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Home My WebLink About181-083 Ima 'roject Well History File Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. /__ ~' I (~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) ~s: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: BEVERLY~INCENT SHERYL MARIA WINDY Project Proofing BY: BEVER~CENT SHERYL MARIA WINDY Scanning Preparation ~._..~ x 30 = ,,]~"~ + TOTAL PAGES BY: BEVERLY~J~/INCENT SHERYL MARIA WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~ YES NO Stage 2 IF NO IN STAGE t, PAGE(S) DISCREPA~Ki~'~E FOUND: YES NO RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality Checked 12110/02Rev3NOTScanned.wpd Well PBU 12-12 Revision . . Page 1 of 1 Fleckenstein, Robert J (DOA) From: Stewman, Sondra D [Sondra.Stewman@bp.com] Sent: Tuesday, July 10,20078:22 AM To: Fleckenstein, Robert J (DOA) Cc: Hubble, Terrie L Subject: Well PBU 12-12 Revision Bob, Here's the Top of Productive Horizon data which was not listed on the recent 10-407 submission for Well PBU 12- 12, Permit # 181-083, Approval #307-104 and API # 50-029-20610-00-00 Top of Productive Horizon: 3481' FSL, 3429' FEL, SEC. 18, T10N, R15E, UM Location of Well (State Base Plane Coordinates, (NAD 27): TPI: X - 694093 Y - 5933723 Zone ASP4 Please advise if you require further information. Sandra Stewman ADW Drilling TA Diversity & Inclusion Resource D&I Info: httpj jalaska.bpweb.bp.comjdi SCANNED JUL 1 () 2001 7/10/2007 . STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COM SSION JUN 2 9 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LO.IG I. . Ala$l\a 011 & Gas Cons. Commission RECEIVED . , 1a. Well Status: o Oil o Gas o Plugged ~ Abandoned o Suspended 1 b. Well Class: ... 20AAC 25.105 20AAC25.110 ~ Development o Exploratory D GINJ OWINJ o WDSPL DWAG D Other No. of Completions Zero D Service D Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aba~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/2/2007 ~ «,/0 181-083 307-104 3. Address: 6. Date Spudded --, 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 07102/1981 50-029-20610-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 07/19/1981 PBU 12-12 1015' FSL, 751' FEL, SEC. 18, T10N, R15E, UM 8. KB (ft above MSL): 71.0 15. Field 1 Pool(s): Top of Productive Horizon: . ~~e4.-A-.tJ'\~~ Q.- m~·t.. Ground (ft MSL): Prudhoe Bay Field 1 Prudhoe Bay Total Depth: ~ 7 -to -1:)""7 9. Plug Back Depth (MD+ TVD) Pool 4065' FSL, 3648 EL, SEC. 18, T10N, R15E, UM 3318 3311 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 696843 y- 5931327 Zone- ASP4 10870 9471 ADL 028330 - 11. SSSV Depth (MD+ TVD) 17. Land Use Permit: TPI: x- N/A y- N/A Zone- N/A Total Depth: x- 693856 5934301 Zone- ASP4 N/A N/A y- 18. Directional Survey 0 Yes ~ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and orinted information ner 20 MC 25.050\ N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): DIL, BHCS, GR, SP, FDC, CNL, CBL, CET 22. CASING, LINER AND CEMENTING RECORD \CÂsm.¡¿i G~DEi .... SETTING DEPTH Mt> SETTING· DEPTH 1'\10 HOLE ·.4~"": ,.,T.. Wr.PËRFT. Top BOTTOM Top BoTtoM SIZE ~ ...;. /POI.l.ED. 20" 91.5# H-40 Surface 110' Surface 110' 30" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2664' Surface 2664' 17 -1/2" 2750 sx Fondu 400 sx PF 9-5/8" 47# L-80 Surface 9933' Surface 8758' 12-1/4" 500 sx Class 'G' 7" 29# L-RO 9619' 10870' 8502' 9471' 8-1/2" 300 sx Class 'G' 23. Open to production or injection? DYes ~No 24. ...... < ;i i. ... > . ...... .. If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD) (MD+ TVD of Top & Bottom; Perforation Size and Number): None 5-1/2",17#, L-80 3801' - 9588' 9578' MD TVD MD TVD 4-1/2",12.6#, L-80 9588' - 9651' 25. iÂ).;...<-· , ,..: ....< ..(}( ( ( n...'''',}, < .(, i'...·.. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9365' P&A with 14.5 Bbls Class 'G' 3580' Set EZSV placed 45 Bbls Class G below 3339' Set EZSV with Whipstock on Top 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: PRODUCTION FOR OIL-BBL: GAs-McF: WATER-BBL: CHOKE SIZE: I GAS-OIL RATIO: TEST PERIOD ... Flow Tubing Casing Press: CALCULATED OIL-BBL: GAs-McF: WATER-BBL: OIL GRAVITY-API (CORR): Press. 24-HoUR RATE'" 27. CORE DATA Conventional Core(s) Acquired? DYes ONo Sidewall Core(s) Acauired? DYes DNo If Yes to either question, list formations and intervals cored (MD+ TVD 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 results per 20 MC 250.071. IOMPtETIOK None RBDMS BFL JUL 0 6 2007 ~..~11 Ít""\ I; ,.. Form 10-407 Revised 02/2007 0 RIG I N ACrTINUED ON REVERSE SIDE ~ 7ff~7 (, 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A KERS ENCOUNTERED): NAME MD TVD Permafrost Top Permafrost Base Top SadleRochit 10028' 8832' O\W Contact 10369' 9094' Base SadleRochit 10775' 9400' 29. FORMATION TESTS Well Teste. 0 Yes ~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. None Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Pre-Rig Work Summary. Signed oing is true and. correct to the best of my knowledge. Title Technical Assistant Date ' 1.9-ê).8 {)7 PBU 12-12 Well Number Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Mehrdad Nadem, 564-5941 181-083 307-104 Permit NO.1 A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: 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 29: 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 MC 25.071. Form 10-407 Revised 02/2007 Submit Original Only · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-12 12-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/26/2007 Rig Release: 6/20/2007 Rig Number: Spud Date: 7/2/1981 End: 6/20/2007 5/26/2007 00:00 - 16:30 16.50 MOB P PRE Depart DS 01-05. Travel to DS 12-12. 16:30 - 17:30 1.00 MOB P PRE Arrive on location @ 16:30 hrs. Move rig to 12-12 site. 17:30 - 00:00 6.50 RIGU P PRE PJSM. Spot rig over well @ 17:30 hrs. Rig up. 5/27/2007 00:00 - 01 :00 1.00 RIGU P PRE Rig up circulation lines in the cellar and pressure test to 3500 psi. 01 :00 - 02:00 1.00 WHSUR P DECOMP Take on fluids in pits. Rig accepted @ 01 :00 hrs 5/27/076 02:00 - 02:30 0.50 WHSUR P DECOMP Pre-Spud meeting I PJSM. 02:30 - 03:00 0.50 WHSUR P DECOMP Service rig, mobilize, rig up DSM to pull BPV. 03:00 - 03:30 0.50 WHSUR P DECOMP Pull BPV. 03:30 - 08:00 4.50 Kill P DECOMP Circulate wellbore clean of freeze protection and other fluids. Circulate in 8.5 ppg Seawater 104 gpm I 42 psi. -Pump 450 bbls of heated Seawater @ 8.5 ppg. -Pump 50 bbls of Safe Surf-O I Seawater sweep. -Displace well to 9.8 ppg NaCI Brine - 200 gpm I 225 psi. 08:00 - 09:00 1.00 Kill P DECOMP RlU & test Tbg x IA t/ 3500 psi - FAIL. Bled to -0 in 20 minutes. 09:00 - 11 :00 2.00 Kill P DECOMP RlU little Red Hot Oil Services. Test OA t/ 2000 psi wI diesel for 30 minutes. - Final pressure 1900 psi - PASS. RID little Red. 11 :00 - 12:00 1.00 Kill P DECOMP Monitor IA on well losing- 5- bbls/hr. 12:00 - 13:00 1.00 BOPSU P DECOMP DSM - install BPV. Attempt to test fl below to 1000 psi. 3" Grey valve packing on IA leaking - tightened packing. Test BPV to 1000 psi f/ 10 minutes with mud pumps maintaining 0.5 bpm on pump to maintain hole fill and 1000 psi. - Pass. UD lubricator. Continue to keep hole full (IA) wI 9.8 ppg NaCI Brine. 13:00 - 14:30 1.50 BOPSU P DECOMP Cameron - dry rod TWC. -1 st test failed due to O-ring failure on Otis Cap. -Retest to 1000 psi f/ 10 min - PASS. RID and blow down test equipment. 14:30 - 16:00 1.50 BOPSU P DECOMP PJSM wI Cameron and crew. N/D Tree & Adaptor flange. 16:00 - 17:00 1.00 BOPSU P DECOMP Inspect top connection on Tbg hanger. Verified thread type on hanger. 57/8" RH ACME. 18 1/4 tums make up. 17:00 - 19:00 2.00 BOPSU P DECOMP PJSM. N/U BOPE. 19:00 - 19:30 0.50 BOPSU P DECOMP RlU test equipment 19:30 - 00:00 4.50 BOPSU P DECOMP Test BOPs 250 13500 psi. w/ 4" & 5 1/2" test jts. AOGCC Bob Noble declined to witness. BP rep Dan Shearer and NAD TP Bitt Perry witness test. Brine wt = 9.8 ppg. Total losses for the day = 83 bbls. 6.38 bph Average. 5/28/2007 00:00 - 01 :30 1.50 BOPSU P DECOMP Test BOPs 250 13500 psi. wI 4" & 5 1/2" test jts. AOGCC Bob Noble declined to witness. BP rep Dan Shearer and NAD TP Bitt Perry witness test. 01 :30 - 02:00 0.50 BOPSU P DECOMP Blow down all lines. RID all testing equipment. Printed: 612812007 1 :26:20 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-12 12-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/26/2007 Rig Release: 6/20/2007 Rig Number: Spud Date: 7/2/1981 End: 6/20/2007 RlU DSM lubricator. Pull TWC. RID lubricator. RlU to unseat Tbg hanger and pull 5 1/2" Tbg. Back out lock down screws. Pull Tbg hanger above floor. Pull free wI 175K. Up wt 83K. Brine wt in hole 9.8 ppg CBU. 240 gpm I 90 psi. Gas seen on bottoms up (Brine wt= 9.2 ppg @ B.U.) Circ and condition Brine untill 9.8 ppg all the way around. UD hanger and jt of DP. C/O elevators to pull 5 1/2" Tbg. Up wt= 80K, SOW= 78K. POH, UD 5 1/2", 17#, L-80 Tbg. Recovered: -23 clamps, 23 pins & 6 SS bands. -94 full jts & 1 cut off jt = 20.31'. -1-GLM. DECOMP RID Tbg handling equipment. DECOMP RlU BOPE test equipment. DECOMP Test bottom pipe rams ( 2 7/8" x 5") variables, wI 5" test jt.-250 13500 psi.-PASS. Attempt test wI 4" test jt-SSSV control line port (SMR) leaking. Mobilize Haliburton Storm Pkr. RID and blow down test equipment. P/U 9 - 6 1/4" DCs. M/U RTTS. Up wt= 45K, SOW= 45K. Set 80' below RKB. Test from above to 1000 psi. -PASS. Run in 4" test jt. Cameron remove SMA. Set test plug. Verify set through SMR hole. Install SMR blanks. Test bottom pipe rams ( 2 7/8" x 5") variables, wI 4" test jt.-250 13500 psi.- PASS. RID and blow down test equipment. Back out RTTS. UD 2 jts DP, UD RTTS. Rack back 3 stds 6 1/4" DCs. Set wear ring. PJSM wI SLB. RlU E-line wI 8 1/2" Gauge ring & Junk basket RIH wI E-line, Hang up @ 245' md - Not enough weight. POH add weight bars. RIH work @ 248' md, continue to RIH. Tag 51/2" Tbg top @ 3801' md ELM. 04:00 - 04:30 0.50 PULL P DECOMP 04:30 - 05:00 0.50 PULL P DECOMP 05:00 - 06:00 1.00 PULL P DECOMP 06:00 - 08:00 2.00 PULL P DECOMP 08:00 - 08:30 0.50 PULL P DECOMP 08:30 - 14:45 6.25 PULL P DECOMP 14:45 - 15:00 15:00 - 15:15 15:15 - 17:15 0.25 PULL 0.25 BOPSU 2.00 BOPSU 17:15 - 17:30 0.25 BOPSU DECOMP 17:30 - 18:30 1.00 BOPSU DECOMP 18:30 - 20:30 2.00 BOPSU DECOMP 20:30 - 21 :00 0.50 BOPSU DECOMP 21 :00 - 22:00 1.00 BOPSU P DECOMP 22:00 - 22:30 0.50 DHB P DECOMP 22:30 - 00:00 1.50 DHB P DECOMP 5/29/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP 01 :00 - 02:00 1.00 EVAL P DECOMP 02:00 - 04:30 2.50 EVAL N SFAL DECOMP 04:30 - 08:30 4.00 P DECOMP 08:30 - 10:00 1.50 EVAL P DECOMP 10:00 - 13:00 3.00 CASE P DECOMP 13:00 - 14:00 1.00 CASE P DECOMP Continue to run w/SLB E-line. POH wI Junk basket & Gauge ring. Junk basket empty. RU USIT Run USITI CBL. Computer failres resulted in running the USIT in teh hoe I again. RlU & Run USITI CBL fl 3,810' md to surface. Send logs to Town & consult wI Town on next step. RlU & run EZSV cementer on E-line to 3,564' md. Set plug and POH. PJSM. Printed: 6/28/2007 1 :26:20 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-12 12-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/26/2007 Rig Release: 6/20/2007 Rig Number: Spud Date: 7/2/1981 End: 6/20/2007 5/29/2007 13:00 - 14:00 1.00 CASE P DECOMP RlU & test 9 5/8" casing to 3500 psi I 30 minutes - PASS. RID and blow down all lines and equipment. 14:00 - 17:30 3.50 CASE P DECOMP PJSM wI HES hand & rig crew. P/U Star Guide cement stinger. RIH picking up 5" DP tJ 3,5610 md. 17:30 - 18:30 1.00 CASE P DECOMP Circulate 212 bbls @ 6 bpm 1135 psi to insure DP is clear of debris. PJSM during circulation wI BP reps, NAD TPs, SLB and rig crew. 18:30 - 20:00 1.50 CASE C DECOMP Attempt to tag EZSV @ 3,564'md. P/U single, RIH, tag EZSV @ 3,583' md. (19 ft deep). Set down wI stinger, open valve wI 20K. PU= 90K. SOW= 95K. 20:00 - 20:30 0.50 CASE C DECOMP RlU cement head & manifold. 20:30 - 21 :00 0.50 CASE C DECOMP Establish injection rate @ 0.5 bpm I 1100 psi fl 5 bbls. Unsting fl EZSV. 21 :00 - 22:00 1.00 CASE C DECOMP Close bag, SLB pump 5 bbls water to PT lines to 4000 psi. Pump cement while holding 200 psi back pressure wI Choke. -5 bbls water. -45 bbls of 15.8 ppg class "G" cement. -10 bbls of 12.5 ppg Mud Push. Sting into EZSV. Rig pumps displace 63 bbls. As follows: Start - 0.5 bpm I 760 psi. @ 380 stks I 1285 psi. Open bag. @ 500 stks I 940 psi. Up rate to 1 bpm @ 550 stks I 730 psi. -700 stks I 480 psi. @ 800 stks I 608 psi. @ 900 stks I 729 psi. -1000 stks I 800 psi. Slow pump rate to 0.5 bpm. @ 1050 stks 753 psi. @ 1090 stks I 767 psi. C.I.P. at retainer. 27 bbls of Cement through suspected leak at 3,810' md in casing. 22:00 - 22:30 0.50 CASE C DECOMP Circulate out excess Cement and Mud Push. Pump- 238 bbls, received and dumped 30 bbls of Cement and Mud Push contaminated brine returns. 22:30 - 00:00 1.50 CASE P DECOMP Monitor well - Static. POH wI SLM to 1,603' md. 5/30/2007 00:00 - 01 :00 1.00 CASE P DECOMP Continue to POH (SLM) fl 1,603' md. UD Cement stinger. No correction on SLM. 01 :00 - 02:00 1.00 CASE P DECOMP Clean and clear rig floor. Service Rig: Top drive, Draw works and Koomey. 02:00 - 02:45 0.75 CASE N DPRB DECOMP PJSM on rigging up SLB. Rig up SLB E-liners. 02:45 - 05:30 2.75 CASE N DPRB DECOMP RIH wI SLB E-line. Confirm depths and collar locations. -SLB= 3,565' md. - DP= 3,583' md. Confirm EZSV is 35' md below casing collar. E-line depth correction is 18 ft. 05:30 - 08:00 2.50 STWHIP P WEXIT PJSM wI Rig crew, Baker hand and BP rep. P/U & M/U Whipstock and Milling BHA, RIH. 08:00 - 11 :30 3.50 STWHIP P WEXIT P/U 17 jts of 5" HWDP fl shed. RIH tJ 894' md. Continue to RIH from Derrick wI 5" DP to 3,537' md. M/U Top drive. Pump 520 gpm 11150 psi. Circulate 1 DP volume. Orient Whipstock 5 degrees left of high side. RIH, tag @ 3,559' md. Set down 1 OK I 23' high. Check logs. Whipstock sitting across collar. Printed: 6/28/2007 1 :26:20 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-12 12-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/26/2007 Rig Release: 6/20/2007 Rig Number: Spud Date: 7/2/1981 End: 6/20/2007 5/30/2007 11 :30 - 15:00 3.50 STWHIP N DPRB WEXIT POH wI Whipstock. 15:00 - 16:15 1.25 STWHIP N DPRB WEXIT PJSM wI BP rep, Baker hand and crew. UD Whipstock. Inside the trip anchor of Whipstock is packed off with firm contaminated Mud Push and Cement. 16:15·16:30 0.25 STWHIP N DPRB WEXIT Clean and clear floor. 16:30 - 18:00 1.50 STWHIP N DPRB WEXIT PJSM. P/U -clean out I casing scraper BHA. 18:00 - 21 :30 3.50 STWHIP N DPRB WEXIT PJSM. P/U 5" DP, RIH to 3,500' md. 21 :30 . 23:00 1.50 STWHIP P WEXIT PJSM. Cut 54' of drilling line, adjust brakes on draw works. Service Top drive, service Crown. 23:00 - 00:00 1.00 STWHIP N WEXIT RIH, tag cement @ 3,559' md. Break circulation. 190 gpm I 154 psi stage up to 500 gpm I 900 psi. Up wt= 120K, SOW= 115K, ROT wt= 120K, RPM= 20, Tq= 1 K. Clean out cement fl 3,559' md to 3,570' md wI RPM= 60, Tq= 2.5K. 5/31/2007 00:00 . 01 :00 1.00 STWHIP N DPRB WEXIT Continue to clean out cement. 500 gpm I 920 psi. RPM= 60, UP wt= 175K, SOW= 115K. Tagged top of EZSV @ 3,580' md. Pick up, shut down pumps and rotary, set down 40K-OK. 01 :00·02:30 1.50 STWHIP N DPRB WEXIT Stand back 1 stand of DP. RlU & test 9 5/8" casing to 3500 psi. - PASS. RID test equipment. 02:30 . 04:00 1.50 STWHIP P WEXIT Displace well to new 10.0 ppg LSND from M-I mud plant. 250 gpm I 860 psi. 237 bbls hole volume. 04:00 - 05:00 1.00 STWHIP N DPRB WEXIT POH from 3,580' md to 757' md, for Whipstock. 05:00 . 06:00 1.00 STWHIP N DPRB WEXIT UD "Clean-Out" BHA 06:00·06:15 0.25 STWHIP N DPRB WEXIT PJSM wI Baker rep, WSL and rig crew on P/U and running Whipstock. 06:15·08:00 1.75 STWHIP N DPRB WEXIT P/U & M/U Whipstock & BHA, RIH. 08:00 - 10:30 2.50 STWHIP N DPRB WEXIT RIH wI Whipstock & Milling assembly to 3,541" md. 10:30 - 11 :00 0.50 STWHIP N DPRB WEXIT M/U Top Drive, Orient 14 degrees left of top center, RIH. Up wt=120K, SOW=115K, GPM= 500. Tagged plug @ 3,579' md. Set down 25K, sheared Pin on Whipstock. P/U with no excess weight. Set down 40K, set trip Anchor. 11 :00 . 12:00 1.00 STWHIP N RREP WEXIT Change out Gilmore valve on Accumulator. For annular pressure control. 12:00 - 16:30 4.50 STWHIP P WEXIT Cut window from TOW= 3,557' md to BOW=3,567 'md. Rot wt= 116K, RPM= 80, GPM= 500, PSI= 860, WOM= 6K, Tq= 4-5K. Drill to 3,586'. (Gauged hole depth = 3,582' md). Total wt of recovered metal = 2761bs. 16:30 . 18:00 1.50 STWHIP P WEXIT Work mill through window several times, with and without rotation. No problems. Pump 10.0 ppg Super Sweep with a 10% increase in cuttings returns when back at surface. 18:00 . 19:00 1.00 STWHIP P WEXIT RlU and perform FIT I LOT. Mud wt= 10.0 ppg, TVD= 3,539' tvd, LOT= 600 psi. EMWT = 13.26 ppg. Printed: 6/2812007 1 :26:20 PM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-12 12-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/26/2007 Rig Release: 6/20/2007 Rig Number: Spud Date: 7/2/1981 End: 6/20/2007 5/31/2007 19:00 - 21 :00 2.00 STWHIP P WEXIT POH from 3,557' md. 21 :00 - 22:15 1.25 STWHIP P WEXIT UD (9)- 61/4" DC's. UD MWD, Jars, UBHO, and Milling assembly. Mills in gauge. 22:15 - 22:30 0.25 STWHIP P WEXIT Clean & clear Rig floor. 22:30 - 23:30 1.00 STWHIP P WEXIT Pull wear ring. MIU Stack Jetting tool. Function BOP's. Jet Stack. BID lines. Install wear ring. 23:30 - 00:00 0.50 STWHIP P WEXIT P/U DP to 125' md. 6/1/2007 00:00 - 02:00 2.00 STWHIP P WEXIT Pick up 5" drill pipe and stand in derrick. Prepare tools and rig floot to pick up BHA. 02:00 - 04:00 2.00 STWHIP P WEXIT Pick up new 81/2" PDC bit and Drilling Rotary Steerable Power drive BHA (RSS). 04:00 - 08:00 4.00 STWHIP P WEXIT RIH to window at 3,557' with drilling BHA picking up 5" drill pipe in singles. Shallow test MWD. 08:00 - 08:30 0.50 STWHIP P WEXIT Service top drive 08:30- 10:00 1.50 STWHIP P WEXIT POH to 3485'. RIH to top of 9 5/8" window MAD pass to tie-in GR logs. 10:00· 11 :00 1.00 STWHIP P WEXIT Slowly lower bit and BHA to window at 3357' and across Whipstock slide. Tag up 3' from bottom of window. Work BHA and attempt to pass through window. No success 11 :00 - 13:30 2.50 STWHIP N DPRB WEXIT POH with RSS drilling BHA. Mud weight 10.0 ppg 13:30 - 15:00 1.50 STWHIP N DPRB WEXIT Stand back drilling BHA, 5" HWDP and drill caoolars. Lay down RSS, MWD and bit. PDC bit damaged on all 6 blades in the shoulder area. 15:00 - 16:30 1.50 STWHIP N DPRB WEXIT Pick up clean-out milling BHA, Baker 81/2" starting mill, 5" flex joint and 8 1/2" upper Watermellon mill. RIH with HWDp to 603'. 16:30 - 17:15 0.75 STWHIP N DPRB WEXIT RIH with clean-out milling BHA to 3535' 17:15 - 22:45 5.50 STWHIP N DPRB WEXIT Establish up, down and rotating weights. Mill on obstruction in window with 2K weight on the mill, 1K-2K torque and slow RPM. Having difficulty keeping the mill on the Whipstock slide. 22:45 - 23:30 0.75 STWHIP N DPRB WEXIT Circulate around 11.0 ppg Super Sweep pill. 23:30 - 00:00 0.50 STWHIP N DPRB WEXIT Monitor well. Pump dry job, blow down top drive 61212007 00:00 - 02:00 2.00 STWHIP N DPRB WEXIT POH fl 3,560' md to 603' md. 02:00 - 02:30 0.50 STWHIP N DPRB WEXIT Rack collars and HWDP in derrick. UD Milling BHA. 02:30 - 02:45 0.25 STWHIP N DPRB WEXIT PJSM- wI WSL, NAD TP, SLB & rig crew. Discuss RlU & running of CCL & EZSV Bridge plug. 02:45 - 03:30 0.75 STWHIP N DPRB WEXIT RlU E-liners. 03:30 - 04:00 0.50 STWHIP N DPRB WEXIT RIH for CCL and depth control run. 04:00 - 06:30 2.50 STWHIP N DPRB WEXIT Pull E-line out of the hole & RID due to bad spot in line (wire frayed). Cut +250 feet off drum. Rehead running tool. 06:30 . 07:00 0.50 STWHIP N DPRB WEXIT RlU E-line. 07:00 - 07:30 0.50 STWHIP N DPRB WEXIT Run correlation log-CCL to 3,550' md. 07:30 - 10:00 2.50 STWHIP N DPRB WEXIT RID logging equipment. RlU to run EZSV Bridge plug. 10:00 - 11 :30 1.50 STWHIP N DPRB WEXIT RIH wI EZSV Bridge plug. Set plug @ 3,339' md I 3,327' tvd. POH wI Wireline. 11 :30 - 12:15 0.75 STWHIP N DPRB WEXIT RID E-liners Printed: 6/2812007 1 :26:20 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-12 12-12 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 5/26/2007 Rig Release: 6/20/2007 Rig Number: Spud Date: 7/2/1981 End: 6/20/2007 6/212007 12:15 - 13:15 1.00 STWHIP N DPRB WEXIT RlU & test EZSV Bridge plug to 3500 psi I 5 minutes - PASS. 13:15 - 14:30 1.25 STWHIP N DPRB WEXIT P/U & stand back (9 jts)- 6 1/4" DC's 14:30 - 17:30 3.00 STWHIP N DPRB WEXIT PJSM -M/U Whipstock Assy & BHA. 17:30 - 19:15 1.75 STWHIP N DPRB WEXIT RIH, Surface test MWD @ 1,031' md. RIH to 3,302' md. 19:15 - 20:00 0.75 STWHIP N DPRB WEXIT Establish circulation & string wts. Orient Whipstock 21 degrees left of Top. Tag EZSV Bridge plug @ 3,339' md. Set Whipstock. 1.00 STWHIP N DPRB WEXIT Mill Lug off of Whipstock. 3.00 STWHIP N DPRB WEXIT Mill window f/3,318' md (window plan 3,318' md to 3,320' md). GPM= 504, PSI= 839, RPM= 88, Tq= 5K, Up wt= 115K, SOW= 115K, WOB= 6K. Metal cuttings returned= 18 Ibs. 6/3/2007 00:00 - 08:30 8.50 STWHIP N DPRB WEXIT Continue to Mill new window in 9 5/8" casing from 3,318' md to 3,335' md. TOW= 3,318' md. BOW= 3,335' md. Metal recoverd= 371 Ibs. 08:30 - 09:00 0.50 STWHIP P WEXIT Drill 25 ft of new formation to 3,360' md for LOT. 09:00 - 09:30 0.50 STWHIP P WEXIT Pump sweeps. Work Mill through window with and without rig pumps on. No Drag or weight stacking noted. Pull up into casing for LOT. 09:30 - 09:45 0.25 STWHIP P WEXIT RlU for LOT. 09:45 - 10:30 0.75 STWHIP P WEXIT Perform LOT to 13.01 ppg EMWT. RID, pump dry job. Blow down lines. 10:30 - 11 :30 1.00 STWHIP P WEXIT POH f/3,310' md to 375' md. Mud weight= 9.6 ppg. 11 :30 - 13:45 2.25 STWHIP P WEXIT UD DC's, MWD and Milling Assy. Upper Mill in gauge, Starter Mill 1/8" out of gauge. 13:45 -14:45 1.00 STWHIP P WEXIT Pull wear bushing, Jet the Stack clean, set Wear bushing. 14:45 - 17:00 2.25 STWHIP P WEXIT PJSM. -M/U Rotary Steerable BHA. 17:00 - 18:30 1.50 STWHIP P WEXIT RIH t/ 739' md. Surface test MWD. RIH t/ 3,295' md. 18:30 - 19:30 1.00 STWHIP P WEXIT Establish ECD and drilling parameter baselines. Work through window: 5K Dn wt @ 3,321' md. 10K Dn wt @ 3,328' md. Slack off past 3,328' md wI 424 gpm I 860 psi to 3,345' md. Ream from 3,345' md to 3,360' md.wl 545 gpm, 1265 psi. Tq= 4K, RPM= 30, Up wt= 115K, SOW= 105K. 19:30 - 00:00 4.50 DRILL P INT1 Drill from 3,360' md to 3,600' md. WOB= 5K, GPM= 547, PSI on= 1324, PSI off= 1250, Tq on= 3K, Tq off= 2K, Up wt= 118K, SOW= 105K, Rt wt= 11 OK, RPM= 120, ECD= 10.45 Calc, 10.44 Act. Mud weight 9.6 ppg. 6/4/2007 00:00 - 12:00 12.00 DRILL P INT1 Drill ahead 8 1/2" hole with Rotary Steerable System (RSS) Power Drive from 3,600' md to 4,707' md. GPM= 550, PSI on= 1740, PSI off= 1607, PU wt= 135K, SOW= 120K, Tq on= 6K, Tq off= 5K, ROT wt= 120K, Calc ECD= 10.38 ppg, Act ECD= 10.65 ppg. Mud wt= 9.6 ppg. 12:00 - 15:00 3.00 DRILL P INT1 Drill ahead 81/2" hole with RSS from 4,707' md 5232'md. At 5,935' md pumped a Lo I Hi Sweep ECD from 11.01 ppg to 10.90 ppg. GPM= 546, PSI on= 1803, PSI off= 1794, PU wt= 175K, SOW= 130K, Tq on= 9K, Tq off= 8K, ROT wt= 140K, Calc ECD= 10.41 ppg, Act ECD= 10.89. Mud wt= 9.6 ppg. 15:00 - 15:30 0.50 DRILL N STUC INn Sudden increase in torque while drilling, stall out Top Drive, unable to pick up or rotate, full circulation. Work pipe several times to 200K. Pipe came free. Work pipe up one full stand no tight hole. Run stand in while rotating with no obstruction. Work pipe one more time with out rotating and slow pump rate, Printed: 6/28/2007 1 :26:20 PM Digital Wellfile . . Page 1 of 2 Well: 12-12 Well Events for SurfaceWell - 12-12 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FSl -> 12 -> 12-12 Date Range: 01/Apr/2007 to 28/Jun/2007 Data Source(s): AWGRS Description Cost placeholder for 3 sets of connection ends for T handle plug pullers PULL BPV, POST RIG PULLED TWC , RIG TESTED TREE PULLED BPV / BOP TEST SET BPV / NIPPLE DOWN TREE SET BPV / PRE RIG Post Circ Out RD time T/I/O=0/0/60 Circ Out MW (Rig prep) - Pump 180 bbls diesel down IA taking returns up tubing to the flowline of Well 13 to circ MWout of wellbore for upcoming rig work, Bleed WHP's Final WHP's=O/O/O PULL BPV . RIG MOVED ON T/I/O=NA/O/O No scaffolding MIT OA PASSED to 2000 psi (Pre SDTRCK) (Shut in) Pumped 3.9 bbls of 70* ccrude down OA to reach 2000 psi for MIT OA 1st test 1st 15 min lost 120 psi 2nd 15 min lost 30 psi for a total of 150 psi in 30 min Bled OA psi off. Bled back aprox. 2 bbls transfer fluid Final Whp's NA/O/O AWGRS 12-12 05/04/2007 T/I/O= BPV/O/O. Temp= 51. Monitor post-bleed (pre-RIG). No AL or flowline, scaffolding and wellhpuse have been removed for rig prep. Intergal flange installed on IA. No change in pressure overnight. AWGRS 12-12 05/03/2007 T/I/O=BPV/210/20 Temp=SI Bleed WHPs to 0 psi (pre-RIG). No A/L connected or flowline. Scaffolding and well house has been removed for rig prep. IA FL @ surface. Bled lAP from 210 psi to 0 psi in 100 min. OA FL @ surface. Bled OAP from 20 psi to o psi in 2 min. Shut in bleeds and monitor for 30 min. lAP increased to 3 psi. Bled lAP from 3 psi to 0 psi in 20 min « 5 bbls total returned). Monitor for 15 min. No change in pressures. **Note TBG was cut 4/28 so TBG x IA preesures should be the same** Final WHPs=BPV/O/O T/I/O=50+?/210/20. 51. Bleed WHP's to 0 psi (pre-rig). Flow line and AL line have been dropped. Well house and scaffolding have been removed. Will need a ladder to access swab and master valve. Bleed trailer should be on location by AM. SET BPV , PRE RIG ***CONTINUED FROM 27-ARP-2007**** INITIAL T/I/O 0/120/0. 5.5" TUBING CUT AT 3810 FT WITH 4.15" SCP POWERCUTTER. DEVIATION AT CUT 25 DEGREES. DEPTH CORRELATED TO TUBING TALLY DATED 25-JUL-1981. FINAL T/I/O 0/120/0 *****JOB COMPLETE****** AWþRS 12-12 04/27/2007 JET CUT TUBING @ 3,800'. INITIAL T/I/O 0/120/0 RIG UP FOR 5.5" TUBING CUT AT 3800 FT WITH 4.15" SCP POWERCUTTER. DEVIATION AT CUT 25 DEGREES. ***JOB CONTINUED 28-APR-2007*** AWGRS 12-12 04/27/2007 *** WELL 51 ON ARRIVAL *** (pre tbg cut) DRIFTED W/ 4.50" CENT. & S. BAILER TO 8848' SLM (HARD TAG)... BAILER EMPTY DRIFTED W/ 3.50" CENT. & S. BAILER TO 8862' SLM (SOFT TAG)...CEMENT IN BAILER *** WELL LEFT 5/1 *** *****WSR Continued from 04-25-07****** Bleeding TBG & IA pressures post passing CMIT TxlA Final WHP's 0/0/0 T/I/O=O/O/O CMIT TxlA PASSED to 3500 psi. (Post PM) Pump 11.9 bbls. 40* diesel down IA to reach test pressure of 3500 psi., CMIT-TxIA passed on 2nd attempt, T/IA lost 40/50 psi. in 1st 15 min. and lost 40/40 psi. in 2nd 15 min. for a total loss of 80/90 psi., Bleed whp's. -----------IN PROGRESS------------ AWGRS 12-12 04/23/2007 T/I/O = 0+/60/10. Temp = 51. TBG & IA FL's (pre FB). AL = Spool removed. TBG FL near surface. IA FL @ surface. *Note: Integral on Companion Valve and IA Casing Valve. AWGRS 12-12 04/22/2007 CTU #8, PM; Co nt' from WSR 4/21/07 ... Pumped total of 125 bbls of diesel down IA for freeze protect. Continue circulating water down coil taking returns up backside. Pumped 14.5 bbls of 15.8 ppg cement down coil. Lay cement in tubing 1 Events Source Well Date AWGRS 12-12A 06/25/2007 AWGRS 12-12A 06/22/2007 AWGRS 12-12A 06/20/2007 AWGRS 12-12 OS/27/2007 AWGRS 12-12 OS/27/2007 AWGR$ 12-12 OS/26/2007 AWGRS 12-12 OS/26/2007 AWGRS 12-12 OS/25/2007 AWGRS 12-12 OS/25/2007 AWG_RS 12-12 OS/23/2007 8'1'L G R.s 12-12 05/03/2007 AWGRS 12-12 04/29/2007 AWGRS 12-12 04/28/2007 AWGRS 12-12 04/26/2007 AWGRS 12-12 04/25/2007 http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 6/28/2007 Digital Wellfile . . Page 2 of 2 for 1 from 9550' to 8950'. Close in backside and displace approx. 9 bbls of cement into IA through punched holes at 9510'. Est. TOC @ 9365'. POOH replacing coil voidage. FP tubing to 2500' with 60/40 methanol. Secure well. Perform weekly BOP test. RD CTU. *** Job Complete *** AWGRS 12-12 04/21/2007 CTU #8, Tbg. Punch / PM; Cant' from WSR 4/20/07 .... RIH with PDS memory GR/CCL for depth control. Sat down at 9609' ctmd. Logged up and flagged pipe at 9400' ctmd. POOH. RIH with SWS 5' tbg punch loaded 4 spf. Punch holes in 5 1/2" tubing from 9510' to 9515'. Pull to surface, confirm guns fired, recover ball. MU 2.75" BDJSN, no checks. RIH, correct to flag and park at 9550'. Circulate down coil taking returns simultaneously up backside and IA. Well is fluid packed with good 1 for 1 returns. Pump diesel down IA for freeze protection to 2500'. Cant' on WSR 4/22/07 ... AWGR,S 12-12 04/20/2007 CTU #8, Tbg. Punch / PM; MIRU CTU #8. RIH with PDS memory GR/CCL for depth control. Cont' on WSR 4/21/07 ... AWGRS 12-12 04/16/2007 CTU #8, Pull TTP/PM; ... Cant' from WSR 04/15/07 ... MU and RIH with accelerator, jars and 4.5" GS hydraulic spear. Latch KB packer and hit 30 jar licks. Plug did not release. POOH for weight bar. MU and RIH with accelerator, 3 weight bars, jars and 4.5" hydraulic GS spear. Hit 50 licks @ ~ 17K. Could not pull KB pkr & plug assembly. RDMO. *** Job Postponed - TTP and Packer Assembly still in hole *** T/I/O = 340/520/100. Temp = 51. IA FL (CT). IA FL @ 660' (29 bbls). Coil on location. CTU #8, Pull TTP/PM; ... Co nt' from WSR 04/14/07 ... Cant' RIH and tag top of 2- 7/8" XXN plug at 9618' ctmd. Jet 20 bbls of diesel/xylene on top of TTP in 5 bbl stages, letting fluid soak in-between each stage. Spot last 5 bbls on plug. POOH. MU and RIH with jars and 2.5" hydraulic GS spear. Tag at 9607' ctmd. Tagging top of KB packer assy. Unable to get through to latch plug. POOH. MU and RIH with jars, hydraulic centralizer and 2.5" hydraulic spear. Latch plug at 9617' ctmd. Only able to hit 2 jar licks; having trouble getting jars to reset. POOH. MU and RIH with BIDI Hipp Tripper, hydraulic centralizer and 2.5" GS Spear. Latch plug at 9615' ctmd and attempt to work out of hole. Weight indicator suggested plug was pulled but plug was not latched at surface. MU and RIH with jars and 4.5" GS spear to pull KB packer. Latched packer at 9606' ctmd. Hit 40 jar licks. Packer did not release. POOH for accelerator. ... Cant' on WSR 04/16/07 ... AWGRS 12-12 04/14/2007 CTU #8, Pull TTP/PM; MIRU unit. Pump 1.25" OD ball to drift new spool. Ball recovered. Perform weekly BOP test. MU and RIH with 2.0" OD JSN. ... Cant' on WSR 04/15/07 ... AVVGRS 12-12 04/12/2007 ** CONT FROM 4-11-07 WSR** (pre sdtrk) SET 1 1/2" RK- DGLV IN STA 10- 9487'MD. PULLED EMPTY C-SUB FROM 9584' SLM. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** !!!! TTP STILL IN HOLE!!!!! AWGRS 12-12 04/12/2007 T/IA/OA= 400/380/100 PPPQT-T (PASS) PPPOT-IC (PASS) ( PRE RWO) PPPOT-T (PASS) RU bled tool onto tubing head adapter test void. 100 psi bled to 0 psi, pressured to 5000 psi for 30 minute test. 4950/15 minutes, 4950/30 minutes. THA test void bled to 0 psi RD test equipment re installed Alemite. Cycled LDS all moved free with no bent or broke pins PPPOT-IC (PASS) RU bled tool onto IC test void 0 psi. Pressured IC void to 3000 psi for 30 minute test. 3000/ 15 minute, 3000/ 30 minute. Bled IC test void to 0 psi RD test equipment re installed Alemite. Cycled LDS all moved free with no bent or broke pins. AWGRS 12-12 04/11/2007 ***CONT FROM 04/10/06 WSR*** ( pre sidetrack) PULLED STATION#3 5/0 @ 6804 SLM. SET 1 1/2" RK- DGLV IN STA' 5, 3- 6804'MD, 2- 5095' MD, 6- 8711' MD. ** CONT ONTO 4-12-07 WSR** AWG,R,S 12-12 04/10/2007 ***WELL SHUT IN ON ARRIVAL*** (pre sdtrk) RAN 4.5 CENT,SAMPLE BAILER TO @ 9584 SLM. SOFT BOTTOM, RECOVERED ASPHALTINES. SET 5.5" WHIDDON CATCHER SUB @ 9584 SLM. ATTEMPT TO PULL 5/0 IN STA #3 @ 6806' MD. ***CONT ON 04/11/07 WSR*** AWGRS 12-12 04/09/2007 ***WELL 5/1 ON ARRIVAL ***(pre sdtrk) RAN 2 7/8" EQ.PRONG TO TT PLUG. TAG UP AT 9581'SLM, NO PSI CHANGE. RAN 2.15" CENT, 1.90" LIB TO 9581'SLM, OOH NO SIGN OF PLUG. RAN 2.25" PUMP BAILER TO 9581'SLM (BAILER FULL OF ASPHALTINES). JOB STOPPED DUE TO ENGINE FAILURE ON SWCP DC#7. ***WELL LEFT 5/1/ DSO NOTIFIED*** AWGRS 12-12 04/15/2007 A WG.KS 12-12 04/15/2007 http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 6/2812007 . 12-12A TREE = Cameron WELLHEA IJ3RA Y /McEvoy ACTUA TOR - Baker KB. ELEV = 70.84 BF. ELEV = 21.78 KOP- 3318' Max Angle = 98.81 Datum MD = Datum TVD = 8800' SS DRlG DRAFT 113-3/8" CSG, 72#, L-80, ID = 12.347" H I TOC on 7" Tieback H 2664' I 2765' I~ Minimum ID = 3.725" @ 10238' XN NIPPLE ÆRFORA TION SUMMARY REF LOG: BHCS ON 07/20/81 ANGLE AT TOP ÆRF: 38 @ 9906' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 9906 - 9926 0 06/15/98 2-7/8" 6 10031 - 10035 0 06/15/98 2-7/8" 6 10038 - 10041 0 06/15/98 3-118" 4 10041-10059 0 07/14/86 3-3/8" 4 10041 - 10059 0 12/03/90 3-118" 4 10064 - 10077 0 07/14/86 3-3/8" 4 10064 - 10077 0 12/03/90 3-3/8" 4 10084 - 10100 0 12/03/90 3-1/8" 4 10084 - 10162 0 02/13/84 8 10178 - 10218 S 11/15/90 8 10230 - 10250 S 11/15/90 3-3/8" 4 10358 - 10360 S 11/15/90 I PBTD H I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I.., 10870' I DATE 07/26/81 1 0/26/01 02/06/03 10/26/03 11/04/03 01/30/04 REV BY COMMENTS ORIGINAL COM PLETION RNlTP CORRECTIONS ATDITP DELETE WAIVER SAFETY NO CAOITLP PULL PATCH @ 7926' SVClTLP CORRECT SQZ'd ÆRFS 11/90 GJBITLP GL V C/O DATE 08/14/04 03/06/05 04/01/05 06/21/07 As-Drilled 10837' ~ REV BY COMMENTS LDKlTLP SET PACKER KSBITLH PKR XN NIPPLE CORRECT MGSITLH XN PLUG SET (03/07/05) CC As Drilled . 2217' H4-1/2" X Nipple (3.813" ID) S MD TVD DEV TYPE VLV LAT PORT DATE 5 3496 3492 17 KBG2 DMY BK 0 06/20/07 4 6166 5632 38 KBG2 DCK BK 0 06/20/07 3 7957 7043 35 KBG2 DMY BK 0 06/20/07 2 9069 7 43 KBG2 DMY BK 0 06/20/07 1 10104 57 KBG2 DMY BK 0 06/20/07 3213' 3213' 9-5/8" X 7" Baker ZXP Packer / Hanger W/11.61'PBR ID = 7.5" ID 10173' H4-1/2" X Nipple (3.813" ID) 10192' IÎ7" x 4-1/2" Baker S3 Production ,Packer 10217' H4-1/2" X Nipple (3.813" ID) 10238' H4-1/2" XN Nipple (3.725" ID) 10251' H4-1/2" WLEG 7",26#, L-80 Liner / Tieback (6.276" ID) \ troc I TOP OF 7" LNR H 11716' H4-1/2" Tam Swell Packer H -9,365' 9619' 9601' TOP OF 4-1/2" BKR KB BTM PKR (08/14/04) Stucked w /2-7/8" XN NIP, ID = 2.25" PLUG SET (03/07/05) 9651' H4-1/2" TUBING TAIL I 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9933' I 10030' H FISH - PATCH RUBBER & ELEMENTS I 10821' I FISH - (7) FINGERS F/KIN CALlÆR 1/8"X5/16"X1" I 1 0826' HFISH- GLV I PRUDHOE BAY UNIT WELL: 12-12 PERMIT No: '1810830 API No: 50-029-20610-00 SEC 18, T10N, R15E, 3639.14' FEL & 1237.52' FNL BP Exploration (Alaska) ......-. ,,- .._£.. "...-. ".........."-'1. .. .............. '-""''--'t''..... ...'--'.. .l ~'" .......l0 .l J.~bJ.\..t,..1I.J. '-, ~f Mehrdad, You know better of the well conditions. Main issue is placing cement proximate to the packer. 200' outside and 300' inside should do it nicely. Call or message with any questions. Tom Maunder, PE AOGCC Nadem, Mehrdad wrote, On 4/19/2007 3:16 PM: Tom, Based on my discussÎon with the Well Groups Operations on the Slope, we would like to slightly modified the pre rig work for 12-12. As discussed during our telephone conversations, AOGCC has no objection with proceeding with these modification: 1. C MIRU CTU. RIH to above the PBR assembly at 9,558' MD. With a tubing punch, punch 5' of holes in the tubing. Punch holes starting at - 9,500' MD- please note that tubing tally for the 5-1/2" is incomplete. As such, I am unable to determine whether the 9,500' would correspond to location of a tubing collar. 2. F Full bore circulate the IA and tubing to either seawater or KC!. 3. C Lay cement on top of the plug that is stuck in the tubing tail. This plug is set at 9,601'. Pump 12.51 of cement for the plug and abandon operations. This would leave 300' of cement in the tubing and -200' of cement in the 9-5/8" x 5.5" inner annulus. There is no concern if the top of cement is higher than 9,300' MD. The regulatory limit requires 100' of cement plug. 4. F CMIT X IA to 3500 psi for 30 minutes. 5. E Jet cut the tubing at 3800'. 6. 0 Set BPV, pull well house and level pad. Please call if you have any questions or comments. Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademm@bp.com sc;ANNED APR 2 0 2001 From: Thomas Maunder rmailto:tom maunder@admin.state.ak.usl Sent: Tuesday, April 17, 2007 1:37 PM To: Hobbs, Greg S (ANC) Subject: Re: 12-12A Revised Work Scope for Pre Rig Program 1 0£2 ~119/2007 3:38 PM .._ ...~£.. ..."-...." ..-.J........... "~11.'" ~""'vl...J"...... 1. VI. L I........ L'-J.6 L !VS~Ul.lt C""-~ l'hanks lÓr documenting (Treg. Tom "-' Hobbs, Greg S (ANC) wrote, On 4/17/2007 1 :28 PM: AII- Following the failed attempt to retrieve the plug from the tailpipe on 12-12 A with Coil, and discussions with Tom Maunder and Jay Grover, the following plan will be followed to ready 12-12 for its upcoming Sag Sidetrack: 1. C MIRU CTU. RIH to a point within a joint or two above the PBR assembly at 9558' MD. With a tubing punch, punch 5' of holes in the tubing. Circulate the IA and tubing to to 9.8 brine. Lay cement on top of the plug that is stuck in the tubing tail. Pump a 100' balanced plug through the holes so that there is 100' of cement outside and inside the tubing to abandon the perforated intervals below. 2. F CMIT X IA to 3500 psi. 2. E Jet cut the tubing at 3800'. 3. F Freeze protect the top -100' of the well with diesel (IA and tubing). 4. 0 Set BPV, pull wellhouse and level pad. I will add this to the pre rig schedule tommorrow. Please respond with any comments or questions. My cell is 980-1439. Greg 20f2 4/19/20073:38 PM I L-I Lrt ~C; V I::!C;U VV VII.\. ..J~VJ:1C; IVI r I C; I'\..ib r I Vbi aUi \-- ~ AII- Following the failed attempt to retrieve the plug from the tailpipe on 12-12 A with Coil, and discussions with Tom Maunder and Jay Grover, the following plan will be followed to ready 12-12 for its upcoming Sag Sidetrack: 1. C MIRU CTU. RIH to a point within a joint or two above the PBR assembly at 9558' MD. With a tubing punch, punch 5' of holes in the tubing. Circulate the IA and tubing to to 9.8 brine. Lay cement on top of the plug that is stuck in the tubing tail. Pump a 100' balanced plug through the holes so that there is 100' of cement outside and inside the tubing to abandon the perforated intervals below. 2. F CMIT X IA to 3500 psi. 2. E Jet cut the tubing at 3800'. 3. F Freeze protect the top -100' of the well with diesel (IA and tubing). 4. 0 Set BPV, pull well house and level pad. I will add this to the pre rig schedule tommorrow. Please respond with any comments or questions. My cell is 980-1439. Greg SCANNED APR 1 '1 2007 1 of 1 4/17/2007 1:37 PM . . SARAH PALIN, GOVERNOR A1tASIiA OILAlWD GAS CONSERVATION COmoSSION Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-12 Sundry Number: 307 -104 SCANNED APR 0 9 2007 of6?; \Cb \~ Dear Mr. Hobbs: 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. DATED thi~day of March, 2007 EncL ~ I STATE OF ALASKA _1"~? RECEIVED ALAS OIL AND GAS CONSERVATION COM~ON µ'I MAR 2 1 2007 APPLICATION FOR SUNDRY APPROVAL $' 20 AAC 25.280 ^1.u.lt.. nil & Gas Cons. Commlssl 1. Type of Request: ~ Abandon o Suspend o Operation Shutdown o Perforate o Time ExtensionAnchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit ToJrill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 181-083 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20610-00-00/ 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 12-12 r' Spacing Exception Required? DYes ~No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): / ADL 028330/ 71.0 I Prudhoe Bay Field / Prudhoe Bay Pool 120». > PRESENT WELL ·>ii»> ·U. ............. <.> » ... ... . Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10870 9471 10203 8967 9601' 10030',10821',10826' Casina Lenath Size MD TVD Burst Collacse Structural Conductor 80' 20" 110' 110' 1490 470 Surface 2664' 13-3/8" 2664' 2664' 4930 2670 Intermediate Production 9933' 9-518" 99:\3' 8758' 6870 4760 Liner 1251' 7" 9619' - 10870' 8502' - 9471' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9906' -10162' 8737' - 8935' 5-1/2" x 4-1/2", 17#x 12.6# L-80 9651' Packers and SSSV Type: 9-5/8" x 5-1/2" BOT Packer, 4-1/2" BKR KB BTM Packer, packers and SSSV MD (ft): 9578",9601',2195' 5-1/2" CAM BAL 0 SSSV 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina Ocerations: April 1 , 2007 DOil DGas D Plugged ~ Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that th~~g~~fis true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Name Greg b s Title Senior Drilling Engineer R~ ~ Prepared By Name/Number: Signature Phone 564-4191 Date Sondra Stewman, 564-4750 ." /IJ Commission Use Onlv , I Sundry Number: (~7 - / ¡)<.þ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity &Z{ BOP Test D Mechanical Integrity Test D Location Clearance Other: ?, SO O~c.;-\ \Sa \' \(:.~ \- Subsequent Form Required: ~0rð/; Date L3 .] Ð -If.?-- ~ ~OMMl5SIONER APPROVED BY Accroved Bv: THE COMMISSION Form 10-403 Revised 06/2006 V Submit In Duplicate " '00 ORIGINAL RSDMS 8ft. APR 0 3 2D01 . . Obp GL.AJr6rßy To: AOGCC Date: March 20, 2007 From: Mehrdad Nadem- BPXA GPB Rotary Drilling Subject: 12-12 Application for Sundry Approval- P&A for Sidetrack Operations Approval is requested for the proposed P&A of the 12-12. This well is currently shut-in due to TxlAxOA communication via multiple leaks. The new well is targeted to develop reserves in the Sag reservoir which is expected to recover 1,108 MBO. The parent well 12-12 has not been a full time producer since 2001. The well's remaining reserves value is less than 300 MBO and is not able to compete with more robust RWO candidates. Therefore, a sidetrack to the nearby Sag targets will enable recovery of the Sag reserves. 12-12 was completed in July of 1981 in upper Zone 4A and lower 4B. Production declined and by March of 1983 the well would not flow to the system. A channel was diagnosed from below the oil-water contact to the perforations. Five coil unit squeezes were performed before the well was returned to production in December of 1983 with perforations added to upper 4B. The original perforations were abandoned. In July of 1986 the oil rate increased to over 6,000 BOPD with the addition of upper Zone 4 perforations. A year later production had declined to 2000 BOPD, but as water apparently broke through, production jumped back up to 5,000 BOPD by September of 1987. Scale and increasing water cut became issues and the tubing was initially acidized and the well placed on gas lift in 1988. Over the next couple of years, additional acid washes and cleanouts were necessary because of scaling. By late 1990 the water cut was over 70% and the well was squeezed again to eliminate suspected channeling. The well was perforated again in upper Zone 4 only in preparation for a frac job. Initial frac rates were up at 4000 BOPD in August of 1991. The well declined to less than 500 BOPD by the end of 1994. Foamed acid was attempted in early 1993 without success. Once the hydrate and cleanout problems were solved, the oil rate was back up to 1000 BOPD following a second zone 4 frac (115K) in December of 1994. Annular problems began surfacing in early 1995 and the well was shut in for annular communication in January of 1998. The first patch was set in July of 1998 over a hole near GLM #4, but it immediately fell down the hole. A second patch was set but a second hole was located near the SSSV. The second patch was pulled in March of 2002 and reset in September of 2002, again unsuccessfully, due to additional leaks below gas lift mandrel (GLM's) 2 and 3. Significant corrosion was located in the pups below GLM's 5,6, 7, and 8 and the third patch had fallen to the bottom. A plan was in place to install a record 6200' patch over GLM's 2-10. The job was placed on hold due to the number of patch failures, and low likelihood for success. The plan is to exit the parent 12-12 well bore at -3,500' MD. A whipstock will be run and an 8-1/2" window will be milled in the 9-5/8" casing. An 8-1/2" hole will be drilled to the Top of the Sag River formation. A 7" drilling liner will be run, and will be fully cemented in two stages to the liner top. The 6-1/8" well bore then builds to horizontal, landing in the Sag. The planned well bore runs horizontally for approximately -2,270'. A slotted 4-1/2" production liner will be run with -150' liner lap into the 7" drilling liner. A 7" tieback will be run and partially cemented, if USIT results indicate corrosion, or annulus fill issues prevent cut and pull of the 9- 5/8" casing. . . Page 2 of 4 Mehrdad Nadem CC: Well file Terrie Hubble / Sondra Stewman Proposed Procedure Current Status: ~ Shut in. ~ T x IA x OA communication BHP - 3,200 psi @ 8,800 ft TVD MASP - 2,320 psi = (3,200 psi - (0.1 psi/ft * 8800ft)) Pre-RiQ Operations: 1. SLICKLlNE: Replace all live gas lift valves with dummy valves, and fluid pack as necessary for coil tubing P&A. 2. SLlCKLINE: Pull the tubing tail plug set in the 2-7/8" 'XN' nipple in the 9-5/8" X 5-1/2" Baker packer at 9,601' MD. 3. SLlCKLlNE: Drift the tubing to confirm and tag top of cement. Top of cement is expected to be at 10,101' MD. 4. Coil: P&A the 12-12 well bore. Lay in -26 bbls of 15.8 ppg cement, leaving top of cement in the 5-1/2" tubing at -9,260' MD. Cement volumes may have to be adjusted based on PBTD from step 3. 5. WIRELlNE: Jet cut the tubing at 3,800' MD with the appropriate jet cutter. 6. OTHER: CMIT T x IA to 3,500 psi for 30 minutes. MIT OA to 2,000 psi for 30 minutes. 7. OTHER: Circulate well with sea water and freeze protect to 2,200' MD. 8. OTHER: Bleed casing and annulus pressures to zero. 9. OTHER: Function all tubing and casing lock down screws. Repair and replace as necessary. PPPOT-IC and PPPOT-T 10. OTHER: Set a SPY. Remove well house and flow line. Level the pad as necessary. Ria Operations: 1. MI / RU Nabors rig 27E. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. 3. Pressure test CMIT TxlA to 3,500 psi for 30 minutes. 4. Pressure test the OA to 2,000 psi for 30 minutes. 5. Set TWC and test from below to 1,000 psi. 6. Nipple down tree. Nipple up and test BOPE to 3,500 psi. Pull TWC. 7. R/U. Pull 5W' tubing from the cut at -3,800' MD and above. 8. R/U E-line. M/U 8-1/2" gauge ring / junk basket / casing collar locator (CCL). RIH and tag tubing stump at -3,800' MD. POOH. 9. On E-line, run USIT/CBL from surface to the tubing stump at 3,800' MD. USIT should be set in both cement and corrosion modes. 10. Determine the depth of the 9-5/8" casing cut based on USIT results. If it is determined that it is not operationally feasible to cut and pull the 9-5/8" casing, or if USIT results show corrosion in the 9-5/8" casing below the surface shoe, then a 7" tieback will be run to surface. A contingency plan for running a tieback assembly will be attached to the Drilling and Completion Plan. 11. On E-Line with CCL and string shot assembly. Fire shots at the collar to be backed off. 12. On E-line, RIH with HES EZSV. Set bridge plug at -3524', as required to avoid cutting a casing collar while milling the window. POOH. R/D E-line. 13. Pressure-test the 9-5/8" casing to 3,500 psi for 30 minutes. Record test. 12-12 Application for Sundry -<:~' r fJ ð' ....... ~.) . . Page 3 of 4 14. MU a Baker 9-5/8" multi string cutting assembly. RIH and cut the 9-5/8" casing in the middle of joint per Baker representative instructions. 15. POOH, UD multi string cutting assembly. 16. Change out to 9-5/8" rams, and test. 17. Back out lock down screws, RU/MU casing spear assembly, and unseat the 9-5/8". Circulate the Arctic Pack from the annulus with warm diesel followed by seawater and detergent sweeps. Continue circulating until getting clean returns. Displace the well to 9.8 ppg brine. 18. Pull the 9-5/8" casing from the cut. 19. MU Baker wash-over assembly per Baker Oil Tools representative. 20. RIH, and wash over the 9-5/8" stub. POOH, UD the assembly. 21. RU Baker back-off assembly, RIH, and back off the 9-5/8" casing joint. POOH. UD the back off assembly. 22. MU Baker casing spear assembly. RIH and recover the cut 9-5/8" casing stub. 23. MU 13-3/8" casing scraper and 12-1/4" mill assy. RIH to the top of the 9-5/8" stub. POOH. UD assy. 24. Pressure test the 13-3/8" and 9-5/8" casing to 1,000 psi for 30 minutes. 25. MU 9-5/8", 40#, L-80, TCII with ES Cementer and screw-in-sub with one centralizer on each joint above the ES Cementer. 26. RIH and screw in tie back casing. Pull test to 250K. Maintain hook load and pressure test to 2000 psi. 27. RU and test cement lines. Pressure up to open the ES Cementer, and cement the 9-5/8" x 13-3/8" OA with 15.8 ppg Class G. Ensure ES cementer closed. ,"~cl<;.\- c;.\' ~s 28. Split stack. Cut casing with WACHS cutter. LD excess casing. Install VETCO Gray primary pack off per Cameron rep. Install new Cameron tubing spool and Cameron wellhead per Cameron Rep. Test pack off to 2400 psi for 30 minutes. 29. NU BOP, and test to 3500 psi high and 250 psi low. RU and test the rams. 30. RIH and tag cement and ES cementer with 8-1/2" bit, boot basket, and jars, circulate 110'F seawater until cement reaches 1,500 psi compressive strength Per Schlumberger Rep. Circulate clean. 31. Drill cement and ES Cementer. Test casing to 3,500 psi for 10 minutes. Drill the baffle plate. Continue to RIH to EZSV. Circulate sweep. 32. RU test equipment. Circulate bottoms up. Test casing to 3,500 psi for 30 minutes. POOH 33. P/U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly on 4" DP. Orient whipstock, as desired, and set on bridge plug. Shear off of whip stock. 34. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning millin operations. 35. Mill window in 9-5/8" casing at + , well bore clean. 36. Pull up into 9 5/8" casing and conduct an FIT to 12.1 ppg EMW. POOH. 37. M/U 8%" Dir/GR assembly. RIH, kick off and drill the 8W' intermediate section with 9.0 ppg LSND. 38. At approximately 100' above the THRZ weight up the system to 11.5 ppg with spike fluid from the MI plant. 39. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate well clean, short trip to window. POH. 40. Run and cement a 7", 26#, L-80, BTC-M intermediate drilling liner. Cementing will be done in two stages. Test to 3,500 psi for 30 charted minutes. 41. Dress casing stub and install packoff and tubing spool. NU and test BOPs 42. M/U the first 6-%" Dir/GR/Res assembly with an insert bit. 43. RIH to the 7" tie-back landing collar. Drill out the 7" tie-back cement. 44. RIH to the 7" liner landing collar. Drill out the 7" liner float equipment and cement to the shoe. 45. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 46. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 9.0 ppg EMW. 47. 24 degree dog legs will be required below the 7" shoe to minimize the distance the wellbore is out of the target Sag River formation. 12-12 Application for Sundry . . Page 4 of 4 4B. Once the well is landed in the Sag River, POH and PU the second 6- Ys" BHA with a PDC bit and ABI/GR/Res/AZDensity, StrataSteer processing will also be utilized through this section. Drill ahead to planned TD. 49. Circulate well bore clean, short trip to shoe, circulate. POOH. 50. Run a 4%",12.6#, L-BO, IBT-M slotted production liner. POOH laying down DP. 51. R/U and run a 4%", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4%" liner tie back sleeve. 52. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 53. Set a BPV. 54. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. 55. Freeze protect the well to -2,200' TVD. Secure the well. 56. Rig down and move off. Post-Rica Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. 12-12 Application for Sundry . GRAY GEN2 TREE = SAOTES: PATCH SET ACROSS HOLE IN TBG WB.LHEAD = GRAY 12-12 ACTUATOR-, AXB.SON @ 7939', IA X OA COMMUNICATION TO AL GAS. KB. B.6.V - 71' BF. B.EV = KOP= 3100' Max Angle = 42 @ 10783' 2195' 5-1/2" CAM BAL-O SSSV NIP, ID = 4.56" Datum MD - 10078' . 5-1/2" CAMCO DSSSV, ID = 3.025" (09/12/02) Datum ND = 8800' SS GAS LIFT MANDR8.S ST MD ND DEV TYÆ VLV LATCH PORT DATE 113-3/8" CSG, 72#, L-80, ID = 12.347" I 1---4 ~ 1 2896 2896 4 CAMCO DOME RK 0 01/30/04 2664' 2 5095 4803 39 CAMCO OÆN RK 0 01/30/04 3 6806 6151 38 CAMCO S/O RK 24 L 4 7939 7059 35 CAMCO DMY RK 0 5 8636 7645 31 CAMCO DMY RK 0 Minimum ID = 2.25" @ 9601' 6 8711 7710 31 CAMCO OÆN RK 0 01/30/04 2-7/8" XN NIPPLE IN BKR PKR 7 9108 8056 28 CAMCO DMY RK 0 8 9182 8122 29 CAMCO DMY RK 0 9 9412 8323 28 CAMCO DMY RK 0 10 9487 8389 30 CAMCO OÆN RK 0 01/30/04 l I 9558' 1-15-112" BOTPBRASSY I J ~ 2S 9578' H9-5/8" x 5-1/2" BOT PKR I 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I 9588' I I 9588' 1-15-1/2" x 4-112" XO I 1 TOP OF 4-1/2" TBG-PC I \ 9588' I I 9601' TOP OF 4-1/2" BKR KB BTM PKR(08/14/04) TOPOF7" LNR I 9619' - 11II I w /2-7/8" XN NIP, ID = 2.25" PLUG SET (03/07/05) I . 9648' 1-14-1/2" CAM DB LANDING NIP, ID = 3.81" I I 9650' 1-14-1/2" BOT BULLNOSE SHEA ROUT SUB I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9651' I ~ H4-1/2" TUBING TAIL I I ~I 9651' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9933' ... J----4 ÆRFORA TION SUMMARY : REF LOG: BHCS ON 07/20/81 ANGLE AT TOP ÆRF: 38 @ 9906' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9906 - 9926 0 06/15/98 2-7/8" 6 10031 - 10035 0 06/15/98 -, 2-7/8" 6 10038 - 10041 0 06/15/98 10030' H FISH - PATCH RUBBER & B.EMENTS I 3-1/8" 4 10041 - 10059 0 07/14/86 3-3/8" 4 10041 - 10059 0 12/03/90 3-1/8" 4 10064 - 10077 0 07/14/86 I 3-3/8" 4 10064 - 10077 0 12/03/90 3-3/8" 4 10084 - 10100 0 12/03/90 3-1/8" 4 10084 - 10162 0 02/13/84 II 8 10178 - 10218 S 11/15/90 8 10230 - 10250 S 11/15/90 3-3/8" 4 10358 - 10360 S 11/15/90 l----i. 10821' ~ FISH - (7) FINGERS F/KIN I CALlÆR 1/8"X5/16"X1" IPBTD I 10837' r---r 10826' 1-1 FISH- GLV I I I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 10870' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/26181 ORIGINAL COM PLETION 08/14/04 LDKlTLP SET PACKER WB.L: 12-12 10/26/01 RNlTP CORRECTIONS 03/06/05 KSBfTLH PKR XN NIPPLE CORRECT ÆRMIT No: "1810830 02106/03 A TDfTP DB.ETEWArvERSAFETY NOTE 04/01/05 MGSfTLH XN PLUG SET (03/07/05) API No: 50-029-20610-00 10/26/03 CAOfTLP PULL PATCH @ 7926' SEC 18, T10N, R15E, 3639.14' FB. & 1237.52' FNL 11/04/03 SVO'TLP CORRECT SQZ'd ÆRFS 11/90 01/30/04 GJBfTLP GL V C/O BP Exploration (Alaska) TREE'; '" 8RA Y GEN 2 WELLHEAD = GRAY ACTUATOR=, AXELSON KB. ELEW = 71' BF. ELEV = KOP= 3100' Max Angle = 42 @ 10783' Datum MD = 10078' Datum lVD = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2664' Minimum ID = 3.725" @ 10176' XN NIPPLE 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9933' ÆRFORA TION SUMMARY REF LOG: BHCS ON 07/20/81 ANGLE AT TOP ÆRF: 38 @ 9906' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2-7/8" 6 9906 - 9926 0 06/15/98 2-7/8" 6 10031 - 10035 0 06/15/98 2-7/8" 6 10038 - 10041 0 06/15/98 3-1/8" 4 10041 - 10059 0 07/14/86 3-3/8" 4 10041 - 10059 0 12/03/90 3-1/8" 4 10064 - 10077 0 07/14/86 3-3/8" 4 10064 - 10077 0 12/03/90 3-3/8" 4 10084 - 10100 0 12/03/90 3-1/8" 4 10084 - 10162 0 02/13/84 8 10178-10218 S 11/15/90 8 10230 - 10250 S 11/15/90 3-3/8" 4 10358 - 10360 S 11/15/90 1 PBTD H 10837' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 10870' DATE 07/26/81 10/26/01 02/06/03 10/26/03 11/04/03 01/30/04 REV BY COMMENTS ORIGINAL COM PLETION RNITP CORRECTIONS ATD/TP DELETE WAIVER SAFETY NO CAOffiP PULL PATCH @ 7926' SVC/TlP CORRECT SQZ'd ÆRFS 11/90 GJBffiP GL V C/O DATE 08/14/04 03/06/05 04/01/05 12-12A S OTES: PATCH SET ACROSS HOLE IN TSG @ 7939'. lAX OA COMMUNICATION TO AL GAS. Proposed Completion 2,200' - 4-1/2" X Nipple (3.813" ID) GAS LIFT MANDRELS ST MD lVD DEV iYÆ VLV LATCH PORT DATE 1 2 3 4 5 3,500' 9-5/8" X 7" BKR ZXP PKR/HGR 10,116' - 4-1/2" X Nipple (3.813" ID) 10,136' -7" X 4-1/2" BKR S3 Packer 10,156' - 4-1/2" X Nipple (3.813" ID) 10,176' 4-1/2" XN nipple (3.725" ID) 10,196' - 4-1/2" WLEG 10,346' - 7",26#, L-80 liner 4-1/2", 12.6#, L-80, Slotted Liner - 12,633' TOPOF 7" LNR H 9619' 9601' I TOP OF 4-1/2" BKRKB BTM PKR(08/14/04) w 12-7/8" XN NIP, ID = 2.25" PLUG SET (03/07/05) 9651' H4-1/2" TIJBING TAIL I 10030' H FISH - PATCH RUBBER & ELEMENTS 10821' I FISH - (7) FINGERS F/KIN CALlÆR 1/8"X5/16"X1" 10826' HFISH- GLV I REV BY COMMENTS LDKlTLP SET PACKER KSBffiH PKR XN NiPPlE CORRECT MGSffiH XN A..UG SET (03/07/05) PRUDHOE BAY UNrr WELL: 12-12 ÆRMrr No: '1810830 API No: 50-029-20610-00 SEC 18, T10N, R15E, 3639.14' FEL & 1237.52' FNL BP Exploration (Alaska) Re: DS 12-12 . . Mehrdad, I am finishing my review of the sundry. Thanks for your response. One comment ... With regard to the fluid in the IA below the cut. The fluid left in abandoned portions of wells must exceed the hydrostatic of formations between plugs. See 20 AAC 25.112 (t). Crude should not be left below the planned depth of your tubing cut. Call or message with any questions. Tom Maunder, PE AOGCC Nadem, Mehrdad wrote, On 3/27/2007 1 :29 PM: Tom, This Email is a follow up to our discussions earlier today regarding Sundry Application for 12-12. Below, please find my response to your questions. Thank you for your comments. ¡look forward to continue working with you, and very much appreciate you time. Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademm@bp.com 1. In Step 3, you indicate that a "top of cement" might be tagged at 10100', however that does not agree with the drawing you have provided showing the existing well. Would you please confirm the depth? You note that the cement volume might need to be adjusted (step 4). it appears that considerable amount of fill has settled in the 7" casing since the well was drilled. It is also conceivable that the fill contains some cement left behind during the coil tubing squeeze operations. The top of fill could be as high as 10,089'. To confirm the top of the fill, I have requested tagging the TO before laying cement for the plug and abandon operation. The schematic that I attached to the Sundry Application shows the PBTO when the we!1 was initially completed. 2. In Step 6 you plan to perform a CMIT T x IA and an MIT OA. Is it expected that these tests will pass to fluid? Do any tests from Problem Wells show a leak loss rate? Similar tests are proposed after the rig arrives. MIT-OA has passed a number of times, the last test was performed on March 12, 2007. CMIT- TxlA passed to 2,000 psi on April 24,2004. The reason for duplicating the MIT-OA and CMIT TxlA is to comply with BP's Barrier Policy. 10f2 3/28/2007 10:46 AM Re: DS 12-12 . . . . 3. Has the IA been recently circulated between the packer and where you plan to cut? It is proper to have fluid with known properties in this space. On August 15, 2004 415 barrels of crude was pumped down the IA. 4. Step 24 of rig procedure tests the 9-5/8" and 13-3/8" casing. I presume that if earlier tests have failed badly that the 7" tieback scenario will come into play. In either case, I believe the upper portion of the 9-5/8" casing will be replaced. Although an outer annulus re-pressurization test (OART) passed on April 17, 2005. The Pad Engineer suspects that there is a preferential leak to gas most likely through the buttress threads of the 9-5/8" casing. We would like to cut and pull the 9-5/8" casing above the 13-3/8" surface casing shoe based on USIT results. We could run a 7" tieback independent of the 9-5/8" casing, and could change the well head without cutting and pulling the 9-5/8" casing, although this is not a preferred option. We will make all efforts to replace the 9-5/8' casing with a new string of 9-5/8",47#, L-80 with TC-II connections. We plan to cement the 9-5/8" x 13-3/8" annulus to surface. 5. Step 28, I believe you will need to set slips prior to cutting off. Yes. In fact ¡ had ordered the slips over a week ago. Per your comment, ¡ will include a line noting setting of the slips. ¡ am meeting with Cameron reps on Thursday to develop a detailed program for changing the wellheads for inclusion in the Drilling and Completion Program. 20f2 3/28/2007 10:46 AM STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ SET PATCH Pull tubing _ Alter casing _ Repair well _X Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development mX ExploratoryM StratigraphicM Service._ 4. Location of well at surface 4265' FNL, 751' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 1798' FNL, 3429' FEL, Sec. 18, T10N, R15E, UM At effective depth 1728' FNL, 3462' FEL, Sec. 18, T10N, R15E, UM At total depth 1214' FNL, 3647' FEL, Sec. 18, T10N, R15E, UM (asp's 696843, 5931326) (asp's 694093, 5933723) (asp's 694057, 5933792) (asp's 693857, 5934301) 12. Present well condition summary Total depth: measured true vertical 10870 feet Plugs (measured) 9467 feet Effective depth: measured true vertical 10030 feet Junk (measured) 8834 feet Casing Length Conductor 80' Surface 2636' Intermediate 9905' Liner 1251' 6. Datum elevation (DF or KB feet) RKB 91 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-12 9. Permit number / approval number 181-083 10. APl number 50-029-20610-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Size Cemented Measured Depth True Vertical Depth 20" 300 sx Permafrost 110' 110' 13-3/8" 2750 sx Fondu, 400 sx 2664' 2664' PF 9-5/8" 500 sx Class 'G' 9933' 8758' 7" 300 sx Class 'G' 9619' - 10870' 8502' - 9467' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 9906-9926, Perfs Below Fish 10031-10035, 10038-10059, 10064-10077, Perfs Below Fish (continued) 10084-10162, 10178-10218, 10230-10250, 10358-10360 true vertical Open Perfs 8737-8753, Perfs Below Fish 8835-8838, 8840-8856, 8860-8870, Perfs Below Fish (continued) 8875-8935, 8948-8978, 8987-9003, 9085-9087 5-1/2", 17#, L-80, TBG-PC @ 9588' MD; 5-1/2" x 4-1/2" XO @ 9588' MD. 4-1/2", 12.6#, L-80 TBG-PC 9651'. Eclipse Retrievable Patch ~7~ E ~ V ED 9-5/8" x 5-1/2" Baker Packer @ 9578'. 5-1/2" Camco BAL-O $SSV Nipple @ 2195' MD. 13. Stimulation or cement squeeze summary 0CT 0 Zi 2002 Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ,~l~as~l 0il & Gas ¢~ns. ~mmissl0n 14. Representative Daily Averaqe Production or Injection Data /~llcll0rage Prior to well operation Shut-In Subsequent to operation Shut-in OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~X Gas ~ Suspended ~ Service 17. I hereby certif7 that the foregoing is true and correct to the best of my knowledge. ,~~~~;~ ~~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date September 16. 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 12-12 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/21/2002 09/06/2002 09/11/2002 09/11/2002 09/12/2002 09/12/20O2 09/1 2/2002 09/15/20O2 PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING SECURE WELL: / LINER: PATCH TUBING / CASING / LINER: PATCH TUBING / CASING / LINER: SSSV C/O OR STROKE / LINER: MIT-IA / LINER: AC-FLUID LEVEL / LINER: MIT-IA / LINER: SSSV C/O OR STROKE AC-MITOA EVENT SUMMARY 08/21/02 DRIFT W/4.50 CENT 5 1/2 BL BRUSH! BRUSHED FROM 7850' TO 7975'. DRIFT WITH DUMMY PATCH 4.55" OD 26'7" OAL TO 8100' SLM. (WELL LEFT SHUT-IN). 09/06/02 SET ECLIPSE RETRIEVABLE PACKER. SET LOWER PACKER ASSY @ 7960' - CCL TO ELEMENT 15.5'- SET UPPER PACKER ASSY. @ 7930'- CCL TO ELEMENT 15.5' - TOP OF PATCH @ 7926' - LEFT WELL SHUT IN. 09/11/02 DRIFT TO SSSV NIP. - ATTEMPT TO SET 5-1/2" DUMMY SSSV. 09/11/02 MIT-IA TO 3000 PSI WITH 205 BBLS CRUDE. MIT-IA PRESSURE TEST FAILED. 09/12/02 IA FL FOR SLICKLINE IA FL @ 1040'. 09/12/02 SET 5-1/2" CAMCO DUMMY SSSV (STANDARD PKG, OAL 80" OD OF NO-GO 4.63", ID 3.025"). ******WELL LEFT SI.****** 09/12/02 PUMP 212 BBLS CRUDE DOWN IA. NEVER PRESSURED UP. 09/15/02 MITOA TO 2400 PSI (PASSED) Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL. 417 CRUDE 6.7 DIESEL 423.7 TOTAL Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner ~a~ Tom Maunder, ~ P. I. Supervisor'-" FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: May 7, 2001 Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday. May 7. 2001: I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The .surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment aPpeared to be in good condition. Summa.fy.: I witnessed the semi annual SVS testing at BPXs 'Drill Site 12. PBU DS t 2, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhoUse inspections Attachment: SVS PBU DS 12 '5-7-01 CS .X Unclassified Confidential (Unclassified if doc. removed ) Confidential' SVS PBU DS 12 5-7-01 CS Ai~i's~ta Oil and Gas Conservation Commiss.on Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Pmdhoe / PBU / DS 12 Separator psi: LPS 160 HPS 5/7/01 Well "" '. '"'" ' Pilots Retest ' Well Typ~ ' ' ' Data'",. i. "' · ''.. ' $$V S$$V . . . . , . ..': II I I I I I I I1 Well Permit Separ Set L/P Test Test Test Date oik WAG, GI~J, Number Number PSI PSI Trip Code Code Code Passed GAS orCYCLE , 12-01 1790230 , i , 12-02 1790320 , , 12-03 1790410 160 150 150 P P OIL , , , 12-04A 1811870 160 150 150 P P OIL 12-05 1790550 12-06A ' 1920540 ' 160 150 150' P p ' oIL . . 12-07A 1811750 160 150 140 P P OIL 12'08B 1811670 160 150 140 P P 'OIL .12-09 1800930 160 150 125 P P OIL , ~12-'10A 1920890 160 150 150 p P OIL . 12-11 1810730 .~.'.1,~,~;- 1810830 160 150 90 P 4 OIL 12-13B ' 1960170 160 ' 150 '150 p p ' 0IL 12-14A 1981460 160 150 150 P p OIL 12-15 ' 1830320 160 150 150 P P 'OIL 12-16A 19314S0, ''.160 lS0 150 V P ,, , ., Oil 12-17 1830040 160 150 150 P P OIL 12-18 ' '1822060 160~ 150 150 P P' ' OIL . 12-19 1821980 :12-20 1821910 112-21 1840480 ...... 12-22 ' 1840600 160 150 '" 125 P p OIL. , . 12-23 1840580 12-25 1831660 12-26 1840140 "'160 150 '125 p p '0IL . 12-27^ 1990390 12-28A 199033~i ' 160 ' 150 " 170 ' P P "' OIL i I I . i2-29 1840320 12-30 188'1420 ..... ~ . 12-31 1890010 12-32 1890110 160 150 150 P P OIL 12-33 1890100 12-34 'i941370 'i60 150 '150 ' P' P ' ' OIL, . , 12-35 1951300 160 150 1001 12-36 1951580 160 150 150 P P OIL RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-~l~C_S Number Number ! PSI PSI Trip Code ] Code ] Code ] Passed | GAS orCYCLE Wells: 21 Components: 42 Failures: 1 Failure Rate: 2.$8% [-] 90 Day Remarl~: Surface Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulatem Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1015' N & 751' W of SE cr, Sec 18, T10N, R15E, UM. At top of productive intewal: 3609' N & 3437' W of SE cr, Sec 18, T10N, R15E, UM. At effective depth: 3609' N & 3437' W of SE cr, Sec 18, T10N, R15E, UM. At total depth: 4067' N & 3662' W of SE cr, Sec 18, T10N, R15E, UM. 12. Present well condition summary Total Depth: measured 10870 feet true vertical 9396 feet Effective Depth: measured 10100 feet true vertical 8887 feet Casing Length Size Conductor 80' 20" Surface 2593' 13-3/8" Production 9862' 9-5/8" Liner 1251' 7' 5. Type of Well: Development _X Exploratory _ Stratagrapic _ Service _ 6. Datum of elevation (DF or KB feet): 71' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 12-12 ' 9. Permit number/approval number: 81-83 10. APInumber: ""~'" "' 50-029-20610 11. Field/Pool: Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 300 Sx Permafrost 80' 80' 2750 Sx Fondu & 2664' 2664' 400 Sx PF 500 Sx Class G 9933' 8758' 300 Sx Class G 10870' 9396' Perforation Deplh measured 9906-9926';10031-10033';10038-10059';10064-10077';10084-10100' true vertical 8737 - 8753'; 8835 - 8836'; 8840 - 8856'; 8860 - 8870'; 8876 - 8888' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 9588' MD; 4-1/2", 12.6#, L-80, PCT Tail @ 9651' MD Packers and SSSV (type and measured depth) BOT Packer @ 9578' MD; 5-1/2" Camco BaI-O SSSV @ 2195' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) seeaffached 14. Re@resentitive Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation 387 2094 3018 Subsequent to operation 460 2517 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~"~ '~. ~ Title: Engineering Supervisor 3451 Casing Pressure Tubing Pressure 282 264 J16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ Form 10-404 Rev 06/15/88 SUBMITIN DUPLICATE 12-12 DESCRIPTION OF WORK COMPLETED PERFORATING & TUBING PATCH INSTALLATION 4130/98: Performed a Leak Detection Log & identified a leak present in Station #4 mandrel at 7939' MD. 6/15/98: RIH w/perforating guns & shot Add Perforations at: 9906 - 9926' MD (Sag) Ref. Log: BHCS 7/20/81. 10031 - 10033' MD (Z4) 10038- 10041' MD (Z4) Used 2-7/8" carriers & shot the perfs at 6 spf at 60 degree phasing at underbalanced pressures. POOH w/perf guns. Noted ASF. RD. 8/21/98: RIH w/2.992" ID retrievable AVA DWP Tubing Patch & set the patch at 7932' MD (top element) to isolate the mandrel leak (above). POOH. RD. Returned the well to production w/gas lift & obtained a valid production test. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: David John..~~,. Chairma~ ~" ' Blair Wondzell,-~ P. I. Supervisor John Spaulding,~_/L Petroleum Inspf"'"' DATE: FILE NO: SUBJECT: August 20, 1995 1E9LTHCD.doc No Flow Test ARCO Prudhoe Bay Unit Well 12-12 Prudhoe Oil Pool Sunday 'August 20,1995:; I witnessed'the No Flow Test on ARCO's PBU well 12-12. The artificial lift gas was shut (~ff 24 hours prior to the test and the production tubing was de-pressured to an upright tank.open to the atmosphere, thru a 2" line. Upon my arrival the pressures were as follows; inner annulus 25 psi, tubing pressure 100 psi. The production tubing was bled down to a positive press in 15 minutes. · inner annulus - 25psi · tubing - positive pressure · 120 scf/hour gas I hour · inner annulus- 25 psi tubing - positive pressure 90 scf/hour gas 1 hour · inner annulus- 25 psi · tubing - positive · 90 scl/hour gas Well 12-12 is well within the AOGCC guidelines for No Flow status. I recommend the AOGCC consider ARCO's PBU well 12-12 for No Flow status. Summary' I witnessed the No Flow test on ARCO's PBU well 12-12 Attachments: STATE OF ALASKA ALASKA(' _AND GAS CONSERVATION C~" ~IlSSlON REPORT UF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Ot~er 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1015' N & 751' Wof SEcr, Sec. 18, T10N, R15E, UM At top of productive interval 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At effective depth 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At total depth 4067' N & 3662' W of SE cr, Sec. 18, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED Nasta ~ii & ~as Cons. .... , ~o~e 12. Present well condition summary Total depth: measured 10870 feet Plugs(measured) true vertical 9396 feet Effective depth: measured 10100 feet true vertical 8887 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 300 sx Permafrost Surface 2593' 13-3/8" 2750 sx Fondu & 400 sx PF Production 9862' 9-5/8" 500 sx Cl G Liner 1251' 7" 300 sx Cl G 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-12 g. Permit number/approval number 81-83 10. APl number 50 - 029-20610 11. Field/Pool Prudhoe Bay Oil Pool feet Measured de~h True ve~ical de~h 80' 80' 2664' 2664' 9933' 8758' 10870' 9396' Perforation depth: measured 10041-10059'; 10064-10077'; 10084-1'0100' true vertical 8842-8856'; 8860-8870'; 8876-8887' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9588' MD; 4-1/2", 12.64t, L-80, PCT tail @ 9651' MD Packers and SSSV (type and measured depth) BOT packer @ 9578' MD; 5-1/2", Camco BaI-O SSSV @ 2195' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaqe Production or Injection Dar; OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 467 329 1669 - Subsequent to operation 1056 494 4190 Tubing Pressure 365 383 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations .. Oil X Gas Suspended, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Title Engineering Supervisor GSS cc: KZ, JWP SUBMIT IN DUPLICATE 12-12 DESCRIPTION OF WORK COMPLETED HYDRAULIC REFRACTURE TREATMENT OF ZONE 4 1211194: RIH & tagged PBTD at 10096' MD. 12120/94: MIRU & PT equipment to 8000 psi. Pumped a Hydraulic Fracture Treatment using 12/18 mesh proppant, through the open perforations located above the sand plug at. 10041 - 10059' MD (Z4) 10064 - 10077' MD (Z4) 10084- 10100' MD (Z4) Ref. Log: BHCS 7/20/81. Pumped: a) 400 bbls 20# Pre-Pad Gel @ 30 bpm, followed by b) Shutdown. ISIP @ 600. Resumed pumping: c) 840 bbls Pad @ 30 bpm, followed by d) 570 bbls Crosslinked Slurry w/proppant stages @ 2 - 12 ppg, followed by e) 233 bbls Flush, followed by f) Shutdown. Placed a total of 115,000 lbs of proppant into the formation. Rigged down. 1/14/95: RIH w/CT & jetted a proppant fill cleanout to 10065' MD. 2/1 0/95: RIH w/CT & jetted a nitrified proppant fill cleanout to 10141' MD. Returned the well to production w/gaslift & obtained a valid production test. RECEIVED MAR 1 4 1995 Oil & Gas Cons. Commission STATE OF ALASKA ALASKA (' . AND GAS CONSERVATION C(~'" 'llSSION REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2242' FNL, 930' FWL, Sec. 22, T10N, R15E, UM At top of productive interval 1500' FSL, 1734' FWL, Sec. 15, T10N, R15E, UM At effective depth At total depth 1650' FSL, 1909' FWL, Sec. 15, T10N, R15E, UM 12. Present well condition summary Total depth: measured Effective depth: 5. Type of Well Development Exploratory Stratigraphic RECEIVED MAR -7 1995 true vertical measured 10258 feet true vertical 9014 feet Junk(measured) 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 17-7 9. Permit number/approval number 81-66 10. APl number 50 - 029-20596 11. Field/Pool Prudhoe Bay Oil Pool feet Alaska 0il & Gas Cons. Commission 10790 feet Plugs(~~ed) PBTD @ 10258' MD (10/23/94) 9512 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 232 sx AS II 80' 80' Surface 2616' 13-3/8" 3000 sx Fondu & 850 sx PF II 2687' 2687' Production 9891' 9-5/8" 500 sx Cl G 9962' 8742' Liner 1133' 7" 420 sx Cl G 10790' 9512' Perforation depth: measured 10026-10046'; 10148-10188'; 10202-10242'; 10257-10267' true Vertical 8801-8819'; 8911-8948'; 8961-8999'; 9013-9022' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 @ 9580' MD; 4-1/2", 12.6~, N-80, PCT tail @ 9644' MD Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2178' MD; Baker SAB packer @ 9567' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Shut In Subsequent to operation 769 702 5973 - Tubing Pressure 250 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. ...Signed Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 cc: KZ, JWP SUBMIT IN DUPLICATE .~. 17-7 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 715/94 · Ran a leak detection log indicating a leak was present at 9483' MD, at GLM #10. I O/23/94- RIH & tagged PBTD at 10258' MD. I 0/29/94- MIRU & PT equipment. RIH w/perforating gun & shot 20' of reperforations at: 10026 - 10046' MD (Sag) Ref. Log: BHCS 6/4/81. Used a 2-1/8" carrier & shot 4 spf at 180 degree phasing at overbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. I 1/16/94' Performed a leak detection log indicating a leak was present at the 5-1/2 x 4-1/2" crossover at 9580' MD, just below the production packer. 11/29/94 - 1 2/2/94: RIH w/5-1/2" Repeta Packer w/2-7/8" tail assembly & set assembly at 9560' MD (middle of packer element). Ran & set PXN plug in 2-7/8 tail & PT tubing to 3000 psi OK. POOH leaving top of packoff assembly at 9550' MD. Rigged down. 1/9/95: MU & RIH w/5-1/2" Repeta Tubing Patch w/2-7/8" tubing & sealbore extension, and stabbed into the lower packer receptacle (above) to complete straddle assembly across leaking GLM #10. POOH leaving straddle top packer set at 9447' MD (middle of packer element) & top of patch at 9445' MD. Patch minimum ID is 2.25" XN nipple at 9566' MD. Rigged down. 1/13/95: PT tubing/patch assembly to 3000 psi OK. I I1 6/95: RIH & retrieved the PXN plug from the 2-7/8" tubing tail. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED MAR -7 1995 At~s~ Oil & Gas Cons. Commission Anch0m",~ ARCO Alaska, Inc. Date: September 20, 1994 P.O. Box 100360~' 1chorage, AK Transmittal #: 94111 Subject: ARCO Static Pressure Survey's From/Location: Telephone: To/Location: Karla Zuspan/ATO-1529 (907) 263-4310 Distribution wo~ilo.i!Tool Type ii Flun Contractor' · Number (M-D-Y) 04-19 i 05-23-94 ! Pressure Survey 1 SCH 04-45i ! 07-05-94 Pressure Survey I SCH 11-29i I 07-08-94 1 Pressure Survey 1 SCH 11-36 ! 06-09-94 ~ Pressure Survey 1 SCH 12-07A i 06-06-94 I Pressure Survey ~c~.~ i 12-10A ! 06-07-94 ! Pressure Survey i 12-12 I 06-08-94 ! Pressure Survey 1 ~ ~ 12-16A I 07-07-94 ! Pressure Survey i 1 SCH ~'~ i 12-26 I 06-08-94 t Pressure Survey i I SCH ) I 13-31 I 06-09-94 t Pressure Survey ! 1 SCH { 13-35 I 06'09'94i Pressure Survey { 1 SON ~ I 18-01 106-04-941 Pressure Surveyi 1 SCH '3'~ t 18-08 i 06-10-94 i Pressure Survey ! 1 SCH Number of Records: 13 Karla Zuspan Distribution: Central Files BPX State of Alaska Mobil Please le receipt aq Phillips Exxon D&M Date: ism/ ARGO Alaska, lng. Is a Subsidiary of A~lmmlcRIchtlMdGoml~ny ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: '(,' August 4, 1994 Kinley Caliper Survey's John E. DeGrey/ATO-1529 (907) 263-4310 Distribution P.O. Box 100360, Aq~r.'' Transmittal #: 94071 Well Log Date Tool Type Contractor Number (M-D-Y) ?~ q~ 6-1 7-4-94 Caliper Survey Kinley ?~. ~/. 12-7 7-3-94 Caliper Survey , Kinley :?1 -'~? 12-11 6-29-94 Caliper Survey Kinley k I'- f;'[ 12-12 7-4-94 Caliper Survey Kinley ~.. II 12-32 6-30-94 Caliper Survey Kinley i~o.l,~;-i 13-12 6-30-94 Caliper Survey Kinley i~0 o1:~0'=14-10 7-1-94 Caliper Survey Kinley ~6- I.~ I 14-11 7-1-94 Caliper Survey Kinley li'~'-2~'5" 16-20 ~ 7-3-94 Caliper Survey Kinley ~"' 77 17-3 ! 7-2-94 Caliper Survey Kinley Number of Records: 10 ~rage, AK John E. DeGrey Distribution: Central Files State of Alaska ANO-8 Geology BPX Exxon Plea.~~owledge r.~i~t~,.by signing and returning a copy o~~~mjtJa,. ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ARCO(ALASKA) · . ~ .'. . ..:.: .... · · . · · · . . ' ~ '.~:i. · ... Survey~. No,. '23996 · . · .:':. ~ ":' ..':':'. :... '... . · · ·' ': .... ",~'t~"¢£l .. ·PRUDHOE..BAY~ AK ,~o-~ :o~ ........ · · DRIL~'Si~E'12.12~,~o,,,.. . . . . ".". . 'July.4; i994. .. . .". '... . . · Caliper Specialists' Since 1SI15~ KINLEY CORPORATION 5815 Royslton, Houston, Tsxss 77081-2:gg3 U.S.A. Phone (71 3] 864-4501 Telefax (71 3].884-1037 SERVICE AVAILABLE WORLOWIOE tlltTrH ALL KINLEY WIRELINE Calipers · Tubing Perforators .. Sencl Line Cutte, r~ · I~ower Jars · Measuring Line Cutter~ HOW TO-READ iE SURVEY ABB REVIA~ Q NS I.U. "~ Ul3set Con'. U.U. = Umer U~et mB. ='middle Body Shall. La. = ~Body NUMBERS AND LETTERS ON THE SURVEY All JO I NT~ in the tubing string am numbered, from the top down, starting with the first ful! [oi'nt below the Christmas tree. PUP JOINTS am given decimal numbem. Example.= 1.1 represents' the first pup joint below j~int ~1. SPECIAL'TOOLS AND NIPPLES am identified by letters. Example: "B" is ',he sea=nd spec. ial't~l, or nipple~ down from the top. Gas Lift Mandrels am numbered from the top, as shown: GLM (1), Gl.bi (2),' GLM (3). etc, TABULATION SYMBOLS .. 'WHY IS THE CIRCLE OUR BASIC SYMBOL? The Kinley Caliper records the action of all its ., '. fifteen feelers simultaneously, instead of recording justthe action of the one feelerthat is.the ~rthest 'off-center. The Klnley Caliper Survey has fifteen Ii.nee, Instead of just one line. These fifteen lines' of information give us a circular view of the inside surface'of the tubing.A complete circle on the tabulation sheets indicates that all ~teen feelers (or at least fourteen), found tubing wall reductions at the same I~vel in the well.. SYMBOLS showing NUMBER OF FEELERS indiceting tubing walireducttons atthe same'leveL 31o5 ~ $to9 ~ 10to13 ~ 14orlS (MI=) MEASUREMENT and PERCENTAGE SURVEY symbols (also (MPM) MEASURE- MENT and PERCENTAGE MODIFIED sYmbols) · " A PIT-A' number alone represents the penetration, expressed in hundredths of an inch, of the deepest pit.(In this example, the d~epest p.enetratton, probably due to corrosion, ~easures.08".) A RING--A groove around the pipe, probably including corrosion, found by ail(or at least 14) of the 15 feelers. The number Inside the circle represents the maximum penetration:of the dng, ex- pressed in hundredths of an inch. (In this example, a complete pit rin~[maches a maximum pone-.. tration of .1(7'~ · A PARTIAL RING-A groove, I=r~bably including corrosion, found ~3y at least 3 feelers, but no more than 13. (In this example,'10 feelers found penetration, reaching a maximum penetration of.07".) ~[] MINOR DAMAGE--Indications of "minor" corrosion not sufficiently severn to warrant measurement. [~] NO COMMENT--No indication of any damage is recorded in ~hat Joint. Arco (Alaska), Inc. Prudhoe Bay, AK Drill Site #12-12 July 4, 1994 Survey # 23996 T30 Chart # X-1544 · This is the first survey of this well to be made with the Kinley 30- Feeler Microscopic Caliper. The condition of the internal surface of the ~ 1/2" 17# Buttress tubing in the well, from .0t to 9,570t (WLM), is covered in this report. The deepest penetrations recorded in the survey are one shallow pit and three areas of shallow corrosion that measure 0.04" or 13% of the tubing wall thickness. These penetrations are located in Joint #'s 65, 192, 209, and 213.3. As there are no penetrations recorded in excess of 20% of the tubing wall thickness, the usual cross-sectional drawings and Pit Depth Rank Chart are not included in this report. The condition of the tubing surveyed and analyzed appears good with respect to corrosive damage. Indications of minor'corrosive damage are recorded in all of the joints in the forms of isolated shallow pits, areas of shallow corrosion, and roughness of the tubing I.D. As indicated by the Corrosion Profile, minor corrosive damage is recorded throughout the tubing interval surveyed and analyzed. Most of the pup joints and flow couplings above and below the tool assemblies and the GLM's contain shallow corrosion. The deepest penetration in these tool assemblies is recorded in the lower pup joint of GLM (5) in Pup Joint #213.3 and measures 0.04" or 13% of the pup joint wall thickness. Photocopies of GLM (5) and other representative tool assemblies are included in this report. Six of the caliper feelers did not function properly during the running of the survey. The rest of the survey recorded with the remaining 24 feelers was not affected by the malfunction. CALIPER TECHNICIAN Ken Bullock SURVEY ANALYST Mark A. Brown mab Distribution: ARCO (ALASKA), INC., ATTENTION:' Records Processor, Room #AT0-1529, P. O. BoX 10-3240, Anchorage, AK 99510-3240 (TR) ARCO (ALASKA), INC., ATTENTION: Mr. Jason Weaver, Room #AT0-1768, P. O. Box 10-3240, Anchorage, AK 99510-3240 (1R) Chart received: Report faxed: Report mailed: 07-06-94 07-07-94 07-'06-94 KINLEY CALIPER TALL~ SHEET (Composite) DRILL SITE 12-12 Survey # 23996 July 4, 1994 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Penetrations Over 85% (Possible Hole) # of Jts 0 Penetrations 41 - 85% (Poor) · Penetrations 21 - 40% (Fair) Penetrations 11 - 20% (Good) Penetrations 1 - 10% (Very Good) 257 No Penetrations Recorded TOTAL JOINTS SURVEYED: 268 ( Includes 37 Pup Joints ) DR/LL S/TE 12-12 PRUDHOE BA Y~ AK Ju/y 4. 1994 SURVEY # 23996 5 I/2" 17# BUTTRESS CORROSt VE DAMA GE F, REQUENC Y DISTRIBUTIONS MAXIMUM PENEZRA TION CONFIGUP.,A TION NUMBER OF JOINTS DESCRIPTION BODY PENETRATIONS % Vt'ALL LOSS 20 40 6'El80 6 12 18 24 AZT DEPTH (1~ICe'inch} KINLEY ¢ 5 1/2" 17# BU'I-I'RESS Body: 0.304 Upset: 0.304 Chart # X1544 Feeler Ratio 1 · 1 .LIPER JOINT TABU I( TION SHEET DRILL SITE 12-12 PRUDHOE BAY, AK Suwey # 23996 UulY 4, 1994 n#1 MAXIMUM MAXIMUM UPSET/MAKEUP I BODY JOINT PENETRATION PENETRATION DAMAGE n PROFILE NO % INCHES % INCHES COMMENTS i (% WALL) 0.1 , Pup Jt. 1 7 0.02 , Shallow corr.; 1st full length Jr. below Tree 2 3 0.01 ~ Roughness 3 7 0.02 :Shallow corr. 4 7 0.02 Shallow corr. 5 3 0.01 ~ Roughness 6 7 0.02 1 Shallow corr. 7 3 0.01 Roughness 8 3 0.01 ]Roughness 9 10 0.03 Shallow pits m.B. & I.B.; Roughness (.01") 10 7 0.02 Shallow corr. 11 7 0.02 Shallow corr. 12 7 0.02 :Shallow corr. .. 13 7 0.02 Shallow corr. , 14 7 0.02 Shallow corr. 15 7 0.02 Shallow corr. 16 7 0.02 Shallow corr. 17 7 0.02 Shallow corr. 18 7 0.02 Shallow corr. 19 3 0.01 Roughness 20 7 0.02 Shallow corr. 21 7 0.02 Shallow corr. 22 7 0.02 Shallow corr. 23 7 0.02 Shallow corr. 24 7 0.02 Shallow corr. 25 7 0.02 Shallow corr. 26 7 0.02 Shallow Corr. 27 7 0.02 Shallow corr. 28 7 0.02 Shallow corr. 29 7 0.02 Shallow corr. 30 7 0.02 Shallow corr. 31 7 0.02 Shallow corr. 32 ~ 7 0.02 Shallow corr. 33 7 0.02 Shallow corr. 34 7 0.02 Shallow corr. 35 7 0.02 Shallow corr. 36 7 0.02 Shallow corr. 37 7 0.02 Shallow corr. 38 7 0.02 Shallow corr. 39 7 0.02 Shallow corr. 40 10 0.03 Shallow corr. 41 10 0.03 Shallow corr. 42 10 0.03 Shallow pit u.B.; Shallow corr. (.02") 43 10 0.03 Shallow corr. 44 7 0.02 Shallow corr. . 45 7 0.02 Shallow ,corr. 46 7 0.02 Shallow corr. .. 47 7 0.02 Shallow corr. 48 7 0.02 Shallow corr. 49 10 0.03 Shallow corr. . . 50 7 0.02 Shallow corr. ~l~ ' BODY ~ - UPSET 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chad # X1544 Feeler Ratio I · '1 '.LIPER JOINT TABUI(.'I TION SHEET DRILL SITE 12-12 PRUDHOE BAY, AK · Suwey # 23996 4, 1994 un#1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY JOINT PENETRATION PENETRATION DAMAGE . NO % INCHES % INCHES COMMENTS 51 10 0.03 Shallow corr. 52 7 0.02 Shallow corr. 53 7 0.02 Shallow corr. 54 7 0.02 Shallow corr. 54.1 Pup Jt. 54.2 Flow Coupling; "$$SV" Nipple Assembly (A) 54.3 Flow Coupling 54.4 10 0.03 Shallow corr.; Pup Jr. 55 7 0.02 Shallow corr. 56 7 0.02 Shallow corr. 57 7 0.02 Shallow corr. . 58 7 0.02 Shallow corr. 59 7 0.02 Shallow corr. 60 7 0.02 Shallow corr. 61 10 0.03 Shallow corr. 62 3 0.01, Roughness 63 10 0.03 Shallow corr. 64 7 0.02 Shallow corr. 65 13 0.04 Shallow coif. 66 10 0.03 Shallow corr. 67 7 0.02 Shallow corr. 68 7 0.02 Shallow corr. 69 7 0.02 Shallow corr. 70 7 0.02 Shallow corr. 71 7 0.02 Shallow corr.. 71.1 7 0.02 Shallow corr.; Pup Jt 71.2 Flow Coupling; GLM 71.3 7 0.02 Shallow corr.; Pup Jt 72 7 0.02 Shallow corr. 73 10 0.03 Shallow corr. 74 7 0.02 Shallow corr. 75 7 0.02 Shallow corr. " 76 7 0.02 Shallow corr. 77 10 0.03 Shallow corr. 78 7 0.02 Shallow corr. , 79 7 0.02 Shallow corr. 80 7 0.02 Shallow corr. 81 10 0.03 Shallow corr. 82 7 0.02 Shallow corr. 83 7 0.02, Shallow corr. ., 84 7 0.02 Shallow corr. 85 7 0.02 Shallow corr. ,,,86 7 0.02 Shallow corr. 87 7 0.02 Shallow corr. 88 7 0.02 Shallow corr. 89 7 0.02 Shallow corr. 90 7 0.02 Shallow corr., 91 7 0.02 Shallow corr. 92 7 0.02, Shallow corr. .. 93 7 0.02 Shallow corr. 94 7 0.02 Shallow corr. 95 7 0.02 Shallow corr. 99~7 7 0.02 Shallow corr. 7 0.02 Shallow corr. 7 0.02 Shallow corr. 7 0.02 Shallow corr. 100 . 7 0.02 Shallow corr. BODY ~ - UPSET KINLEY ( 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chart # X1544 Feeler Ratio I · I I MAXIMUM I MAXIMUM IUPSET/MAKEUPI BODY JOINTI PENETRATION I PENETRATION NO .LIPER JOINT TABUI(" TION SHEET DRILL SITE 12-12 PRUDHOE BAY. AK Suwey # 23996 July 4, 1994 Run # 1 COMMENT8 DAMAGE 'O PROFILE (% WALL) 100 Shallow corr. Shallow corr. Shallow corr. Shallow corr. ,Shallow corr. Shallow corr. Shallow con'. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. ' Shallow corr. Shallow corr. Shallow corr. Shallow Shallow Shallow Shallow corr.; Pup Jt corr.; Flow Coupling; GLM (2) corr.; Pup it. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr.. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. " ~ -BODY ~m -UPSET JOINT NO KINLE¥ 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chart # X1544 Feeler Ratio 1: 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY PENETRATION PENETRATION LIPER JOINT TABU I(," TION SHEET Shallow corr. Shallow corr. Shallow corr. COif. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow con'. Shallow corr. Shallow corr. Shallow corr. Shallow corr. DRILL SITE 12-12 PRUDHOE BAY, AK Survey # 23996 July 4, 1994 Run # 1 COMMENTS DAMAGE O PROFILE (% WALL) 100 Shallow Shallow Shallow Shallow corr.; Pup It. corr.; Flow Coupling; GLM (3) corr.; Pup ~t. COif. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow coif. Shallow corr. Shallow corr. ' Shallow corr. Shallow con'. ' Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr. (.02") Shallow corr. Shallow corr. Shallow corr. Shallow corr. Shallow corr.; Pup Flow Coupling; OLM (4) Shallow coif.; Pup lt. Shallow coif. Shallow corr. Shallow corr. Shallow corr. Bm - UPSET 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chart # X1544. Feeler Ratio 1 · 1 .LIPER JOINT TABULATION SHEET DRILL SITE 12-12 PRUDHOE BAY, AK Suwey # 23996 July 4, 1994 Run # 1 MAX]MUM MAXIMUM UPSET/MAKEUP BODY JOINT PENE'11=IATION PENETRATION DAMA~3E n PROFILE .,, NO % INCHES % INCHES COMMENTS ] ~ WALL)" 201 7 0.02 I Shallow con.. 202 7 0.02 1 Shallow con.. 203 10 0.03 Shallow corr. 204 10 0.03 Shallow con'. 205 7 0.02 1 Shallow corr. 206 7 0.02 1 Shallow coif. 207 7 0.02 Shallow corr. 208 7 0.02 Shallow corr. ' . . 209 13 0.04 1 Shallow corr. 210 10 0.03 ~$hallow con.. 211 7 0.02 : Shallow corr. 212 7 0.02 Shallow con.. 213 7 0.02 Shallow con.. 213.1 3 0.01 'Roughness; Pup Jt. 213.2: Flow Coupling; GLM (5) 213.3[ 13 0.04 Shallow con..; Pup Jt. 214 7 0.02 Shallow con.. 214.1 7 0.02 Shallow corr.; Pup ;lt. 214.2 7 0.02 Shallow corr.; Flow Coupling; GLM (6) 214.3 7 0.02 Shallow corr. 215 7 0.02 Shallow con.. 216 7 0.02 Shallow corr. 217 7 0.02 Shallow con.. 218 7 0.02 Shallow con.. 219 10 0.03 Shallow con'. 220 7 0.02 Shallow con'. 221 7 0.02 Shallow con'. 222 7 0.02 Shallow con'. 223 7 0.02 Shallow corr. 223.1 7 0.02 Shallow con'.; Pup.lt. 223.2 7 0.02 Shallow con'.; Flow Coupling; GTM (7) .2,23.3 7 0.02 Shallow con..; Pup.lt. 224 10 0.03 Shallow con.. 224.1 7 0.02 Shallow con..; Pup.it. 224.2 . 7 0.02 Shallow corr.; Flow Coupling; GI.M (8) 224.3 10 0.03 Shallow corr. 225 7 0.02 Shallow con.. 226 10 0.03 Shallow con'. 227 7 0.02 Shallow con'. 228 7 0.02 Shallow con'. 229 7 0.02 Shallow con'. 229.1 7 0.02 Shallow corr.; Pup Jt. 229.2 7 0.02 Shallow con'.; Flow Coupling; GLM (9) 229.3 7 0.02 Shallow con..; Pup.it. 230 10 0.03 Shallow corr. 230.1 7 0.02 Shallow con'.; Pup.iL , 230.2 7 0.02 Shallow corr.; Flow Coupling; GI.M (10) ,230.3, 7 0.02 Shallow con..; Pup.it 231 7 0.02 'Shallow con.. 231.1 7 0.02 Shallow con..; PUp .it.; "BOT PBR" As~mbly (B) 231.2 7 0.02 Shallow corr.; Pup ;It.; "BOT" Packer Assembly (C) . . 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' : .... __!i __-.. -_ ~".~~ . "--- ............ - · , · ~ · · · . J ' '-" . . .' .. - . . ... ·., . _ : .~~__: ._. ~'.._/i ~;. -.~. .-, . . : '~ · ........ t' · ° .~ · . .... · ..... ;;~ -=-'-~---:'-'--- ~ '.'_- i ~. ' ' . i '.- . .i - · .~-.~; " ' . ' i.' · I : .... · · ' i' ' -: .. : ' . ' · : · . . , : . · .: : · .. _~L_;_ : ' '. I ' · .: . ' . '- .~.~-- .... - ~ : ' ' .I .... ; d... .' ~ ~ L '- . · '..... o. ...... ·. i !:..-. · .. ' ..- .~.,:' ~ . · ....... · ' ' "l ~ ~i-~-~- ~' ~- · · ' : f . ,[ · ' ; " r · : . ' · -- · '. ! - . -. ~. . · . ! · .- . .'. ; . ... ,'.. ,. _ · o $ halla~ aec ¢. ~O'T POR · : · o · .. ,, ,,e .: : · .. · · oo .... : · . ..'.1 Drill Site: 12 ': ~ Wezz: 12 Sat Jan 22 12:04:09 1994 ! ! ' '~', ' '-', FTP ~ CLOSE (PSIG): 295 PSI~ ii CO~ENTS: Redesigned to allow testing of k-valve in well. This will require the well be choked back to keep (o~ ~~ ~u'~ from dumping. To aid in dumping, the LGR can be raised, up, and if ok, open the drain system also. CC: ENGINEERING FiLE / COORDINATOR PRB 24 (WITH ATTAC~%iENTS ) J.C. S~%RT / M.~. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) Tom Brassfield / Joe Ralph PRB 15 (COVER ONLY) Melanie Wilson ATO 15 (WITHOUT ATTACF~4ENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: ~ Drill Site: 12 Well: 12 WELL TEST DATA Sat Jan 22 12:04:10 1994 CK L~R FTP OIL %WTR ~OR GLR L IQ PWF P I SEPARATOR DATE SEL TE~iP PRES 89 3279 296 593 75.5 1058 1607 2430 1069 1.02 139 282 01/20/94 Y 89 3158 27~ 597 76.6 1261 1530 2555 89 4034 280. 631 75.1 1157 1874 2542 89 4080 301 89 3294 283 89 3247 271 89 3323 300 89 3262 282 89 3279 295 89 2838 272 630 73.9 1028 1952 2422 587 74.4 943 1675 2296 651 73.6 1177 1625 2469 615 74.1 872 1623 2377 615 7~.2 1097 1648 2389 586 73.8 1042 1737 2239 574 74.1 1406 1541 2221 0 0.00 137 265 01115/94 0 0.00 139 265 01t08~94 0 0.00 138 286 12130/93 0 0.00 137 268 12/23193 0 0.00 139 258' 12/20/93 0 0.00 137 288 12/07/93 0 0.00 139 269 11/09/93 0 0.00 139 282 11/08/93 0 0.00 136 258 11/03193 ESC=EXIT; Fl=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; F6=CHECKLiST; F10=ACCEPT; SFS=RESTORE WELL TEST; CF9=CYCLE DATA; SSSV DEPTH (MEAS): 2195 FTP @ CLOSE (PSIG): 295 PRESS ADJUSTmeNT: 0 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TE~, PI PROF USES BH TEMP AND W~LL PI WPS C= ..28243e-3 N= 1.000000 NEW C= ..28745e-3 E~ERED N= 1,000000 Drill Site: 12 Wmll: 12 K-VALVE Thu May 27 13:23:~8 1993 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm! FTP ~ CLO~E (PSIC.): 133 PSIC K-VALVE CLASS .(A.,B., C): C COMMENTS K-valve will have to be bench tested. Design accounts for tncreased PI., water cut and LUR changes. Design also accomodates occasional reductions in LP commonline pressure down to.2&0 psi or lower. Drill Site: 12 Well: 12 K-VALVE DESIGN Sun Feb 21 15:18:50 1993 DOME SET PRESSURE FTP @ CLOSE K-VALVE CLASS (A,B,C) 235 PSI~ @ 60 DE~ F 260 PSI~ B COMMENTS: Well is in the "~P" LP CL at DS 12. The "LP" LP CL operates around 198 psi. To dump this k-valve, switch well from "HP" to "LP". It should d,~,mp. J.C. SMART / M.O. S~IOEMAKE Tom Brassfi.eld / Joe Ralph EN~INEERIN~ WELL FILE PRB PRB 20 PRB STATE OF ~.L~.SKA (COVER} DESIGNED BY: MMM . STATE OF ALASKA ALASKA (' . AND GAS CONSERVATION CO( /IlSSION 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1015' N & 751' Wof SEcr, Sec. 18, T10N, R15E, UM At top of productive interval 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At effective depth 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At total depth 4067' N & 3662' W of SE cr, Sec. 18, T10N, R15E, UM 12. Present well condition summary Total dePth: measured 10870 feet true vertical 9396 feet 5. Type of Well Development ~ Exploratory .i. Straligraphic i-, 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-12 9. Permit number/~oproval number 81-83 10. APl number 50 - 029-20610 11. Field/Pool Prudhoe Bay Oil Pool feet Plugs(measured) Fill @ 10089' MD (1/16/93) Effective depth: measured 10089 feet true vertical 8879 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 300 sx Permafrost Surface 2593' 13-3/8" 2750 sx Fondu & 400 sx PF Production 9862' 9-5/8" 500 sx Cl G Liner 1251' 7" 300 sx Cl G Measured depth True vertical depth 80' 80' 2664' 2664' 9933' 8758' Perforation depth: measured 10041-10059'; 10064-10077.; 10084-10100' true vertical 8842-8856'; 8860-8870'; 8876-8887' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9588' MD; 4-1/2", 12.6#, L-80, PCT tail @ 9651' MD Packers and SSSV (type and measured depth) BOT packer @ 9578' MD; 5-1/2", Camco BaI-O SSSV @ 2195' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Rel~resentative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 591 1169 2485 -- Subsequent to operation 962 ~/' 730 1967 -- 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run ---. I Daily Report of Well Operations ..i Oil x.~_ Gas/ Suspended / Service 17. I hereby certify that the fore_going is true and correct to the best of my knowledge. .Si~ned Title Engineering Supervisor Form 10-404 Rev 06/15/88 950/14 KRF cc: SW, JWP Tubing Pressure 245 325 SUBMIT IN DUPLICATE 12-12 DESCRIPTION OF WORK COMPLETED FOAMED ACID STIMULATION TREATMENT 1116193: RIH & tagged bottom fill at 10089' MD. 1/17193: A fullbore Foamed Acid Stimulation Treatment for Scale Removal was performed as follows: MIRU CT & PT equipment to 5000 psi. Treated the open perforations located at: 10041 - 10059' MD (Z4) 10064 - 10077' MD (Z4) 10084 - 10100' MD (Z4) Ref. Log: BHCS 7/20/81. Pumped Stage #1: a) 20 bbls 1% NH4CI Water w/foaming agent @ 10 bpm, followed by b) 40 bbls 50% Diesel/50% Xylene @ 10 bpm, followed by c) 10 bbls 1% NH4CI Water w/foaming agent @ 10 bpm, followed by d) 40 bbls 15% HCI w/additives foamed w/700 scf/bbl Nitrogen, followed by e) 10 bbls 6% HCI - 1.5% HF foamed w/700 scf/bbl Nitrogen, followed by f) 100 bbls 1% NH4CI Water foamed w/700 scf/bbl Nitrogen, followed by Diverter Stage: g) 25 bbls Foamed 1% NH4Cl Water w/3700 scf/bbl Nitrogen, followed by Stage #2: h) 10 bbls 1% NH4CI Water w/foaming agent @ 10 bpm, followed by i) 40 bbls 50% Diesel/50% Xylene @ 10 bpm, followed by j) 10 bbls 1% NH4Cl Water w/foaming agent @ 10 bpm, followed by k) 40 bbls 15% HCI w/additives foamed w/700 scf/bbl Nitrogen, followed by I) 10 bbls 6% HCI - 1.5% HF foamed w/700 scf/bbl Nitrogen, followed by m) 100 bbls 1% NH4Cl Water foamed w/700 scf/bbl Nitrogen, followed by Diverter Stage: n) 25 bbls Foamed 1% NH4CI Water w/3700 scf/bbl Nitrogen, followed by Stage #3: Flowed well. Rigged down. 2/1/93: Pumped a Scale Inhibition Treatment. o) 10 bbls 1% NH4CI Water w/foaming agent @ 10 bpm, followed by p) 40 bbls 50% Diesel/50% Xylene @ 10 bpm, followed by q) 10 bbls 1% NH4Cl Water w/foaming agent @ 10 bpm, followed by r) 40 bbls 15% HCI w/additives foamed w/700 scf/bbl Nitrogen, followed by s) 10 bbls 6% HCl - 1.5% HF foamed w/700 scf/bbl Nitrogen, followed by t) 400 bbls 1% NH4CI Water w/foaming agent @ 10 bpm. .~,~.),~ ?-',' .~ Returned well to production w/gaslift & obtained a valid production test. D~ill Si~e: 12 ~ell: 12 K-VALVE DESIGN Thu ~ul 30 20:26:26 1992 DOME SET PRESSURE FTP @ CLOSE (PSlG K-VALVE CLASS (A,B,C) 170 PSIG @ 60 DEG F 160 PSIG C COMMENTS: K-VALVE REDESIGNED BECAUSE WELL HAS DUMPED SEVERAL TIMES IN THE LAST WEEK. .. · CC: C.P. FARMER / W.D. COOPER~ J.C. SMART / M.G. SHOEMAKE C.B. HURST / E.A. CAMPBELL ENGINEERING WELL FILE PRB 24 PRB 20 PRB 15 K.L. HUDSON ATO 1566 S~AT~ OF ALASKA (COVER) DESIGNED BY: R.T.BURNO ECEIVED AUG 1 0 1992 Oil & Gas Cons. Commi~ion Anchoralle Drill Site: 12 Well: 12 Thu Jul 30 14:37:23 1992 K-VALVE DESIGN SSSV DEPTH (MEAS): 2195 FTP @ CLOSE (PSIG): 160 PRESS ADJUSTMENT: 99 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI CONDITIONS OF WELL TEST: SEP COML CK LGR FTP OIL %WTR GOR GLR LIQ PWF PI TEMP PRES DATE SEL 81 2514 242 1482 59.8 885 '1037 3690 1231 1.62 150 185 07/26/92 Y CONDITIONS AT CLOSURE: 81 2514 160 1581 59.8 885 994 3938 1042 1.62 150 185 WELL TEST ~CLOSE TEMPERATURE @ SSSV: 165 165 PRESSURE @ SSSV: 392 293 DOME SET PRESSURE: 170 PRIOR DESIGNS: DATE: 05/01/92 SET PRESSURE: 185 FTP @ CLOSURE: 190 02/11/92 185 300 o1/o1/81 o o TAMP: LINEAR LINEAR NA ESC=EXIT; Fl=HELP; F2=WELL .TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..648248-7 N= 1.599999 NEW C= ..102578-7 ENTERED N= 1.599999 Drill Site: 12 Well: 12 SENSITIVITY TABLE Thu Jul 30 14:38:21 1992 P.m. %WTR GOR LGR 1.60 1.60 60.0 60.0 9,00 ~, ~,, ',i '1000 2500 , .... ,.' 'o 1. O0 2. O0 55.0 70.0 950 1000 3000 3000 FTP 1 242 393 .. ,,. FTP 2 100 226 .. 529 384 389 . . 286 229 227 FTP 3 270 428 575 417 423 ENTER VALUES FOR PRODUCTIVITY INDEX, WATER CUT, GAS-OIL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WILL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fl=HELP; F2=WELL TESTS; F3=DESIGN; F4=DISTRIBUTION LIST; F6=CHECKLIST; F10=ACCEPT; K-VALV]~ D~I~N K.L. IiUDBON Atto ]-566 S~AI'g OF ALASKA (COrgi) DESIGNED BY i MMPi RECEIVED MAY 1 1 1992 ~as~ Oil & Gas Cons. Commission Anchorage Drill Site: 12 Well: 12 Mon Oct 28 16:15:29 1991 0 K-VALVE DESIGN SSSV DEPTH (MEAS): 0 FTP @ CLOSE (PSiG): 300 PRESS ADJUSTMENT: 64 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES ma .z.,:lv~ AND WELL Pi CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR GLR 85 2519 365 2583 46.6 1535 1339 4842 CONDITIONS AT CLOSURE: 85 2519 300 2710 46.6 1535 1315 5080 WELL TEST @CLOSE TEMPERATURE @ SSSV: 148 148 PRESSURE @ SSSV: 367 303 SEP COML PWF PI TEMP PRES DATE SEL 1361 2.21 148 0 10/29/91 Y 1247 2.21 148 0 DOME SET PRESSURE: 185 PRIOR DESIGNS: DATE: 01/01/81 SET PRESSURE: 0 ol/oi/81 o o1/o1/81 o FTP @ CLOSURE: 0 TEMP: ~ NA 0 NA 0 NA ESC=EXIT; Fl=HELP; F2=WELL TESTS; F4=DISTRIBUTiON; F5=SENSITIVITY TAB/E; F6=CHECKLIST; Fi0=ACCEPT; SFS=RESTORE WELL TEST; CFg=CYCLE DATA; Printing contents of current screen - wait for message to Clear Drill Site: 12 Well: 12 Mon Oct 28 16:22:27 1991 SENSiTiViTY TABLE GOR 1535 4000 1535 4O00 LGR 2500 2500 2500 2500 NOV 0 8 1991 FTP i 360 362 366 36i 363 Alaska Oil & Gas Cons. CorrJmissio.n Anchorage FTP 2 300 303 308 301 303 FTP 3 i00 iii 132 106 i12 ENTER VALUES FOR PRODUCTiViTY INDEX, WATER CUT, GAS-OiL RATIO, LIFT GAS RATE, AND FLOWING TUBING PRESSURE 1, 2, or 3. PRESSURES AT THE SSSV WiLL BE CALCULATED FOR EACH GROUP OF ITEMS ENTERED. ESC=EXIT; Fl=HELP; F2=WELL TESTS; F3=DESiGN; F4=DiSTRIBUTiON LIST; F6=CHECKLIST; F10=ACCEPT;. Printing contents, of current screen - wait for message to clear Drill Site: 12 Well: 12 K-VA~v~ u~zGN Mon Oct 28 lo:±D:02 1991 , II DOME ~' PR~u~: 185 PSiG @ ~u om~ r' II PTP @ CLOS~ (PSiG): 300 ~±u i i, ~-¥.t-~vE CLASS (A,B,C): B Ii · . CO~MENTS: New K-valve well. Frac operations plugged off control and balance lines. CC: C.P. FARMER / W.D. COOPEt~~" J. Smart / M. Shoemake PRB 20 J. RaiDh / T. Brassfieid PRB 15 ENGINEERING WELL FILE PRB 24 K. Hudson ATO 1560 STA.TE OF ALASKA (COVER) DESIGNED BY: M. Maguire Printing contents of current screen - wait for message to clear STATE OF ALASKA '~' REt. 'ut- :SUNUHY WELL OPI:.HAIIONS 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 1015' N & 751' Wof SE c;r, Sec. 18, T10N, R15E, UM At top of productive interval 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At effective depth 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At total depth 4067' N & 3662' W of SE cr, Sec. 18, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development ~X Exploratory StralJgraphic Service 10870 feet Plugs(measured) 9396 feet 6. Datum of elevation(DF or KB) 71 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-12 g. Permit number/approval number 81-83 10. APl number 50 - 029-20610 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 10203 feet true vertical 8967 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2593' 13-3/8" 2750 sx Fondu & 400 sx PF 2664' 2664' Production 9862' 9-5/8" 500 sx CI 'G' 9933' 8758' Liner 1251' 7" 300 sx CI 'G' 10870' 9396' Perforation depth: measured 10041-10059'; 10064-10077'; 10084-10100' true vertical 8842-8856'; 8860-8870'; 8876-8887' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9588' MD; 4-1/2", 12.6~, L-80, PCT tail @ 9651' MD Packers and SSSV (type and measured depth) Brown 3-H packer @ 9578' MD; 5-1/2", Camco Bal-0 SSSV @ 2195' MD 13. Stimulation or cement squeeze summary R ~'~, E iV ~D 14. Intervals treated(measured) See attached JUL 1 § 199 Treatment description including volumes used and final pressure :~.I~.~I~ 0il & Gas Cons. C0~ss~Ot~ Reoresentative Daily Averaoe Production or In!ection D~.ta ~flchor~,ge OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 276 . 423 119 -- 234 Subsequent to operation 2705 .~ 1721 735 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations __ Oil. X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"'~'~" 'Z' ~ Title Form 10-404 Rev 06/15/88 Service Sr. Area Operations Engineer 579 727 JWS c: D. Warner, ATO-1479 SW JWP SUBMIT IN DUPLICATE .. DS 12-12 FRACTURE TREATMENT OF ZONE 4 DESCRIPTION OF WORK COMPLETED 6/1 7/91: MIRU & PT equipment to 9000 psi. Pumped a Propped Fracture Treatment, using 12/18 carbolite proppant, through the perforations at: 10041 - 10059' MD (Z4) 10064 - 10077' MD (Z4) 10084 - 10100' MD (Z4) Ref. Log: BHCS 7/20/81. Pumped: a) 352 bbls 40# Gelled Pre Pad w/1% Scale Inhibitor, followed by b) Shutdown. ISIP @ 2145. Resumed pumping: c) 518 bbls Pad, @ 40 bpm, followed by d) 441 bbls Slurry w/proppant concentrations of 1 to 12 ppg, followed by e) 170 bbls Flush, followed by f) Shutdown. Placed a total of 78,000 lbs of proppant into the formation. Rigged down. 6/1 9/91: Performed a proppant fill cleanout to 10130' MD. Returned well to fulltime production & obtained a valid production test. ..~la~ 0il & · - A~chors,~e ARCO ALASKA, INC· P...O. BOX t ~)0360 ' ,., ANCHORAGE,. ALA£KA 995( ~. DATE: 7-t2-9t .- REFERENCE: ARCO CASED HOLE FINALS f-tt 6-5:-9t PROD F'ROFILE-'"' RUN i, 5" CAMCO t-t t 6-5-9t GR-COLLAR ~ RUN t, 5 · CAMCO i-2i 6-7-9i PROD PROFILE/. RUN i, 5" CAMCO 2-4 6-30-9i CCL-PERF/ RUN t, 5' ATLAS 4-36 6-2t-9t F'FC-GR (PACKER SETTINGY' RUN t, 5" ATLAS r4-37 6-2t-9t CBTj RUN i, 2"&5" $CH P O UOTZON S' -SS S' 7-t~ 6-3~-9J OCL-PERF~ RUN t, D" ATLA~ * 9-6 6-t6-9t _ LEAK DETECTIO~ RUN ~, 2"&5" CAMCO 9-8 6-~-9~ PERFORATION BREAKDOW~ RUN ~, ~" CAMCO 9-9 6-2~-9t OOLLAR-PERF~ RUN t ~ ~ · ATLA~ ** 9-te 4-~7-9f INJ PROFILEx RUN t, 5" CAMCO 9-t8 6-t3-9t ~EWELRY~ RUN t, ~" CAMCO 9-3~ 6-t4-9t LEAK DETECTIO~ RUN ~, 2" CAMCO ~'J~* 9-4~ 6-t2-9t INJ PROFILE~ RUN ~ 5" CAMCO ~-~9-47 6-8-9~ DATA FRAC 'FEMP~ .RUN t, ~" CAMCO ** t t-~ 4-t7-9t LEAK DETECTION~ RUN t, D" CAMCO ~, ~t t-5 6-~2-9~ PROD PROFILE~. . RUN ~, ~" CAMCO t t-22 7-t-9t PDK-~ GG./GR/CCL-BORAX~ RUN t , ~" ATLAS' ~2-t2 6-~6-9~ LEAK DETECTION-- RUN t~ 2"&D" ~AMCO t~-~5 6-t7-9t INJ PROFILE-- RUN t, 5" CAMCO **** ~-~6 6-t7-9t INJ PRO.FILE-- RUN t, D · CAMCO ~6-~6 6-t3-9~ IN~ECTION/F'RODUCTIO~ RUN t, 5" CAMCO t7-~ 6-~6-9~ PRZ~ RUN ~, '~ · ATLA~ ~7-t~ 5-8-9t LEAK DETECTIO~ RUN ~, 2"&5" CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY.AS RECEIPT OF DATA. HAVE A'NICE DAY! SONYA WALLACE AT0-t529 DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON " MARATHON MOBIL BPX STATE OF ALASKA TEXACO * CORRECTED LOG INTERVAL FOR 9-6 IS 6788-7788 ** REFERENCE MIX UF' ON TRANSMITTAL 9tf59 - POSSIBLE DUPLICATE LOGS *** CORRECTED LOGGED INTERVAL FOR ?-48 IS t375t-t425t **** CORRECTED API~ FOR tJ-t6 IS 5e-~29-2~823 STATE OF ALASKA "" ALASKa' LAND GAS CONSERVATION C{~' MISSION "'~ REPORT' F 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 1015' N & 751' Wof SE cr, Sec. 18, T10N, R15E, UM At top of productive interval 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At effective depth 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At total depth 4067' N & 3662' W of SE cr, Sec. 18, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development X~ Exploratoq, StralJgraphic 10870 feet Plugs(measured) 9396 feet 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-12 9. Permit number/approval number 81-83/90-441 10. APl number 50 - 029-20610 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 10203 feet true vertical 8967 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depti' Conductor 80' 20" 300 sx Permafrost 80' 80' Surface 2593' 13-3/8" 2750 sx Fondu & 400 sx PF 2664' 2664' Production 9862' 9-5/8" 500 sx Cl 'G' 9933' 8758' Liner 1251' 7" 300 sx CI 'G' 10870' 9396' Perforation depth: measured 10041-10059'; 10064-10077'; 10084-10100' true vertical 8842-8856'; 8860-8870'; 8876-8887' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9588' MD; 4-1/2", 12.6~, L-80, PCT tail @ 9651' MD Packers and SSSV (type and measured depth) Brown 3.H packer @ 9578, 1~;~?~2~ ~?~..D~.,_0 SSSV @ 2195, MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached FEB 25 lgg! Treatment description including volumes used and final pressure A!as~,:0jl &.~as Cons. ~ i ~n~.tinmr~r~ Reoresentative Daii¥ Averaoe Production or In!ect'rsh--D~at-~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 1595 2014 3386 -- Tubing Pressure 217 Subsequent to operation 1897 2633 4492 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations . Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 216 673 DMS c: J. Gruber, ATO-1478 Title Sr. Area Operations Engineer Date SUBMIT IN DUPLICATE DS 12-12 DESCRIPTION OF WORK COMPLETED HCL ACID STIMULATION TREATMENT W/DIVERTER 6/20/90: An HCI Acid Stimulation w/OSR Diverter was performed as follows: MIRU CT & PT equipment to 4000 psi. Loaded wellbore w/500 bbls of Dead Crude. RIH w/CT & treated open perforation intervals at: 10041 - 10059' MD (Z4) 10064 - 10077' MD (Z4) 10084 - 10162' MD (Z4) 10178 - 10218' MD (Z4) 10230 - 10250' MD (Z4) Ref. Log: BHCS 7/20/81. Pumped: a) 28 bbls b) 36 bbls c) 24 bbls d) 36 bbls e) 24 bbls f) 36 bbls Methanol, followed 12% HCl, followed 2% NH4CI w/OSR, 12% HCI, followed 2% NH4Cl w/OSR, 12% HCl, followed by by followed by by followed by by g) 21 bbls 2% NH4CI w/OSR, followed by h) 38 bbls 12% HCI, followed by i) 28 bbls Methanol, followed by j) 5 bbls Diesel, followed by k) 20 bbls Methanol, followed by I) 38 bbls Diesel, followed by m) 238 bbls Crude, followed by n) 10 bbls Diesel. Rigged down. Flowed well. Obtained a valid production welltest. STATE Of ALASKA ALASK./( LAND GAS CONSERVATION C{' MISSION ' .'" REPORT UF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown Stimulate -~. Plugging ~ Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) ARCO Alaska, Inc. Development X Exploratory 71 RKB feet 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 Service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1015' N & 751' Wof SE cr, Sec. 18, T10N, R15E, UM 12-12 At top of productive interval 9. Permit number/approval number 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM 81-83 At effective depth 10. APl number 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM 50 - 029-20610 At total depth 11. Field/Pool 4067' N & 3662' W of SE cr, Sec. 18, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10870 feet Plugs(measured) true vertical 9396 feet Effective depth: measured 10203 feet true vertical 8967 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 300 sx Permafrost 80' 80' Sudace 2593' 13-3/8" 2750 sx Fondu & 400 sx PF 2664' 2664' Production 9862' 9-5/8" 500 sx Cl 'G' 9933' 8758' Liner 1251' 7" 300 sx Cl 'G' 10870' 9396' Perforation depth: measured 10041-10059'; 10064-10077'; 10084-10100' true vertical 8842-8856'; 8860-8870'; 8876-8888' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9588' MD; 4-1/2", 12.6g, L-80, PCT tail @ 9651' MD Packers and SSSV (type and measured depth) Brown 3-H packer @ 9578' MD; 5-1/2", Camco Bal-0 SSSV @ 2195' MD 13. Stimulation or cement squeeze summary i-~ ~. I1~," [~ I V Intervals treated(measured) See attached F[,~' 2 5 ]99! Treatment description including volumes used and final pressure -~..~a.~'J ~& .~aS CONS, ~_l~ll~lissi0i3 14. Reoresentative Daily Averacm Production or Iniecti(~n b ~_~_'~l~u[aw ' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1432 1522 4404 -- 222 Subsequent to operation 1105 859 148 -- 252 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil .. X Gas Suspended Service : 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~I,~ ~-~~ / Title Sr. Area Operations Engineer Date ~./J''/~'J Form 10-4~ 4 Rev 06/1~;/~,a ~[/~,r;¥:---- ........ - ...... ;.. ..... ~ 628 SLW SUBMIT IN DU c: J. Gruber, ATO-1478 DS 12-12 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER SHUT-OFF I 1/1 0/90: MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. RIH w/CT & performed a fullbore tubing and perforation wash of perforations at: 10041 - 10059' MD (Z4) 10064 - 10077' MD (Z4) 10084 - 10162' MD (Z4) 10178 - 10218' MD (Z4) 10230 - 10250' MD (Z4) Ref. Log: BHCS 7/20/81. Pumped 10 bbls Crude, followed by 100 bbls 15% HCI. Shutdown to soak. Resumed pumping 235 bbls Crude. Displaced CT w/40 bbls M/W. POOH. RD. I I/15/90: Performed a perforation acid wash, followed by a CTU cement squeeze as follows: MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. Loaded wellbore w/seawater & RIH w/CT & jetted an acid wash across the open perforations at: 10041 - 10059' MD (Z4) Ref. Log: BHCS 7/20/81. 10064 - 10077' MD (Z4) 10084 - 10162' MD (Z4) 10178 - 10218' MD (Z4) 10230 - 10250' MD (Z4) Pumped 56 bbls 12% HCI w/12% Xylene. Displaced CT then pumped a CTU Cement Squeeze as follows: Pumped 10 bbls of cement w/expanded aggregate, followed by 30 bbls of regular cement, squeezing the open perforations (listed above). Briefly attained a maximum squeeze pressure of 2800 psi, but had several pressure breaks during the squeeze. Lost the squeeze w/a breakback to 100 psi. Contaminated cement w/biozan & displaced cement & contaminant into the formation w/seawater. Pumped a second batch of 20 bbls latex cement, and attained a maximum squeeze pressure of 3200 psi, but had several breakbacks during the resqueeze. Contaminated cement w/biozan & reversed contaminated cement from wellbore. Pumped a third batch of cement consisting of 10 bbls cement w/aggregate, and sustained a squeeze pressure of 2500 psi. Contaminated cement & jetted cement from wellbore. Placed a total of 52.5 bbls of cement behind pipe. Rigged down. I 1/1 7/90: Performed an Injectivity test that indicated the squeeze was holding. 12/3/90: Reperforated: 10041 - 10059' MD (Z4) 10064 - 10077' MD (Z4) 10084 - 10100' MD (Z4) Ref. Log: BHCS 7/20/81. Returned well to production and obtained a valid production test. ,. ., F'~O· BOX ~)8~&e ANCFIORAGF, ALASKA 9~5~) .. REFEi"(ENCE: ARCO CASED HOI..E F"INAL. 2 4-'-2'~. · t 'i -'3--9,3, I" E:.F'..F" F,E:.L, OF, D F;:LJN'i 4-'32 · 'i 'i-"9-'-9e F'F;:OD PF;:OFII_E/F'IT2 ' RUN 'i , 6-" t 4, t 0 '-' 26 - 9 ('>F:' E.'. R F' R E C ('1 I:;: D R LJ Nt , 'i 'i -4 .- 't 'i "-I 'i--90 F'IT2 RUN 'i '1 --6 r 9-"1 ~--' ,c,;',O THD-BCJRAX RUN 'i, t t-t t~' t f-t 2-90 F'IT'$ RLJN · ' .... · * t t '.-t t t t .-. t 2--c,,'~,.;,'1'BI; CL)I_L. AR RUN t, t 2-2 ' t t -26.-9e F'IE'RF RUN ,..'"',. .... , O COI...L. AI:;:/F'E;I";:F' · .! ..... ! ,,- t 2-33' t 'i -28-'9G !" I::.RF RUN ., t 4-- 2' t t -" t 4'-' 9 0 F:' R 0 D F:' R C] F I I.. E R U N t , t 4. .... 'i ('), t 'i .... 9-'9¢" LEAK DIETECT'ION RUN t , ""' r' ', f 4 .... 'i ().. t 'l .... 9..-.9(.) TBC; C,..JL..I...~..~I-.~ F,'t.J~ t, t 4 .... ~'..'l~,, t '! .... t 4...-':?,3,COI...LAF;.:/[;I:;:/CCI... RLJN 'i · i '."-; .... f 6 · ~i 1 'i 4....- 9 (..':. F:'IE F;..'F:' '" ....... ' .... F., E:. L, 0 R D R U N 't , "l .... ! '" 'i 5 '- 2 t ·'i "i .-5 '"' 9 (') I" I::. I',, I.. R I.J N t 5--' 2 t' 'i t .-- 7 -'- 9 () F' I .............. I .S / i' E:. rl F" R U N 'f , 'l 6-'6, 'i f / t 9"-'2(-)/9e L..EAK Dli"'Tli"'CT I [)N RI. JN t 6 .... ,..':.:' ,,..":-~ ' t 'i .... 't 8 '-' 9 0 I'"" R" L'i D F"' R" 0 F" I' I... E R U N 2, F:'I... E A 2 E $ I [.'; N A N D F~'.I!""¥' U R N T I"1E". A'I" T A C,l"lliE I) C 0 F:' Y A $ R Iii] C E I F' T 0 F I) A'I" A, HAVI.'-. A NICE DAY! A F:' F:' R 0 i~'i E D .~ T'F:.:AN2:.: 9:~I'78' 5:" 5" 5" 5" 5" 5" 5" 5' 5" 5" 5" 2"&5" 5" 5" 5" 5" 5" 2"&5" 5" I..IL.,.$' C A ~ C O HL..2 CAMCO FILS CAM(:;[) CAHCO F4L. 2 A'I'L. A2 HL.$ C; A M C 0 CAMCO C A Pi C 0 C Att C 0 I-IL. 5' H L...s,' [;AHCO. C A H C 0 CAMCO I) I $'r R I B LJ T' I 0 N '"' CI:"N'FRAL. FILES "Ir ...'"' C I.-! E:' V R 0 N D & H · ~ EXTE:N2ZON · "- I:'" X X 0 N '11' i'4~RATHON · f,: HOBZL EXPL. ORATI ON ,# · .- F'H I I.. L I f:'2 F'B WELL. FILE£ · .. BF'X $1'AI'E OF ALA2KA TEXACO RECEIVED DEC 17 1990 Alaska Oil & Gas Cons. Commission Anchorage ARCCi ALA~'KA: Ii'..!C P.O. BOX ANCHORAGE, ALA~'KA DATE' '7-se--ge i:;.: E F E. R E N C E ' A F: C 0 E: A,S' E D i"l 0 L_ r.£ f" I N A i._,':..' "2 -- "'.,26 '7 -- 4 .- 9' ,.')F-' i:;.: 0 .f.) LJ C: T .'[ 0 is! F:' F.'. 0 F' I L.. E 3'- 1 9 '7-3'-9¢' F'F','ODUCT I Obi F'ROF.[ L.F- 4-- ;3 7 - i - 9 6: I... E A K D iii. T E C'i" I 0 N 4.-i $ 7.-7.-9¢, INJIECTION F'ROF.i'I_E 9 -.- i .';:..:: 7 ...-6 - '.:;" :'.:) I N ,..i IE C.~ ]" I 0 N F:' R 0 r:' I L E 9 - 3 2 7 -- t i .- 9,.'..) i"' F;.: 0 D U tS T i 0 N I::' R i"~ F' .i: I.. Ii-' .:, ---,:~ .,-.., , - t,..'?- o,. ,":;,, N J E C '1" In.. N F:' F;.'. 0 F-" i L [:' ~. 'i,.. '7 .- -i 2 '-'- 9 (.;, F:' R 0 D I.J C 'f' I 0 N P R 0 F I ,_~ ,..':-" t 2- i 6 7..--6 .-. 9 (.) L.. E A 14 i) E ]" Iii: £.'. T l 0 N · i 6"-2'2 7-4'-9e (.;-R COL. L. AF;,' t 6'-23 7-3-96., Gl:;.: COLL. AR 'i 8"-t 'i '7'"'8'-'9~.) LEAl( DETli:CTION/F'T'f'$ F'LE:A,?E ~'i(:.;.N AND RETUF,'N '!"HI:Z A"I""f'AC~.i"IE;i) C:OEY A,S' RECE-IF:"I" RECEIVED BY ~_ ._~_f. ZJ~._ ....._ _ ... ...... 0 F:' D A "1" A HAVE A NIC'E :()AY! ;; A I..i... Y HOFFECi<ER A'TO'- t 529 _. // AI::'F'F<O~IED ~ 'f'F;.:'AN;~,':Il. $:,6r;~ :¢5 D l $ "I" R I B U "1" ICI N '"' CENTF,'AL FILES ,il, ,il, ! I · ,,- C H E v r4.: 0 N D & M · ,,-"'- E:XTEN,.?TON E'XF.L..)F:~AT'ION" r " ~ EXXON blARATHON · " MOBIl_ .il- :¢: F' H I: L. L I r" ,.~ F:'B WEI...L 'I:']iI...E.~' R & D '"' BF'X '!1' · · ¢ ,',.,'TA]"I£ CtF ALA~'KA r, A C 0 ' 3 19 0 I AnChOrage. I 1. Type of Request: STATE OF ALASKA ALASI~" ')IL AND GAS ~" CONSERVATION.(, MMISSION~,~ APPLIC,., rlON FOR SUNDRY A PROVAL$ 2. Name of Operator ARCO Alaska, Inc. Abandon .~. Suspend m Operation shutdown ~. Re-enter suspended well ~ Alter casing Repair well ~ Plugging ~ Time extension Stimulate ~X Change approved program Pull tubing Variance Perforate Othe'"--'r 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1015' N & 751' Wof SE cr, Sec. 18, T10N, R15E, UM At top of productive interval 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At effective depth 3609' N & 3437' W of SE cr, Sec. 18, T10N, R15E, UM At total depth 4067' N & 3662' W of SE cr, Sec. 18, T10N, R15E, UM 12. Present well condition summary Total depth: measured 10870 feet true vertical 9396 feet Effective depth: measured true vertical Casing Length Conductor 80' Sudace 2593' Production 9862' Liner 1251' Perforation depth: 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-12 9. Permit number 81-83 10. APl number 50 - 029-20610 11. Field/Pool Prudhoe Bay Oil Pool feet Plugs(measured) ECEIVED 10203 feet JU~,~ 0 7 ]990 8967 feet Junk(measured) AJ~J~l,0il & Gas COns. c0allljat~.n Size Ceme~ed Measured ~0~e Ve~ical depff 20" 300 sx Permafrost 80' 80' 13-3/8" 2750 sx Fondu & 400 sx PF 2664' 2664' 9-5/8" 500 sx Cl 'G' 9933' 8758' 7" 300 sx Cl 'G' 10870' 9396' measured 10041-10059'; 10064-10077'; 10084-10162'; 10178-10218'; 10230-10250' true vertical 8842-8856'; 8860-8870'; 8876-8935'; 8947-8978'; 8987-9002' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9588' MD; 4-1/2", 12.6~, L-80, PCT tail @ 9651' MD Packers and SSSV (type and measured depth) Brown 3-H packer @ 9578' MD; 5-1/2", Camco Bal-0 SSSV @ 2195' MD 13. Attachments Description summary of proposal ~ ' i 4. Estimated date for commencing operation ~ June 1990 16. If proposal was verbally approved 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 Sr. Area Operations Engineer FOR Cl3MMI~ION U~F ONLy Conditions of approval: Notify Commission so representative may witness Plug integrity . BOP Test Mechanical Integrity Test. Approved by order of the Commissioner Location clearance Subse(~uent formreQuired, l 0- ORIGINAL SI[~NED uY ' LONNIE C. SMITH. , Form 10-403 Rev 06/15/88 403 DMS cc: J. Gruber, ATO-1478 P1112-12]W1-3 Detailed operations program BOP sketch ~x 15. Status of well classification as: Oil ~ Gas m Suspended .. ~tu/'ned Date I Approval No. ~_. ~// Date ~./~/~/~ SUBMIT IN TRIPLICATE ( Drill Site 12-12 ARCO Alaska, Inc. intends to perform an HCI acid treatment on DS 12-12. The treatment will be performed as follows: 1. Obtain a wellhead fluid sample and perform emulsion and sludge tests with all stimulation fluids. 2. Load the casing annulus with dead crude. 3. Mix 6000 gals of 12% HCl acid with additives. Titrate acid and test for iron content. 4. Pump the above-noted fluid in four equal stages, using oil soluble resin (OSR) diverter in 2% NH4CI water between stages, and 1200 gal. methanol before and after the acid. 5. Pump 1800 gal. diesel for OSR cleanup and displace with 238 bbls dead crude. 6. Unload the well immediately and obtain a stabilized test following cleanup. RECEIVED JUN o ? 1990 Oil & Gas Co.s. Commission Anchorage 5 4 2 COILED I*UBI. NO UN]T BOP EOU ] PHE ~ 1. 5000 PSI ?" W[LLHr. AD CONN£CTOR FLANG£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI4 1/6" HYD~LC SLIPS 4. 5000 PSI4 1/6" SHEAR RAMS 5. 5000 PSI4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 H]REL]NE BOP EOUIPHENT I I I i 1. 5000 PSI ?" WELLHEAD CONNEC10R FLANGE 2. 5000 PSI WlRELIN[ RAtdIS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 Peal4 1/6" FLOW TUBE PACK-Orr F'.O. BOX toe36e ANCHORAGE, ALASKA 995t DATE' 4-24-89 REFERENCE: ARCO CASED HOLE FINALS t-tA 4-&-89 PRODUCTION F'ROFILE RUN 2, 2-t6 J-25-89 TEMP RUN 9-t4 3-2~-89 CCL/X-Y CALIF'ER RUN 9-t6 4-~4-89 COLLAR/PERF RUN 9-~8 4-t J-89 CBI' RUN 9-J8 4- t 3-89 CET RUN t t-6 3-15-89 PRODUCTION PROFILE RUN 2, ~t-t7 4-t5-89 COLLAR/PERF RUN ~t-t8 4-t6-89 COLLAR/F'ERF RUN ~2-4 3-2~-87 PRODUCTION PROFILE RUN t2-t2 ~-t9-89 PRODUCTION PROFILE RUN t2-~3 3-~6-89 PRODUCTION PROFILE RUN t2-t7 3-t8-89 PRODUCTION PROFILE RUN ~-'~ ~ 3-~7-89 PRODUCTION PROFILE RUN ~8-t6 ~-26-87 TEHP RUN ~8-2~ ~-29-89 COL RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS' RECEIF'T OF' DA'FA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-~529 _ ! ED 2'&5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' CAMCO CAMCO CAMCO ATLAS $CH $CH CAMCO A TI_AS ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES ~,~' PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTEN$ I ON EXPLORAT I ON ~ ~ BF'X EXXON ~ STATE OF ALA~'KA MARATHON ~'- TEXACO MOBIL F'.O. BOX ~ 0(-)368 ANCHORAGE, AL'ASKA 995J(~ DATE: 4-?-89 REFERENCE: ARCO PRESSURE DATA 2-2 3-26-89 BHP--$TATIC GRADIENT OTIS 2-~3 3-26-89 BHP--$'FATIC GRADIENT OTIS 2-~6 3-23-89 BHP--$TATIC GRADIENT CAMCO 2-~? 3-22-89 BHP--$TATIC GRADIENT OTIS 2-~8 3-38-89 BHF'--$TATIC GRADIENT OTIS 7-3 3-30-89 BHP--£TATIC GRADIENT CAMCO ?-~? 3-3~-89 BHP--$TATIC GRADIENT CAMCO 7-22 3-3~-89 BHP--$TATIC GRADIENT CAMCO 7-29 3-38-89 BHP--$TATIC GRADIENT CAMCO 7-38 3-J~-89 BHP--$TATIC GRADIENT CAMCO i2-4 7-20-89 BHP--FLOWING GRADIENT CAMCO t2-i2 3-i9-89 BHP--FLOWING GRADIENT CAMCO t3-i4 3-3i-89 BHP-'$TATIC .GRADIENT OTIS t4-32 3-30-89 BHP.--$TATIC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVED BY ATO-~ 529 ' ~"~~ APR 1 1 1989 '"' TRAN$~ 89f':~5 Alaska Oil & Gas Cons. Commission Anchorage D'ISTRIBUI'ION CENTRAL FILES ~ . F'HIELIP$ CHEVRON PB WELL FILES ... R&D EXTENSION EXPLORATION ~ .. BF'X ~ EXXON .., ~ $TATE OF ALAEKA MARATHON ~ TEXACO ~ MOBIL · ~ ARCO Ataska, Inc· I::'·0. Box J i)O~&(~ Anchorage, Alaska 995~ E) DATE: Hay 29, ~987 REFERENCE: ARCO F'ressure Da'l'a ~-29 5-t6-87 Static BftP Otis 3-.5 5- ~ 8-8? ~ t m ~ i c BHF' C, 1 i .s' 9-t3 5-t8-87 $~a~ic BHP ()'tis t2-t2 5-t7-8'? ,S'~at i c BHP O~i.s ~ 6-24 4--L~G--87 F:'~-es.zure ]B~l i Ld--Up O~ i ~ F'tease sign and r'e~'urn 'l'he attached ('.'opy aS receip't of data. I:;:ece i red By ............ TRAN$ ~-87278 //~ .Alaska 0il & Gas Cons. Commission A p p r o v ecl ............ ..'..~. .......................................... Ar~cl'to;'~qe DISTRIBUTION · '" F'hi llips (~e,n'tra l I:." i les ',' C. hevron F'T ~.:,'.'. ' ' ""i !.es '"' R&D '~ I) & M '~' '11' '~ ,S'oh i o Ex~er~.sion Exptora~ion .,,. ~ S'ta~e of ALaska' '"' E x x o n '"' 'Ir "' 'r e X 8 C 0 H a r a 'l' h o n ',' · "' Hob i t · Ir , ('" STATE OF ALASKA i' /~ ALASKAb~L AND GAS CONSERVATION CO,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL ~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-83 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20610 4. Location of well at surface 9. Unit or Lease Name 1015' N & 751' W of SE cr, Sec. 18, TiON, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 3609' N & 3437' W of SE ct, Sec. 18, T10N, R15E, UM 12=12 At Total Depth 11. Field and Pool 4067' N & 3662' W of SE cr, Sec. 18, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 71' RKBI ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 118. No. of Completions 07/02/81 07/19/81 07/26/81 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10870'MD, 9396'TVD 10203'MD, 8967'TVD YES ~ NO [] 2195 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL, BHCS, GR, SP, FDC~ CNL, CBL, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-/+O Surf. 80' 30" 300 sx P~_rm~frost 13-3/8" 72.O~ L-80 Surf. 266/+' 17~" 2750 sx Fondu & /+00 sx PF 9-5/8" /+7.0~ L-80 Surf. 9933' 12~" 500 sx Class "G" 7" 29,0~ " L._~_8.0 Surf, 10870' 8~." 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) *100/+l-lO059'MD 88/+2-8856'TVD 4 SPF 5% 9651 ' q~7R' '1006/+-10077'MD 8860-8870'TVD /+ SPF 1008/+-10162'MD 8876-8935'TVD /+ SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10178-10218'MD 89/+7-8978'TVD /+ SPF DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED * Added on 7/1/+/86 Ref: BHCS 7/20/81 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 1/1/82I Flow~,m Date of Test Hours Tested PRODUCTION FOR ~1L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/15/~ ~ 5.0 TEST PERIOD I~ l~.n ~7 lZ,& ~I .v~;~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. /+1/+ 550 24-HOUR RATE I~ 537/+ /+112 702 27 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. FEB o 2 BI 7 AI~a 0tt & G~s ConS. commission Anchorage Form 10-407 Submit ir, duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Top Sadlerochit O/W Contact GEOLOGIC MARKERS j I::OHMAI' ~ON '['ES'['L; MEAS. I.)EPI'H [; TRUE VERT. DEP% H jj 10028 ' i~ 8832 I N/A , · ~ , Base Sadlerochit 10775' 9400' 32. I hereby certify that the foregoing is true an('] correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali 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 rneasurernents given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than ()ne 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 2-.3: Attache. d ;supplemental records for this well should show the details of any multiple stage cement- ing and the Ioc'atJo'ri 'd.'.f the cementing tool. Item 27: Methodi'.0f. Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- .jection,'-Gas Injection, Shut-in, Other-explain. Item 28: If no cores taker), indicate "none". I-orm 10-407 .,- STATE OF ALASKA I~.'. ALASI;I,. OIL AND GAS CONSERVATION COM SION 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. Aql,d re~is vos~: Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 1015' N & 751' N of SE cr, Sec 18, T10N, R15E, UM At3t~89o~f Productive interval N & 3437' N of SE cr, Sec. 18, T10N, R15E, UN At3~)e9c~tiv~d~P~437' N Of SE cr, Sec. 18, T10N, R15E, UM At4t~b~'d~tr~ 3662' N of SE cr, Sec. 18, T10N, R15E, UM 5. Datum elevation (DF or KB) 71' RKB Feet 6. Unit or P~,ope['~y nar~e vruanoe ~ay Unit 7. Well number DS 12-12 8. Approval number 81-83 9. APl number 50-- 029-20610 lO. POO~rudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10870 feet Plugs (measured) 9396 feet Effective depth: measured true vertical feet Junk (measured) feet Casing Length CondUctor 80' Surface 2664' Producti on 9933 ' Liner 1251' Perforation depth: measured true vertical Size 20" 13-3/8" 9-5/8" Cemented Measured depth True Vertical depth 300 sx Permafrost 80' 80' 2750 sx Fondu & 2664' 2664' 400 sx PF 500 sx Class G 9933' 8758' 7" 380 sx Class G 10870' 9396' 10041-10054' 10064-10077' 10084-10162' 10178-10218' 8842-8856' 8860-8870' 8876-8935' 8947-8978' Tubing (size, grade and measured depth) 5~", 17#, L-80, 9651'MD Packers and SSSV (type and measured depth) Brown 3-H Packer (a g578'MD, Camcn RAI-(1 .~.~.~V 0 ?lq.~' 12. Stimulation or cement squeeze summary Kl:Lt:lVCU Intervals treated (measured) Treatment description including volumes used and final pressure FEB 0 2 1987 Alasl(a 0il & Gas Cons. Commission Anchorage 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 4475 3400 550 550 400 Subsequent to operation 5200 4585 670 550 420 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledgeC~,-w '--~r~'7~'~;'T"~ o~.,, rT''' ~'~' Signed Form 10-404 Rev. 12-1-85 JEH (265-6859) Title Operations Enqineering Manager Date Submit in Duplicate DS 12-12 Additional Perforations Began perforating operations 7/14/86. Rigged up perforating unit; pressure tested surface equipment. RIH w/gun #1, shot 10064-10077'MD, 4 SPF (ref: BHCS 7/20/81). POOH, all shots fired. RIH w/gun #2, shot 10041-10059'MD, 4 SPF (ref: BHCS 7/20/81). POOH, all shots fired. RD and turn well over to production. ARCO Alaska, Inc. ~ Prudhoe Bay~,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 27, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-12 Permit No. 81-83 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/TAB:sd Enclosure cc: Standard Alaska Petroleum Co. File PI(DS 12-12)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany STATE OF ALASKA ALASI~.' .)IL AND GAS CONSERVATION COMN'I: 51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon "- Suspend - Operation Shutdown .-' Re-enter suspended well - Alter casing - Time extension- Change approved program- Plugging '~, Stimulate- Pull tubing- Amend order- Perforate ~ Other 2. Name of Operator ARCO Alaska, 1nc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 1015' N & 751' N of SE cr., Sec. 18, T10N, R15E, UN At top of productive interval 3609' N & 3437' N of SE cr., Sec. 18, T10N, R15E, UM At effective depth 3609' N & 3437' W of SE cr., Sec. 18, TION, R15E, UM At total depth 4067' N & 3662' W of SE cr.. Sec, 18, TION, R15E, UM 11. Present well condition summary Total depth: measured 10870 feet Plugs (measured) true vertical 9396 feet 5. Datum elevation (DF or KB) 71' RKB 6. Unit or ~,O~ae~t~en~r~ Un it 7. Well number DS 12-12 8. Permit number 81-83 feet 9. APl number 50-- [3?9-20610 10. Pool Prudhoe Bay 0il Pool Effective depth: measured feet Junk (measured) true vertical feet 10203' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 20" 2664' 13-3/8" 9933' 9-5/8" Measured depth 300 SX Permafrost 80' 2750 SX Fondu & 400SX PF 2664' 500 SX Class "G" 1251' 7" 380 SX Class "G" measured 10084'- 10162' 10178'- 10218' true vertical 8876'- 8935' 8947' - 8978' Tubing (size,. grade and measured depth) 5~" 17# L-80 9651' MD Packers.and SS~V. jty. pe ~nd m,~a.~l,t~..d,~l.e, pth)., ~rown J-H racker La ~b/~ mu, ~amco BAL-O SSSV ~ 2195' 9933' True Vertical depth 80' 2664' 8758' 10870' 9396' 12.Attachments Description summary of proposal © Detailed operations program ~*'""§~q~ketch [] 13. Estimated date for commencing operation July 1, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,,~ertify that the foregoing is true and correct to the best of my knowledge Signed 2~"~/~,~~-~ Title Operations En~ineerin0 Manager -- Commission Use Only Date '~ ~'/~ Conditions of approval Approved by Notify commission so representative may witness '1 Approval No. [] Plug integrity [] BOP Test [] Location clearancel .......... '~': ..... -- by order of ?~, ~...~',~..~ ~; S~IT~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 12-12 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 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref' BHCS 7/20/81 Proposed Perforation Intervals' 10041' - 10059' MD 10064' - 10077' MD 8842' - 8856' TVD 8860' - 8870' TVD · ~ STATE OF ALASKA ALASI~,. ,).IL AND GAS CONSERVATION ~'". MMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AN_[] 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] -- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-83 3. Address 8. APl Number P.O. Box 100360, Anchora§e, Alaska 99510 50-029-20610 -- 4. Location of weal at surface 9. Unit or Lease Name 1015' N & 751' W of SE cr. Sec. 18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 3609' N & 3437' W of SE cr. Sec. 18, T10N, R15E, UM DS 12-12 At Total Depth 11. Field and Pool 4067' N & 3662' W of SE cr. Sec. 18~ T10N~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.)/ 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 71' R_KB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 7/2/81 7/22/81 7/26/81I -- feet MSLI 1 17.10870Total, DepthHD (M D+TV D) 18. Plug10837Back, [VID Depth (MD+TVD) y19'EsDirectional~] SurveYN O []II 20.2201Depth where feetSSSVM setD 21. Thickness1900 ' agprox°f Permafrost 22. Type .Elec.tric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ZU~ 94~, u-4u 5urn. 80' 30" 300 sx. Permafrost '. 13-3/8" 72~ L-80 Surf. 2664' 17~" 2750 sx. Fondu & 400 s:~ Permafrost 9-5/8" 47~A L-80 & Surf. 9933' 12~;" 500 sx. Class "G" S00-95 7" 29# L-80 9619' 10870' 8~" 380 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) 4spf 10084-10162' MD (78') 8875-8935'. TVD 5~" 9651' 9578' 8spf 10178-10218' MD (40') 8947-8978' TVD 8spf !0230-10250' MD (20') 8987-9003' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. (squeezed) ., · ..... DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED .. ', , . . . . : . 27. PRODUCTION TEST Date First Produc'ti0n : : ' I Me'thud of Oper'ation ('FloWing, gas'lift; e.tc,) ', 1/4/82 Flowing I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO 12/15/84 '4.0 TEST'PERIOD e '702 · :541 . '. 0 55I' 77.1 Flow Tubing ' Casing Pressure ' ' CALCUL'ATED' ' OIL-BBL ' ' GAS-MCF WATER-BBL OIL GRAVITY-APl (corr), Press.' 949 N/A' '. 24:HOUR RATE e 4212 3245 ~ .0 24.9° ., 28. CORE DATA ' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , - , , ' , , . . ' APR '9 I98¢ · , , A~ask..3 0ii~" Gas Cons. C.0mm%,,%,-...., ,, Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS NAME Top Sadlerochit MEAS. DEPTH ]0027' 1.0365' O/W Contact Base Sad]erochit 10774' 31. LIST OF ATTACHMENTS TRUE VERT. DEPTF 8831' 9090' 9399' 30. FORMATIQN TESTS Include interval tested, pressure data, all fluids recovered and gray fy, GOR, and time of each phase. 32. I hereby certify that the'l~oregoing is true and correct to the best of my knowledge Title ' 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 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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 ARCO Alaska, In{' Prudhoe B~,~ Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 16, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-16 Permit No. 77-37 DS 9-20 Permit No. 77-41 DS 12-12 Permit No. 81-83 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells· Very truly yours, · . Seheve DFS/m:/la Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaaka, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASK(' .)IL AND GAS CONSERVATION ~'. VIMISSlON SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~[ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 7. Permit No. 81-83 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20610 4. Location of Well 1015' N & 751' W of SE cr, Sec. 18, T10N,R15E,UM(Surface) 3609' N & 3437' W of SE cr, Sec. 18, T10N,R15E,UM(Top Prod) 4175' N & 3662' W of SE cr, Sec. 18, T10N,R15E,UM((TD) 6. Lease Designation and Serial No. ADL 28330 5. Elevationinfeet(indicateKB, DF, etc.) 71' RKB 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] ' Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Rroposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting anv proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 2/13/84. RU perf unit, pressure tested equipment. RIH with gun $1, flowed well,, shot 10139-10159' MD 4 spf (20' ref: CNL, 7/31/81), shut in well, POH, all shots fired. RIH with gun $2, flowed well, shot 10119-10139' MD 4 spf (20' ref: CNL 7/31/81), shut in well, POH, gun misfired. RIH with gun $2A, flowed well, shot 10119-10139' MD .4 spf (20' ref: CNL 7/31/81), shut in well, POH, all shots fired. Run in hole with gun $3, flowed well, shot 10099-10119' MD 4 spf (20' ref: CNL 7/31/81), shut in well, POH, all shots fired. RIH with gun $4, flowed well, shot 10081-10099' MD (18' ref: CNL 7/31/81), shut in well, POH, all shots fired. RD and secured well. 14. I hereby c,p.~rtify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of APproval, if any: Bv Order of Approved bY .COMMISSIONER the Commission Date __ Form 10-403 Rev. 7.1-80 Subm. it "Intentions" in Triplicate and "Subsequent Reports" i n Duplicate ARCO Alaska, Inc. Office{'J · 360 . Post Anchorage, Alaska 99510 Telephone 907 277 5637 February 24, 1984 Reference: Arco Cased Hole Finals D.S. 1-9 -- 1-8-84 D.S. 5-12 11-9-83 D.S. 6-3 11-14-83 D.S. 7-2~- 1-3-84 .D.S. 9-4 11-13-83 D.S. 12-12 9-9-83 -9-14-83 9-9-83 9-9-83 9-28-83 ~9-16-83 D.S. 14-4--- 2-4-84 D.S. 14-35 11-19-83 CPL/TDT-M w/listing CH CNL CH CNL CPL/TDT-M w/listing CH CNL Production Caliper Production Caliper HP Gradient Stops CET Caliper Presentation EPL CCL & perf Record CPL/TDT-M w/listing C L/vD 5" Sch Run 10 5" Sch Run 8 5" Sch 5" Sch Run 8 5" Sch Run 1 5" Sch Run 2 5" Sch Run 1 Sch Run 1 5" Sch Run 1 5" Sch 5" Sch 5" Sch Run 1 · 5" Sch sign and return the'attached copy as receipt of data. HAVE A NICE DAY! Kelly McFar land ATO-1429F Trans. #' 073 Chevron D & M Dallas Dril!ihg Exxon Getty Marathon Mobil DISTRIBUTION North Prudhoe R & D Caroline Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office/' .x 360 Anchorage.,~ aska 99510 Telephone 907 277 5637 February 2, 1984 Reference: Arco Pressure Data D.S. 2- lA '-" 1-7-84 _-1-7-84 D.S. 2-8 ~-- 1-8-84 f 1-8-84 ~.S. 2-10/'- 11-4-83 D.S. 2-15 <'" 11-10-83 D.S. 2-16" 11-10-83 D.S. 12-12 '~ 12-23-83 /'12-23-83 D.S. 12-3 ~-' 1-15-84 --1-15-84 D.S. 13-32"" 1-5-84 'D.S. 14-7f'' 12-22-83 D.S. 14-8/ 1-12-84 D.S 14-1/12-2'2-83 D.S. 14-33 -'-'1-6-84 D.S. 15-2 ~,z 12-23-83 D.S. 15-5 / 12-23-83 D.S. 15-6 .... 1-13-84 / 1-13-84 D.S. 15-13 J12-24-83 D.S. 18-7 ~' 9-17-83 Build-up PBU Data Sheet Build-up PBU Data Sheet Static Static Static Build-up PBU Data Sheet Build-up PBU Data Sheet Fall-Off Static Statiq Static Static Static Static Build-up PBU Data Sheet Static Build-up Camco Ca, co GO Camco GO GO Otis GO Camco GO DA Camco Camco Camco Camco Camco Camco Kelly McFarland ATO-1429F Chevron Trans. # 042 D & M Dallas Drilling Exxon Getty DISTRIBUTION North Geology Phillips Prudhoe Bay '~ C., .~, ,, ": ~.~ Sohio · ,., .... %3, ,~.,. c ,.~:.~,:3 .,~ ..... L,~,,,.~i~,,3~. Pl~~ease Marathon State of,Alaska Mobil sign and return the attached copy as receipt of data. ARCO Alaska, Inc.I Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 2, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 12-12 Permit No. 81-83 Enclosed is an "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/TPA/la Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASK/~' .IL AND GAS CONSERVATION C( ,'1MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL L3 COMPLETED WELL [] OTHER [] .~ / 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360~ Anchorage~ Alaska 99510 4. Location of Well 1015' N & 751' W of SE cr Sec. 18, TION, R15E, UM 3609' N & 3437' W of SE cr Sec. 18, T10N, R15E, UM 4175' N & 3662' W of SE er Sec. 5. Elevationinfeet(indicate KB, DF, etc.) __ 71 t WER 12. TiON; RI 5E: DM I 6. Lease Designation and Serial No. AT)T, 9R'430 7. Permit No. 81-83 8. APl Number 50-- 029-20610 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D,S, 12-12 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed Work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 12-12 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricators 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. Proposed Perforation Interval: Zone 4 1008h-10162' MD Ref: BHCS 7/20/81 ...~b,~eq~]ent Work Reporte~l , No./ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. . Signed ~~lv~.. ~~_ ~~_~..~,,~.__ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved by App.roved Copy Returned ....... ........... By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Ofiice{e' ( 360 ,.V, nc.-.a:'a~e. ,.. ~-s.kc ,--:.it-.r. hc-~e 907 27T December 19, 1983 Reference: Arco Cased Hole Finals D.S. 1-6 10-31-83 Caliper Log 11-11-83 Caliper Log D.S. 12-12 10-26-83 Spinner Log Run 1 5" Camco ~n 1 5" Camco Run 1 5" Camco sign and return the att.ached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 678 DISTP~I~UTION Chevron. North Geolog7 D & M Phillips Dallas Prudhoe Bay Marathon State of Alaska ,~ 0~ ~ gas ARCO Alaska, Inc. Post Office I~' 360 Anchorage. A~,~ska 99510 'l'ei,=cno,',e 907 ?77 =.~'2..~ August 29, 1983 Reference · Arco Cased Hole Finals D.S. 3-19 '" 7-2-83 CBL/VD D.S. 4-8 / 6-22-83 EPL D.S. 5-17~/ 6-24-83 EPL D.S. 6-9/ 3-3-83 Epilog D.S. 12-12/ 6-24-83 CET 7-23-83 CCL & Perforating'Record 7-21-83 Completion Record D.S. 13-3 / 3-13-83 Epilog D.S. 13r7'"' 3-12-83 Epilog D.S. 14-5/ 8-22-80 Epilog D.S. 14-7/ 1-12-81 Epilog 3-9-83 Epilog D.S. 14-9B ~'" 3'-11L83 Epilog D.S. 14-24/ 6-30-83 CBL/VD D.S. 14-26~/ 2-27-83 Epilog D.S. 16-11`,/ 7-30-83 Spinner.Log Run i 5" Sch Run 2 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch Run 1 .5" Sch Run 1 5" Sch Run 1 5" DA' Run 1 5" DA Run 1 5" DA Run 1 5" DA Run 2 5" DA Run 1 5" DA Run 1 5" Sch Run 1 5" DA 5" Camco .///P1/e~se sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 492 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe Bay R & D ...... ,,' ..>' '. ~,. ..... Sohio ' --' ' ' '~.,. State of Alaska ARCO Alaska, Inc. ~ Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 March 11, 1983 Reference: Arco Cased Hole Finals D.S. 1-24 ~"1-19-83 EPL 1-18-83 CBL/VD D.S. 1-25~/ 2-13-83 CBL/VD %~1 D.S 2-20' 1-27-83 Perforating Record D.S. 3-15J 12-9-82 CNL/GR/MSN ~--D.S. 6-11 11-29-82 CNL/GR/MSN D.S. 12-12a 2'223-83 Temperature Survey D.S. 12-17~'1-28-83 Temperature Log D.S. 13-2A~"2-7-83 CBL/VD 1-29-83 "Tubing Puncher Record D.S. 13-9J 1-24-83 CEL 1-~7-83 1-30-83 1-?-83 2-3-83 1-28-83 1-28-83 CET CBL/VDL & Waveforms Temperature Log EPL CCL & Perf Record CET D.S. 14-15/ 12-15-82 CNL/GR/MSN D.S. 16-13/12-10/11-82 CNL/GR/MSN Run 1 2" & 5" S Run 1 5" Sch Run 1 5" Sch Run 2 5" DA Run 1 5" Sch Run 2 5" DA Run 2 5" DA Run 1 5" Camco .Run 1 5" Sch Run 1 5" Sch Run 1 5" Sch Run. 1 5" Sch Run 2 5" Sch Run 1 .5" Sch Run 1 5" Sch Run 1 5" Sch Run 2 5" Sch Run 3 5" Sch Run 2 5" DA Run 2 5" DA P~~le'as'e sign and return the at'tached copy as receipt of data. .Kelly McFarland AFA-403 Trans. # 207 ,, NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON MOBIL' · ,ETT , ~'~' ' '~'3_ ~"J~' -- '~"'~t'~ O & M STATE OF ALAS~ DALLAS 'c~ CAROLINE SMITH ~;~.. , ARCO Alaska, Inc. Post Office Box 360 Anchorage. ~* ka 99510 Telephone 9G..,77 5637 September 15, 1982 Reference: Arco Pressure Data D.S. 12-12 6-22/23-82 -. Pressure Build-up Survey DA se sign and return the attached copy as reciept of data. Kelly McFarland AFA-403 Trans. # 472 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON DALLAS .~, ...; :. ,~ .,, .., ,, ,... ~ ... ,, ~.~ ~ ', ' : : . ,. ?,!, ... ". v .-,?.,.,. ALASKA STATE OF ALASKA ... AND GAS CONSERVATION CO5~ 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 RE: .SS I ON Receipt of the following material which was transmitted via is hereby acknowledged. QUANT I TY DESCRIPTION RECEIVED: DATED.: Copy sent YE.S Z 'r to sender NO June 23, 1982 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-12, Corrected Bottomhole Location Dear Elaine: The DS 12-12 completion report, dated September 17, 1981, incor- rectly lists the BHL as: 4175' FSL, 3662' FEL, Sec. 18, TION, R15E, UM The correct location is: 1213' FNL, 3662' FEL, Sec. 18, TiON, R15E, UM Sincerely, Gruber Associate Engineer JG:llm cc: M. Kellis, AFA 403 R. W. Crick, ANO 912 G. Arnold, ANO 927 Op. Engr. Coord., PBOC 103 Well File GRU1/L34 ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany ARCO Alaska, InC. B{~, Post Office ., 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 25, 1982 Mr. C.D. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Subject: D.S. 3-8 Permit No. 76-73 D.S. 12-.10 Permit No. 81-53 D.S. 12-11 Permit No. 81-73 '.'.'.D~.S., 12-12 'Permit No.. 81-83 Enclosed are Completion Reports for work done on the above-mentioned wells. Ve_~ry truly yours, /~..~5. F. Scheve District Operations Engineer DFS: TKKW: role Enclosures Distribution: Sohio Petroleum Co. R CElVEI) MAY 2 7. 982 Oil & Gas Cons. Comm~ew A~chorage ARCO Alaska, Inc. is a subsidiary of A~.lanticRichfieldCompany ALASKA .~. AND GAS CONSERVATION C ..MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL:I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-83 - 3. Address B. APl Number P.O. Box 360 Anchorage, Alaska 99510 50-029-20610 4. Location of well at surface 9. Unit or Lease Name 1015'N & 751'W of SE cr Sec 18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 3609'N & 3437'W of SE cr Sec 18, T10n, R15E, UM D.S. 12-12 _~toTotal Depth 11. Field and Pool ~~ & 3662'W of SE cr Sec 18~ T10N, R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Prudhoe Oil Pool 71' RKBJ ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore J 16. No. of Completions 7/2/81 7/22/81 7/26/81 feet MSLJ 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MI~TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10870MD 10837MD YES~ NO [] 2201 feet MD1 1900' (approx) 22. Type Electric or Other Logs Run 9[L/SP/]mCS/OR, ~9C/CNL 23. CASING, LINER AND CEMENTING RECORD , · . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 80' 32" 300 sx Permafrost 13-3/8" 72~/ L-80 Surf 2664' 17-1/2" ~.750 sx Fondu & 400 sm Perm~fros ' ' 9-5/8" 47# L-80 &, Surf , ,". 9933." 12,,1/4,.,. 500 s×' Class..G' - S00-95 ' ' 1 7" 29# L-80 9619' 10870' 8-1/2" 380 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) 5-1/2" 9651 9578 8 shots per foot ,. ,. ' 10178' - 10218'MD 8947'-9003'TVD ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 1023.0' - 10250'MD, . , Oi/.O,,I./.~L.'' .. ~ ..:D.EPTH .INTERVA.L .(MD) AMOUNT& KIND. OF MATERIAL'USED · , ., · . ., , 27. pRODucTION TEST Date First production ' I Method of Operation (Flowing, gas I.ift,.etc.) .' ' ' 1-4'82' ,' : ' ~'"I 'Flowi~g ' ' "~ .... ..,, .' :, .' :., .;'" ~ ,, Date of Test Hours Tested PR,gDUGTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 3-12-82 11.1 TEST, pERIOD I~ 2050 ,. 855,: ,. 67 .50 'I 625 Flow Tubing Casirig Pressure" CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) .... ' '' ' 1~ . 3.943" 1'.2,,.4.66 ,, 148 .. 24.2 Press.t 7.6'9 .... NA., 24-HO.UR RATE ., 28. " C'ORE DATA -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . ,. · .. ,', , " ,. ,' RECEIVEI) . . ".. '" "" " :: MAY 2,7.1982 .. Alaska Oil & Gas Cons. Co~missi0n Form 10-407 Submit in duPlicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS ._ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadleroch±t 10027 8831 Oil/Water 10365 9090 Base Sadlerochit 10774 9399 ¢ --.. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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 STATE OF ALASKA ~, ' ALASKA(~,~L AND GAS CONSERVATION C .,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:IE~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-83 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50- 029-20610 9. Unit or Le_~se Name Prudhoe Bay Unit (surface) 4. Location of Well 1015'N & 751'W of SE cr Sec 18,T10N,R15E,UM 3009'N & 3437'W of SE cr Sec 18,T10N,R15E,UM (top producing interval) 4175'N & 3662'W of SE cr S.ec6 18,T10N,R15E,UM 5. Elevation in feet (indicate KB, DF, etc.) / . Lease Designation and Serial No. RKB 71' ADL 28330 (TD) 10. Well Number D.S. 12-12 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing I-I Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operations 12-31-81. Pressure tested tree, casing and wireline perforating equipment. Perforated 10178-10218' and 10230~10250'MD (ref BHCS 7/20/81) with 8 shots per foot. Ran static BH pressure. Ran.and set SSSV and tested same. Installed and tested tree cap. Released well to Production Department. 1-4-82. Alaska 0il & (]as Cons. Commission tu~chorage 14. I hereby c.,~¥ that the foregoing is,true and correct to the best of my knowledge. The spac,e~ow for Commission use Conditidhs of Approval, if any: Enqineer · Date Approved by Form 10~,03 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Rex 360 ,, Anchorage. ,.¥ :3 90510 Telephone 90,~ ..77 5637 February 5, 1982 Reference: ARCO CASED HOLE FINALS D.S.7-6 1/8/82 Collar Log & Perf Log Run 5 5" D.S.12-4A 1/7/82 ACBL/VDL/GR Run 1 5" D.S.12-10 1/3/82 Collar Log & Perf Log Run 1 2"/5" D.S,12-12 1/1/82 Collar Log & Perf Log Run 1 2"/5" D.S.12-14 1/27/82 Borehole Audio Tracer Run 1 5" D.S.16-2 1/25/82 Cont Flow Survey Run 1 5" Please sign and return the attached copy as receipt of data. Mary F..Kellis North Engineering DISTRIBUTION Transmittal # 948 NORTH GEOLOGY R&D DRILLING PHILLIPS SG~O' MARATItON, CHEVRON ARCO Ala'$ka, In~;, iS a sub',ldl~ryl OI AIl,ltlllcRichheldCompan¥ EXXON M'OBIL GETTY D&M' .GEOLOGY STATE OF ALASKA RECEIVE Al..qsk~'t..-.,, UiF~ [-;as COnS.i Anchur~go ARCO Alaska, Inc> Post Office~'-- .' 3': 0 Anchorag;: .... :'-:ka .q~5 ~ r Telephono 9,~7 277 ';~"..:.., ~' October 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: D.S. 12-9 Permit No. 80-93 D.S. 12--10 Permit No. 81-53 D.S. 12-11 Permit No. 81-73 D.S. 12~12 Permit No. 81-83 Enclosed are our Sundry Notices'detailing the work to be done on the above mentioned wells, Very truly yours, ,: ...... G/'A. Rochon District Operations Engineer JAR/TKKW/kam Enclosures STATE OF ALASKA ~ ALASKa('. _~ILAND GAS CONSERVATION ~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Name of Operator DRILLING WELL [] COMPLETED WELL:~] OTHER [] ARCO Alaska, Inc. Address P.O. Box 360, Anchorage, Alaska 99510 Location of Well 1015'N & 751'W of SE ct., Sec. 18, T10N, R15E, UM - Surface 3009'N & 3437'W of SE cr. Sec. 18, T10N, R15E, UM - Top of Interval 4175'N & 3662'W of SE ct. Sec. 18, T10N, R15E, UM- TD 7. Permit No. 81-83 5. Elevation in feet (indicate KB, DF, etc.) 12. 8. APl Number 50-029-20610 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 12-12 11. Field and Pool Prudhoe Bay Field on and Serial No. Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO proposes to perforate selected intervals within the Sadlerochit for production. The perforated intervals will be.reported on a subsequent report. A 5000 PSI WP BOP/ lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. The well will be flowed to the Flow Station for clean up. 14. I h~~.~hat ~re~[~ The spac. ,~ow for Commission use 0CT 2 8 ,3 9 ,i · '!~$ka Oil & Gas Date Conditions of Approval, if any: true and correct to the best of my knowledge. TitleD±strict Operations Engineer Approved by__ Form 10-403 BY [~,~I~IE C. SJ~lTff COMMISSIONER Approved Copy Retumed By Order of the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B Anchorage, Alask,3 99510 Telephone 907 277 5637 Oct'ober 9, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject. Dear Sir- Completion Gyroscopic Surveys Enclosed please find the completion Gyroscopic~/$urvey for the following wells- 'DS: 12-1.2'~:?DS 17-71, DS 17-9, A-5~A-6, q~-6~ and B-7.J/ ' , , Sincerely, P. A..VanDusen District Drilling Engineer PAV-cm Enclosures ARCO Alaska. Inc. is a s~Jbsid~nry of AllnrHi~. RichlieldCompany October 9, 1981 Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Dear Mr~ VanDusen; We have recently received completion reports on several wells where the reported bottom hole location cannot be verified by the directional surveys that have als0 been submitted. The list of the wells in question is enclosed. We would appreciate your checking .to determine the data used in arriving at the bottom hole locations for these wells. Since w~ have' an internal program to cross-check the accuracy of the submitted data, .it is necessary to detemine why the discre- pancies exist. If you could have a member of the department that determines . this data call Mrs. Elaine. Johnson at 279-1433 it should pin- .point where and why there' are differences. Thank you for your help in this m~tter. Yours very truly, ~']arry W. Kugler Commi s si one r Enclosure }5~K= be ALASKA OIL AND GAS CONSERVATION COMMISSION IiELL I,OCATION DISCREPANCIES Kuparuk 25647 Kuparuk 25648 Kuparuk 25649 A-2 B-4 C-8 The following are all in the Prudhoe Bay Unit: DS 14-11 DS 14-19 DS 14-20 DS 16-4 DS 16-5 DS 17-7 DS 17-8 DS 17-9. ARCO Alaska, Inc. Post Office 15I,. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 28, 1981 Mr. Harry Kugler State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS 16-4 West Sak #18 DS 12-12 DS 16-5 A-2 DS 14-9A DS 16-14 A-3 DS 14-19 DS 17-7 B-4 DS 14-20 DS 17-8 C-8 DS 16-1 DS 17-9 Dear Sir: Enclosed please find the Completion Reports for the following wells: A-2, A-3, B-4 and C-8. Although these Kuparuk wells have been per- forated, production test data has not been obtained; this information will be forwarded to your office when available. Also enclosed are Completion Reports for the following wells: DS 12-12, DS 14-19, DS 14-20, DS 16-4, DS 16-5, DS 17-7, DS 17-8 and DS 17-9. Production test information is not applicable for these Wells since they have not yet been perforated but will be submitted to your office when we obtain the information. Previously unreported information such as locations for bottom hole, producing interval and geological forma- tions have been added to the updated Completion Reports. DS 14-9A and West. Sak #18 have been plugged and abandoned. An updated Completion Report with Drilling Histories. for these wel.ls is enclosed. Information ~egarding West Sak #18 is of a confidential nature and we would appreciate securely storing the report where it will receive minimum exposure. The initial Gyroscopic Survey for DS 16-1 was unacceptable and. a rerun is presently being authorized by our engineering staff. An updated Completion Report for this well will be sent to your office subsequent to our receivi.ng an acceptable survey. The remainder of the requested information - an overdue Completion Report on DS 16-14 and an incomplete Completion Report for DS 12-11 was sent to your office August 27, 1981 and was apparently enroute at the time of your September 2, 1981 letter to this department. Also included are completion Gyroscopic Surveys for DS 12-12, DS 17-7 and DS 17-9. Sincerely, RECEIVED SEP 0 1981 Alaska Oil & Gas Cons. Commjsslofl Anchorage STATE OF ALASKA 0 E ~ 6 I N )~ [ ALASKA 0/,-.,ND GAS CONSERVATION CO,~ ...SSION · WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL)~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] /J 2. Name of Operator 7. Permit Number ARCO A1 aska, Inc. ~ ..... ,,'"' , 81-83 3. Address U'? / 8. APl Number P,0, Box 360, Anchorage, Alaska 99510 .~-~.. --~. so- 020-20610 .. 4. Location of well at surface -¥LL~¢.,~.,¥¢-~ / 9. Unit or Lease Name IO15'N & 751'W of SE cr Sec 18, TION, R15E, UM ~ ~i~:~,.~a \ Prudhoe Bay Unit At Top Producing Interval 3609'N & 3437'W of SE cr Sec 18, T10N, R15E, UM \~'~' ~'-~'-~ lO. WellNumber m ~ ~ ~]~. ~ DS 12--12 A~o~al Depth~ 11. Field and Pool -4-1-TFy'N &-366~'W of SE cr Sec 18, TION, ELSE, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe 0i 1 Pool 71' RKB ADL 28330 12~a~puddedl 13. Date T.D. ReachedT/22/81 14. Date Comp., Susp. or Aband.7/26/81I' 5' Water Depth' if °ffsh°re--feet MSLI~6' N°' °f c°~p'eti°nsl 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 10870MD 10837MD YES [~X NO~ 2201 feet MD 1900' (approx) 22. Type Electric or Other Logs Run D[L/SP/BHCS/GR, FDC/CNL, 23. CA~ING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED -20" 94# H-40 Surf 80 32" 300 sx Permafrost ]3-3/8" 72# L-80 Surf 2664 17-1/2" 2750 sx Fondu & 400 sx Permafrost 9-5/8" 47# L-80 & 'Surf 9933 12-1/4" 500 Sx Class G . S00-95 7" 29# L-80 9619 10~870 8-1/2" 380 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') 5-1/2" 9651 9578 n/a .,, ,. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. " : DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL 'USED . . ; ... . . .~' .:. _ ', . n/a . : . . . ,. 27. PRODucTION TEST ' =,, Date' Firs't P.rbduetqon'. ' I Meth.°d of Operation (Flowing, gas lift, etc.).. n/aI ~ . , ' Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO .... .. '. .." TEST PER OD I~ .. .. Flov~,T. ubing · Casing Pres.sure CALCULATED. OIL-BBL GAS-MGF .WATER-BBL OIL GRAVITY-APl (corr) Press. ~. ... '. .: 24-HOUR .RATE I~ :. 28. CORE DAT/~ ' Brief description of lithology, porosity, fractures, apparent dips and presence of, . .. oi,, gas or wats r. Submi~c~e~r~i V ED n/a . ' ... ', " ',, SEP 3 0 1981 . Naska 0il & Gas Cons, Commission " . .... ... .., Anchorage, · __ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit Oi 1/Water Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 10,027' 10,365' 10,774' 8831' 9090' 9399' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. n/a 31. LIST OF ATTACHMENTS Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Eng. Date 9/17/81 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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 ARCO Oil and Gas ~~mpany North Alaska~, strict Post Otlice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 16, 1981 Reference: ARCO DIRECTIONAL SURVEYS D.S.17-7 8/31/81 Gyroscopic D.So12-12 8/31/81 Gyroscopic D.S.17-9 8/31/81 Gyroscopic Job No. 5257 Job No. 5256 Job No. 4469 's sign and return the attached copy as receipt of data . , Mary F. Kellis North Engineering Transmittal ~/599 , . DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D'&M GEOLOGY STATE OF ALASKA, EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Oivlswon OI AtlanticRichfieldCompany September 2, '1981. Mr. P..A. Van Dusen District Drilling Engineer Arco Alaska, 'Inc. P.O. Box 360 Anchorage, Alaska 99501 Re~ Overdue Data Submission ~ear Mr. Van Dusen: Wells on the attached lists ~are those, for which Completion ~eports (form 10-407) are either incemplete or. apparently overdue, with completion,i abandonment, or suspension dates prior, to 'August 1,' 19'81... i : , The first list is of those wells for which an incomplete Completion Peport was filed, with the' comment that the locations at the top of the producing interval and at the total depth were be submitted" or "M/A." The'~completion dates go back to January 9. The 'second list is of .those wells for which available information indicates the wells have been cc~.~pleted, but the 30 day filing period has passed without a .Completion Report having been submitted. , We need to' be brought up~t°-date on directional survey proDlem$ that may be responsible for these late filings, or have the required directional surveys' and reports submitted to us. We would appreciate a response at your earliest convenience. Sincerely yours, · .../' ,., .... / .... ,,. Harry Kug let Commissioner hTWK/JAL/g P. A. Van Dusen ... (~,~eptember 2, I981 Incomplete Completion Reports Well Name and Number Comp 1 e t i on / Ab a ndo nme nt Suspension Date Prudhoe Bay Unit DS 16-1 Prudhoe Bay Unit DS 14-9A Prudhoe Bay Unit DS 16-4 West Sak 18 Prudhoe Bay Unit DS 16-5 Kupa ruk C-8 Prudhoe Bay Unit DS 14-19 Prudhoe Bay Unit DS 17-7 Prudhoe Bay Unit DS 14-20 Prudhoe Bay Unit DS 12-11 Kuparuk A-2 Prudhoe Bay Unit DS' 17.8 1-9-81 3-21-81 3-27-81 4-17-81 4-21-81 5-15-81 6-6-81 6-10-81 6-30-81 7-1-81 7-2-81 7-2-81 Overdue (?) Completion Rep_o_rts prudhoe Bay Unit DS 16-14 Kuparuk B-4 Kuparuk A-3 Prudhoe Bay Unit DS 17-9 Prudhoe Bay Unit 7-9-81 7-1~-81 7-24-81 7-25-81 7-26,-81 ARCO AlaSka, Inc. Post Office~''1~' 360 Anchorage, Ataska 99510 Telephone 907 277 5637 August 27, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-11 DS'12-12 DS 13-5 DS 14-11 DS 16-14 DS 17-9 DS 17-10 DS A-3 DS A-4 ,DS B-4 DS B-5 Dear Sir' Enclosed please find' · The Monthly Drilling Reports for DS 14-11, DS 13-5, DS 17-10, DS A-4. · The subsequent Sundry Notice for DS 16-12. e The Well Completion Reports for DS 12-11, DS 12-12, DS 16-14, DS 17-9, DS A-3, DS B-4, DS B-5. Sincerely, P. A. VanDusen District Drilling Engineer PAV/GLA:sp Enclosures ARCO AIn.~ka, II'~r i,~'~1 s~b$idinry of Allenlic,~irhli~,ld[~omp,lny · (" , STATE OF ALASKA ALASKA ~..,_ AND GAS CONSERVATION C ,...MISSION 0 J:JI GIN WELL COMPLETION O'R RECOMPLETION REPORT AND LOG_ AL 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED .'.--) ABANDONED .~ SERVICE '~. . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-83 ._ '3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 5o- 020-20610 4. Location of well at surface 9. Unit or Lease Name lO15'N & 751'W of SE cr Sec 18, TION, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number To be submitted DS 12-12 At Total Depth 11. Field and Pool To be submitted Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe 0i 1 Pool 71' RKB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. i 15. Water Depth, if offshore 116. No. of Completions 7/2/81 7/22/81 7/26/81j -- feet MSLJ 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10870MD 10837MD YES ~X NO [] 2201 feetMD 1900' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 80 32" 300 sx Permafrn~t 13-3/8" 72# L-80 Surf 2664 17-1/2" 2750 sx Fondu & 400 sx Permafrost 9-5/8" 47# L-80 & Surf 9933 12-1/4" 600 ~x £1a~ G S00-95 7" 29# L-80 9619 10,870 8-1/2" 380 sx Class G .. 24. Perforations open to Production (MD+TVD of Top and Bottor~ and 25. TUBING RECORD interval, size and number) . SIZE DEPTH SET (MD) PACKER SET (MD) -~-]/?" q~-~] 9578 n/a , , 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED n/a · . , . __ 27. PRODUCTION TEST Date First"Pro'duct. ion' "' " I Method.of Operation (Flowing, gas lift, etc.) . n/aI ' Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO " : '.' " , TEST PERIOD mm~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-"BL OIL GRAVITY-APl (corr) Press. ' 24-HOUR RATE .. ... 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. :. n/a ,:.,.,. .,.',. J ECEIVED AUG 1 1981 , , · .Alaska 0ii & Gas Cons. Commission, Anchorage Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 29, GEOLOGIC MARKERS 30. FORMATION TESTS NAME T. Sadlerochit B. Sadlerochit MEAS. DEPTN To be -~UE VERT. DEPTH submitted !nclude interv~;i .:e~t=.d, p'ess~:re data, eil ;h,'~d,~ recove,'ed GOR, and time of each phase. n/a 31. LIST OF ATTACHMENTS 32. . . -Br-H-q-~q Hi stoi-v -., I hereby certify that the foregoing ~$ true anocorrectto theibest of my knowledge u~st. Drig. En~t. 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 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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". DS 12-12 DRILLING HISTORY NU 20" riser. Spudded well @ 1000 hrs, 7/2/81. Drld 17½" hole to 2675'. Ran 67 its 13-3/8" 72#/ft L-80 cs§ w/shoe @ 2664'. Cmtd 13-3/8" csg w/2750 sx Fondu & 400 sx Permafrost. ND 20" riser. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd cs§ to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12¼" hole to 9949' Ran 253 its 9-5/8" 47#/ft L-80 & S00-95 csg w/shoe @..9933'. Cmtd ~-5/8" csg w/500 sx Class G cmt. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8½" hole to 10,870' TD. Ran DIL/BHC/GR/SP & FDC/CNL. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H2.0, ~...sx Permafrost C cmt & 132 bbls Arctic Pack. Ran 33 its 7" 29#/ft L-80, 8RD, AB MOD lnr fr/9619'-10870'. Cmtd 7" liner w/380 sx Class G. Drilled cmt to 10,837' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL. Ran 5½" completion assy w/tail @ 9651' & pkr @ 9578'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel w/30 bbl cap. on annulus..Dropped ball & set pkr. Tstd tbg to 3000 psi & ann to 200 psi - ok. Tstd tbg to 200 psi & ann to 1500 psi - ok. Clossed SSSV. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 1715 hrs, 7/26/81. AUG F 1 1981 A~aska Oil & Gas Oo~s. Oommfs~ion Ap. chorage SCIENTIFIC DRILLING INTERNATIONAL 1111 East 80th Street, Anchorage, Alaska 99502 · 907/349-3541 · Telex: 09025364 (SDC AHG) Subsidiary of AMF INCORPORATED August l, 1981 Job #5256 North Slope Drilling: Enclosed please find our Gyro Survey on Drillsite 12-12 along with our Vertical Section and Horizontal View maps. Also enclosed you will find the Calculations. If any other information is needed please call at 349-3541. Thank you for using Scientific Drilling International and please call again. Sincerely Manager RECEIVED SEP · 0 l,.qRI Oil & Gas Cons. Commission Anchorag9 :OMPLETION REPORT kRCO"OIL G GAS ~YROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION :OMPUTED FOR SDC BY FM L INDSEY & ASSOC 31 AUG 81 WELL D5 12"12 KB ELEV 71. FT. JOB NO 5256 RECORD OF SURVEY TRUE ¢~EAS. DRIFT VERTICAL ]EPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 0 0 0 0.00 100 0 0 100.00 200 0 0 200,00 300 0 0 300.00 400 0 0 400.00 500 0 0 500.00 '600 0 0 600,00 700 0 O 700.00 800 0 0 800.00 900 0 0 900.00 1000 0 30 999,99 -71.00 N O,OOE 29.00 N O,OOE 129,00 N O.OOE 229,00 N O.OOE 329,00 N O.OOE 429.00 N O.OOE 529.00 N O.OOE 629.00 N OJOOE 729,00 N O.OOE 829,00 N O,OOE 928.99 S84.48E 1100 0 0 1099.99 1028.99 N O.OOE 1200 0 30 1199,99 1128.99 $23.53E 1300 0 0 1299.99 1228,99 N O,OOE 1400 0 0 1399,99 1328,99 N O,OOE 1500 0 0 1499.99 1428.99 N O.OOE 1600 1 0 1599.98 1528.98 $57.08E 1700 0 30 1699,98 1628.98 S41.71E 1800 1 0 1799.97 1728.97 S40.35E 1900 i 0 1899.95 1828.95 $80.985 2000 0 0 1999,95 1928.95 N O.OOE 2100 1 0 2099.94 2028.94 N42.91E 2200 0 0 2199.94 2128,94 N O,OOE 2300 0 .45 2299,93 2228.93 $42,36E 2400 I 0 2399J92 2328,92 S32,00E TOTAL COORDINATES 0,00 S 0,00 W 0.00 S 0.00 W 0.00 S 0,00 W 0.'00 $ 0.00 W O"'O0.S 0,00 W 0.00 $ .... ~.,. 'O.OQ, W ..... O.OO"::"S",'~" ..O,,O0.'W-. ," , ,.... 0,00.$..,.,'? ...... "O.'O0'"W' 0.00",$ '" .i.O*O0"W..:::':.:' 0.00 S 0.00 W 0.26 N 0,28 E 0,52 N 0.57 E 0,58 N 0,88 E 0.64 N 1,18 E 0.64 N 1,18 E 0.64 N 1.18 E 0.99 N 1.81 E 0.14. N 2.80 E 0.84. $ 3.66 E 1.68 S 5,15 E 1.18 S 5.73 E 0.39 S 6,05 E 0.40 N 6.96 E 0,58 N 6.83 E 0.62 $ 7.75 E C L.O S U R E S DISTANCE ANGLE O M S I 0.00 S 0 0 0 W 0.00 S 0 'O 0 W 0,00 S O. 0 0 W , 0.00 $ 0 0 0 W 0,00 S 0 0 0 W 0.00 .S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0' 0 W 0.00 $ 0 0 0 W 0.38 N 47 45 90 E. 0.77 N 47 4.5 30 E 1.05 N 56 23 38 E 1,35 N 61 19 54 E 1.35 N 61 19 54 E 1,35 N 61 19 54 E 2.06 N 61 22 32 E 2,80 N 87 7 ~,2 E 3,76 S 76 '59 31 E 5,4.2 $ 71 54' 33 E 5,85 .578 19 55 E 6,06 S 86 17 42 E 6.37 N 86 23 15 E 6.86 N 85 6 23 E 7,78 S 85 21 31 E DOG LE6 SEVERITY DEG/iOOFT 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0,000 0.000 0.000 0,500 0.500 0,500 0.500 0,000 0.000 1.001 0,500 0.500 0.694 1.000 1.000 1.000. 0,750 0,250 ( SECT I ON DISTANCE 0,00 0,00 0.00 0.00 0.00 0,00 0.00 0,00 0.00 -O.OZ -0,0~ -0.1 -0.35 -0,35 -0,35 -0,54 -3,15 '4.78 -4.83 -4,47 -4.12 -4,32 -5.83 ARCO DS 12-12 .' GYROSCOPIC SURVEY JOB NO 52 56 31 AUG 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 2500 1 0 2499,91 2428,91 536,63E 2600 0 45 2599.90 2528.90 S29,36E 2700 0 30 2699.89 2628,89 S31,21E 2800 1 0 2799.88 2728.88 Sll,05E 2900 3 45 2899,78 2828,78 N43.88W 3000 6 45 2999,35 2928,35 N54.66W 3100 10 0 3098.27 3027,27 N60,BSW 3200 13 0 3196,26 3125m26 N66,88W 3300 14 30 3293.39 3222,39 N68,56W 3400 17 15 3389.56 3318,56 Nb6,35W 3500 18 30 3484,73 3413,73 N66,05W 3600 21 0 3578,84 3507,84 NSO.16W 3700 22 0 3671,89 3600,89 N79,05W 3800 25 0 3763e58 '3692e58 N79e61W 3900 27 30 3853,26 3782,26 N76,56W 4000 30 15 3940,82 3869,82 N73.13W 4100 33 30 4025e73 3954,73 N72.S1W 4200 36 30 4107e63 4036,63 N71.70W 4300 38 0 4187.23 4116,23 N70.71W 4400 41 0 4264e39 4193e39 N70,45W 4500 41 0 4339.86 4268,86 N70.35W 4600 41 30 4415,04 4344,04 N69e46W 4700 39' 0 4491,36 4420,36 N64,03W 4800 37 0 4570.16 4499.16 N54,98W 4900 38 0 4649e49 4578e49 NSOJ96W 5000 38 15 4728.16 4657,16 N49,26W 5100 38 45' 4806e42 4735,42 N47,63W 5200 38 30 4884,54 4813,54 ' N45,80W 5300 38 15 4962e94 4891e94 N45,63W TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S 2,07 S 8.7~ E 3,35 S 9,57 E 4,29 S 10,12 E 5.50 S 10,59 E 6,93 S 7,84 E 0,97 S 0.92 E 6,84 N 11,35 W 15.69 N 29,20 W 24.70 N 51,19 W 35,i9 N 76,45 W 8,98 S 76 40 18 E 10,14 S 70 ~2 27 E 10,99 S 67 1 11 11,93 S 62 31 41 E 10.47 S 48 31 ~0 £ 1,34 S 43 26 1 E 13.25 N 58 55 5 W 33,15 N 61 44 22 W 56,84 N 64 14 17 W 84.16 N 65 17 2 W 47.57 N' ..104e'54..'W..:., 114.85 N 65 31 ~3 W ,.. 57,3'7.>N . i~. ¥136,'79.,'. W 71,36'":N. "212',02 .W.. ' 80,48 N 93,10 N 108,56 N 126,03 N 145,53 N 166,68 N 188'68 N 211,33 N 236,83 N 268,03 N 304.68 N 344,27 N 385,56 N 428,35 N 471,70 N 255,28 W 301,88'W 352,37 W 406.99 W 464.29 W 524,28 W 586.08 W 648,00 W 707,34 W 760,33 W 808,93 W 856,30 W 902,88 W 948,32 W 992.77 W 148.33 N 67 14 46 W 184,30 N 69 41 10 W 223.70 N 71 23 51W .267,67 N 72 30 3 W 31~,91 N 72 51 35 W 368e71 N 72 52 35 W 426.06 N 72 47 33 W 486,57 N 72 35 45 W 550,13 N 72 21 48 W 615.71 N 72 9 15 W 681,59 N 71 56 13 W 74~,94' N 71 29 18 W 806,20 N 70 34'~2 W 864,40 N ~9 21 39 W 922e91N 68 5 ~1W 981,76 N 66 52 33 W 1040e58 N 65 41 29 W 1099,13 N ~4 35 9 W DOG LEG SEVERITY DEG/IOOFT 0.081 0.250 0,250 0'500 2,821 3,004 3,255 3.018 1'504 2,757 1.250 3.088 1.012 3,002 2,583 2,885 3,026 1,546 3,002 0,066 0,633 3,299 3,840 1.822 0,69'8 0.812 0,753 0,258 SECTION DISTANCE -7.5{ -9,05 -10.11 -il.31 -10.43 -1.34 12.80 31,56 53,31 78,38 106,78 165,98 198e47 233,06 276,~ b22e. ~75,10 483,73 '542.46 601,73' 661,25 720,49 780,59 841,97 904,02 966.37 1028,42 RCO DS 12-12 GYRO$COPXC SURVEY JOB NO 52 56 AUG 81 RECORD OF SURVEY TRUE EAS. DRIFT VERTICAL ,EPTH ANGLE DEPTH D N SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURE,5 DISTANCE ANGLE D M $ DOG LEG SEVERITY DEG/iOOFT 5400 37 30 504'1.87 4970,87 N4'6,20W 5500 38 30 5120,67 504.9,67 N4'4',98W 5600 38 0 5199,20 5128,20 N43,91W 5700 37 30 5278,27 5207,27 N4'4,51W 5800 38 15 5357.21 5286,21 N4'3,76W 5900 38 0 54.35,87 5364',87 N43e60W 6000 38 15 5514.54' 5443,54. N43,56W 6100 38 0 5593.21 5522,21 N43,40W 6200 38 0 5672,01 5601e01 N4'3e30W 6300 38 0 5750e81 5679e81 N4'l,4'8W 6400 37 4.5 5829,74. 5758,74. N4.2,15W 514'.4'1 N 1036,87 W 557.49 N 1080.85 W 601,68 N 1124,20 W 64.5,56 N 1166,90 W 689,62 N 1209e65 W 734.,26 N 1252,29 W 778,99 N 1294,85 W 823.78 N 1337.34' W 868,55 N 1379e60. W 914''02 N. 14'21.11 W 1157,4.6 N 63 36 4.7 W 1'216,15 N 62 4.2 56 W 1275,09 N 61 50 37 W 1333,57 N 61 2 50 W 1392,4'2 N 60 18 4.5 W 14'51,68 N 59 36 55 W 1511.12 N 58 58 7 W 1570'70 N 58 22 3 W 1630.24 N 57 4.8 24. W 1689.67 N 57 15 6 W 959.77 N...14.62.'04, W .. 174.8.92 N 56 /+2 59 W 6500 38 0 5908.68 5837.68 N42,gsw 1004.99,'"",'N'¥~:: 't503.,5.7'W'. 1808.52 N 56 14. 28 W 6600 :38 0 5987,4.8 5916.48 N42.88W 1050,06i .'1~'~. i54'5'.:5I""~"W''''~ 1868.4.8 N 55 4,8 23 W 6700 37 0 6066,81 5995,81 N43,36W 1094',50 N : 1587,12 W "1927.92 N 55 2~ 33 W 6800 38 0 614'6,15 6075,15 N4.0,10W 1139.92 N 1627,64 W 6900 37 30 6225e22 6154',22 N4'O.63W 1186,56 N 1667.29 W 7000 37 30 6304'e55 6233,55 N41,ZlW 1232.56 N 1707,17 W 7100 37 30 6383.89 6312,89 N4'O.26W 1278,68 N 174.6e90 W 7200 37 30 64.63,22 6392,22 N40,16W 1325,17 N 1786.20 W 7300 37 4.5 654'2.43 64'71,4'3 N39.28W 1372,12 N 1825.22 W 7400 37 0 6621,89 6550,89 N38,15W 14'19',4'8 N 1863,19 W 7500 36 4.5 6701,89 6630,89 N39,TOW 14'66,17 N 1900,89 W 7600 36 15 6782.27 6711,27 N4.0,31W 1511.73 N 1939.13 W 7700 36 0 6863e05 6792e05 N4.1eO1W 1556.4'4 N 1977e55 W 7800 35 0 69~4'e4'6 6873,46 N41eOSW 1600.25 N 2015,6'? W 7900 35 0 7026,37 6955,37 N$O.IOW 164.3e81 N 2052,98 W 8000 35 0 7108,29 7037.29 N4.0,85W . 1687,4'$ N 2090,21 W 8100 34 0 7190,70 7119,70 N4.1,4'lW 1730,10 N 2127e4.7 W 8200 33 0 7274.,09 7203.09 N4'I,15W 1771,58 N 2163,88 W 1987,11N 54. 59 4.0 W 204.6,~1 N 54 33 4.1W 2105.62 N 54. 10 15 W 2164.,88 N 53 4.7 4.8 W 2224'.10 N 53 25 4.3 W 2342,31 N 52 4'1 51 W 24'00.6~ N 52 21 24. W 2458.77 N 52 3 37 W 2516,59 N 51 4.7 4.2 W 2573,66 N ~1 33 13 W 2629,99 N 51 18 ~7 W 2686,34 N 51 5 8 W 2742,15 N 50 52 52 W 2796,59 N 50 41 33 W 0,779 1.106 0.64.3 0,54.7 0,803 0,258 0,250 0,258 0.062 1,118 0.353 0,~03 0,062 1.015 1.592 0.538 0.355 0,578 0.061 0.415 0.855 0,609 0,54.5 1,O00 0,54.5 0.4.30 1.016 1.003 DISTANCE 1089.77( 1151.31 1213.22 1274.4'4 1335.83 1397.57 1459.51 1521,04 15B2.61 164'4'.15 170~.50 1766.~ 1950.12 2011.23 2132.8 2193,55 2~74'.66 2~92.87 2550.66 2608.12 2665.3'! 272i.95 2777,08 ARCO DS 12-12 GYROSCOP!C .SURVEY JOB NO 5256 31 AUG 81 RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES C L 0 5 U R E $ DISTANCE ANGLE D M 8300 32 0 7358.42 7287.42 N40.OOW 1812.39 N 2198,83 W 8400 32 0 7443e23 7372e23 N39.90W 1853e01 N 2232.86 W 8500 31 0 7528e49 7457e49 N41e36W 1892,66 N 2266e88 W 8600 31 0 7614.21 7543.21 N40.38W 1931.61 N 2300.59 W 8700 30 30 7700.15 7629.15 N40.21W 1970.60 N 2333,66 W 8800 30 0 7786,53 7715e53 N39e13W 2009.37 N 2365.82'W 8900 29 0 7873.57 7802,57 N38.88W 2047.64 N 2396,81 W 9000 28 45 7961.13 7890.13 N37.83W 2085.50 N 2426.78 W 9100 28 0 8049.12 7978,12 N39,41W 2122,'63 N 2456.44 W 9200 29 0 8137.00 8066.00 N38.56W 2159.72 N. 2486.47 W 2849.49 N 50 30 i0 W 2901.61 N 50 18 40 W 2953.12 N 50 8 27 W 3003.97 N 49 58 57 W ~054e~8 N 49 49 16 W 3103,98 N 49 39 27 W 3192.39 N 49 29 31W 3199e78 N 49 19 30 W ~246.49 N 49 10 10 W 3293,4& N 49 1 ,2Z W 9300, 29 30 8224,25 8153,25 N38,O3W 219@.O'6.i,N..';...'.'2516,..75."W"", 3341,48 N 48 52 0 W 9400 28 0 8311.92 8240,92 N37,68W 2236,04..'N..','.2546,27.:~'.. 3388,71 N 48 42 41 W 9500 29 30 8399.59 8328,59 N34,21W 2274,9'7" N'.'2157'4';50"':'W''' 3435,63 N 48 32 4 W 9600 31 0 8485.97 8414.97 N32.60W 2317e02 N' 2602e24 W~ ~3484.28 N 48 19 5 W 9700 34 0 8570,30 8499.30 N31.81W 2362.47 N 2630.87 W 9800 36 0 8652.21 8581.21 N28e70W 2412.01 N 2659e77 W 9900 38 0 8732,07 8661e07 N26.53W 2465,33 N 2687.66 W 10000 39 0 8810,33 8739,33 N24,98W 2521,39 N 2714,71 W 10100 40 0 8887.49 8816.49 N25.20W 2578.99 N 2741.69 W 10200 40 0 8964.10 8893,10 N23e33W 2637.59 N 27&SelO W 10300 40 0 9040.70 8969,70 N21.43W 2697.02 N 2792e58 W 10400 41 0 9116e74 9045e74 N18.96W 2757,97 N 2815,00 W 10500 41 0 9192.21 9121.21 N18.86W 2820.03 N 2836.27 W 10600 41 0 9267.68 9196,68 N17'31W 2882.39 N 2856,65 W 10700 41 0 9343.15 9272.15 N17'21W 2945.04 N 2876.12 W 10783 41 45 9405.44 9334'44 N19.26W 2997e14 N 2893e29 W 10800 41 45 9418.12 9347.12 N17,33W 3007.89 N 2896,84 W BOTTOM HOLE CLOSURE 4176,02 FEET AT N 43 55 21 W ~911' 4~o~ 3535,93 N ~8 4 3~ W 3590.57 N 47 47 ~8 W 3~47,11 N 47 28'14 W 370~,01N ~7 6 52 W 376~,05 N 46 45 ~ W 3823,52 N 46 22 58 W 3882,33 N 45 59 50 W 3940,90 N 45 35 10 W 3999.63 N ~5 9 52 W ~058.16 N 44 ~ 34 W 4116.47 N 44 19 17 W 4155,82 N 43 59 23 W 4176.02 N 43 55 21W DOG LEG SEVER I TY DEG/1OOFT 1.051 0.053 1,073 0.506 0,502 0.569 1.002 0.349 0.827 1,020 0e516 1.502 1.719 1,560 3,010 2.271 2,162 1,173 1.00~ 1.200 1,221 1,458 0.066 1.017 0.066 1,420 7.573 S~CTION DISTANCE 2830,i- 2883.58 2935,74 29~7,18 3038.20 3137,50 31~5.56 3232,8~ 3280.42 3329.05 3374.88 3'24,50 3520.63 3582.36 3699.Z6 3759.4~ 3819,99 3879.78 3939.23 3998.69 ~057,74 4116,37 4165.81 RCO DS 12=12 GYROSCOPIC SURVEY ,JOB NO 5256 'INTERPOLATED TRU~- VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE :ODE MEASURED VERTICAL TOTAL COORDINATES C L O ~ U R E iANE DEPTH DEPTH DISTANCE ANGLE 31 AUG: 81 SUB SEA 'OP SAD 10027 8831.27 2536.94 N 2721.68 W IXL/WATER 10365 9090.26 2736.54 N 2806.98 W iASE SAD 10774 9398.72 2991.55 N 2891.13 W 3720.70 N 47 0 ~3 W 8760,27 3920.18 N 45 43 40 W 9019.26 4160.29 N 44 1 19 W 9327.72 ~RCO DS 12-12 GYROSCOPIC SURVEY JOB NO 52 56 1EASURED DEPTH AND O~'HER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 31 AUG 81 TRUE MEASURED VERTICAL SUB HD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 171 171, 100 0 271 271. 200 0 371 371, 300 0 471 471. ~00 0 571 571, 500 0 671 671. 600 0 771 '771. 700 0 871 871, 800 0 971 971, 900 0 1071 1071, 1000 0 1171 1171, 1100 0 1271 1271. 1200 0 1371 1371, 1300 0 1471 1471, 1400 0 1571 1571. 1500 0 1671 1671, 1600 0 1771 1771. 1700 0 1871 1871, 1800 1971 1971. 1900 0 2071 2071, 2000 0 2171 2171, 2100 0 2271 2271. 2200 0 2371 2371, 2300 0 2~71 2471, 2400 0 2571 2571. 2500 0 2671 2671, 2600 0 2771 2771, 2700 0 2871 2871. 2800 0 2971 2971, 2900 0 3072 3071. 3000 1 3174 3171. 3100 3 3277 3271, 3200 5 3381 3371. 3300 9 3485 3~71. 3400 14 3592 3571. 3500 20 0 0 0 0 0 0 0 0 0 0 0 0 .., 0.00 0.00 0.00 O.OO OeO0 0.00 0.00 0,00 Oe17 0,43 0,62 0.51 0.64 .... O .... ,0,35 N 0'"" "!"?"'":,'"i"i'":.:'"':'"'i:"0,49 S 1.56 S 1,36 S 0,76 S 0,31 N 0,59 N 0,22 S 1,66 S 3.01 S 4.06 S 5,05 S 7.09 S 2.86 $ 4.55 N 13.48 N 22,81 N 33.11 N 45,75 N 56,86 N' 0.00 W 0,00 W 0,00 W 0,00 W 0.00 W 0,00 W 0,00 W 0,00 W 0.11 E 0,61 E 0.72 5 lc21 E 1.18 E 1.18 E 1,~6 E 2,60 E 3.35 E 4,65 E 5.82 E 5.85 E 6.40 E 6.58 E 7,~8 E 8,43 E 9,36 E 9.97 E 10,46'E 9.18 E 3,48 E 7,32 W 23e97 W 45.79 W 71.18 W lOOe17 W 133.83 W RCO DS 12-12 GYROSCOPIC SURVEY JOB NO 5256 6ASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE MEASURED 'VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORD [NATES 31 AUG 81 3699 3671, 3600 28 3808 3771, 3700 37 3920 3871, 3800 49 ~035 3971, 3900 64 4155 4071. 4000 83 4279 4171. 4100 108 4409 4271. 4200 138 ~541 4371. ~300 170 4674 4471e 4400 203 4801 4571, 4500 230 4927 4671, 4600 256 5055 4771. 4700 283 5183 4871. 4800 312 5810 4971. 4900 839 5437 5071. 5000 365 5564 5171. 5100 393 5691 5271, 5200 420 5817 5371. 5300 446 594.4 5471. 5400 473 6072 5571. 5500 501 6199 5671. 5600 528 6325 5771, 5700 554 6452 5871, 5800 581 6579 5971, 5900 608 6705 6071, 6000 634 6831 6171, 6100 660 6958 6271, 6200 687. 7084 6371. 6300 713 7210 6471, 6400 738 7336 6571, 6500 765 7461 6671. 6600 790 7586 6771. 6700 815 7710 6871. 6800 839 7832. 6971, 6900 861 7954 7071, 7000 883 8 63.97 N 9 72.01 N 12 82.78 N 15 98.40 N 19 118,29 N 25 141.86 N 30 168.64 N 32' 197.99 N 33 229.93 N 27 268,39 N 26 315.40 N 27 366,78 N ... 29 421,31 N 27 476,07 N 'i' 26 ... '.". '.530e14 Iq 586,20. N ". '272 8...:, '.: ]i. :'.. :..'i. ;.;..':'."..' "'.. 642 · 07 N ... 26 '"' 27 28 27 26 27 27 26 26 27 26 25 27 25 25 22 22 697,31 N 754.10 N 811.43 N 868.23 N 925.60 N 983.47 N 1041.13 N 1096.70 N 1154e51 N 1213,36 N 1271.28 N 1329.74 N 1389.27 N 1448.24 N 1505,71 N 1560,79 N 1614.13 N 1667.54 N 172.45 W 215.35 W 264.32 W 319.02 W 381.82 W 451.94 W 529,67 W 611.38 W 692.16 W 760,82 W 821.64 W 881.70 W 940.14 W 997,15 W 1052,95 W 1108.27 W 1162,46 W 1216.83 W 1270.79 W 1325.11 W 1378.79 W 1431e22 W 1483,37 W 1536,12 W 1589.17 W 1639e88 W 1690,00 W 1740.33'W 1790,03 W 1839,02 W 1885.90 W 1933.41 W 1981.33 W 2027.67 W 2072.89 W RCO DS 12-12 GYROSCOPIC SURVEY JOB NO 5256 EA~URED DEPTH AND O~'HER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 31 AUG 81 TRUE ~iEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 8076 7171, 7100 905 8196 7271. 7200 925 8315 7371, 7300 944 8433 7471. 7400 962 8550 7571, 7500 979 8666 7671. 7600 995 8782 7771. 7700 1011 8897 7871, 7800 1026 9011 7971, 7900 1040 9125 8071, 8000 1093 9239 8171, 8100 1067 9353 8271, 8200 1082 9467 8371, 8300 1096 9582 8471, 8400 1111 9701 8571, 8500 1129 9823 8671. 8600 1152 9949 8771. 8700 1178 10078 8871, 8800 1207 10209 8971, 8900 1238 10340 9071. 9000 1268 10472 9171, 9100 1301 10604 9271. 9200 1333 10737 9371, 9300 1365 22 1720.33 N 20 1770.11 N 19 1818.41 N 18 1866.35 N 17 1912,01 N 16 1957,52 N 16 2002J48 N 15 2046,76 N 14 2089,72 N 13 2131,73 N 14 2174,62 N 15 2218,45 N 14 2261,91 N , , 15, ' " " ' 2309,41 N ' . '1:8 ..=. ?.::...,..,:' 2362,87 N '2"3. 26: 29 31 30 33 32 32 ......... '2424,04 N "' ""' '' 2492,71 N 2566,47 N 2642,92 N '2721,02 N 2802,82 N 2118,18 W 2162,25 W 2203,87 W 2243,78 W 2283,55 W 2322,33 W 2360,02 W 2395,57 W 2429.97 W 2463,78 W 2498,11 W 2532,52 W 2565,06 W 2597.01 W 2631,11 W 2666,10 W 2700,72 W 2735,16 W 2770e36 W 2801.51 W 2829,58 W 2884,90 N ' 2857,41 W 2968,28 N 2883,42 W ~CO DS 12-12 GYROSCOPIC SURVEY ,JOB NO 5256 NTERPOLATED VALUES FOR EVEN 1000 FEhT OF NEASURED DEPTH. TRkJE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999. 2000 1999, 3000 2999. 4000 3940. 5000 4728. 6000 5514, 7000 6304. 8000 7108, 9000 7961, 10000 8810. 928. 0,25 N 0,28 E 1928. 1,19 S 5,74 E 2928, 0,88 S 1.00 E 3869, 93,3~ N 301,81 W 4657. 344,78 N 855.87 W 5443, 779,42 N 1294.40 W 6233, 1232.85 N 1706,82 W 7037e 1687.75 N 2089.85 W 7890. 2085,95 N 2~26.21 W 8739, 2521.74 N 2713,97 W 31 AUG; 81 ,glOI -o..~ ~< - ! -.-I OMPLETION REPORT -. Red" 01L & GAS YRO$COPI¢ SURVEY ADIUS OF CURVATURE METHOD OF COMPUTATION OMPUTED FOR 5DC BY FM LINDSEY & ASSOC 31 AUG 81 WELL DS 12=12 KB ELEV 71. FT. ,JOB NO 5256 RECORD OF SURVEY TRUE EAS. DRIFT VERTICAL EPTH ANGLE DEPTH D M ,SUB DRIFT SEA DIRE(:: DEG, 0 0 0 0.00 100 0 0 100.00 200 0 0 200.00 300 0 0 300.00 400 0 0 400.00 500 0 0 500.00 600 0 0 "600,00 700 0 0 700,00 800 0 0 800,00 900 0 0 900,00 1000 0 30 999,99 -71.00 N O,OOE 29.00 N O.OOg 129.00 N O.OOE 229,00 N O,OOE 329,00 N O.OOE 429.00 N O,OOE 529,00 N O,OOE 629.00 N O,00E 729,00 N 829.00 N O,OOE 928,99 S84.48E 1100 0 0 1099,99 1028,99 N O.OOE 1200 0 30 1199.99 1128,99 S23,"53E 1300 0 0 1299,99 1228.99 N O,OOE 1400 0 0 1399,99 1328,99 N O,OOE 1500 0 0 1499,99 1428,99 N O.OOE 1600 1 0 1599.98 1528,98 $57,08E 1700 0 30 1699,98 1628,98 S41,71E 1800 1 0 '1799.97 1728,97 S40,35E 1900 1 0 1899,95 1828,95 SBO.98E 2000 O' 0 1999.95 1928.95 N O.OOE 2100 1 0 2099.94 2028.94 'N42.91E 2200 0 0 2199.94 2128,94 N O.OOE 2300 0 45 2299,93 2228,93 S42.36E 2400 1 0 2399.92 2328,92 S32.00E TOTAL COORDINATES 0,00' S 0.00 W 0,.00 S 0.0-"0 W 0.00 $ 0.00 W 0,00 S 0.00 W 0.00 S 0.00 W · , 0,00 .5,,.. , O.OO W ', ,. O,OO"S' i:~. 7.0,00 W 0,00. 5 ....:r<,~ "0,00' W O.00 5 "' 0,OO W 0,00 S 0,00 W 0.26 N 0.28 E 0.52 N 0.57 E 0,58 N 0.88 E 0,64 N 1.18 E 0,64 N 1.18 E 0.64 N 1,18 E 0,99 N 1.81 E 0,14 N 2.80 E O.~J4 `S 3,66 E 1,~8 S 5,15 E 1.18 S 5.73 g 0,39 S 6,05 E 0.40 N 6.36 E 0,58 N 6.83 E 0.62 $ 7,75 E C L.O S U R E $ DISTANCE ANGLE D N S I 0,00 5 0 0 0 W 0,00 5 0 '0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 O W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.38 N /+7 45 30 E. 0.77 N 47 45 30 g 1,05 N 56 23 :~8 E 1,35 N 61 19 54 g 1,35 N 61'19 54 E 1.35 N 61 19 54 E 2,06 N 61 22 32 g 2,80 N 87 7 32 E 3.76 S 76 59 31 E 5.42 S 71 54 33 E 5.85 S 78 19 ~5 E 6.06 S 8~ 17 45 E 6.37 N 86 23 15 ~ 6,86 N 65 6 23 E 7.78 S 85 2.1 31 E '.. m'- CC; - '-. .?: DOG LEG SEVERITY DEG/IOOFT 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0,000 0.000 0,000 O.EOO 0.500 0.500 0.500 0.000 0.000 1.001 0,500 0.500 0.~94 1,000 1.000 1.000 0.750 0.250 .. SFCT I ON DISTANCE 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 -0.01. -0.02( -0.18 -0.35 -0,35 -0,35 -0.54 --1,84 --3,1~ -4e78 -4.83 --4e47 --4.12 --4,32 -5.83 ~RCO DS 12-12 GYRO$COP!C ,SURVEY JOB NO 5256 31 AUG 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 2500 1 0 2499,91 2428.91 $36.63E 2600 0 45 2599,90 2528.90 $29,36E 2700 0 30 2699.89 2628.89 2800 1 0 2799.88 2728.88 2900 3 45 2899.78 2828.78 Ng3.88W 3000 6 45 2999.35 2928.35 N54.66W 3100 10 0 3098.27 3027.27 NGO.35W 3200 13 0 3196.26 3125.26 N66.88W 3300 14 30 3293.39 3222,39 N68,56W 3400 17 15 3389.56 3318.56 N66.35W 3500 18 30 3484.73 3413.73 N66.05W 3600 21 0 3578.84 3507.84 NSO.16W 3700 22 0 3671.89 3600.89 N79.05W 3800 25 0 3763.58 '3692.58 N79.61W 3900 27 30 3853.26 3782.26 N76.56W 4000 30 15 3940.82 3869.82 N73.19W 4100 33 30 4025.73 3954.73 N72.81W 4200 36 30 4107.63 4036.63 N71.70W 4300 38 0 4187.23 4116.23 N70.71W 4400 41 0 4264.39 4193.39 N70.45W 4~00 41 0 4339.86 4268.86 N70.35W 4600 41 30 4415.04 4344.04 N69,46W 4700 39 0 4491.36 4420.36 N64.03W 4800 37 0 4570.16 4499.16 N54.98W 4900 38 0 4649.49 4578.49 N50.96W 5000 38 15 4728.16 4657.16 N49.26W 5100 38 45 4806.42 4735.42 N47.63W 5200 38 30 4884.54 4813.54 N45.80W 5300 38 15 4962.94 4891.94 N45.63W TOTAL COORDINATES DISTANCE ANGLE D iq 2,07 S 8,7~ E 3,35 S 9,57 E 4,29 S 10.12 E 5,50 S 10.59 E 6.93 S 7.8'4 E 0.97 $ 0,92 E 6.84 N 11,35 W 15.69 N 29.20 W 24.70 N 51.19 W 3~.19 N.. 76.45 W 47.57 .N': ..104.54 W 57,37."N" i'..:':136.79 W. 63,98. N :' .. ~.;:'172 ' 83':" W'' 8,98 S 76 40 18 E 10,14 S 70 42 27 E 10.99 S 67 1 11E 11,93 S 62 31 41 E 10,47 S 48 31 40 f 1.34 S 43 26 1 ~ 13.25 N 58 55 5 W 33.15 N 61 44 22 W 56,84 N 64 14 17 W 84.16 N 65 17 2 W 114.85 N 65 31 ~ W 148.33 N 67 14 46 W 184.30 N 69 41 10 W 71,36':'N'""' 212.02'W, ' 223.70 N 71 23 51W 80,48 N 255.28 W 93.10 N 301.88 W 108.56 N 352.37 W 126.03 N 406.99 W 145,53 N 464,29 W 166.68 N 524.28 W 188'68 N 586,08 W 211.33 N 648.00 W 236.83 N 707.34 W 268.03 N 760.33 W 304.68 N 808.93 W 344,27 N 856.30 W 385.56 N 902.88 W 428,35 N 948.32 W 471.70 N '. 992,77 W 267.67 N 72 30 3 W 315.91N 72 5.1 35 W 368.71N 72 52 35 W 426.06~N 72 47 35 W 486.57 N 72 35 45 W 550.13 N 72 21 48 W 615,71N 72 9 15 W 681.59 N 71 56 13 W 74~.94 N 71 29 18 W 806.20 N 70 34'52 W 864e40 N 69 21 39 W 922.91N 68 5 bi W 981.76 N 66 52 .33 W 1040e58 N 65 41 29 W 1099.13 N 64 35 9 W DOG LEG SEVENITY D~G/iOOFT 0.081 O.ZSO 0.250 0.500 2.821 3.004 3.255 3,018 1.504 2.757 1.250 3,088 1,012 3,002 2.583 2.885 3.251 3,026 1.546 3,002 0.066 0.633 3.299 3,840 1.822 0.698 0.812 0.753 0.k55 SkCTION DISTANCE -7.5b -9.05 -10.11 -i.1.31 -10.43 12.80 31.56 5~.31 78.38 106.78 136,21 165.98 198,~7 23~.06 hZ2, 373.10 ~83,73 '542.4~ 601,73 ~61.25 720.49 780,~9 841.97 904.02 966.37 1OZB,42 ~CO DS 12-12 GYROSCOPIC SURVEY JOB NO 5256 31 AUG 81 RECORD OF SURVEY TRUE lAS, DRIFT VERTICAL EPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M DOG LEG SEVERITY DEG/iOOFT 5400 37 30 5041.87 4970,87 N46,20W ~500 38 30 5120,67 5049,67 N44,98W 5600 38 0 5199,20 5128,20 N43,91W 5700 37 30 5278,27 5207,27 N44,51W 5800 38 15 5357,21 5286,21 N43,76W 5900 38 0 5435,87 5364,87 N43,60W 5000 38 15 5514.54 5443,54 N43,56W 6100 38 0 5593,21 5522,21 N43,40W 6200 38 0 5672.01 5601.01 N43.30W 6300 38 0 5750,81 5679,81 N41,48W 514.41 N 1036,87 W 557.49 N 1080,85 W 601,68 N 1124,20 W 645,56 N 1166,90 W 689,62 N 1209,65 W 734.26'N 1252,29 W 778,99 N 1294,85 W 823.78 N 1337,34 W 868,55 N 1379.60 W 914.0Z N, 1421.11 W 1157,46 N 63 36 47 W 1'216.15 N 62 42 56 W 1275,09 N 61 50 37 W 1333.57 N 61 2 50 W 1392.42 N 60 18 45 W 1451,68 N 59 36 55 W 1511,12 N 58 58 7 W 1570,70 N 58 22 3 W 1630,24 N 57 48 24 W 1689.b7 N 57 i5 6 W 6400 37 45 5829,74 5758,74 N42,15W 959,77 N.. 1462,04 W ' 1748,92 N 56 42 59 W 6500 38 0 5908,68 5837,68 N42e98W lOO4,99::":.N;i.:ii'lSO3,57:.:W. 1808,52 N 56 14 2~ W 6600 3'8 0 5987.48 5,916.48 N42.88W 1050.06' N,'"1545.SI"W' 1868.48 N 55 48 23 W 6700 37 0 6066,81 5995,81 N43,B6W 1094.50 N'" 1587.12 :W '1927,92 N 55 24 33 W 6800 38 0 6146,15 6075,15 N40,iOW 1139,92 N 1627,64 W 6900 37 30 6225e22 6154e22 N40,63W 1186,56 N 1667,29 W 7000 37 30 6304.55 6233,55 N41,21W 1232'56 N '1707,17 W 7100 37 30 6383,89 6312,89 N40,26W 1278,68 N 1746,90 W 7200 37 30 6463.22 6392,22 N4Oel6W 1325.17 N 1786,20 W 7300 37 45 6542,43 6471,43 N39.28W 1372,12 N 1825.22 W 7400 37 0 6621,89 6550,89 N38,15W 1419,48 N 1863,19 W 7500 36 45 6701.89 6630,89 N39,7'OW 1466,17 N 1900,89 W 7600 36 15 6782.27 6711,27 N40,31W 1511,'13 N 1939.13 W 7700 36 0 6863,05 6792,05 N41eO1W 1556,44 N 1977,55 W 7800 35 0 6944,46 6873,46 NAl,OSW 1600.25 N 2015,67 W 7900 35 0 7026,37 6955,37 N40,IOW 1643,81 Iq 2052,98 W 8000 35 0 7108,29 7037,29 N40,85W 1687.44 N 2090.21 W . 2686,34 N 51 5 8 W 8100 34 0 7190,70 7119,70 N41,41W 1730,10 lq 2127,47 W 2742,15 N 50 52 52 W 8200 33 0 7274e09 7203.09 N41,15W 1771,58 N 2163,88 W 2796,59 N 50 41 33 W 1987.11N 54 59 40 W 2046.41N 54 33 41W 2105.62 N 54 10 15 W 2164,88 N 53 47 48 W 2224,10 N 53 25 43 W 2283.45 N 53 ~ 56 ~ 2342.31N 52 41 51W 2400.63 N ~2 21 24 W 2458,77 N 52 3 37 W 2516.59 N 51 47 42 W 257~.66 N ~1 33 13 W 2629,99 N 51 18 ~7 W 0.779 1.106 0.643 0.547 0.803 0.258 O.gSO 0,258 0.062 1,118 0,35~ 0.403 0.062 1.015 1,592 0,53~ 0,355 0.578 0,061 0.415 0,609 0.545 0.34~ 1.000 0,~45 0.430 1,016 1.003 S~CTION DISTANCE 1089,77( 1151,3i' 1213.22 1335.83 1397.57 1~b9.31 19~1,04 15BZ.61 1644.1b 1705,b0 176~,~ i828.43 1950,12 2011,Z3 2072.02( 2~2.80 2193.55 ~2D4.44 2~14,~9 2~74.66 Z4~4,0i 2492,87 2608,12 2665.3'! 2721,95 2777.0~ ARCO DS 12-12 · GYRO,SCOPIC ,SURVEY JOB NO 52 56 Si AUG 81 RECORD OF SURVEY TRUE NEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M $ 8300 32 0 7358,42 7287,42 N40.OOW 1812.39 N 2198,83 W 8400 32 0 7443,23 7372,23 N39,90W 1853,01 N 2232,86 W 8500 31 0 '7528.49 7457,49 N41,36W 1892.66 N 2266,88 W' 8600 31 0 7614.21 7543,21 N40,38W 1931.61 N 2300.59 W 8700 30 30 7700.15 7629,15 N40.21W 1970.60 N 2333.66 W 8800 30 0 7786.53 7715.53 N39,13W 2009.37 N 2365,82 W 8900 29 0 7873,57 7802.57 N38,88W 2047,64 N 2396.81 W 9000 28 45 7961.13 7890,13 N37,83W 2085,50 N 2426,78 W 9100 28 0 8049.12 7978.12 N39.AlW 2122,63 N 2456,44 W 9200 29 0 8137.00 8066,00 N38,56W 2159.72 N 2486.47 W Z849.49 N 50 30 10 W 2901,61 N 50 18 40 W 2953.12 N 50 8 27 W 3003.97 N 49 58 57 W ~054,~8 N 49 49 16 W 3103,98 N 49 39 27 W 3192,39 N 49 29 31W 3199,78 N 49 19 30 W ~246.49 N 49 10 10 W 3293.46 N 49 1 22 W 9300 29 30 8224,25 8153.25 N38,03W 219@.06 N....2516,.75 W il 3341,48 N 48 52 0 W 9400 28 0 8311.92 8240.92 N37.68W 2236,04.:'.N., ~2546,27.~ W .... 3388.71 N 48 42 41 W 9500 29 30 8399.59 8328.59 N34,21W 2274.97 N':'2574.50"W 3435.63 N 48 52 4 W 9600 31 0 8485.97 8414.97 NS2.60W 2317.02'N .... "2602,24'.W'" 3484,28 N 48 19 5 W 9700 34 0 8570.30 8499,30 N31.81W 2362,47 N 2630,87 W 9800 36 0 8652.21 8581,21 N28,70W 2412,.01 N 2659,77 W 9900 38 0 8732.07 8661,07 N26,53W 2465.33 N 2687.66 W 10000 39 0 8810.33 ~739,33 N24.98W 2521,39 N 2714.71 W 10100 40 0 8887,49 8816,49 N25,20W 2578,99 N 2741.69 W 10200 40 0 8964.10 8893,10 N23,33W 2637,59 N 2768.10 W 10300 40 0 9040,70 8969,70 N21,43W 2697.02 N 2792,58 W 10400 41 0 9116,74 9045,74 N18,96W 275'1.97 N 2815.00 W 105.00 41 0 9192,21 9121,21 N18.86W 2820,03 N 2836,27 W 10600 41 0 9267.68 9196.68 N17,31W 2882,39 N 2856.65 W 10700 41 0 9343,15 9272,15 N17,21W 2945.04 N 2876,12 W 10783 41 45 9405,44 933~,44 N19,26W 2997,14 N 2893,29 W 10800 41 45 9418,12 9347,12 N17,33W 3007,89 N 2896,84 W IOE70 H~ q~ ~ 17,33~ BOTTOM HOLE CLOSURE 4176.02 FEET AT N 43 55 21W 3535.93 N %8 4 3~ W 3590,57 N 47 47 48 W 3647,11 N 47 28 14 W 3705.01 N 47 6 52 W 3764.05 N 46 45 h W 3823.52 N 46 22 58 W 3882.33 N 45 59 50 W 3940.90 N 45 35 10 W 3999,63 N 45 9 52 W 4058,16 N 44 44 34 W 4116.47 N 44 19 17 W 4165,82 N 43 59 23 W ~176.02 N 43 55 21W DOG LEG SEVEI~ I TY DEG/iOOFT 1.051 0.053 1.073 0.506 0.502 0.569 1.002 0.349 0.~27 1.020 0,516 1,502 1.719 1,560 3,010 2.271 2.162 1.173 1.004 1.ZOO 1.221 1.458 0.066 1.017 0.0~6 1.420 7,573 3ECTION DISTANCE 2883,58 2935,74 2987,18 3038,20 3088,44 3137,50. 3155.56 3280.~2 3329,05 3%24.50 ~52b.63 3640.( 3699.2'~ ~759.46 3819.99 ~879.78 3939.23 3998.69 4057.74 4116.37 4165.81 ~CO DS 12-12 GYROSCOPIC SURVEY JOB NO 5256 'INTERPOLATED TRUe' VERTICAL DEPTH5I COORDINATE5 AND CLOSURES FOR GIVEN DEPTH5 2DE ~,NE TRUE MEASURED VERTICAL TOTAL COORDINATE5 C L 0 5 U R E DEPTH DEPTH DISTANCE ANGLE D M 5 31 AUG: 81 SUB SEA DP 5AD iL/WATER ASE SAD 10027 8831,27 253~,94 N 2721.68 W 10365 9090.26 2736.54 N 2806.98 W 10774 9398,72 2991.55 N 2891.13 W 3720,70 N 47 0 43 W 8760.27 3920.18 N 45 43 40 W 9019.Z6 4160.29 N 44 1 19 W 9327,72 RCO DS 12-12 GYROSCOPIC SURVEY JOB NO 5256 [ASURED DEPTH AND O~'HER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 31 AUG 81 TRUE - MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 171 171, 100 0 0 271 271. 200 0 0 371 371. 300 0 0 471 471. 400 0 0 571 571, 500 0 0 671 671, 600 0 0 771 '771, 700 0 0 871 871. 800 0 0 971 971. 900 .0 0 1071 1071. 1000 0 0 1171 1171, 1100 0 ?.'! 0 1271 1271, 1200 0 "0 1371 1371, 1300 0 0 1471 1471, 1400 0 ...'., 0 1571 1571. 1500 0 '"~,' 0 ' i 1671 1671. 1600 0 ':' ~ O ".," 1771 1771, 1700 0 '0 ':' ' 1871 1871, 1800 '0 0 1971 1971. 1900 0 0 2071 2071. 2000 Q 0 2171 2171, 2100 0 0 2271 2271, 2200 0 0 2371 2371. 2300 0 0 2471 2471. 2400 0 0 2571 2571, 2500 0 0 2671 2671, 2600 0 0 2771 2771, 2700 0 0 2871 2871, 2800 0 0 2971 2971. 2900 0 0 3072 3071, 3000 1 1 3174 3171, 3100 3 2 3277 3271, 3200 5 2 3381 3371, 33.00 9 4 3485 3471, 3400 14 5 3592 3571. 3500 20 6 0 0 0 0 0 0 0 0 1 1 0 0 0 0 1 3 4 5 7 2 13 22 33 45 56 O,OO 0,00 S O,O0 o,oo S 0,00 S 0,00 0,00 S 0,00 S el7 N · 43 N ,62 N · 51 N .64 N ,64 N · 93 N .3~ N ,49 S .56 S ,36 S ,76 S ,31N .59 N · 22 S e66 S ,01 S ,06 $ ,05 S · 09 S ,86 S ,55 N · 48 N · 81 N ,11 N ,75 N ,86 N O.O0 W 0,00 W 0.00 W 0.00 W O,OO W 0.00 W 0,00 W 0.00 W 0.11 E 0,61 E 0,72 E 1,21 E 1,18 E 1,18 E 1,46 E 2.60 E 3,35 g 4,65 E 5,82 E 5,85 E 6,40 E 6.58 E 7,48 E 8,43 E 9,36 E 9,97 E 10.46'E 9,18 E 3,48 E 7,32 ~ 23,97 W 45.79 W .71,15 W i00,17 W 133,83 W ~CO DS 12-12 ' GYROSCOPIC SURVEY JOB NO 5256 ~ASURED D~PTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 31 AUG 81 : TRUE MEASURED 'VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3699 3671. 3600 28 3808 3771. 3700 37 3920 3871. 3800 49 4035 3971. 3900 64 4155 4071. 4000 83 4279 4171. 4100 108 4409 4271. 4200 138 4541 4371. 4300 170 4674 4471. 4400 203 4801 4~71, 4500 230 4927 4671, 4600 256 5055 4771, 4700 283 5183 4871. 4800 312 5310 4971. 4900 339 5437 5071. 5000 365 5564 5171, 5100 393 5691 5271. 5200 420 b817 5371, 5300 446 59Z~.4 5471. 5400 473 6072 5571, 5500 '501 6199 5671. 5600 528 6325 5771. 5700 554 6452 5871. 5800 581 6579 5971. 5900 608 6705 6071. 6000 634 6831 6171. 6100 660 6958 6271, 6200 687 7084 6371, 6300 713 7210 6471. 6400 738 7336 6571, 6500 765 74.61 6671, 6600 790 7586 6771. 6700 815 7710 6871. 6800 839 7832 6971, 6900 861 7954 7071, 7000 883 8 9 12 15 19 25 3O 32' 33 27 26 27 29 27 26 ...... 63.97 N 72. O1 N 82.78 N 98.40 N 118.29 N 141.86 N 168.64 N 197,99 N 229,93 N 268.39 N 315.40 N 366.78 N 421.31 N 476.07 N .... 530.14 N '.: ',;' .' :. , ,; 27 26' 27 28 27 26 27 27 26 26 27 26 25 27 25 25 24 22 22 586.20. N 642.07 N 697,31 N 754,10 N 811,43 N 868.23 N 925.60 N 983,47 N 1041,13 N 1096.70 N 1154,51 N 1213,36 N 1271,28 N 1329,74 N 1389,27 N 1448.24 N 1505.71 N 1560,79 N 1614.13 N 1667,54 N 172,45 W 215.35 W 264.32 W 319.02 W 381.82 W 451.94 W 529,67 W 611.38 W 692.16 W 760.82 W 821.64 W 881.7G W 940.14 W 997,15 W 1052.95 W 1108,27 W 1162.46 W 1216.83 W 1270.79 W 1325,11 W 1378,79 W 1431.22 W 1483,37 W 1536.12 W 1589,17 W 1639.88 W 1690e00 W 1740.33'W 1790,03 W 1839.02 W 1885.90 W 1933.41 W 1981,33 W 2027,67 W 2072.89 W ~CO DS 12-12 --AgURED DEPTH AND o:r'HER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 52 56 FEET OF SUB SEA DEPTH, 31 AUG 81 NEASURED DEPTH TRUE VERTICAL SUB DEPTH SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATE5 8076 8196 8315 8433 8550 8666 8782 8897 9011 9125 9239 9353 9467 9582 9701 9823 9949 1O078 10209 1O340 10472 1O604 10737 7171. 7100 905 7271. 7200 925 7371. 7300 944 7471. 7400 962 7571, -7500 979 7671. 7600 995 7771. 7700 1011 7871, 7800 1026 7971. 7900 1040 8071. 8000 1053 8171. 8100 1067 8271. 8200 1082 8371. 8300 1096 8471. 8400 1111 8571. 8500 1129 8671. 8600 1152 8771. 8700 1178 8871. 8800 1207 8971. 8900 1238 9071. 9000 1268 9171. 9100 1301 9271. 9200 1333 9371, 9300 '1365 22 1720.33 N 20 1770.11 N 19 1818.41 N 18 1866,35 N 17 1912.01N 16 1957.52 N 16 2002.48 N 15 2046.76 N 14 2089.72 N 13 2131,73 N 14 2174,62 N 15 2218.45 N 14... 2261.91 N '., ,..' 15'".. "',,.".:,.,,';.::' "2309.41 N .,.. '1,8 .... " 2362.87 N 23...'.."' " 2424, 04 N "" '.. "':".~,, 2492,71 N. 29 2566,47 N 31 2642,92 N 30 2721,02 N 33 2802.82 N 32 2884,90 N ' 32 2968.28 N 2118.18 W 2162,25 W 2203,87 W 2243.78 W 2283.55 W 2322,33 W 2360.02 W 2395.57 W 2429e97 W 2463,78 W 2498,11 W 2532,52 W 2565.06 W 2597.01 W 2631,11 W 2666.10 W 2700,72 W 2735,16 W 2770e36 W 2801,51 W 2829.58 W 2857.41 W 2~83,42 W ~CO DS 12-12 GYROSCOPIC SURVEY ,JOB NO 5256 · ~TERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH. TRUE NEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999. 928. 2000 1999. 1928. 3000 2999, 2928, 4000 3940, 3869, 5000 4728. 4657. 6000 5514. 5443, 7000 6304, 6233. 8000 7108, 7037. 9000 7961, 7890. 10000 8810. 8739. 0.25 N 0.28 E 1,19 S 5.74 E 0.88 S 1,00 E 93.38 N 301.81 W 344,7~ N 855,87 W 779,42 N 1294.40 W 1232.85 N 1706.82 W 1687.75 N 2089.85 W 2085.95 N 2426.21 W 2521,74 N 2713.97 W 31 AUG 81 OZ 2.1 61 81 'IN'Il ~3~1~1 ~NOIJ. I QAI 3~V 1 N~OHS SH.I. d3Q -I"1V 1861 '1£ ,0001 :.1 3"IVOS 3~IRJ.'~ANt~O dO SRIQVEI x3Aans OldOOSO~A9 S~9 ~ '110 O3~IV /~31^ -'I~.LNOZI~OH 400 1200 · 1600 2000 SURFACE LOC. IS SEC. 18, T ION, R 15E, U.M. 1015 NSL, 751 WEL. - 2400 ~'800 VERTICAL PROJECTION ARCO OIL !~ GAS WELL DS 12- 12 GYROSCOPIC SURVEY RADIUS OF CURVATURE SCALE I"= I000' AUGUST :51, 1981 i-~ :~oo I ARE TVD I · --~ 4400 ' '~4800 " . , .., - ',". · . ~~m . ' ~00 . '. ' ..... ' . . . , ~N 9tOTvDO = 9418' ' '' TMD = 108~' LOCATED IN THE APPENDIX WFL IPR LOG CALIPER SURVEY VOLAN CURVE DATA UI S,TRATIGRAPHIC ,HIGH RESOLUTION DIPMETER OTHER: Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Well Name and Nun~r Reports and Materials to be received by: Required Date Received Remarks' Completion Report Yes ~ ~ ~/--~ / ~ r~ W~II 'History . Yes f~ ,5 1~t ~. ~" r'~"' ' . · . . , - . , .... . Core Chips , ~/~_.. -----'--~ ' ~l~ ~,, , ' ~ ~ , , , ' · . . Core Description "~0''/~''' ~ ~ ~ Registered Survey Plat 7 y-- fl/<' . Inclination Survey . - .... ~ K, Directional Survey 7,~- 'Oc' 0°'~ ' Drill Stm ~ese ~e~ms 'go ~ ~~ ..... .~ ~ , Pr~u~ion T~t Re~rts ~0 ~.. ~.~ ~-- , .~ ~Digitiz~ ~ta. , ,, , ~ ~, .5 ~--~-f~ D/~ ....... ARCO Oil an~",'(~as .{"qmpany North Alask( .strict Post Ollice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 18, 1981 Reference: ARCO CASED HOLE FINALS D.S.1-5 7/30/81 D.S.12-12 7/23/81 D.'S.14-11 8/2/81 CNL/Multi-Spaced ACBL/VDL/GR Neutron ACBL/VDL/GR Run 1 5" Run 1 5" Run 2 5" sign and return the attached copy as receipt of data. Mary F. Keilis North Engineering Transmittal #528 .DI STRI BUTI ON NORTH GEOLOGY R&D DRILL I NG ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON PHILLIPS SOHIO MARATHON CHEVRON ARCO O,I an.d Gas Company ,~ -', D,v,s,,on ol AllanhcR~chf~elclcompany ARCO Oil anc1"?(~as Company North Alaska(' ~trict Post Oflice Box 360 Anchorage, Alaska 99510 Telepl3one 907 277 5637 Jerry A. Rochon District Operations Engineer August 24, 1981 Reference: ARCO Cased Hole Finals D.S.16-11 8/14/81 D.S.16-11 8/14/81 D.S.16-11 8/5/81 .D..S.12-12 7/31/81 Hydro Log Run 1 Fluid Density Log Run 1 Collar Log/Tie-In Perf Log CNL'/GR Multi-Spaced Run 1 ,! 5" Run 6 2"/5" 2"/5" e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transm£ttal #541 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division o! AtlanhcRichhelclCompany ARCO Oil ana.'Gas Company North Alaska" strict Post Office ~_., 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 19, 1981 Reference: ARCO Magnetic Tapes & Listings .D.S.12-5 8/12/81 D.S.12-12. 8/13/81 ' Tape #Alac 1068 Tape #Alac 1061 CN/Multi-Spaced CN/Multi-Spaced Dresser eas sign. and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #530 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETT¢ MARATHON A!2sk,] Oil & G(m Cons. Coiil~]iSSiO~ CHEV RON Allchorage ARCO OII and Ga~ Company i$ a Division o! AllanhcRichlieldCompany ARCO Oil and Gas{" -npany North Alaska ,.)istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Aug 12, 1981 Reference: ARCO Magnetic Tapes & Lists D.S.5-3 7/27/81 Tape #62044 D.'S..12=I2 7/20/81 Tape #62026 sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #509' DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON ' PHILLIPS SOHIO Alaska 0il & Gas Cons. C0mmissio,3 Anchorage MARATHON CHEVRON ARCO Oil,and Gas Cornpany is a Division o! AllanlicR~chli~ldCompa. ny ARCO Oil and Gas~' mpany N:orth Alaska, oistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon July 29, 191~trict-- Operations Engineer Reference: ARCO Cased Hole Finals ~.~.~~' 7/20/81 CN;L ;Run ! 5" D.S. 17-9 7/20/81 CNL Run 1 5" ~/~ease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #468 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG~ MANAGER D&M GEOLOGY STATE OF ALASKA EXXON SOHIOA/~k'a'0' ~'G.,~s, '*' "'. MARATHON CHEVRON ":"" ' ,,",,"'" .,.' ARCO Oil and Gas Company is a Division ot AtlanticRichfieldCompany L' ARCO Oil and Gas Company North Ala~(: District Post Offic~ ,-,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 29, 1981 Reference: ARCO Open D.S.17-9 7/20/81 D.S.17.-9 7/20/81 D.S.17-9 7/20/81 D.S.17-9 7/20/81 D.S.17-9 7/20/81 mi Hole Finals FDC Run 1 5" FDC/CNL Run 1 5" DIL/SFL Run 1 5" BHCS Run 1 5" CPL(Cyberlook) Run 1 5" 7/20/81 FDC Run 1 5" 7/20/81 FDC/CNL Run 1 .5" 7/20/81 BHCS Run 1 2" & 5" 7/20/81 DIL/SFL Run 1 2" & 5" 7/20/81 C?L(Cyberlook) Run 1 5" .o se sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #466 c, , DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D &.M GEOLOGY STATE OF ALASKA EXXON ' Alaska 011 (~ ,.., ~ MOB'I L Ah~h"/~ile "' '"~.Sion' GETTY PH[LL~PS SOHIO MARATHON CHEVRON ARCO Od and Gas Company is a Division of AllardicR~chl~eldCompany. Thru: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton/,_~/. Chairman .~,/.{~ ,~ Lonnie C. Smith Commissioner ~. Ben LeNorman Petroleum Inspector July 13, 1981 Witness B.O.P.E. Test on ARCO'S DS 12-12 Sec. 18, T10N, R15E, UM Prudhoe_. Bay.. Unit. Friday July. 3, !981: I departed my home at 4:35 PM for a 5:05 PM showup and 6:05 PM departure via Wien flight #7 for Deadhorse arriving via Fairbanks at 8:40 PM. _S~at~urday July_. 4,.h.!981: Tests on DS 12-12 began at 7:45 PM and were completed at 10:00 PM. B.O.P.E. test report is attached. S~unday July _5,_. 1981: Outside wing valve on the choke side of the 13 5/8" x-5' 1'/2" tubing spool was replaced and tested to 5000 psig. Automatic choke console was also repaired. , ,, Monday July 6r 1'981: B.O.P.E. test's on ARCO'S DS 17-9 were ~ple'~d, the s~'ject, of a separate, report. ~Tu__esday....July.. 7, 1981: B.O.P.E. test's on .ARCO'S DS 14-1J were completed'', th~' ~b~e'ct of a separate report . I departed Deadhorse via Wien flight $76 at 1:30 PM arriving, in Anchorage at 3:10 PM and at my home at 3:40 PM. In summary, I witnessed successful B.O.P.E. test on ARCO'S DS 12-12. O&G #4 .4/E.~.. ALASKA OIL & -CAS ~ONSERVATION CCM~SION B .O.P.E. Inspection Report Operator Date Representative ~?' Well ~ "~- )-~- Permit # ,~:~/-~,~ Location: Sec /F T)~3~R/~-~'M U~ Erillinq contr2 or Rig ~'/~Representative ft. Location, C~neral Well Sign Ceneral Housekeeping____ Reserve pit Rig BOPE Stack Annular Preventer-- Pipe Rams ~ Blind Rams__ Choke Line Valves H.C.R. Valve.____ Kill Line Valves ~"~ Check Valve__ Test Pressure __~_~~ _ __. .5'Z~ ~. ACCU~. ~UIATOR SYSTEM Full Charge Pressure ~ 2 ~'O psig Pressure After Closure /~ ~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: N2/~..~/-/?~-D! ~,,m/ ~4D~ psig Controls: ~ster ~/~ R_...er0o._te ~/~_.,_..B_!.~.n_d,s_..,~.,.i..t..,_~.,. cover. Kelly and Floor Safety Valves · Upper Kelly ,Test Pressure Lower Kelly., Test Pres sure ' Ball Type .... Test Pressure Inside BOP_ ~ ~ Test Pres sure Choke Manifold Test Pressure No. Valves ..... ~/~ No. flanges_____,,_~. O ,Adjustable Chokes -~, _HY._ _dr_ .a_u. _ i_?_ . l. . _ l. ..Y_.°.P_ .e__r_a_t__ed_.. _~.. __~. _ e ·est hrs._ min~ sec. rain ~nsec. ,! Test Results: Failures Repair or Replacement of failed equipment to be 'made within, days and Inspector/Ccmmission office, notified. Distribution orig. - AO&~CC cc - Operator cc - Supervisor June 23, 198! Mr. P. A. VanDusen District Drilling Engineer ARCO Alaska, Inc. P. O. B~x 360 Anchorage, Alaska 99510 Ret Prudhoe Bay Unit DS 12-12 ARCO Alaska, Inc. Permit No. 81-~ A~ Sur. Lo..~.t 1015'N & 751'W of SE ct, Sec 18, T10N, R15E, UM Bottomhole Loc.~ 4283~N & 4427~W of SE ct, Sec 18, T10N, R15E, UM. Dear Mr. YanDusen~ Enclosed is the approved application for permit to drill the above referenced we/ We.l/ samples and a mud log are not required~..'A, d.irectional .Survey' is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and aipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important 'for the spawning or migration of anadromous fish. .Operations in these areas are. subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Pre. or to commencing operations you may be contacted by the Habitat Coordinator~.S office, Department of Fish and. Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated .thereunder (Title 18, Alaska Administrative Code, Chapter "70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Prudhoe Bay DS 12-12 -2- June 23, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing' of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or .abandonment, please give this office adequate advance notification so that we may .have a .witness present. Very ~,~r'ul.y, yo,~rs,... . ,</,.< , ,,,,., /,.,.,. ..,.~. .... , ,., , }tc~le ~.. ~amilton ':~ ':'".~ ~],.~'.~ .,~.,T. ~ <'. ,,~. ' ..' ~: b' .Alaska Oil & Gas Conservation Commission Enc lo sure cc~ Department of Fish. & Game, ~abitat Section w/o encl. Department of Environmental 'Conservation w/o/encl. ARCO Alaska, InC{'~ Post Office',_ .x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 16, 1981 Mr. Hoyl e Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-12 Dear Sir: Enclosed please find: · 2. 3. 4. 5. 6. Si ncerely, P, A, VanDusen' District Drilling Engineer PAV/HMP:sp Enclosures The Permit to Drill application for DS 12-12. The $100.00 application fee. The horizontal & vertical wellbore projections. The as-built drawing. The BOP stack diagram &. description. The surface diverter system diagram & description. ARCO Alaska, Inc, is a Sabsidiary of A~;lanticRichfieldCompany PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I~ lb. Type of well EXPLORATORY I-'] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENTOIL~ SINGLEZONEX~X DEEPEN [] DEVELOPMENT GAS [] MULTIPLE_~,ZO_N. EJ~.,.. ...., ,.: ~ ~...,~ .'~, 2. Name of operator '.~ ARCO Alaska, ]:nc. , ~ ,-.. ~ .~ 3. Address J ~j ~,~ P.O. Box 360, Anchorage..,__AK 99510 4. Location of well at surface 9. · .... Unit or_ I~% n~.a~. 1015'N & 751 'N of SE ct, Sec 18, T10N, R15E, UM '-'Pl~udhoe~.~ag" At top of proposed producing interval 10. Well number 3915'N & 3676'W of SE ct, Sec 18, T10N, R15E, UM' DS 12-12 At total depth 11. Field and pool 4283 'N & 4427 '~ of SE ct, Sec 18, T]0N, R15E, UM Prudhoe Bay F~eld 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe Bay 0~ 1 Pool 71' RKBI ADL 28330 12. Bond information (see '~20 AAC 25.025) Type S1;atew~de Surety and/or number Fed ;[ns Co#8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed Approx. I m~le NE of Dead, beret: 1365 feet well 2620 feet 16. Proposed depth (MD'-& TVD) 17. Number of acres in lease 18. Approximate spud date ll016"MD, 9494' TVD feat 2512, ~]une 30.19gl 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 35~ -psig@ Surface ' KICK OFF POINT 2800feet. MAXIMUM HOLE ANGLE 38 oI (see 20 AAC 25.035 (c) (2) 4~7~ psig@ qziq? ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTIT.Y OF CEMENT· · Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 32" 20" 94# H-40 Welde( 80' 0 i. 0 80 I 80 300 sx permafrost 17~" ]3-3/8 72# N-80 Butt 2600' 0 ~ ' a ~ 0 2600 I 2600 2300ex Fondu, 400ex PF 12~" 9-5/8 47# L-80 & Butt 10,000 0 , 0 ]0,0001 8696 Class G 500 sx 1st st.q S00_95 ~ I 300 sx 2nd stage 8½" 7" 29# L-80 Butt 1316 9700 ~, 8480 11,016~ 9492 300 sx Class G ' 22. Describe proposed program: ARCO Alaska, Thc. proposes to d.~rect~onally dr~11 th~s well to 11,016'MD (9492'TVD). Logs w~11 be run across selected ~ntervals. A.20" diverter w~11 be used wh.~le drilling.the. surface hole. A 13-5/8" 5000 ps~ RSRRA BOP stack w~11 be used after setting 13-3/8" casing. Tt w~ll be operationally tested each tr~p and pressure tested weekly. A str~ng of 5½" 17.0# L-80 tubing w~th packer and provisions for subsurface safety equipment w~11 be run. A non-freez!ng l~qu~d w~11 be left ~n all uncemented annul~ w~t'h~n the permafrost ~nl;erval. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The spac~below for Commission use ' ' ' CONDITIONS OF APPROVAL Samples required Mud loft required Directional Survey required I APl number []YES ~O []YES ~NO ~YES []NO -- Permit number Approval date g [~ ~' '~ 06/23/81 stiff covfi~ cE'r'rfi~ ~O~ OTH~ ~fiQU~fiM£N'rS APPROVED BY.,~ ,,COMMISSIONER DATE Gune 23, 1981 by order of the Commission Form 10~,O1 Submit in triplicate Rev. 7-1-80 ~- ~ ' ~ ' :t ' ' ' · ' .' !- ~ ':?. ~ ...'..'.. i~ . ~.'~ .... ~ '. .... .... i... ' ,"- ' : . . , : ~ · :' ', ' "~ '. ' ;''' I' ' ' ! ' '~',':'~,';:::: .' ".~.~'...:' . .k . . I . ' ' -' ' · :'. "'. .....~ .' ' .. ", ". ': . ' ! .' .... ?i;'i '.: ii':'!'i', ;"' i :": :":,:':'~T: ':' '. ":'i" :' '. '::' i' ."F!'~':-..:':TF,.-. ;~?:","'r"['r:::'::F':'T"'i" . . · ~ , , ' .... · ..... ~ ....... ',.' .'.,.-'.- ,.,. 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', ..... .'. ...... :._.:..;....; ............. ;...; ................... /. ......... 4....:.. ~ .................. : ..... .+ ......... .--~-~-.{--~-:-~-:-.~-~4-..-;.t ........ : ..... -+,.-: ........ ~- ................. t- ..... i_.~...:..~ ...... ~....;-.~_~ ........ ~- ..... ~-..:. ....... .: ..... ~._~...~..+..:...{ .............. ~-!,-~.--;-..~-:- F-., ...... ;--:..,~---:...-' .......... !..-~.-= ..... ~. ............ ,~--~-: ~- + :?- .... ~ ...... i .... :-.-,-~*,,--.,-~---4 .......... l- ........:,--~ .... +-~'.-.;-----:- .... i- .......... ??,--"- .................. ~: ~: :~-;.-~ ...... 4-,-.~ ...... ~-~..,.,' :-~-,-~-,--,;-. ' : ~ : , ; . ' ' ' t ' ; , ' '~ '. ~ . · ~ * ' . , ' ' * i . ' ' , ', ; , ~ : , ' .... -l-~-~-..,-,-,, .... ~-+-..;--i ................. ,-.~ ......... ~-., ...... ~- .... i-- ............. {- ............................... ~ .............................................................. -'-.-~- ............................... ~ ........................ -. ~-.-;-4-~: i..+.~.4...L ......... '~....i ......... -;--~--~--..~-{ ..... ~--;-;-+--;-.:- .... .;- f-.:-- ~--:--.~-.i4 ........ ~-...~.4 .... : ...... F-~....~-...i-.--~ ............ ,..-;,.. ,~...~...;-.:--.-;--F-.,-~ ..... .,-4--:.--"--.' ....... { ....... ;--;-.-4--.;-.{-..-~ ' ; ; : { : ' . . ' ' : : i' :., ',, : ' ', ' : , ! : ~ i, i. ' ' , ' , : ; ; : . ; ' ~ ~ I i ' ~, ~ ~, ~ .' ' ..... ~.--,...4 ................... '.-I ................. 4- ................... ~ .............................. ~ ....... --': ........ * .......... ,"--l-..~' ........ ~.-..I. ..... -.-~...~ ........... .~ ..... ~.-..--~.-:.....L.~:---.,~-.4--I-.-,.-.~ ....... ,--:-.-.-~. .... ., ...... ~ , ' , ' , ' , ; , . ', , , ' , . ~ : ! ~ , , ! . , . ' I · ,, ' . ~, ' ', ~ 1~ ' ~ , ' . ' ' ~ ' ' ', ............ :"" ........ Rnrl ' '"1 ' ' .......... '"': ........................... : ............ ~ ................... ' ........ :"'"~ ................ t...: ...... ~..~...: .................. , ........ ~ ......... , .......... ~ .... -, .... ~- ....... ~..? ......... ~--~.-..~--, 110 X I 4 LAT LONG 1'9 6)6,, ~?~. 87 zs--' 1~.8°24, 1~2.. '.7 z'2' . ~T - .. 7o°~z'5).305,, LONG a 1~8°2~'~2.~86'' I~ ~ I AtlanticRichfieldCompany ~, NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT- PRUDHOE BAY i i i I ! b ,v' &q-~'"" 17 I HEREBY CE~Ti~ THAT i LICENSED TO ~AGTICE SURVEYING IN THE STATE OF ~:~',.~: "! '? ~:.:";":~'~':~ A~S~ AND THAT THIS .'~.. ;Y:". %:,<....~. :,,,.~..~..,~?.~. L.,~EPR~ENTS AN A~BUILT SURV~ r...e~.~':'.'r;~':.?..'.'.~ MADE BY M~ AND.,THAT A~ DIMENSIONS AND OTHER D~AI~ ARE ~RRECT, AS OF: ~-I~-~ 17 fill Y - ~,~31,1~,~' · X - , " ~T ~;. 70°12,5~,~81,, L~ - I~S~2~,. . 12 ' -'{' "~L . ;S~ 931,326.50 .. "~ , X ~.' 69G,842.~5 ,' Lk~ T' ' 70°12~S9.729' , ~ LOnG - 1~°24,43. 518- . . ~ ~ 696~830.~9 LOU~ - 14a024,43.784 = . . . ~. .. , I I i ii i ii ii I DATE: DRAWING No: . SURFACE DIVERTER SYSTEM .® L JUN 1 c: 1. 20"' BRADENHEAD 2.. 20" 2000 PSI DRILLING SPOO.L $. 20" 2000 PSI ANNULAR PREVENTER. 4. 1§" Ball Valves 5.. RIG DRILLING RISER 6. lO" LINES TO 'SUMP Acc~mulat:r r .. ~ .a..c,%',' Test ~NNULI~.q P.qEYENT-2~ BLIND RAMS PIPE RRMS SPOOL 1. Check and fil 1 acc'J.-..ulator reser':oir to proper level YHth hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 15CO psi do:.mstream of tr.e regulator. 3. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lo,mr limit is 45 seconds closing time and 12DO psi remaining pressure. ) 13-5/8" BCP Stack Test 1. Fill BOP stack and manifold with a non- freezing liquid. 2. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. ~. Close annular preventer and chokes and ~ypass valves on manifold. ' 4.. In each of the following tests, first hold m .... 250 psi low pressure test for a minimum of ~ minutes, then test at the high pressure. Increasel"~essure to 3000 psi a6d hold for a min~.~mm...of ~minutes. Bleed pressure to zero. Open annular preventer and close top set of pipe "rams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. ClOse valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes. 10. 12. 13. 14. 15. 16. Test remaining untested manifold valves {if any) with 5000 psi upstream of valve and zero pressure downstream. · ."'.. '.-.' .' .. , · , B1 eed pressure to zero. Open' bottom set ~f J U N 1 c}"t,~c,~"~)..~ . pipe rams. Back ~ff running joint and pull oui~ of hole Close blind rams and test to 5000 psi for a~ 'A.F~JOiI& least 3 minutes. ~'~:'¥'~'~"~'" ' Bleed pressure off all equipment: Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position, m mm Test standpipe valves to SO00 psi. . Test Kelly cocks and inside BOP to SO00 psi with Koomey pump. Check operation of De Gasser.' Record test information on Blowout preventer test form. Sign and send to Drilling Super. · .. PerfOrm complete BOPE test once'~ '~ek ~J .... functional operate BOPE daily. ~ J~m ~m: J~J~ . . ._ ..... ....~".L ..,.. ]-'-'c.~::' "~" CHECK LIST FOR NEW WELL PEP~MITS Company Lease & Well No. ,' / ITEM APPROVE DATE (l) Fee ,,' (2) Loc (2 thru 8) (3) Admin [""~.~/--~ i~' L2...,.?',"' -- < 9./t'hru 1 ~-) (4) Casg i2~thru 20)&¢z~-2~/ (5) ,, d~2l thru 24) 1 3. 4. 5. 6. 7. 8. 1 10. 11. 12 14. 15. 16. 17. 18. 19. 20., '21. 22. 23. 24. 25., YES NO Is the permit fee attached .......................................... Is well to be located in a defined pool ............. ~_~ Is well located proper distance from property ii&& 11111111 [ 11 '" Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool .... Is well to be deviated and is well bore plat included .... ii{ Is operator the only affected party ........ :...: .... Can permit be approved before ten-day wait .' ............ Is conductor string provided ....................................... Is enough cement used to circulate on conductor and surface ........ .~ __ Will cement tie in surface and intermediate or production Will cement cover all known productive horizons ............. Will surface casing protect fresh water zones ....................... ~ , Will all d'asing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .......................... Are necessary diagrams of diver~er Does BOPE have sufficient pressure rating - Test to ~ooo psig . Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. REMARKS Additional requirements ' IIIltltlllll.ltltlllllllll.llll.llll.llll.lll Addi~ iona~ Remarks: CLt~.,~.~..d' '4: Geology: Engineering: HWK ~ LCS BEW WVA JKT~, PAD JAL ,.~. / rev: 03/10/81 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE /...o:7 Well Histo~, 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 APPEN. DIXi ., No'special'effort has been made to chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Alaska, Inc. Well DS 12-12 Field Prudhoe'Bay · County, State North Slope, Alaska Date 8/13/81 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale CN Compensated Neutron CN/Multispaced 60-0 , LS Long Spaced CN/Multispaced 'O-1000 SS Short Spaced CN/Multispaced 0-1000 GR Gamm~ Ray CN/Multispaced 0-100 100-200 . . CCL Casing Collar Locator CN/Multispaced 0-1 , , ,. . . . . , ,, PAGE 1 AH, CO ALASKA INC. [}.S. 12-12 PRUDHOE BAY NORTH SLOPE OATA EVEP, Y I SAiqPLES LS 9300.00 0.00 9300.50 0.00 9301.00 0.00 9301.50 0.00 9502.00 0.00 9302.50 0.00 9305,00 0.00 9503.50 0.00 9504.00 O.O0 9304.50 0.00 9305.00 0.00 9305.50 0.00 9306.00 0.00 9~06.50 0.00 9307.00 O.O0 9307,50 0,00 9308,00 "0'.00 9508.50 0.00 9309,00 0.00 9309.50 0.00 9310,00 0,00 9310.50 0.00 9311,oO "'o.oo 9311.50 0,00 9312,00 50.00 95i2.50 332'21 9313.00 -60,00 9313,50 222,21 "931~.0'0' 9314,50 211,17 93.15. O0 212.39 9S'15,50 .... 21'7,91 9316.00 224.05 9316.50 227.73 9317,00 2'28'.96' 9317.50 230.18 9318,00 230,18 9318,50 9319.00 9319.50 235,09 9~20,00 9320.50 235.71 9521.00 256.93 9~21,50 239.39 9322.00 241,84 9322,50 241.84 9325.'00' '239'.'39 . . 9323.50 256.~2 9324.00 233.25 9324.50 228.34' 9525,00 224.,05 SS 0.00 0o00 O.O0 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0.00 R,O0 0.00 0.00 C.O0 0.00 0.00 0.00 0.00 0.0O' 0.00 0,00 O,O'O 0.00 -1.84 , , -1.84 -201.84 -201,84 26o,e'e 256.55 25~,71 "2'5~,1'o 2:55.3~ 258.38 259.61 258.38 255.94 255.94 25~.10 254,10 256,55' 259,61 264.50 266.34 267.56 268.18 270.'01 270.62 265.73 260,22 257,7? CN 0.00 0.00 0.00 0.00 0,00 0,00 0,00 0,00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0,00 0.00 0,00 O.Oo 0.00 32.85 32,80 ~2.75 32,76 32.71 32,60 ~2.55 "32,56' 52.89 $*.03 . . . 53,56 · 32.54 31.43 31 .' 0'7 30.66 30.29 30.11 29,71 29.23 '29,2* 29,7~ 30,01 30.02 29.77 29,50 ..... 29.6~ 30.27 30,49 .... 30.55 30.96 GR O.O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0,00 0,00 0.00 0,00 0',00 0.00 0,00 0.0'0 0.00 99,88 99,8'8 99,88 99,88 '"92.'88 '96,07 9.8.40 99"02 102.58 106.8.7 1i'o.~18 110,80 11~,13 11~'.72 113,87 115,09 1'16,2'0 115.09 111,66 111.17 109.69 109,9~ 107,61 .100,O0 92.52 85.28 CCL O,O0 0.00 0o00 0,00 0,00 0,00 0,00 0.00 0.00 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0,00 0,00 0,00 0.00 0,00 0,00 0.00 0,00 0,10 0,10 ... 0.10 0.10 0,10 0.10 0,10 0.10 0,i'0 0,10 0,10 0'10 0,10 0.10 0,10 0,10 0.10 0.10 0,10 0.10 0,10 0,10 0o10 "0',10 0.10 PAGE ~' ARCO ALASKA iNC. D.S. 12-12 PRUC, HOE ~3AY NORTH SLOPE :.,~ATi.~ E'VE..,.-{y 1 SA¢"IPLES LS SS 9325.50 226.50 254.10 9526.00 229.57 250.%5 9326,b0 252.02 2q7.98 9027.00 231.41 2~5.53 9327.b0 251.~1 2%5.53 9328.00 232.02 2~6.76 9528.50 252.02 2~9.20 9329.00 235.71 252.88 ~529.50 238.16 255.32 9350.00 25~,~8 259,00 9530.~ ~3 253.25 260.22 9331.00 250.80 256.55 9331,50 227.12 252.88 9.~32.00 225.28 251.0~ 9332.50 219,75 251.65 9333,00 216o.07 25~,10 9353.50 217,30 255.9~ 933%,00 218.53 25q,71 9.5.5%,50 222.21 252,26 9335,00 226.50 2~9.20 9335.50 226.50 2~8,59 9536,00 224.66 ..¢%8,59 9336,50 223.~ 2~7.98 9337,00 22~ .66 2~8.59 ...95.37..50 22.7.1.2...250,~ 9338.00 232.02 253.q9 9338.50 237.55 259,61 9 9.oo 2 8.77 9359,50 '235.09 257'77 93~0.00 23~.~8 254.10 9340,50 2.53,86 252,26 93~1.00 235,25 255.32 9341.50 23g.~8 260.22 93~2.00 23~.86 266,95 93~2,50 252,6q 266,~ 93~3,00 229,57 265,28 9~3.50 .22~..66 260,22 9344,00 220.98 257.77 9~4~,50 217,30 255.32 93~5,00 ...215..,~6...2~9.~20 93%5,50 212.59 2%0.6% 93%6.00 205.03 230.8~ 9~6.50 199.,51. 93~7.00 196,%q. 22~.11 93%7.50 193.99 222.89 93~8.00 189.69 221.66 95~8.50 191'53" 221','0'5 95~9,00 194,60 222,89 95~9.50 198,28 22~.'72 9550.00 199,51 229.62 9350.50 20~.~2 235.29 CN GR 50.71 86.26 29.76 88.10 28.72 90.45 28.50 91.90 28,50 90,55 28,75 87.85 28.98 86.50 28.98 86.75 28.6~ 87.48 29,05 86,63 29.89 8q.Sq 29.96 83.93 30.21 8~.5~ 30,63 86.50 31,21 88,10 32,22 88..3~ 33.00 89.9~ 32,22 91,90 31,0' .. 9~,~6 30.11 98,~0 29,92 10~.05 ..2.9,.93 !0.7,.12 30,19 107,36 50,~1 109,33 30,38 109,33 30,05 106,50 2.9.71 lO0,O0 .a.9.,ao ...... 28.8~ 90,92 28,85 91.29 29,.07 .97,~2 29.58 106,6~ 29,92 110.06 lO7.12 3o. 8 i'o5, o 31,02 99.51 51.,7~.. .102,70 ~2.20 107,12 32,39 115,3~ ~1,91 . ,!22,33 , . 31,55 126,15 ~0,89 131.29 31,15. 1.30,31 31.80 130,18 33,01 13%,36 33.31 133.87 3~.23 128,3~ 5~.25 122,82 33,67 112.39 33,31 99,75 33,~2 88,~7 CCL 0,10 0.10 0,10 0.10 0,10 0.10 0.10 0.10 0,10 0.10 0.10 O,lO 0.10 0,10 0,10 0.10 0,10 0,10 0,10 0,10 0.10 0,10 0.10 0,10 0,10 0.10 0,10 0.10 0,10 0,10 . . 0,10 0,10 0.,10 0,10 0.10 0,09 0,09 0,07 .0.,15 '0,12 0.10 O,lO 0,10 0,10 0.10 0,10 0,10 0.10 0.10 0.10 PAGE 5 AP, CO ALASKA INC. · . "' ~ ' ~ !:'1 S. t2-1.2 Pt'{UDHOE L3AY f,i,,~TH SLOPE 9.&TA EVERY 1 SAMPLES LS SS CN 9351.00 209.9~ 236.35 52.76 9J~]..50 212.59 234.52 31.59 9352.00 208.71 230,8,~ 30.87 9352.50 205.6q 231.q6 51.12 9353.00 203.19 235.7~ 31,93 ~555.50 20~.~2 238.80 ~2.90 9&5~.00 207.~8 2N2.~7 33,~7 935~.~0 209.~ 2N2.~7 33.1~ 9355.00 207.~8 2N0.02 32,60 9355.50 2{17.~8 236.96 32.36 ~356.U0 209,94 235,7~ 52.09 9356.50 211.78 23~.52 31,~2 9357.00 ~17.~0 236.35 30.69 9357.50 220.98 2~0.6~ 30.~2 9558.00 22~.66 2~6.76 30,53 9358,50 227,73 251.65 30,53 9359,00 228.34 253.~9 30.15 9559.50 227,~2 251,65 29,81 9360.00 2.25,28 251,0~ 30,0~ 9360.50 227,12 251.0~ 30.23 9361,00 228.3~ 252,26 30,07 9561,50 228.96 252.26 30.07 9562,00 227.73' 25~',71 30,20 9362,50 229.57 259.61 30,66 9563.00 230,80 262006 SO,91 , , 9565.50 25~.g8 265.89 50.6~+ 956q.. O0 2ql.2~ 267.56 50.52 9~6q.50 297,~6 275,52 29,98 · , 9~65 O0 25'0,q.~ ~.8g,09 29,90 9~65.50 255,~ 292,66 29,99 9366,00 259,02 299,~9 ~'6~.~o ~9.o~i' ~o~.~, so.2~ 9367.00 260.25 297,55 29,70 9:~67.50 256.56 28~.98 .es.so 9368.00 2~.91 27~.91 28.06 9568.50 236.~2 263.89 29,09 9369.00 2~1.~1 26~.28 30.~9 9~69.50 227.73 265.12 31.'~8 9~70.00 22~.66 266.95 32.25 9570.50 222.~.1 265.73 ~2.58 9~71.00 222,82 26'2.67 ~1.91' 9~'71.50 220.98 ~, 55 31 56 9372.00 2~7.30 2~9.20 31,~9 9572.50 21'6,07 2~3.08 51.51 957~.00 216.07 259.~1 50.95 95'75.50 21~.23 236.96 30.70 93'7~.00 215.01' 236.96' 50.70 957~.50 21~.85 237.58 9~75.00 217.91 2~0.6~ 30.99 9375.50 221.59 '2.~3.08 30.79 9376.00 220.57 2q3.70 ~0.19 GR 79.88 71.55 66.63 68.~7 72.02 75.50 73.87 76.07 80,~9 8~.91 88.3~ 91.53 9o.07 97.67 98,53 95,95 92.52 92.02 92.76 96,~ 98,0~ 95.58 95.71 95.3~ 9~.23 90.80 90.06 87,98 8~,89 81.10 75,~6 68,22 60.7~ 57.55 59,26 65.52 73.25 79.39 82.53 87.61 88,'71 88.22 89,69 92.6~ 96,56 9~,77 98,77 96,~ 95.15 91.55 90.67 CCL 0.10 0.10 0.10 0.10 0.10 0.10 0.10 0.10 0.10 0.10 0.10 0,10 0.10 0.10 0,10 0.10 0,10 0.10 0.10 0,10 0.10 0.10 0,10 0,10 0,10 0,10 0,10 0,10 0,10 0,10 0,10 0.10 0.10 0,10 0.10 0,10 0.10 0,10 0.10 0.10 0.10 0,10 0.10 0.10 0.10 0,10 0,10 0.10 0.10 0.10 0.10 PAbc 4 ARCO ALASKA 1NC, L), $, 12-12 PRUDI. iOE BAY OATA EVL-.R~ I SAF1PLES SL OPE LS SS 9576.50 220.57 241.86 9577.00 2].6.69 256.55 ~77.50,. 21,= .39 ~'50.8~. 9578.00 209.53 227.17 9578.50 211,17 227,17 95'79. O0 212.59 229.01 9579.50 211.17 250.84 9360,00 206.87 ~31.~6 9550.50 204,~2 232.68 93~1.00 201,9b '232,68 9381,50 200.7, 232.07 9582.00 199.51 231.~6 95,52.50 198.28 2~2.07 9383.00 198.28 25~.90 9~83.50 196.90 9584,00 197.67 246.14 958~.50 200,12 2~9,82 9585.00 200.7* 249,20 9385,50. 197.67 2~3.70 938~,00 196,44 233.90 9386,50 193.37 222.28 9587.00 189,08 21~,93 9~7.50 187,85 9388.00 186.6~ 21~.93 9588,..50 18~,79 21~,93 ~'' 56 214. 95 95~9,00 185. . 9589.50 186.63 214.93 90.so 192.15 216.16 9591.00 197.67 216,16 9591.50 200..7~ 2,16.,16. 9392.00 202,58 217,99 9592,50 202,58 218.60 9'595,00 200,7~ 219,22 9393.50 198.28 220,~ 939~.00 200.12 221,05 959~.50 206.26 225.50 9595.00 211.17 226,56 9595,50 209,55 227,17 9596. 00 20~.~2 225. 9596,50 200.12 225.5~ 9397,00 195.21 222.89 9:597,50 192.15 225.50 9598.00 18'7.24 c25, 9598,50 186,6~ 229,62 9599.00 189,69 255.74 9399,50' 195,99 2~1.25 CN 30.05 90.18 29.71 91.66 29.73 98.28 30.04 105.15 50.27 ~08.~7 30.32 108.,7 50.58 105.6q ~0.80 102.09 31,53 lO1,Sq ~1,95 52.82 105.0~ 3~.01 108.10 33.25 109.53 33.76 111.53 34.16 113.87 3~,90 115.3~ 36.05 110,67 35.75 98.5~ 3q.25 92.88 35.~9 90.~5 3~.~8 9~,23 ~.87 96.69 5~.1~ 96,9~ 5~.62 95.71 33.05 8~.70 ~,.52 79.59 31,~9 ..... 76,93 30.6~ 75,58 30,62 78,65 30.,,86 ..80,.25 31,39 80,37 31,85 81,2~ ~1.69 76,69 30.~8 7'2.15 29.98 67.61 30,~0 66,50 30,8~ 66,01 32.~ 65,8O 53.81 66,65 3~,95 70,43 ~6,19 70,4~ 37,02 68,22 36,95 66,13 CCL 0.10 3.10 0.10 O.lO O.lO 0.10 0.10 O.lO 0.10 0.10 0.10 0.10 0.10 0.09 0,09 0,12 0,06 0,10 0.10 0.10 0,10 0,10 0,10 0,10 0,10 0.10 0,10 0...10 0,10 0,10 0.,10 0.10 0.10 ..0,,1,0 0,10 0,10 0.10 0.10 0.10 0.10 0.10 0.10 0,10 0.09 0.08 0.11 0.15 ECC I"..'U ?1 [:~ E R 1061,00 ARCO ALASKA Il\lC, D,S, 12,-12 PRUDHOE [BAY NORTH SLOPE .. 5 CURVES : LEYEL SPAC II'~]G ~_~. 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