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Home My WebLink About200-191 Imagff 'roject Well History' File Cover I~ je 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. ~00- _~ ~_~ L Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds BY; BEVERLY ROBIN VINCENT SHERY[~~WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation i x 30 = ~ {~ BY: BEVERLY ROBIN VINCENT SHERYL,~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: __ YES (SCANNING IS coMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB~'~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12/10102Rev3NOTScanned.wpd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas Plugged / Abandoned ^/ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: October 22, 2007 12. Permit to Drill Number: 200-191 1307-301 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 14, 2000 13. API Number: 50-029-21432-01 4a. Location of Well (Governmental Section): Surface: 527' FSL, 749' FEL, Sec. 7, T12N, R9E, UM 7. Date TD Reached: December 20, 2000 14. Well Name and Number: 3A-03A Top of Productive Horizon: 4468' FNL, 579' FEL, Sec. 18, T12N, R9E, UM 8. KB (ft above MSL): 72' RKB Ground (ft MSL): 121.8' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 3827' FNL, 5211' FEL, Sec. 17, T12N, R9E, UM 9. Plug Back Depth (MD + ND): 4122' MD / 3254' ND Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 507699 y- 5996908 Zone- 4 10. Total Depth (MD + ND): 9735' MD / 6164' ND 16. Property Designation: ADL 25632 TPI: x- 507892 y- 5991913 Zone- 4 Total Depth: x- 508537 - 5992556 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: ALK 2565 18. Directional Survey: Yes ^ NoQ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (lVD): ~ D y/ 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): pg GR/RES ~ ~• 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE ENTING CORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEM RE PULLED 16" 62.5# H-40 Surface 106' Surface 106' 24" 1a7 sxAS II 9-5/8" 36# J-55 Surface 3888' Surface 3098' 12.25" 1200 sx AS III & 320 sx Class G 7" 26# J-55 Surface 7794' Surface 5921' 8.5" 425 sx Class G & 250 sx AS I 2-3/8" 4.6# L-80 7122' 9730' 5418' 6164' 3" 25 bbls 15.8 ppg Class G cement retainer (~ 7100' 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET none perforations a~~ SAN 2 ~ 2008 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 7100' ('A' sand) 18 bbls of 15.8 Class G 'C' sand via IA 56 bbls Class G 26. PRODUCTION TEST Date First Production not available Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVIN -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ^/ Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071 ~ _ F,.., _ _ i~qY~i ~~ ~~f-; ~,,L` '~ ii:s:.C}m~ NONE ~ ~E~11Lv .-_ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~/j~ ~, ~,d~ ~.~ ~ ~ ,4a'~ `~ [OJT /~" STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~~~ ~ ~i~t~] WELL COMPLETION OR RECOMPLETION REP 1a. Well Status: Oil ^ Gas Plugged ~ ~ Abandoned ~ 'Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1 b. Well Class ..n~ ~ „~ Development ~ ~~ ~ ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: October 22, 2007 ' 12. Permit to Drill Number: { 200-191 / 307-301 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 14, 2000 13. API Number: 50-029-21432-01 ' 4a. Location of Well (Governmental Section): Surface: 527' FSL, 749' FEL, Sec. 7, T12N, R9E, UM 7. Date TD Reached: December 20, 2000 14. Well Name and Number: 3A-03A Top of Productive Horizon: 1273' FSL, 652' FEL, Sec. 18, T12N, R9E, UM 8. KB (ft above MSL): 72' RKB Ground (ft MSL): 121.8' AMSL ' 15. Field/Pool(s): Kuparuk River Field Total Depth: 1015' FSL, 679' FEL, Sec. 18, T12N, R9E, UM 9. Plug Back Depth (MD + TVD): 4122' MD / 3254' TVD Kuparuk Oil Pool ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 507699 ' y- 5996908 Zone- 4 10. Total Depth (MD + TVD): 9735' MD / 6164' ND ~ 16. Property Designation: ADL 25632 TPI: x- 507892 y- 5991913 Zone- 4 Total Depth: x- 508537 - 5992556 Zone- 4 11. SSSV Depth (MD + TvD): none 17. Land Use Permit: ALK 2565 18. Directional Survey: Yes ^ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD):~ ,y960' TVD Z/9~ 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): /Z~ !Y•m~ GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT'. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 106' Surface 106' 24" 187 sx AS II 9-5/8" 36# J-55 Surtace 3888' Surtace 3098' 12.25" 1200 sx AS III & 32o sx Class G 7" 26# J-55 Surface 7794' Surface 5921' 8.5" a25 sx Class G & 250 sx AS I 2-3/8" 4.6# L-80 7122' 9730' 5418' 6164' 3" 25 bbls 15.8 ppg Class G cement retainer @ 7100' 23. Open to production or injection? Yes No ~ ~ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET none ®~ perforations abandoned ~ ~ ~ ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~` ~ ~ DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED ~~ ~ cement retainer @ 7100' ('A' sand) 18 bbls of 15.8 Class G ~ v 'C' sand via IA 56 bbls Class G 26. PRODUCTION TEST Date First Production not available Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OiL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No 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 AAC 25.071. / ~?!YcoYC~~2-t~ " OA ~"~ x NONE s /Dp • 2.2 t t/~~~g~-Y~~ t °--~ f Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE r~ 28. GEOLOGIC MARKERS (List all formations and ma ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, List intervals and formations tested, Permafrost -Top ground Surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 3750' 2194' / needed, and submit detailed test information per 20 AAC 25.071. Top of Kuparuk C 7786' 5914' Top of Kuparuk A6 8618' 6120' Top of Kuparuk A5 8664' 6124' Top of Kuparuk A4 8704' 6129' Top of Kuparuk A3 8775' 6133' Top of Kuparuk A2 9280' 6157' N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Nam G ch Title: Wells GrOUp Enoineer /1r/~ r O ~ D ~ ' ate ~ cr S~ Signature Phone ~G r i INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of (ands and leases in Ataska. 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 elevations 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 list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 3A-03A Pre-Rig Summary DATE Summary 9/10/07 TPOT/PPPOT -PASSED, MITOA -PASSED, LDS FUNCTION TEST (PRE-RWO) 9/29/07 9/28/07 Performed Infectivity test down IA: 1 bpm @ 1450 psi, 1.35 @ 1600 psi. 9/29/07 Performed infectivity test down Tbg: 2 bpm @ 1700 psi 10/11/07 RAN A GR/CCL TO CONFIRM ENOUGH SPACE EXISTED TO SET CEMENT RETAINER BETWEEN GLM #5 AND THE SL SET LINER TOP PACKER. SET A HALIBURTON EZSV CEMENT RETAINER WITH MID ELEMENT AT 7100' 10/12/07 TESTED TBG /EZSV 2000 PSI, GOOD. PULLED DV @ 7081' RKB. READY FOR CTU ! CMT. 10/18/07 RIH WITH A 2.25" BAKER BHA AND STUNG INTO A EZSV CEMENT RETAINER @ 7100' E-LINE MD WITH 2.68" MAX OD HALLIBURTON STINGER.PUMP A TOTAL OF 18 bbls OF 15.8 CLASS G CEMENT INTO THE A SAND 2 3/8" LINER BEFORE ACHIEVING 1000# OF SQUEEZE PRESSURE.PULL OUT OF RETAINER AND STARTED BULL HEADING CEMENT INTO THE C-SAND THROUGH THE OPEN GLM @ 7081' MD. PUMPED TOTAL OF 42 BBLS OF CEMENT AND STARTED SEEING AN INCREASE IN SQUEEZE PSI. PUH AND LAID IN 2 BBLS OF CEMENT FROM 7081' CTMD TO 6850' CTMD HOLDING 1100# OF SQUEEZE PSI WHILE CONTAMINATING CEMENT FROM 6600' TO 6900' . WE LOST 400# OF SQUEEZE PSI. POOH AND FREEZE PROTECTED FROM 3000' 10/19/07 GAUGED TBG TO 2.73' ;TAGGED @ 7075' SLM, NO SAMPLE. ATTEMPTED LOCATE GLM @ 7081' RKB, NO SUCCESS. INJ RATE: 1/4 BPM @ 2750 PSI. TBG & IA COMMUNICATING. 10/22/07 PUMPED 16 BBLS CLASS G CEMENT. CIRCULATED 5 BBLS INTO THE IA (TOC 6891' RKB) AND BULLHEADED 6 BBLS ADDITIONAL CEMENT INTO THE IA ATTEMPTING TO GAIN 2500 PSI SQZ PRESSURE. ABLE TO REACH 2400 SQZ PSI, OPENED CHOKE TO LAY IN REMAINING 5 BBLS. LOST A TOTAL OF 3 BBLS WHILE LAYING IN, LEAVING 2 BBLS IN THE TBG WITH AN EST. CEMENT TOP OF 6851' RKB. TOTAL OF 14 BBLS OF CEMENT PUMPED INTO THE IA. WELL LEFT SHUT IN AND FREEZE PROTECT WITH DIESEL TO 2500'. SHUT IN WHP @ 1866 PSIG AND 2037 PSIG IA. 10/24/07 DRIFT TUBING W/ 2.79" SWAGE TO TOC @ 6452' SLM. MIT T TO 1500PSI, DID DRAW DOWN TEST ON IA. MIT IA TO 1500PS1, DID DRAWDOWN TEST ON TUBING. TESTED GOOD. STATE REP (LOU GRIMALDI) WAIVED WITNESS OF TEST. PULLED 1" BKDV FROM STA #4 @ 6345' RKB POCKET LEFT OPEN. 10/25/07 COMBO MIT T X IA (PASSED), 45 MIN DRAW DOWN TEST (PASSED) 10/25/07 TUBING CUT AT 6310' (5' BELOW TOP COLLAR OF FIRST FULL JOINT ABOVE GLM 4) WITH 2.5" SCP POWER JET CUTTER, WELL LEFT SHUT IN. VALVE CREW TO INSTALL BPV TONIGHT. • ~ Q ~ d ~ SARAH PAULA, GOVERNOR ~~~ O~ ~,~D ~~ 333 W. 7th AVENUE, SUITE 100 C011T5ERV~~`I011T CODII-R55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 278-7542 Guy Schwartz Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 #u`f ~ ~~1~ 4 ~0~~ ~'} f~tj -- ~~ Anchorage, AK 99510 O'`` Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A-03A Sundry Number: 307-301 --~ -°~~"'~' Dear Mr. Schwartz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Dan T. Seamount Commissioner DATED this day of October, 2007 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~~ ~~~~7'7.007 APPLICATION FOR SUNDRY APPR~~.~~~, ":32, ~~~ ~~,~~E~$~~~ 20 AAC 25.280 1. Type Of Request: Abandon ^ ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhlllips Alaska, Inc. Development Q ~ Exploratory ^ 200-191 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21432-01 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S NO ~ ~ 3A-03A i 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25632, ALK 2565 RKB 72' ' Kuparuk River Field /Kuparuk Oil Pool - 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth M~ (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9735' 6164' 9698' Casing Length Size MD ND Burst Collapse CONDUCTOR 106' 16" 106' 106' SURF CASING 3816' 9-5/8" 3888' 3098' PROD CASING 7722' 7" 7784' 5921' LINER 2612' 2-3/8" 9730' 6164' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8775'-9235', 9275'-9675' 6133'-6147', 6156'-6161' 3-1/2" J-55 7715' Packers and SSSV Type: Packers and SSSV MD (ft) pkr-- BAKER SAB-3 PACKER pkr- 7680' Camco 'D' nipple @ 513' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 5, 2007 Oil ^ Gas ^ Plugged Q ~ Abandoned Q 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU SChWartz - ? Title: Wells Engineer Signature ~, ~ Phone 263-4820 Date ~..-~~u ^'GJ .~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~ `~\~ i ti\ ~t~`i a`1~:V-~e~`Q~ ~ S•~ y ~~ u Subsequent Form Required: -\~ S ~~ c~~ ~ ~ ~~o~ APPROVED BY /©~ Z,/ Approved by: COMMISSIONER THE COMMISSION Date: ! f Form 10-403 Revised 06/2006 j""~ ~'"~ ~ j'~ ~ ~ /t; Submit in Dup{icate • 3A-03A P & A Outline September 26, 2007 Summary: 3A-03, the original well, was a single selective completion that produced 4.95 MMSTBO (49% recovery) from the C sand and 0.21 MMSTBO (13% recovery) from the A sand. The single selective completion was removed to run an ESP in 07/1998. Due to solids production the ESP failed in 11/1998 and it was pulled on OSJ1999. A single completion was ran in the hole which did not lend itself to isolate the C sand mechanically. 3A-03 was shut-in on 1112000 in preparation for CTD sidetrack 3A-03A which was drilled on 1212000. A 2-318" liner was cemented and perforated. The well was cased, cemented, and 860' of the horizontal section was perforated. 3A-03A failed to produce. It is believed that the well was damaged during the completion:~A gel breaker perforation wash treatment was pumped on 02J2001 with no positive effects. It was noted that lab test results indicated that an HCl treatment would be an effective remedial action. A program was written to spot acid across the horizontal section using coil and a swap cup straddle tool (SCST) and to induce a propped fracture pending the results of the acid stimulation job. To run the SCST through the 1D restriction presented by the liner top packer, the packer had to be removed. After several attempts to retrieve the packer it was chemically cut and retrieved. Unfortunately the 3 '/2" tubing behind the liner top packer was chemically cut in the process and the well started to flow 1,992 to 2,706 BLPD at watercuts greater than 99%. The increase in production is expected to be coming from the C sand through the liner top packer, as indicated by a leak detect log (LDL). Another liner top packer has been run (7-07) ,stinging into the 2 3!8" stub to isolate the A sand horizontal lateral from the leaking 3 lz" tubing. Pre-rig Wellwork: 1) Test wellhead packoffsl cycle LDS's (POT-IC failed) 2) Set 3 %z" cement retainer at 7100' md. 3) Pressure test tubing. Line up on IA and determine injection rate in C sand . (IA will not test due to 3 % "tubing damage below Liner top packer at 7118 ). 4) Pull DV at GLM 7081'md (leave GLM pocket open). ~~~ ` tt ~a( n a ~~jN~ S) Pump cement into A sand 2 3/8" liner via retainer. (liner volume => .00387 bbl/ft x 2600' = 10 bbls ) • • 6) Pull out of retainer and bullhead cement into C sand via open GLM (7081' md) to IA and back into 3 '/2" tubing breach at 7118'md. (Current injection rate into C sand is 1 bpm at 1600 psi. -pump at least 20 bbls into IA to ensure annular space from packer to 3 % "tubing hole is covered. ) 7) Pump cement until 1000 psi squeeze pressure is attained. Lay in cement in tubing to depth of 6900' md. 8) Test IA and tubing cement plugs. 9) Pu11 GLM DV at 6345'. Cut tubing at 6800' md. (jet cut with E-line) 10) Set BPV ,prep wellsite for rig. Rig Work P & A component: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MURU Doyon 141. Test BOP's. 2. L/D the tubing hanger and pull 3-1/2" tubing. 3. PU mill, casing scraper, and 4" DP. RIH to top of tubing stub at 6800'md. POOH. 4. RU wireline set a CIBP inside the 7" casing at +/- 4100' MD based on casing collar depth. • ~`»~` ~`~1~(~~U~~ir~i~'3'Sr` ~l~r3SC~~ ~11~. 1,3A-03A _ _ KRU 3A-03A API: 500292143201 Well T :PROD An le TS: de SSSV T e: Ni le Ori Com letion: 12124!2000 An le TD: 88 de 9735 ' Annular Fluid: Last W/0: Rev Reason: Set Liner to Packer NIP (513-514, 00:3.500) ~ Reference Lo Ref Lo Date: Last U date: 8!10/2007 Gas Lift i ndrel/Dum my Valve 1 _ (3296-3297, ~ I 00:5.390) Gas Lift - indrel/Dummy ' r Valve 2 (4822.4823, 00:5.390) Gas Lift ~ ndrel/Dummy Valve 3 (5349-5350, 00:5.390) i Gas Lift indrel7Dummy Valve 4 .~ _ - ~~ (6345$348, ~ j ~ 00:5.390) I I Gas Lift - i ndrellDummy Valve 5 (7081-7082, 00:5.390) I TUBING " -~ I (0-7715, 00:3.500, ~ I /0:2.992) ® I 1 Gas Lift i ndrel/Dummy Valve 6 _ _ (7607-7608, i 00:5.968) i PBR - (7664-7665, 00:3.500) ~ - _ SEAL - (7670-7671, (' ~ ;. ' I I 00:3.500) i 1 I PKR - (7680.7681, 00:6.500) J - ~ PROD CASING (0-7794, oD:7.oo0, wt:zs.oo) Ped (8775-9235) Casing String -ALL ___ , f]acrrintinn - i Gvn - i Tnn i Rnttnm i TVn i 4Yt i C:radw i- Thread CONDUCTOR 16.000 0 106 106 62.50 H-40 WELDED SURF CASING 9.625 0 3888 3098 36.00 J-55 BTC PROD CASING 7.000 0 7794 5921 26.00 J-55 BTC LINER 2.375 7118 9730 6164 _ _ 4.60 _ _1-8D _ _ FL4S I GSCi WINUUW I 2.SUU I y/94 I /8UU l SyZ, I U.UU I I i Tubing String -TUBING ~ Size ~ Top ~ Bottom ~ TVD ~ Wt Grade ~ Thread Gas Lift Man_dreisN_afves ~~St MD rTVD~~ Man Mfr ~ Man Type i V Mfr i V Type i V OD ~ Latch i Port ~ TRO i Date Run i Vlv MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permitto Drill 200'1910 DATA SUBMITTAL COMPLIANCE REPORT 6/212003 Well Name/No. KUPARUK RIV UNIT 3A-03A Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-21432-01-00 MD 9735 ~----~ TVD 6164 -"- Completion Dat 5/17/2001 J Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._9_o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Data Digital Digital Type Media Fmt Name ~:~'- C "~r LIS Verification I ~-'"'~ c.V. et/ LIS Verification ..~'~- ~oR""Gamma Ray Well Cores/Samples Information: Interval Log Log Run OH / Dataset Scale Media No Start Stop CH Received Number Comments 1 7693 9735 Case 2/7/2003 /__.,,t1~90 1 7693 9735 Case 2/7/2003 25 Blu 1 7693 9735 Case 2/7/2003 25 ....... Blu ....... -1 .............. 76D3 ....... 97-35- -- Case .... 2/712003 .... Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R ~.r~.iv~.d 9 Daily History Received? ~'/N Formation Tops (~ N Comments: Compliance Reviewed By: Date: ~-~ J ~- "~ '~, ~- Transmittal Form BAKER _. _.... HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3A-03A ~ Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional TVD Log LAC Job#: 106551 Sent By: Glen Horel Received B~~~j ' //1_ ~(~ Date: Feb 5, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECEIVE[ FEB 07 Alaska ~ a Gas Scl lumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1736 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 01/17/02 Well Job # Log Description Date BL Sepia CD Color lC-125 <:~bl-lC~'~j PRESSURE STATION PBMS 12/28/01 I 1 1D-137 . .-~E)~)-CY-I-'/ INJECTION PROFILE 01/04/02 I 1 1D-138 ~;~00-©L~ INJECTION PROFILE 01/05/02 I 1 1Q-21 /9 ~ ~ ]~ ~ PRESS-TEMP STATIONS PBMS 12/29/01 I 1 1Y-15A I c} ~_) ~'~ PRODUCTION PROFILE 01/02/02 I 1 1Y-15A GAS LIFT SURVEY 01/02/02 I 1 2K-28 301- I.c~~] STATIC BOTTOM HOLE PRESS SURVEY 12/16/01 I 1 3A-03A ~O~- lC/I LEAK DETECTION LOG 01/08/02 I 1 30-03 ! ~-O~ ~ PRODUCTION PROFILE W/DEFT 12/31/01 I 1 30-03 PROD PROF FIELD DEFT PRESENTATION 12/31/01 1 1 30-03 GAS LIFT SURVEY 12/31/01 I 1 SIGNED: ~ i DATE: RECEIVED JAN 2 fi 200Z Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank yfll~lkll0il&GtlsC01l[~.~llllliJl~t 07/24/01 Schlmberger NO. 1316 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 2-21A ;ZOJ - O~ 21327 MCNL 06110/01 I I 1 D.S. 18-34 1~5~./~zir LEAK DETECTION 07107/01 I 1 A-17 18~"' J~Z" LEAK DETECTION 07118101 I 1 Y-t4A I~;"/~l"~ LEAK DETECTION 071t2/01 I 1 X.lSL~ '?_.ol- effl 21330 MCNL 06/11101 I 1 I C PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered:~~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATi'N: Sherrie Received by: RECEIVED JUL 2001 PI ,.,.LI Alaska, Inc. A Subsidiary of IPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 June 5, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3A-03A (200-191) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation operations on the KRU well 3A-03A. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEIVE Alaska Oil $ Gas C~s. Anchor~e ORIGINAL REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4750' FNL, 748' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 4468' FNL, 579' FEL, SEC. 18, T12N, R9E, UM At effective depth At total depth 3825' FNL, 5209' FEL, Sec. 17, T12N, R9E, UM 5. Type of Well: Development _X Exploratory_ Stratigraphic_ Service_ (asp's 507699, 5996908) (asp's 507892, 5991913) (asp's 508537, 5992556) 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3A-03A 9. Permit number / approval number 200-191 / 10. APl number 50-029-21432-01 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 9735 feet Plugs (measured) 6164 feet Effective depth: measured true vertical Casing Length CONDUCTOR 106' SURF CASING 3816' PROD CASING 7722' LINER 2612' CSG WINDOW 6' 9698 feet Junk (measured) 6162 feet Size Cemented Measured Depth 16" 187 sx AS II 106' 9-5/8" 1200 sx AS III & 320 sx Class G 3888' 7" 425 sx Class G & 250 sx AS I 7794' 2-3/8" 25 bbls Class G 7122'-9735' 2.8' 7794'-7800' True vertical Depth 106' 3098' 5921' 6164' 5925' Perforation depth: measured 8775'-9235',9275'-9675' true vertical 6133'-6147', 6156'-6162' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7715' MD. Packers & SSSV (type & measured depth) RECEIVED JUN 1 3 2001 Alaska Oil & Gas Cons. Commission Anchorage HES 'GHP' RETRIEVABLE LINER TOP PACKER @ 7118' MD; BAKER SAB-3 PACKER @ 7680' MD. CAMCO 'D' NIPPLE @ 513' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Md Water-Bbl Shut-In 40 40 1948 Casing Pressure Tubing Pressure 126 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. Michael Mooney Title Staff Engineer Questions? Call Michael Mooney @ 263-4574 Prepared by Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE~~) Date Comment 3A-03A Event History 02/04/01 0;2 05 ;1 RIH FOR PERFORATION WASH. CONT'D ON NEXT WSR [Other Stim] WASHED PERFS W:TH 33 EELS OF GEL BREAKER: !3AS~ .'-'UID 2;'0 KCL W 252-'.' J21 GAL F078. ALLOWED 4 HOURS SOAK TIME, JETTED OUT WITH SW. LAID IN DIESEL FROM 8500' WITH ZERO PSI WHP AND 1:1 RETURNS WHILE POOH. RELEASED WELL TO PRODUCTION FOR FLOWBACK. [Other Stim] Page 1 of 1 5/18/01 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil r~ Gas D Suspended D Abandoned D Service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ~ V~-I~IPI~D I 200-191 3. Address ~ ,5 . 8. APl Number P. O. Box 10360 Anchorage, AK 99501-0360 g. 50-029-21432-01 4. Location of well at surface 9. Unit or Lease Name ,,... ....... : .-~..-%-:~ :.--.~ 4750' FNL, 748' FEL, Sec. 7, T12N, R9E, UM (asp's 507699, 5996908) ~ C, 0i,..~?,.~_T~0~, : Kuparuk Unit t At Top Producing Interval ~ ~ATE ~ ,~. 10. Well Number 4468' FNL, 579' FEL, SEC 18, T12N, R9E, UM (asp's 507892, 5991913) ....... 3A-03A At Total Depth ;~ '/~!:~L~ ! 11. Field and Pool 3826' FNL, 5210' FEL, SEC 17, T12N, R9E, UM (asp's 508537, 5992556) ,. .................................. Kuparuk Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 72 feetI ADL 25632 ALK 2565 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 14, 2000 December 20, 2000 May 17, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9735' MD / 6164' TVD 9698' MD / 6162' TVD YES [~] No ['--]I 513' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 106' 24" 187 Sx AS II 9-5/8" 36# J-55 Surface 3888' 12-1/4" 1200 Sx AS III & 320 Sx Class G 7" 26# J-55 Surface 7794' 8-1/2" 425 Sx Class G & 250 Sx AS I 2-3/8" 4.6# L-80 7122' 9735' 3" 25 bbls 15.8 ppg 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) 3-1/2" 7715' 7680' 8775' - 9235' MD; 6133' - 6147' TVD; @ 4 SPF 7118.5' 9275' - 9675' MD; 6156' - 6161' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 18, 2001 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 5/21/2001 3.85 Test Period >I 1000 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -126 psi 24-Hour Rate > 40 40 1948 28. CORE DATA Brief description o! lithology, porosity, fractures, apparent dips and pressence ol oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved November 28, 2000 (Permit #200-191) jUi ' j Aiast(a ©il & Gas (.;,z~ns. (;ommissiop Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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 of Kuparuk C 7786' 5914' Top Kuparuk A6 8618' 6120' Top Kuparuk A5 8664' 6124' Top Kuparuk A4 8704' 6129' Top Kuparuk A3 8775' 6133' Top Kuparuk A2 9280' 6157' 31. LIST OF ATTACHMENTS Summary of 3A-03A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. SignedXi~...~__ _ '~ t ~ Title Coil Tubin.q Drillin.q E nqineer Date May 31. 2001 Lamar Gantt INSTRUCTIONS Prepared by Paul Rauf 564-5799. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. il'~t~}. !t'"'!~. (~ E I'V' E '~b~ Item 28: If no cores taken, indicate "none". ~,.,,;'~ L.~ ~'~ Form 10-407 ,~'-'Jssl,,~a {.}il & C~as.~.'5'_,,~:.",° Commissien A~sch0rage i 3A-03A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 12/08/2000: 1 2/09/2000: 12/10/2000: 12/11/2000: 12/12/2000: 1 2/13/2000: 1 2/14/2000: 12/15/2000: 12/16/2000: 1 2/17/2000: 1 2/18/2000: 1 2/19/2000: 12/20/2000: 12/21/2000: 12/22/2000: 12/23/2000: 12/24/2000: 12/29/2000: MIRU CTU#4 & Nabors 3S. Rig accepted 0100 hrs. NU BOP Stack. Completed RU. PT'd BOPE. RIH w/CT. The first Cement Plug was pumped to Plug & Abandon the lower wellbore. The second Cement Plug was pumped to Plug & Abandon the lower wellbore. Cleaned out wellbore & PT'd cement. RIH & tagged TOC @ 7697' MD. Milled pilot hole to 7794' & POOH. RIH w/one step mill & tagged BTM. Milled window through the 7" casing. TOW = 7794'. RIH & dressed window interval. POOH. RIH & drilled f/7811' to 7863'. 25% lost rtns. POOH. RIH & drilled to 8080' MD. POOH. Begin AOGCC witnessed BOPE Test. RIH w/CT & injected LCM pill (38 bbls total). POOH w/CT. RIH & drilled to 8150'. Drilled to 8335' & POOH. RIH & drilled to 8400'. Drilled to 9350'. Had trouble w/shales f/8630' - 8680'. Drilled to TD @ 9735'. Conditioned OH f/liner run. Reamed f/8630' to 8680' & POOH. MU 2-3/8" 4.7# FL4S L-80 liner. RIH & worked liner to 9660' w/difficulty. Pumped 12 bbl extra slick Diesel pill & landed liner @ 9735'. TOL = 7122'. Pumped 25 bbls of 15.8 ppg Class G Cement to cement liner in place. Placed 15 bbls of Cement behind pipe. Pulled stinger f/seal sub. 1:1 returns. Contaminated cement w/Biozan & jetted contaminated cement f/wellbore. POOH w/CT. WOC. PT'd liner lap to 2000 psi - it leaks @ I bpm @ 1000 psi. RIH w/CT conveyed Perf guns & tagged PBTD @ 9698'. Shot 860' of Initial Perforations f/: 8775' - 9235' MD (Zone Kuparuk A3) 9275' - 9675' MD (Zone Kuparuk A2) Used 1-9/16 .... carriers & shot all Perfs @ 4 SPF, 60° phasing, random orientation, & underbalanced press. POOH w/guns. RBIH w/guns & circulated 12 ppg KWF. POOH. LD guns - ASF. RIH & set liner top packer @ 7118.5'. Good indication of set. POOH. FP'd well. RDMOL. 3S rig released 2330 hrs. Installed static GLV's. ORIG'II Ai Sidetrack Summary Page 1 3A-03A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 1/06/2001 - Tagged XO @ 7135'. Performed GLV work. 1/12/2001' 1/28/2001' MIRU CTU. PT'd equip. RIH w/CT & performed FCO to 9681' CTM. Loaded well w/Diesel. Attempted to POP well - no flow. LDFN. 1/29/2001' RIH & tagged PBTD @ 9687' CTM. Performed N2 lift to initiate flow - well has no fluid influx. POOH & RD CTU. 2/04/2001' Performed a CT Perforation Wash as follows: MIRU CTU. PT'd equip. RIH w/CT & tagged PBTD @ 9700'. 2/05/2001: Pumped 30 bbl Diesel pill, followed by 20 bbls of SW. Washed perfs w/33 bbls of Gel Breaker. Soaked for 4 hrs. Jetted out w/SW. POOH w/CT. FP'd well. RD CTU. 2/19/2001' 4/27/2001' 4/28/2001 - 4/29/2001' Performed Step Rate Test - estimated ISIP = 1900 psi - FG = 0.76. Measured BHP @ 8105' WLM - 3179 psi. Drifted tubing to 7116'. Made numerous attempts to pull liner top packer @ 7118' - no success. 5/03/2001: 5/15/2001 - 5/17/2001: Attempted to pull liner top packer w/3/16" braided line - no movement. Sheared GS profile in packer. Made numerous attempts to retrieve liner top packer. Moved fish to 7090'. Well will flow now (from C Sand Zone in window vicinity). Placed well 3A-03A on initial production & obtained a valid well test. Options for future wellwork are currently being evaluated to initiate flow from the C sand perf intervals. Sidetrack Summary Page 2 BP Amoco WELLPA TH DETAILS 3A-O3A 500292143201 Parent Wellpath: 3A-03 Tie on MD: 7794.00 BAKER : HUGHE~i IINTE, Q LEGEND 3A-03 (3A-03) 3A-O3A I W¢llp]th: I $A-0]/$^-0~^ ) Azimuths Io True North I /l',, ?[4agnelic Nort h: 26.17oI ............. jP ..... Magnetic Field I .... t .......... Strenglh: 57416nT Dip Angle: 80.70 Dale: 12/4/20001 ~:],;:; '~ i/:~'~:>~:~'~.. ...... Model: BGGM2000 1 Ve~ical Section Origin: Slot - (0,00,0.00) Verffcal Section Angle: 73.00° Depth Reference: 3A-03 72.00ft -400 ....................................................................................................................... '~ ................................... Yertical O'VD) Re[erenco: S~tem: Mean Sea I_evot ...................... ....... St.~on {VS) Roleronco: Slot - (0.00,0.00) Measured Depth Relemnco: 3^-03 72.0 Galculation Method: Minimum Gurvatum ~.02 ..... ~ ..... =,~ ...................... ~ -zoo .... t ....... !- i ..................... ..q. :... ~ . ......... ; ......... i:.!: ii. : ...... ./. .... ~ss~ .......... ~ ........... ........... :- ................... L/_... ...................... i ~ } ' ~/ - : ~ } ; -~000 -500 0 SOO ~000 ~0 q IK k rfp ~ ... ~ ~ ~ ....... ~ ~i. ~ ~i~ ~ West(-)lEas,( ) [200~in] 6 ~ ......... ~ ......... ~ ....... t .......... .....~ ............ : ........... ; ............ ~ ........... [ ......... ~ ............ ~ ........ ;' .......... ~' ........ [ ......... ~ ........ : .......... ............... ~ ....... . . . . J [ : ..... ~: ~: : ~ ~ : ..¢ i.. ~ ~ ~. .... ,: ~ ~ ~ ~~'"'~ -20~ -1800 -1600 -1400 -1200 -1000 -800 ,::~ 400 -200 Veaical Section at 73.00~ [200~in] Plot 1/17/2001 11:10 AM BP Amoco Baker Hughes INTEQ Survey Report i~:;;~!'[i~ .............................. Company: BP Amoco Date: 1/1712001 Time: 11:04:44 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3A-03, True North Site: KRU 3A Pad Vertical (TVD) Reference: 3A-03 72.0 Well: 3A-03 Section (VS) Reference: Well (0.00E,0.00N,73.00Azi) Wellpath: 3A-03A Survey Calculation Method: Minimum Curvature Db: Sybase Survey F MD Incl Azim TVD SSTVD N/S E/W MapN MapE DLS VS ft deg deg ft ft ft ft ft ff deg/100ft ft 8348.00 87.50 113.70 6108.87 6036.87 -5025.97 -225.15 5991882.47 507479.06 25.03 -1684,76 8378.00 89.10 107.00 6109.76 6037.76 -5036.39 -197.05 5991872.07 507507.17 22.95 -1660,93 8415.00 88.00 101.80 6110.70 6038.70 -5045.58 -161.23 5991862.92 507542.99 14.36 -1629,38 8445.00 88.00 96.50 6111.74 6039.74 -5050.35 -131.64 5991858.18 507572.58 17.66 -1602,47 8475.00 88.90 90.90 6112.56 6040.56 -5052.28 -101.73 5991856.28 507602.50 18.90 -1574.43 8510.00 89.50 83.80 6113.04 6041.04 -5050.67 -66.79 5991857.93 507637.43 20.36 -1540.55 8540.00 86.90 88.00 6113.99 6041.99 -5048.52 -36.89 5991860.11 507667.32 16.46 -1511.33 8574.00 84.10 91.90 6116.66 6044.66 -5048.49 -3.01 5991860.17 507701.20 14.09 -1478.91 8603.00 86.10 86.60 6119.13 6047.13 -5048.11 25.87 5991860.58 507730.08 19.47 -1451.19 8635.00 85.90 80.70 6121.37 6049.37 -5044.58 57.58 5991864.14 507761.78 18.40 -1419.83 8661.00 83.80 75.40 6123.70 6051.70 -5039.22 82.91 5991869.53 507787.10 21.85 -1394.04 8692.00 82.40 69.10 6127.43 6055.43 -5029.85 112.20 5991878.93 507816.38 20.67 -1363.29 8726.00 86.20 69.10 6130.81 6058.81 -5017.78 143.80 5991891.03 507847.97 11.18 -1329.54 8753.00 88.00 63.10 6132.18~ 6060.18 -5006.86 168.44 5991901.97 507872.59 23.17 -1302.78 8783.00 89.10 58.50 6132.94~ 6060.94 -4992.24 194.61 5991916.63 507898.75 15.76 -1273.48 8812.00 87.30 55.00 6133.85 6061.85 -4976.35 218.85 5991932.54 507922.96 13.57 -1245.66 8849.00 86.00 49.00 6136.01 6064.01 -4953.62 247.94 5991955.30 507952.03 16.57 -1211.19 8877.00 86.70 45.60 6137.79 6065.79 -4934.67 268.48 5991974.26 507972.54 12.37 -1186.01 8914.00 88.90 39.50 6139.21 6067.21 -4907.45 293.46 5992001.51 507997.50 17.51 -1154.16 8945.00 90.50 34.60 6139.38 6067.38 -4882.71 312.13 5992026.26 508016.14 16.63 -1129.07 8978.00 91.10 31.80 6138.92 6066.92 -4855.11 330.20 5992053.88 508034.18 8.68 -1103.72 9010.00 88.90 34.30 6138.92 6066.92 -4828.29 347.65 5992080.72 508051.60 10.41 -1079.20 9045.00 89.10 29.00 6139.53 6067.53 -4798.51 366.01 5992110.51 508069.92 15.15 -1052.94 9075.00 91.70 24.80 6139.32 6067.32 -4771.76 379.57 5992137.27 508083.46 16.46 -1032.14 9113.00 92.50 21.60 6137.93 6065.93 -4736.86 394.53 5992172.18 508098.38 8.67 -1007.63 9154.00 89.20 27.20 6137.32 6065.32 -4699.55 411.46 5992209.50 508115.27 15.85 -980.54 9182.00 85.20 26.70 6138.68 6066.68 -4674.63 424.13 5992234.44 508127.92 14.40 -961.13 9207.00 81.20 27.20 6141.64 6069.64 -4652.50 435.38 5992256.57 508139.14 16.12 -943.90 9242.00 75.60 27.20 6148.68 6076.68 -4622.02 451.04 5992287.07 508154.77 16.00 -920.01 9273.00 77.30 29.30 6155.94 6083.94 -4595.48 465.31 5992313.62 508169.01 8.57 -898.61 9305.00 80.60 31.40 6162.08 6090.08 -4568.38 481.18 5992340.73 508184.85 12.16 -875.51 9343.00 83.40 38.80 6167.37 6095.37 -4537.62 502.81 5992371.51 508206.44 20.64 -845.84 9380.00 88.40 39.90 6170.02 6098.02 -4509.10 526.20 5992400.06 508229.80 13.83 -815.13 9390.00 90.00 41.60 6170.16 6098.16 -4501.52 532.72 5992407.64 508236.32 23.34 -806.67 9422.00 90.80 44.10 6169.93 6097.93 -4478.06 554.49 5992431.12 508258.05 8.20 -779.00 9457.00 91.70 48.70 6169.17 6097.17 -4453.94 579.82 5992455.26 508283.36 13.39 -747.72 9490.00 94.10 53.60 6167.50 6095.50 -4433.27 605.47 5992475.96 508308.99 16.52 -717.15 9518.00 94.90 57.80 6165.30 6093.30 -4417.55 628.53 5992491.71 508332.03 15.22 -690.50 9556.00 95.10 64.80 6161.98 6089.98 -4399.38 661.71 5992509.91 508365.19 18.36 -653.46 9572.00 93.80 67.00 6160.74 6088.74 -4392.87 676.27 5992516.43 508379.74 15.94 -637.63 9593.00 91.30 69.10 6159.81 6087.81 -4385.02 695.73 5992524.29 508399.19 15.54 -616.73 9613.00 89.40 71.20 6159.69 6087.69 -4378.23 714.54 5992531.10 508417.99 14.16 -596.76 9632.00 88.70 74.00 6160.00 6088.00 -4372.55 732.66 5992536.80 508436.10 15.19 -577.76 9653.00 88.20 77.50 6160.57 6088.57 -4367.39 753.01 5992541.99 508456.44 16.83 -556.80 9673.00 87.50 80.70 616t.32 6089.32 -4363.61 772.63 5992545.79 508476.06 16.37 -536.93 9735.00 87.50 80.70 6164.02 6092.02 -4353.60 833.76 5992555.86 508537.17 0.00 -475.54 ' ( BP Amoco · bp Baker Hughes INTEQ Survey Report /~-,:'i~'E'~ ............................ Company: BP Amoco Date: 1/17/2001 Time: 11:04:44 Page: Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3A-03, True North Site: KRU 3A Pad Vertical (TVD) Reference: 3A-03 72.0 Well: 3A-03 Section (VS) Reference: Well (0.00E,0.00N,73.00Azi) ...... _W_e. !.!?.t_ .h.!.........3.A._-.°..~.A_ ............................................................................................................................................ _S_u...~y.C.~!~ u.!a.t! ~_n_ .M__e_.t.h.0..d.! ............. .M!.n_.i.?? m..C._u_~t_?!? ................... Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: KRU 3A Pad UNITED STATES: North Slope Site Position: Northing: 5996908.16 ft Latitude: 70 24 9.994 N From: Map Easting: 507699.01 ft Longitude: 149 56 14.399 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.06 deg Well: 3A-03 Slot Name: Well Position: +N/-S 0.00 ft Northing: 5996908.16 ft Latitude: 70 24 9.994 N +E/-W 0.00 ft Easting: 507699.01 ft Longitude: 149 56 14.399 W Position Uncertainty: 0.00 ft Wellpath: 3A-03A Drilled From: 3A-03 500292143201 Tie-on Depth: 7794.00 ft Current Datum: 3A-03 Height 72.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/4/2000 Declination: 26.17 deg Field Strength: 57416 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg Survey: MWD Start Date: 12/22/2000 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation M D 1'VD ft -'--~3T.O-~ ...... ~-d;~-~-----R[~'i~':;~"~;;i';:,T ..................................................................................................................................... 9735,00 6164_ 02 Projected to TD / Survey MD" '. Incl.. AZim' ' "TVD" ' ssTVD .... N/S .... . 'E/W "MapN" MapE .DLS.. VS. ft" "" ':deg:' '. deg :.'"ft'.'. .. ft ':' ft : :. 'ft' ff.. · :' ft..~' '""degll00ft ft 7794,00 40,33 188.75 5920.67 5848,67 -4669,63 -416,13 5992238,57 507287,73 0~00 -1763,21 7843,00 43,00 235,30 5958,16 5886,16 -4695,43 -432,67 5992212,75 507271,22 62,37 -1786,58 7872,00 47,70 224,50 5978,57 5906,57 -4708,74 -448,35 5992199,43 507255,55 31,02 -1805,46 7897,00 48,30 208,30 5995,36 5923,36 -4723,60 -459,30 5992184,56 507244,63 48.14 -1820,28 7945,00 55,40 187,20 6025,20 5953,20 -4759,27 -470,36 5992148,88 507233,60 37,47 -1841,28 7975,00 57,00 175,90 6041,92 5969,92 -4784,13 -471,01 5992124,03 507232,98 31,73 -t849,17 8004,00 58,90 165,00 6057,34 5985,34 -4808,31 -466,92 5992099,86 507237,09 32,51 -1852,33 8035,00 62,10 153,40 6072,65 6000,65 -4833,45 -457,32 5992074,73 507246,71 34,14 -1850,50 8053,00 65,30 147,80 6080,63 6008,63 -4847,49 -449,40 5992060,69 507254,65 33,07 -1847,03 8091,00 74,80 142,20 6093.59 6021,59 -4876,67 -428,90 5992031,54 507275,18 28,57 -1835,96 8120,00 79,70 139,70 6099,98 6027,98 -4898,63 -411,08 5992009,60 507293,02 18,87 -1825,34 8148,00 84,20 135.50 6103,91 6031,91 -4919,08 -392.39 5991989,17 507311,73 21,88 -1813,45 8172,00 89,10 133,00 6105,31 6033,31 -4935,80 -375,24 5991972,47 507328,90 22,91 -1801,93 8202,00 91,00 127,10 6105,28 6033,28 -4955,09 -352,28 5991953,21 507351,87 20,66 -1785,62 8228,00 92,30 120,00 6104,53 6032,53 -4969,44 -330,64 5991938,87 507373,53 27,75 -1769,11 8262,00 89,20 113,00 6104,09 6032,09 -4984,60 -300,23 5991923,75 507403,94 22,51 -1744,47 8300,00 86,10 123,90 6105,65 6033,65 -5002,66 -266,90 5991905,73 507437,29 29,80 -1717,88 8320,00 85,40 120,40 6107,13 6035,13 -5013,27 -250,02 5991895,14 507454,18 17,80 -1704,83 ALASKA OIL AND GAS CONSERVATION CO~iSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Lamar Gantt Coil Tubing Drilling Engineer Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River 3A-03A Phillips Alaska, Inc. Permit No: 200- ! 9 l Sur. Loc. 4750'FNL, 748'FEL, Sec. 7, TI2N, R9E, UM Btmhole Loc. 3750'FNL, 814'FEL, Sec. 18, T12N, R9E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced well. The permit t° redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, J. M. Heusser CommisSioner BY ORDER OF THE COMMISSION DATED this ~~..- day of November, 2000 dlf/Enclosures CC: Department offish & Game, Habitat Section w/o encl. Department of.Environmcnlal Conserv'ation w/o cncl. t" STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill r--~ Redrill[~] I lb. Type of well. Exploratory F-~ StratigraphicTestr'"] Development Oil [~] Re-entry E] Deepen DI Service O Development Gas E] single Zone r~ Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 72 feet 3. Address.,.-z. ~6' Property Designation Kuparuk Field Anchorage, AK 99501-0360 b~.~c~vj/~D L 25632/ALK 2565 Kuparuk Oil Pool P. O. Box 10360 4. Location of well at sudace 7. Unit"'o~'property Name 11. Type Bond (see 20 AAC 25.0251) 4750' FNL, 748' FEL, Sec. 7, T12N, R9E, UM Kuparuk Unit Statewide At top of productive interval 8. Well number Number /../_- ~- ~ ~-/~ FNL, 1165' FEL, Sec. 18, T12N, R9E, UM 3A-03A #2S1,~0~30-277 4520' At total depth 9. Approximate spud date Amount 3750' FNL, 814' FEL, Sec 18, T12N, R9E, UM December 14, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 25631,3750' @ TD feetI No Close Approach feet 2448 9178 M D / 6133 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 7760' MD Maximum hole angle 90° Maximum surface 2695 psig At total depth (TVD) 3307 psig @ 6115' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Weight Grade Couplin~ Length MD TVD MD TVD (include sta~e data/ 3" 2-3/8" 4.6 L-80 FL4S 1928' ~j.,~~/ 5513' 9178' 6133' 9 bbls LARC n ! ("1 IXl A 19. TO be completed for Redrill, Re-entry, and Deepen Operations. U ~'~ I U I I ~ ~ L, Present well condition summary Total Depth: measured 8390 feet Plugs (measured) Tagged PBTD @ 8213' MD on 5/12/1999. true vertical 6378 feet Effective Depth: measured 8213 feet Jun k (measured) true vertical 6240 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 106' 16" 187 Sx AS II 106' 106' Surface 3816' 9-5/8" 1200 Sx AS III & 320 Sx Class G 3888' 3098' Production 8298' 7" 425 Sx Class G & 250 Sx AS I 8370' 6363' RECEIVED Pedoration depth: measured 7790'-7874'; 7882'-7892'; 8010' - 8034'; 8050'-8089'. NOV true vertical 5918' - 5981'; 5987' - 5995'; 6085' - 6103'; 6115'- 6152'. Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee r~ Property Plat D BOP Sketch r'~ Dive,er Sketch D Drilling program r'~ Drilling fluid program Time vs depth plot r~ Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements r'~ ., 21. i hereby ce~y~that the foregoing i~true and correct to the best of my knowledge Questions? CallDan Venhaus@564-5273. Signed ~/'"~/~///~ ~ Z- "~ -'~' Title: CoilTubing Drilling Engineer Date Commissio~se Only Permit Number ,,~ ..,/.4~,/ I APl number I ISee c°ver letter 50- 0 ?-,~ '-- .~/' Y'~ ~ - ('~ l Approval date __ I/-',2~'~ Iforother requirements Conditions of approval Samples required E] Yes [~ No Mud Icg required r~ Yes r-~ No Hydrogen sulfidemeasures ~] Yes D No Directional surveyrequired r~] Yes D No Required working pressure for BOPE E]2M; D 3M; D SM; E] 10M;D [~]350opsiforCTU Other: $~GNED ~Y by order of ..... A.p. proved by O~;;~{~JL~'L,j. ~. ~(~t,isse~' commissioner the commission Date//- ,, , Form 10-401 Rev. 12/1/85 · Submit in triplicate KRU 3A-03A CT Sidetrack and Completion Intended Procedure Objective: P&A well with 17 ppg cement. Mill window from cement plug. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: · P&A existing perfs with 17 ppg cement. · Mill window from cement in 7" casing at 7760' md. · Directionally drill a 2-3/4" (3" bi-center) well using dynamically overbalanced drilling techniques. Planned TD is 9177' md. ·Run 2-3/8" blank liner to TD, cement in place. · Perforate, place on production. Drilling fluids will be injected into a dedicated Class II disposal well. Dynamically overbalanced drilling techniques will be employed to address high reservoir pressure. Plans are to use ,,,9 ppg drilling fluid in cOmbination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the upper BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as stripper. Lower BOP rams will be used only for primary well control. At least two times hole volume of kill weight fluid will be on location as a contingency. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage November 15, 2000 Kuparuk 3A-03A Potential Drilling Hazards POST ON RIG Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. At any stage in the operation, if things don't look right shut- down the operation and discuss the situation before making the next move. SAFETY FIRST. Current H2S is 275 ppm. The 3A pad is a designated H2S area. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. Ensure H2S monitoring equipment is functional. All personnel must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in H2S in pit area, although KRU CTD sidetracks in the past have not seen this. A sand BHP: 3030 psi @ 6035' TVD, 5963'ss (9.7 ppg EMW) May '98 C sand BHP: 3069 psi @ 6023' TVD, 5951' ss (9.8 ppg EMW) May '98 Combined NC SBHP = 2618 psi @ 5565' TVD, 5493' ss (9.0 ppg EMW) April '99 Reservoir frac gradient is ~0.8 psi/ft or 15.4 EMW, 4860 psi. Offset producer 3F-19 A-sand SBHP = 2450 psi @ 6046' TVD (7.8 ppg EMW) Dec '99 Offset injectors (both shut-in since Sept '00): 3F-07 A-sand BHP = 4200 psi @ 6106' TVD (13.2 ppg EMW) Nov '00 3A-04 A/C sands SBHP = 3200 psi @ 5941' TVD (10.4 ppg EMW) Nov '00 Note: 3F-07 is >3000' from the'target area, 3A-04 is ~ 2000' from target. Both are separated from the target area by faults, Plans are to start drilling with less than kill-weight fluid (9.0 ppg FIo-Pro). While circulating at least 1.5 bpm, BHP will overbalance reservoir pressure due to high ECD (expected BHCP @ window - 3390 psi). However, when circulation is shut down, the reservoir will be underbalanced by -430 psi. Maintain at least 625 psi WHP when not circulating to prevent reservoir in-flux and maintain formation stability close to circulating pressures seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole APS sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return-line flow rate and pit volume continuously. If crude enters the circulating system, divert those returns to an outside tank. Maximum anticipated WHP w/full column of gas: -2695 psi assuming 0.1 psi/ft gas gradient. No gas saturated intervals are expected. November 15, 2000 KRU 3A-03A(.. P, OPOSED CT HORIZONTA¢.. ,51DETRACK D Nipple @ 513' 9-5/8" Shoe @ 3888' 3-1/2",9.3#, J-55 Production Tubing to Surface Top of 2-3/8" Liner @ 7130' (proposed) Tubing Tail @ 7715' 3-1/2" x 7" Baker SAB-3 Packer @ 7680' Cement Top 7715' Mill Window in 7" Casing @ 7760' ELM RECEIVED NOV 2 0 ?0~0 AJaska 011 & Gas Cons. Commission Anchorage 3" Open hole 2-3/8" FL4S 4.6# Liner Cemented & Perforated TD @ 9178' 7" Liner & Peris P&A'd with 17.0 ppg Cement 7" Shoe @ 8370' PCR 11/17/2o00 BPAmoco BP Amoco Baker Hughes INTEQ Planning Report Company: BP AmOco Field: Kuparuk River Unit Site: KRU 3A Pad Well: 3A-03 Wellpath: Plan03 3A-03A Date: 11/17/2000 Time: 16:24:03 Page: 1 Co-ordinate(NE) Reference: Well: 3A-03, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00E,0.00N,0.00Azi) Survey Calculation Method: Minimum Curvature Db: Sybase Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: KRU 3A Pad UNITED STATES ' North Slope Site Position: Northing: 5996908.16 ft Latitude: 70 24 9.994 N From: Map Fasting: 507699.01 ff Longitude: 149 56 14.399 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ff Grid Convergence: 0.06 deg Well: 3A-03 Slot Name: WelI Position: +N/-S 0.00 ft Northing: 5996908.16 ft Latitude: 70 24 9.994 N +E/-W 0.00 ft Easting: 507699.01 ft Longitude: 149 56 14.399 W Position Uncertainty: 0.00 ft Wellpath: Plan#3 3A-03A Drilled From: 3A-03 500292143201 Tie-on Depth: 7760.00 ft Current Datum: 3A-03 Height 72.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2000 Declination: 26.19 deg Field Strength: 57416 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 0.00 Plan: Plan #3 Date Composed: 11/17/2000 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets · '. ':. :.:Name: · .. : : i ' DesCripti0n".!: ::i :...; :TVD: : ::. :: .+N)-S .... :'~: +El,W:: :' :: .::.N'0rthing.: :: .' East:ing · ..' Deg' Mi:n .;Sec :: :Deg':.'.Min· :.SEC..: .: .:: Annotation '::';7'!~;¥ZTZ~-~-~7:iTiTV!-7:":':.'"?V":'7~'i"~'~:~'77~:777~~ ii: ~i~!'777~7~:i'"'~"5-:'.-'~V:~'77'i:"V':":':"7'i':::!":'"'"V';'.'"'"7 :"!'"i'""i .......... T'7;'"';:":-i'Ti ~5-!-'-?T'i _'_:....£.:~:-.~.;2._..~.:_._..2....L:._L'i~_.:._..:_.:.._.:._:.._:_. .............. ....-: .............. ;-...-:-..:._.,-:......_.:...L._~: .......... ~.'.~.__:.z ............... a.:. ............ '~...:..: ....... ~..: ...................... :....'...~._..!.~[L..:_:.d_SAL :.~:Z_;.d_L.:,:LL,::x_Li.~'.i_.;.L ........ L.:_.__.:.,d_,.:.__[.~._'.[_:.__.:.x:.Z.L_:L.:.:j ............ ~-Ld..;_.:.:2..~. 7700.00 5777.30 Tie-in Point 7760.00 5822.79 Kick-off Point 7830.00 5882.28 1 7904.22 5943.47 2 8131.39 6035.00 3 8484.72 6035.00 4 8672.63 6039.80 5 8833.97 6048.00 6 9177.92 6061.02 TD Plan Section Information ':~. ii~':.~DI..~ :i'!~:'i:.!'.~; iii:~i~::.::;.? :~; ::.~ ~/:~l~:;~::;~: ::: :.i ~'iT~; !.: :i "'~; ~N)i;$:.i::..~.. ;~ .;:"ffE!-Wi::;.:: .:: ii"~])~s~. ~:i::::~'. :i:Buiid.'~, '?' ?~T:'~rfi: i. i ::~F::O' ! !i Target :~J::.:. ::". ~::;;. ':' :i .:::: ..' ':':~'. :~;. ;: :::: ':'. !:lift :'~;"i :::' ;:.~;~;i:~i :~:.d~g:~.':~'; ': ~: 'ii :! elb~'~':'~: i:.'~..:: ' ':; ::: :~..i:f!i ~:.:.~..:"~:. ?:. 'i':.. :i: '..~. ft~i :"!::!";:':! ::: ;.: ~; i,ft ?::i~: i"::": ...d'i~g!!ooft": d~HOOff.:id~!!O~!..~:.: :'.'d~g: i: i.'...:.. ;:.'i:...;:'!. i:::"i~i..!:' i.. 'i.~ ~: ';i!" ...... :':../~:~:':[,.. ::' 7700.00 40.87 187.72 5777.30 -4609.09 -407.37 0.00 0.00 0.00 0.00 7760.00 40.53 188.38 5822.79 -4647.83 -412.85 0.91 -0.57 1.10 128.56 7830.00 22.98 211.21 5882.28 -4682.41 -423.36 30.00 -25.07 32.61 155.00 7904.22 45.00 205.00 5943.47 -4719.04 -442.19 30.00 29.67 -8.36 348.36 8131.39 90.00 146.00 6035.00 -4909.32 -408.49 30.22 19.81 -25.97 293.02 8484.72 90.00 40.00 6035.00 -4925.29 -103.85 30.00 0.00 -30.00 270.00 8672.63 87.10 21.00 6039.80 -4764.20 -8.94 10.22 -1.54 -10.11 261.16 8833.97 87.11 4.50 6048.00 -4607.58 26.50 10.21 0.01 -10.23 -90.38 BPAmoco BP Amoco Baker Hughes INTEQ Planning Report ILNTEQ Company: BP Amoco Field: Kuparuk River Unit Site: KRU 3A Pad Well: 3A-03 Wellpath: Plan03 3A-03A Date: 11/17/2000 Time: 16:24:03 Page: 2 Co-ordinate(NE) Reference: Well: 3A-03, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00E,0.00N,0.00Azi) Survey Calculation Method: Minimum Curvature Db: Sybase Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target fi: deg deg ft fi: ft deg/10Oft deg/100ft deg/100fi: deg i 9177.93 88.69 329.38 6061.00 -4278.00 -50.00 10.21 0.46 -10.21 -88.17 Survey MD Incl Azim SSTVD N/S EfW MapN MapE DLS VS TFO Tool fi: deg deg fi: fi: ft fi: fi: deg/100fi: ft deg 7700.00 40.87 187.72 5777.30 -4609.09 -407.37 5992299.11 507296.43 0.00 -4609.09 0.00 MWD 7725.00 40.73 187.99 5796.23 -4625.27 -409.60 5992282.93 507294.21 0.91 -4625.27 128.56 MWD 7750.00 40.59 188.27 5815.19 -4641.40 -411.91 5992266.81 507291.93 0.91 -4641.40 128.35 MWD 7760.00 40.53 188.38 5822.79 -4647.83 -412.85 5992260.37 507290.99 0.91 -4647.83 128.14 MWD 7775.00 36.49 191.58 5834.53 -4657.03 -414.46 5992251.17 507289.39 30.00 -4657.03 155.00 MWD 7800.00 30.01 198.50 5855.43 -4670.26 -417.94 5992237.94 507285.93 30.00 -4670.26 152.50 MWD 7825.00 24.07 208.62 5877.70 -4680.68 -422.37 5992227.52 507281.51 30.00 -4680.68 146.69 MWD 7830.00 22.98 211.21 5882.28 -4682.41 -423.36 5992225.78 507280.52 30.00 -4682.41 137.64 MWD 7850.00 28.88 208.71 5900.26 -4689.99 -427.71 5992218.20 507276.18 30.00 -4689.99 348.36 MWD 7875.00 36.30 206.65 5921.31 -4701.92 -433.93 5992206.27 507269.96 30.00 -4701.92 350.61 MWD 7900.00 43.74 205.21 5940.44 -4716,37 -440.94 5992191.81 507262.97 30.00 -4716.37 352.35 MWD 7904.22 45.00 205.00 5943.47 -4719.04 -442.19 5992189.14 507261.73 30.01 -4719.04 353.35 MWD 7925.00 47.73 197.18 5957.82 -4733.06 -447.57 5992175.12 507256.36 30.22 .4733.06 293.02 MWD 7950.00 51.65 188.70 5974.01 -4751,61 -451.79 5992156.56 507252.16 30.22 -4751.61 298.42 MWD 7975.00 56.11 181.15 5988.75 -4771.71 -453.49 5992136.47 507250.49 30.22 -4771.71 303.92 MWD 8000.00 60.99 174.38 6001,80 -4792.99 -452.62 5992115.18 507251.37 30.22 -4792.99 308.38 MWD 8025.00 66.18 168.24 6012.93 -4815.10 -449.22 5992093.08 507254.80 30.22 -4815.10 311.91 MWD 8050.00 71.58 162.58 6021.94 -4837.64 -443.33 5992070.55 507260.71 30.22 -4837.64 314.65 MWD 8075.00 77.15 157.28 6028.68 -4860.23 -435.06 5992047.97 507269.00 30.22 -4860.23 316.69 MWD 8100.00 82.82 152.20 6033.03 -4882.47 -424.55 5992025.74 507279.53 30.22 -4882.47 318.12 MWD 8125.00 88.54 147.25 6034.91 -4903.99 -411.99 5992004.24 507292.11 30.22 -4903.99 319.01 MWD 8131.39 90.00 146.00 6035.00 -4909.32 -408.49 5991998.91 507295.62 30.09 -4909.32 319.36 MWD 8150.00 90.00 140.42 6035.00 -4924.22 -397.35 5991984.03 507306.77 30.00 -4924.22 270.00 MWD 8175.00 90.00 132.92 6035.00 -4942.39 -380.21 5991965.88 507323.94 30.00 -4942.39 270.00 MWD 8200.00 90.00 125.42 6035.00 -4958.17 -360.84 5991950.12 507343.32 30.00 -4958.17 270.00 MWD 8225.00 90.00 117.92 6035.00 -4971.28 -339.57 5991937.03 507364.59 30.00 -4971.28 270.00 MWD 8250.00 90.00 110.42 6035.00 -4981.51 -316.78 5991926.82 507387.39 30.00 -4981.51 270.00 MWD 8275.00 90.00 102.92 6035.00 -4988.68 -292.85 5991919.68 507411.33 30.00 -4988.68 270.00 MWD 8300.00 90.00 95.42 6035.00 -4992.66 -268.19 5991915.73 507436.00 30.00 -4992.66 270.00 MWD 8325.00 90.00 87.92 6035.00 -4993.38 -243.21 5991915.03 507460.97 30.00 -4993.38 270.00 MWD 8350.00 90.00 80.42 6035.00 -4990.84 -218.36 5991917.59 507485.81 30.00 -4990.84 270.00 MWD 8375.00 90.00 72.92 6035.00 -4985.08 -194.05 5991923.38 507510.11 30.00 -4985.08 270.00 MWD 8400.00 90.00 65.42 6035.00 -4976.20 -170.70 5991932.29 507533.45 30.00 -4976.20 270.00 MWD 8425.00 90.00 57.92 6035.00 -4964.34 -148.71 5991944.17 507555.43 30.00 -4964.34 270.00 MWD 8450.00 90.00 50.42 6035.00 -4949.72 -128.46 5991958.81 507575.66 30.00 -4949.72 270.00 MWD 8475.00 90.00 42.92 6035.00 -4932.57 -110.29 5991975.97 507593.81 30.00 -4932.57 270.00 MWD 8484.72 90.00 40.00 6035.00 -4925.29 -103.85 5991983.26 507600.24 30.01 -4925.29 270.00 MWD 8500.00 89.76 38.46 6035.03 -4913.45 -94.19 5991995.10 507609.89 10.22 -4913.45 261.16 MWD 8525.00 89.37 35.93 6035.22 -4893.54 -79.08 5992015.03 507624.98 10.22 -4893.54 261.16 MWD 8550.00 88.98 33.41 6035.58 -4872.98 -64.86 5992035.60 507639.18 10.22 -4872.98 261.18 MWD 8575.00 88.59 30.88 6036.11 -4851.82 -51.56 5992056.77 507652.45 10.22 -4851.82 261.22 MWD 8600.00 88.20 28.35 6036.82 -4830.10 -39.21 5992078.51 507664.78 10.22 -4830.10 261.27 MWD 8625.00 87.82 25.83 6037.68 -4807.86 -27.83 5992100.76 507676.13 10.22 -4807.86 261.34 MWD 8650.00 87.44 23.30 6038.72 -4785.14 -17.45 5992123.48 507686.49 10.22 -4785.14 261.43 MWD 8672.63 87.10 21.00 6039.80 -4764.20 -8.94 5992144.43 507694.98 10.25 -4764.20 261.50 MWD 8675.00 87.10 20.76 6039.92 -4761.99 -8.10 5992146.64 507695.82 10.21 -4761.99 269.62 MWD 8700.00 87.08 18.20 6041.19 -4738.45 0.23 5992170.18 507704.12 10.21 -4738.45 269.63 MWD 8725.00 87.08 15.65 6042.46 -4714.57 7.50 5992194.07 507711.36 10.21 -4714.57 269.76 MWD BPArnoco BP Amoco Baker Hughes INTEQ Planning Report Company: BP Amoco Field: Kuparuk River Unit Site: KRU 3A Pad Well: 3A-03 Wellpath: Plan#3 3A-03A Date: 11/17/2000 Time: 16:24:03 Page: 3 Co-ordinate(NE) Reference: Well: 3A-03, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00E,0.00N,0.00Azi) Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg fi: ft ft fi: fi: deg/100ft fi: deg 8750.00 87.08 13.09 6043.74 -4690.38 13.69 5992218.26 507717.53 10.21 -4690.38 269.89 MWD 8775.00 87.08 10.53 6045.01 -4665.95 18.80 5992242.70 507722.62 10.21 -4665.95 270.02 MWD 8800.00 87.09 7.98 6046.28 -4641.31 22.82 5992267.34 507726.61 10.21 -4641.31 270.15 MWD 8825.00 87.10 5.42 6047.55 -4616.51 25.73 5992292.14 507729.49 10.23 -4616.51 270.26 MWD 8833.97 87.11 4.50 6048.00 -4607.58 26.50 5992301.07 507730.25 10.23 -4607.58 270.39 MWD 8850.00 87.16 2.86 6048.80 -4591.60 27.53 5992317.05 507731.27 10.21 -4591.60 271.83 MWD 8875.00 87.25 0.31 6050.02 -4566.64 28.22 5992342.00 507731.93 10.21 -4566.64 271.91 MWD 8900.00 87.34 357.75 6051.20 -4541.68 27.80 5992366.97 507731.48 10.21 -4541.68 272.04 MWD 8925.00 87.44 355.20 6052.33 -4516.75 26.26 5992391.89 507729.92 10.21 -4516.75 272.16 MWD 8950.00 87.55 352.65 6053.43 -4491.92 23.62 5992416.72 507727.25 10.21 -4491.92 272.27 MWD 8975.00 87.66 350.10 6054.47 -4467.23 19.87 5992441.40 507723.48 10.21 -4467.23 272.38 MWD 9000.00 87.77 347.54 6055.47 -4442.72 15.03 5992465.90 507718.62 10.21 -4442.72 272.49 MWD 9025.00 87.89 344.99 6056.42 -4418.46 9.10 5992490.16 507712.66 10.21 -4418.46 272.59 MWD 9050.00 88.01 342.44 6057.32 -4394.48 2.10 5992514.13 507705.63 10.21 -4394.48 272.69 MWD 9075.00 88.13 339.89 6058.16 -4370.83 -5.97 5992537.76 507697.54 10.21 -4370.83 272.78 MWD 9100.00 88.26 337.34 6058.94 -4347.57 -15.08 5992561.02 507688.41 10.21 -4347.57 272.87 MWD 9125.00 88.40 334.79 6059.67 -4324.73 -25.22 5992583.84 507678.25 10.21 -4324.73 272.95 MWD 9150.00 88.53 332.24 6060.34 -4302.36 -36.36 5992606.19 507667.08 10.21 -4302.36 273.02 MWD 9175.00 88.67 329.68 6060.95 -4280.51 -48.49 5992628.03 507654.93 10.25 -4280.51 273.11 MWD 9177.93 88.69 329.38 6061.00 -4278.00 -50.00 5992630.54 507653.42 10.25 -4278.00 273.18 MWD BP Amoco WELLPATH DETAILS Plan~3 3A-03A 500292143201 Parent Wellpath: 3A-03 Tie on MD: 7760.00 Vertical Section Origin: Slot- (0.00,0.00) Vertical Section Angle: 0.00° Rig: Depth Reference: 3A-O3 72.0Oft REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: 3A-O3, Tree North Vedical (TVD) Reference: System: Mean Sea Level Section tVS) Reference: Slot- (0.00,0,00) Measured Depth Reference: 3A-03 72.0 Calculation Method: Minimum Curvature ANNOTATIONS N~. TVD MD AnnotaUon BPAmoco LEGEND 3A-03 (3A-03) Plan~3 3A~03A T WellpaUl: 3A-03A) Azimuths to True North I Magnetic North: 26.19° ~ Created BT. B~ Poe~s Date: 11117/2000 Strength: 57416nT ! Dip Angle: 80.70° I Model: BGGM2000 I -4300~iii' -4350-~? 6034.99 8131.3~ 3 ~ ! . ! ': ': : · ,~ t : : :. ~ i : ' :. ' ~ · 6o34.99 84s4.72 4 -r ;' ' :':: ~,:~ ~:~ ~ ~' ...... ;....i'.L::.:..i..:..~:i ......... I . L..:.L..:.L..L.:....'..L~..:.:~:.LL..:,.i ...... L..'...4 ...... ' .............. ~ ....... GOGI.00 9177.92 TD '~ · ' ..... o · i...:' ::..i:: .:..:.L'.::.~: Z ...... ;:":'".:"::'::::'' ·-7 ..... .' : ......... -.~,~// · -... · . :--~':-.~:?:-:":-i~. - : ........ :.'-! ........... :'-'-'?:':-!'-;-'~-'!'--":'-. - : · i~ :' · 'I/ ~"-i" ' ' ' '"'"'' ' = -4750-4 ' - ii i;, ....... ...... ........ ........ ........... ..... · '' :". !;:: ...... ........ ~~,:...,:::: ~ooa-'. ' ':'""?':""":-~"' t/ Z I ' -- ; ~ .... : ..... ~ .................... : I , ~ ' ,,,',, ' , ,,:,,..',. ,:, ,,.~, 5~ .................. ....:............ ............... .. :V · !~.:~:: ...... .: ~ ~ i :: : ! - ~ : : ~°"--'-i' :::::::::::::::::::::::::::::::::::::::::::::::::: ' ' '[k :' · i · '. · /~:-::! .... :i'-:-:---'~ ............. :'! ........... i ............ :"r?":':':"T-:: 56oo-J''~' :. ......................... : .... : -4 ' :::i: :: ' :- ' ~ \ . - : · /: : ~-' ~:: :i · · : : ;' ': . .... ~ : : : ' · -49 ~[r--q. - :.~:., F.~;~:-,..''-,. ...;:-~--:::-- , ..... :.:.:., ,.:... ,-~50 '' : ....... : ........ ~ ......... ~ ........ :' : ' ":" . ..... .... . .... ::: ..... '""' ; ' - · 'I " : '" =~o~ ..~ ..., .................. : ....... : ! ..... / · ~. .-.:.-.;....:.-:....:.....::. . 0 :::) : : . : · / -5 )ou- i ".'"'""~':'"'":'" '~''''''':: · l' - . · ·: · . ...... ~-- ~ ....... t ....... ? ........... ~ ........... ~ .......... ~ ...... :-~-.--:----.: ....... .r ....... ~50~..~ ...... ; ........ ' ........ :...: .... :. :. .... / · . ::i :" '. '!:~_ .="'""~. · · · - · %/' ' --~ .~ '"',',',':',":',',:,',",', ........ ~m..~..~.~.~.~?~.~...;.~.~.~.~.~..:..~.:....~..~..~.~.`.~....~..:.?~.~..~.~.~.~`T~::.:r~?.r~`~ .... i .... i .... , .... , .... ,' '"{ .... ~ .... ~"' ~iI "~ : : · : : / ; , i ; , , : : i : : : ~ , , , , , , ~ ~ ' II : I I : ........ 1 ........... : ~ I ' /' '" '800 '75O '70O --850 '600 '550 '500 --450 -4OO '35O '300 '250 '2O0 '150 '100 --50 0 50 100 150 200 250 300 350 400 ~' .-~ :, i ; i · :, . · '~' ' ' West(-)/East(+) [5Oft/in] = :~ ....... ~ .... i... :..: ...... : .......... !..Z/-4-, :. .. ' : ' ~ ~ : : ; \,/:J/:~ . : _ED : · ::: ~ 6~oo~ ..... · .... ; "'; ....... ~ "" ........ ' .... ' · d ~ : / , ; ; · : · · ' ': - ' ' - ' : ; : ' ' : ' " ........................ = ~ ; / : ; i ; : : : t~ 62oo-'-_I ..... ; ..... :./Z..'~ .: : ~ ' · .. : · . -: : ' : .--; -i--i- ............ ' .... i:-.---:i---:::::-:i :"::--'~-i:-" 'i ........ i-i.. ........ i-.: ........ ~ ............. i ............ ~':: ......... i-. ~1 ............ ~I ..... I .... I ................................. 6250" i'm'rFT~~~-~:]'~'t.~'~'f'~'mTmTf-n't'~'F'','':r'f'r'r...-'q'm-q-:'~''-:' -5100 -5050 -50004950 49004850 -4800 -4750-4700 -4650 -4600-4550 -4500-4450 -4400 -4350-4300 -4250 -4200-4150 -4100-4050 -4C~)0 -3'J50-3UO0 -3850 -3800-3750 -3700-3650 -3600 -3550-3500 -3450 -3400-3350 -3300 -3250-3200 -3150 Vertical Section at 0.00° [50ft/in] Plot 11/17/2000 4:25 PM ARCO Alaska, inc. (513-514, OD:3.500) Gas Lift ~ MandreJNalve 1 (3296-3297, 0D:5.390) Gas Lilt UandrelNalve 2 (4822-4823, 00:5.390) Gas Lift MandrelNalve 3 (5349-5350, OD:5.390) PBR (7664-7665, OD:3.500) SEAL ASSY (7679-7680, 0D:3.500) PKR (7680-7681, 0D:6.500) Nil: (7703-77O4, 0D:3.500) SOS (7715-7'716, 00:3.500) Perf (7790-7874) Perf (7882-7892) Perf (8010-8034) Per[ (8050-8098) 3A-03 GKA 3A-03 APl: 1500292143200 INone 18213 15/5/~9 SSSV Type: Annular Fluid: Reference LOg: Last Ta(/: Last Ta(/Date: Well Type: IPROD Od(/Completion: 19/16/85 Last W/O: I Ref Log Date: I TD: 18390 ftKB Max Hole Arkie: ~49 de(/~ 4000 Angle ~ TS: 140 dog ~ 7792 Angle ~ TD: 139 de(/~ 8390 Rev Reason: IWORKOVER BY Last Update: 7/5/99 Casing String, CONDUCTOR 16.000 0 106 106 I62.50 I H-40 I Casing String- SURFACE'. 9.625 0 3888 3098 I36.00 I J-55 I casing string.'PRO.DUCTION s,., 7.000 0 8370 6363 I 26.00 I J-55 I Tubing:!string~ri'TUBING.:, ".,.' ~ .... :.~'.!, ': . ':,.:" ,: ' Size I Top I eottom I TVo I Wt IOrade I 3.50o 0 7715 5861 I 9.3o I J-55 I IntervalI TVD Ii ZOc~e it; 77o0-7874 59~8-5981 I UNiT / -3, ,C-1 7882-7892 5987-5995 / UNiT e / I ^-,/ 8050 - 8098 6115 - 6152 ^-2 Thread Welded Thread BTC Thread BTC ... Thread EUE-ABM ,tuslFeetlSPIFt Date! Type I Comment ~01 12~1120/05~IPERF 15"C~, 120 de(/ phase 241 4]I1/20/85~IPERF t4"CG, O0dogphase 481 4]11120/85~IPERF 14"CG, 9Odogphase Gas LiffMandmls/Valyes:~ . ' ;'i: '. stnlMD ITVDI Man I Man I VMfr I VType IVODILatchlPortlTeoI Date / v,v I I IMfr I TYPe ] I I ! I I ] Run ~omment 1I 32981 27061CAMC01 KBMM I ! GLV I 1.o /BK lO.leaI 12921 5113/99 / 2I 48221 37431CAMC0! KBMM I I ~LVI 1.0 /BK 10.2501 14031 5/13/99 / 3153491 41141CAMCOI KBMM ! I OV I ~.0 /BE I0.3131 01 5/13/99 / 4I 63451 4~21CAMCOI KBMM I I DM¥ I 1.0 / BK 10'00OI01 5~3/99 / 5 I 7°8~1 53881 CAMCO I KBMM I ! DMY I 1.0 / BK 10.000101 5/13/99 / 6I 76071 57791CAMCOIUM~ I I DMY I 1.5 IRK 10.0001 01 5/13/99 / :Oth:er(pitigs~:elqdiP;.,:etc:):~JEWEERY ': ~'* /: ':: · . ' . . . Depthl'rVDI Type I Description I ID 5131 5131 NIPPLE ICAMCO D Nipple. Pulled CAT SV on 7123/98. I 2.812 76641 5822] PBR leaker 80-40 13.000 7679] 58331SEAL ASSY 1Baker KBH-22 77031 5S521 NIP 1Camco D Nipple ] 2.750 77151 58611 SOS IBaker, pinned for 3500 psi I 1.750 KRU CTD BOP Detail ~ CT Injector Head ,1~ I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I _ 7" Riser Methanol Injection tis 7" WLA Quick ' ' onnect ----- 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Hydril Model B Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure I 2 3/8" Slips 2 3/8" PipesI Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic XO Spool 3 1/8" x 7 1/6" or as necessary 2" Side outlets I Blind/Shear I 2" combi Pipe/Slip 2 flanged gate valves Single or Double Manual Master Valves MOJ 9/16/00 THA I Tubing Spool 7" Annulus 9 5/8" Annulus i" STATE OF ALASKAI"' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 10360 Anchorage, AK 99501-0360 4. Location of well at surface 4750' FNL, 748' FEL, Sec. 7, T12N, RgE, UM At top of productive interval 4520' FNL, 1165' FEL, Sec. 18, T12N, R9E, UM At effective depth At total depth 4518' FNL, 1238' FEL, Sec. 18, T12N, R9E, UM 5. Type of Well: Development __X Exploratory J Stratigraphic _ Service__ (asp's 507699, 5996908) (asp's 507305, 5992244) (asp's 507233, 5991861) 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3A-03 9. Permit number / approval number 185-206 10. APl number 50-029-21432 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 106' Surface 3816' Production 8298' Size 16" 9-5/8" 7" 8390 feet Plugs (measured) 6378 feet 8213 feet Junk (measured) 6240 feet Cemented 187 sx AS II 1200 SxAS III & 320 Sx Class G 425 Sx Class G & 250 Sx AS I :~ ii'~,:! , :,:-.,~i!~:~;~'7 ' Tagged PBTD @ 8213' MD on 5/12/1999. Measured Depth True verticalDepth 106' 106' 3888' 3098' 8370' 6363' Perforation depth: measured 7790' - 7874'; 7882? - 7892'; 8010' - 8034'; 8050' - 8089'. true vertical 5918' - 5981'; 5987' - 5995'; 6085' - 6103'; 6115' - 6152'. ,, Tubing (size, grade, and measured depth 3-1/2". 9.3#, J-55 Tbg @ 7715' MD. Packers & SSSV (type & measured depth) 3-1/2" x 7" BAKER SAB-3 Packer @ 7680' MD. 3-1/2" CAMCO D NIPPLE @ 513' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch ___X 15. Status of well classification as: 14. Estimated date for commencing operation December 4, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas m Suspended Service 17. I hereby certily that the loregoing is true and correct to the best o! my knowledge. SignedL~~ Title: Coil Tubing Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Questions? Call Dan Venhaus @ 564-5273. Plug Integrity __ BOP Test _ Mechanical Integrity Test m Location clearance m Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE H 177352 I'" ...... , V~NDO. ALASKASTAT 10 DATE II~IVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET , , , -102500 CK%O2500B 100. O0 100. O0 HANDL::NO INST: S/H - TERRIE HUBIILE X4628 r,E ^~^c,~o C,'CK ~S ,, P^Y~,T FOR ~,S ~SC,m~O ^,OW. ~ 100. O0 100. O0 BP.EXPLORATION (ALASKA)~:.INC .... "...'::~:. ...:.-: .~:.-'-.:. .... P. o:'iiiBOX' 196612 ~.. i.. '::!:iL;i: PAY -T° .-The'... STATE OF ALASKA::' ' ........ :":.:-: i::::::~': ::':!':-"" -:'!-"~ -" ORDER. :':.:'-' :-.AOOCC:'.' -' ....... : ...... '" '-' · ' ....... ':.'.;i:'O~, .!-.;i'::. ~ ':,300t-;::;;'PORCUP zNE!:::'::Dn;:::]:~' ANCHORAOE AK c~501 oNE :'"';HuNfiRE~/&'-.-:.O0/100'~"~'*:~'~;~* .*:~'~*~:"'*'m~'~**'~'**~-*'--:~*;'~'~:~I* -;U'~i::; DOLLAR:' · -'~ ::-.'::-'. :-:;":~[' :.]::'"-":-.'- ?.::'::' NO~LID A~ER 120 DAYS. :' :.::-5:'-.-- :':]'~':.": ..~};.":.}] ..~ · ~. ........... ..:. ... ............. .... ~ ......... ..: ..... -. _; ..- .........: ............ WELL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION APPR DATE ENGINEERING WELL NAMF-~//~- O ~4 PROGRAM: exp 1. Permit fee attached ........................ 2. Lease number appropriate~?~.--..~..~"~.'.~. ,. ~. ;~Y.i. · · 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is we,bore plat included ............... 9. Operator only affected party .......... . .... ; .;... 10. Operator has appropriate bond in force.'~.' .N~ ¢-?..~.. t'~..~ ' -~N 11. Permit can be issued without conservation order ........ 12. Permit canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... dev ¢' redrll ~' serv wellbore seg ann. disposal para req . GEOL AREA ~?:>~:::~'(_~ UNIT# L.~/[ ,/'~,~ ON/OFF SHORE N N N 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~"~ _C) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... N o 29. Is presence of H2S gas probable ................. . ,erm,,ca. e,,sue, ~ 31. Data presented on potential overpressure zone~A~_"_~.... ~-,.,., ,;, 2~A'c~,.~t)' , / / /'/ ~ /2 . // / /~ /.,///7 ~:~/ . 32. Seismic analysis of shallow gas zones ............. IIAPPR DATE 33. Seabed condition survey (if off-shore) ......... : · · .~JtJ'~ Y N ~..-~ z,y~(. ~~~. "/'~~,'/~~ ,r.~/~c.,.~..~.c~ '~,.-..C) ILT~~/~ ,. 2.D,~ 34. Contact. name/phone for weekly progress reports [explo,~l{~. only] Y N V~ ,~.~"/~/. ~f-~r-~/L,..~t,:j Z.~'(~).?,~,-,~ ,~A.~z..~..~". . ANNULAR DISPOSAL35. With proper cementing records, this plan . APPR DATE (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQG.Y: ENGINEERING: I~nnular COMMISSION: 87s coz JMH ~ Comments/Instructions: O Z O Z c:\msoffice\wordian\diana\checklist (rev. 11/01 fl00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well permitting Process but is part of the history file. To improve the readability of the Well HistOry file and to simplify finding information, information, of this . nature is accumulated at the end of the file under APPENDIXi. ., No 'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 03/02/04 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** PrWD 03/02/03 106551 01 1 3/4" Tiny *** LIS COM~ENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block #MNEM.UNIT Data Type STRT.FT 7705.0000: STOP.FT 9735.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: ~Parameter Information Block #MNEM.UNIT Value CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska Inc. 3A-03A Kuparuk River Unit 4750' FNL 748' FEL North Slope Alaska Baker Hughes INTEQ 1 3/4" Tiny 20-Dec-00 500292143201 Description ---- SECT. 07 TOWN.N 12N RANG. 9E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 72 DMF . KB EKB .F 72 EDF .F N/A EGL .F N/A CASE.F N/A OS1 . DIRECTIONAL ~Remarks : Section : Township : Range : Permanent Datum : Elevation Of Perm. Datum : Log Measured from : Feet Above Perm. Datum : Drilling Measured From : Elevation of Kelly Bushing Elevation of Derrick Floor : Elevation of Ground Level : Casing Depth : Other Services Line 1 (1 Ail depths are Measured Depths (MD) unless otherwise noted. (2 Ail depths are Bit Depths unless otherwise noted. (3 Ail Gamma Ray data (GRAM) is the memory data recorded while drilling. (4 Well 3A-03A was drilled to TD at 9735 ft MD (6092 ft SSTVD) on Run 9. (5 Interval from 9710 ft MD (6091 ft SSTVD) to 9735 ft MD (6092 ft SSTVD) was not logged due to sensor bit offset at TD. (6 The data presented here is final and has not been depth shifted to PDC (Primary Depth Control). RWD Gamma Ray was tied to the parent Gamma Ray in the field during logging at 7794 ft MD (5849 ft SSTVD) (per PAI documentation received via e-mail, 24-Sep-2002). (7 A Magnetic Declination correction has been applied to the Directional Surveys. MNEMONICS: GRAM -> Gamma Ray MW-D-API [RWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAPIMA DIRECTIONAL 1 19.60 ft. 24.58 ft. 2 22 . 11 ft. 27 . 09 ft. 3 22.11 ft. 27.09 ft. 4 22.93 ft. 27.91 ft. 5 22.93 ft. 27.91 ft. 6 21.69 ft. 26.67 ft. 7 21.69 ft. 26.67 ft. 8 21.67 ft. 26.65 ft. 9 21.67 ft. 26.65 ft. Tape Subfile: 1 Minimum record length: Maximum record length: 68 records... 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN Phillips Alaska Inc. WN 3A-03A FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COM~ENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has not been depth shifted to PDC (Primary Depth Control. RWD Gamma Ray was tied to the parent Gamma Ray in the field during logging at 7794 ft MD (5849 ft SSTVD) (per PAI documentation received via e-mail, 24 September 2002. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAM 0.0 ROP ROP ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 API 2 ROP MWD 68 1 F/HR Size Length 4 4 4 4 Total Data Records: 49 Tape File Start Depth = 7705.000000 Tape File End Depth = 9735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 58 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN raw.xtf LCC 150 CN Phillips Alaska Inc. WN FN COUN S TAT 3A-03A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .......... GRAM GRAM GRAM 0.0 ROPS ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GRAM MWD 68 1 API ROPS MWD 68 1 F/HR Size Length 4 4 4 4 Total Data Records: 97 Tape File Start Depth = 7705.000000 Tape File End Depth = 9735.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 106 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/02/03 106551 01 **** REEL TRAILER **** MWD 03/02/04 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 7705.0000 7705.5000 7800.0000 7900.0000 8000.0000 8100.0000 8200.0000 8300.0000 8400.0000 8500.0000 8600.0000 8700.0000 8800.0000 89OO.OOOO 9000.0000 9100.0000 9200.0000 9300 0000 9400 0000 9500 0000 9600 0000 9700 0000 9735 0000 GR 66 0020 65 4010 51 1610 58 4790 100 1690 48 3660 106 2110 85 3870 102 0200 99 6710 109 4600 98 8620 47 6910 50 1270 49 8450 42 8830 55.4860 50.9600 78.2550 92.4930 48.2180 57.0440 -999.2500 2 records... 132 bytes 132 bytes ROP -999.2500 -999.2500 16.4350 26.0730 59.6310 116.3250 9.6540 15.7800 36.9790 26.4900 75 1950 74 5210 177 5950 83 5400 79 1710 141 2720 130 8910 30 5850 48 3790 92 1280 130 0200 95.3400 -999.2500 Tape File Start Depth = 7705.000000 Tape File End Depth = 9735.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 7705.0000 7705.2500 7800.0000 7900.0000 8000.0000 8100.0000 8200.0000 8300.0000 GRAM 66 0020 65 7015 51 1610 58 4790 100 1690 48 3660 106 2110 85 3870 ROPS -999.2500 -999.2500 16.4350 26.0730 59.6310 116.3250 9.6540 15.7800 8400.0000 102.0200 36.9790 8500.0000 99.6710 26.4900 8600.0000 109.4600 75.1950 8700.0000 98.8620 74.5210 8800.0000 47.6910 177.5950 8900.0000 50.1270 83.5400 9000.0000 49.8450 79.1710 9100.0000 42.8830 141.2720 9200.0000 55.4860 130.8910 9300.0000 50.9600 30.5850 9400.0000 78.2550 48.3790 9500.0000 92.4930 92.1280 9600.0000 48.2180 130.0200 9700.0000 57.0440 95.3400 9735.0000 -999.2500 -999.2500 Tape File Start Depth = 7705.000000 Tape File End Depth = 9735.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS