 12,682' 12,845', (0'), Rn'g 7" inr Wt. 9.8, PV 21, YP 10, PH 10.0, WL 5.0, Sol 11 RU DA, rn DIL/BHC/GR/SP f/12,834'-12,680', FDC/CNL/GR/CAL f/12,767'-12,680', cont w/GR to 13-3/8" shoe, RD DA. TIH, C&C, POOH. RU & rn 11 ]ts, 7", 29#, L-80 BTC lnr. The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Date ]Title 4/14/86 Drilling Superintendent RECEIVED 8 1986 Alaska 0il & Gas Cons. Commission anch0mge AtlanticRichfieldCompany Daily Well History-Final Report Instructiona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Prudhoe Bay Field County or Parish North Slope Borough ADL #28323 Auth. or W.O. no, AFE AS0138 State Alaska Well no. 4-33 Lease or Unit Title Drill Operator Rowan 33 ARCO Alaska, Inc. Spudded or W.O. begun Spudded 3/15/86 thru 3/17/86 Date and depth as of 8:00 a.m. 3/18/86 AP1 50-029-21545 A.R.Co. W.I. rrotal number of wells (active or inactive) on this~ Icost center prior to plugging and I 21.66% labandonment of this well Date IHour I Prlor status if a W.O. 2/14/86 ! 0430 Hrs. Complete record for each day reported 7" f/12,843'-12,345' 12,845' TD, 12,793' PBTD, (0'), LD DP 9.4 ppg brine w/C-193 corrosion inhibitor Rn 11 its, 7", 29#, L-80 BTC lnr w/TOL @ 12,345', LC @ 12,708', FC @ 12,793', FS @ 12,843'. Cmt w/300 sx C1 "G" w/5% KC1, .5% D-31, 1.2% D-19, .04% R-5 & .2% D-6. Displ'd w/mud, bump plug. TIH w/8½" bit/9-5/8" csg scrpr, drl cmt f/11,712' to TOL, circ, POOH. TIH w/6" bit, drl 10' plug @ TOL. TIH, tag cmt @ 12,543', drl cmt to 12,793' PBTD. Circ, tst lnr lap to 3000 psi. Displ w/9.4 ppg brine, re-tst lnr lap to 3000 psi, POOH, LD DP. TIH to 400', displ w/diesel. PU BP, TIH & set @ 456', POOH, LD DP & rn'g tl. 12,845', 43°, N47.3E, 8777 TVD, 8740.82 VS, 6131.15N, 6233.14E 7" f/12,843'-12,345' 12,845' TD, 12,793' PBTD, (0'), Inject diesel 9.4 ppg brine w/C-193 corrosion inhibitor ND BOPE, repair 9-5/8" x 13-3/8" packoff. NU tbg spool, adapter, tbg hgr & master vlv; tst to 5000 psi. Inject 120 bbls diesel f/freeze protection. RR @ 1200 hfs, 3/18/86. Stack rig. RECEIVED' MAY- 8 1985 o~t ~.,,Gas~.. ,. ,~= _ Cons, (J~nmls~on Old TD New TD 12,845' 12,793' Released rig Date 1200 Hrs. Classifications (o11, gas, etc.) Oil Producing method Flowing Potential test data PB Depth IK nd of rg 3/18/86 Rotary Type completion (single, dual, etc,) Single I Official reservoir name(s) [ Sadlerochit Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected .., The above is correct Signature __ For form preparation and distribt~ion, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate ITItle 4/14/86 Drilling Superintendent REFERENCE ' ,..,:,,_. 0 Ma g':.-"~e t i c. w," I is!' ]]rma Car Li'n A'¥O-i 429F' · ,. u.~.-.:'~ ~. i-a I. F i l.e:=: Ch err on c~. hi ~ ::.:: ~: e i',' ~: i o ','] E x p L c: '? a t: i c,. n Ex xon H~'ra ~.hon .... ~" STATE OF ALASKA ..... ~ ALASKA t,,~ AND GAS CONSERVATION CU,v, MISSION ~/~ ..ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ': 1. Drilling well ]~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-35 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21545 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Well atsurface 677' FSL, 303' FWL, Sec.26, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 62' RKB ADL 28323 ALK 2321 10. Well No. 4-33 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. March , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0430 hrs, 2/14/86. Drld 17-1/2" hole to 1999'. Set plug w/1545 sx CS II & 865 sx CS III to 1369'. Cont'd drlg 17-1/2" hole to 1722'. Attempted to kickoff; cmt not firm. Set 2nd plug w/2600 sx AS II to 1186'. Cont'd drlg 17-1/2" hole to 2750'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 8173'. Pipe stuck. Jarred & fished for stuck pipe; recovered. Cont'd drlg 12-1/4" hole to 12,692'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 12,845'TD (3/12/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 12,793'. Secured well & RR ~ 1200 hrs, 3/18/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#, H-40, weld conductor set (~ 120'. Installed w/1775# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe 2747'. Cmtd w/3500 sx CS III & 400 sx CS I1. Top job performed w/200 sx CS I1o 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe @ 12,682'. Cmtd w/500 sx Class G. 7", 29.0#/ft, L-80, BTC csg f/12,345' - 12,843'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHC/GR/SP f/12,834' - 12,680' FDC/CNL/GR/Cal f/12,767' - 12,680'; GR to 2747' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ (~ ~~A_/' Associate Engineer 4'Z-~O SIGNED . _ TITLE __ ____ DATE NOTE--Report or,r,r~this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conser'vation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM2/MR10 Submit in duplicate STATE OF ALASKA ..... ALASKA ,~ .,.- AND GAS CONSERVATION C~ MISSION .-ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~X~ Workover operation [~] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-35 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21545 4. Location of Well at surface 677' FSL, 303' FWL, Sec.26, T11N, R15E, UM 5. Elevationinfeet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 62' RKB ADL 28323 ALK 2321 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 4-33 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of Ma rch , 19 86... 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0430 hfs, 2/14/86. Drld 17-1/2" hole to 1999'. Set plug w/1545 sx CS II & 865 sx CS III to 1369'. Cont'd drlg 17-1/2" hole to 1722'. Attempted to kickoff; cmt not firm. Set 2nd plug w/2600 sx AS II to 1186'. Cont'd drlg 17-1/2" hole to 2750'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 8173' Pipe stuck. Jarred & fished for stuck pipe; recovered. Cont'd drlg 12-1/4" hole to 12,692', Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 12,845'TD (3/12/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 12,793'. Secured well & RR @ 1200 hrs, 3/18/86. 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91 .5#, H-40, weld conductor set @ 120'. Installed w/1775# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe 2747'. Cmtd w/3500 sx CS III & 400 sx CS II. Top job performed w/200 sx CS II. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe ~ 12,682'. Cmtd w/500 sx Class G. 7", 29.0#/ft, L-80, BTC csg f/12,345' - 12,843'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHC/GR/SP f/12,834' - 12,680' FDC/CNL/GR/Cal f/12,767' - 12,680'; GR to 2747' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report o his form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conse~vation Commission by the 15th of the succeeding month unless otherwise directed. Form 10-404 DAM2/MRIO Submit in duplicate ARCO Alaska P~O. Box Anchorage, ALaska DATE' March 27, t986 REFERENCE' ARCO Open HoLe Finals DS 4-28 2-2-86 BHC$ Run t ~~ Go DS 4-28 2-2-86 CNL (PorositY) Run t 2.'&~,_'x Go DS 4-28 2-2-86 CNL (Raw) Run t 2'&5' Go D~ 4-28 2-2-86 DIL Run ~ 2'&5' Go Run ~ ~'~" DA D~ 4-SS S-~-86 BHC ACou~t~ tog Run ~ ~'~" DA D~ 4-SS S-~S-86 CDL Run ~ ~"~' DA D~ 4-SS S-~$-86 CDL/CNL Run ~ ~~' DA D~ 4-33 3-~3-86 DIFL Run ~~,~ DA D~ 4-33 3-t3-86 Gamma Ray ~-~-86 BHC Acou~i ~oq Run ~ ~&~ DA Dg ~6-24 ~ ~* Run ~ ~&5~ DA D~ 46-24 2-22-86 ~D~ Ron ~ ~&5~ DA DS ~6-24 ~-z=-86 CDL/CNL D~ t6-24 ~ ~- Run DS i6-24 2-22-86 ~ Gamma Ray F'[ease sign and return the attached copy as receipt of data. Received By. HAVE A NICE DAY! Irma CarLin ATO-1429F TRAN$ $862t2 DISTRIBUTION Phi llips F'B Well Fi les - R& D -$ $oh i o ~ ~ =.State.of ALaska ._ -"- Texaco "' ' 1' FebrUary 4, 1986 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re- Prudhoe Bay Unit DS 4-33 ARCO Alaska, Inc ~ Permit No. 86-35 Sur. Loc. 677'FSL, 303'~.~L, Sec. 26, TllN, R15E, UM. Btmhole Loc. 2070'FSL, 1700'FWL, Sec. 24, TllN, R15E, Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~trul¥~Y~urs~. ~ c. v. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF nE CO~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Box 100360 Anchorage: Alaska 995"10-0360 Telephone 907 276 12'!5 January 23, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 4-33, Permit to Drill Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill DS 4-33, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore ° Proximity plots o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on February 11, 1986, your earliest approval will be appreciated. If you have any questions, please call Gregg Walz at 263-4541. Sincerely, T. P. Oostermeyer Regional Drilling Engineer TPO/GSW/tw PD/L215 Enclosures RECEIVED ....... ~ch0r39~ ARCO Alaska, Inc, is a Subsidiary of A~lanticRichfieldCompany la. Type of work. ~ STATE OF ALASKA E C E IV E D ALASKA O,- AND GAS CONSERVATION CO~, dlSSlO~N PERMIT TO DRILL ,jAr, u 20 AAC 25.005 DRILL ~ lb. Type of well EXPLORATORY ~ ~E~VIC~ S~RA~~IC ~ ~n~h0r~o REDRILL ~ DEVELOPMENTOIL~ SINGLEZONE~' DEEPEN ~ DEVELOPMENT GAS ~ MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 677' FSL, 303' FWL, Sec.26, T11N, R15E, UN At top of proposed producing interval 1320' FSL, 1320' FWL, Sec.24, T11N, R15E, UM At total depth 2070' FSL, 1700' FWL, Sec.24, T11N, R15E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 62', PAD 22' GL I ADL 28323 ALK 2321 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 6 mi. NE of Deadhorse miles 1320' ~ Target feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 1 2768 'MD, 8775 ' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures HOLEANGLJS0-1/2° (see 20AAC25.035 (c) (2) KICK OFF POINT 500 feet. MAXIMUM 21 9. Unit or lease name Prudhoe Bay Unit 10. Well number 4-33 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool Amount $500 15. Distance to nearest drilling or completed 4-16 well 47 ' ~ 907 ' feet 18. Approximate spud date 02/11/86 2941 psig@___80°F . Surface 3950 psig@ 8776 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing JUi~ 17-1/2" 13-3/8" 12-1/4" 9-5/8" ]-1/2" 7" 22. Describe proposed Weight 91.5# 68.0# CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD Grade H-40 72.0# 47.0# 29.0# K-55 L-80 program: L-80 L-80 Coupling Welc BTC BTC BTC BTC Length 80' 40' 41 ' 39 ' I 2805 ' 80 ' 12537 ' 494' I 40' I 39' ~ 80' 37' I 37' t 12274' I 8462' MD BOTTOM TVD 120'1 120' 80 ' 80 ' 2885 ' I 2500 ' 12574 ' I 12768'l 1 8652' (include stage data) 2000# Poleset 2500 sx CS III & 400 sx Class G 500 sx Class G 8775' 200 sx Class G ARCO Alaska, Inc., proposes to drill this Sadlerochit oil production well to 12,768'MD (8775'TVD). Logs will be run across selected intervals. A string of 5-1/2", 17.0#, L-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A separate Sundry Notice will be submitted when the well is to be perforated. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 13-3/8" surface pipe. It will be tested to 5000 psi (3000 psi for annular) upon installation and weekly thereafter. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic pack upon completion of the fluid disposal process. The following wells are within 200': DS 4-16 47' ~ 907'MD; DS 4-17 102' ~ 1038'MD; DS 4-18 155' @ 1166'MD; Pingut State #1 130' ~ 12,470'MD. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TP ~ion~ TITLE Regional Dril 1 i ng Engineer The space below for Commiss DATE /.-_,~ - ~fi. CONDITIONS OF APPROVAL Samples required []YES ~NO Permit number APPROVED BY Form 10-401 Rev. 7-1-80 (GSW r- PD7PD21. Mud log required I-lYES [~LO Approval date 02/04/85 Directional Survey required I APl number ¢~.Y__E S [] N O I 50- 0 'Z.~i- L! SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE February 4, 1986 by order of the Commission Submit in triplicate D84-33 ]ooo 20oo 3000 4000 ~-~ 5000 o~ 80o0 7o0o 8000 9000 lO000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 gU- GA~IN[ I VD : (OIP TYD = 500 17_5 --- 1000 22.~ 2-/.5 ARCED AL/ ,SKA, INC. 37.5 ~CALE 1JN = 1~ F3._ ~000 42.5 ~-1~7.5 3O3' F~L, ~ E(~C TVD = 2271 MD =: 523 DEP = 837 SHL: 677' ~SL~ "~ ' 13-3/8' C,~S~NG TVD = 2500 MI~ = 2885 CEP = 1116S~C.26, T11N, F 15E, UM(APFROX) THL:1320'I:SL, 1320' F~'L, RE~4~ F11N, RI~E~ · 3000 5000 N46 DEG4I MINE 8645 FT(TO TARGET) AVERAGE A~ GLE [0 DEG35 ~IN 6000 K-10 TVD = 7612 MD: 10[136 DEP: 7336 K-R TV~ ~8~19 ~[): 11RRR F,FP ~7R99 8000 [~-5/8' CASING TVD = ~652 MD = 12574 DEP = 8601 TOF SADLERO{;HIT TVD = 8662 MD = 12589 DEP = 8613 TAR()ET TVD = 8888 ~D · 12830 D~P = 8845 9000 BA~ E SADLERC~CHIT TVD = 8712 MD = 12668 D~[P = 8674 TD TVD = 8775 MD = 12768 D~P = 8750 [~0o0 ,I , , , · , , , ........ , ..... , ] , , , , , , , , , , , , , , ~ , , , , , ................. , ................... , , ' , , , [ 000 2000 ~000 ~000 5000 6000 7000 8000 9000 ~ 0000 E ~ N COOROINFtl~F.S o - 1000 0 1000 2000 3000 4000 5000 8000 7000 8000 BO00 i .c:~. fl77' F.c ana' ~:w~ J E EC.26, TllN, ~lBE, UM(AP ~ROX) I THL:1320'F$ L, 1320' FWL i OS~:-' i~EC.24, Tll ~1, ELSE, OM I ~.1'"i~1~ I TVD -- 8! 88' DEP -, 8e ~.B' N. 5t~23 E 6297 o i 0 0 I - 1000 0 1000 2000 3000 4000 5000 8000 7000 8000 9000 E - N COOROtNATES o -1000 P. - N COOROINATF.$ 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 o z o OS4-1 - 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 E - N COOROINRTES Ancho,~afle E - N COORDINFITES - 100 '~'- 1 O0 200 300 400 500 600 0 [-~ CE: Z I I -200 . , - BiS )S~-i375 ~~8261 ~693 2 /3377 ~1814 X127 I 3189 _~~792 ~?~ ~-, 372 _~.. ~ ~~~ ~ 7559 ]S ~-26 7~15 /70~ 9{~5 ', , , ~ , ~ , , i i ~ , ~ , i ~ ~ , ~ ~ , t ~ ~ ~ ~ , ~213 -200 - 1 O0 0 1 O0 200 300 400 500 600 E - N O00RDINRTES E - N COORDINBTES o 5800 5900 6000 6100 6200 8300 6400 6500 6600 I i ~ i i i i i i i I i i i i I i i I i I i i I i i i i I i t I I I I I I I I I I , , i , i ~ i i i i ! i ~i i i i , i t i , , , i t i i i i ~ , ,l,~ ~ ~ i , , , ~ ~ , s , , , i ,i , ~ i , ~ ~ ~ , , , i ~ a ~ , i ~ , i , , i , , i i ~ ~ , , ~ s ~ ~ ,[ ~ , ~ ~ , , , , , , r i , , i , , 0 [.u.1® I 5800 5900 6000 61 O0 6200 6300 8400 8500 6600 £ - W OOOROINBTF. S SURFACE HOLE D IVERTER SYSTEM SCHE~TIC ARCO ALASKA INC. NOTE: Valveg on diverter line~ open automati- cally when the annular preventer is closed. I0' ~ lC ,, D£ TA lq-" SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC. I I .... -~~ Ii ~)TE: Valve, on diverter I II lin~open .utonati preventer is closed ~e~ ~ ~ ~ ~~, of 3ms. Bl~~~z~. ~. ~ ~~ ~ S~ ~i ~ld ~ ~, ~~~~o~ ~~~of~le. ~oM ~X~~~o~ ~. ~b~~. ?e~ ~i~ v~ves to fO00 Te~ ~11~ ~ ~ ~i~ ~ to fO~ psi ~ ~ ~i~ of ~~r. ~. Si~ ~ s~ to ~11~ ~r. 9 · I0 · 9 · 8 · 7 · 6 o 5 · 4 zo · Z! · P TH Grid North is I-5°58'East Cond ASP ZONE 4 COORDINATES WITHIN SECTION 26 19 Y= 5 952 791.73 I.AT= 71D°16~264359'' 2.54 913 X = 713 05Z60 LONG = 148o16'35.2442" 53 ¥ = 5 952. 558.46 LAT = 70° 16'24.12.66" 304 6'78 X = 715 !14.53 LONG =14c3°16'53,7795'' Z5 Y = 5 . 957. 092.0Z I_AT = 70016, 19. 5094" 404 208 X = 713 227.65 LONG=I48°I6~30.8718' 2.5 Y = 5 951 975.43 LAT = 70°16' 18.5552" 429 91 X = 713 ~2,5. S9 LONG = 148° 16' 30.1433" WITHIN SECTION 35 WLO NLO 27 Y=5 951 858.74 X = 713 284.2.5 28 Y = 5 951 742.10 X = 7/3 312.58 LAT = 70°16'17. ZOO1" 453 26 LDN'G = 148°16'29 4172 LAT = 70°16'16.0455" 478 144 LOb:G= 148°1~' 28.68~9' CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORREGT,..., r r_ .EIVED xo/.hs DA~'E ~' SURVEYOR Alaska Oil & Gas Cons. Anchorac~ Ill' I I II Il ~q i i i ~ii i i LEGEND WLO- WEST LINE OFFSET SLO -SOUTH LINE OFFSET NORTH LINE OFF~ET ...... CONDUCTORS AS-BUILT THIS SURVEY. i iii i ARCO NO. 1 ARCO Alaska , Inc. AS- BUILT DRILL SITE 4. CONDUCTORS LOCATED IN PROTRACTED SECTIONS Z6 & 35, TilN~RISE U.M. PREPARED BY LOUNSBURY 8~ ASSOCIATES, INC. 725W 6th AVE., ANCHORAGE,ALASKA ,DATE_: 10/29/85 [SCALE: I": 400' CHKD. BY: GEL JFLD. BK.: LHD 85-10t iii iii i ~ ~L ~FOR~'NEW"WELL PERMITS~ /" COmpanyI [~Y~.~ ...' :~' ' ; : Lease & Wel_ No. F'3 ~ ITEM APPROVE DATE YES NO REMARKS Is the permit fee tached ' Is ~ell to be located in a defined pool ................. ... Is well located proper distance from other wells ........ Is sufficient undedicated acreage available in this poo Is ~ell to be devlated and is ~ellbore plat included... ... .~__~ Is operator the only affected party .................... · Can permit be approved before ten-day wait .... ' ........ · Does operator have a bond in force .................................. Is a conservation order needed ...................................... I administrative approval needed · S eeeeeeeeeeeeeeeeeeeee.eeeeeeeeeeeee ease' Is the 1 number appropriate .................................... Is conductor string provided ........................................ Is'enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ............... Will surface casing pr°tect fresh water z°nes ''i i~ i~d'ii Will all casing give adequate safety in collapse t sion rstl Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ . 5. 6. 7. 8. (3) Admin'(~ ~"~ ~"¥~ 9. (( 91~O~_/~lat h r u 1/~/)o~/~,g 10. 11. nd ~2) ~ 12. (4) Casg~,~..~ ~-~/-8~ (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached, ~ ..... ~ Does BOPE have sufficient pressure rating - Test to ~-~ psig . Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: 7M~v~,; uJ ~;~ 97/ & 9 ~/~ ~o ~ ~07 , o ~Z H o mm Geology: Engin. eDrSng: JAL rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. .o * ALASKA COMPUTING CENTER * . . ****************************** . ............................ . . ....... SCHLUMBERGER ....... . . ............................ . ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 4-33 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292154500 REFERENCE NO : 98043 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/01/28 ORIGIN : FLIC REEL NAME : 98043 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-33, API# 50-029-21545-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/28 ORIGIN : FLIC TAPE NAME : 98043 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-33, API# 50-029-21545-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4-33 API NUMBER: 500292154500 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 28-JAN-98 JOB NUMBER: 98043 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: G SARBER SURFACE LOCATION SECTION: 26 TOWNSHIP: lin RANGE: 15E FNL: FSL: 667 FEL: FWL: 303 ELEVATION(FT FROM MSL O) KELLY BUSHING: 62.00 DERRICK FLOOR: 61.00 GROUND LEVEL: 21. O0 WELL CASING RECOR~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) .............................................. 7.675 12332.0 29.70 7.000 12843.0 29.00 5.500 8209.0 17.00 4.500 12311.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(f4EASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 12-MAR-86 LOGGING COMPANY: DRESSER ATLAS BASELINE DEPTH .............. 88888.0 12733.5 12728.0 12725.5 12717.5 12702.0 12698.0 12697.5 12692.5 12692.0 12690.0 12689.5 12679.0 12676.0 12672.5 12672.0 12665.5 12659.5 12659.0 12652.0 12649.5 12646.0 12644.5 12643.0 12642.5 12638.5 12637.5 12634 5 12634 0 12631 5 12630 5 12628 5 12624 0 12623 5 12619.5 12619.0 12617.0 12616.0 12611.5 12604.0 12603.5 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88890.0 88889.5 12735.0 12730.0 12730.0 12727.0 12719.0 12703.5 12703.5 12699.0 12699.0 12693.5 12691.0 12677.0 12673.5 12665.0 12693.0 12691.0 12680.0 12677.0 12673.5 12665.0 12657.5 12657.5 12650.5 12650.5 12647.5 12647.0 12645.5 12645.5 12642.5 12639.5 12638.0 12636.0 1263 O. 5 12628.0 12625.0 12622.0 12617.5 12613.5 12602.5 99.0 12639.5 12638.0 12636.0 12630.5 12628.0 12625.0 12622.0 12617.5 12614.0 12602.5 98.5 REM. ARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 DATA AQUIRED ON ARCO ALASKA'S DS 4-33 WELL. T~E DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BASE GAI~W~A RAY, ALSO NPHI PASS #1 AND THE BASE GAMFIA RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~FL~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12737.0 12599.0 CNTG 12747.5 12598.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. THERE ARE NO PASS TO 'PASS CORRELATIONS APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1173646 O0 000 O0 0 1 1 1 4 68 NPHI CNTG PU-S 1173646 O0 000 O0 0 1 1 1 4 68 ENPH CNTG PU-S 1173646 O0 000 O0 0 1 1 1 4 68 CPHI CNTG PU-S 1173646 O0 000 O0 0 1 1 1 4 68 NRAT CNTG 1173646 O0 000 O0 0 1 1 1 4 68 CRAT CNTG 1173646 O0 000 O0 0 1 1 1 4 68 ENRA CNTG 1173646 O0 000 O0 0 1 t 1 4 68 NCNT CNTG CPS 1173646 O0 000 O0 0 1 1 1 4 68 FCNT CNTG CPS 1173646 O0 000 O0 0 1 1 1 4 68 CNTC CNTG CPS 1173646 O0 000 O0 0 1 1 1 4 68 CFTC CNTG CPS 1173646 O0 000 O0 0 1 1 1 4 68 CNEC CNTG CPS 1173646 O0 000 O0 0 1 1 1 4 68 CFEC CNTG CPS 1173646 O0 000 O0 0 1 1 1 4 68 GRCH CNTG GAPI 1173646 O0 000 O0 0 1 1 1 4 68 TENS CNTG LB 1173646 O0 000 O0 0 1 1 1 4 68 GR BCS GAPI 1173646 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12760.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS -999.250 -999.250 -999.250 110.824 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: DEPT. 12500.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. CNTG -999. 250 CRAT. CNTG -999. 250 ENRA. CNTG -999. 250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 GR.BCS -999.250 -999.250 -999.250 185.014 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS~BER: 2 DEPTH INCREMENT: 0.5000 FILE SU~4~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12740.5 12600.0 CNTG 12750.0 12601 . 5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG .............. LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 88888.0 12744.0 12742.5 12740.5 12738.0 12734.0 12731.5 12728.5 12727.5 12724.5 12721.0 12716.5 12715.0 12710.5 12707 5 12706 5 12704 5 12703 0 12700 5 12697 0 12696.5 12694.5 12689.0 12687.5 12684.5 12683.5 12678.5 12678.0 12673.5 12673.0 12670.5 12668.5 12666.0 12665.0 12663 5 12659 0 12658 5 12656 0 12655 0 12653 5 12652.0 12650.5 12648.5 12646.5 12644.0 12641.5 12639.0 12637.5 12635.5 12635.0 12632.0 12629.5 12629.0 12626.5 12625.0 88892.5 12736.0 12732.0 12728.0 12725.0 12718.0 12713.5 12710. 5 12703.5 12701.0 12699.0 12691.0 12685.5 12679.0 12673.5 12665.0 12658.0 12656.0 12653.0 12650.5 12645.5 12642.5 12639.5 12636.0 12632.5 88891.0 12747.0 12743.5 12741.5 12740.0 12735.0 12730.0 12727.0 12719.0 12710.5 12708.0 12706.0 12702.5 12699.0 12695.5 12689.5 12685.5 12680.0 12675.0 12673.5 12669.5 12667.0 12663.5 12661.0 12657.5 12655.0 12653.5 12650.5 12646.0 12639.5 12638.0 12636.0 12630.5 12628.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 12623.0 12625.5 12620.5 12626.5 12617.5 12622.0 12615.0 12617.5 12612.5 12617.5 12614.0 12611.5 12611.0 12609.5 12609.0 12608.0 12607.0 12607.0 12607.5 12605.5 12605.5 12603.0 12602.5 12601 . 0 12601.0 12602.5 100.0 100.0 101.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 60 66 1 0.5 FT 17 0 FT 68 1 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) DEPT FT 1173646 O0 000 O0 0 2 1 1 4 68 NPHI CNTG PU-S 1173646 O0 000 O0 0 2 1 1 4 68 ENPH CNTG PU-S 1173646 O0 000 O0 0 2 1 1 4 68 CPHI CNTG PU-S 1173646 O0 000 O0 0 2 1 1 4 68 NRAT CNTG 1173646 O0 000 O0 0 2 1 1 4 68 CRAT CNTG 1173646 O0 000 O0 0 2 i 1 4 68 ENRA CNTG 1173646 O0 000 O0 0 2 1 1 4 68 NCNT CNTG CPS 1173646 O0 000 O0 0 2 1 1 4 68 FCNT CNTG CPS 1173646 O0 000 O0 0 2 1 1 4 68 CNTC CNTG CPS 1173646 O0 000 O0 0 2 1 1 4 68 CFTC CNTG CPS 1173646 O0 000 O0 0 2 1 1 4 68 CNEC CNTG CPS 1173646 O0 000 O0 0 2 1 1 4 68 CFEC CNTG CPS 1173646 O0 000 O0 0 2 1 1 4 68 GRCH CNTG GAPI 1173646 O0 000 O0 0 2 1 1 4 68 TENS CNTG LB 1173646 O0 000 O0 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12750.000 NPHI.CNTG 36.160 ENPH. CNTG 34.464 CPHI.CNTG NRAT. CNTG 3.909 CRAT. CNTG 3.386 ENRA.CNTG 5.106 NCNT. CNTG FCNT. CNTG 495.211 CNTC. CNTG 1445.187 CFTC. CNTG 445.290 CNEC. CNTG CFEC. CNTG 491.732 GRCH. CNTG -999.250 TENS. CNTG 1705.000 DEPT. 12600.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 108.500 TENS. CNTG -999.250 34.127 1670.244 2510.699 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE · 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001 CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUF~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12738.0 12602.0 CNTG 12749.5 12598.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12741.5 12738.5 12728.0 12727.5 12726.5 32726.0 12724.0 12720.5 12718.0 12716.5 12711.0 12707.0 12702.0 12700.5 12697.0 12695.0 12692.5 12690.0 12688.0 12686.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88890.0 88890.5 12744.0 12740.0 12730.0 12730.0 12728.0 12727.0 12725.0 12722.5 12722.5 12719.5 12718.0 12714.0 12714.0 12710.5 12710.5 12703.5 12703.5 12701.0 12701.0 12699.0 12699.0 12697.0 12697.0 12693.0 12693 . 0 12689.0 12689.0 12688.0 12688.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 10 12684 . 0 12685.5 12685 . 5 12680.5 12680.0 12680.0 12680.0 12677.5 12679.0 12677.0 12679.0 12676.0 12677.0 12677.0 12671.0 12672.5 12673.5 12668.0 12669.5 12664.5 12665.5 12662.5 12663.5 12659.0 12657.5 12655.5 12655.0 12649.5 12650.5 12648.5 12647.5 12652.0 12645.5 12650.5 12644.0 12645.5 12641.5 12646.0 12641.0 12642.5 12639.0 12639.5 12638.0 12639.5 12636.0 12638.0 12635.0 12638.0 12633.0 12636.0 12632.0 12636.0 12629.0 12630.5 12628.5 12632.5 12627.0 12627.0 12625.0 12628.0 12624.0 12622.5 12623.5 12626.5 12618.0 12615.0 12617.5 12620.0 12614 . 5 12617.5 12613.5 12615.0 12612.0 12613 . 5 12611 . 0 12609.0 12609. 0 12611 . 5 12607. 0 12606. 0 12607.5 12603.5 12601.5 12603. 0 12606. 0 12600.5 12602.5 100. 0 102. 0 98. 0 $ REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 1i ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1173646 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12749.500 NPHI.CNTG 41.016 ENPH. CNTG 39.550 CPHI. CNTG NRAT. CNTG 4.229 CRAT. CNTG 3.653 ENRA.CNTG 5.578 NCNT. CNTG FCNT. CNTG 469.563 CNTC. CNTG 1432.672 CFTC. CNTG 445.195 CNEC. CNTG CFEC. CNTG 449.259 GRCH. CNTG -999.250 TENS. CNTG 1670.000 33.695 1540.455 2506.032 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 12 DEPT. 12598. 000 NPHI. CNTG 60. 448 ENPH. CNTG 48.616 CPHI. CNTG NRAT. CNTG 4.209 CRAT. CNTG 4.719 ENRA. CNTG 6.340 NCNT. CNTG FCNT. CNTG 288. 323 CNTC. CNTG 1364. 715 CFTC. CNTG 301 . 464 CNEC. CNTG CFEC. CNTG 406. 490 GRCH. CNTG -999.250 TENS. CNTG 1670. 000 59. 628 1456. 517 2576. 991 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUM~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12740.0 12570.5 CNTG 12749.5 12569.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 13 88888.0 12741.0 12739.5 12737.5 12730.5 12727.0 12721.0 12718.0 12709.5 12707.0 12705.0 12703.5 12700.5 12700.0 12699.0 12694.0 12693.5 12691.0 12686.0 12683.5 12683.0 12680.0 12679.0 12674.0 12673.0 12672.5 12670.0 12668.5 12668.0 12665.5 12661.5 12659.5 12658.0 12657.0 12655.0 12651.5 12647.0 12646.5 12640.5 12639.5 12636.0 12635. 0 12628.5 12625. 0 12624. 0 12620. 0 12619. 0 12616.5 12611.5 12608. 0 12607.5 12603.5 12602.0 100. 0 $ 88893.0 12735.5 12730.0 12724.5 12720.5 12714.0 12704.0 12701.0 12697.0 12692.0 12689.0 12685.5 12679.0 12675.0 12673.5 12669.5 12667.0 12664.0 12657.5 12656.0 12650.5 12645.5 12642.5 12640.0 12638.0 1263 O. 5 12626.5 12617.5 12613.5 12611.0 12606.5 12602.5 100.5 88891.5 12744.5 12742.0 12740.5 12735.5 12730.0 12724.5 12720.5 12710.5 12708.0 12706.0 12702.5 12695.5 12692.0 12689.0 12685.5 12680.0 12675.0 12673.5 12669.5 12667.0 12655.0 12650.5 12646.0 12642.5 12638.5 12636.5 12630.5 12626.5 12617.5 12615.0 12611.0 12607.0 12602.5 99.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 14 RE~RKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #4 AND GRCH PASS #1, ALSO NPHI PASS #4 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU-S 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU-S 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNTG PU-S 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNTG 1173646 O0 000 O0 0 4 1 1 4- 68 0000000000 CRAT CNTG 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNTG 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNTG CPS 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNTG CPS 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTG CPS 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNTG CPS 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNTG CPS 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TENS CNTG LB 1173646 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12749.500 NPHI. CNTG 31.585 ENPH. CNTG 37.823 CPHI. CNTG NRAT. CNTG 3.424 CRAT. CNTG 3.135 ENRA. CNTG 5.422 NCNT. CNTG FCNT. CNTG 458.578 CNTC. CNTG 1428.969 CFTC. CNTG 428.685 CNEC. CNTG CFEC. CNTG 442.969 GRCH. CNTG -999.250 TENS. CNTG 1715.000 DEPT. 12569.000 NPHI.CNTG 82.618 ENPH. CNTG 52.729 CPHI. CNTG NRAT. CNTG 6.000 CRAT. CNTG 5.935 ENRA. CNTG 6.655 NCNT. CNTG FCNT. CNTG 238.349 CNTC. CNTG 1467.870 CFTC. CNTG 244.706 CNEC. CNTG CFEC. CNTG 435.527 GRCH. CNTG -999.250 TENS. CNTG 1675.000 35.521 1553.051 2401.620 171. 173 1612.187 2898. 595 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 16 CNTG REM_ARKS: 1, 2, 3, 4, THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, 3 &4. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 56 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNAV PU-S 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 NRAT CNAV 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 CPHI CNAV PU-S 1173646 O0 000 O0 0 5 1 1 4 68 · 0000000000 CRAT CNAV 1173646 O0 000 O0 0 $ 1 1 4 68 0000000000 ENPH CNAV PU-S 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA CNAV 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 NCNTCNAV CPS 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 FCNTCNAV CPS 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNAV CPS 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNAV CPS 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC CNAV CPS 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNAV CPS 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG 2'TPE CI..~SS MODNUMB SAMP ELEbl CODE (HEX) GRCH CNTG GAPI 1173646 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12749.500 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CPHI. CNAV CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV -999.250 NCNT. CNAV FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV CFEC. CNAV -999.250 GRCH. CNTG -999.250 -999.250 -999.250 -999.250 DEPT. 12598.000 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA. CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUBtLetY LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 18 CNTG $ LOG HEADER DATA VENDOR TOOL CODE START DEPTH ........................... 12769.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~A RAY CNTG COMPENSATED NUETRON $ STOP DEPTH .......... 12598.0 02-NOV-97 CP 44.2 1027 02-NOV-97 12776.0 12754.0 12600.0 12749.0 1800.0 TOOL NUMBER SGC- SA- 664 CN C- GA - 63 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 12843.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPI THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZOIFE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (.CPS): 5500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 19 TOOL STANDOFF (IN): REMARKS: TIED IN TO DA CBL DATED 4/11/86. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC AND TO DETECT GAS UNDERRUNS. TOTALS PUMPED: 560 CRUDE(6 BPM INITIAL RATE, 3 BPM WHILE LOGGING PASSES HAD SOME SPIKING. PASS #2 NOT PRESENTED. PASS #4 & #5 LOGGED AT 900 FPH. OVERLAY AND AVERAGE ARE ONLY OF PASSES 3,4, &5. GOC NOT OBSERVED AND NO OBVIOUS GAS UNDERRUNS. THIS FILE CONATINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS1 PU 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS1 PU 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS1 PU 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS1 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS1 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS1 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 20 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CNEC PS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS1 CPS 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS1 PU 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1173646 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12771.000 NPHI.PSi 33.552 ENPH. PS1 30.885 TNPH. PS1 32.801 TNRA.PS1 3.243 RTNR.PS1 3.340 ENRA.PS1 4.752 CFEC.PS1 579.966 CNEC. PS1 2755.743 RCEF. PS1 580.947 RCEN. PS1 2458.316 RCNT. PS1 1651.714 RCFT. PS1 488.157 CNTC. PS1 1519.117 CFTC. PSi 480.573 NPOR.PS1 32.801 GR.PS1 75.625 TENS. PSI 1030.000 DEPT. 12600.000 NPHI.PS1 66.522 ENPH. PS1 49.871 TNPH. PS1 47.422 TNRA.PS1 5.052 RTNR.PS1 4.435 ENRA.PS1 6.438 CFEC. PS1 388.730 CNEC. PS1 2502.566 RCEF. PS1 387.198 RCEN. PS1 2180.574 RCNT. PS1 1395.642 RCFT. PS1 281.219 CNTC. PS1 1346.612 CFTC. PSi 332.312 NPOR.PS1 49.967 GR.PS1 185.000 TENS. PSI 1735.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE . 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 21 FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SO?4FiARY VENDOR TOOL CODE START DEPTH CNTG 12770.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 12595.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 02-NOV-97 CP 44.2 1027 02-NOV-97 12776.0 12754.0 12600.0 12749.0 1800.0 TOOL NUMBER SGC- SA- 664 CNC- GA- 63 12843.0 CRUDE 10.0 E P I THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 22 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REFiARKS: TIED IN TO DA CBL DATED 4/11/86. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC AND TO DETECT GAS UNDERRUNS. TOTALS PUMPED: 560 CRUDE(6 BPM INITIAL RATE, 3 BPM WHILE LOGGING PASSES HAD SOME SPIKING. PASS #2 NOT PRESENTED. PASS #4 & #5 LOGGED AT 900 FPH. OVERLAY AND AVERAGE ARE ONLY OF PASSES 3, 4, &5. GOC NOT OBSERVED AND NO OBVIOUS GAS UNDERRUNS. THIS FILE CONATINS THE RAW DATA FOR PASS #2. (PASS #3 ON THE FIELD PRINT) $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 23 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173646 O0 NPHI PS2 PU 1173646 O0 ENPH PS2 PU 1173646 O0 TNPH PS2 PU 1173646 O0 TNRA PS2 1173646 O0 RTNR PS2 1173646 O0 ENRA PS2 1173646 O0 CFEC PS2 CPS 1173646 O0 CNEC PS2 CPS 1173646 O0 RCEF PS2 CPS 1173646 O0 RCENPS2 CPS 1173646 O0 RCNT PS2 CPS 1173646 O0 RCFT PS2 CPS 1173646 O0 CNTC PS2 CPS 1173646 O0 CFTC PS2 CPS 1173646 O0 NPOR PS2 PU 1173646 O0 GR PS2 GAPI 1173646 O0 TENS PS2 LB 1173646 O0 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 i 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12770.500 NPHI.PS2 27.212 ENPH. PS2 36.584 TNPH. PS2 TNRA.PS2 2.895 RTNR.PS2 2.981 ENRA.PS2 5.307 CFEC. PS2 CNEC. PS2 2226.017 RCEF. PS2 420.158 RCEN. PS2 1985.764 RCNT. PS2 RCFT. PS2 541.034 CNTC. PS2 1501.773 CFTC.PS2 532.628 NPOR.PS2 GR.PS2 72.875 TENS. PS2 975.000 DEPT. 12595.500 NPHI.PS2 55.292 ENPH. PS2 50.546 TNPH. PS2 TNRA.PS2 4.436 RTNR.PS2 4.547 ENP~.PS2 6.490 CFEC. PS2 CNEC. PS2 2794.986 RCEF. PS2 400.048 RCEN. PS2 2284.530 RCNT. PS2 RCFT. PS2 317.071 CNTC. PS2 1504.580 CFTC.PS2 321.620 NPOR.PS2 GR.PS2 86.375 TENS.PS2 1680.000 27.558 419.448 1632.857 27.558 65.852 430.665 1765.375 60.890 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-i998 16:30 PAGE: 24 **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCR~ENT: O. 5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH CNTG 12767.0 $ LOG HEADER DATA STOP DEPTH 12595.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAIV~qA RAY CNTG COMPENSA TED NUETRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~Z4PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 02 -NOV- 97 CP 44.2 1027 02-NOV-97 12776.0 12754.0 12600.0 12749.0 900.0 TOOL NUMBER SGC-SA-664 CNC-GA-63 12843.0 CRUDE 10.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 25 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REFIARKS: TIED IN TO DA CBL DATED 4/11/86. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC AND TO DETECT GAS UNDERRUNS. TOTALS PUMPED: 560 CRUDE(6 BPM INITIAL RATE, 3 BPM WHILE LOGGING PASSES HAD SOME SPIKING. PASS #2 NOT PRESENTED. PASS #4 & #5 LOGGED AT 900 FPH. OVERLAY AND AVERAGE ARE ONLY OF PASSES 3, 4, &5. GOC NOT OBSERVED AND NO OBVIOUS GAS UNDERRUNS. THIS FILE CONATINS THE RAW DATA FOR PASS #3. (PASS #4 ON THE FIELD PRINT) $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 2 6 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELM CODE (HEX) DEPT FT 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 NPHI PS3 PU 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 ENPH PS3 PU 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 TNPH PS3 PU 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 TNRA PS3 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 RTNR PS3 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 ENRA PS3 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 CFEC PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 CNEC PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 RCEF PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 RCEN PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 RCNT PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 RCFT PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 CNTC PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 NPOR PS3 PU 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1173646 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 12767.000 NPHI.PS3 48.504 ENPH. PS3 36.117 TNPH. PS3 TNRA.PS3 4.063 RTNR.PS3 4.184 ENRA.PS3 5.263 CFEC. PS3 CNEC.PS3 2683.798 RCEF. PS3 510.780 RCEN. PS3 2394.136 RCNT. PS3 RCFT. PS3 379.948 CNTC. PS3 1482.763 CFTC. PS3 374.045 NPOR.PS3 GR.PS3 34.563 TENS.PS3 1080.000 DEPT. 12595.000 NPHI.PS3 57.617 ENPH. PS3 50.622 TNPH. PS3 TNRA.PS3 4.563 RTNR.PS3 4.790 ENRA.PS3 6.496 CFEC. PS3 CNEC. PS3 2719.174 RCEF. PS3 406.083 RCEN. PS3 2454.985 RCNT. PS3 RCFT. PS3 321.535 CNTC. PS3 1478.530 CFTC. PS3 341.700 NPOR.PS3 GR.PS3 93.750 TENS. PS3 1660.000 45.915 509.918 1612.187 45.915 53.166 418.609 1564.309 54.733 ** END OF DATA ** · LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 27 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH CNTG 12766.5 $ LOG HEADER DATA STOP DEPTH 12569.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~4A RAY CNTG COMPENSATED NUETRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 02-NOV-97 CP 44.2 1027 02-NOV-97 12776.0 12754.0 12600.0 12749.0 900.0 TOOL NUMBER SGC-SA-664 CNC-GA-63 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 28 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 12843.0 CRUDE 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REMARKS: TIED IN TO DA CBL DATED 4/11/86. THE PURPOSE OF THIS LOG WAS TO MONITOR GOC AND TO DETECT GAS UNDERRUNS. TOTALS PUMPED: 560 CRUDE(6 BPM INITIAL RATE, 3 BPM WHILE LOGGING PASSES HAD SOME SPIKING. PASS #2 NOT PRESENTED. PASS #4 & #5 LOGGED AT 900 FPH. OVERLAY AArD AVERAGE ARE ONLY OF PASSES 3, 4, &$. GOC NOT OBSERVED AND NO OBVIOUS GAS UNDERRUNS. THIS FILE CONATINS THE RAW DATA FOR PASS #4. (PASS #5 ON THE FIELD PRINT) $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 29 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) DEPT FT 1173646 O0 000 O0 0 9 1 ! NPHI PS4 PU 1173646 O0 000 O0 0 9 1 1 ENPH PS4 PU 1173646 O0 000 O0 0 9 1 1 TNPH PS4 PU 1173646 O0 000 O0 0 9 1 1 TNRA PS4 1173646 O0 000 O0 0 9 1 1 RTNR PS4 1173646 O0 000 O0 0 9 1 1 ENRA PS4 1173646 O0 000 O0 0 9 1 1 CFEC PS4 CPS 1173646 O0 000 O0 0 9 1 1 CNEC PS4 CPS 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 RCEF PS4 CPS 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 RCEN PS4 CPS 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 RCNT PS4 CPS 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 RCFT PS4 CPS 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC PS4 CPS 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC PS4 CPS 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 NPOR PS4 PU 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1173646 O0 000 O0 0 9 1 t 4 68 0000000000 TENS PS4 LB 1173646 O0 000 O0 0 9 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-JAN-1998 16:30 PAGE: 30 DEPT. 12766.500 NPHI.PS4 TNRA.PS4 3.955 RTNR.PS4 CNEC. PS4 2631.729 RCEF. PS4 RCFT. PS4 377.967 CNTC. PS4 GR.PS4 24.125 TENS.PS4 DEPT. 12569.000 NPHI.PS4 TNRA.PS4 5.467 RTNR.PS4 CNEC. PS4 2746.603 RCEF. PS4 RCFT. PS4 358.069 CNTC. PS4 GR.PS4 73.813 TENS.PS4 46.539 ENPH. PS4 4.073 ENRA.PS4 433.586 RCEN. PS4 1435.059 CFTC. PS4 1075.000 74.094 ENPH. PS4 5.889 ENRA.PS4 387.094 RCEN. PS4 1541.027 CFTC.PS4 1680.000 45.395 TNPH. PS4 6.080 CFEC. PS4 2347.688 RCNT. PS4 372.094 NPOR.PS4 54.320 TNPH. PS4 6.773 CFEC. PS4 2544.776 RCNT. PS4 323.182 NPOR.PS4 44.096 432.853 1560.319 44.096 70.116 405.519 1692.395 69.411 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/28 ORIGIN · FLIC TAPE NAME : 98043 CONTINUATION # : 1 PREVIOUS TAPE : COIVlPIENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-33, API# 50-029-21545-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/0~/28 ORIGIN · FLIC REEL NAME : 98043 CONTINUATION # : PREVIOUS REEL : COMIVlENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-33, API# 50-029-21545-00 LIBRARY TAPE CURVE SPECIFICATIONS Company Well Field ARfq.~ AT,A.q~A: TNC . D. S. 4-33 PRUn~oE BAY County, State .NORT~ ST.OPE, ALASKA Date 3/13/86 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RFOC RILM RILD " RESISTIVITY FOCUSED · RESISTIVITY I~EDIUM IND. RESISTIVITY DEEP IND. GA/~A RAY DIFL/AC .2 - 2,000 0 - 100, 100 - 200 CAL CALIPER t CN/CDLt 6 - 16 GR1 i GAlenA RAY i " 10 - 100, 100 - 200 DES I BULK DENSITY " 2 - 3 (;ORR .CORRECTIO~ " -. 5 - · 5 I SP SELF POTENTIAL " " I kC ACCOUSTIC LOG " 150 - 50 '.:: 'L'_:':.:".-..' '..'. .................................... ...................... ~: ............................... ~:~'~ .................... ~:~:'~'"~ ................ ~:' ............. ::~?~' ........ ~??~:~'-~:~??"~"~'"~"~'-'~:~:~.:~:~:~:~:~??~.?::~ : .......... : .~:~: :.7 :.,~:~~'~=?:'~""~ ':7-C~C,., ~,, ................................................................... 0"~'~"~-'~. .......... 0'"~' P1'~. '~ ..... 0, '~',. i~ ~' '~ ............................ 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