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Home My WebLink About200-020 MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ') ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 March 3, 2005 RECEIVED MAR 0 4 200!1 Alaska Oil & Gas Co . IJB. COÐ1mIS'!>':¡r,. Anchorage ~ " Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3H-14A (APD # 200-020/305-010) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations of the Kuparuk well 3H-14A. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, "', """ ......~ l,.... ~\~ R. Thomas Kuparuk Drilling Team Leader CP AI Drilling RT Iskad 5C;ANNED MAR 2 '1 2DOS F="C" E' r.1' );~,...? ~~-'VED ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 4 2005 WELL COMPLETION OR RECOMPLETION REPORT^~ND LOG Oil 0 Gas U Plugged U Abandoned [] Suspended U WAG 0 1b. Wel~~I~~S:"'"" ..~, ~¿f¡. CtÌ!~$. Cumuds~i( 20AAC 25.105 20AAC 25.110 Development [] AnGhQflijJlatory 0 WINJ 0 WDSPL 0 No. of Completions _ Other Service 0 Stratigraphic TestD ,/ 12. Permit to Drill Number: 1 a. Well Status: GINJ 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1157' FNL, 281' FWL, Sec.12, T12N, R8E, UM At Top Productive Horizon: n/a Total Depth: 3629' FNL, 1802' FEL, Sec. 1, T12N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-498655 y- 6000500 TPI: x- n/a y- n/a Total Depth: x- 501850 y- 6003307 18. Directional Survey: Yes 0 NO~ Zone- 4 Zone- 4 Zone- 4 21. Logs Run: 22. STATE OF ALASKA ) 5. Date Comp., Susp., or Aband.: February 21, 2005 6. Date Spudded: November 17, 2000 7. Date TD Reached: November 26, 2000 8. KB Elevation (ft): 76' RKB 9. Plug Back Depth (MD +ND): 7425' MD 15794' TVD 10. Total Depth (MD + ND): 7709' MD 1 5986' TVD 11. Depth where SSSV set: 1797' 19. Water Depth, if Offshore: N/A feet MSL CASING SIZE WT. PER FT. 16" 62.5# 9-5/8" 36# 7" 26# GRADE H-40 J-55 J-55 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND TOP BOTTOM TOP BOTTOM Surf. 115' Surf. 115' Surf. 3455' Surf. 3001' Surf. 7685' Surf. 5970' 23. Perforations open to Production (MD + ND of Top and Bottom Interval, Size and Number; if none, state "none"): perfs squeezed off 26. Date First Production n/a Date of Test Hours Tested 12.25" 24. SIZE 3.5" 1 2-3/8" 200-020 1 305-010 13. API Number: 50-103-20092-01 14. Well Name and Number: 3H-14A 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25531 17. Land Use Permit: ALK 2657 20. Thickness of Permafrost: 1900' MD HOLE SIZE 24" CEMENTING RECORD AMOUNT PULLED 200 sx AS I 1350 sx AS III, 400 sx Class G 800 sx Class G, 175 sx AS I 8.5" TUBING RECORD DEPTH SET (MD) 7685' 1 7691 ' PACKER SET 7674' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7425' - 7660' Class G cement PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Production for OIL-BBL Test Period --> Calculated OIL-BBL 24-Hour Rate -> Flow Tubing Casing Pressure 27. P&A WATER-BBL GAS-MCF GAS-MCF WATER-BBL CHOKE SIZE GAS-Oil RATIO CORE DATA OIL GRAVITY - API (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). J/ / _ d. f- rf~-Lh ¡j Y7at_~1 - Submit core chips; if none, state "none". " -' . :~.' RBDMS BFL MAR 1 5 ~@~E Form 10-407 Revised 12/2003 CONTINUED ON REVERSE r:::.O'C) ! ~ , ~~J /A a \ ¡ ~"'" ' fA, \ "7,Z/-öst" ¡-. ,. ~. -'0___ l' '~'--' ., ~7:::":::" (~ I:: ':J 28. ) 29. ) GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 3H-14A Top of Kalubik Shale 7466' 5822' N/A 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: Pat Reilly @ 265-6048 Printed Na~ Ran~ T~~.as Signature \ ~,\'\;:~~ Title: Greater Kuparuk Area Drillina Team Leader Phone 2.,6'> G '8 3 J Date "3 /~ Ie .,:r Prepared by Sharon AI/sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ) 3H-14A Well Events Summary ) Date Summary 02/21/05 LAYED IN CLASS "G" CEMENT PLUG FROM 7660' CTM (7689' RKB) TO 7396' (7425' RKB). DROPPED BALL AND CLEANED TO TOC WI SEAWATER & 2# BIOZAN. WELL FREEZE PROT'D WI DIESEL TO 2500'. [Cement-Poly Squeeze] 02/24/05 TAG TOP OF CEMENT @ 7425' RKB. TESTED CEMENT PLUG TO 2000 PSI ( GOOD TEST,STATE INSPECTOR WAIVED WITNESS 02/23/05) ) AND BLEED TBG. DOWN TO ZERO AND MONITOR FOR 1 HOUR WI NO FLOW. PUMPED 290 BBLS OF SEA WATER DOWN TBG AND TAKING RETURNS UP IA. PUMPED 88 BBLS OF DIESEL DOWN IA AND TAKING RETURNS UP TBG. RET AG CEMENT PLUG @ 7425' RKB. 02/25/05 CUT 3 112" TBG: SHOT STRING SHOT FROM 7376' TO 7388.5' -- CUT TUBING AT 73861 02/27/05 SET FRAC SLEEVE ( 10' OAL WIlD OF 2.275 ) IN 3 1/2 TRDP-1A ENC @ 1797' RKB. READY FOR BPV. [SSSV Work] rF ~ ~ tfù '? ¡ ~\ ¡ i ¡L \ ~ ~ FRANK H. MURKOWSK/, GOVERNOR AI¡ASKA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 ~_;"i" ;;~.!....' '~r"U Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk 3H-14A Sundry Number: 305-010 Dear Mr. Thomas: 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. 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 i ay or weekend. A person may not appeal a Commission decision to Superior ourt ess rehearing has been ~~. . DATED this '} ~ay of January, 2005 Enc!. SCANNED FES 0 42DD5 ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 January 19, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 V.,.m'D"'~','."'. 1::' Y J~~~; 2~2aQøJ~ AJBgiL~ ,9~s Con,s,.,ÇQromif¡Ùgl1m AHlß Subject: Application for Sundry Approval for 3H-14A (APD# 200-020) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval to P&A the Kuparuk well 3H-14A. This work is in preparation for a sidetrack on this well. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, '-''''-''~''- .'-- - ~~~/~ \~~..._~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad OR'G\~JAL ) ),) RECEIVE ~\ JAN 2 0 ZOO~5š& Aiaské\JM!e~ Gagon~"h~uYalJ~~~.S~l . .An rage Time Extension Other 0 Re-enter Suspended Well ~ bt'Nt 1. Type of Request: Abandon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 Suspend 0 Repair well 0 Pull Tubing 0 Perforate 0 Stimulate 0 ," Alter casing Change approved program 0 0 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 7. KB Elevation (ft): RKB 76' 4. Current Well Class: Development - 0 Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill Number: 200-020 6. API Number: 50-1 03-20092-01 9. Well Name and Number: 3H-14A 8. Property Designation: ADL 255311 ALK 2657 11. Total depth MD (ft): 7709' Casing CONDUCTOR 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5986' 7697' Length Burst SURF CASING PROD CASING 115' 3455' Size MD TVD 16" 115' 115' 9-5/8" 3455' 3001' 7" 7685' 5970' Collapse 7685' Perforation Depth MD (ft): open hole 7690.5'-7709' Packers and SSSV Type: Baker 'FHL' pkr @ Camco SSSV @ 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randv Thomas r'~' \\~ Perforation Depth TVD (ft): 5974'-5986' Tubing Size: 3.5" / 2-3/8" Tubing Grade: J-55 Tubing MD (ft): 7685' / 7691' February 2, 2005 Date: Packers and SSSV MD (ft) 7674' 1797' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Signature Contact: Pat Reilly @ 265-6048 Title: GKA Drilling Team Leader Phone ZG) 6 <3 3ò Date t/,~ I D ~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3o~-o/õ Plug Integrity ~ BOP Test ø Mechanical Integrity Test 0 Location Clearance 0 0 "- ~'\ \)\ ~'ð -\c., ~'\s. at... \., ~\ \ '\ It"'> . RBDMS 8FL JAN 2 4 2005 ORIGINAL ~ COMMISSIONER BY ORDER OF THE COMMISSION Date If/oS Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate ) 3H-14A P & A Summary Background: 3H-14A is an abandoned CTD sidetrack well drilled in November 2000. The C sand straddle was cement squeezed before milling the initial sidetrack window. Kulubik shale sloughing forced the abandonment of the first OH section which was TD'd at 8702' MD. A cement plug was set from 7710' (shale collapse area) to above the whipstock and the hole was redrilled. The redrilled hole depth is 7709'. Again, shale and window access problems caused the second ST attempt to be abandoned, leaving a bit and mud motor @ 7697'. The original OH section to 8702' is not accessible due to this stuck assembly and will be left as is. P & A plan is to cement squeeze the existing open hole section, bringing cement 250' above the upper straddle packer both inside and outside the 3.5" tubing. The tubing will be chemical cut above this cement plug and the Sidetrack rig will pull the tubing, set a CIBP/whipstock and sidetrack. ~ Procedure outline: 1. PT wellhead packoffs (Tubing, IC and OC). Cycle Tubing LDS' s 2. MIT IA to 3000 psi 3. File Plug Back Sundry notice. 4. Perform injectivity test into OR section. 5. Pull lower DV at 7629' (if not possible, using E-line tubing puncher & shoot tubing holes at 7645'). 6. Notify AOGCC inspector 24 hours before commencing plug back work. 7. RU CTU and lay in cement from PBTD (7700' approx.) to 250' above top packer to 7425'. Attempt to squeeze in cement if possible. 8. Open IA and pump 6.5 bbls cement down CT string taking returns up the IA to surface. This puts 250' of cement in the IA above the packer. 9. RU Slickline and tag top of cement. PT to 2000 psi with AOGCC witness prese~. . 10. Rig up E-line and cut tubing at approx. 7300'. 11. Set VR and BPV. Remove wellhouse and flowlines. 12. MIRU DOlon ,15. 13. Pull Tubing. 14. Set CIBP +/- 6270'. 15. Set whipstock +/- 6250'. ç~ ~~ -:JCJ-'- r:>~~çO ,,\\) \ KRU 3H-14A Pro¿l-cer P&A Completion ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ..Jí. 9-5/8" 36# J-55 @ 3455" 3.5" x 7" Cement Squeeze Perfs 7684' - 7688' 3.5" x 7" Cement Squeeze Perfs 7725' - 7729' Collapsed Tubing 7752" I I I ~ I ~ " ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I .,., ~ I I ~ ~ ~ ~ i .. I ~ ~ ~ ~ ~ ~ ~ ~ I .... I I I I ~ ~ ~ i .. I ~ ~ ~ ~ ~ ~ I ~ I ~ I '- ~ ~ ~ I ~ ~ ~ ~ I ~ I I8Þ I ~ , ~ '- ~ ~ ~ ~ I I ~ ~ IJ;;;L. : I ~ " ~ ' . . ~ ... ~ PHilLIPS Alaska, Inc. ~~¡ A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" 5M McEvoy tubing hanger w/ BPV a ~ ~ ~ ~ I l ~ I l ~ ~ ~ ~ 1797' MD 3-1/2" Camco 'TROP-1A' SSSV (valve closed) 3-1/2" 9.2# J-55 BTC AB-mod IPC tubing to packer w/ 3-1/2" x 1" Camco 'KBUG' mandrels spaced as: GLM# MD 1 2882' 2 5311' 3 6753' 4 7280' 7629' MD 3-1/2" x 1-1/2" Camco 'MMG-2' Mandrel 7660' MD 3-%" Baker PBR 7674' MD Baker 3-1/2" x 7" FHL packer Tubing to fish loaded with 12.2 ppg NaBr brine 7685' - 7690' MD 3-%" x 7" two-string window PBTO - Fish consisting of pressure sub, motor, and bit 7710' Bottom of Cement Plug (Placed after hole collapse) ~ ~ ~ ~ ~ ~ i! ~ ~ ~ ~ ~ ~ 8702' MD TO of collapsed 3" openhole PJR 1/17/05 KRU 3H-14A Proytcer P&A Completion ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 9-5/8" 36# J-55 @ 3455" - 250' - 3.5" x 7" Cement Squeeze Perfs 7684'- 7688' 3.5" x 7" Cement Squeeze Perfs 7725' - 7729' Collapsed Tubing 7752" ~ PHilLIPS Alaska, Inc. ~~' A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" 5M McEvoy tubing hanger w/ BPV ~ I I ~ ~ ~ ~ I ~ ~ I I ~ ~ I ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ I I j ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~,."., ~ ~ I~ ~ /' '\,../" ~ ~: ~ ~ ~ I z ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ 1797' MD 3-1/2" Camco 'TRDP-1A' SSSV (valve closed) 3-1/2" 9.2# J-55 BTC AB-mod IPC tubing to packer w/ 3-1/2" x 1" Camco 'KBUG' mandrels spaced as: ... GLM# MO 1 2882' 2 5311' 3 6753' 4 7280' .... 7300' MD Tubing Cut 7425' MD Top of Cement 7629' MD 3-1/2" x 1-1/2" Camco 'MMG-2' Mandrel 7645' MD Contingency Tubing Punch Location 7660' MD 3-%" Baker PBR 7674' MD Baker 3-1/2" x 7" FHL packer Tubing to fish loaded with 12.2 ppg NaBr brine 7685' - 7690' MD 3-%" x 7" two-string window 7697' MD PBTO - Fish consisting of pressure sub, motor, and bit 7709' TO of redrilled hole I 7710' Bottom of Cement Plug (Placed after hole collapse) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 8702' MD TO of collapsed 3" open hole PJR 1/17/05 Â 250' t 3.5" x 7" Cement Squeeze Perfs 7684' - 7688' 3.5" x 7" Cement Squeeze Perfs 7725' - 7729' Collapsed Tubing 7752" ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 6250' MD Whipstock 6270' MD CIBP 7300' MD Tubing Cut 7425' MD Top of Cement 7629' MD 3-1/2" x 1-1/2" Camco 'MMG-2' Mandrel 7645' MD Contingency Tubing Punch Location 7660' MD 3-112" Baker PBR 7674' MD Baker 3-1/2" x 7" FHL packer Tubing to fish loaded with 12.2 ppg NaBr brine 7685' - 7690' MD 3-112" x 7" two-string window PBTD - Fish consisting of pressure sub, motor, and bit 7709' TO of redrilled hole I 7710' Bottom of Cement Plug (Placed after hole collapse) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~11¡~~~!III~{\~II!II!I~~iiiii~lliiili~I¡~~lii¡¡liilll¡l¡11¡!lI¡lillll~li~i!í,i,iiiiilil¡'I'I'I,ililli;'li¡¡,i 3" openhole PJR 1/17/05 Permit to Drill 2000200 MD 7709 --~ 'I'VD DATA SUBMITTAL COMPLIANCE REPORT 7/10/2003 Well Name/No. KUPARUK RIV UNIT 3H-14A Operator CONOCOPHILLIPS ALASKA INC 5986 ? Completion Dat 11/27/2000 f Completion Statu SUSP Current Status SUSP APl No. 50-103-20092-01-00 UIC N REQUIRED INFORMATION Mud Log N_go Sample N__~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD & GR Well Log Information: Log/ Data Digital Digital Log Log Type Media Fmt Name Scale Media ~pt ~- Dir Directional Survey prat- Dir Directional Survey ~.~__ C Ver LIS Verification Ver LIS Verification GR Gamma Ray c. Z5 Blu GR Gamma Ray ~ Blu (data taken from Logs Portion of Master Well Data Maint) Interval Run No Start Stop 1 7680 8700 1 7680 7709 I 7685 8702 1 7685 8702 I 7685 8702 I 7685 8702 OH / Dataset CH Received Number Comments Open 4/20/2001 PB1 Open 4/20/2001 PB2 Open 3/5/2003 11583 '-'PB1 Open 3/5/2003 PB1 Open 3/5/2003 PB1 Open 3/5/2003 PB1 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received? Analysis R ~.r~.iv~.d ? Daily History Received? I~V N Formation Tops ~)'/N Comments: Compliance Reviewed By: Date: Transmittal Form BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Anchorage GEOScience Center Reference: 3H-14APB1 Contains the following: LDWG Compact Disc (Includes Graphic Image files) LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline- GR/Directional TVD Log LAC Job#: 97356 Sent~ , Receive Bd~~~ j~~ ~.Q~ Date: Mar 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 RECEI MAR 0 5 I',;:' ,, 3H-10A and 3H-14A status Subject: 3I-I-10A and 3I-I-14A status Date: Tue, 24 Sep 2002 07:07:12 -0800 From: "Dan Venhaus" <dvenhaus@ppco.com> To: winton_aubert~admin.state.ak.us CC: "Michael B Mooney" <mmooney~ppco.com>, "Johnny O Golden" <jgolden@ppco.com> Winton, Regarding your memo to Mike Mooney dated July 26, 2002: Well Completion Reports (10-407) were filed for both 3H-10A and 3H-14A in February 2001 designating them as suspended wells. Please let me know if your records do not contain these reports and I can fax them to you. If you have any questions, you can reach me at 263-4372 or cell phone 230-0188. Thanks, Dan Venhaus PAI Drilling & Wells ALASKA OIL AND GAS CONSERVA~I~ION CO~ISSION July 26, 2002 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-14.%3 FAX (907) 276-7542 Mike Mooney Wells Team Leader Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re; Kuparuk River Unit 3H-10A (PTD #200-041) Kuparuk River Unit 3H-14A (PTD #200-020) Dear Mr. Mooney: AOGCC records indicate that Kuparuk Well 3H-10A drilling operations were shutdown on December 7, 2000 and that Kuparuk well 3H-14A drilling operations were shutdown on November 27, 2000. Per 20 AAC 25.072 (d), well operations must resume within 12 months, or the well be suspended or abandoned. Please file appropriate documents notifying the Commission of your plans for 3H-10A and 3H-14A no later than August 26, 2002. Thank you for your attention to this matter. Sincerely, Winton Aubert Petroleum Engineer PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 D. Venhaus Phone (907) 263-4372 Fax: (907) 265-6224 December 13, 2001 Cammy Oechsli-Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Application for Sundry Approval and Report of Sundry Well Operations 3H-14A (200-020) Dear Commissioner: Phillips Alaska, Inc. submits the attached Application for Sundry Approval and the Report of Sundry Well Operations for the Operations Shutdown of 3H-14A. Attached is a previous correspondence defining the reason for suspending operations and the well's suspended condition. A schematic is attached for further clarification. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Alaska Inc. MM/skad RECEIVED DEC 2 6 200~ Alaska Oil & Gas Cons. Commissio~ Anchorage ORIGINAL STATE OF ALASKA i' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_X Stimulate _ Plugging _ Perforate _ 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 1155' FNL, 4997' FEL, Sec. 12, T12N, RSE, UM At top of productive interval 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service__ (asp's 498655, 6000500) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-14A 9. Permit number / approval number 200-020 / 10. APl number 50-103-20092-01 At effective depth At total depth 3629' FNL, 1802' FEL, Sec. 1, T12N, R8E, UM (asp's 501850, 6003307) 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 3455' PROD CASING 7685' 7709 feet Plugs (measured) 5986 feet Perforation depth: 7697 feet Junk (measured) 5978 feet Size Cemented :Measured Depth True vertical Depth 16" 200 sx AS ~ 1 15' 115' 9-5/8" ~350 sx AS m, 4O0 sx C~ass G 3455' 3001' 7" 800 sx Class G, 175 sx AS I 7685' 5970' measured open hole 7690.5' - 7709' true vertical 5974' - 5986' Tubing (size, grade, and measured depth) RECEIVED DEC g Alaska 0ii & Gas Co~s. Commissi0~ Anctt0~age 3-1/2,,, 9.2#, J-55 Tbg @ 7639' MD; 3-1/2", 9.3#, J-55 Tbg @ 7660' MD; 3-1/2", 9.2#, J-55, Tbg @ 7685' MD. Packers & SSSV (type & measured depth) Baker'FHL' pkr @ 7674' MD. CAMCO 'TRDP-1A-ENC' @ 1797' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A 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 N/A Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil __ Gas __ Suspended Service ,Water Injector. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Michae/ Mooney Form 10-404 Rev 06/15/88 ' Title Wells Group Team Leader Questions? Call Dan Venhaus 263-4372 Prepared by Sharon A//sup-Drake 263-4612 ORiGiNAL*"""s BEC 2 8 2001 ~:~ SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. Baker Hughes INTEQ Survey Report INTEQ Company: Phillips Alaska, Inc. FieM: Kuparuk River Unit Site: KRU 3H Pad Well: 3H-14 Wellpu~: 3H-14APB2 Date: 3/19/2001 Time: 15:57:27 Page: 1 Coordinate(NE) Reference: Well: 3H-14, True Noflh Vertical (TV])) Reference: 3H-14 Rig 76.0 Section (va) Reference: Well (0.00E,0.00N,48.68Azi) 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 3H Pad UNITED STATES: North Slope Site Position: Northing: 6001657.06 ft From: Map Easting: 498373.50 ff Position Uncertainty: 0.00 ff Ground Level: 0.00 ft Latitude: 70 24 56.740 N Longitude: 150 0 47.691 W North Reference: True Grid Convergence: -0.01 deg Well: 3H-14 Slot Name: Well Position: +N/-S -1156.72 ft Northing: 6000500.40 ft +E/-W 282.18 ft Easting: 498655.40 ft Position Uncertainty: 0.00 ft Latitude: 70 24 45.364 N Longitude: 150 0 39.419 W Wellpath: 3H-14APB2 Drilled From: 3H-14 501032009201 Tie-on Depth: 7680.00 ft Current Datum: 3H-14 Rig Height 76.00 ff Above System Datum: Mean Sea Level Magnetic Data: 1/17/2001 Declination: 26.10 deg Field Strength: 57414 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 48.68 Survey: MWD Start Date: 11/2712000 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD 7680.00 5966.54 Kick-off Point 7709.00 5986.11 Projected to TD Survey MD Incl Azlm TVD SSTVD N/S E/W MapN MapE DLS VS ff deg deg ff ff ff ff ff ff degll00ff ff 7680.00 47.57 39.82 5966.54 5890.54 2791.40 3180.35 6003290.95 501835.93 0.00 4231.61 7709.00 47.57 39.82 5986.11 5910.11 2807.84 3194.05 6003307.39 501849.64 0.01 4252.76 REFERENCE iNFORMATiON 3/19/2001 4:06 PM PHILLIPS Alaska, Inc. Baker Hughes INTEQ Survey Report 14LIGHES Company: Phillips Alaska, Inc. FieM: Kuparuk River Unit Site: KRU 3H Pad Well: 3H-14 WeUpath: 3H-14APB1 Date: 3/19/2001 Time: 15:56:09 Page: 1 Ce-ordinate(NE) Reference: Well: 3H-14, True Norlh Verti~i (TVD) Reference: 3H-14 Rig 76.0 Section CVS) Reference: Well (0.00E,0.00N,45.00Azi) Snrvey Calenlaflon 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 3H Pad UNITED STATES · North Slope -;' Site Position: Northing: 6001657.06 ft Latitude: 70 24 56.740 N ', From: Map Easting: 498373.50 ff Longitude: 150 0 47,691 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.01 deg Well: 3H-14 Slot Name: Well Position: +N/-S-1156.72 ft Northing: 6000500.40 ft Latitude: 70 24 45.364 N +E/-W 282.18 ft Easting: 498655.40 ff Longitude: 150 0 39.419 W Position Uncertainty: 0.00 ft Wellpath: 3H-14APB1 Drilled From: 3H-14 501032009270 Tie-on Depth: 7680.00 ft Curreut Datum: 3H-14 Rig Height 76,00 ff Above System Datum: Mean Sea Level Magnetic Data: 12/21/2000 Declination: 26.12 deg Field Strength: 57414 nT Mag Dip Angle: 80.70 de0 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 45.00 Survey: MWD Start Date: 11/21/2000 Measured While Drilling Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD 7680.00 5966.54 Kick-off Point 8700.00 6176.07 Projected to TD Survey MD Incl Azlm TVD SSTVD N/S E/W MapN MapE DLS VS ff deg deg ff ' ff ff ff ff ff degll00ff 7680.00 47.57 39.82 5966.54 5890.54 2791.40 3180.35 6003290.95 501835.93 0.00 7715.00 36,70 43.30 5992,46 5916.46 2808.99 3195.64 6003308.53 501851.42 31.76 7769.00 44.20 49,70 6033,54 5957.54 2832.95 3221.31 6003332.49 501876.90 15.86 7810.00 48.40 58.50 6061.89 5985.89 2850.23 3245.31 6003349.76 501900.90 18.58 7846,00 53.30 69.80 6084.66 6008.66 2862,28 3270.40 6003361.80 501925.99 27.86 7884,00 58.60 68,70 6105.93 6029.93 2873.44 3299.83 6003372.96 501955.41 14.15 7915.00 63.00 76.10 6121,06 6045.06 2881.57 3325.60 6003381.09 501981.19 25.20 7942.00 64.20 82.80 6133.08 6057.08 2885.99 3349.36 6003385.50 502004.94 22.66 7968.00 66.40 88.00 6143.95 6067.95 2887.88 3372.89 6003387.38 502028.47 20.04 8006.00 70.40 95180 6157.95 6081.95 2886.67 3408.16 6003386.17 502063.74 21.79 8057.00 75.10 105.60 6173.11 6097.11 2877.59 3455.93 6003377.08 502111.50 20.53 8100.00 81.00 114.10 6182.02 6106.02 2863.30 3495.43 6003362.78 502150.99 23.70 8126.00 83.60 114.10 6185.50 6109.50 2852.78 3518.94 6003352.26 502174.51 10.00 8153.00 86.30 111.60 6187.88 6111.88 2642.34 3543.73 6003341.81 502199.28 13.60 8175.00 89.00 109.80 6188.78 6112.78 2834.57 3564.29 6003334.04 502219.64 14.75 8228.00 87.80 103.50 6190.26 6114.26 2819.39 3615.02 6003318,86 502270.56 12.10 8262.00 86.70 99.60 6191,90 6115.90 2812.59 3648.28 6003312.06 502303.82 11.91 8299.00 86.90 95.80 6193.96 6117.96 2807.65 3684.89 6003307.10 502340.42 10.27 4222.66 4246.05 4281.01 4310.20 4336.46 4365.16 4389.13 4409.06 4427.03 4451.12 4478.47 4496.30 4505.49 4515.63 4524.67 4549.82 4568.53 4590.91 PHILLIPS Alaska, Inc. Baker Hughes INTEQ Survey Report INrEQ CompaBy: Phillips Alaska, Inc. Date: 3119/2001 Time: 15:56:09 Page: 2 Field: Kup~ruk RJYer Unit ~ Co-ordimate(NE) Referemce: Well: 3H-14, True Site: KRU 3H P~d Vertical (TVD) RefereBce: 3H-14 Rig 76.0 Well: 3H-14 SectioB (VS) RefereBce: Well (0.00E,0.00N,45.00A~i) Wellpath: 3H-14APB1 Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD iacl Azlm TVD SSTVD N/S ~W MapN MapE DLS VS it deg deg it it it fl: it ff deg/100it fl 8329.00 87.70 92.60 6195.38 6119.38 2805.45 3714.77 6003304.90 502370.30 10.98 4610.49 8364.00 90.60 88.00 6195.90 6119.90 2805.27 3749.75 6003304.71 502405.28 15.53 4635.10 6419.00 93.30 85.60 6194.02 6118.02 2808.34 3804.62 6003307.77 502460.15 6.57 4676.07 8468.00 93.60 79.20 6191.07 6115.07 2814.80 3853.08 6003314.23 502508.60 13.05 4714.90 6494.00 93.80 75.40 6189.39 6113.39 2820.50 3878.39 6003319.92 502533.91 14.61 4736.83 8521.00 94.70 72.20 6187.39 6111.39 2828.01 3904.24 6003327.43 502559.76 12.28 4760.42 8549.00 95.10 69.10 6185.00 6109.00 2837.26 3930.56 6003336.67 502586.08 11.12 4785.57 8576.00 94.40 70.10 6182.76 6106.76 2846.64 3955.78 6003346.04 502611.29 4.51 4810.03 8601.00 92.20 73.30 6181.32 6105.32 2854.47 3979.47 6003353.87 502634.98 15.52 4832.32 8630.00 90.30 76.80 6180.69 6104.69 2861.95 4007.47 6003361.34 502662.99 13.73 4857.42 8654.00 93.00 76.10 6180.00 61 04.00 2867.57 4030.79 6003366.96 502686.31 11.62 4877.88 8673.00 95.40 75.00 6178.61 6102.61 2872.30 4049.14 6003371.68 502704.66 13.89 4894.20 8700.00 95.40 75.00 6176.07 6100.07 2879.25 4075.11 6003378.63 502730.62 0.00 4917.48 WELLPATH DETAILS 3H-14APD,2 R FERENCE iNFORMATiON 3/I9/2001 4:06 PM 3H-14A and 3H-10A shutdowns Subject: 3H-14A and 3H-10A shutdowns Date: Mon, 12 Feb 2001 20:53:57-0000 From: "Venhaus, Dan E" <VenhauDE~BP.com> To: "'tom_maunder~admin.state.ak.us'" <tom_maunder~admin. state.ak.us> CC: "Rauf, Paul C" <Rau~C~P.com>, "Gantt, Lamar L" <GanttLL~BP.com>, "Stanley, Mark J (ANC)" <StanleMJ~BP.com> Tom, CTD operations were shutdown on sidetracks 3H-14A and 3H-10A due to problematic Kalubik shales. Both wells have KOPs in the Kalubik which is collapsed just outside the window. Drilling through the Kalubik was unavoidable, due to directional limitations and/or existing completion problems. Both are loaded with KWF and a backpressure valve set. 3H-14A Nabors 3S moved over well 3H-14A on November 15, 2000. A two-string window was milled followed by drilling 1017' of openhole, of which 600' was horizontal. During a short trip to the window, packing off and sticking problems prevented getting the BHA back through the Kalubik shale. An attempt to plugback with cement and redrill through the Kalubik was unsuccessful and resulted in leaving a fish (motor & bit) across the window. This occurred on November 26 at which time it was decided to suspend this operation and move to the next well. Fishing operations were considered risky due to the small clearance around the BHA across the window. 3H-10A Nabors 3S moved from 3H-14A to 3H-10A on November 27, 2000. Again, the KOP was located in the Kalubik, but it was considered a less risky operation than the 3H-14A sidetrack due to a cleaner window through one string. The window was milled successfully but only 101' of Kalubik was drilled when failure of the shale occurred. The hole completely collapsed just 15' outside of the window. The decision to suspend operations was made December 3. Nabors 3S moved off December 7. I hope this "closes the loop" on the Operations Shutdown for these two wells. Let me know if you need any other information. Thanks, Dan Venhaus 230-0188 cell 564-5273 BP 263-4372 Phillips I of 1 7/25/2002 1:13 PM 3H-14A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/15/2000: 11/16~2000: 11/17/2000: 11/18/2000: 11/1912000: 11/20/2000: 11/21/2000: 11122/2000: 11123/2000: 11/24/2000: 11/25/2000: 11/26/2000: 11/27/2000: MIRU Nabors 3S & CTU#4. 3S rig accepted 1000 hrs. Continued MIRU. PT'd BOPE. RIH & tagged top of Whipstock @ 7685'. Commenced window milling through the 3-1/2" & 7" casing. Time milled to 7687' & POOH. RIH & milled window to 7690'. Completed window milling. TOW=7685'. BOW = 7690.5'. Drilled FM to 7697' & POOH. RIH & conditioned window interval. Swapped to FIo Pro while reaming & POOH. RIH w/bi- centered bit & drilled to 7720' MD. Drilled to 8110' & POOH w/bi-centered bit. RIH w/bi-centered bit to BTM. Drilled to 8550'. Reamed shales below window. POOH. RIH w/BHA. Drilled to 8702' & short trip to window. RBIH & stacked weight. Packed off. Lost returns- worked free. PUH & circulated BTM's up. RBIH - stacked weight & packed off again. Worked free & PUH to above window. Circulated new 10.5 ppg FIo Pro. Reamed Kabulik Shales. Unable to get beYond 7720' so POOH. "' RIH w/taper mill & dressed window. Reamed shale to 7730'. Stacked weight. Overpull. Dressed window. Reamed shales & POOH. RIH w/drilling BHA & tagged 7736' after running through the window smoothly. Packed off & stUck w/CT. worked CT free. PUH & circulated BTM's up. POOH. Decided to plugback. RIH w/CT nozzle to 7712' & got stuck mechanically. PUH & pumped 15 bbls 15.8 ppg Class G Cement f/7710' to 7575'. Contaminated w/Biozan & cleaned out to 7575'. POOH w/CT. WOC. Completed BOPE test. Performed rig maintenance. RIH & milled cement fl 7580' to 7696'. Dressed window interval. Dressed window & POOH. RIH & drilled to 7703'. Drilled to 7709' (TD) & POOH. RIH to 7709' & began drilling. CT stuck / packed off. Pull max & POOH. BHA parted - Baker press sub, motor, & bit left fish in hole as fish. Discussed options w/town. RIH w/CT & loaded well w/12.2 ppg Brine. Left FIo Pro mud below 7667' to top of fish 7697'. FP'd well w/Diesel f/2000'. POOH. RDMOL. 3S released 1800 hrs. Well 3H-14A is currently suspended. Future options are currently being evaluated. Sidetrack Summary Page 1 KRU 3H-14A Pr0clucer P&A Completion 9-5/8" 36# J-5 ~ 3455" PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" 5M McEvoy tubing hanger wi BPV 1797' MD 3-1/2" Camco 'TRDP-1A' SSSV (valve closed) 3-1/2" 9.2# J-55 BTC AB-mod IPC tubing to packer w/ 3-1/2" x 1" Camco 'KBUG' mandrels spaced as: GLM# MD 1 2882' 2 5311' 3 6753' 4 7280' I'ubing to fish loaded with 12.2 ppg NaBr brine 7629' MD 3-1/2" x 1-1/2" Camco 'MMG-2' Mandrel 7660' MD 3-%" Baker PBR 7674' MD Baker 3-1/2" x 7" FHL packer 7685' - 7690' MD 3-%" x 7" two-string window · ~e,' .' .' · 7697' MD PBTD - Fish consisting of pressure sub, motor, and bit Collapsed openhole, partially plugged with 15.8 ppg Class 'G' 8702' MD TD of collapsed 3" openhole DEV 12/17/01 , {' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification ot Service Well , Oil D Gas D Suspended [~] Abandoned D Service [~ I YE'~_..el~ 2. Name of Operatora ~~{ ,~ 7. Permit Number Phillips Alaska, Inc. [~~ .. 2O0-020 3. Address~r~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ?', SoC,,,~c_,iZ~/, 50-103-20092-01 4. Location of well at surface ;'i'"~:.-:':/' ---1 9. Unit or Lease Name , Kuparuk Unit 1155' FNL, 4997' FEL, Sec. 12, T12N, R8E UM (asp's 498655, 6000500) i : -' At Top Producing Interval i Z_/'..__~.7._i. ~.. ' 10. Well Number '~. 'i/'L; '. "i 3H- 14A At Total Depth I ...... ~ ..... 11 Field and Pool ~, · 3629' FNL, 1802' FEL, SEC 1, T12N, R8E, UM (asp's 501850, 6003307) ~ ........................ Kuparuk Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 76 feetI ADL 25531 / ALK 2657 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 I November 17, 2000 November 26, 2000 November 27, 2000 I 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 7709' MD / 5986' TVD 7697' MD / 5978' TVD ;YES [~ No DI 1797' 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'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 200 Sx AS I 9-5/8" 36.0# J-55 Surface 3455' 12-1/4" 1350 Sx AS III & 400 Sx Class G 7" 26.0# J-55 Surface 7685' 8-1/2" 800 Sx Class G & 175 Sx AS I 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" 7685' 7674' 7690.5' - 7709' MD; 5974' - 5986' TVD; Open hole w/fish ,, 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.) Date ot Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) :24-Hour Rate > 28. CORE DATA Brief description ot lithology, porosity, fractures, apparent dips and pressence ot oil, gas or water. Submit core chips. · This 10-407 is submitted as directed per the 10-401 form approved March 20, 2000 (Permit #200-020) '*:r'J[IJ S BFI_ SEP 24 2002 FEB 0 7 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate Alaska Oil & Gas Cons. Comrnissior/ Anchorage 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 Kalubik Shale 7466' 5822' 31. LIST OF AI-['ACHMENTS Summary of 3H-14A CT Sidetrack Drilling Operations + End of Well Survey & 1 Plugback Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Dan Venhaus 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. Item 28: If no cores taken, indicate "none". Form 10-407 FEB 0 ? 2.001 Alaska Oil & Gas Cons. Commisoion Anclnorage ,,. 3H-14A . DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/15/2000: 11/16/2000: 11/17/2000: 11/18/2000: 11/19~2000: 11/20/2000: 11/21/2000: 11/22/2000: 11/23/2000: 11/24/2000: 11/25/2000: 11/26/2000: 11/27/2000: MIRU Nabors 3S & CTU#4. 3S rig accepted 1000 hrs. Continued MIRU. PT'd BOPE. RIH & tagged top of Whipstock @ 7685'. Commenced window milling through the 3-1/2" & 7""~ casing. Time milled to 7687' & POOH. RIH & milled window to 7690'. Completed window milling. TOW=7685'. BOW = 7690.5'. Drilled FM to 7697' & POOH. RIH & conditioned window interval. Swapped to FIo Pro while reaming & POOH. RIH w/bi- centered bit & drilled to 7720' MD. Drilled to 8110' & POOH w/bi-centered bit. RIH w/bi-centered bit to BTM. Drilled to 8550'. Reamed shales below window. POOH. RIH w/BHA. Drilled to 8702' & short trip to window. RBIH & stacked weight. Packed off. Lost returns - worked free. PUH & circulated BTM's up. RBIH - stacked weight & packed off again. Worked free & PUH to above window. Circulated new 10.5 ppg FIo Pro. Reamed Kabulik Shales. Unable to get beyond 7720' so POOH. RIH w/taper mill & dressed window. Reamed shale to 7730'. Stacked weight. Overpull. Dressed window. Reamed shales & POOH. RIH w/drilling BHA & tagged 7736' after running through the window smoothly. Packed off & stuck w/CT. Worked CT free. PUH & circulated BTM's up. POOH. Decided to plugback. RIH w/CT nozzle to 7712' & got stuck mechanically. PUH & pumped 15 bbls 15.8 ppg Class G Cement f/7710' to 7575'. Contaminated w/Biozan & cleaned out to 7575'. POOH w/CT. WOC. Completed BOPE test. Performed rig maintenance. RIH & milled cement f/7580' to 7696'. Dressed window interval. Dressed window & POOH. RIH & drilled to 7703'. Drilled to 7709' (TD) & POOH. RIH to 7709' & began drilling. CT stuck / packed off. Pull max & POOH. BHA parted - Baker press sub, motor, & bit left fish in hole as fish. Discussed options w/town. RIH w/CT & loaded well w/12.2 ppg Brine. Left FIo Pro mud below 7667' to top of fish @ 7697'. FP'd well w/Diesel f/2000'. POOH. RDMOL. 3S released 1800 hrs. Well 3H-14A is currently suspended. Future options are currently being evaluated. Sidetrack Summary Page 1 FEB 0 ? 2001 Aiaska Oil & Gas Cons. Commission Anchorage Subject: Re: CTD BOP stack for KRU wells Date: Wed, 27 Sel:(i )0 14:37:12-0800 il From: Blair WondzeH <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Johnson, Mark O" <JohnsoMO~bp.com> Mark, I re-read your original E-mail. We accept these changes for the 5 wells you listed. Thanks for including the PTD numbers. That makes our life a little easier. Thanks, Blair Wondzell, 9/27/00. "Johnson, Mark 0" wrote: Blair, I could not save the visio drawing in xls, pdf, or txt. I saved it in jpg which I think you will be able to open. I also faxed over a copy. Thx MOJ 240-8034 Good Morning Mark, We can read the attached vsd file. Can you please send it in xls, pdf, . doc, .txt. or a paint brush file or fac to me at 276-7542 or both. Thanks, Blair Wondzell "Johnson, Mark 0" wrote: > Blair, > > We would like to make a change to the BOP stack configuration in five (5) > KRU CTD drilling permits. The drilling permits were approved by AOGCC in > 3/00. Please approve this change for those drilling permits listed below. > > A drawing of the proposed BOP stack is attached. > > The primary difference in this stack compared to what is in the KRU drilling > permits is how the ram type BOps stack up. We want to put the 2" coil > tubing pipe rams below the mud cross. In the unlikely event of a mud cross > leak, this configuration would allow us to isolate the leak by closing the > pipe rams on the coiled tubing during the drilling phase. > > A risk assessment was performed on this BOP configuration and results were > favorable. > > The five sidetrack wells will be drilled with CTD using the dynamically > overbalanced drilling technique, as per the permits. The wells and approved > drilling permit numbers are as follows: Well Permit '# 1R-O3Ai 200-021 3K-22Ai 200-026 3H-IOAi 200-041 3H-14A 200-020 3H-16A 200-022 <<KRU BOP Stack. vsd>> FYI, a new drilling permit request for the sidetrack of 1R-O1Bi will also include this BOP stack. Thanks, Mark O. Johnson 564-5666 (office), 240-8034 (cell) > > Name: KRU BOP Stack.vsd > > KRU BOP Stack. vsd Type: > application/x-unknown-content-type-vsd auto file C:\Transfer~U BOP Stack jpg.jpg (local) - Microsoft Intemet Explorer Page 1 of 1 KRU CTD. BOP Detail . '-" CT InjeCtor '"'"--' Stuffing Box(Pack-Off), 1'0,000 Methano.i injection ~~~ I,'-- 7'' Riser 'Otis"7'"':VY' LA'QUick :u. onnec~: ~ ~':1' I i :' :i: .:An. nuiar. BOP. (H:y.d,ril)...7.:.ltl:6.,! ..iD ....... 5000.psiworking p're.s. SUr:e 7.(:i/16';..iiD.; :5i300..psi ::working: ::pre s su re .Ram.TyPe.DUal: Gate :BOPE ' · ....... :Manual,over, Hydraulic ~:Hydril ['2 '3'/8,"Pipes I ..................... I' ~Fia'ng'e.d !F, ire:Re:s!'stantl. 'HCR: .... ' ....... 'U'""' " , , Manual, valves Kelly:Hose,to'D a'l: · .~., ~...~.i:.. 5.]. i:. ' :'.." ' . ...... ':.lZ'.ill line o,,~ck:,,,~l,,e \ .... ~ '.,t~a ~,,,~: ,,~C, oke: 'fi, od:/, .......... ! ~' ,;;' ~:~.. .. 7:~t::'/16 iiD',',:5000 p:si:working:pressure ~ ..... ;[ ~'~' 'l ........ brl Rlind~Rh~_.r I ....... ' .................... ::Ram,.T:ype DualGat:e:BOP. E I TOT :." I:: .~: ...... .;/" ~ !.' ........ .ri ! .',,',:.,.".,:,,:..,: ,:'" ..... :Manual'~Over HYdraulic ' .~, .Ii ,.(¢,~.. :~!! [ z ,,;u:omm' ~pe~ ' Sing!e.. o.r..D0uble ~:' ::ManuaI, :MaSter,Val~)es, .'IL T A.:' ,I · .sp'oOl~ , '?' ':: 7"'Ann.Ulus. .. .9':5/B;" Anh.ulus 9/27/00 2:26:24 PM TONY KNOWLES, GOVERNOR ALASI~A OIL AND GAS CONSERVATION COH~IlSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 B E Smith AAI Coil Tubing Drilling Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk Unit 3H-14A ARCO Alaska, Inc. Permit No: 200-020 Sur. Loc. 1155'FNL, 4997'FEL, Sec. 12, T12N, R8E, UM Btmhole Loc. 2287'FNL, 652'FEL, Sec. 1, TI2N, R8E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OFf. COMMISSION DATED this day of March, 2000 dlf/Enclosurcs cc: Department of Fish & Game, Habitat Section xv/o encl. Department of Environmental Conscn'ation w/o encl. STATE OF ALASKA i~i ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~. o, wo,~ ~,,,n El Ilb. Type ofwell. Exploratory E~] Stratigraphic Test r~ Development Oil r~l Re-entry I~l Deepen [-~I Service I~ Development Gas E~] single Zone ~l Multiple Zone r'"] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 76 feet 3. Address 6. Property Designation Kuparuk Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531/ALK 2657 Kuparuk Oil Pool 4. Location of well at sudace 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.0251) 1155' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM Kuparuk Unit Statewide At top of productive interval 8. Well number Number 3593' FNL, 1777' FEL, SEC. 1, T12N, R8E, UM 3H-14A #U-630610 At total depth 9. Approximate spud date Amount 2287' FNL, 652' FEL, Sec 1, T12N, R8E, UM April 1,200O $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 25630, 652' @ TD feetI No Close Approach feet 2560 9751 MD / 6136 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 7690' MD Maximum hole angle 110° Maximum surface 3250 psic, I At total depth (TVD) 3845 psig @ 6047' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin[I Welc, lht Grade couplin~l Length MD TVD MD TVD {include sta~e dataI 2-3/4" 2-3/8" 4.6 L-80 FL4S 2401' 7350' 5743' 9751' 6136' 12 bbls ! I ! 19. To be completed for Redrlll, Re-entry, and Deepen Operations. U I ~ I ~ I I Ii~ r~ L. Present well condition summary Total Depth: measured 8250 feet Plugs (measured) Collapsed Tubing Tag @ 7752' MD on 7/14/1999. tree vertical 6374 feet Effective Depth: measured 7752 feet Junk (measured) tree vertical 6015 feet Casing Length Size Cemented Measured depth True Vertical depth CON DU CTOR 115' 16" 200 Sx AS I 115' 115' SUR. CASING 3379' 9-5/8" 1350 Sx AS III & 400 Sx Class G 3455' 3001' PROD. CASING 8144' 7" 800 Sx Class G & 175 Sx AS I 8220' 6351' RECEIVED 25 2000 Perforation depth: measured 7758' - 7763'; 7768' - 7798'; 7882' - 7902'; 7917' - 7929'; 7954' - 7974'. true vertical 6018'-6022'; 6025'-6046'; 6103'-6117'; 6128'-6136'; 61~4'-6166'.AlaskaOil&GascOas'cOmmiatiOn Anchorage 20. Attachments Filing fee F~I Property Plat D BOP SI(etch ~1 Diverter Sketch D Drilling program ~ Drilling fluid program Time vs depth plot D' Refraction analysis D Seabed report D 20 AAC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my knowledg~ Questions? Call Dan Kara @ 263-4837. a.e Commission Use Only Permit NumberI I ~ Isee c°ver letterlfor other requirements C,~ Q~(~ (~ 7 I1~ , APl numbe.__~- ,. -- Conditions of approval Samples required r~ Yes ~J No Mud log required I--I Yes [~ No Hydrogen sulfidemeasures E] Yes ~I Ho Directional surveyrequired ~, Yes r~ No Required worklng pressure for BOPE D2M;'"D 3M; D 5M; I~l lOM;E] r~ 3500 psi for CTUv~ Other: ORK~INAL SIGNED BY' by order of Approvedby ~-~_..~,-,,.+ ....~..4~..,~,,~ ..... r~ Commissioner thecommisslon Date''~c::,('~' ~I~)'' '"'-- Form 10-401 Rev. 12/1/85 · Submit in triplicate KRU 3H-14A CT Sidetrack and Completion Intended Procedure Objective: P&A well with 15.8 ppg cement. Mill window from mechanical whipstock. 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 and place cement behind straddle interval. Mill window from whipstock in straddle interval through both the 3-1/2" tubing and 7" casing at 7690' md. Drill 10' of formation and perform leak-off test to 12.7 ppg, 0.5 ppg above the highest anticipated equivalent mud weight. Directionally drill a 2-3/4" (3" bi-center) well using dynamically overbalanced drilling techniques. Planned TD is 9751' md. · Run 2-3/8" blank liner to TD, cement in place. · Perforate, place on production. Drilling fluids will be injected into disposal well 1R-18. Dynamically overbalanced drilling techniques will be employed to address high reservoir pressure. Plans are to use ~-10 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. At least two times hole volume of kill weight fluid will be on location as a contingency. Frequent monitoring and rolling of the kill weight fluid will be done to ensure proper weight distribution. February 17, 2000 Kuparuk 3H-14A Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 3845 psi @ 6047' TVD, 5971'ss (12.2 ppg EMW) estimated pressure. Reservoir frac gradient is estimated at -0.85 psi/ft or 16.3 EMW, 5140 psi Plans are to drill with less than kill-weight fluid, or dynamically overbalanced. 10 ppg mud will result in a hydrostatic pressure that is -700 psi less than reservoir pressure. Maintain at least 900 psi WHP for well control when not circulating. Pressure loss associated with circulating (ECD) is expected to be >700 psi so applied WHP is not necessary while circulating. Monitor return-line flow rate and pit volume continuously. If crude enters the pits, take all returns to an outside tank first. Have on location at least two times wellbore volume, 12.2 ppg Kill Weight Fluid. Frequent monitoring and rolling of the kill weight fluid is required to ensure proper weight distribution. Maximum anticipated WHP w/full column of gas: -3250 psi assuming 0.1 psi/ft gas gradient. However, no gas saturated intervals are anticipated. February 17, 2000 ARCO Plan.xlt 5600 - - 5700 - 5~oo- - _ ARCO Alaska, Inc. - ................ ......................... Structure : Pad 3H Well : 3H-14A, 50-103-20092-01 Field : Kuparuk River UnitLocation : North Slope, Alaska : East (feet) -> 2400 2600 2800 3000 3200 3400 3600 5800 4000 4200 4400 4600 4800 5000 I! I ! I I I ! I I I I I I I I I I ! I , , , , , , ' ' 4600 ~ 3H-14 T4 TD 9 IF = 9ffff 8 TF=-94/ 7 TF--130J ° 3H-14 13 90 / §~- ~ ~ · 3H-14 T2 90 ~ · 3H--14 T1 90 Kick--off Point TF=I75 ,/ '~' Tie-in Point 4600 4700 4800 4go0 5000 5100 52~ 53~ 54~ VeHicol Section (feet) Azimuth 41.00 with reference 0.00 N, 0.00 E from 5H-14 TO 5500 ~00 5700 5800 5900 6000 6100 6200 , 4400 4200 ~4000 =r .3400 ~-~ 3200 3000 Prepared by BH102/12/00 KRU 3H-14J' ?ROPOSED CT HORIZONTA' SIDETRACK @ 1798' 9-5/8" Shoe @ 3455' 3-1/2",9.3#, J-55 Production Tubing to Surface of 2-3/8" Liner @ 7350' (proposed) 3-1/2" x 7" Baker FHL Packer @ 7674' Shoot Circulation holes 7680' - 7700' Top of P&A Cement @ 7685' Whi Collapsed Tubing @ 7752' Low Injectivity Past Collapse: 0.5 bpm @ 3000 psi 7" Liner & Perfs P&A'd with 15.8 ppg Cement Set Mechanical Whipstock in 3-1/2" tubing @ 7690' - Mill Window through 3-1/2" tubing & 7" Casing. Install Bridge Plug @ 7750' 3-1/2" Production Mandrel @ 7710' 2-3/8" FL4S 4.6# Liner Cemented & Perforated Blast Rings 7753' - 7803' 3-1/2" x 7" Otis WD Packer @ 7832' 2-7/8" 6.5# J-55 Tubing7859,Tail to~ _ 7" Shoe @ 8220' 3" Open hole PCR 2/16/2000 ARCO ver # Company: Well: Calculation Method: IVeracal Sect. Plane: IMeasured Depth from: MD 7600.00 7625.00 7650.00 7675.00 7690.00 7700.00 7720.00 7725.00 7740.00 7750.00 7775.00 7800.00 7825.00 7850.00 7875.00 7900.00 7925.00 7950~00 8000.00 8050.00 8075.00 8100:00 8105.51 8125.00 8150~00 8175.00 8200.00 8225.00 8250,00 8275.00 8300.00 8325.00 8350.00 8375.00 8400.00 8425.00 8450.00 8475.00 8500.00 8525.00 8550.00 8575.00 8600.00 8625.00 8650.00 8675.00 8700.00 8725.00 8750.00 8775.00 8800.00 8825.00 8840.00 8850.00 Arco Alaska Inc. 3H-14A Version#1 Minimum Curvature 41.00 RKB 76.00 Azi TVD (BRT) 39.92 5912.57 39.89 5929.44 39.86 5946.30 39.82 5963.17 39.80 5973.29 40.00 5980.14 40.42 5994.43 41.60 5998.10 45.12 6009.10 46.86 6016.36 50.91 6033.93 54.60 6050.60 57.98 6066.29 61.09 6080.91 63.98 6094.39 66.69 6106.68 69.23 6117.71 71.54 6127.43 73.95 6135,78 76.17 6142.73 78.32 6148.25 80.43 6152.31 82.50 6154;88 84.55 615196 85.00 6156.00 83.80 6156.00 82.27 6156;00 80.74 6156.00 79.20 6156.00 77.67 6156.00 76.14 6156.00 74.60 6156.00 73.07 6156.00 71.53 6156.00 70.00 6156.00 68.50 6156~00 67.00 6156.00 65.50 6156.00 54.00 6156.00 62.50 6156.00 61.00 6156.00 59.50 6156.00 58.00 6156.00 56.08 6155.12 54.14 6152.50 52.16 6148.14 50.12 6142.08 48~00 6134.35 44.45 6126.40 41.00 6119.67 37.65 6114.22 34.36 6110.06 31.12 6107.23 27.92 6105.74 26.00 6105.50 25.38 6105.50 TVD (MSL) 5836.57 5853.44 5870.30 5887.17 5897.29 5904.14 5918.43 5922.10 5933.10 5940.36 5957.93 5974.60 5990.29 6004.91 6018.39 6030.68 6041.71 6051.43 6059.78 6066.73 '6072.25 6076.31 6078.88 6079.96 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 6080.00 ~6079.12 6076.50 6072.14 6066.08 6058.35 6050.40 6043:67 6038.22 6034.06 6031.23 6029.74 6029.50 X Y 501798.17 6003245.36 501810.01 6003259.52 501821.84 6003273.68 501833.66 6003287.84 501840.75 501845.43 6003301.93 501854.46 6003312.61 501856.69 6003315.18 501863.69 6003322.59 501868.63 6003327.36 501882.03 6003339.03 6003350.29 .501913.07 6003361.08 501930.55 6003371.34 501949.22 6003381.03 501969.01 6003390.10 501989.80 6003398.51 502011.50 6003406.21 502034.01 502057.20 6003419.35 502080:98 6003424.72 502105.22 6003429.26 502129.80 6003432.95 502154.61 6003435.76 502160,10 6003436.26 502179.49 6003438.15 502204.31 6003441.18 502229.03 6003~.87 502253.65 6003449.22 502278.14 6003454.22 502302.48 6003459.88 6003466.19 502350.68 6003473.14 502374.50 6003480.74 502398.10 6003488.97 502421.48 6003497.82 502444.62 6003507.28 502467.50 6003517.34 502490.11 6003528.00 502512.43 6003539'.24 502534.45 6003551.07 502556.16 6003563.47 502577.53 6003576.43 502598.49 6003590.02 502618.88 6003604.23 502638.58 6003618.98 502657.46 6003634.18 502675.42 6003649.75 502692.53 6003666.14 502708.86 6003683.82 502724.31 6003702.69 502738.80 6003722.62 502752.23 6003743.51 502764.53 6003765.21 502771.33 6003778.58 6029.50 502775.67 6003787.59 Page 1 4189.38 4200.45 4493.24 5038.521 5062.59! 5086.97: 5111.52 5136.09 5160.54 5175.09 ARCO ver # 8875.O0 8900,00 8925.00 8950,00 8975.00 9000.00 9025.00 9050.00 9075,00 9100.00 9125.00 9150.00 9175,00 9200.00 9225.00 9250.00 9275.00 9300.00 9325,00 9350.00 9375.00 9400.00 9425.00 9450.00 9475.00 9500.00 9525.00 9550.00 9575.00 9600.00 9625.00 9650.00 9675.00 9700.00 9725,00 9750,00 9751.24 23.82 22.27 20.72 19.16 17.61 16.05 14.50 12.94 11.39 9.83 8.28' 6.72 5.17 3.61 2.06 0.50 2.03 3.57 5.10 6.63 8.16 9.70 11.23 12.77 14.30 15.83 17.37 18.90 20.44 21.97 23.51 25.04 26.58 28.11 29.65 31.18 31.26 6105.55 6105.66 6105.82 6106.03 6106.30 6106.62 6107.00 6107.43 6107.92 6108.45 6109.04 6109.69 6110.38 6111.13 6111.93 6112.77 6113.66 6114.58 6115.54 6116.52 6117.54 6118.59 6119.66 6120.77 6121.90 6123.06 6124.24 6125.45 6126.69 6127.94 6129.22 6130.53 6131.85 6133.19 6134.55 6135.93 6136.00 6029.55 6029.66 6029.82 6030.03 6030.30 6030.62 6031.00 6031.43 6031.92 6032.45 6033.04 6033.69 6034.38 6035.13 6035.93 6036.77 6037.66 6038.58 6039.54 6040.52 6041.54 6042.59 6043.66 6044.77 6045.90 6047.06 6048.24 6049.45 6050.69 6051.94 6053.22 6054.53 6055.85 6057.19 6058.55 6059.93 6060.00 502786.08 502795.87 5028O5.03 502813.56 502821.45 502828.69 502835.28 502841.21 502846.49 502851.09 502855.03 502858.30 502860.89 502862.81 502864.05 502864.61 502865.17 502866.40 502868.29 502870.85 502874.07 502877.95 502882.49 502887.69 502893.54 502900.03 502907.17 502914.95 502923.36 502932.39 502942.05 502952.31 502963.19 502974.66 502986.72 502999.36 503000.00 6003810.31 6003833.31 6003856.57 6003880.06 6003903.78 6003927.71 6003951.81 6003976.09 6004000.52 6004025.09 6004049.76 6004074.54 6004099.39 6004124.30 6004149.25' 6004174.23 6004199.20 6004224.15 6004249.06 6004273.91 6004298.67 6004323.35 6004347.90 6004372.33 6004396.61 6004420.72 600'!. ~.~.~. .64 6004468.37 6004491.87 6004515.15 6004538.17 6004560.92 6004583.39 6004605.56 6004627.42 6004648.94 6004650.00 5208.72 5232.50I 5256.06 5279.39 5302.47~ 5325.27 5347.79 Page 2 C T Drilling BOPE ~ CT Injector Head I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection I ---- 7" Riser Otis 7" WLA , , Quick Connect------I I i '~ Annular BOP5000(Hydril),7-1/16"psi WP ID Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~ Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7'1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold inner Annulus Outer Annulus ARCO Alaska, Inc. (1797-1798, 0D:3.500) Mandrel/Valve 1 (2882-2883, 0D:5.390) Gas I.ift MandrelNalve 2 (5311-5312, OD:5.390) Gas Lift Mandrel/Valve 3 (6753-6754, OD:5.390) Gas Lift Mandrel/Valve 5 (7629-7630, 0D:5.750) TUBING (7639-766O, OD:3.500, ID:2.992) TUBING (7660-7841, 0D:3.500, ID:2.992) Production Mandrel/Valve 6 (7710-7711, OD:5.390) Per[ (7758-7763) Per[ (7768-7798) NIP (7817-7818, . 0D:3.500) PKE (7832-7833, 0D:6.151) TUBING (7841-7859, 0D:2.875, ID:2.441) sos (7859-7860, 0D:2.875) Per[ (7882-7902) Per[ (7917-7929) Per[ (7954-7974) GKA 3H-14 3H-14 APl: 1501032009200 SSSV Type: Camco Annular Fluid: I'TRDP'IA'ENc' Reference LOg:I Last Tag:! 7714 · Last Tag Date: 14/12/99 Well Type: PROD Orig Completion: 12/14187 Last WlO: 8/27/90 Ref Log Date:t 'rD: 8250 ftKB Max Hole Angle: 48 dog ~ 7100 Angle @ TS: 148 deg ~ 7767 Angle @ TD: !41 deg @ 8250 Rev Reason: GLM BY VG Last Update: 1/4/00 i Casing String. CONDUCTOR Size 16.000 Casing String Size 9.625 Casing String Size 7.000 Tubing String Size 3.500 3.500 3.500 Top I Bottom TVD Wt Grade 0 [ 115 115 62.50 H-40 -SURFACE Top Bottom 0 3455 -PRODUCTION Top 0 TVD 1 Wt Grade 3001 36.00 J-55 Bottom TVD Wt Grade 8220 6352 26.00 J-55 Bottom TVD 5939 - TUBING 2.875 Perforations Summa~ Top 0 7639 Thread Thread 7639 7660 5953 7660 7841 6076 7841 7859 6088 Thread Wt Grade Thread 9.20 I J-55 BTC AB MOD 9.30 J-55 AB MOD 9.20 J-55 BTC AB MOD/MoD EUE AB 6.50 J-55 EUE 8RD AB MOD Interval TVD Zone Status FeetlSPFI DateI Type I Comment 7758 - 7763 6019 - 6023 UNIT D 51 10 5/16/8811PERF 15" Csg Gun, 120 deg. phasing 7768-7798 6026-6046 C-4,=UNIT 30 1015116/88IIPERF 5" Csg Gun, 120 deg. phasing 7882-7902 6104-6118 A-3 201 12~I0/29/8{IPERF 12118" Ener Jet, 30deg. Dhasing . 7917 - 7929 6128 - 6137 A-2 12 12 ~10/29/8{ IPERF 2 118" Ener Jet, 30 deg. phasing 7954 - 7974 6155 - 6169 A-1 20 415/16/8811PERF 4 112" Csg Gun, 135 deg. phasing Gas Lift MandrelsNalves Stn MD TVD Man I Man VMfr VType VOD Latch Port TRO Date Vlv I I I Mfr I TYPe ] I I' I I I i Run _[Comment 1 t 28621 26011 Camco I KBUG I I GLV I 1.0 leK-2 10.1251 13311 6/24/98~ : - -2I 53111 43271 CamcoI KBUG I I GLV I 1.0 I BK-2 10.1561 13421 6/24/98/ 3 I 67531 53411 CamcoI KBUG I I GEV I 1.0 1BE-2 10.1881 13551 6/24/98--[ 4 I 72s01 56961 CamcoI KBUG I I DMY I 1,0 I BK-2 10.0001 01 8/27/90 I ' 51 76291 59321 Camco l MMG-2 I I OV I 1.5 IRK 10.1561 01 6/24198 I : Production MandrelsNalves Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date VIv I Mfr I Type I I t I I I Run JComment '6 7710 5987 Camco KBUG CV 1.0 BK:2 0.000 0 1/4/00 CLOSED Other'(plugs, .equip., etc.) - JEWELRY (TBG STRING 7660' on Down from Previous Com 31etlon (5 ID 2.812 3.000 3.000 2.810 2.350 3.250 2.250 2.441 2.441 Depth lTVDI Type I Description 1797 t 17761 SSSV I Camco 'TRDP-1A-ENC'. 76601 59531 PBR I Baker ' 76741 59631 PKR I Baker'FHL' 7817 t 60591 NIP I Otis OPLN Ported Landing Nipple. 78181 60601 SLEEVE lOfts comingling sleeve set 12/15/98 78321 60691 PER lOfts 'WD' 75491 60811 NO G° t Camco'D' Nipple 7859 6088 SOS I BOT "7860 6089 TTL General Notes Date Note -7/1__4/__99. Confirmed apparent collapsed tubing ¢~ 7740' SLM (7752' RKB). /~RCO Alaska, Inc. PRUDHOE BAY UNIT DISBURSEMENT P.O. BOX 102776 ANCHORAGE. AK 99510-2776 ~UNT PAGE 1 OF 1 FEBRUARY 2. 2000 TRACE NUMBER: 225126820 CHECK NUMBER: 225126820 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3OO1 PORCUPINE DRIVE ANCHORAGE AK ~01 AMOUNT PAID : $100.00 PAY ENTITY: 0201 VENDOR NO: N00072020221 INQUIRIES:(907) 263-442214988 (FAX) P.O. BOX 103240 ANCHORAGE, AK 99510-3240 01/28/00 VRC128005dD04 '/116POOO15dD $100.00 $0.00 $100.0f FILING FEE FOR FFR~ZT TO DRILL NSK ~IDETRACK 3H-14A RECEIVED "-' '~ 8 ~-000 Al~a Oil & Gas Cons. ~mission Chicago, .,!il i':i' ,:::~RAcE":i!:.':~U~E~? .... ,T I~N t STATE OF ALASKA [ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILl. 20 AAC 25.005 la. Type of work:. Ddl, E] Reddl, r~ lb. Type of well. Exploratory r~ Stratigraphic Test E] Development Oil [~] Re-entry E] Deepen E] Service [~ Development Gas [~ Single Zone r~ Multiple Zone E] 2. Name o! Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 76 feet 3. Address 6. Property Designation Kuparuk Field P.O. Box 100360~, Anchorage, AK 99510-0360 ADL 25531/ALK 2657 Kuparuk Oil Pool 4. Location of well at su~ 7. Unit or property Name 11. Type Bond (see 2O AA¢ 25.0251) 1155' FNL, 4997' FEL, S'~,~12N, R8E, UM Kuparuk Unit Statewide At top of productive interval '~. 8. Well number Numb;~2~.27,'~'-z~ 3593' FNL, 1777' FEL, SEC. 1, T12N,~, UM 3H-14A ~.~ 2287' FNL, 652 FEL, Sec 1, T12N, R8E, UM "~ April 1, 2000 $ 12. Distance to nearest property line I 13. Distance to ~est well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) ADL 25630, 652' @ TD feetI No Close Appro~h feet 2560 9751 M D / 6136 'rVD 16. To be completed for deviated wells ~. 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 7690' MD Maximum hole angle~° Maximum surface 3250 psi~l At total depth (TVD) 3845 psi~l @ 6047' 18. Casing program % Setting Depth size Specifications Quantity of Cement Hole Casin~l Weic, lht Grade Couplinc, I Length \"~MD Top Bottom TVD MD TVD (include sta~le dataI 2-3/4" 2-3/8" 4.6 L-80 FL4S 2401' 73`%5~ 5743' 9751' 6136' 12 bbls 19 'pTr;sbe~)ve~lPlce~;~ ;~ornRs~lml' aRr; 'entrY' an d Deep e n OPe rat I°n s' Total Depth: measured 8250 feet Plugs (measured~ Collapsed Tubing Tag @ 7752' MD on 7/14/1999. true vertical 6374 feet Effective Depth: measured 7752 feet Junk(measured, \ Casing Leng;~Ue vert, Scailze Cemente6d015 feet MeasUred dep,~ CONDUCTOR 115', 16" 200 Sx AS I ~15', 115', SUR. CASIN(3 3379 9-5/8" 1350 Sx AS III & 400 Sx Class (3 3;~,5, 3001, PROD. eASING 8144' 7" 800 Sx Class G & 175 Sx AS I 822~ 6351 RECEIVED Perforation depth: measured 7758' - 7763'; 7768' - 7798'; 7882' - 7902'; 7917' -- 7929';7929'; 7954' -7954' - 7974'.7974'. ~ , truevertica~ 60~6'-6022'; 6025'-6046'; 6103'-61~7'; 6126'-~36'; 61~'-616S'. Ala~[10il&GasC0as Commi~ion 20. Attachments Filing fee ~1 Property Plat D BOP Sketch r~l Dive,er Sketch E] Drilling prog~m r~l Ddlling fluid pregr.,e,~ Time vs depth plot D Refraction analysis D Seabed report r'"] 20 AAC 25.050 requirements 21. I hereby certi~ foregoing istr/,q.e~"a'~.. ~.~rrect tothe best of my knowledge Questions? CallDanKar~@ 263-4837. '~~) .... O ~ 50- a/'O 3' 24~)~;~'2-' -- O i Ifor other require,rn~nts Conditions of approval Samples required E] Yes ,~ No Mud log required E] Yes ~ No Hydrogen sulfide measures E] Yes ~No Directional survey required ~YesD No .e.u redwo,< ngpressuretorBOPE 1--12U; El 3u; El 5u; El ou;l-I rTI3500ps forcTu Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate STATE OF ALASKA { 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._ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 76 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratk~raph~_ Anchorage, AK 99510-0360 service_ Kuparuk Unit 4. Location of well at surface 8. Well number 1155' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM (asp's 498655, 6o0o5oo) 3H-14 At top of productive interval 9. Permit number / approval number 3593' FNL, 1777' FEL, SEC. 1, T12N, R8E, UM (asp's 501875, 6003344) 187-123 At effective depth 10. APl number 50-103-20092 At total depth 11. Field / Pool. 3338' FNL, 1560' FEL, Sec. 1, T12N, RSE, UM (asp's 502091, 6003597) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8250 feet Plugs (measured) Collapsed Tubing Tag @ 7752' MD on 7/14/1999. true vertical 6374 feet Effective depth: measured 7752 feet Junk (measured) true vertical 6015 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 200 sx AS ~ 115' 115' SUR. CASING 3379' 9-5/8" 135o Sx AS m & 4OO Sx C~ass G 3455' 3001' PROD. CASING 8144' 7" 8oo Sx Class G & 175 Sx AS I 8220' 6351' Perforation depth: measured 7758' - 7763'; 7768' - 7798'; 7882' - 7902'; 7917' - 7929'; 7954' - 7974'. true vertical 6018' - 6022'; 6025' - 6046'; 6103' - 6117'; 6128' - 6136'; 6154' - 6168'. Tubing (size, grade, and measured depth 3-1/2", 9.3#, J-55 Tbg @ 7841' MD; 2-7/8", 6.5#, J-55 Tbg O 7859' MD. Packers &ssSv (type & measured depth) BAKER FHL Packer O 7674' MD; OTIS WD Packer @ 7832' MD. CAMCO TRDP-1A-ENC SSSV ~ 1797' MD. 13. Attachments Description summary of proposal ~X Detailed operations program __ BOP sketch .__X 14. Estimated date for commencing operation 15. Status of well classification as: February 29, 2000. 16. If proposal was verbally approved Oil .__X Gas __ Suspended __ Name of approVer Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Dan Kara @ 263-4837. Signed ~.~~_.. ~'~ .~'~.~'~--O~,. ,,itlo: AAl Coil Tubing Drilling Suporvisor Date ~'~/~S~"/~ Br ~ *" '~1' - "~,[/~.~ PreDated by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I ' Approval no. Plug integrity _ SOP Test _ Location clearance __, ~(~ -- {~ ~/~ Mechanical Integrity Test_ Subsequent form required 10- Approved by order of the Commission ~ Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE :t STATE OF ALASKA i,, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of uest: andon_X Suspend_ Operational shutdown _ Alter casing _ Repair well _ Plugging _X Change approved program _ Pull tubing _ Re-enter suspended well _ Time extension _ Stimulate _ Variance _ Pedorate _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1155' FNL, 4997' FEL, Sec. 12, T12N, RSE, UM At top of productive interval 3593' FNL, 1777' FEL, SEC. 1, T12N, R8E, UM At effective depth At total depth 3338' FNL, 1560' FEL, Sec. 1, T12N, R8E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ (asp's 498655, 6OO05O0) (asp's 501875, 6003344) (asp's 502091, 6003597) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. unit or Property name Kuparuk Unit 8. Well number 3H-14 9. Permitnumber/approvalnumber 187-129 10. APInumber 50-229-20092 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SUR. CASING 3379' PROD. CASING 8144' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) Size 16" 9-5/8" 7" 825O 6374 7752 6015 feet Plugs (measured) feet feet Junk (measured) feet Cemented 200 Sx AS I 1350 Sx AS III & 400 Sx Class G 800 Sx Class G & 175 SxAS I Collapsed Tubing Tag @ 7752' MD on 7/14/1999. Measured Depth True verticalDepth 115' 115' 3455' 3001' 8220' 6351' 7758' - 7763'; 7768' - 7798'; 7882' - 7902'; 7917' - 7929'; 7954' - 7974'. ORIGINAL RECEIVED 6018' - 6022'; 6025' - 6046'; 6103' - 6117'; 6128' - 6136'; 6154' - 6168'. 2000 3-1/2", 9.3#, J-55 Tbg @ 7841' MD; 2-7/8", 6.5#, J-55 Tbg @ 7859' MD. BAKER FHL Packer @ 7674' MD; OTIS WD Packer @ 7832' MD. CAMCO TRDP-1A-ENC SSSV @ 1797' MD. Ala~a 0il & Gas Coas. Commission Anc~0rage 13. Attachments Description summary of proposal _~X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: February 29, 2000 16. If proposal was verbally approved Oil __X Name of approver Date approved Service Signed /~" ~-~ Title: AAI Coil Tubing Drilling Supervisor Bru~e E. Smith. P.E. Gas m FOR COMMISSION USE ONLY Suspended m Questions? Call Dan Kara @ 263-4837. Pre?amd b~ Paul Rauf 263-4990 Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance _ Mechanical Integrity Test_ Subsequent form required 10- ...' Commissioner Approval, Do. Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE WELL PERMIT CHECKLIST FIELD & POOL , ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells.'~. ........ Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party .................... Operator has appropriate bond in force.~ .'~4~. .......... Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... /<'~_ COMPANY ,~~/'5 WELL NAMF_~-/~Z'/~ PROGRAM: exp~dev //' redrll ~ serv~wellbore seg ann. disposal para req~ 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... GEOL AREA ~('"') UNIT# (~/.//~,o~') ON/OFF SHORE N N N 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs, do they meet regulation .......... = ~_ DATE _ 26. BOPE press rating appropriate; testto ~~ ~/~J 5/~-O~ 27. Choke manifold complies w/APl RP-53 (M~ 84) ........ II ~ ' ' 28. Work will occur without operation shutdown ........... I1~ 29. Is presence of H2S gas probable ................. JJ 'GEOLOGY 30. Permit can be issued w,o hydrogen sulfide measures ..... JJ~ 31. Data presented on potential overpressure zones ..... 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 GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: . TE~ ~/~.. C)~ CO t~l,~ ' Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. ~. No special'effort has been made to chronologically organize this category of information. · ; · ,. **** REEL HEADER **** MWD 03/03/05 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 00/11/16 97356 01 1 3/4" TINY *** LIS COMMENT 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 7680.0000: STOP.FT 8700.0000: 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. 3H-14APB1 Kuparuk River Unit 1155' FNL, 4997' FEL North Slope Alaska Baker Hughes INTEQ 1-3/4" TINY - Gamma Ray 22-Nov-00 501032009270 Description SECT. 12 TOWN.N 12N RANG. 8E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 76 DMF . KB EKB .F 76 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) All Gamma Ray data (GRT~X) presented is realtime data. (4) Well 3H-14APB1 was drilled to TD @ 8700' MD (6100' SSTVD) on Run 5. (5) Well 3H-14APB1 was kicked off @ 7680 MD (5967' SSTVD) on Run 1 from the original borehole of Well 3H-14. (6) The interval from 8680' MD (6102' SSTVD) to 8700' MD (6100' SSTVD) was not logged due to sensor to bit offset. (7) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). As per PA1 documentation received via e-mail on 24-Sep-02, the MWD Gamma Ray was tied to the parent gamma ray in the field during logging. (8) A Magnetic Declination correction of 26.12 degrees has been applied to the Directional Surveys. (9) Well 3H-14APB1 was plugged back due to an inability to return to bottom. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAPR4A 1 21.95 2 22.57 3 21.40 4 21.40 5 21.40 6 21.76 7 21.40 DIRECTIONAL 26.77 27.39 26.22 26.22 26.22 26.58 26.22 CURVE SHIFT DATA BASELINE, MEASURED, N/A N/A EOZ END DISPLACEMENT N/A Tape Subfile: 1 Minimum record length: Maximum record length: 73 records... 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN Philips Alaska Inc. WN 3H-14APB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COM~4ENT 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 a PDC Log. 3. The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). As per PAI documentation received via e-mail on 24-Sep-02, the MWD Gamma Ray was tied to the parent gamma ray in the field during logging. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 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: 25 Tape File Start Depth = 7680.000000 Tape File End Depth = 8700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 34 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 Philips Alaska Inc. WN 3H-14APB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data contains the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRCX GRCX GRAX 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: [F ] 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 1 GRCX MWD 68 1 API 2 ROPS MWD 68 1 F/HR Total Data Records: 49 Size Length 4 4 4 4 Tape File Start Depth = 7680.000000 Tape File End Depth = 8700.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 00/11/16 97356 01 58 records... 54 bytes 4124 bytes **** REEL TRAILER **** MWD 03/03/05 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS DEPTH GR 7680.0000 -999 7680.5000 52 7700.0000 112 7750.0000 97 7800.0000 86 7850.0000 126 7900.0000 62 7950.0000 84 8000.0000 84 8050.0000 85 8100.0000 97 8150.0000 75 8200.0000 66 8250.0000 70 8300.0000 53 8350.0000 69 8400.0000 60 8450.0000 80 8500.0000 96 8550.0000 84 8600.0000 42 8650.0000 85 8700.0000 -999 ROP .2500 -999.2500 .3821 -999.2500 .8330 89.4430 .8400 5.7010 .0860 74.5180 6220 38.3000 4480 65.1760 5770 122.1600 7530 67.9240 7160 120.0600 3820 127.2860 4700 125.3400 7160 19.3990 7230 123.6930 3250 120.9340 6400 119.1840 7112 120.9820 8420 91.0420 8990 121.4400 7830 120.1720 4040 126.4840 5300 124.8390 2500 45.0000 Tape File Start Depth = 7680.000000 Tape File End Depth = 8700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 7680. 7680. 7700. 7750. 7800. 7850. 7900. 7950. 8000 8050 8100 8150 8200 8250 8300 8350. 8400 8450 8500 8550 8600 8650 8700 0000 2500 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 GRCX -999.2500 -999.2500 112.8330 97.8400 86 0860 126 6220 62 4480 84 5770 84 7530 85 7160 97.3820 75.4700 66.7160 70.7230 53.3250 69.6400 -999.2500 80.8420 96.8990 84.7830 42.4040 85.5300 -999.2500 ROPS -999 -999 89 5 74 38 65 122 67 120 127 125 19 123 120 119 120 91 121 120 126 124 45 .2500 .2500 .4430 .7010 .5180 .3000 .1760 .1600 .9240 .0600 .2860 .3400 .3990 .6930 .9340 .1840 9820 0420 4400 1720 4840 8390 0000 Tape File Start Depth = 7680.000000 Tape File End Depth = 8700.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS