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Home My WebLink About201-098 Imag( '~roject Well History' File Cover{ ,ge 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. ~:~(~ L - _~_~ Well History File Identifier Organizing I~o,.~l [] f Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA / Diskettes, No.I [] Other, No/Type BY: BEVERLY ROBIN VINCENT ,~HERY~. WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation / x 30 = ~ + BY: BEVERLY ROBIN VINCENT SHERYL(~ WINDY /-'- = TOTAL PAGES Production Scanning Stage t PAGE COUNT FROM SCANNED FILE: .Z~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~//YES - ~ BY: Stage 2 IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS COMI~LETE 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 General Notes or Comments about this file: DATE: Is~ Quality Checked 12/10/02Rev3NOTScanned.wpd ConocoPhillips a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri14, 2010 Mr. Dan Seamount Alaska Oil and Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ~~~~~~ APR ~ 7 201Q ~l~lta Oil & has Conn Cotruniasion A.AI~'lOMQ~' a°` ~ °~ ~. 33_ o~ Over the last couple of weeks we have been scanning our data base to confirm we were up to date on our sealant 10-404's. In doing so, we discovered the 10-404 notifications for Wells 1C- 22, 2X-04, 3J-07 and 3J-16 were missing. Please accept our apology for not sending them in a timely manner. The attached spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Roger Winter at 907-659-7506, if you have any questions. Sine ely, ~ Roger Winter ConocoPhillips Well Integrity Field Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/4110 1 C-22.2X-A4.3J-~7 & 3J-16 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corcosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1C-22 50029231270000 2022220 NA NA NA NA 42.5 7/1/2007 2X-04 50029209950000 1831180 SF NA 6" NA 30 5/12/2007 7A 50029214380100 2010980 13' 2.75 1'4" 618!2008 9.77. fi/21t2008 3J-16 50029214980000 1852900 36'2" 6.25 2'7" 6/8/2008 7.65 6/21/2008 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~~ ~1AY 0 ~ ?009 REPORT OF SUNDRY WELL OPERATIOMfdska Oii & ~,~ ,. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ nNfiIISSfQII Other AnCI Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ 1 e Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ~ ` Exploratory ^ 201-098 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21438-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 76' 3J-07A ' 8. Property Designation: 10. Field/Pool(s): ADL 25630 ~ Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7741' feet true vertical 6461' feet Plugs (measured) Effective Depth measured 7642' feet Junk (measured) true vertical 6398' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURFACE 3414' 9-5/8" 3490' 3426' PRODUCTION 7557' 7" 7633' 6409' LINER 1086' 4-1/2" 7740' 6466' Perforation depth: Measured depth: 7390'-7425', 7440'-7485', 7505'-7520', 7575'-7585' true vertical depth: 6275'-6294', 6303'-6328', 6339'-6348', 6378'-6383' ~ 33`y~ ~ ~~l ~~'~ `~t~ ~ ;;tt(~ `t. ~UU~ ~ ;~ 61R3. ~,u i ~ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6654' MD Packers & SSSV (type & measured depth) Baker SAB-3 pkr, Baker ZXP liner top pkr @ 6610', 6654' Camco 'DS' nipple @ 493' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 242 889 984 -- 134 Subsequent to operation 330 1111 758 -- 170 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^.r Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer Signature -~' Phone: 265-6471 _ Date ~ ~""' ~~ ' s ~' `~ Pre aced b Sharon Allsu Drake 263-4612 „~.~----~ ~ ~ ~. ~!~ Y ~°~ . ~ S~ 3 Form 10-404 Revised 04/2006 ~ '~ Submit Original Only ~~~(~f "~ KU P '~ -- ConocoPhillips ~ well Attributes _ -- ' 4P;SitB fKi WellboreAPl/UWl Field Name I Well Status ~ . , i 500292143801 IPROD KUPARUK RIVER UNIT C mead H2S (ppm) Data IAnnotahon End Date PM ---_- ~- SSSV: NIPPLE 5 s s 90 1!1/2009 (Last WO: 6111 _ _weilC g 3J,~,7p, s15rzo _ _ Schema0c ~ Ac1u 4 0 0 a al A Cation Depth (ftK6) 'End Date Annotation Last Tag' WLM 7,583.0 ~ 3127/2009 Rev Reason: ADD PERF C_ asinn~ Strings String OD ~ String ID I Set Depth I Set Daptl ~ Casing Description (in) (inl '. (flKl Top (HKB) (HKB) CONDUCTOR, tts CONDUCTOR 16 15.062', 0.01 115.01 SURFACE 95/8 A.650' 0.0'. 3,490.0 ~I NIPPLE, 693 PRODUCTION 7~ 6.151 OO 7,6330 LINER 41/21 3.9581 6,654.0 7,740.0 Tubing Strings String OD String ID Set Depth Set Dept1 GAS LIFT._ Tubing Description (in) tin) Top (kK8) (ftKB) (fiK 2.595 TUBING 31/2 2.992 00 66540 Ocher in hole ( Top Depih Ail Jewelry: Tubin '~ g Run 8 Retrievable, Fish,. i (ND) Top Incl Top (k KB) (ftKB) (°) Description II Comment suRF3aso - 493 493.0 0.13 NIPPLE IICAMCO'DS'NIPPLE 2,595 2 595.01 1 11.14 GAS LIFT ~CAMCO/KBMM-211/GLV/BK-5/.156 GAS LIFT, - - - 4,083 3,904.51 38.94 GAS LIFT CAMCO/KBMM-211/GLV/BK-5L188 a.o63 5,2551 4,740.0 1 42.78 GAS LIFT CAMCOIKBUG/1IOVBK-5/25/I Co 6,021 i 5,309.9 41.26 GAS LIFT CAMCOIKBUG/1/DMY/BK-5f// Con 6,5731 5,730.7 39.33 GAS LIFT CAMCO/MMGI7.5/DMY/RK!!/ Com1 G~5255- - - 6,5871 5 741 6 39.27.NIPPLE CAMCO'DS' NIPPLE 6,5941, 5 747.0 1 1 39.24~PBR (BAKER 80-00 PBR 4' SEAL _ _ 6,609'' S 758.5 38.92 SEAL 'BAKER KBH-22 80-DS-00 ANCHO GAS uFT. ___ _ 6,610, 5,759.3 38.92 PACKER !BAKER SAB-3 PACKER 8-00 X 32 s,62t ~ 6.6531 5.792.8 1 38.85 NIPPLE CAMCO'D' NIPPLE 3J-07A Act Bim (ftKB) 7,741.0 Rig R I se Dale 10I11/198~ End Date 5,793.5 ID 2 GASUFT,-_ 6,654 5,793.5 38.85 SEAL BAKER SEALASSEMBLY'GBH-22'w/locator 6/10/2001 3.00 6,5]3 _... - -- - 6,678 - - 5,812.2 38.81 SBE BAKER 800 SEAL BORE - EXTENSION 6/10/2001 4.00 7,642 6413.51 57.72iCOLLAR 6/10/2001 3.95 _.. 7,738 - 6464.6 _. 57.91ISHOE ~ _ __ --- 6/10/2001 3.95 _ NIPPLE.6se]- Perforat ions & Slots I ' snot i I o ~ ) r p (rvD) Btm vD Den: T p (HKB) Bt (kK8) (HKB) (ftKB) Zone ~ D t (sh Type C t PBR, sssa j 7,390 7,425' 6,274.81 6,294 4 A-3, 3J-07A 4/11/2009 6 0 APERF 2 1!8" POWER EJ 145 deg phase ~ 51 6,303.0 6,308 7 A-2, 3J-07A ,,4/5/2009 6.0 APERF 2 1!8" Power EJ +/ 45 deg phase ~.490 -~ 6,308.7 6,317 1 A-2, 3J-07A - 4!4/2009 ~ 6.0 APERF 2 1/8" POWER EJ +l- 45 deg phase 7,465 ~ 7,485 6,317.1 6,328 3 A-2, 3J-07A 6/19/2001 4.0 (PERF 12.5' HC, ALT BH-DP Chrgs, 180 tleg SEAL, 6,609 - ., ~ ~ ph L-- - - ~ 7,505 7.520' 6,339.4' 6,347.6 A-2, 3J-07A 4/4/2009 6.0 APERF 2 1/8' POWER EJ +!- 45 deg phase PACKER. 6.610-- 7,5751 7,585 6,377.6 6,383.0 A-1, 3J-07A 14/4/2009 I 6 OAPERF 2 1/8" POWER EJ +/-45 deg phase Stimula tions 8 Treatmen ts - -. __ I -. _. P M To a th P P ~t ; P NIPPLE. 6.653 '~ DeP<h Depth ~ D) D I 1 ' I (ftK6) (ftKB) (HKB) (HKB) Type i Date Comment _ PACKER, sss4- "~ 7,465.0 7 485.0 6,317.1 'A' SAND FRAC 6,328.3: 6/23/2001 ~, Placetl 193475 lbs. 16120 8 12/18 proppant behind SEAL, 6.654 ~ :,... l ( __. - pipe, 10 ppa on peels. ~ I Notes: General End D to 4 ~ Safety __ '= Annotation sBE.6.6]6 F =-. I 5/25/2005 1NOTE WAIVERED WELL: IA x.OA COMMUNICATION FRAC, ],d65 (PERF, __ 7,465-].665 APERF, ],505-].520 APERF. ],575-],565 PRODUCTION, 7.633 COLLAR. ],642 ~ - SHOE, 7.736 LINER. 7,740, ],141 3J-07A Well Work Summary DATE SUMMARY 3/27/09 TAGGED AT 7583' SLM. DRI D TO 7585' RKB WITH 20' x 2.63" DUM~UN. READY FOR E/L. 3/31/09 ATTEMPTED TO PERFORATE 7575'-7585' WITH 2 1/8" POWER ENERJET GUN. DUE TO PRIMACORD BEGIN DAMAGED WHILE RUNNING IN HOLE. DETONATOR FIRED, PRIMACORD FIRED LOW ORDER. NO SHOTS FIRED. /' 4/4/09 PERFORATE WITH 2 1/8" +/-45 POWER ENERJETS LOADED 6 SPF FROM 7575'-7585', 505'-7520', AND FROM 7450'-7465'. WELL LEFT SHUT IN TO CONTINUE PERFORATING ON 05-APR-2009. 4/5/09 PERFORATE WITH 2 1/8" POWER ENERJETS LOADED +/-45 DEG AND 6 SPF FROM _7440'-7450'. PERFORATING GUNS FIRED LOW ORDER ON ATTEMPTS TO PERFORATE FROM 7390-7425'. 4/11/09 PERFORATE INTERVAL FROM 7390'-7425' IN TWO RUNS WITH 2-1/8" POWER ENERJET, 6SPF, +/- 45 DEG PHASING 4/20/09 PULLED 3/16" ORIFICE @ 5255' RKB (BAD CHECK VLV). SET 1/4" ORIFICE IN THE SAME. JOB COMPLETE. f ,, J j / ,; 07/24/08 ~, NO. 4792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ ,~~~ ~~ ~ ~ 2~~$ Attn: Christine Mahnken ATTN: Beth ~~~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1A-06 12080402 INJECTION PROFILE ~ - ( 07/06/08 1 1 3C-17 11964626 SFRT (~~- 07/12/08 1 1 1Y-04 12096505 INJECTION PROFILE - t7 07/13/08 1 1 i G-O6 12061729 INJECTION PROFILE a d ` 07/13/08 1 1 i F-06 12096506 PRODUCTION PROFILE - ~ 07/14!08 1 1 3M-08 12096516 SBHP SURVEY 07/21/08 1 1 3M-09 12096515 SBHP SURVEY (p - 07/21/08 1 1 3N-13 12096517 SBHP SURVEY v C (o - 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFILE ~~ = 07/16/08 1 1 1 F-06 12096510 PRODUCTION PROFILE - /~( 07/17/08 1 1 2A-02 12096511 INJECTION PROFILE 07/18/08 1 1 3J-17 12096514 SBHP SURVEY ~ U !~ ~~{$'} ~ 07/20/08 1 1 3J-07A 12097409 _ SBHP SURVEY + ~ ~ ~~~~ 07/20/08 1 1 3C-15A 12097406 _ USIT ~ '~ 07/17/08 1 1 2A-05 12096512 SCMT l.(- 07/19/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _Inserts\Microfilm _ Marker.doc 10/31/05 Schlumbepgep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 SCANNED NOV 2 3 2005 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk '- Well Job# Log Description Date BL Color CD 1 R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1 D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 ./ 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 -' 2C-04 11022934 INJECTION PROFILE 10/14/05 1 "~M_07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01 A 11072922 INJECTION PROFILE 10/26/05 1 1 R-1 0 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 US IT 10/19/05 1 1 J-154 11022931 USIT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: ~ ðiw DATE: I g (fov ~l Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ 1"'_ .,~~ Permit to Drill 2010980 MD 7741 TVD DATA SUBMITTAL COMPLIANCE REPORT 7/8/2003 Well Name/No. KUPARUK RIV UNIT 3J-07A Operator CONOCOPHILLIPS ALASKA INC 6461 / Completion Dat 6/19/2001 '"~- Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-21438-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital T~ype M~e.ej:lia Interval Log Log Run OH / (data taken from Logs Portion of Master Well Data Maint) Dataset Fmt Name Scale Media No Start Stop CH Ver LIS Verification Pdf Cn See Notes Directional Survey ~~urvey SBHP Survey/PRES/ TEMP 1 6802 7695 Open FINAL CH FINAL OH 5 FINAL 7328 7512 OH I 6824 7741 Case Received Numl~er 1/3/2002 ~_,.1,e~08 6/19/2001 6/19/2001 7/30/2001 12/6/2002 ~1~7 Comments Directional Survey, Paper Copy MWD Survey, Digital Data 7328-7512 BL, Sepia Digital Well Log Data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis ~-"Y~- R ~. c.~.iv~.d ~ Daily History Received? ~ Formation Tops ~ N Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 11, 2002 RE: MWD Formation Evaluation Logs 3J-07A, AK-MM-10179 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3J-07A: Digital Log Images 50-029-21438-01 1 CD Rom RECEIVED DEC 0 6 £002 Alaska 0~I & Gas Cons. Commi~ion '~ '~-o 7 Pr o WELL LOG TRANSM1TYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 18, 2001 MWD Formation Evaluation Logs 3 J-07A, AK-MM- 10179 1 LDWG formatted Disc with verification listing. API#: 50-029-21438-01 PLEASE ACKNOWLEDGE. RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO TIlE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. · Anchorage, Alaska 99518 Date: Signed: RECEIVED ,.!),.~,l 0 $ 200:> Ai~k~ Oil & Gas (;on,s, ~'~'r~i~o~ SENT BY: , , 7-25- 1 · 2'laPM ; PHILLIPS AK INC--,. 907 276 7542;# 1/ 2 Phone: 283-4612 Fa]( To.* Mr. Steve Davies From-. Sharon AIIsup-Dmke Fax:. 9-907-276-7542 ~' Dale: July'2$, 2001 Phone: 793-1224 Pages: 1 Re: Perf Info for 3J-07A CC: [] Urgent [] For Review [] PI~aN Comment [] Please Reply [] Please Recycle ,Comments: Mr. D~vie~: Here is the additional information on the perf history for 3J-07A as requested. If you have any questions, please feel free to call me at 263~4612. Thanks, Sharon : SENT BY: 7-2~- 1 · 2'16P~ ; PHILLIPS AK INC--,. 907 276 7~42:# 2/ 2 Date 06/19101 Well Na 3J-07A Service Type ELECTRIC LINE Desc of Work PERFORATE AND SBHP Supervisor CHANEY Campier J~ Accident I-- Injury J'- Spill r- Summary Upcoming J-- Job Num 0519011557,2 Unit SWS 2128 Contractor Key Perso SWS-JOHNSON Successful r~ Initial Tbg Press 0 Initial Int Csg Press 0 Initial out Csg Press 0 AFC 999674 0 Prop 230DS36J, Uploaded to Sep Final Tbg Press 1250 Final Int Csg Press 0 Final Out Csg Press 0 PERFORATED 7465' TO 7485' WITH 4 SPF 2.5" HSD 180 DEG ALTERNATING BH-DP CHARGES, SBHP AT MID PERF, 7475'= 4107.1 TEMP= 167,1 DEGF Date printed: 07/25/01 at: 14:21:09 RECEIVED JUL 2, 5 2001 'AJsBJ(~ Oil & ~a~ ~O/llL Anchorage ' PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 T. Brockway Phone (907) 263-4135 Fax: (907) 265-6224 July 19, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 3J-07A (201-098) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 3J-07A. If you have any questions regarding this matter, please contact me at 263-4135 or Brian Noel at 265- 6979. SincereJ~, /~ T. Brockway /t~,/ Interim Drilling Engineering Supervisor PAI Drilling TAB/skad RECEIVED JUL 1 9 2.001 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASr~A OIL AND GAS CONSERVATION COMMisSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~i Gas D Suspended D Abandoned D Service D 2. Name of Operator ;L.r,u;,~,~,Ta~,~,.,.,~ :7. Permit Number Phillips Alaska, Inc. ~ 201-098 3. Address ~.-~ 8. APl Number P. O. Box 100380, Anchorage, AK 99510-0380~ 50-029-21438-01 4. Location of well at surface ~ 9. Unit or Lease Name 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM ,~~ (asp's 519545, 6002573) Kuparuk River Unit At Top Producing Interval.i/ -',,,"J ,-, ~rJ'k'T-~ ! 10. Well Number --~zJ-L2/ '--'-'-'-'-'-'-'-'-~ ~ (asp's 517684, 6000057) 3J-07A 1621' FNL, 1309' FEL, Sec. 9, T12N, R9E, UM1 .~-, At Total Depth~ ~:~ 11. Field and Pool 1777' FNL, 1369' FEL, Sec. 9, T12N, R9E, UM ~ ---'-'~'~--'-- ~: (asp's 517625, 5999902) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 75.6' feetI ADL25630 ALK2563 Kuparuk River 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 June 4, 2001 June 7, 2001 June~l~,""~ 2001~x~'~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 7741' MD / 6461' TVD 7642' MD / 6398' TVD YES [~] No [~I N/A feet MD 1700' (approx) 22. Type Electric or Other Logs Run GR/Res/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surf. 115' 24" 183 sx AS II 9.5/8" 36# J-55 Surf. 3490' 12.25" 1005 sx AS III & 295 sx Class G 7" 26# J-55 Surf. 7633' 8.5" 435 sx Class G & 250 sx ASI 4.5" 12.6# L-80 6654' 7740' 6.125" 40 bbls 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) 4.5" 6654' 6610' & 6654' 7465'-7485' MD 6302'-6313' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7465'-7485' 39962# 16/20 and 153513# 12/18 carbolite behind pipe 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 10, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 7/10/2001 18.5 hrs Test Period > 939 340 1441 104I 362 Flow Tubing Casing Pressure Calculated GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 196 psi not available 24-Hour Rate > 1035 276 1474 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A JUL 1 9 2.00 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKE 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 Kuparuk C 7137' 6111' Base Kuparuk C 7206' 6152' N/A Top Kuparuk A 7365' 6245' Base Kuparuk A 7590' 6370' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify ~at the following is,t,~.and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed Title Interim Dr Iling En,qineedn.q Supervisor Date . Prepared by Sharon AIIsup-Dral~e INSTRUCTIONS General-' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 JUL 1 9 001 Alaska Oil & Gas Cons. Commission Anchorage PHILLIPS ALASKA INC. Page 1 of 4 Operations Summa Report Legal Well Name: 3J-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: 5/31/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Phase Description of Operations Code 16/1/2001 15:00 - 18:00 3.00 WELCTL NUND ABANDN Ru flow back lines to production injection system. Set in flow back tnks. Berm up around rig & flow back tnks. Press test flow back hard lines to 1000 psi. 18:00 - 21:00 3.00 WELCTL NUND ABANDN Retrieve bpv & vr plugs. Si & monitor / confirm well static. Initial before bleed down = SIP/3.5/3.5 x 7"/9.625/7" = 400/200 / 0 psi7 21:00 - 22:00 1.00 ABANDN SFTY ABANDN Pre job safety / ops meeting. Review hook uo into production injection system w/production personnel. 22:00 - 00:00 2.00 WELCTL CIRC ABANDN Disp well bore w/warm sea water @ 3.5 bpm / 500 psi. After 260 bbl fluid [composed of 10% crude & 90% sea water] cleaned up to moderately clean fluid - si & monitor well static for 15 minutes. X-over to recovering returns to flow back tnk & pump an additional 100 bbl sea water until returns clean [incomplete rpt time]. 6/2/2001 00:00 - 01:00 1.00 WELCTL CIRC ABANDN Complete circulating well bore to clean sea water. 01:00 - 04:00 3.00 WELCTL NUND ABANDN RD circulation lines in cellar & lines to surface flow back tank. Set bpv in tree, nd tree. Make up blanking plug to mandrel. Nu bope. 04:00 - 09:00 5.00 WELCTL BOPE ABANDN Function test bops. Test bope 250 / 5000 annular 3000 psi 5 min. Aogcc 24 hr notified - no show. NOTE: Unable to test lower pipe rams due to interference of stick up of blanking flange into lower pipe ram cavity. Will accomplish when out of hole. 09:00 - 11:00 2.00 WELCTL BOPE ABANDN Pooh w/test jt & blanking flange. Pull bpv. Rih w/Idg jt & pull hanger / tbg string to floor w/56k lbs to string, no ovger puli.Set wear bushing. 11:00 - 12:30 1.50 WELCTL CIRC ABANDN Start 180 bbl cir for bu, after 40 bbl away riser leaking, sd. 12:30 - 15:00 2.50 RIGMNT RGRP ABANDN Repair riser leak. 15:00 - 16:00 1.00 WELCTL CIRC ABANDN Restart cir for bottoms up, circulate 180 bbl @ 4 bpm / 450 psi. 16:00 - 21:30 5.50 ABANDN RTRV ABANDN Pooh w/existing completion, break out tbg accessories, visually insp threads, installing thread protectors on pin end & standing back. Recovered all completion from top seals in the seal assmby to hanger. The threads below the top seals were not damaged. There is no immediate evidence of any cut [partial or otherwise] in the 31.47' joint where the cut was attempted. Measurements of the "Baker Seal XO" [.33'], pup jt [6.11], Camco "W" nipple [1.95'] & full jt [31.47'] where cuts were located match w/old completion tally. 21:30 - 23:00 1.50 WELCTL BOPE ABANDN Complete bop test by testing lower pipe rams 250 / 5000psi. Set wear bushing. NOTE: Previously unable to test lower pipe rams wi blanking flange made up to mandrel - to tall, interferes w/closing rams. 23:00 - 00:00 1.00 ABANDh:TRIP ABANDN X-out floor equip for handling drill string. Pu csg scrapper on hwdp & dp tripping to 3.5" tbg cut @ sim of string. NOTE: Cut joint of tbg where cut was located in two 15.5' pieces - no Printed: 7/11/2001 4:30:13 PM PHILLIPS ALASKA INC. Page 2 of 4 Operations Summa Report Legal Well Name: 3J-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: 5/31/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Date From - To Hours Code Sub Phase Description of Operations Code 6/2/2001 23:00 - 00:00 1.00 ABANDI~ TRIP ABANDN evidence of attempted cuts. 6/3/2001 00:00 - 06:00 6.00 ABANDI~ TRIP ABANDN C. omplete tih w/bit / scrapper to tag top of pkr @ 6919' rkb Nordic 3. 06:00 - 09:00 3.00 ABANDI~ ClRC ABANDN Circulate bu @ 10 bpm / 1200 psi while cutting drlg line. After bu decrease rate to 3 bpm. Simultaneous ops: Cut & slip drlg line. 09:00 - 12:30 3.50 ABANDh TRIP ABANDN Pooh w/bit & scrapper. 12:30- 13:00 0.50 WALTON EQIP ABANDN Wo Schlumberger- flattire. 13:00 - 14:30 1.50 ABANDI~ RURD ABANDN Ru Schlumberger for junk basket run w/6.0 gage ring run. 14:30 - 16:00 1.50 ABANDh TRIP ABANDN Schlumberger trip junk basket to wi depth of 6885'. Smooth run, minor trash recovery in basket. Did not tag packer due to shape of junk basket & id of packer. 16:00 - 17:00 1.00 ABANDI~ TRIP ABANDN Schlumberger rih w/Baker cibp, run correlation log tieing in to cbl dated 10x10x1985. Set cibp @ 6849', 2' above collar @ 6851'. Pu 10 ', sit down confirming cibp in place. Pooh w/setting tool, no damage to same. Ld tools, rd schlumbergr. 17:00 - 18:00 1.00 WELCTL OBSV ABANDN SI w/blind rams. Test [charted] cibp / 7" csg to 3000 psi / 30 min. Aogcc notified - no show. 18:00- 18:30 0.50 ABANDh PLUG ABANDN Pjsm concerning running whipstock. 18:30 - 20:30 2.00 ABANDI~ TRIP ABANDN Rih w/whipstockmill out assmby, hanging up in well hd [wearbushing]. Pull milling assmby. Recover wear bushing. Incorrect bushing [6.125"] will not pass upper mill [6.151 "] Locate a bushing w/6.25" special bore. Check clearance on floor, Install same in stack. 20:30 - 00:00 3.50 ABANDh TRIP ABANDN Pick up milling assmby & make up to whipstock. Continue pu bha & dp tripping in hole. 6/4/2001 00:00 - 04:00 4.00 ABANDI~ITRIP ABANDN Complete trip to 6775', 75' above cibp. 04:00 - 05:30 1.50 ABANDI~ ClRC ABANDN Displace well bore & surface system to 12.5 ppg GEM mud - 8 bpm / 2400 psi. Used 25 bbl spacer pill between SW & GEM mud. 05:30 - 06:30 1.00 ABANDI~ PLUG ABANDN Orient tool face to 14deg left of high side. Pumping @ 8bpm / 2400 psi Set down incrimentaly to 25k lbs over string - anchor did not set. Repeated second time w/no result. Pulled pumps to 4.7 bpm [rnin mwd flow rate]/2000 psi, set down on cibp & set anchor @ 12k lbs. Continue to set down wt & shear off stud @ 30k lbs down wr. 06:30 - 09:30 3.00 ABANDI~ MILL ABANDN Cir / cond mud to 12.5 ppg. Large amts of fine sd on shakers, cleaned up in 1 hr. Erratic sw cut mud to 12.1 ppg noted. 09:30 - 18:00 8.50 ABANDh MILL ABANDN Begin milling csg @ 60 rpm / 3-4 k lbs, 2800 psi/5.5 bpm. Gradually increased rpm to 80, bit wt to 9k lbs, rpms to 80. torque leveled off to 9000ft-lbs 71000 fi-lbs. Continued to drlg formation to 6848'. Window: Printed: 7/11/2001 4:30:13 PM PHILLIPS ALASKA INC. Page 3 of 4 Operations Summa~ Report Legal Well Name: 3J-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: 5/31/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Date From - To Hours Code Code Phase Description of Operations 6/4/2001 09:30 - 18:00 8.50 ABANDN MILL ABANDN 6824 - 6836', open hole to 6848'. 18:00 - 19:30 1.50 WELCTL OTHR ABANDN Circulate cond mud for leak off test. 19:30 - 20:00 0.50 WELCTL TRIP ABANDN Pull milling assmby into csg [6800']. 20:00 - 22:30 2.50 WELCTL OTHR ABANDN Si on dp for FIT test. Made numerous attempts to run w/rig pumps, bleed back to 200 psi each time. Si chole / kill / mud manifold 2 X redundancy & use bope test pump. Test better but still bled to 200 psi. EMW = 12.5 ppg +{200}/[.052 x 5927'tvd] = 13.15 psi Unable to record vol pumped or recovered, however it was very small. 22:30 - 23:30 1.00 WELCTL ClRC ABANDN RIH to td & spot a 20 bbl "ultra" Iow fluid loss pill composed of gel, fluid loss agent, & light Icm. 23:30 - 00:00 0.50 WELCTL TRIP ABANDN Pooh w/milling assmby. NOTE: have recovered 220 lbs steel by 0600 hrs, cai steel to rec = 6' x 26 ppf = 156 lbs. Rate recovery decreased uniformally w/time, last 6 hr rec less than 20 lbs. 6/5/2001 00:00 - 03:30 3.50 ABANDI~ TRIP ABANDN Pooh w/milli'ng assmby. All mills in gage as run: lead mill = 5.625, middle = 5.875", upper mill 6.151". Clean out bop,s & service top drive. 03:30 - 04:00 0.50 WELCTL OTHR ABANDN Perform FIT test: si choke / kill / mud manifold w/2 x redundant valves. Use bop test pump. Impose 250 psi, after 5 min down to 230 psi, Held steady for 5 min @ 230 psi. EMW = 12.5 ppg + 230/[.052 x 5927' tvd] = 13.21 ppg EMW 04:00 - 05:30 1.50 DRILL PULD PROD Pick up additional 27 jts 3.5" dp & stand back in derreck. 05:30 - 08:30 3.00 DRILL PULD PROD Make up bha #3 & test mwd. 08:30 - 12:00 3.50 DRILL TRIP PROD RIH w/dp to top of window. 12:00 - 00:00 12.00 DRILL DRLG PROD Ream thru window-no problem-Drlg. & sliding. 6/6/2001 00:00- 12:00 12.00 DRILL DRLG PROD Drill from 7086-7220'. 12:00- 00:00 12.00 DRILL DRLG PROD Drill from 7220-7560'. 6/7/2001 00:00 - 06:00 6.00 DRILL DRLG PROD Drlg. from 7560 to 7740 MD. 6460 TVD. 06:00 - 08:00 2.00 DRILL ClRC PROD Pump hi Vis Sweep-Circ.-cond mud-Monitor well. 08:00 - 09:00 1.00 DRILL WIPR PROD Wiper Trip to Window @ 6810'. 09:00 - 11:00 2.00 RIGMNT RGRP PROD Service top drive & repairs to same. 11:00 - 12:00 1.00 DRILL OBSV PROD Well appears to be flowing small amount-observe & shut in same-90# on dp. 12:00 - 13:30 1.50 DRILL TRIP PROD RIH to 7740'. 13:30 - 18:00 4.50 DRILL ClRC PROD Circ. & cond hole for liner-build mud wt. to 13# while circ.-drill to 7740' while circ.. 18:00 - 19:30 1.50 DRILL TRIP PROD POH to shoe-no hole problems=hole taking correct amount of fluid. 19:30 - 20:00 0.50 DRILL ClRC PROD Pump dry job & blow down top drive. 20:00 - 23:30 3.50 DRILL TRIP PROD POH w/bha #3. 23:30 - 00:00 0.50 DRILL PULD PROD Lay down BHA #3. 6/8/2001 00:00 - 00:30 0.50 DRILL PULD PROD Finish Laying Down BHA #3. 00:30 - 04:00 3.50 CASE PULR PROD Rig up handling equipment & run 34 jts 4.5" 12.6# L-80 nsct csg. -liner hanger & packer. 04:00 - 09:00 5.00 CASE RUNL PROD RIH w/4.5" liner on 3.5" dp to 6725'. 09:00 - 10:00 1.00 CASE OTHR PROD Cim. capacity of liner & dp @ window-pick up & make up cement head Printed: 7/11/2001 4:30:13 PM PHILLIPS ALASKA INC. Page 4 of 4 ) Operations Summary Report Legal Well Name: 3J-07 Common Well Name: 3J-07A Spud Date: Event Name: ROT- SIDETRACK Start: 5/31/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 SUb Phase Description of OPerations Date From - To Hours Code Code 6/8/2001 09:00 - 10:00 1.00 CASE OTHR PROD on 1 jt. dp & lay in 'V' door. 10:00 - 12:00 2.00 CASE RUNL PROD RIH w/4.5" liner to 7725'-pick up cement head jr.-make up same & rig up cement lines. 12:00 - 14:30 2.50 CASE ClRC PROD Circ. Condition mud as per program to 7740'-reciprocate same. 14:30 - 16:00 1.50 CEMEN'] PUMP PROD PJSM-Batch mix spacer & Cement-pump 5 bbls. CWl00-test lines to 4000#-pump 5 bbls. CWl00-Pump 40 bbls. 14.0# mudpush XL-pump 40 bbls. Class 'G' cement-15.8# Followed w/2 bbls. water to clear cement line. 16:00 - 19:30 3.50 CEMEN'] DISP PROD Displace cement w/rig pump-bump plug-set hanger & packer-release from liner-pump 10 bbls.mud long way-rig up & reverse out 11 bbls. cement-10 bbls. CWl00 & 40 bbls. mudpush. Circ. 2 volumes dp @ 10 bpm to clean cement out of dp. 19:30 - 00:00 4.50 DRILL PULD PROD PJSM-Pump dry job-poh laying down 3 1/2" dp. 6/9/2001 00:00 - 04:00 4.00 DRILL PULD PROD Finish laying down 3.5" dp-hwdp & dc,s. 04:00 - 05:30 1.50 DRILL OTHR PROD Pull wear ring-change out handling equipment-empty pipe shed-hold PJSM. 05:30 - 11:00 5.50 CMPLTN RUNT CMPLTN Run in hole w/3.5" completion as per program. 11:00 - 16:00 5.00 CMPLTN OTHR CMPLTN Attempting test on annulus & packer-Pump away @ 1.16 bpm @ 900#-check all surface equipment-sting in w/seal assembly-test down tbg. 3500# 15 mins. OK. (decision to run Retriev'o'matic on tbg. & test csg. 16:00 - 20:00 4.00 CMPLTN CIRC CMPLTN Circ. condition mud due to 10 bbl. loss to formation-stabilize wt. @ 12.8# to prevent flow back. 20:00 - 00:00 4.00 CMPLTN OTHR CMPLTN POH w/3 1/2" completion string for retriev'o'matic packer. 6/10/2001 00:00 - 03:00 3.00 CMPLTN TRIP CMPLTN RIH w/Retriev'o'matic packer to 4310'. 03:00- 03:30 0.50 CMPLTN DEQT CMPLTN Set Packer & test csg. 'OK' 03:30 - 05:30 2.00 CMPLTN TRIP CMPLTN Continue running in hole to 6654'-tag packer & set @ 6652'. 05:30 - 06:30 1,00 CMPLTN DEQT CMPLTN Test csg. to 3500# 15 mins. 'OK'-release packer-set 25k down on packer. 06:30- 08:30 2.00 CMPLTN OTHR CMPLTN Service top drive & cut drlg. line. 08:30- 12:00 3.50 CMPLTN TRIP CMPLTN POH w/packer & lay down same. 12:00 - 17:00 5.00 CMPLTN RUNT CMPLTN Rig up & RIH w/completion as per tbg. details, 17:00 - 19:00 2.00 CMPLTN PCKR CMPLTN Stab into seal bore & drop ball to set packer. 19:00 - 20:30 1.50 CMPLTN PCKR CMPLTN Set packer & test tbg. 3500# OK-test annulus 3500# OK. Shear PBR & shear Dump kill valve. 20:30 - 23:00 2.50 CMPLTN ClRC CMPLTN Pump sweeps & displace well w/seawater @ 7.5 bpm-3000#. 23:00 - 00:00 1.00 CMPLTN SOHO CMPLTN Space out-make up hanger & landing jt. Land hanger, 6/11/2001 00:00 - 00:30 0.50 CMPLTN SOHO CMPLTN Land hanger & rilds. 00:30 - 03:00 2.50 CMPLTN NUND CMPLTN Pull landing jt.-set BPV-nipple down bope & nipple up tree. 03:00 - 04:00 1.00 CMPLTN SEQT CMPLTN Test packoff to 5000#-test tree 5000#. 04:00 - 06:00 2.00 CMPLTN FRZP CMPLTN Pull test plug-rig up circ. hoses-pump diesel down annulus-'U' tube diesel. 06:00 - 07:30 1.50 CMPLTN OTHR CMPLTN Rig down circ. hoses-set BPV secure well-prep for rig move. (rig released @ 0730 6/11/01. for move to 3G-19A. Printed: 7/11/2001 4:30:13 PM Date 06/23/01 Well Na 3J-07A Service Type PUMPING Desc of Work A SAND FRAC Supervisor GOBER Complet Accident F Idury I-- Spill I~ Summary Upcoming F Job Num Unit 0519011557.2 AFC 999674 0 Prop 230DS3& Uploaded to Contractor Key Perso DS-GALLEGOS Successful ~ Initial Tbg Press 1200 Initial Int Csg Press 300 Initial Out Csg Press 0 Final Tbg Press 0 Final Int Csg Press 500 Final Out Csg Press 0 PUMPED POST-SIDETRACK A SAND FRAC - PUMP BREAKDOWN STAGE - MAX PRESSURE 7284 PSI AT 29.1 PSI - MAX RATE 35.8 PUMP SCOUR STAGE - GOOD PRESSURE DROP SEEN - PUMP DATAFRAC - INCREASE PAD TO 500 BBLS - PUMPED FRAC HAD NWBSO WITH 10 PPA CARBOLITE ON PERFS AND 10 PPA AT SURFACE - PLACED 39962 LBS 16/20 AND 153513 LBS 12/18 CAR BEHIND PIPE - 87% OF DESIGN PLACED IN FORMATION - LEFT 23291 LBS 12/18 IN WELLBORE - RECOVERED ALL TREESAVER R~ [Frac-Refrac] Date printed: 07/12/01 at: 11:15:44 14-J u n-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3J-07A Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,796.15' MD 'MD 7,741.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED Kuparuk River Unit North Slope, Alaska Kuparuk 3J, Slot 3J-07 3J-O7A Job No. AKJVIMfOf79, DEFINITIVE S UR VEY REPORT 14 June, 200f Your Ref: API500292143801 Surface COordinates: 6002572.61 N, 5f9544.67 E ('/0° 25' 05.4954" N, Kelly Bushing: 76. f5ft above Mean Sea Level f49° 50'26.8562"1/V) .sp=,r~r~j-sur].~- DRILLING e;ERVICE~;~ A HallibUrton Company Survey Ref: svy9564 Kuparuk. River Unit Measured Depth (ft) Incl. Azim. 6796.15 38.620 212.800 6828.00 38.400 2131710 6911.92 48.500 -212.170 7005.38 53.250 211.670 7098.24 54.110 208.120 Sub-Sea Depth (ft) 5823.97 5848.90 5909.74 5968.70 6023.71 7164.38 53.760 203.350 6062.66 7295.41 54.180 200.220 6139.75 7393.05 55.240 200.170 6196.16 7490.70 56.360 200.220 6251.04 7587.67 57.430' 200.990 6304.01 Sperry-Sun .Drilling Services Survey Report for 3J-O7A Your Ref: API50029214380f Job No. AKMMf0179, Vertical Depth 5900.12 5925.05 5985.89 6044.85 6099.86 6138.81 6215.90 6272.31 6327.19 6380.16 Local Coordinates Northings ' ' Eastings (ft) (ft) 1972.65 S 1596.26W 1989.23 S 1607.13W 2037.64S 1638.41W 2099.17 S 1676.73W 2164,02 S 1713.99W 2212.1'6 S 1737.20W 2310.54S 1776.51W 2385.34S 1804,03W 2461.13 S 1831.91W 2537.16 S 1860.50W DEFINITIVE Global Coordinates Dogleg Northlngs Eastings Rate (ft) (ft) (°/100ft) 6000595.79 N 517953.58 E 6000579.17 N 517942.75 E 1.908 6000530.68 N 517911.60 E 12.101 6000469.06N 517873.45 E 5.099 -6000404.11 N 517836.35 E 3.216 6000355.91 N 517813.26 E 5.853 6000257.43 N 517774.21 E 1.958 6000182.56 N 517746.90 E 1.086 6000106.69 N 517719.21 E 1.148 6000030.59 N 517690.82 E 1.288 North Slope, Alaska Kuparuk 3J Vertical Section 2537.59 2557.32 2614.65 2686.60 2760.49 Comment Tie On Point Interpolated 2812.53 2913.81 2989.32 3065,85 3142.99 7678.23 57.910 200.910 6352.44 7741.00 57.910 200.910 6385.78 6428.59 2608.63 S 1887.86W 5999959.05 N 6461.93 2658.30 S 1906.84W 5999909.32 N 517663.65 E 0.535 3215.81 517644.80 E 0.000 3266.41 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 80' RKB (MSL). Northings and Eastings are relative to 890' FSL & 564' FWL. Projected Survey Magnetic Declination at Surface is 26.079° (02-Jun-01) The Dogleg Severity is in Degrees per 100: feet (US). Vertical Section is from 890' FSL & 564' FWL and calculated along an Azimuth of 218.843° (True). Based upon Minimum Curvature type calcU, lations, at a Measured Depth of 7741.00ft., The Bottom Hole Displacement is 3271.48ft., in the Direction of 215.652,' (True). 14 June, 2001-f5:48 Page 2 of 3 Dr#lQ,est 2.00.08.005 Kuparuk River unit Sperry-Sun Drilling Services Survey Report for 3J-OTA Your Ref: API500292143801 Job No. AKMM10179, North Slope, Alaska Kuparuk 3J Comments Measured Depth. (ft) 6796.15 6828.00 7741.00 Survey tool program for 3J. O7A From Measured Vertical Depth Depth (ft) (ft) Station Coordinates TVD Northings Eastings (ft) fit) i (ft) 5900.12 1972.65 S 5925.05 1989.23 S 6461.93 2658.30 S To MeaSured Vertical Depth Depth (ft) .. 6461.93 0.00 0.00 -7741.00 Comment 1596.26 W Tie On Point 1607.13 W Interpolated 1906.84.W Projected SUrvey Survey Tool Description MWDMagnetic (3J-07A) .._ 14 June, 2001- 15:48 Page 3 of 3 DrillQ~lest 2.00.08.005 3J-07A sidetrack APD - H2S information Subject: 3J-07A sidetrack APB - H2S information \ -- ~) Date: Wed, 23 May 2001 14:05:46 -0800 From: "Brian D Noel" <bnoel@ppco.com> To: tom_maunder@admin.state.ak.us CC: "James A Trantham" <jtranth@ppco.com>, "Randy L. Thomas" <rlthomas@ppco.com> Tom - As discussed this morning, have not encountered H2S during drilling operations on 3J but it is present in the produced fluids. Per your request, the H2S concentration (ppm) measured each August in the production stream for well 3J-07 and the 3J drillsite average are: 3J-07 3J ave 1994 80 101 1995 110 170 1996 120 93 1997 95 95 2000 105 91 3J average: 7 wells 1994, 95 and 10 wells 1996, 97, 2000. Please let me know if you need additional information. Thanks - Brian 265-6979 1 of 1 5/23/01 2:44 PI~ ~KA OIL AND GAS CONSERVA~ION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-14.33 FAX (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Unit 3J-07A Phillips Alaska, Inc. Permit No: 201-098 Sur Loc: 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM Btmhole Loc. 1773' FNL, 1325, FEL, Sec. 9, T12N, R9E, UM Dear Mr. Trantham: 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ 3 ~ day of May, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Ddll r'~ Redrill [~ I ~b. Type of well. Exploratory r'~ Stratigraphic Test D Development Oil ~] Re-entry [~ Deepen E]I Service E] Development Gas r-] single zone [~] Multiple Zone r-] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 75.6, Pad 45.3 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25630 ALK 2563 Kuparuk River Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 890' FSL, 564' FWL, Sec. 3, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1612' FNL, 1267' FEL, Sec. 9, T12N, RDE, UM 3J-07A #59-52-180 At total depth 9. Approximate spud date Amount 1773' FNL, 1325' FEL, Sec. 9, T12N, RDE, UM May 29, 2001 $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) 1773' @ TD feetI 3J-03 1673' at 7712' feet 2560 7736' MD / 6459' TVD 16. To be completed for deviated wells 17. Anticipat~'ee-2Z).~AAC 25.035 (e)(2)) iKickoff depth: 6828 MD Maximum hole angle 58.8 Maximum surfl~ 3402 psig,....~At total depth (TVD) 4095' 18. Casing program Settin~l Depth size Specifications Top Bottom Quantify of Cement Hole Casin~l Wei~lht Grade couplin~l LenCh MD TVD MD TVD /include sta~e dataI 6.125" 4.5" 12.6# L-80 NSCT 1060' 6676' 5806' 7736' 6459' 26 bbs Class G 19. To be completed for Re,rill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 7650 feet Plugs (measured) .,~ Effective Depth: measured 7177 feet Junk (measured) true vertical 6201 feet ~I/!,,l:i ¥ ~l ~? 20 01 Casing Length Size Cemented Measured~.~ ~.~.ii ~ ¢' T. rue Vertical depth Conductor 80' 16" 183 sx AS II 115' ......... , .... ]lb" Surface 3460' 9.625" 1005 sx AS III & 295 sx Class G 3490' 3422' Surface Production 7603' 7" 435 sx Class G & 250 sx AS I 7633' 6561' Liner Perforation depth: measured 7128'-7134', 7158'-7165', 7279'-7300', 7322'- 7325',7325'- 7328', 7328'-7350' true vertical 6162'-6167', 6186'-6191', 6281'-6298', 6315'-6318', 6318'-6320', 6320'-6337' 20. Attachments Filing fee r~] Property Plat [~] BOP Sketch [~] Dive,er Sketch r~] Drilling program r'~ Ddlling fluid program r~] Time vs depth plot [~aefraction analysis [~ Seabed report ~ 20 AAC 25.050 requirements r~ ! 21. I hereby certify hat the foregoing is true and correct to the best of my knowledg~ Questions? Call Brian Noe1265-697~ Signed r~nthaf~m e ~ ~ Title: DrillingEnginoeringSuporvisor Dater Jar,~ e n ~ o-Draki Commission Use Onl) Permit Number APl number I Approval date ~--~,~ J~/ Ieee cover letter -~---(::~/'-' O ~'~ 50- ~:~--~'- ~_,/'~,/,~'-,~3/' '~ [for other requirements Conditions of approval Samples required r-~ Yes ,'~ No Mud Icg required / / E] Yes ~ No Hydrogen sulfidemeasures ~ Yes E] No Directional surveyrequired ~ Yes r-] No Required working pressure for BOPE r~2M; r~ 3M; [~ 5M; E] 1OM;El 1~ Other: by order of Approved by O~l~i~t(~!~'L ~IG~ED BY commiss,oner the commission Date ~_~' ~ ~..~.' t~ / !') T Pv :?',flOr Seamount Form 10-401 Rev. 12/1/85 · ORIGINAL Submit in triplicate A~'-' ""ation for Permit to Drill, Well 3J-07A Revision No~0 Saved: 17-May-01 Permit It- Kuparuk Well 3J-07A App//cation for Permit to Dr///Document MaxWell I~10 x i rlli z E Well VoluE Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2 a Location Summary ................................................................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b) ........................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................. 3 Requirements of 20 AAC 25. 005(c)(6) ................................................................................................... 3 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 4 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 4 10. Seismic Analysis ...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ................................................................................................ 5 Requirements of 20 AAC 25. 005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ...................................................................................... 5 3J-O7A PERMIT IT. DOC ORIGINAL Printed: 17-May-01 14. 15. AT "'at/on for Permit to Drill, Well 3J-07A Revision No.0 Saved: 17-May-01 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 Attachments ............................................................................................................. 6 Attachment I Directional Plan ................................................................................................................ 6 Attachment 2 Well Schematic .............................................................................................. 6 lw . Well Name Requirements of 20 AAC 25.005 (f) Each we//must be/dent/fled by a unique name designated by the operator and a unique APZ number assigned by the commission under 20 ~C 2b~ 040(b). For a well w/Th muLhple well brand~e.~ each branch must 5imHarly be identified by a unique name and number by adding a suffix to the name d~ignated for the well by the operator and to the number &~?gned to the well by the ~mmi~fon. The well for which ~his Applic~tion is submi~ed will be designated ~s 3]-07A. Location Summary Requirements of 20 AAC 25. 005(c)(2) An application for a Permit to Dr/Il rnust be accornpanied by each of'the f'o//owifLq item.$ except for an item a/ready 0/7 file w/th the commission and identified fi7 the application; (2) a p/at identifying the property and the prope/ty's owners and showing (A)the coordinates of the proposed/ocati~x~ of the well at' the surface, at' the top of each ol%jective formation, and at total depth, referenced to governmental section line. s: (B) the coordinates of the proposed location o? the well at the surface, referenced to the state plane coordinat'e system for this state as' ma!rite#zed by the National Geodetic Survey in ~he National Oceanic and Atmospheric Administration/ (C) the proposed depth of the well at the top of'each objective fbrmation and at total depth/ Location at Surface I 890' FSL~ 564' FWL~ NG$ Coordinates North/rigs: 6,002,572.6 East/rigs: 519,544.7 Sec 3~ T12N~ R9E~ UM RKBElevati°nl Pad Elevation 75.6' AMSL 45.3' AMSL Location at Top of 1612' FNL, 1267' FEL, Sec 9, T12N, R9E, UM ,Productive ]:nterval (Kuparuk "Al" Sand) NG$ Coordinates Neasured Depth~ RKB: 7536' North/rigs: 6,000,070 East/rigs: 517,724 Total Vert/ca/ Depthz RKB: 6356' Total Vertical Depth~ 55: 6280' Location at Total Depth I 1773' FNL~ 1325' FEL Sec 9~ T12N~ R9E~ UM NG$ Coordinates Neasured Depth~ RKB : 7735' North/rigs: 5,999,909 Eastings: 517,667 Total Vertica/Depth~ RKB: 6459' Total Vertical Depth~ SS: 6384' and (D) other infbrmation required by 20 AAC 25.050(b); Requirements of 20 AAC 25. 050(b) Ifa we//is to be intentionally deviated, the application for a Permit to Dr///(??x'm 10-40.~) must (1) include a p/at, drawn to a suitable sca/e, showi/Lg the path of the proposed weffbor~ #~d~ing all adjacent wellbores w/thin 200 feet of any potion of the proposed we/~r Please see Attachment 1' Directional Plan 3J-O7A PERMIT IT. DOC Page 2 of 6 ORIGINAL Printed: 17-May-01 w m 1 Sm ~," Al?' "'at/on for Permit to Drill, Well 3J~O7A it~ ~ Revision No.0 Saved: 17-May-01 and (2) for all wells w/thin 200 feet of the proposed we#bore (A) t/st the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each nam~ operator has been furnished a copy of the application by ce~ified mai~' or (B) state that ~e applicant is the only affected owner. The Applicant is the only affe~ed owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the foliowirLq items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as requ/i'ed by 20 ~C 25.035, 20 ~C 25.03~ or 20 ~C 25.037, as applicable; Please reference BOP schematics on file for Nordic 3. ~ Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dr/II must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the con?n'Hssion and identified irt the application: (q) irtformation on dc#ling hazar(/~ #Tc/uding (A) the maximum downho/e pressure that may be encountered, criteria used to detem?ine it, and maximum potent/a/suffbce pressure based on a methane ~gradient; The expected reservoir pressure in the Kuparuk sands for the 3.]-07A wellbore replacement sidetrack is 4085 psi at 6300' tvd, 0.65 psi/ft or 12.5 ppg EMW (equivalent mud weight). This pressure was obtained from 33-07 and matches offset pressure data for the Kuparuk sands. The maximum potential surface pressure (MPSP) while drilling the sidetrack is calculated using above reservoir pressure, a gas gradient of 0.11 psi/fi, and A3 sand target mid-point 5' tvd: MPSP =(6300 fi)~(0.65 - 0.11 psi/fi) = 3402 psi (B) data on potent/a/gas zones;' The well bore is not expected to penetrate any gas zones. (C) data concerning potent/a/cau.%,s of hole problems such as abnormally geo..pressured st/~ta, lost circulation zones and zones that have a propensi~ fbr different/a/sticking; No significant drilling hazards anticipated, Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25. 005 (c)(5) An application for a Permit to DHII must be accompanied by earl? of'the fo#owing items; except fbr an item a/ready on file with ~mmis~Yon and/dent/fled in the app/ic~"~tion: (5) a description of the~~uct/ng tbrmation integrity test¢ as rec/uired under 20 ~C 25.030(f); Pedorm FIT test (0 ~3.2 ppg (e~e~ed ECD at window for ~2.5 ppg LSND mud) in accordance with the Kuparuk LOT/FI~hat Phillips Alaska has on file with the Commission. Casing and Cementing Program Requirements of 20 AAC 25. 005(c)(6) An applicaflt'~n fo/' a Pern?it to Dr/Il must be accon?panied by each of the/b/lowing items; except for an item a/ready on file w/th the c~mmissYon and/dent/f/ed in the app/ic~tion: (6) a complete proposed casing and cementing program as required by 20 AAC 25.03~ ,~zd a description of any slotted line5 pre- pedbrated line5 or screen to be installe~' 3J-O7A PERMIT IT. DOC Page 3 of 6 OHl ttvt L Printed:IT-May-01 . Sm , A~' "'at/on for Permit to Drill, Well 3J-07A Revision No.O Saved: 17-May-O1 Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/fO Grade Connection (ft) (ft) (ft) Cement Program 4-1/2 6-1/8 12.6 L-80 NSCT 1060' 6676'/5806' 7736'/6459' 26 bbls Class G w/ 3-1/2 9.3 L-80 EUE 8rd 6646' 30 / 30 6676' / 5806' additives Hod Diverter System Information Requirements of 20 AA C 25. 005(c)(7) An application for a Permit to Dr///must be accompanied by each o? the fo/lowing items, except for an item a/ready 0/7 file with the commission and identified in the a/ppi/cation: (7) a diagram and description of the diverter system as' required by 20/AC 25.035, un/es.s' this requirement is' waived by the comnTission under 20 AAC 2.$i 035'(h)(2)~ N/A - Sidetrack out of 7" with BOP installed. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application fbra Permit to Drill must be accompanied by e,.Tch of the fbi/owing items, except for an item a/ready on file w/th the commission and/dent/fled in the application: (8) a drilling fluid program, inc/udi/~g a diagram and description of the drilling/Tuid system, as r~quired by 20 AAC Drilling will be done with a LSND system having the following properties: Millin9 Dr/I1/nE Density (ppg) 12-13 12-13 Funne/Viscosity(sec) 45-60 45-60 Y/eld Point (cP) 25-30 20-25 Plastic Viscosity (lb/1 O0 sO 11- 25 11- 27 10 sec. Ge/(lb/lO0 sf) 8-13 7-13 10 min. Ge/(lb/lO0 sf) 10-20 10-20 API Filtrate (cc) < 6 < 6 pH 9-9.5 9-9.5 So/ids (%) 10-15 10-15 Diagram of Nordic 3 Mud System on file. Drilling fluid system of Nordic 3: Tandem Geolograph/Swaco Shale Shakers Mud Cleaner, Degassers, Fluid Agitators Pit Volume Totalizer (Visual and Audio Alarm), Fluid Flow Sensor Trip Tank Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dr/Ii must be accompanied by ~ch of the fo/lowing item.%, except for an item a/ready on file with the comn'zission and iden/ified in the application: (9) fo/' an exploraZory or stra~igraphic test we/l, a tabu/at/on setting out' the depths of predictec! abnom'~ally geo-pressured strata am' required by 20 AAC 25.033(f); N/A - Application is not for an exploratory or stratigraphic test well. 3J-O7A PERMIT IT. DOC 4 of 6 Printed: 17-May-01 ORIGINAL Ap" ' 'ation for Permit to Drill, Well 3J-O7A Revision No.O Saved: 17-May-01 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fo/Io~Yng items, except for an item a/ready on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test we//, a seismic refract/on or reflection analysis as required by 20 AAC 25. 061{a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25. 005 (c)(11) An application for a Permit to Dr///must be accompanied by each of the fo//owirLq itern.$ except for an item a/ready on file with the cornmission and identified in the application: (11) fbr a well dH/led f/om an ot'f~hore platform, mobile bottom-founded structure, jack-up Hg, o/' floating dr#ling vessel, an anNys/s of'seabed conditions as required by 20 AAC 25.061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25. 005 (c)(12) An applicaEon tbr a Permit to Dr/Ii must'be accompar#ed by each of the fo/lowing item~¢~ except' for an item a/ready on tile with the con?m/ss/on and iderNfied in the application: (12) evidence showirL~ that the requirern~.:nts of 20 AAC 25. 025 ('Bond/YLQ~¥~a~e been met; Evidence of bonding for Phillips Alaska, Tnc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application tot a Permit to DH// must be accompanied by each of the fo/lowing/tams, except fbr an item a/ready on file with the conzmLssion and/dent/f/ed in the application: The proposed drilling program is listed below. Please refer as well to Attachment 2, Well Schematic. 1. IVl]:RU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Verify well is dead. Circulate well to 12.5 ppg milling fluid through tubing cut at 6900' IVlD. 3. Set BPV. ND tree. NU and test BOPEF 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. 5. PU 7" Casing Scraper on DP and run through Bridge Plug setting depth. 6. RU E-line Unit. R]:H and set Bridge Plug at 6850' MD. Test bridge plug/7" casing to 3000 psi. 7. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, etc and R]:H. Orient and set whipstock w/MWD. Shear off whipstock bolt and mill window in 7" casing and 20' formation. Perform F]:T test to 13.2 ppg (expected ECD at window for ::[2.5 ppg LSND mud). POOH and LD milling · . assembly. Note: ]:f unable to obtain adequate FTT, squeeze window with cement, redrill and test again. 8. R[H w/6-1/8" bit, IVlWD / LWD, and steerable drilling assembly. Slide out window, kick-off and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH and lay down drilling assembly. 9. Run 4-1/2" liner to TD w/150' of overlap above top of milled window. 10. Cement liner in place, set liner hanger and liner top packer, circulate out excess cement and POOH laying down 3-:[/2" DP. 11. Pressure test casing and liner lap to 3000 psi for 30 min (Chart Test for State). 12. R[H w/3-1/2" completion assembly and sting into Seal Bore Extension below liner top packer. Space out. Displace well to seawater and land tubing. Test tubing and annulus to 3000 psi. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDIVlO Nordic 3. 3J-O7A PERMIT IT. DOC ORIGINAL Printed: 17-May-01 14. A~ "-at/on for Permit to Drill, Well 3J-O7A Revision No.O Saved: 17-May-01 Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dr/Il mustc be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application: (J4) a genera/descrip&'on of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AA£ 25.080 for an annular disposal opezation in the well,; Waste fluids generated while drilling the sidetrack will be hauled to a KRU Class I! disposal well. All cuttings generated will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The surface by production casing annulus was Arctic Pak with 55.5 bbls AS1 on 10/21/85, thus Phillips Alaska does not intend to request authorization for annular disposal operations. 15. Attachments Attachment I Directional Plan Attachment 2 Well Schematic. 3J-O7A PERMIT IT. DOC ORIGINAL Printed:Pl~7g"eMa6j/°'fO~ Kuparuk River Unit ~.., ~--?~~!~. ~'~i~i~:il Kuparuk 3~ S~~-~A ~'~:~*- REPORT ~' ~ 5 May, 2001 Your Reh ... Per Brian Noel wi Philli~ (KOP ~ 6828' MD) ~ordina~: ~257~61 N, 5f9~.67 E (70° 25' 05.3774"N, ~49° ~' 26.8876" C~rdina~ mlat~e to Pro~t H Reference: f~2572.6f N, f9~.67 E (GrM) Suffa~ ~o~ina~ relative to S~re: 149.97 N, 0.46 E ~r~) Kelly Bushing: 75.6~ a~ve Mean ~ Level Proposal Ref: pro9517 North 6600 Scale: linch = 200fl EastJngs 2000 1900 2400 2600 2~)0 3000 3200 3400 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 6828.00 38.402 213.708 5849.33 6843.00 40.028 6858.00 40.028 Sperry-Sun Drilling Services Proposal Report for 3J. O7A wp03 Your Ref: ... Per Brian Noel w! Phillips (KOP @ 6828' MD) Revised: 5 May, 2001 Local Coordinates Global ~d~.'~::~/~ ~leg Vertical Northings Eastings Northings ~a~§s oRate Section (ft) (ft) ..~.~. ~,. (ft) (/1 ooft) 5924.93 1989.52 S 160~2 ~~8.~ 517942.57 E 2464,16 ~617.84 W 6000562.88 N 517932.08 E 0.00 2483.01 1~.43 S 6900.00 41.783 211.502 5904.18 5979.78 ~~" 1632.56 W 6000539.62 N 517917.42 E 5.00 2510,17 7000.00 46.059 207.761 5976.20 605~f~) ~i:~:"03 S 1666.76 W 6000479.23 N 517883.38 E 5.00 2579.09 7100.00 50.440 204.528 6042. ~ 2156.00 S 1699.56 W 6000412.17 N 517850.76 E 5.00 2653.58 7200.00 54.900 201.683 6~D~~61:~_~ 2229.13 S 1730.69 W 6000338.96 N 517819.82 E 5.00 2733,06 7285.46 56.759 199.491 ~~ .~225.77 2296.08 S 1755.81 W 6000271.94 N 517794.88 E 5.00 2804,48 7360.32 58.759.~::~1 ~ 6~9.00 7422.0~?~.7_.5~*~.49 ~;'--'~ 7 500.0 ~~~?~_~199.491 7530.0~*~8.7-~ ~99.491 7535.78~ 58.759 199.491 6209.58 6285.18 6221.00 6296.60 6261.44 6337.04 6277.00 6352.60 6280.00 6355.60 2307.80 S 1759.96 W 6000260.21 N 517790.76 E 0.00 2816.89 2356.42 S 1777.17 W 6000211.54 N 517773.68 E 0.00 2868.34 2388.40 S 1788.49 W 6000179.54 N 517762.44 E 0.00 2902.19 2406.15 S 1794.77 W 6000161.77 N 517756.21 E 0.00 2920.97 2469.00 S 1817.01 W 6000098.86 N 517734.13 E 0.00 2987.49 2493.18 S 1825.57 W 6000074.66 N 517725.63 E 0.00 3013.07 2497.84 S 1827.22 W 6000070.00 N 517724.00 E 0.00 3018,01 North Slope, Alaska Kuparuk 3J Comment Top of Whipstock: Begin Dir ~ 11.0°/100ft (6-1/8" Hole Thru 7"{ 6828.00ft MD, 5924.93ft TVD 7" Casing End of Whipstock: Begin Rathole 40.028°: 6843.00ft MD, 5936.55 Begin Dir @ 5.00°/100ft: 6858.( MD, 5948.03ft TVD End Dir, Start Sail @ 58.759° · 7285.46ft MD, 6225.77ft TVD A3 A1 Target - T1 (3J-07), 50.00 Rad~u~ Current Target 7600.00 58.759 199.491 6313.31 6368.9t 7700.00 58.759 199.491 6365.17 6440.77 7735.78 58.759 199.491 6383.73 6459.33 2549.60S 1845.54W 6000018.19 N 517705.81E 0.00 3072.79 2630.20S 1874.07W 5999937.51N 517677.50E 0.00 3158.09 2659.04S 1884.27W 5999908.65 N 517667.36E 0.00 3188.61 Total Depth · 7735.78fl MD, 645! TVD 5-1/2" Liner 5 May, 2001 - 17:53 Page 2 of 8 DritlOuest 2.00.08.000 Sperry-Sun DnTiing Services Proposal Report for 3J-O7A wp03 Your Reft ... Per Brian Noel wi Phillips (KOP @ 6828' MD) Revised: 5 May, 200f Ail data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 75.6' RKB (MSL). Northings and Eastings are relative to 890~~ 564'~:~. The Dogleg Sevedty is in Degrees per 100 feet. ':'~i~_ ~!~ Vertical Section is from KOP @ 6828' MD and calculated along an Based upon Minimum Curvature type calculations, at a Measur~.Dept~35.7~-., The Bottom Hole Displacement is 3258.99ff., in the Direction ~.323°~e). Comments ~.~ Measured S t a t|o~i ~n a t e s Depth TVD<~---'¢~~ gs Eastings Comment 6~~ ~-~"5 1997.43 S 16t2.55 W 6~ .03 2oo5.50 s 1617.84 w 7~ ~;?~6~-~.77 2296.08 S 1755.81 W 77~78 6459.33 2659.04 S 1884.27 W Top of Whipstock: Begin Dir @ 11.0"/10Oft (6-1/8" Hole Thru 7" Csg): 6828.00ft MD, 5924.93ff TVD End of Whipstock: Begin Rathole @ 40.028°: 6843.00ft MD, 5936.55ft 'rvD Begin Dir @ 5.00°/10Oft: 6858.00ft MD, 5948.03ft TVD End Dh', Start Sail @ 58.759": 7285.46ff MD, 6225.77ft TVD Total Depth: 7735.78ff MD, 6459.33ft TVD North Slope, Alaska Kuparuk 3J 5 May, 2001 - 17:53 Page 3 of 8 DrillQuest 2.00.08.000 Kuparuk River Unit Formation Tops Formati on Plane P r o f i I e (Below Well Origin) Measured Vertical Sub-Sea Dip Dip Dir. Depth Depth (it) Deg. Deg. (ft) (It) 6189.00 0.000 6221.00 0.000 6277.00 0.000 Casing details 0.150 7360.32 6264.60 0.150 7422.02 6296.60 0,150 7530.00 6352.60 From ' ."-:'~ Measured Yerti~' M~a~d Yerticai Depth ~} ~:.'i' I~p[~? ~th ~(~,. : (it} (it) <S ~ ~ 6828.00 <s~~~ 773~.78 5924.93 6459.33 Sperry-Sun Drifting Services Proposal Report for 3J-O7A wp03 Your Ref: ... Per Brian Noel wi Phillips (KOP @ 6828' MD) Revised: 5 May, 2001 P · n e t r a ti o n ~P.. ~~.~ '~ Depth ~J~ ~__~.~-~gs Formation Name ~~ :~ 24~.15 S 17~.~ W ~ 2493.18 S 1825.57 W A1 Casing Detail 7" Casing 5-112" Liner North Slope, Alaska Kuparuk 3J 5 May, 2001.17:53 Page 4 of 8 DrillQuest 2,00.08.000 perry- un Anticollision Report CompanY: . phili~Ps ^laska~nc. .Field: Kuparuk River Unit ReferenCe Site: .KUparuk 3J Pad' ReferenCe Well: 3J-07 i Reference Wellpath: 3J'07A Date: 5/5/2001 Time: 114:04:46 Co'ordinate(NE) ReferenCe: Well: 3J-07, True North VertiCal CI'VD) Reference: 3J-07A 75.6 Db: GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 3J-07A wp03 & NOT PLANNED PR(~ Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 6828.00 to 7736.07 ft Scan Method: Tray Cylinder North Maximum Radius: 966.03 ft Error Surface: Ellipse + Casing Casing Points ::.MD. 6820.00 5918.66 7.000 8.500 7" 7739.00 0.00 5.500 6,125 5 1/2" Plan: 3J-07A wp03 Date Composed: 5/4/2001 KOP @ 6828' MD Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary < -- Offset Wellpath .> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ff ff ft ',,:,:,,;' :,:,' .i ,',~. ':,',' ','~ :, ,'', ,',','~ ' .',, ~ ' ,' "',' '',~, ', ',:,.: ,;,:' ,~ ,' ', ,:,;", ',' ,:' ~' ' ',-'.',,',;' ',, ,'' ,,'i:, ,'~ ~.' -; .',. '~, ': ,".~.,:::,,; ,~",', ,':' i~;!,:".~ ,', ~';,' '~: '. ,',":'. '; Kuparuk 3J Pad 3J-07 3J-07 V1 6899.85 6900,00 3.16 0.73 2,44 Pass: No Errors Site: Kuparuk 3J Pad Well: 3J-07 Wellpath: 3J-07 Vl Rule Assigned: No Errors Inter-Site Error: 0.00 ft Reference .MD TVD ft. ff Off, et Semi-Major Axi~ Ctr-Ctr No-Go Allowable · . MD TVD Ref Offset' TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ff ft ft deg deg in ft ft ft 6899.85 5979.66 6900.00 5981.53 19,37 19.61 3.97 152.46 6998,11 6050.49 7000.00 6060.68 19.27 19.78 356.20 148.37 7093.15 6114.00 7100.00 6139.90 19.17 1~96 353.26 148,51 7184.04 6169~74 7200.00 6218.78 19.10 20.23 351.66 149.52 7270.10 6217.70 7300,00 6297.42 19.05 20.53 350.61 150.72 7359.26 6263.98 7400,00 6376.10 19.17 20.92 350.55 151.04 7449.35 6310.66 7500.00 6455,40 19.33 21.26 350.65 151.14 7539,01 6357.12 7600.00 6535.14 19.52 21,66 350.71 151.20 7579.89 6378.31 7645.60 6571.50 19.62 21.88 350,73 151.22 3,16 0,73 2.44 Pass 16.65 1.19 15.46 Pass 39.56 1.65 37.91 Pass 70.16 2.09 68.08 Pass 107.70 2.50 105.20 Pass 149.83 2.58 147.25 Pass 193.23 2,58 190.65 Pass 237,52 2.58 234.94 Pass 257.71 2.58 255.13 Pass ORIGINAL Kuparuk River Unit 3J-07A (wp03) !:i:~:~:i:~:i:i:i:i:i:i:i:i:!:i~!:i:i:!:i:!:i:i:~:!:!:i:i:i:!:i:i:i:!:i:i:i:i:i:i:i:!:i:i:i:!:i:i:i:i:!:i:!:!:i:!:!:!:!:!:!:!:!:!:!:!:i:i:!:!:!:!:!:i:!: MD Inc Azim. SSTVD TVD N/S E/W Y X DLS V.S. Comment (ft) /Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft'~ (ft ~~::~~:::~;:;:::~::;::::::::~:::::~::::~~~::~:~:~::`~;:::~:::;:~:~:~::::::~:~:;:;:~:;:::~:~:~:~:::~:~:~:~~~~~~:~:::~:::~:::~:::~:~:~:::~:~:~~~~~~~::::~:~:::::::~:::::~:::::::::~:::::::~::;~:::~:::~: 6828.00 38.40 213.71 5849.33 5924.33 1989.52 S 1607.32 W 6000578.89 N 517942.57 E 2464.16 Top of Whipstock 6843.00 40.03 213.26 5860.95 5936.55 1997.43 S 1612.55 W 6000570.96 N 517937.35 E 11.00 2473.50 End of Whipstock 6858.00 40.03 213.26 5872.43 5948.03 2005.50 S 1617.84 W 6000562.88 N 517932.08 E 0.00 2483.01 Begin Dir 7285.46 58.76 199.49 6150.17 6225.77 2296.08 S 1755.81 W 6000271.94 N 517794.88 E 5.00 2804.48 End Dir, Start Sail 7360.32 58.76 199.49 6189.00 6264.60 2356.42 S 1777.17 W 6000211.54 N 517773.68 E 0.00 2868.34 A3 7422.02 58.76 199.49 6221.00 6296.60 2406.15 S 1794.77 W 6000161.77 N 517756.21 E 0.00 2920.97 A2 7530.00 58.76 199.49 6277.00 6352.60 2493.18 S 1825.57 W 6000074.66 N 517725.63 E 0.00 3013.07 A1 7535.78 58.76 199.49 6280.00 6355.60 2497.84 S 1827.22 W 6000070.00 N 517724.00 E 0.00 3018.01 Target 7735.78 58.76 199.49 6383.73 6459.33 2659.04 S 1884.27 W 5999908.65 N 517667.36 E 0.00 3188.61 Total Depth ::::::::::::::::::::::::::::::::~:~:~:~:~:::;:;:~:~:::::::::::::::::::::::~:;:~:;:~:::;:~:~:~:~:;:;:~:::::::;:;:::::::::::::::::::::::::::::::::::::::::::~:~:::i:i:i:i: KRU 3J-07A Producer Proposed Completion H. 3-1/2" 5M FMC Gen IV PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY tubing hanger with 3-1/2" L-80 EUE 8rd Mod pin down. G. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to surface. F. 3-1/2" Camco 'DS' landing nipple with 2.812" ID No-Go profile set at +/-500' MD. 9-5/8" 36~f J-55 @ 3490' E. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to 'DS' landing nipple w/ 3-1/2" x 1" Camco 'KBMM' mandrels w/DV's, spaced out as follows: GLM# MD TVD Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail. These depths need to be converted to Nordic RKB. 2 TBD TBD 3 TBD TBD 4 TBD TBD 5 TBD TBD 6 TBD TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. D. 3-1/2" x 1-1/2" Camco 'MMG' Mandrel w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6" L-80 handling pups installed on top and bottom of mandrel. C. 1 joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing B. 3-1/2" Camco 'DS' landing nipple with 2.75" ID and No-Go profile 4-1/2" liner top @ +/ -6680' MD Top of Whipstock & KOP at +/-6830' MD Window in 7" A. Baker 3-1/2" 'GBH-22' Tubing Seal Assembly w/10' of seals and special Iocator to locate in liner tie back sleeve. Locator 5.125" OD, seals 4.0" OD. 6' L-80 Handling Pup Joint installed. Liner Top Baker 5" x 7" 'C-2 ZXP' Liner Top Isolation Packer and 6' setting sleeve w/5" BTC Box Down. Baker 5" x 7" 'HMC' Hydraulic Liner Hanger w/5" BTC Pin x Pin. Baker '80-40' SBE (12' Length w/4" ID seal bore). 4-1/2" NSCT pin down. Solid Liner 4-1/2" 12.6# L-80 NSCT from Liner Hanger to Landing Collar. Bridge Plug at +/-6850' MD Abandoned Perfs C/B-Sand Per A-Sand Cement Future Perfs 4-1/2" NSCT Baker Landing Collar. 1 joint 4-1/2" L-80 NSCT tubing. 4-1/2" NSCT Baker Float Collar. 2 joints 4-1/2" L-80 NSCT tubing. 4-1/2" NSCT Baker Float Shoe. 7" 26~ J-55 @ 7633' Fill · . TD @ +/-7740' BDN 5/17/01 ORIGINAL PHILLIi '5 Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 May 18, 2001 Ms. Camille Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: Dear Ms. Camille Taylor: KRU 3J-07A 890' FSL, 564' FWL, Sec. 3, T12N, R9E 1612' FNL, 1267' FEL, Sec. 9, T12N, R9E 1773' FNL, 1325' FEL, Sec. 9, T12N, R9E Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 3J-07A. The well will be drilled and completed using Nordic 3. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids generated from drilling the sidetrack will be pumped down an approved KRU Class II disposal well and all drill solids will be hauled to an approved Prudhoe Bay facility for grind and inject disposal. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs Mark Scheihing, Geologist (20 AAC 25.071) 265-6072 If you have any questions or require further information, please contact Brian Noel at (907) 265-6979 or James Trantham at (907) 265-6434. Sincerely, James Trantham Drilling Engineering Supervisor R. ECE VEI " Oil & C.-..as C,::?,~s. ComrnJssin. r~ Anchorage American Express' Cash Advance Draft 134 , PAY TO THE ' , ' ~ . i ' Issued :b)~ lnr, egrat, ed Payment'S),srem, Inc. Englewood, Colorado I P~Fable m: Norwest Bank of Grand Junction - Downf. own. Grand Junction, Color*ado PERIOD,ENDING ,: ],O'2 ~,001, OO,: 55 ,,,O ~, ?500055~,,'O WELL PERMIT CHECKLIST FIELD & POOL COMPANY ,/~/////,~ ~. ? WELL NAME / - INIT CLASS ._/')~.z/ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 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 .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 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 .......... PROGRAM: exp dev ,~ redrll _"X" sew wellbore seg ann. disposal para req GEOL AREA ~ ~ 4:3 UNIT# .///~"O ON/OFF SHORE ,,~/l J -- IN YNt N DATE GEOLOGY DT ! · 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~)~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown. .......... 29.. Is presence of H2S gas probable ................. Y 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential over pressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory only]' ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (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 GEOLD,GY: ENGINEERING: UIC/Annular COMMISSION: w, 8¢s TE~~) ~. JMH ~~l~/~l Commentsllnstrucfions: I§ Z -I -I- c:\msoffice\word ian\diana\checklist (rev. 11/01//00) 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 APPEN. DIX~ No'special'effort has been made to chronologically ". organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Dec 10 16:30:49 2001 Reel Header Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN RECEIVED 0 ;S 200 Alaska Oil & Gas Cons. Cornr~issiar,: Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KRU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-10179 R. MCNEIL R. BOWIE 1ST STRING 2ND STRING 3J-07A 500292143801 Phillips Alaska Inc. Sperry-Sun Drilling Services 10-DEC-01 3 12N 9E 890 564 76.15 45.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 6824.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . THERE IS AN UNEXPLAINED GAP IN THE SROP DATA FROM ABOUT 6953'MD TO ABOUT 6969'MD. 5. DEPTH SHIFTING/CORRECTION STATUS OF MWD DATA IS PENDING PER E-MAIL FROM R.KALISH (SSDS) TO D.SCHWARTZ (PHILLIPS ALASKA) DATED 09/12/01. 6. MWD RUN 2 REPRESENTS WELL 3J-07A WITH API#: 50-29-21438-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7741'MD/6462'TVD. File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP) . $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 6802.5 RPX 6815.0 RPS 6815.0 RPM 6815.0 STOP DEPTH 7695.5 7702.5 7702.5 7702.5 RPD 6815.0 FET 6815.0 ROP 6827.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 7702.5 7702.5 7741.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 6802.5 7741.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR Min 6802.5 0.07 31 75 1 16 1 14 1 13 0 99 0 77 Max Mean Nsam 7741 7271.75 1878 398.74 35.8985 1801 209.13 104.25 1787 1690.94 7.38993 1776 1970.32 9.49324 1776 2000 17.5358 1776 2000 16.6269 1776 32.91 2.8867 1776 First Reading 6802.5 6827 6802.5 6815 6815 6815 6815 6815 Last Reading 7741 7741 7695 5 7702 5 7702 5 7702 5 7702 5 7702 5 First Reading For Entire File .......... 6802.5 Last Reading For Entire File ........... 7741 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6802 5 7695 5 RPX 6815 0 7702 5 RPS 6815 0 7702 5 RPM 6815 0 7702 5 RPD 6815 0 7702 5 FET 6815 0 7702 5 ROP 6827 0 7741 0 $ LOG HEADER DATA DATE LOGGED: 07-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 7741.0 TOP LOG INTERVAL (FT) : 6824.0 BOTTOM LOG INTERVAL (FT) : 7741.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 39.0 MAXIMUM ANGLE: 57.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : TOOL NUMBER PB01967GR4 PB01967GR4 6.125 6824.0 Water Based 12.50 54.0 9.4 1200 FLUID LOSS (C3): RESISTIVITY (OHM_M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 2.6 2.500 100.000 1.470 3.250 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 72.0 144.0 72.0 72.0 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 0HMM RPM MWD020 0HMM RPD MWD020 OHMM FET MWD020 HOUR Min 6802.5 0.07 31 75 1 16 1 14 1 13 0 99 0 77 Max Mean Nsam 7741 7271.75 1878 398.74 35.8985 1801 209.13 104.25 1787 1690.94 7.38993 1776 1970.32 9.49324 1776 2000 17.5358 1776 2000 16.6269 1776 32.91 2.8867 1776 First Reading 6802.5 6827 6802.5 6815 6815 6815 6815 6815 Last Reading 7741 7741 7695 5 7702 5 7702 5 7702 5 7702 5 7702 5 First Reading For Entire File .......... 6802.5 Last Reading For Entire File ........... 7741 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/12/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File