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Home My WebLink About196-113XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /(:~- )1_.~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Scanned by: Bevedy~ncent, TO R£-$C~ Nathan Lowell Date:l 3-.-]~---' Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALA5KA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 SCANNED SEP 0 82005 Anchorage, AK 99501 ~ l,/ \ \ \~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-704~,ji{you have any questions. /~ Sincerely, /;~ ¡i? /// ~;~/~l' /' . ' . f~.././J7.'~/~ #' ;,' JI .VVv d f M.J. toveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date ·3F.:o1 " ". K' 1a$;,-225... .'. I . NA . . . "'~ , :r'.<.I . '8'I~4iltb~6' 3F-02 1 85-226 24' 7,0 8/14/2006 7.5 8/21/2006 3~~Q3· , .18Ã~~~7 " ;< . ,1:a'4~: .. '.2::3 . I· . .;. . , 8t14}~0:b.6 . ; A A. ,,",' . : ,J ;,a¡.~'Þ12,âÐØ~;" '7 3F-04 185-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 ~ " 5:1 .; ! '. ". '.." ,.' '.ait412:QØ'Š· ' i ',' '1.5' . . ~ ~1nðø6'r '. , 1 85-244 Did not modify 3F..2Q;7·'· . ;' 1ß:~~2'~¡ ; I' ,,' .' kCf,' 6;6· 81<14/2:0.08 '. ' 7~5 . 8/21J2QØØ ,. 3F-08 1 85-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21/2006 3F,;Q~ I.,'· l8ß;~æO' Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 ·3F-11 , . .... ."185:'~72 " . '.,:. . .... " NA . NA..:, . ., [ . , 1.7 81~3J2.Ø,Q6- .' 3F-1 2 1 85-273 7'4" 1 .8 8/14/2006 6.2 8/23/2006 ;3E-::!t3', ; '. l~~1:'ré::,c I.' .' NA . ~ ',' 21."'·" '. .' "£Bi2g12Ð'fÍ~'~:" . ~ 1 85-292 Did not " ,~, £: " 1~l~.f~:~:: l., I 2A· . ", :, , " à~14'leo:â6;¡' .' ,- ']~f?~120,06' . 3F-16 196-151 6" NA NA 2.7 8/23/2006 ~ ~ ' 3." . , . " ',; '," ~8¡,(4liøa:/¡),~¡ ~, .... > .'àf~31.2ø:ø:ß>: . c, .0", " >"-.. ,~, '-'- - ". ~,., "" ~ .',>--.-' '- 4' NA NA 28 8/23/2006 ..3F,;J,9, " ·zcx4:Ö;1;Er:' .'.:.," ,.'. no :. . .... NÂ '';' 81~ ·NÂ::·· " .... '2 ',' ''fffi~gI20rJõ: '.. 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-2'1 ' " ,;, . 2ÒÔ'i2Ó3 45" . NA NA . . 31 ' ',812't];2Ôøè , RECEIVED A.U L; () ð 2006 08/01/06 Scblumbergel' AJaska Oil & Gas Cons. Corr~ A.nchc-rage NO. 3899 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ¡C,(c-ll3 (' '1 å. ?DOí) SC;'\'NNED TÙJ.5 "~" - Field: Kuparuk Well Color CD Job# Log Description Date BL 1 J-1 01 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1D-107 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1 Y -05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumberger RFCEIVED NO. 3638 Schlumberger -DCS ,jAN 0 9 2006 2525 Gambell Street, Suite 400 Com pany: Anchorage, AK 99503-2838 A TTN: Beth -\iaska o¡¡ \~ Gas ConS. Commission An-chcœ.ge Field: Well Job # Log Description Date BL 20-02 N/A SHUT IN BOTTOM PRESSURE 12/03/05 1 1A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE WIDEFT 12/27/05 1 2U-08 11166750 PROD PROFILE WIDEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V -11 11166736 PROD PROFILE WIDEFT 12/16/05 1 3Q-09 11166737 LDL 12/17/05 1 3S-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 ¡q(o-/, 3 11144054 PROD PROFILE WID EFT 12/22/05 1 2X-15 11144058 PROD PROFILE W/DEFT 12/26/05 1 3Q-09 11144055 LDL 12/23/05 1 2V -01 11144056 INJECTION PROFILE 12/24/05 1 SIGNED&2\uQ001-¡ :SCANNED JAN 3 1 2006 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 12/30/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color - CD _/ e e RECEIVED NOV 2 9 Z005 C sion AI!l~IlI¡ nil Ri Gas Cons. OrM1IS 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other ÄiÏChorage Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 19611~ '" 3. Address: Stratigraphic D Service D 6. APf'Wiinìber: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22685-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 3F-17 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7165' feet true vertical 6314' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' SUR. CASING 3389' 7-5/8" 3485' PROD. CASING 6474' 5-1/2" 6570' PROD. CASING 579' 5.5" 7166' Perforation depth: Measured depth: 6861-6881, 6900-6912 ~ANNEL DEC ~ 6 2005 I' , "'" true vertical depth: 6038-6056, 6073-6084 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6578' MD. Packers & SSSV (type & measured depth) Baker PBR, 6575 SSSV= NIP SSSV= 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS 8FL NOV 29 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubinn Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 305-123 Contact Brad Gathman/MJ Loveland/Marie McConnell Printed Name ;;:;?5n Title Problem Wells Supervisor J/jz.rft'1' Signature Phone 907 -659-7224 Date Pre Dared bv Sharon A/lsun-Drak'" 263-4612 , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Form 1 0-404 Revised 04/2004 ORIGINAL Submit Original Only ~ e 3F-17 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 10/23/2005 Clean cement off of OC after conductor cut off. Cut a total of 9' 7" of conductor off. TII/O=O/O/O 10/30/2005 Cut Conductor, Initial TII/O=O/O/O, Rigged up N2 purge hoses to OA and the IA for conductor cut away. Drilled, tapped and plugged leak point in surface casing, also cleaned away casing cement. Total conductor pipe removed measuring from the bottom of the mandrel hanger is 11' 2". Final T/I/O=OIOIO 11/13/2005 Monitor WHP's, TIIIO=OIOIO. Strap OA FL@18"belowOAleak,12'6"belowannularvalve'll Ready to go for patch weld. 11/1412005 Vac'd OA FL to 2 ' below top of conductor cut. Seal welded csg mandrel hanger to surface casing, installed upper and lower wedding bands. Bottom of bottom wedding band at 10.75' below mandrel hanger. Deposition welded pit on north side below wedding band. 11/15/2005 Finished sleeve patch installation. MITOA failed (post patch weld). TIIIO=OIOIO. TOC in conductor @ 11' 8" from top of flutes. Conductor cutoff length from top of flutes is 11' 4". Overall length of SC patched is 10' 8" (from seal weld on mandrel hanger to bottom of lower wedding band). Rigged up N2 for purge across the IA during weld. Held 3 psi N2 cap on OA during weld. Welded patch on SC. Filled void with grout. Seal welded plugs on patch where grout was poured in. Pressured up OA with .5 bbl of diesel to 460 psi. OA lost 30 psi in 10 min. Bumped pressure up to 980 psi. OA lost 70 psi in 10 min. Bumped pressure up to 1480 psi. OA lost 80 psi in 15 min. Bumped pressure up to 2000 psi. Start MITOA, TIIIO=010/2000. 15 min TIIIO=010/1900. Bumped pressure back up to 2010 psi and restart MITOA. 15 min TIIIO=010/1985, 30 min TIIIO=010/1970. Started to see small amount of diesel weeping out of upper seal welds on grout plugs. Bled OA down to 0 psi. Wrapped absorb around upper seal weld plugs. Final T/I/O=OIOIO. 11/17/2005 MITOA SC patch - Passed, Initial TIIIO= 01010, Pressure up OA with diessel to 2000 psi, start MITOA TIIIO= 0130/2000, 15 minute reading TIIIO= 0130/1870, Re-pressure to 2000 psi, start MITOA TIIIO= 0130/2000, 15 minute reading TIIIO= 0/30/1980, 30 minute reading T/I/O= 0/30/1970,45 minute reading TIIIO= 010/1970 Bleed down OA, final TIIIO= 010/0 11/23/2005Patched conductor to original height. , :;¡~:',;: :.;,., ,~:/,,~.,:'i ': """"'~I::'';-." , " ."¡..""""" '. '.III1S...~y,' ", ~ :~¡I ~" ' '"M'M(.I " :' .¡,~: ~~ i"' I~·, , I" I , I, , I," '. ", . :~: :J ;~~ ~j} ,':=' " ! ' " ':~,' . I I, I " ¡ , , .~~' ',I : i:~"I> ~"l~~=... .~~ ;;:' , ,Ho*'¡I."",~",,,", ,:',: . ,~~. . ':\:>~.~,.: '" ",...1,., ; ~ . " , '~ , , -'" ',' "' , , ,~!~I!~~~~~~II~\ll~~tI~~ ~-'IIi~.i~~~:'I~~ '.,~ ::,:11 .' ~~:~-"~'Ù~~iUj~~ht;~~Mi~ ' ': ':,:' ; i ':';'~";1!:::,::.:~,~, '. ~~ 'w' I" I ~ ' "~:"W' f,: 'i' ~ "1', '" ~ "111 -, , t . ! I, : ~!¡I '. , I, .' 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I I I I·' " .-~~~èJ,-'! f --r--~Tr ~-T·-t-t-.L- :f.t;tt-~H} Ll·t I-rt-r-Il ! II~Jgr~~}+ 35 r-f2J~e.t~~'-l-D.~1':-J.:;,JfJ- Ci l-r- ¡ - j ~L' t' t ¡ ¡ I T-lfT .~ ¡ Id r 'I~-'- r'l~p I'I--~-l- l . J -J-- -1-- -ï--'!" r--¡--r--r--:- : LJ-~:r1~rT ¡~-tTd-i=-tJ-W---¡--+~rI1J I" ILL-hi , . . -- · s . L f 11 teL: /:-1_' _. ea _ L.AJe . , . YJ e .~. .. _ , Ga·$..i.r11 thre:~JÞ ¡ MECHANICAL 4ÞrEGRITY TEST (MIT) FORM e WELL NO.: 3F-17 I DATE: 111-17-05 WELL TYPE: I Prod AIL I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: I MITOA I i.e., Tbg, IA /9-5/8", OA 113-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 PSi. Note: Please consult the PWS if there's any question @ 7224, pager 909, FLUID TVPE(S) USED TO PRESSURE TEST: Diesel R d" W IIh d P b f d d . T t ecor a e ea ressures e ore an unnq es. STARTTIME:7:50 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)- FAIL S TUBING 0 0 0 T IA 0 0 0 OA 0 2000 1870 1 COMMENTS: ' START TIME:18:05 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)- (PSI)* (PSI)** FAIL S TUBING 0 0 0 0 0 T IA / 9·5/8" 0 0 0 0 0 Pass OA /13-3/8" 1870 2000 1980 1970 1970 2 COMMENTS: Re-pressure to 2000 psi START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA / 9-5/8" OA /13-3/8" 3 COMMENTS: rSC COMMENTS * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. D -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: cc: PWS 6/3/00 ~' "1 . ~~' ~(r-r': r-,¡ 'I," (,i",J, 1,': ,: ßi \ 1; i r \) i¡ i/I'.: l't r~ 'I I, ¡ , I ,. nJ, 'I /,n\\ ¡¡ i!L ~~I w ~J :w \] ~.,:J ~"> ¡-- if' ''''''I\~ I,' ',r i I ~ I Ui ~r' (' I II! ¡ ~ ¡\.u, :¡ ) r" I;' f¡r ~;1 /tl\ !I II iJ'~\! L :, U:I.._:iI ) l~): ili /('7:"1 \ :,l!\ I ¡ '~" ,/ , J 1\ ~ \'''" :i,' IJli"\~ , '\) : ~,\ i .':,.,;; ~ nJ .II U1 I ~~ : ,'M ~, '\....::::./ : '1..)\ iJ...} ~J FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~q"- \ \.3 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska SCANNED MAY 2 6 2005 Re: Kuparuk 3F-17 Sundry Number: 305-123 Dear Mr. Dethlefs: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a liday or weekend. A person may not appeal a Commission deciSion~o Su erio, ou unless rehearing has been requested. /' ( Si. ¡y, ~~ ,. K orm~ L.. Chairman DATED thiS/v(OfMay, 2005 Encl. ... . ') ConocJP'hillips Alaska ) P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 1/ , \ ~ \~'() RECEIVED MAY 11 2005 May 8, 2005 Alaska Oil & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find three 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 2V-08A, 3F-17 and 3F-18. The approval requests regard repairs for surface casing leaks. Also encloséd is a 10-404 Report of Sundry Operations for well3F- 09 for an attempt to repair a surface casing leak with sealant. Please call MJ Loveland or Marie McConnell at 659-7224 or me at 659-7043 if you have any questions. Sincerely, fl· ICD¢u Jerry Dethlefs Problem Well Supervisor Attachments CØ/-5-/J -05' ) STATE OF ALASKA ) RECEIVED k ALASKA Oil AND GAS CONSERVATION COMMISSION MAY 11 2005 :;( \. APPLICATION FOR SUNDRY APPROVAL . . 20 AAC 25.280 Alaska Œ~ & Gas Cons. Commissum Operation Shutdown D Perforate D ~~pra~ Annular Disp. D Plug Perforations D Stimulate D Time Extension D Other D Perforate New Pool D . . 1. Type of Request: Abandon D D D Suspend D o D Alter casing Repair well Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 96' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7165' 6314' 7100 Casing Length Size Re-enter Suspended Well D 4. Current Well Class: Development _ 0 Stratigraphic D 5. Permit to Drill ~umber: 196-113 ,/' 6. API Number: J 50-029-22685-00 9. Well Name and Number: 3F-17 Exploratory D Service D 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 6254 MD TVD CONDUCTOR 121' 16" 121' 121 SUR. CASING 3389' 7-5/8" 3485' 3182 PROD. CASING 6474' 5-1/2" 6570' 5774 PROD. CASING 579' 4-1/2" 7166' 6315 Perforation Depth TVD (ft): 6038-6056, 6073-6084 Perforation Depth MD (ft): 6861-6881 , 6900-6912 Packers and SSSV Type: no packer SSSV= NIP 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: June 1, 2005 Date: Tubing Size: 3-1/2" Packers and SSSV MD (ft) SSSV= 516' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~ry De~h~f~ n ~ Signature 7~ ~ '" Commission Use Only Contact: Title: Phone 659-7043 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: ~o~~'-( s: Junk (measured): Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 65781 Service D Plugged D WINJ D Abandoned D WDSPL D Jerry Dethlefs @ 659-7043 Problem Well Supervisor Date ¢~.s- Sundry Number: 305=-/;;:;..3 ~c.\.o\-..¡..j"'~", ~o.l ~<,. bo<:.(è~ "Iê't~~d 'I, f......¡ \1-C.\~~\N:..LV)\oK.Q~'<;)Oc...~t-^Q\o'-~-\\ÖI\ ú~ ~~~ - \ lU\'llJ ¡ ¡\tt-\ r , COMMISSIONER ~~~~g~~~~ION Date: 4;~( RBDMS BFL MAY 1 6 2005 SUBMIT IN Lp~I~LE v ) ') ConocoPhillips Alaska, Inc. Kuparuk We1l3F-17 (PTD 1961130) SUNDRY NOTICE 10-403 APPROVAL REQUEST May 7, 2005 This application for Sundry approval for Kuparuk well 3F-17 is for the repair of a surface casing leak. The well is an oil producer, completed in July 1996. On June 13, 2003, liquids in the conductor were observed while attempting to perform an MITOA. On August 17, 2003, a cement shoe was pumped into the outer annulus (OA) to isolate formation pressure at the surface casing shoe from pressurizing the OA and supporting the leak mechanism. In August 2004, diagnostics were performed to locate and quantify the leak. A leak rate of 1.9 gpm was established at 2000 psi, but the exact leak depth has not been determined. The tight tolerance between the 5-1/2" production casing and 7-5/8" surface casing does not provide enough room to locate the exact depth. However, the response from pumping and purging with nitrogen suggests the leak is less than 7-feet below the OA annular valve. With approval, repair of the surface casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the OA and conductor so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. Approximately the top 8- feet of conductor will be removed to provide access to the surface casing. 6. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 7. QNQC the repair and MIT -OA for a final integrity check. 8. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 9. Replace the conductor and fill the void with cement to seal out water and oxygen. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10-404 with the AOGCC post repair. NSK Problem WeB Supervisor 05/07/05 " ) ) ConocoPhillipsAlaska,lncl< NIP (516-517, OD:3.500) TUBING (0-2985, OD:3.500, ID:2.992) Gas Lift V1andrelNalvE 1 (3021-3022, OD:4.507) Gas Lift V1andrelNalvE 2 (4436-4437, OD:4,507) Gas Lift V1andrelNalvE 3 (5407-5408, OD:4.507) Gas Lift V1andreliVah/t 4 (6124-6125 OD:~ 51j71 Gas Lift V1andrelNalvt 5 (6525-6526, OD:~ 5071 n.JBING (6486-6570, OD:2875 ID.2W) XO (6587-6588, OD:5.000) Perf (6861-6881) 1£-' lËI .. - "'1 .. - -. t1!!¡¡¡@:ØF'-'j,:,"m:~ . J,,;: ~ ,,':~.,- ,", ,.11 I "'I.{ -.. J ,e ~ : \" , -k._...._ __ _ ' n Ft SPF Date Type Comment 20 4 7/29/1996 IPERF 180 deg phasmg; Oriented (+/-) 90 deg. f/ Lowside; 2 1/8" EnerJet 12 6 9/17/2000 APERF 180 deg ph; 2 1/8" Enerjet, Powerjet class; Oriented (+/-) 90 deg from low side. !3F-17 API: 500292268500 8SSV Type: Nipple Well Type: PROD Ong 7/18/1996 Completion: Last W/O: Annular Fluid: Ref Log Date: TD: 7165 ftKB Max Hole Angle: 37 deg tã} 2869 Reference Log: Last Tag: 7000 LastTag Date: 7/16/2003 CasingStfing .~ÄL.L.STRINGS Description Size Top Bottom SUR. CASING 7.625 0 3485 CONDUCTOR 16.000 0 121 PROD. CASING 5.500 0 6570 PROD. CASING 4.500 6587 7166 Tubir'lg...Slring,.~,.OaING·..(3·1J2!~"BGMtXEDwt 2.7/8~!TBGl Size Top Bottom TVD 3.500 0 2985 2775 2.875 2985 3097 2865 3.500 3097 4397 3933 2.875 4397 4511 4027 3.500 4511 5369 4740 2.875 5369 5482 4836 3.500 5482 6086 5349 2.875 6086 6200 5448 3.500 6200 6486 5699 2.875 6486 6570 5774 3.500 6570 6578 5782 Perforations Summary Interval TVD 6861 - 6881 6038 - 6056 Zone A-3 Status 6900 - 6912 6073 - 6084 A-2 Gas Li,ft .. Màndrels/ValVes St MD TVD Man Man Mfr Type 1 3021 2804 Cameo KBMM 2 4436 3965 Cameo KBMM 3 5407 4772 Cameo KBMM 4 6124 5382 Cameo KBMM 5 6525 5734 Cameo KBMM other (31I.1gs, equip., etc.:. JEWELRY Depth TVD Type 516 516 NIP Cameo 'DS' Nipple 6564 5769 JOINT 6569 5773 NIP Cameo 'D' Nipple NO GO. 6575 5779 PBR Baker Locator 6587 5790 XO KRU 3F-17 Angle @ T8: 26 deg @ 6648 Angle @ TD: 24 deg @ 7165 Rev Reason: Tag fill, GLV design, pull plug Last Update: 7/19/2003 TVD Wt Grade Thread 3182 29.70 L-80 121 62.50 H-40 5774 15.50 L-80 7166 12.70 L-80 Wt Grade Thread 9.30 L-80 EUE 8RD MOD 6.50 L-80 EUE8RD 9.30 L-80 EUE 8RD MOD 6.50 L-80 EUE8RD 9.30 L-80 EUE 8RD MOD 6.50 L-80 EUE8RD 9.30 L-80 EUE 8RD MOD 6.50 L-80 EUE8RD 9.30 L-80 EUE 8RD MOD 9.30 L-80 EUE8RD 6.50 L-80 EUE 8RD MOD V Mfr V Type VOD Latch Port TRO GLV 1.0 BK 0.156 1365 GLV 1.0 BK 0.156 1347 GLV 1.0 BK 0.188 1366 GLV 1.0 BK 0.188 1349 OV 1.0 BK 0.188 0 Description Date Run 7/15/2003 7/15/2003 7/15/2003 7/15/2003 7/15/2003 Vlv Cmnt ID 2.812 4.825 2.250 4.000 4.000 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 30, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 1.0-404 Sundry Notices for ConocoPhillips Alaska, Inc., well. s 3F-17 (PTD 1961130), 3K-32 (PTD 1970760), and 2T-39 (PTD 2011830). The Sundry Notices regard cement shoes that were pumped on the surface casing. Please call Nina Woods, or me at 907-659-7224 if you have any questions. Sincerely, ~ Problem Well Supervisor ConocoPhillips Alaska, Inc. Attachments ~O,&NNED SEF 1 5 2003 -'"' STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon BI Suspend [] Operation Shutdown BI Perforate [~ variance BI Annular Disp. E~ Alter Casing E] Repair Well BI Plug Perforations r'"] Stimulate E~] Time Extension [] Other r'~ Change Approved Program E~] Pull Tubing E] Perforate New Pool E~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number:. ConocoPhillips Alaska, Inc. Development __ :~ Exploratory E] 196-113 / 3. Address: Stratigraphic O Service ~ 6. APl Number: P. O. Box 100360 50-029-22685-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 3F-17 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7165' feet true vertical 6314' feet Plugs (measured) Effective Depth measured 7100 feet Junk (measured) true vertical 6254 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 3389' 7-5/8" 3485' 3182' PROD. CASING 6474' 5-1,/2" 6570' 5774' PROD. CASING 579' 4-1/2" 7166' 6315' Perforation depth: Measured depth: 6861-6881, 6900-6912 C', i', '. 'i". ::;:' (ii't, ~''' ~ .... .~ :, ? r~.,. ¢. q. , true vertical depth: 6038-6056, 6073-6084 ,., .. ,, , Tubing (size, grade, and measured depth) 3-1/2", L-80, 6578' MD. Packers & SSSV (type & measured depth) no packer SSSV: NIP SSSV= 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casin,q Pressure Tubing Pressure Prior to well operation 350 330 75 1000 180 Subsequent to operation 350 330 75 1000 180 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory [] Development r~ service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[-~ GasE] WAG['-] GINJ F-] WINJ E] WDSPLF'-] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' I Sundry Number or N/A if C.O. Exempt: I 303-197 contact Nina Woods/MJ Loveland Printed Name MJ Loveland Title Problem Well Supervisor Signature,~.~.~ ,~ J~¢;~~~~' Ph°ne 659-7224 Date ~'/.~/d~, Prepared by Sharon AIIsup. Drake 263-4612 Form 10-404 Revised 2~~ B~. SUBMIT IN DUPLICATE Ii" DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 8/17/20031Pumped 25 bbls of 15.8 ppg Cement w/40 bbls diesel freeze protect down the OA (7/5/8" lannulus). Cement top @ 2697' MD RKB for a 788' Cement column. 8/20/20031MITOA - Passed w/1800 psi; initial T/I/O= 150/420/0, Start T/I/O = 150/420/1800, 15 min I reading T/I/O = 150/420/1720, 30 min reading T/I/O = 150/420/1700 - No steady trickle/leak Iobserved out conductor valve, ~ 1 qt collected during the test and appeared to be clear water Idue to expansion. Re: 3F-";i7 and 30-04 Subject: Re: 3F-17 and 30-04 Date: Mon, 21 Jul 2003 16:41:04 -0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: I will attempt to answer your questions in order. Also, you will be getting a couple more Sundrys for OA cement jobs, so the following statement applies to them as well. 3F-17: I have not yet completed the procedures for the actual cement pumping yet. But based on experience (some bad) we plan for a minimum of 500' cement column in the OA. We then mix and pump 100-120% excess to account for the amount that goes past the shoe. If the reservoir does not take any cement we may end up with a 1000' column. From experience we found it will probably take quite a lot. If we do not get a pressure bump we will shut down pumping with the calculated 500' column. The displacement fluid is 5 bbls water spacer to clean lines followed by diesel. There will not be any "Arctic Pack" pumped. The cement blend is recommended by Dowell for this purpose. An MITOA will be done a couple days after the job to test for integrity. 30-04: In preparation for attempting a SealTite repair on this well a couple months ago, we drilled and tapped a 3/4" hole in the conductor. The vendors needed a leak rate through the surface casing into the conductor to plan their sealant repair. When the hole was drilled it was obvious there was cement in the conductor, since the hole drilled straight into cement. However, we were able to establish a leak path from the surface casing out our hole in the conductor. Just by luck the hole we drilled in the conductor is fairly close to where we identified the leak with the boroscope. As we pumped diesel to get the leak rate, chunks of cement came out with the diesel and the leak rate increased up to 10 gpm, which is the maximum rate our pump would put out. That high of leak rate is not suitable for a SealTite repair, so we did not follow-up on that option. We expect there is a distinct possibility of hydrocarbon contaminated cement in the conductor. Since the void area should mostly be cement, we expect very little accumulated fluid. The Welding Foreman wants holes drilled top and bottom prior to cutting the window to verify that condition. I am unclear about your statement about cutting the window-the procedure starts with the major steps only. All the safeout steps and nitrogen purging are to be done prior to and in conjunction with cutting the window AND the casing repair. There will be nitrogen purging on the conductor, OA and IA during all the hotwork. After looking at the boroscope picture again, I suspect there is a split in either the surface casing mandrel or the pup joint immediately below it. Cutting the conductor window should make that clear. We can keep you posted as to what we find--I think it will take at least a few days or more after cutting the window before we attempt the repair. There are lots of approvals internally that will need to be obtained. I will be leaving the slope Tuesday and Nina will be here for another week. Please let us know if you want more information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska Tom Maunder <tom_maunder@admin.state.ak.us> 8 NED J U L g ,3 D3 1 of 2 7/22/2003 7:30 AM Re:,3F-:'i7 and 30-04 07/21/2003 12:17 PM To: Jerry C Dethlefs/PPCO@Phillips, NSK Problem Well Supv/PPCO@Phillips cc: Michael B Mooney/PPCO@Phillips Subject: 3F-17 and 30-04 Jerry, MJ or Nina, I was looking at the sundries for these wells and had a few questions. 3F-17--What cement volume is proposed?? Will the displacement fluid be diesel?? 30-04--In the Job Procedure, step 2, it is noted that N2 should leak through the surface casing hole and provide purge for cutting the conductor window. With all the other gas checks planned, it seems strange that there are no similar plans for the conductor x OA. --Is the fluid level in the conductor x OA below the split?? --What fluid is present in the conductor x OA?? --Where is the cement level in the conductor x OA?? --Prior to cutting will the atmosphere in the conductor x OA be checked?? --Is it planned to attempt to keep water in the conductor x OA while the cutting is performed to allow steam to develop and prevent formation of an explosive mixture?? Thanks for you attention to these questions. Tom Maunder, PE AOGCC (See attached file: tom_maunder.vcf) Tom Maunder <tom maunderC, admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 7/22/2003 7:30 AM ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 19, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice for ConocoPhillips AlaSka, Inc., well 3F-17 (PTD 1961130. The Sundry Notice regards pumping a cement shoe on the surface casing. Please call Nina Woods, MJ Loveland, or me at 907-659-7224 or 7043 if you have any questions. Sincerely, j~e~y~Det'~hle~fs ~)~ Problem Well Supervisor ConocoPhillips Alaska, Inc. Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon F-~ Alter casing [~ Change approved program [] Suspend E~] Operation Shutdown r-1 Repair well [-'] Plug Perforations F-'I Pull Tubing r"-] Perforate New Pool [~ Perforate r'-'] Vadance [--1 Stimulate [] Time Extension E~ Re-enter Suspended Well [--'] Annular Disp. r~ Other ['~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development __ [] Exploratory Stratigraphic ~ Service 5. Permit to Drill N~lmber: 196-113 ''/ 6. APl Number: 50-029-22685-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 3F-17 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11, PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7165' 6314' 7100 6254 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SU R. CASING 3389' 7-5/8" 3485' 3182 PROD. CASING 6474' 5-1/2" 6570' 5774 PROD. CASING 579' 4-1/2" 7166' 6315 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6861-6881, 6900-6912 6038-6056, 6073-6084 3-1/2" L-80 6578' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 516' 12. Attachments: Description Summary of Proposal F~ 13. Well Class after proposed work: Detailed Operations Program r"-I BoP Sketch r-1 Exploratory r-'l Development I-~ Service 14. Estimated Date for Commencing Operations: August 1, 2003 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil [-~ Gas ~] Plugged [--1 Abandoned [] WAG I~1 GINJ ['--I WINO r'-I WDSPL I-'-I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature .~~Dethlefs Commission Use Only Contact: Title: Phone 659-7043 Jerry Dethlefs @ 659-7043 Problem Well Supervisor Date ISundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity F'-I BOP Test [~ Mechanical Integrity Test r'-'] Location Subsequent Form Required: '%0 ~ ~D~$ BFL JUl BY ORDER OF THE COMMISSION FormlO-403('~~03· 'X,,~ ORGI ..... INAL SUBMIT IN DUPLICATE ConocoPhiilips Alaska, Inc. Kuparuk Well 3F-17 (PTD 1961130) SUNDRY NOTICE 10-403 REQUEST 7/19/03 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Kuparuk producing well 3F-17. 3F-17 was drilled in 1996 and has been in production since that time. A surface casing cement shoe was not pumped at the time of original completion. In June 2003, Operations personnel reported "wet gravel" around the wellhead, either from the casing head or conductor. An MIT- OA indicated there might be a small leak in the surface casing. The results are questionable since there is not a cement shoe to pressure up against. Fluid can readily be pumped into the OA and a leak rate into the conductor cannot be determined. The proposed plan includes pumping a cement shoe and performing an iMIT-OA / LLR (liquid leak rate test) to verify and quantify if any fluid leaks into the conductor casing. Should a leak be confirmed, the AOGCC will be contacted about a proposed repair plan. NSK Problem Well Supervisor 07/19/03 COnocoPhillips Alaska, Inc. 3F-17 KRU 3F-17 NIP (516-517, 0D:3.500) (0-2985, 0D:3.500, ID:2.992) Gas I_ift ~ mdrel/Dummy Valve 1 (3021-3022. 0D:4.507) Gas Lift ~ndrellDummy Valve 2 (4436-4437, 0D:4.507) Gas L~t lndrel/Dummy Valve 3 (54O7-54O8, 0D:4.507) Gas LA ]ndrel/Dummy Valve 4 (6124-6125, OD:4.507) Gas LA ~ndrel/Dummy Valve 5 (6525-6526, 0D:4.507) TUBING (6486-6570. 0D:2.875. ID:2.441) (6587-6588, OD:5.000) Perf (6861-6881) APl:1500292268500 SSSV Type:I Nipple Annular Fluid1 Reference Log:~ Last Tag:~ 6989 Last Tag Date:l 9~3~2002 Casing String - ALL STRINGS Well Type:I PROD Orig 17/18/1996 Completion:I Last W/O:I Ref Lo9 Date:I TD:~7165 ftKB Max Hole Angle:137 deg ~ 2869 Angle (~ TS: 126 deg @ 6648 Angle @ TD:I24 deg @ 7165 I Rev Reason:lGLV design, set Last Update:l 7~5~2003 I Description Size Top SUR. CASING 7.625 0 CONDUCTOR 16.000 0 PROD. CASING 5.500 0 PROD. CASING 4.500 6587 TUbing String ,:' ;UBING::(3 112,' TBG MIXED wi 2 718', TBG) Size ..... Top Bottom TVD I Wt IGrade 3.500 0 2985 2775 I 9.30 IL-S0 I 2.875 2985 3097 2865 I 6.5o I L-so I 3.500 3097 4397 3933 I 9.30 I L-80 2.875 4397 4511 4027 I 6.50 I L-80 3.500 4511 5369 4740 I 9.30 I L-so '1 2.875 5369 5482 4836 I 6.50 I L-80 I 3.500 5482 6086 5349 I 9.30 I L-80 2.875 6086 6200 5448 I 6.50 IL-S0 I 3.500 6200 6486 5699 I 9.30 I L-80 I 2.875 6486 6570 5774 I 9.30 I L-80 I 3.500 6570 6578 5782 I 6.50 I L-80 Bottom I TVD I wt I Grade I 3485 I 3182 129.70l L-80 I 121 I ~21 162.501 H-~O I 6570 I 5774 1~5.501 L-80 I 7166 I 7166 I 12.70 ] L-80 I Thread Thread EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE SRD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD Perforations Summary Interval TVD I Zone I StatuslFt ISPFI Date I Type I Comment 6861-6881 6038-6056 I A-3 I 120 I 4 17/29/199611PERF 1180deg. phasing;Or,ented I I I I I I I(+/-) 90 deg. f/Lowside; 2 I I I I I I 11/8''EnerJet 6900-6912 6073-6084 I A-2 I 1121 6 19/17/20001APERFI180degph;21/8"Enerjet, I I I I I I I Powerjetclass; Oriented I I I I I I I(+/-) 90 deg from Iow side.: Gas. L~iftMandrels/ValVeS'..:::' '.....: ..............".." :.:.....:: :...: . :...:. · ..... ;... ::' · .......:. : ..' st l MD I TVD I Man I Man '1 VMfr'l V'Type I VOD I,atchl Po. I TRO I Date I v,v Mfr Type Run 113021128041Camco[ KBMM I I DMY I 1.0 I BK 10.0001 0 16/26/20031cmnt 2144361 39651camcoI KBMM I I DMY I 1.0 I BE 10.0001 0 16126/20031 315407147721cam0oI KBMM I I DMY 11.0 I BE 10.0001 0 16/26/2003I 4161241 53821CamcoI KBMM I I DMY I 1.0 I BE 10.0001 0 IS/26/20031 5165251 57341CamcoI KaUU I I DMY I 1.0 I BK 10'0001 0 16/27/20031 'Other (plUgS,"equipi,.:'etc;)-'JEWELRY.:.''.: . ". ' ':'; ." '..' ':' :.' ..' '." '.;'::': :' ". :'".::"..'.::'. ~:' ';." Depth l'TVD I Type ' " Description ID 516 516 I NIP ICamco'DS' Nipple 2.812 6564 15769 I JOINT I 4.825 6569 I 5773 I NIP 1Camco 'D' Nipple NO GO. 2.250 6569 15773 I PLUG I SET 2.25" A-2 PLUG 6/27/2003 0.000 6575 I 5779 I PBR I Baker Locator 4.000 6587 15790 I xo I 4.000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, Al'( 99510-0360 4. Location of well at surface 88' FSL, 240' FEL, Sec. 19, T12N, RgE, UM At top of productive interval 2231' FSL, 1907' FEL, Sec. 19, T12N, R9E, UM At effective depth At total depth 2388' FSL, 2052' FEL, Sec. 19, T12N, R9E, UM 5. Type of Well: Development _X Exploratow__ Stratigraph lc__ Service__ (asp's 508256, 5985913) (asp's 506579, 5988055) (asp's 506434, 5988212) 6. Datum elevation (DF or KB feet) RKB 96 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3F-17 9. Permit number / approval number 196-113 10. APl number 50-029-22685 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 7165 6314 feet feet Plugs (measured) Tagged PBTD (9/4/00) @ 7008' MD. Effective depth: measured true vertical 7008 feet 6170 feet Junk (measured) Casing Length Size CONDUCTOR 121' 16" SURF CASING 3389' 7-5/8" PROD CASING 6474' 5-1/2" PROD CASING 579' 4-1/2" Cemented 240 Sx AS I 650 SxAS III & 280 Sx Class G 200 Sx Class G ii II . Ii . Measured Depth True vertical Depth 121' 121' 3485' 3182' 6570' 5774' 7166' 6315' RECE Perforation depth: measured 6861 - 6881'; 6900 - 6912' true vertical 6038 - 6056'; 6073 - 6084' B ? 001 Alaska Oil & Gas Cons. Commission Anchorage tubing (size, grade, and measured depth) Multiple alternating sections of 2.875" & 3.5", 6.5/9.3#, L-80, Tubing to 6578' MD. Packers & SSSV (type & measured depth) No Packer. Camco 'DS' Nipple @ 516' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 442 Subsequent to operation 537 Representative Daily Average Productionorlnjection Data Gas-Mm Water-Bbl 260 23 396 32 Casing Pressure - Tubing Pressure 177 187 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 · Title: Date .~//~ ~--~////~ / Prepared by Joh~i Peirce 265-6471 .~;,,.~..,~ I SUBMIT IN DUPLICAT~ 3F-17 DESCRIPTION OF WORK COMPLETED ADD PERFORATING OPERATIONS 9/4/00: RIH & tagged PBTD at 7008' MD. 9/17/00: MIRU & PT equipment. RIH w/perforating guns & shot 12' of perforations in the 'A2' sand as follows: Added perforations: 6900 - 6912' MD Used a 2-1/8" Enerjet carrier & shot the perfs at 6 spf at 180 degree phasing. POOH w/guns. RD. Returned the well to production w/lift gas & obtained a valid well test. PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 07/07/98 RUN RECVD 96-113 CBL 10-407 DAILY WELL OPS L 6460-7045 d~0MPLETION DATE R / //~ /,~ / TO FINAL 09/25/96 ~o/' ~ ;"?" ,',?,-f; q /,.o//~.¢'/ ',~,/ t :~/ >;'" / ::,> / Are dry ditch samples required? yes ~_. And received? Was the well cored? yes ~..__Analysis & description received? y~.s---~o ..... Are well tests required? yes ~'~ Received? Well is in compliance COMMENTS Initial ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 25, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Subject: 3F-17 (Permit No. 96-113) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3F-17. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad · ' STATE OF ALASKA ,-,LASKA OIL AND GAS CONSERVATION C,..,.,/IMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS E~ SUSPENDED E~ ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-113 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22685 4 Location of well at surface ~- - .......... ~=~-~ 9 Unit or Lease Name 88' FSL, 240' FEL, Sec. 19, T12N, RDE, UM ~ , · ..... '" ,(~ ~z-':;*:;:",', ,"'¢~;r' Ku~ruk River Unit At Top Producing I nte~al ~ ~ '.' 2231' FSL, 1907' FEL, Sec. 19, T12N, R9E, UM ¢ .... ~" At Total Depth i - .¢~ Field and Pool , - . _ ._. , ~ ;> ,;.~¢- 2388' FSL, 2052' FEL, Sec. 19, T12N, R9E, UM ~;¢'~~ ~ KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) ~ 6 Lease Designation and Serial No. Ri¢ RKB 41' PAD 55'~ ADL 25632 ALK 2565 12 Date Spudded 13 Date T.D. Reached 14 Date Comp. , Susp. or Aband. ~ 15 Water Depth, if offshore ~16 No. of Completions 12-Jul-96 16-Jul-96 29-Jul-96 (~rrd)[ NA feet MSL~ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey ~20 Depth where SSSV set 21 Thickness of permafrost 7165' MD & 6314' TVD 7100'MD&6254'~D YES ~ NO ~~ NA feetMD =1380'ss APPROX 22 Ty~ Eleciric or Other Logs Run ARC5/GR, G~CCMSLTJ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE CEME~ 16" 62.5¢ H-40 SURF. 121' 24" ,240 sx AS I 7.625" 29.7¢ L-80 SURF. 3485' 9.875" 650 sx AS III Lead, 280 sx Class G Tail 5.5" x 4.5" 15.5¢/12.7¢ L-80 SURF. 7166' 6.75" 200 sx Class G 24 Pedoralions o~n to Production (MD+TVD of Top and Bosom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET 3.5" 6578' 6861 '-6881'MD 4 spf 6037'- 6055'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 0 R I G J NA L DEPTH INTERVAL'(MD) AMOUNT & KIND OF MATERIAL USED 6861'-6881' 135111¢ up to 10.1 p~ 1~18 to perfs, 20900~ 10 p~ left in wellbore 27 PRODUCTION TEST Date First Production lMe[hod of O~ration (Flowing, gas lift, etc.) 8/25~6~ Gas Lib Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 10/6~6 17.80 TEST PERIOD ~ 782 830 0 136~ 1375 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 186 701 24-HOUR RATE~ 1055 1118 0 =24~ 28 CORE DATA Brief description of lithology, ~rosity, fractures, apparent dips and presen~ of oil, gas or water. Submit core chips. RECEIVED OCT ~ 9 1996 A!aske Oil & Gas Cons. Commission An .... Form 10-407 Submil in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29., ~ !30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6648' 5844' Bottom Kuparuk C 6738' 5925' Top Kuparuk A 6843' 6020' Bottom Kuparuk A 6986' 6150' FREEZE PROTECT ANNULUS WITH DIESEL 31'. LIST OF A-FFACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 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'~ · %0 *-~ . - -1818,53 z,~3,04 J~,.= .3,67 0,00 Date: 7/19/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:3F-17 RIG'PARKER WELL ID: AK8557 AFC: AK8557 TYPE: STATE:ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK: FINAL: WI' 55% SECURITY:0 AFC EST/UL:$ OM/ OM API NUMBER: 50-029-22685-00 7/11/96 (1) PBTD: 121(0) SUPV:DCL DAILY: MW: PV/YP: APIWL: DRILLING AT 700' Move rig from 3F-18 to 3F-17. Accept rig at 2100 hrs. $61,959 CUM: $61· 959 ETD: $0 EFC:$61,959 7/12/96 (2) MW. 10.1 PV/YP: 26/27 APIWL: PBTD' 3495( 3374) RIH W/7-5/8" CSG SUPV'DCL Drill 9-7/8" hole from 121' to 3495' DAILY: $87 263 CUM: $149 222 ETD' $0 EFC:$149,222 7/13/96 (3) PBTD' 3495(0) SUPV: DCL DAILY: MW: 10.0 PV/YP: 26/15 APIWL: 6.4 DRILLING AT 3600' Pre-job safety meeting. RIH w/7-5/8" casing. Hole tight at 2475'. Hole packing off. Pump cement. ND diverter. NU BOPE. Test all BOPE to 300/3000 psi. $140,799 CUM: $290,021 ETD: $0 EFC:$290,021 7/14/96 (4) PBTD: 5409(1914) SUPV: DCL DAILY' MW: 9.0 PV/YP: 16/14 APIWL: 6.5 PLUGGED TOOLS - PREP POH Drill out green cement to 3377'. Test casing to 2000 psi for 30 min. Drill out float equipment, cement and 10' new formation to 3505'. Performed FIT = 15 ppg EMW. Drilling 6-3/4" hole from 3505' to 5409'. $78,835 CUM: $368,856 ETD: $0 EFC:$368,856 7/15/96 (5) PBTD: 6385(976) SUPV:DCL DAILY' MW: 11.6 PV/YP: 31/17 APIWL: 4.6 DRILLING AT 6740' Drilling from 5409' to 6053'. Attempt to survey. Tool jammed. POH. Pulser sub locked up w/small rocks. RIH to TD. Drilling from 6053' to 6385' $100·974 CUM: $469·830 ETD: $0 EFC:$469,830 7/16/96 (6) PBTD: 7165(780) SUPV' DCL DAILY' MW: 11.7 PV/YP: 27/16 APIWL: 4.2 RIH W/5.5" CSG Drilling from 6385' to 6967'. Gas cut mud to surface. Had indication of flow. No gas influx. Monitor well. Static. Work pipe. No gas. Drilling from 6967' to 7165'. Monitor well. No problems. Drop survey. Monitor well. Pump slug. Monitor well at shoe. Retrieve survey. $76,797 CUM: $546,627 ETD: $0 EFC:$546,627 7/17/96 (7) PBTD' 7165( 0) SUPV:DCL MW: PV/YP: APIWL: RIH W/3.5" TBG Held pre-job safety meeting. RIH w/4.5" and 5.5" casing to 3483'. No returns after 3200'. Attempt to CBU w/no success. RIH w/5.5" csg to 7165'. Lost 172 bbls to for- DAILY: 7/18/96 (8) PBTD: 7165(0) SUPV:DCL DAILY' mation. Pump cement. Bumped plug. Floats OK. NU BOPE. Test BOP flanges to 300/3000 psi. $151,348 CUM: $697,975 ETD' $0 EFC:$697,975 MW: PV/YP: APIWL: MOVE RIG TO 3G-25 Held pre-job safety meeting. RIH w/3.5" and 2-7/8" completion. Pressure test 5.5" x 4.5" casing to 3500 psi for 30 min. OK. Test tbg to 3500 psi f/10 min. OK. Test annulus to 3500 psi f/10 min. OK. ND BOPE. NU tree adapter and master valve. Test adapter to 5000 psi. Release rig @ 2400 hrs. 7/18/96. $128,401 CUM: $826,376 ETD: $0 EFC:$826,376 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3F-17(W4-6)) WELL JOB SCOPE 3F-17 PERFORATE, PERF SUPPORT DATE 07/29/96 DAY 1 DAILY DAILY WORK PERF 'A' SANDS OPERATION COMPLETEYES IsUCCEss L YES Initial Tbg Press Final Tbg Press Initial Inner 0 PSI 900 PSI 0 PSI SUMMARY JOB NUMBER 0725961950.3 UNIT NUMBER KEY PERSON SUPERVISOR SWS-SCHWARTZ STRICKLAND Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 800 PSI[ 800 PSI PERFORATED 'A' SAND FROM 6861' - 6881' WITH 2-1/8" ENERJETS (BIG HOLE CHARGES, 4 SPF, 180 DEG PHASING, +/- 90 DEG CW FROM LOW SIDE). TIME LOG ENTRY 07: 3 0 MIRU SCHLUMBERGER. HOLD TAILGATE SAFETY MEETING. NOTIFY ALL PERSONNEL ON PAD OF PERFORATING OPERATIONS AND CALL IN FOR RADIO ANNOUNCEMENT. 08:45 ARM GUN #1 - 2-1/8" ENERGET LOADED AT 2 SPF WITH 14G BIG HOLE CHARGES. ORIENTATE GUNS 90 DEG CCW. PU TS - FN/CCL/DUAL MPD/GUN #1. CCL TO TOP SHOT = 7.5'. PT LUB AND RIH. 09:45 TIE IN TO CBL (7/27/96) THAT IS TIED INTO ANADRILL ARC 5 (7/14-16/96). NO DEl:TH CORRECTION IN ZONE OF INTEREST. 10:00 INCREASE WHP TO 900 PSI FOR CALCULATED 100 PSI UNDERBALANCE. FIRE GUN/41. GOOD INDICATION ON SURFACE AND WHP INCREASED TO 1000 PSI. POOH WITHOUT ANY PROBLEMS. ALL SHOTS FIRED. 10:30 REPEAT FOR GUN #2. ORIENTATION IS 90 DEG CW. WELLHEAD PRESSURE IS STILL 900 PSI. ALL SHOTS FIRED. 12:00 RD AND MOVE TO 1G~16. ARCO Alaska, Inc. Date: September11, 1996 Transmittal Cf: 9735 RETURN TO: ARCO Alaska, Inc. Attn.: Bethany Lilly Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 3G-25 Cement Bond Log 07-25-96 3F-19 Cement Bond Log 07-27-96 3F-18 Cement Bond Log 07-26-96 3F-17 Cement Bond Log 07-27-96 2M-35 Cement Bond Log 07-28-96 2M-34 Cement Bond Log 07-31-96 Receipt ~~ Acknowledge Date: DISTRIBUTION: Sharon AIIsup-Drake DS Development ATO-1 205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 2700-3520 7460-7876 6000-6770 6~60-7045 14000-14775 16240-16560 Chapman/Zuspan NSK Wells Group NSK69 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE:. (907) 279-1433 FAX: (907) 276-7542 June 18. 1996 Michael Zanghi, Drill Site Develop Supv ARCO ~jast-~ !nc. P O Box 100360 Anchorage, 3~<2 99510-0.360 Re~ Kuparuk River Unit 3 F-17 ARC O A!aska. !nc. Permit No: 96-i !3 ~,n,rrT c~ 19. T~'.xT R9E, UM c.,. Loc. 88'FSL ........ o ....... , Btrnhole hoc. _.,z~ r~,. zl · ~,~. Sec. 19. T12N. R9E. ~ Dear Mr. Zanghi' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were mn. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CCi Department of Fish & 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 Drill X Redrill E] lb Type of Well Exploratory r'] Stratigraphic Test FI Development Oil X Re-Entry ~1 Deepen ~'~ Service r'~ Development Gas D Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Ricj RKB 41', Pad 55' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25632, ALK 2565 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 88' FSL, 240' FEL, Sec. 19, T12N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2282' FSL, 1948' FEL, Sec. 19, T12N, RgE, UM 3F-17 #U-630610 At total depth 9. Approximate spud date Amount 2521' FSL, 2121' FEL, Sec. 19, T12N, RgE, UM 6/24/96 $200~000 1 2. Distance to nearest 13, Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3F-16 7166' MD 2282 @ Target feet 14.4' @ 100' feet 2448 6276' TVD feet 16, To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 1 000' feet Maximum hole angle 33.3° Max~m~ur~ace 1 892 pslg At total depth ('I'VD) 3200 pslg 18. Casing program Settir~l Depth size Specifications Top Boltom Quantit~ of cement Hole Casir~l Weight Grade Couplin0 LinCh IV~ TVD MD TVD tinctude stickle datat 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' :~r.200 CF 9.875' 7.625' 29.7# L-80 LTC 3441' 41' 41' 3482' 3196' 570 Sx Arcticset III & HF-ERW 300 Sx Class G 6.75' 5.5' 15.5# L-80 LTCMOD 651 6' 41' 41' 6557' 5767' 190SxClassG HF-ERW Top 500' above Kuparuk 6.75' 3.5' 9.3# L-80 EUESrdM 609' 6557' 5767' 71 66' 6276' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present we# condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor su..c. RECEIVED Intermediate Production LinerM AY 5 '1 19 9 6 Perforation depth: measured true vertical Alaska 011 & 13as Cons. C0mmJssiorl 20. Attachments Filing fee X Property plat D BOPSketch X DiverterSketch X '-'"~l~l~l~l~Program X Drilling fluid program X Time vs depth plot [~ Refraction analysis [~ Seabed repro1 D 20 AAC 25.050 requirements X Signsd21'l hereby certify~, ' L, thalt the lore~oing~ is true and correct to the best of my knowledgeTille Drill Site Develop. Supv. Date ~') Commission Use On~ PeE~it Number "-'~ [ AJ;q' number I Approval date (,¢///~/~ I See cover letter for ~'~ -~'/_.~ ~'~'0- O ~--'~- ~ ~ ~' ~2",..~"' ~n other requirements Conditions of approval Samples required D Yes ,[~ No Mud log refq~i~'e~ r"] Yes [] No Hydrogen sulfide measures ]~ Yes [~ No Directional survey required ~ Yes [-] No Required working pressure for BOPE [~ 2M ~ 3M r~ 5M BI 1OM r'~ 15M Other: 0rigina.! Signed By 0avid W. Johnston by order of ~//~-?/~,~(~, Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 , r /in triplicate · . . 10. 11. 12. 13. 14. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3F-17 Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3,482')according to directional plan. Run and cement 7-5/8" casing· Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (7,166') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 3-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed·) Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well· Clean location and release rig in preparation for perforating· RECEIVED MAY ,~ 1 199t~ DRILLING FLUID PROGRAM Well KRU 3F-17 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillino Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,892 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3F-18 is 3F-16. As designed, the minimum distance between the two wells would be 14.4' @ 100'. Drillin~l Area Risks: Risks in the 3F-17 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. R E C E IV E D *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill ~[~,vfel;sb~j~; Alaska 0il & (;a~ t;o~t¢;, t;0mrmss~or~ Anchorage ANNULAR PUMPING OPERATIONS WELL KRU 3F-17 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (_Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3F-17 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3F-17 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3F surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3494 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 .~_ ~6~6~'~ rED Fluids to be disposed of in subject annulus will be limited to drilling wast~A~o~ial~j~; with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). Alaska 0il & Gas Cons, Commission Anchorage 0 0 350 _ _ 0 _ _ 350 _ _ 700 _ 1050_ _ 1400_ _ 1750_ 2100_ _ 2450_ _ 2800 _ _ 3150_ 3500_ _ 3850_ _ 4200_ _ 4550_ 4900_ _ 5250_ _ 5600_ _ 5950_ _ 6300_ _ 6650_ ARCO ALASKA, Irlc. Structure : Pad 3F Well : 17 Field : Kuporuk River Unit Location : North Slope, AIosko] N 37.89 DEG W 2781' (TO TARGET) ***PLANE OF PROPOSAL*,* For: D PETEASH[ CreWed by : jones [ Dote plotted : 1f-May-g6 Plot Reference ia 17 Version ~5. Co~rdin~ea ore in feet reference slot. I~17. ~245). True Vertical Depths or~ reference RKB (Parker RKB EL!~CATION: 96' <-- West Scale 1 : 100.00 ~.~ TVD=300 TMD:300 DEP:O 2.00 200 5.00 1 DE(; / 100' DLS 2000 1800 1600 1400 1200 1000 800 600 400 200 0 +.00 I I I I I I I I I I I I I I I I I I I I I I I 2600 END BUILD TVD=T99 TMD=800 DEP=-,8 TD LOCATION: - 4.goKOP TVD=999 TMD=IO00 DEP=-1.44 ~ 2521' FSL, 2121' FEL 5.85 J' hN ~Base Kup Sands SEC. 19, T12N, R9E 7.90 3 DEG / 100' DIS / '~, ~rop-A3 Interval -- ~-- 10.42 / ~. \Too Unit B oonn 15.96 B/ PERMAFROST Bas,, HRZ -- ~ ~' [oc WD=2066 TUD=213~ DEP=316 X rAR6~ _~800 ~ ~ WD=5826 ~ ~ TMD-6627 - ~ DEP=2781 ~ ~ NORTH 2194 _1600 ~ T/ W ~K SNDS ~ WEST 1708 ~ ~-2531 TMD-2687 DEP=621 % - I ~ ~ _1400 ~ WD=2996 TMD=3~43 DEP=926 X 1200 ~ 7 5/8" CSG P ~ - - ~t" I ,, ~ . _ 2~ 0 B/ HRZ ~ IMD~4~P=2676 ~ ~ Z ' ~ S C TVD 5826 TMD 662 DEP 2781 -L .................. - =. = T/ ~ B WD~96 TMD=6711 DEP=2826 T/ ~ A ~O~ TMD~~P=2884 T/ ~D~~6834 DEP=289~ B/ ~ WD~ m~ DE~966 ~q~" ID ~=6876 T~=7166 DEP=3076 RECEIVED ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' MAY311996 350 0 350 700 1050 1400 1750 2100 2450 2800 .3150 3500 Scale 1 : 175.00 Vertical Section on 32.2.11 ozirnuth with reference 0.00 N, 0.00 Ir from slot #17 Alaska 011 & Gas Cons. Commission Anchorage Cre~ed by : jones For: D PETRASH D~te p4otted : 16-May-96 Plot Reference is 17 Vets/on ~5. Coordinotes ore in feet reference slot ]~17. TnJe Ver'ticol Depths~RKB (Porker ~245). ARCO ALASKA, Inc. Structure : Pad 5F Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska < - - W e s f ~o,~ ~ · ~o.oo 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 240 I I I I I I I I [ I [ [ I I I I [ [ [ I I I I I [ I I [ [ I [ [ I . 240 t - 220 _ 220 ¢~o0 2O0 180 160 140 100 ~o ~o 1500 C' 40 0 20 0 120 1900 4100 17O0 1300 1700 1100 1500 7OO 37OO 200 180 _ 160 _ 140 _ 120 _ _ 100 - 0 20 ! 0 300 60 ~ 60 _ 80 0 ~oo 0 100 100 o 0 - _ _ .. ~ 24o ~2o 200 ~ao ~,o ~4o ~2o ~oo ~o ,o ~ 2o ~}~ ~o < - - W e s f Alaska 011 & ~L~n~.:od~si0n Anchorago {Cren{~d by : io--~ For: D PETRHH} {)ate piotEeo: }P{ot Reference is 17 Version ~5. Coordinotes ore in feet reference slot ~17, True Verticol Depths ore reference RKB (Perker ~245), 1900 1700 1 1500. 140~ 120( 1100. 900 8OO 700 6OO 5OO ¢00 3OO 200 AI~CO ALASKA, Inc. Structure : Pad 3F Well : 17 Field : Kuparuk River Unit Location : Norfh Slope, Alasko <~ - - We si Scole 1 ' 50.00 1700 1600 1500 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 · 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 . 4700 ~500 ,6300 2900 6100 59O0 37O{ 530O 51OO 4900 57OO 3500 5500 1800 1700 1200 1100 1000 ~00 53OO ~ 800 5100 700 4900 2100 230( REC 1900 21C 1700 1 600 1500 1400 1 $00 1200 11 O0 1000 g00 800 700 600 500 400 300 200 100 <~ W e s ~ Alaska 011 & {3as Cons. Commmsi~n 6OO 5OO 400 3OO 200 A I I 7 O ARCO ALASKA, Inc. Pad 3F 17 slot #17 Kuparuk River Unit North Slope, ALaska CLEARANCE REPORT Baker Hughes [NTEQ Your ref : 17 Version ~5 Our ref : prop1499 License : Date printed : 16-#ay-96 Date created : 9-Jan-96 Laat revised : 16-#ay-96 Field is centred on n?O 16 18.576,w150 5 56.536 Structure is centred on n?O 22 20.956,w149 55 51.299 Stol location is nTO 22 21.8~1,w149 55 58.321 Slot Grid coordinates are N 5985910.981, E 508259.858 Slot local coordinates are 88.00 N 240.00 W Referee North is Trc~ North Main calculation perfomed with 3-D #ininu~Di Object we[ lpath stance method Closest approach with 3-D mininundistance method Last revised Distance M.D. Diverging from#.D. 21-Nov-91 14.4 100.0 300.0 21-Nov-91 88.5 400.0 400.0 21-Nov-91 4~.4 350.0 5640.0 21-Nov-91 39.6 100.0 120.0 21-Nov-91 64.6 100.0 6560.0 21-Nov-91 113.1 350.0 350.0 21-Nov-91 124.9 980.0 980.0 21-Nov-91 165.0 260,0 260,0 21-Nov-91 263.2 120.0 120.0 21-Nov-91 2~.5 60.0 120.0 21-Nov-91 314,8 20,0 20,0 21-Nov-91 338.8 160.0 160.0 21-Nov-91 364.1 60.0 5880.0 21-Nov-91 389.1 120.0 120.0 21-Nov-91 413.8 20.0 20.0 21-Nov-91 189.0 100.0 120.0 16-Nay-96 123.3 600.0 600.0 16-Nay-96 277.2 300.0 300.0 RECEIVED MAY ::~ '1 1996 Alaek~ 01t & ~a~ Cons, Commission Anchorage KUPARUK RIVER Uh, i' 20" DIVERTER SCHEMATIC I4 Z 5 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16' CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE. 4. 20'-2000 PSI DRILLING SPOOL WITH ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20'-2000 PSI ANNULAR PREVENTER. R E C E iV E D DKP 11/9/94 Alaska Oil & Gas Con,~. (~omlnission Anchorage i 7 , 6 5 4 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. P_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ~ OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOPSTACKTEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHEC~ THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. :~ CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VN_VES. ~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)O PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 30(X) PSI FOR 3 MINUTES. BLEED TO ZEFIO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1. 16' - 2000 PSI STARTING HEAD 11" - 3000 PSI CASING HEAD 11' - 30(X) PSI X 1~5/8" - 5(X30 PSI SPACER SPOOL 4. 13~/6- - 5000 PSI PIPE RAMS 5. 13~/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL ENES ~ 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 195/8" - 5000 PSI ANNULAR 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY CO(~S AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. l& RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCONIODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. RECEIVED MAY ,3 Alaska Oil & G~s Cons. Commission Anchorage FIELD &'POOL WELL NAME..,~/..., ,..~/~-/,~ PROGRAM: exp [] dev~reddl [] serv [] wellbore seg [] ann. disposal para req ~ GEOL AREA ?' ? C) UNIT# //'~,.._~/'~::P . ON/OFF SHORE ,,-"3 ~ WELL PERMIT CHECKLIST ADMINISTRATION INIT CLASS ,_,~,~.,~"' N N N N N N N N N N N N N ENGINEERING APPR DATE 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 drlg unit boundary ..... 6. Well located proper distance from other wells ......... 7. Sufficient acreage available in drilling unit ........... 8. If deviated, is wellbore plat included ...... ........ J.' 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 ......... 14. Conductor string provided ................... (~ N 15. Surface casing protects ail known USDWs 's~lr~ ~s~ 16. CMT vol adequate to circulate on conductor ~& ....... 17. CMT vol adequate to tie-in long string to surf csg ....... Y 18. CMT will cover ail known productive hodzons ......... ~N 19. Casing designs adequate for C, T, B & permafrost ...... (..~N 20. Adequate tankage or reserve pit ................ 21. If a re-drill, has a 10-403 for abndnmnt been approved .... 22. Adequate wellbore separation proposed ............ 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schematic & equip list adequate .... .C~ N 25. BOPEs adequate ........................ ~ N -26. BOPE press rating adequate; test to ,_:~<~:~(::~ psig.(~) N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ,,~ N 28. Work will occur without operation shutdown .......... ~ N 29. Is presence of H2S gas probable ............... L_T,) N REMARKS GEOLOGY ./ -- 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N J ~, ,/,¢~ 31. Data presented on potentiaJ overpressure zones ....... Y,, ,,,~, /'l.,,/~// u' ,~ 32. Seismic analysis of shallow gas zones ............. .~..N. 33. Seabed condition survey (if off-shore) ........... /,/.Y N AP__PR DAT~E ~ 34. Contact name/phone for weekly progress report, s, ,.../... Y N [~ ~'~'"'~"'/~'~ G EO LO GY: lexp,oramryonn/]/ ENGINEERING: COMMISSION: JDH_,.,/' JDN TAB Comments/inst~'uctions: HOW/]jb- A:~FORMS',chektist rev 4796