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Home My WebLink About184-103 Ima~Project Well .History File Coverage 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. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, NofType [] Poor Quality Originals: [] Other: NOTES: ,,~BREN VINCENT SHERYL MARIA LOWELL [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing . BEVERLY BRE~ SHERYL MARIA LOWELL Scanning Preparation ~ X 30 "_~L~_ + ~ - TOTALPAGES /7,~v BY: BEVERLY BREN VIN~MARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES } i~~UNT MATCHES NUMBER IN SCANNING PREPARATION: '/.~. YES NO F NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA General Notes or Comments about this file,: LOWELL DATE: /8/ Quality Checked Ill Illllllllll • ~r-' , , ConocoPhillips Al~ska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~~~~~~~D ~~~, 3~ ~ ~ ~oQ~ ~_~, ~ ~tk ~: ~~~s i~~r~~. ~orrnmssion ~nehorag~ ~-t~ '' 1 ~ a~ ~ ~3 ~~ Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, 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 was pumped September 20~' and October 13th 2009. The corrosion inhibitor/sealant was pumped October 1 Sth and 31 St + November 1 St and 2"d 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. mcerely, ~ Perry Kle~~ 1~~, ~,,~ ~~ ~ ~t1~~ ~-'~4~J~~b~rE.+~ z~~W' 4 <.. ~7 ConocoPhillips Well Integrity Projects Supervisor .. ~ • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 ~~ ~n ~~ R ~K Par~ Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corzosion inhibitor/ sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 500292Q9740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2G12 50029212220000 1842060 25' 4.5 26" 10/13l2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10l31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/172009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" tdA 5.1 11/2J2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11 /2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11l1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11 /1 /2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 16" NA 16" ~ NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 ~~ n~~~~, ~~ I" i ~a ~c~t~um~erger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ., ~~ ~ ~ ~ ~ ^~ ~~~ ~~1 ~+ Well Job # Log Description I J ~?~..~{ it ~q NO. 486T Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 09/05/08 1J-127 12096529 INJECTION PROFILE ~ - ~ 08/14/08 1 1 1 R-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE 08/17!08 1 1 iJ-122 12066542 MEM INJECTION PROFILE / (~ 08/18!08 1 1 2D-09 11978477 PRODUCTION PROFILE +{- (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE L/ - p 08/19/08 1 1 iJ-105 12066543 MEM INJECTION PROFILE gip'}- I(p 08/19/08 1 1 2E-12 11996653 SBHP SURVEY C, I G.(-. ~ 08/21/08 1 1 iJ-156 12080419 INJECTION PROFILE ( 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q -( 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ( ` 08/22/08 1 1 2D-05 12080422 INJ PROF/LDL ~ - {t'p - 08/23/08 1 1 iH-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 28-03A 11996656 PRODUCTION PROFILE ~ 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY app- l(p / 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / --' ~ $-Q 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE ~ '- O~ ~/4 08/30/08 1 1 2E-13 12080431 SBHP SURVEY ~ - `~G 08/31/08 1 1 2E-14 12080432 SBHP SURVEY ~-(•- 08/31/08 1 1 1B-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 1H-18 11996666 INJECTION PROFILE - ~( 09/03/08 1 1 F-10 11996660 PLUG SETTING RECORD 08/28/08 1 1 iG-05 11996665 PACKER SETTING RECORD 09/02/08 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. r~ U e e RECEIVED DEC .2 6 2005 .... Omm~t'i 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other ¡'¡~orage 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 184-103/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21137-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 126' 20-09 8. Property Designation: 10. Field/Pool(s): Kuparuk River Field Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7900' feet true vertical 6272' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 3761' 9-5/8" 3887' 3148' PROD. CASING 7744' 7" 7870' 6246' Perforation depth: Measured depth: 7563-7579,7592-7641' true vertical depth: 5989-6002, 6012-6053' -C CO, t Zmj\", Tubing (size, grade, and measured depth) ötANNE.C Dt . t~; . ;...,) 3-1/2" , J-55, 7532' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' HYD SET RETR. pkr= 7501' SSSV= SSSV SSSV= 1921' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubina Pressure Prior to well operation 111 235 511 1232 150 Subsequent to operation Not tested 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 if C.O. Exempt: N/A Contact McConnell / Loveland 659-7224 Printed Name rry Dethlefs O~ --- Title Problem Well Supervisor / L,ft-.? A..s--- Signature L ./:' x...--' Phone 659-7224 Date y~ ------ / ) , STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONs4I;;~ id tJ. Gas {'ons C n Form 10-404 Revised 04/2004 L RBDMS BFL DEC 2 7 2005 Submit Original Only ) ') ConocoPhillips Alaska, Inc. REPORT OF SUNDRY OPERATIONS 10-404 2D-09 (PTD 1841030) A tubing patch was set in Kuparuk we1l2D-09 on 12/16/05. The operations summary is as follows: 12/05/05: TAGGED TD @ 7717' RKB. SET NIPPLE REDUCER W/2.25" CAMCO D PROFILE, IN D NIPPLE @ 7522' RKB. TESTED REDUCER SEAL W/ 2.25" CAT SV. IN PROGRESS. 12/06/05: PULLED 2.25" CAT SV FROM NIPPLE REDUCER @ 7522' RKB. 12/16/05: SET A 3.5" UNIQUE PERMANENT TUBING PATCH @ 7442-7462'. PATCH ill = 2.36" . 12/17/05: TIFL PASSED POST PATCH. Perf (7592·7641 ) I - Perf (7563-7579) TUBING (0-7532, 00:3.500, 10:2.992) SOS (7531·7532, 00:3.500) - NIP (7522-7523, 00:3.500) [] PKR (7507·7508, 00:6.151) PBR (7492-7493, 00:3.500) [_. I Gas Lift MandrelNalve 5 (7448-7449, Gas Lift MandrelNalve 4 (6684-6685, Gas Lift MandrelNalve 3 (5564-5565, Gas Lift MandrelNalve 2 (4095-4096, Gas Lift MandrelNalve 1 (2002·2003, J SSSV 1921·1922, 00:3.500) .,-._Gräc:lel .. Throad I J.!,1j 1.1 ,'I <: =: mmary ::::::: ...... TVD ..Tn'ziñë-"ï ·Statu~Jï:t...r~ÞF; . Date ._i..J)pÐolllmont 98D.60U2 A-5 ,16 4 10/15/19119 API .¡, ¡ 1°¡, ;.'", / 012 - 9053.:='1. ....A-4 .:._! 49 .:, : 4 9/16!19~I IPE HI l' Ii, /,11·," : i:: ~;!'::!'olslValves ...... t!1: I VI! Man' ¡'Mãñ-TYPEï V Mfr'" T\j"fÿpe' j V OD : Läneh Port Mfr . I / / MH 'F"¡\m~ i "'GLV' i 1.0 I BK II II.'> I . MH ! FMï~'" . Gl:-1/'-" . 1.0' BK' I. ::,!i '~u; o ' MH . FrvïAo'- . ,GLV --:--{O· BK (I h¡ 55 1 .. --: ==ß~ I ~~~~_~C:.' . '~~~-....:~{.g ~~ :: :;:~ ~5; í.i:ill¡J':õ I!::¡U).I?~tE..) - JEWELRY..___......i Vi) Typ.~_.__:. - SSSV Baker 'FVL' -locked out 1 e.z.. PBR Baker w/1 0' stroke - PKR Baker 'FHL' hyd set Retr. NIP Cameo 'D' Nipple NO GO SOS Baker TTL .e.. c......-- ..:z ¿...- ;; , I ;; " :U!! /:~i : ~}::; i;~~; ID Hi:' I:W; ¿,J$I, . :.~;:1;¡I~~~::,J 1:~" - ~ :=-:j=;~iiJ~; 13 0 í;_-;¿IH::¡ U li;,j/:;II', I n;:;-;i:::'1 .:) Vlv Crnnt . ..---B.ef Log Date:. ___..__ 7583 I TO: 7900 ftKB "-/27/2005 =M"~x Hole I\~ ;SQ..dog @'3800 ·~C. NJ - ALL STRINGS w Si~ ''r~p =~ß..ottom. '~--j"VD JR 16.000 I [) : 110 I 110 'JG 9.625: 0"-" 3887 "-3148 ING 7:00U . :.-----0 "1 7870' "'-6246 TUSING < » .... .....--. . ........_L..... .... Top __~___.·BõttOriï-·i [) : .......l§~2 i . TVD'- --:~963 __ ---Wt'" 9.3[ 62.50 36.00 26.00 í1Gr~.da H-,.J J-:,', J.~', Thread Last U ,ate: T¡\: i C'I) 11, 0;(::' T e: PROD Orig 8/10/1984 Completion: LastW/O: Rev Reason: - ., '! 'if ~,;: I" '.j /,1,;01 !~j:l: e ConqcoPhUUps At$$k~, tne. e KRU 2D-09 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 995011 \.. _ t D3 Kuparuk \ ~ '"'1 Schlumberger RECEIVED NO. 3615 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth jiLt"'< ? 1 Znn; u c.. L, ~ ...n" '/ . C ffi-i~":;~n ~Gü&GasCooS. .c 11\\""'''-'-''.1 Anchorag€ Field: ""=~~ Well Job # Log Description Date BL 1 Y -19 11144040 PIEZO SONA TOOL 11/19/05 1 1 Y -27 11072935 PRODUCTION PROFILE W/DEFT 11/22/05 1 2D-09 ,) - I,' - 11072933 SBHP SURVEY 11/18/05 1 1 R-15 ¡ 11072932 SBHP SURVEY 11/18/05 1 / 3F-05 N/A PRODUCTION LOG 11/13/05 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE WIDEFT 09/10/05 1 1 Q-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1 E-33 N/A GLS & BHP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12/03/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1C-07 11141231 PRODUCTION PROFILE WID EFT 11/30/05 1 1 Q-09 11141233 INJECTION PROFILE 12/02/05 1 3B-16 N/A INJECTION PROFILE 12/08/05 1 1 Q-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 ~~ 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 1 Q-1 01 11144044 MDT 11/24/05 12/20/05 Color CD --"-----<= Î I 1 DATE&~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. SIGNED: 5t;At~NED ~JAN 3 G 2005 SChlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # 2C-05 2Z-09 2D-09 3F-03 3F-01 3F-15 1 F-03A 1 G-17 1 J-164 3G-25X 1 Q-20A 11072930 11057062 11141218 11141219 11057064 11057065 11141222 11141221 N/A 11141229 11144038 SIGNED:¿>'~C~(:.' ,__ ~ - fÎ J EC;El\JE:O /'" C-\ ¿ 1 ~~}J5 i\J?i \D0 ,~~ GG.5 f))13. CœT;;;,Ü;;-s;ct NO. 3604 Com pany: Field: 11/18/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 1 00 ~:. Anchorage, AK 99501 _. tQ}.f . :/. Kuparuk \b0c.-''' BL Color CD ~ 1 1 1 1 1 1 1 1 lú3-0CP¡ UL lÔ5-- \:3& LJ1 C ¡~-+- IÒ3 j '65 -';'>d1 i.I '! ( iSS-dd5 ¡55 -<~cr~, u¡ C:.... ,q~.. 09lL/ i<-1C¡ -O~:) .205 - I 'Í-'t- J cUP - i 30 /q5 - f 5/¿, }\nt:~oragf~ . r ') Û 2005 . . r..\~r;, t;.~Ov w ii 5CAN~"þ,b t, Log Descriptior'i- Date INJECTION PROFILE INJECTION PROFILE LEAK DETECTION LOG INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE USIT SBHP SURVEY SBHP SURVEY 1~-lD~ 11/02/05 11/03/05 11/04/05 11/05/05 11/05/05 11/07/05 11/08/05 11/07/05 11/12/05 11/16/05 11/17/05 1 1 1 -. DATE: n)v-lloJ:) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ r"\ (~J.' l"l-r Î,:\ C'1""r'J re '.', } 11'\ \ I' b' ) :' \ I Q1¿ t LJ'J .1 L [ill ~ /Æ ~!Æ ~ lK( t4~ ¡ ! I , / í f I / t i FRANK H. MURKOWSKI, GOVERNOR . AI/ASIiA. ORAND GAS CONSERVATI ON COMMISSION May 12, 2004 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 ¡g L/--!6 3 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2D (KRU 2D) pad on May 6, 2004. Attached is a copy pfthe Inspection Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective May 6, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2D must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, 1-/ ð ;(JAþ7 me! T. Seamount, Jr. Commissioner Attachment cc: AOGCC Inspectors (via email) Safety Valve & Well Pressures Test Report - Review Reviewed By: P.I. Suprv Comm Pad: KRU_20 Inspection Dt 5/6/2004 Inspected by Chuck Scheve Interval: InspectNo: svsCS040507072635 Src: Inspector Field Name KUPARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Reason 90-Day Well Number Permit Number Separ PSI Set PSI UP Trip Test Test Test Code Code Code OateSI Oil,WAG,GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI YesINo YesINo i 20-13 1840120 98 70 60 P P I -OIL 65 P I-OIL -. 20-12 1840940 98 70 P I. I 20-09 1841030 98 70 65 P P I -OIL ! 20-08 1841270 98 70 65 P P I-OIL ! 20-06B 1981760 98 70 65 P P I-OIL I 20-03 1841530 98 70 65 P P I-OIL ! 20-15 1841600 98 70 50 P 4 I-OIL 1000 1000 150 Yes Yes IA x OA communication : 20-01 1841710 98 70 0 10 P I-OIL L ) Comments Performance Pilot on well 20-0 I failed to trip on initial test, was replaced and passed retest. Surface Safety Valve on Well 20-15 had very slow leak when pressure tested. Valve to be repaired and retested by operator. Wells 8 Components 16 Failures 2 Failure Rate 12.5% ) Wednesday, May 12,2004 Y.* Alaska Oil and Gas Conservation Commission Safety Valve SYstem Test Report Operator: prillips Submitted By: Chuck Scheve Date: 1/28/01 Operator Rep: Eamie B,,amdt,, Field/Unit~ad: Kuparuk._ .. / KRU / 2D Pad AOGCC Rep: Chuck Scheve Separator psi: 'LPS .... 9,9 HPS Well Permit Separ Set L/P Test Test Test Date , o~ WAO, o~J, Number Number PSI PSI Trip. Code Code Code Passed GAS or CYCLE 2D-01 1841710 '99 70 65 P P .... 0IL 2D-02 1841520 2D-03 1841530 ............. 2D-05 1841260 3750 2600 1750 P'" 7 "' WAG · , _ 2D-06B 198176~ 99 L 70 " 55 .· P P " OIL 2D-07 ' 184i430 .... 3~50 2000 1850 P '" P .......... WAG 2D-08 1841270 99 70 60 P P OIL 2D-09 I 1841030 9'~] " 70 55 P" P .......... 0IL 2D-10 1841010 2D-11 ' 1840'990 , L , . , 2D-12 1 ~0940 '- 99! 701 60 P P ' OIL 2D-13 1840120 99 70 .. 60·_P P OIL , , , 2D- 14 1841590 2D-15 1841600 991 70 60 P P OIL 2D-16 184'f610 ........ Wells: 9 Components: 18 Failures: 1 Failure Rate: 5.56% [] 00 ray Remarks: ..Surface. ,safety on 2D-05 not tested due a slow leaking wing valve Grove valve could be closed due to snow drffis. RJF 1/16/01 Page 1 ofl SVS KRU 2D Pad 1-28-01 CS.xls MEMORANDUM TO: THRU: FROM: Julie Heusser, ~' Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation COmmission DATE: SUBJECT: Chuck Scheve; Petroleum Inspector January 28, 2001 Safety Valve Tests Kuparuk River Unit 2D & 2E Pads Sunday, January 28, 2001: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2D & 2E Pads. As the attached AOGCC Safety Valve SyStem Test Report indicateS I .WitneSsed the testing of 9 wells and 18 components with one failure on 2D Pad and 5 Wells and 10 components with one failure on 2E Pad. The Surface SafetY Valve on Well 2E-16 had a slow leak when pressure tested. This valve will be serviced and-retested by the operator. The Surface SafetY Valve on well 2D-05, a WAG injector, could not be tested due to a leaking wing valve. This valve will be tested as soon as the wing valve is repaired. Earnie Barndt conducted the testing .today he demonstrated good test procedure and was a pleasure to' work with . All the wellhouses entered at these locations were clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 2D & 2E Pads in the Kuparuk River Field. KRU 2D Pad, 9 wells, 18 components' 1 failure 5,56% failure rate KRU 2E Pad, 5 wells, 10 components, 1 failure 10% failure rate 24 wellhouse inspections Attachment: SVS KRU 2D & 2E Pads 1-28-01 CS X Unclassified Confidential (Unclassified if doC. Removed) SVS KRU 2D & 2E Pads 1-28 01 CS.doc Alaska Oil and Gas Conservation CommissiOn Safety Valve SYstem Test Report Operator: Prillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve -Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupar~...._ / KRU / 2D Pad. Separator psi: 'LPS 99 HPs . , 1/28/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GI~IJ, Number Number PSI . PSI :~ Trip Code Code Code Passed GAS o~(.~CI~ 2D-01 1841710 '99 70 65 P P OIL 2D-02 1841520 I 2D-03 1841530 ~- 2D-05 1841260 3750 2000 1750 P 7 ' wAG 2D-06B 1981760 99i., 70 55-P P ~ 'oI'L 2D-07 1841430 ~750 2000 . . 1'850 P P ' 'WAG 2D-08 - 1841270 99 70 60 P P ~ OIL 2D-09 1841036 99 70 ' 55 P . P ' ~ OIL 2D-10 1841010 .......... 2D-11 1840990 · i 2D-12 1840940 99 70 60 P P ~ OIL , 2D-13 1840120 99 70 , 60 P P oIL 2D-14 1841590i 2D-15 1841600 99 70 60 'P P ' ' OIL 2D-16 1841610: . Wells: 9 Remarks: 'Components: 18 Failures: 1 Failure Rate: 5.56% [] oo oar 2D-05 not tested due a slow leaking wing valve Grove valve could on i be closed due to snow drifts. RJF 1/16/01 Page 1 ofl SVS KRU 2D Pad 1-28-01 CS.xls Alaska Oil and Gas Conservation COmmission Safety Valve System Test Report Operator: Phillii~' Operator Rep: Earnie Brandt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/PM: Kupamk / KRU / 2E Pad - Separator psi: LPS 99 HPS 1/28/01 I ii i i i Well Pemit Separ Set L/P Test .Test Test Date Oil, WAG, GIN J, Number Number, , , PSI PS, I Trip Code ,,C°de Code Passed GAS or CYCLE 2E-07 1931040 2E-08 1931890 99 70 60 P -P - 2E-09 1842400 , , 2E-10 1842300! 99 70 60 P P , , , 2E- 11 1842260' 99 70 50 P P 2E-15 1841890, 99 70 50 · P P - ' ,2E-16' 184i900 991' 70 ' '50 P 4 .... Wells: 5 Components: 10 Failures: 1 Failure Rate: 10.O0°/f3 9o my Remarks: Surface safety on 2E-16 had Slow leak when pressure tested. Valve .will, be .serviced a retested ,by operator. ~ i i i RJF 1/16/01 Page 1 of 1 SVS KRU 2E Pad 1-28-01 CS.xls PERMIT DATA ~ AOGCC Individual Well ~ Geological Materials Inventory T DATA_PLUS Page: 1 Date: 02/10/95 RUN DATE_RECVD 84-103 1281 84-103 407 84-103 DWOP 84-103 SURVEY 84-103 CBT/VDL 84-103 T 3871-7829 DIL/FDN 1-4 R COMP DATE:09/16/84 R 08/01-09/17/84 08/11-10/31/84 R 0.00-7900 GCT SCHLUMBERGER L 6700-7768 1 COMPUTER PROCESS L 7450-7710 84-103 DIL/SFL/GR 84-103 DIL/SFL/GR 84-103 DNL 84-103 DNL 84-103 DNL L 3895-7834 1 L 3895-7834 1 L 7250-7809 RAW DATA L 7250-7809 POROSITY L 7250-7809 RAW DATA 08/31/1984 02/21/1985 02/21/1985 02/21/1985 10/26/1984 10/29/1984' 10/29/1984 10/29/1984 10/29/1984 10/29/1984 10/29/1984 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS yes no yes no ARCO Alaska, Inc. Post Office B0"~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION 2D-09 Fracture 2D- 12 Fracture 2H-11 Fracture 2X-14 Perforate 3K- 11 Fracture 3M-05 Fracture 3M-14 Fracture 3M-19 Fracture 30-02 Fracture 30-08 Fracture 30-18 Fracture If you have anony questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering S. P. Hoolahan~r~~ ATO-1226 Well Files (w/o attachments) Alaska 0il & Gas Cor~s. C, om~'~ss'to~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCornpany .-.~- STATE OF ALASKA '~- ~ 0 ~ OIL l~/qD G~ CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 11. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well _ Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 370' FNL, 59' FEL, Sec. 26, T11N, RgE, UM At top of productive interval 1458' FNL, 1270' FEL, Sec. 25, Tll At effective depth 1488' FNL, 1135' FEL, Sec. 25, Tll At total depth 1499' FNLr 1085' FELr Sec. 25r Tll 12. Present well condition summary Total Depth: measured 7 9 0 0' true vertical 6271 ' 5. Type of Well: Development Exploratory Stratigraphic Service N, R9E, UM N, R9E, UM N, R9E, UM feet feet Plugs (measured) 6. Datum elevation (DF or KB) 126' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-09 9, Permit number/approval number 84-103 10. APl number 5o-029-21 1 37 11, Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 7787' feet true vertical 61 75' feet Junk (measured) None Casing Length Size Cemented Structural Conductor 1 1 0' 1 6" 224 Sx CS II Surface 3 8 8 7' 9 5/8" 1765 Sx Intermediate Production 7 8 7 0' 7" 550 Sx Liner Perforation depth: measured 7592' - 7641' true vertical 6011' - 6049' Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55, 7532' Packers and SSSV (type and measured depth) Baker FHLr 7506'~ Baker FVL, 1921, 13. Stimulation or cement squeeze summary Refrac A Sand Intervals treated (measured) 7592' - 7641' Treatment description including volumes used and final pressure Pumped 301~100 lbs of light weight pro[ 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby certify that the foreg.oing Measured depth 110' 3887' 7870' True vertical depth 110' 3146' 6246' Form 10-404 Rev 06/15/88 RECEIVED S EP 2 B 1992 Alaska 0il .& Gas Cons. Comm'tssl0n 'A n~,hnr~nR ,pant (LWP) in I to 14.9 ppa stages. Last WHTP=5176 psi. Renresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Press Tubing Press 970 514 10 1 400 170 2615 1876 259 1825 196 16. Status of well classification as: Oil X Gas ~ Suspended is true and correct to the best of my knowledge. TiUe PETROLEUM ENGINEER Service SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~_, Subsidiary Of Atlantic Richfield Company 'TRACTOR Rf~MARKS FIELD- DISTRICT - STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDA~/s IDATE RECEIVED · S E P 2 B 1992 Alaska Oil & Gas Cons, Comm[sS'tor~ Anchorage lt~.L. · CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report °F F miles IWincl VeL knots J Slgned~ STATE OF ALASKA A~ OIL AND GAS CONSERVATION cOM'I~'~'rON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate ~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 370' FNL, 59' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 5. Type of Well' Development Exploratory Stratigraphic Service 1458' FNL, 1270' FEL, Sec. 25, T11N, R9E, UM At effective depth 1488' FNL, 1135' FEL, Sec.25, T11N, R9E, UM At total depth 1499' FNL, 1085' FEL, Sec. 25, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 7 9 0 0' feet true vertical 6271 ' feet Effective depth: measured 7787' feet true vertical 61 75' feet Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 3887' 9 5/8" Intermediate Production 7 8 7 0' 7" Liner Perforation depth: measured 7562'-7578', true vertical 5988'-6000', Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) 6200' SS feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-09 Producer 9. Permit number 84-103/9-895 10. APl number 5o-029-21 137 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 224 Sx CS II 1 1 0' 1 1 0' 1765 Sx 3887 31 46' 550 Sx 7870' 6246' 7592'-7641' MD 6011'-6049' TVD Tubing (size, grade, and measured depth 3 1/2", 9.3 lb/fi, J-55, 7532' Packers and SSSV (type and measured depth) Baker FHL, 7506', Baker FVL, 1921' 13. Stimulation or cement squeeze summary Intervals treated (measured) Perforated 7562-7578' MD @ 4 spf Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 1150 700 0 680 1450 80O 0 700 Tubing Pressure 210 190 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. --orm 10-404/Rev- 05/17/89 Title Sr. Operations Engineer SUBMIT Ih DU~LI'CATE ARCO Alaska, In~.' ~ Subsidiary of Atlantic Richfield Company IPBDT WELL · 2 D-9 1%7S7, WELL SERVICE REPORT . ./NTRACTOR REMARKS tFIELD - DISTRICT- STATE OPERATION AT REPORT TIME DATE I~OO £b.zo CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK DIST: D5 Fer~mam NOoK Cent File KUPARIJK OPERATIONS ENGINEERING PERFORATION RECORD DS lng 0PN Eng FII~ wEu. ~U~tE: . '~' ~""-".:,° ~ ENO REP: '. TIED IN WITH:. .~o ~. fllL. DATED '$- ,4~6~$.,/& ~.o.~ _i,j:'T. DATED~'-~:~--e'/~' C0rlPLETI0tq DETAILS.' NSK 0J/ES File 0~T£: j lo -, 7---- ~ Pert SE'RY. CO & ENO:. ~,c.d~" ' PERF INT: '7 ~' ~,~. _ "; ~ ?f~ 0UN ' 'ProPOSED" PIUiPos~D ' OU~ ' "(:~L rUH PE:RFOP. AT,~ PeP. F0nATmN5 LeNOtH totep HO. (mO-DIL) (md-CET) (ft) ~ .j ii i i ii i i i i ii i i i · i i i i · i (' ~ Tlr'II SETTING 6UN DEPTH COHI"IENT$ SHOT ...... 2. ~';~ .... ') ~'~"T · 7 ~ 0o +.~( . ..i! 2..0 Ts'sT, 7_ ~°-¢ .~~ , , 3?? ,,. ii ii ii ill ii ii i i ii i il _ i i ii BI I I · I · I I ' -- IIII I JI _ _IL Ill Il II ' I ,~l _ Il · STATE Of ALASKA Ab.~SKA OIL AND GAS CONSERVATION COMIV,~ocON APPLICATION FOR SUNDRY APPROVALS Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate ~ Other _ 6. Datum elevation (DF or KB) 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator 5. Type of Well: Development Exploratory Stratigraphic Service ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 370' FNL, 59' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1458' FNL, 1270' FEL, Sec. 25, T11N, R9E, UM At effective depth 1488' FNL, 1135' FEL, Sec.25, T11N, R9E, UM At total depth 1499' FNL, 1085' FEL~ Sec. 25, T11N, R9E, UM 12. Present well condition summary Total Depth: measured Effective depth: 7900' true vertical 62 71 ' measured 7 78 7' true vertical 61 75' Length Size 110' 16" 3887' 9 5/8" 7870' 7" measured 7592'-7641' true vertical 6011'-6049' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet Plugs (measured) feet feet Junk (measured) feet feet 6200' SS 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-09 Producer 9. Permit number 84-10,3 10. APl number 5o-02 9-21 1 37 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool True vertical depth 110' 3146' 6246' Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7532' Packers and SSSV (type and measured depth) Baker FHLI 7506'~ Baker FVL, 1921' Cemented Measured depth 224 Sx CS II 1 10' 1765 Sx 3887 BOP sketch 13. Attachments Description summary of proposal _ A Sand perforations. 14. Estimated date for commencing operation October 9. 1989 16. If proposal was verbally approved Date approved Detailed operation program X.~ 15. Status of well classification as: Oil X Gas Suspended Name of approver Service Pro d u c e r 17. , hereby certify that the (~regoing is true and ~rrect to the~st of my knowledge. FOR COMMISSION USE ONLY 10- Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require OR!GI.N~L SIGNED BY !,''',''-':'''c C SM.~TH Commissioner ~-/~ Date IApprova, No. ! Approved by the order of the Commission Form 10-403 Rev 5/03/89 Date ~,,'~ ~-~-.~' SUBMIT IN TRIPLICATE Sundry Notice - Well 2D-09 Perforate the A5 Sand with a total of 4 shots per foot and 60 deg 'V' phasing from 7563' to 7579' MD. A Sand Pressure (6200' SS) = 2413 psi WHP/FL 3/30/89 NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. Kuparuk Well 2D-09 Perforate A5 Sand 9/29/89 CC: 230DS28DL This procedure is designed to pedorate the A5 Sand and increase production. An E-line through tubing perforating system will be used. Two runs with 2 shots per foot each are required oriented 60 degrees apart which will allow more efficient flow into the welibore. The perforating will be performed underbalanced with a total of 4 shots per foot. 2.) 3.) 4.) 6.) 7.) 8.) Obtain a 24 hour well test. MIRU Slickline unit. Pressure test the lubricator. RIH and tag fill. POOH. If less than 15 feet of rathole below the new perforation interval is discovered during the pre-perf wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. MIRU E-line perforating unit. Pressure Test the lubricator. Tie-in and perforate the following depths: DIL/SFL (MD-RKB) CBL (MD-RKB) Shot Density/Phase ~ 7562' - 7578' 7563' - 7579' 2 spf/+30<' 16' 7562' - 7578' 7563' - 7579' 2 spf/-30° 16' Perforate underbalanced with well flowing (just enough to lower the bottom hole pressure by 300 to 500 psi). After shooting, flow well to clean up perforations. RDMO E-line perforating unit. Return well to production and obtain a 24 hour flow test once well stabilizes. RU Automatic Echometer Equipment and obtain a 60 hour PBU. RD Automatic Echometer Equipment. 4 i i 2 1. SO00 PSI ?" W[LLHF,.AD CONNCCTOR IrLANG[ 2. 5000 PSI WIR[LIN£ RAMS (VARIABLE SIZE) ,3. SOO0 PSI 4 1/6" LUBRICAI'OR 4. 5000 PSI 4 1/6" FLOW TUB[ PACK-Orr ,; _-: I 1, '! ,.H.]REL.. INE, BOP EOU].PHENT. ARCO Alaska, Inc. Date: May 26, 1988 Transmittal #: 7171 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. ARCO Alaska, Inc. . Attn: Sabrina A. McKnuckles Kuparuk Records Clerk~. ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Please aCknowledge receipt and return '"~2D-09 ~ 2~-09 ~2 -14 5-09-88 Well .Test Interpretation Plots 3- 1 -3-88 #1 00839H Bottomhole Pressure/Temp. Printout 4 - 2 5 - 2 8 - 8 8 # 1 0 0 6 4 8 Kupaurk Operations Engineering Water Injection Spinner Data Sheet Both Sands If you have any questions, concerning this or any other transmittals please call me at 265-6835. · Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D & M State of Alaska Chevron Mobil SAPC Unocal ARCO Alaska, Inc."~' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 22, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. The wells are listed below. Well Action Anticipated Start Date 2A-2 Conversion March, 1988 3M-6 Conversion April, 1988 3M-7 Conversion April, 1988 3M-12 Conversion April, 1988 3M-21 Conversion April, 1988 2D-9 Fracture March, 1988 2G-11 Perforate, Fracture March, 1988 If you have any questions, please Call me at 265-6840. Sincerely, G. B. Sma llwood Senior Operations Engineer GBS-pg'0165 Attachments cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlieldCompany STATE OF ALASKA ALASN-,-~OIL AND GAS CONSERVATION COMrv,.._./iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate I~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska: Inc. 3. Address P.O. Box 100360, Anchorage~ Alaska 99510 4. Location of well at surface 370' FNL, 59' FEL, Sec. 26, TllN, RgE, UM At top of productive interval 1458' FNL, 1301' FEL, Sec. 26, T11N, RgE, UH At effective depth 1488' FNL, 1135' FEL, Sec. 26, T11N, RgE, UH At total depth 1499' FNL, 1085' FEL, Sec. 26, T11N, RgE, UM 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-9 Producer Feet 8. Approval number 8-206 9. APl number 5O-- 029-2124600 10. Pool Kuparuk River' 0il Pool 11. Present well condition summary Total depth: measured true vertical 7900' 6271' feet Plugs (measured) feet Effective depth: measured 7787' feet Junk (measured) true vertical 6175' feet Casing Length Size Cemented Measured depth Structural Conductor 110' 16" 224 Sx C. S. II 110' Surface 3887' 9-5/8" 1765 Sx 3887' Intermediate Production 7870' 7" 550 Sx 7870' Liner 7' ,,.,.~-.~,~ _ Perforation depth: measured 7592' 60-~_~MB True Vertical depth 110' 3146' 6246' true vertical 6011'-6049' TVD Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft, J-55, 7532' Baker FHL, 7506', Baker FVL, 1921' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summaryRefracture A Sand with gelled diesel sand time. Intervals treated (measured) 7592'-7641' Treatment description including volumes used and final pressure 525 bbls gelled diesel, 47,000 lb 20/40 sand, 3700 psi. 13. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 811 461 2 1200 134 Subsequent to operation 1795 1441 0 1200 152 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /Y'~/¢,~,,,/,./ ~' ~..~-~~ Form 10-4'04 Re~.-~t~-85 Title Date ~')~ 5/¢ -~ Submit in Duplicate 'ARCO Alaska, In~ .0 Subsidiary of Atlantic Richfield Coml~_..,_~ REMARKS FIELD- DISTFIICT- ST, ATE 3PERATI6N.AT R~=ISO'I:IT TIME WELL SERVICE REPORT · I~/~ 19bo I'-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' I Chill Fact°r I VlslbllltYReport 'F ~'F miles IWInd vel' knots I Signed,~ (_ STATE OF ALASKA ALAS~,,: ~"~L AND GAS CONSERVATION COMh,,.,~._~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [~, Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska; Inc. 3. Address P.0. Box 100360~ Anchora§e~ Alaska 99510 4. Location of well at surface 370' FNL, 59' FEL, Sec. 26, T11N, R9E, UM 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-9 Producer feet At top of productive interval 1458' FNL, 1270' FEL, Sec. 25, A~l~qtivF~N~_e, pt~135' FEL, Sec. 25, Atl~l'd~, 1085' FEL, Sec. 25, T11N, R9E, UM T11N, R9E, UM T11N, R9E, UM 8. Permit number 84-103 9. APl n(~j~ 137 O0 50-- 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7900' 6271' feet feet 7787' 6175' feet feet Plugs (measured) Junk (measured) Casing Length Structural 110 ' Conductor Surface 3887' Intermediate 7870' Production Liner Perforation depth: measured true vertical Size Cemented Measured depth True Vertical depth 16" 224 Sx C.S. II 110' 110' 9-5/8" 1765 Sx 3887' 3146' 7" 550 Sx 7870' 6246' 7592'-7641' MD 6011'-6049' TVD Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft J-55 Packers and SSSV (type and measured depth) BCker FHL. 7506'. Baker FVL, 1921'. 12.Attachments Description summary of proposal ~ Detailed operations program Ref~actu~e A Sand with ge]led diesel sand f~ac. 13. Estimated date for commencing operation 03/16/88 14. If proposal was verbally approved Name of approve, L .¢ -~h ~7t'i Date approved 15. I hereby certify that the~oregoing is true and correct to the~est of my knowledge Signed ~ ~ ~ ~q/~¢-~~-~ Title ~ ~ Commission Use O~ly Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date 2/,~..~ ~'t Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned- .-~ Comm~2m~oner Form 10-403 Rev 12-1-85 by order of ,.~_~ ~ / the commission Date ~:~ Submit in triplicate~/ Kuparuk~Wel 1 2D-9 A Sand ~.Bl~Procedure 3/11/88 : 1) 4) s) 7) 8) 9) MIRU Slickline. RIH to rep.lace GLV's at 2002', 4095', 5564', 6684' and 7448' with DV's. PT tubing to 4000 psi to ensure DV's are in place. RDMO Slickline. MIRU fracture equipment. Install "tree saver". Check diesel for contamination prior to gelling for frac. Check frac sand for fines due to excessive handling. Obtain a sample of the frac sand and the gelled diesel with breaker. Record proppant weight before and after the fracture treatment. Pump fracture treatment per the attached schedule. Expected Wellhead Treating Pressure: WHTPE -- 4500 psi (Based on previous fracture treatment.) Fracture Gradient --0.65 psi/ft (6020' TVD) Tubing Friction -- 160 psi/lO00 ft (7532' MD) ** If treating pressure during the pad is in excess of 6000 psi, shut down job and confer with Operations Engineering. SI well and rig down frac equipment. As soon as practical begin flowback to surface tanks. Initial flowback rate for the first day should be 5 - 10 BPH (120-240 BPD). Record tank straps(rates), choke settings, and WHP's during flowback period. Inspect samples for frac sand. If frac sand is produced, SI well and begin flowback again after 4 hours. Take BS & W samples after every choke change and every 8 hours. Bring well back on production gradually, per normal flowback schedule after first day. Inspect samples for frac sand. If frac sand is found, increase WHP by 100 psi and contact Operations Engineering. Well can be turned into CPF when BS & W is less* than 2%. 10) Once well has completed flowback, obtain a 24 hour well test. Contact Operations Engineering for a new gas lift design. STAGE FLUID DESCRIPTION PRE-PAD SLICK DIESEL/10% MUSOL I GD PAD 2 GD wi2 PPG 3 GD w/4 PPG 4 GD wi6 PPG 5 GD w/8 PPG 6 GD w/10 PPG 7 SLICK DIESEL FLUSH KUPARUK WELL 2D-9 FRACTURE PUMP SCHEDULE 3/10/1988 STAGEVOLUIVE PUMP RATE PROP. ~. PROPPN;T BBLS BPM PPG 100 20 0 - - 250 20 0 - - 36.7 20 2 20-40 M SD 42.3 20 4 20-40 M SD 39.3 20 6 20-40 M SD 36.8 2 0 8 20-40 M SD 34.5 20 10 20-40 M SD 66.8 20 0 - - PROPPANT WT DIRTY VOLUME LBS STG/CUM - - 1 00/1 00 - - 250/350 3083 401390 7106 50/440 9903 50/490 12365 50/540 14483 50/590 - - 66.81656.8 HIT PERPS BBLS 68 168 418 458 5O8 558 608 658 TOTAL SLICK DIESEL = 157 BBL TOTAL MUSOL - 10 BBL TOTAL GELLED DIESEL= 440 BBL TOTAL SAND .- 46940 LBS 20/40 MESH NOTES: Stage 1 consists of Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 12 hour break. Stages 2 through 4 are Gelled Diesel with Iow temperature breaker ( 8 hr break) and without silica flour. Stages 5 and 6 are Gelled Diesel with Iow temperature breaker ( 6 hr break) and without silica flour. The final flush stage should include a volume adjustment for surface equipment between the wellhead and densitometer. This job is intentionally undedlushed by 1 bbl. The blender tub should be bypassed at flush. All fluids should be maintained at 70 to 90 F on the sudace. ARCO Alaska, In¢ Post Office Jx 360 Anchorage. Alaska 99510 Telephone 907 277 5637 ,q I::.; !;;'.') /:'~ I._ ~'::i I< (:'~, ;[ N (;;' ,. ,q 't' 'f' f--.!: !:;.: 1.7..; E.'. 0 Ft .f.) :!.;' C I... I!!: !:;' I< /:i "[' C! .... 'i i 'i !5' [.", ' F:'.,O, f::OX t00560 K'i f..: (_'.' !-l(:l: F:; ¢~ (.'; IE, /:-'l !'-'{ 99 '.iF i 0 .,- ........ :. i '"'2 "" -~? :'~. .. 2):.'.' .... .,. ' .: ,', f: ~::' ~ .,. /';):) ..... : ~' ..: .... ..,.:. ,.::, ~ /'; 7'.. ..' .~ ..-.~.. (-.., /. ..'.' ;-.-" :'::' -~ . . d:: '~ '"'¥" -'7 ~' ! '"' ' '"~'"' ~'!-; .. . ;.? .T.)..- :.':; ,,'.,,, ,:..-, ,7, .7' 'i::' .. % ", "'; T', ,. ¢", ,'", ;'", .-', .; -"~ .', ."---'.."' '';." ... .... i ' .. ": :~!?"' i'''''''/:}"'"';.?':.-." .... 'Z:-? -", r'.-. .... 'i'i --/ '"'":"'-" 'i :"~ .:':- :'" L', -. i .-:t ..... ':::: ""'" ..: ...... i;:: "" !'", ..... i '::' / ,'" i .... :') 6 :::;: 5: · ", r-, ..... ! ,:!!.-/' .... ~ .. ,.-,, ,.... :::..: ,::- 7'..Z -. ,Sm , .-, .-~ .. ~ ,:-, .,.., ,::.. _. ...: Z ..... '" ":' · -., v ... 1 I / '""' i · "; "':" "'" '::' · · "'1 :.: -'1 "'" ~r ~'"' i' ,'". ,'-'. '-." f.:' I..I I::, 1.) &., I I I ,? ..T.: I"l F:' 5.' .Ti': H F:' :!: )3 I"I i::' F: [!: .. I::,' L ;;'~ ;::' i~{-: i ,?.;3 I.-I I='" .!; ;({-: I-'I I':' ,:;' .Ei !"i I::' · · . ".." Y'~ I I"~ ,..'- -"." I"l I" ,?.," f:)I-'I F:' ,? D II I::' 5-' .E: H F:' ,!i; E: I--I ',':' /.7 .f3 I'-I F:' .? .f."': I-I F:' S' E',' I"I F' · ',!:; ~';~ I-'I F:' I-.:,I ~,.', ~. ARCO Alaska, Inc. Post Office B0'3r'~100360 Anchorage, Alaska 99510 Telephone 907 276 1215 , v February 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-9 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L177 Enclosures ARCO Alaska, Inc. is s Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO,_.~41SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-103 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21137 4. Location of well at surface 9. Unit or Lease Name 370' FNL, 59' FEL, Sec.26, T11N, R9E, UN ___~ Kuparuk River Unit At Top Producing Interval , ~ ....... I 10. Well Number 1458' FNL, 1270' FEL, Sec.25, T11N, R9E, UN 2D-9 At Total Depth ~; S.urr.~__~ 11. Field and Pool 1499' FNL, 1085' FEL, Sec.25, TllN, R9E, UM :'~..I-L ~_~-~~ _~, Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126' RKBI ADL 25658 ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/01/84 08/09/84 09/16/84 N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7900'MD,6271 'TVD 7787'MD,6175'TVD YES [~X NO [] 1921 feet MD 1500' (Approx) 22. Type E.lectr c or Other Logs Run D IL/SP/GR/Cal/FDC/CNL, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 224 sx CS II 9-5/8" 36.0# J-55 Surf 3887' 12-1/4" 1065 sx AS Ill & 700 s: Class G 7" 26.0# J-55 Surf 7870' 8-1/2" 300 sx Class G & 250 s; AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) 7623' - 7641' w/4 spf 3-1/2" 7532' 7506' 7592' - 7623' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See Well Hi story ~,ddendum. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED Alaska 0it & Gas Cons. Commission Form 10-407 GRU4/WC31 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk B Top Lower Sand Base Lower Sand .. '- ,. ...... . .,. ~.~O_ ~..-: .--.. ...... -: ~.;, :' _, . .- _ ;- "i,'. ii: ~: .:: "~"~'-"'" -.': "":' ~:~':.':"'~' i;':: ?:: ..... ~': .:,-.. :: ..,~-"..,,~:. ~:~ ....... -~, ........ ~- . ~ ~.:¥; :; ':;"'~'~ .... ~ :~_~ ~ ~.~ ~.~.~.:,~.. -; ,,-~'"'-~'~ ..... .,.~:- ., ........ . ~ : ,'~'. ,~. ...... . .... GEOLOG]CMARK~ERS' -' ~. ;'.. ' ~- ¥ ~-' '-: ~ :": ....... .' ': ': ~-',::- :~'~FORMAT'ION:TESTS~'~. - , ?-~.:: ..:-' ~ -.. Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each )hase. . N/A 7483' 7550' '7686' 5922' 5977' 6090' 31. LIST OF ATTACHMENTS ,,,.~.v,~, ~,,.,,v,~,~.,,,~ ~,~,~,~:,,~.,,,j.~ ,,~, ..v.~., ,,'~ ......... j.~ ~.z .....I~.C rv~' ~_ ~, 32. I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed ~~ ~~ Title ^$soe~l:e Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 2;4 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores ~aken, indicate "none". Form 10~07 ARCO Olland Gas Company Well Hist~ - Initial Report- Daily rpJ~J~J~J and Jubmlt the "Initial Relle~' on the flint Wa¢tneaday alta, a well Is spudded or workover operations are started. Dally wo~ I~rior to alXiddlng Nlould be summarized on the form giving inclu~t~ dates only. ...~. Alaska DS 2D-9 District Ico~,w.parlJl~ or borough I State Alaska I' North Slope Borough I Field Lease or Unit Kuparuk River ADL #25658 Auth. or W.O. no. ~Tltle AFE 902110 I Drill, Complete & Perforate Parker #191 API 50-029-21137 Operator ARCO W.I. ARCO Alaska, Inc. Spudded or W,O. begun lears IHour Spudded 8/01/84 0700 Hrs. Complete record for each day reposed Date and depth aa of 8:00 a.m. 8/Ol/84 8/02/84 8/03/84 8/o4/84 thru 8/06/84 8/07/84 The above I$ correct Signature For form preparatlo d d~JtrJbu'~n,-- ~,~ Pr~Rdurea Manual Sel~tlon 10. 56.24% Prior status if a W.O. 2D-9 16" @ 110' Wt. 9.0, PV 25, YP 42, PH 10.5, WL 17.4, Sol 3 Accept rig @ 2215 hrs, 7/31/84. NU diverter sys. Spud well @ 0700 hfs, 8/1/84. 16" @ 110' 1700', (1590'), Drlg Wt. 9.3, PV 18, YP 30, PH 10.0, WL 14, Sol 4 Drl, DD & surv 12¼" hole to 1700'. .511', Assumed vertical 611', 2.0°, S76E, 610 TVD, 1VS, OS, 1E 914', 10.9°, S78E, 911TVD, 34VS, 9S, 33E 1368', 27.5°, S80E, 1339 TVD, 182VS, 36S, 179E 1647', 36.3°, S73E, 1577 TVD, 328 VS, 67S, 321E 16" @ 110' 3905', (2205'), Prep to rn 9-5/8" csg Wt. 9.9, PV 24, YP 30, PH 10.0, WL 14, Sol 10 Drl & surv 12¼" hole to 3905', 10 std short trip, C&C f/csg, POOH. 1810', 37.6°, S73E, 1707 TVD, 426 VS, 95S, 415E 2302', 45.6°, S72E, 2071TVD, 755 VS, 190S, 731E 2852', 47.0°, S69E, 2453 TVD, 1149 VS, 321S, l104E 3159', 47.4°, S68R, 2662 TVD, 1372 VS, 402S, 1314E 3870', 49.8°, S66E, 3129 TVD, 1902 VS, 602S, 1812E 9-5/8" @ 3887' 6005', (2100'), Drlg Wt. 9.4, PV 11, YP 6, PH 10, WL 10.2, Sol 4 RU & rn 98 j ts, 9-5/8", 36#, J-55 BTC csg w/FC @ 3805', FS @ 3887'. Cmt w/1065 sx AS III with 1/4#/sx cellophane flake, followed by 700 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 1830 hrs, 8/03/84. ND 20" Hydrl & diverter, NU & tst BOPE to 3000 psi. TIH w/BHA, tst csg to 1500 psi. DO cmt, float equip + 10' new hole. Conduct formation tst to 13.3 ppg EMW. Drl& surv 8½" hole to 6005'.',m ECEI WED 4067', 43.9°, S68E, 3264 TVD, 2044 VS, 657S, 1945E 4442', 39°, S82E, 3549 TVD, 2286 VS, 714S, 2180E 5048', 38.5°, 881E, 4021 TVD, 2664 VS, 762S, 2557E 5680', 37.9°, S84E, 4522 TVD, 3046 VS, 805S, 2940E 9-5/8" @ 3887' 7305', (1300'), RIH Wt. 9.8, PV 15, YP 11, PH 10, WL 9, Sol 8 Drl 8½" hole to 7305', POOH, chg BHA, RIH. 6054', 41.8°, S79E, 4809 TVD, 3285 VS, 839S, 3177E 6553', 39.3°, SSOE, 5186 TVD, 3613 VS, 916S, 3495E 7240~, 36.6~, 582E, 5725 ~vu, 4037 v~, 982~, 39i6~ 8i3o/84 Alaska 0,7 &~Oa$. Cons. Commission Drilling Superintendent ARCO Oil and Gas Company Well History--Interim Instructlonl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative lest on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25658 Complete record for each day while drilling or workover in progress 8/o8/84 8/09/84 8/10/84 JState Alaska tWell no. 12I)-9 9-5/8" @ 3887' 7850, (545'), Prep to log Wt. 9.8, PV 17, YP 12, PH 10, WL 6.4, Sol 9 Drl 8½" hole to 7850', CBU, POH. RU Schl. 9-5/8" @ 3887' 7900, (50'), Chg pipe rams Wt. 9.8+, PV 16, YP 10, PH 10, WL 6.4, Sol 10 RU Schl, DIL/SP/GR/CAL/FDC/CNL f/7840' WLM - 3895', RD Schl. TIH, rm 7703'-7850', drl 8½" hole to 7900', 15 std short trip, C&C f/7" csg. Chg rams to 7", RU to rn csg. 7" @ 7870' 7787' PBD, Inj'g Wt. 10.2 ppg Brine Tst pipe rams to 3000 psi. RU & rn 200 jts, 7", 26#, J-55 BTC csg w/FS @ 7870', FC @ 7787'- Cmt w/300 sx C1 "G" w/3% KCl, .8% D-60 & .2% D-46. Displ cmt w/10.2 ppg brine using rig pmps. Bump plug. CIP @ 2000 hrs, 8/9/84. ND BOPE. Instl'd lower pack-off &tst. RECEIVED 2 l I 85 Alaska Oil & Gas Cons. Commission Anchoraga The above is correct Signature For form preparation and distribution- see Procedures Manual Sectlon%llO, Drilling, Pages 86 and 87 IDate 8/30/84 JTit,e Drilling Superintendent ARCO Oil and Gas Company' Daily Well h tory-Final Report Instructions: Prepare and submit the "Final Report" on the firsl Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test dfita in blocks provided. The "Final Repo,t" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Kuparuk River Field County or Parish Lease or Unit North Slope Borough ADL 25658 Auth. or W.O. no. AFE 902110 State Alaska Well no. DS 2D-9 Title Drill~ Complete & Perforate Parker t/191 API 50-029-21137 Operator A.R.Co. W.I. ~otal number of wells (active or inactive) on this i Icost center prior to plugging and I ARCO Alaska, Inc. labandonment of this well I 56.24% Spudded or W.O. begun Date IH°ur I Prior status if a W.O. / I Spudded 8/01/84 | 0700 Hrs Date and depth Complete record for each day reported as of 8:00 a.m. 8/11/84 thru 8/13/84 Old TO 7" @ 7870' 7787' PBD, RR Pmp 300 bbls H 0 & 10 bbls diesel dwn 7" x 9-5/8" ann. Arctic P~k w/250 sx AS I cmt, foliowed by 59 bbls it wt Arctic Pak. RR @ 0600 hrs, 8/10/84. New TO Released rig Date 0600 hfs Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data 7900' (8/9/84) Pa Oepth IKind of 8/10/84 I Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7787' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day [ FCFIVF Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ' 'Ef~'~ti~e corrected The above is correct D Date I Title AilCh 0[~.g~ 8/30/84 I Drilling Superintendane Signature For form preparation and di~rlbution, see Procedures Manual, Section 10, Orilling, Pages 86 and 87. 0mmissto~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Repo~t" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Repo~t" should be submitted alee when operetlOll~.~llJNieflded for ~ Indefinite or appreciable length of time. On workovers when an official test is not required upon completion, repo~ completion and rep~d~l in blocks provided. The "Final Re~" form may be used for reporting the entire operation f space is available. District .ICounty or Parish I Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no. ITitle I AFE 902110 North Slope Borough ADL #25658 IAccounting cost center code State Alaska IWell no. 2D-9 W/O Completion WWS #1 API 50-029-21137 Operator A~CO Alaska, Inc. Spudded or W.O. begun Completion A.R.Co. W.I. 56.24% Date 9/15/84 I otal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well our I Prior status if a W.O. 0130 Hrs. I Date and deplh as of 8:00 a.m. Old TD 8/26/84 8/27/84 9/17/84 Released rig 0500 Hrs. Classifications (oil, gas, sic.) - .' Oil -. Producing. method Flowing Complete record for each day reported Rn CBL/JB f/7781'-6700'. Rn GCT gyro f/surf-7745'. 7" @ 7870' 7787' PBTD, RR Crude oil Accept rig @ 0130 hrs, 9/15/84. ND tree, NU & tst BOPE to 3000 psi. RU DA, tst lub to 1000 psi, perf w/4" gun @ 4 SPF, 7623'-7641', 7592'-7623'. Rn 6.125" gage ring/JB to 7777' WLM, RD DA. RU & rn 244 its, 3½", 9.3#, J-55 IPC EUE 8RD tbg & lnd w/tbg tail @ 7531', FHL retrv pkr @ 7506'. ND BOPE, NU & tst tree to 3000 psi. Displ w/30 bbls diesel, followed by 245 bbls crude oil. Set BPV, secure well. RR @ 0500 hrs, 9/16/84. INew TO I PB Depth 7900' (8/8/84) 7787' IDate IKind of rig 9/16/84 Rotary Type c~pletion (single, du~l, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. I Date I Reservoir Pump size, SPM X length Choke size The abov~ls~rect Signatu r/e~!· I~/ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Producing Interval C.P. Water % IDate 10/04184 Oil or gas GOR ITitle Test time Gravity corrected Production Oil on test Allowable Gas per day Effective date FEB2119 5 Drilling Superintendent ADDENDUM WELL: 8/11/84 10/22/84 10/29/84 10/31/84 2D-9 Arctic Pak w/41 bbls AS I, followed by 59 bbls Arctic Pak. RU Dowell to frac; gel fluids. Instl tree saver. Tst ins to 5500 psi. Pmp'd 100 bbls gelled H~0 pre-pad @ 19 BPM, 4660 psi. ISIP = 2500 psi. Perf friCtion press = 638 psi. Pmp'd 50 bbls gelled H20 pad @ 22 BPM, 3900 psi. ISIP = 2200 psi. Perf friction press = 570 psi. Pmp 10 bbls gelled H?0 pad @ 15 BPM, 3850 psi. Pmp 35 bbls gel H~O spacer @ 15 BPM, 4000 psi. ISIP = 1950 psi. Perf friction press = 609 psi. Flush w/72 bbls gel/diesel @ 15 BPM/4250 psi. ISIP = 2800 psi. Pmp'd 1500# 100 mesh sand. SI & RU Camco E-line, tst BOPE & lub to 2500 psi. RIH w/CCL/Temp tl, log 7750'-7530', POH, RD & secure well. 7787' PBTD RU Dowei1 CT, press tst to 4000 psi. RIH, pmp'g min rate, diesel .2 BPM to 7641'. SI well, pmp'd 24 bbls of 50% Xylene/50% Egmbe @ .5 to 1BPM, 3000 psi. Chase pill w/12 bbl @ .8 BPM, POH, circ diesel @ .2 BPM. RD. Pmp'd 100 bbls gelled diesel pre-pad. Pmp'd 48 bbls gelled diesel 100 mesh, pmp 45 bbls spacer, pmp 26 bbls 2 ppg, pmp 40 bbls 7 ppg, pmp 68 bbls flush. Pmp'd 1890# 100 mesh sand & 10,836# 12-20 mesh sand in formation. Driliin~ Sup'e~intendent RECEIVED FEB 2 i I985 Aiasl<a Oil & Gas Co.s. Gommissio~ Anchorage DZate SUB-SURFACE DIRECTIONAL SURVEY F~'! UIDANCE l'~ ONTINUOUS 1-~'-! CO L Company ATLANTIC RICHFIELD COMPANY Well Name 2D-9 Field/Location KUPARUK. NORTH SLOPE ,.. ALASKA Job Reference No. 69508 Logged By: MURTLAND/MCBRI DE F E~ 2 ~ ~B5 26-AUG-B4 ~;,O~nlD uted Alask~ 0il & Gas Cons. Commis~:-,, By: ~ch6r~ge R. KRUWELL '. 'I GCT I) I P~':C:f] ur~ AL At, CO AI,,ASK~ Ii.lC. 20-9 KdPRRuK ARCO ALASKA INC. 2D-9 KBPARUK COi4PtJTAT.i. ON DA'IE: 13 5rAP~'EMBi~R PAG~ K~Li, Y Bb$~ING E~EYATIUN~ 126,00 FT ENGINEER: ~[}RTbAhD/MCBRIDE DEPTH MEASURED VERTICAL Vt~R't'ICAU DEVIAT].Oa AZII'auTH Di~PTH DEPTI-i l)r.:PiH OgG ~lIN OEG din O.0u 100.00 200 Ob 300 O0 400 O~ 50O OO 600,00 700.00 800,0~ 9~0.0~ VER'flCA[. ~3ECT I. ON k'EET DdG/1 O0 0.0o -1 26.0u 0.00 O.uO '0.01 0,07 '0.01 0.02 0.22 0.07 0.30 0.37 0.46 1.52 1.60 5.78 2,30 14.6~ 3.41 28.91 3,26 IOU.UO 'Z6.00 200,00 74.00 300.(;O I ?4.00 400,00 7..'/4,00 SOO.U() 3'14.00 599,99 41 '~. 99 b99 . M9 b't 3 . 89 799,.~8 h'73.4B ~9U,,*4 7'/2.44 1000.00 990,3b 8'10.35 13 28 1100.00 1092.85 9o6.8b 16 58 1200.00 1187,4tt 10ol.4~ 20 41 1300,00 1~79,~1 i153,81 24 ~7 1400.00 I369.45 12~3.45 27 ~7 1500 00 ~600 00 ~541.b9 14'~5.59 1700 1800 00 1703.13 1577,.13 37 lEU00U 1781.'12 lt)bS, 72 39 2000.00 1658.09 1'7~2.09 41 8 100,00 1932,13 1806.13 43 15 ~200,00 ~0()~.U~ 18'/a,O~ 44 29 2300.00 2074.~3 1948.83 45 22 2400.00' 2144,'/0 2(.)I~,70 45 b7 7'7 23 g 49,1b $.20 '/9 20 E 75.29 3.91 79 21 E 107.52 3,52 79 10 E 145.85 3.21, 78 44 E 190.06 1.82 70 55 E 238,21 2.71 '13 50 E 291.60 3.96 72 19 E 349,6~ 7Z il E 409.23 1,48 72 8 E 470.90 2,30 S 71 53 E S 71 23 g $ 'Ii 27 E $ 70 b6 E S 70 37 535.26 1.90 602,25 1,85 671.4b 0,93 74~,83 0,76 813.()4 0.74 2500,00 2214.07 20~8.07 45 46 261)0.¢)0 2283,9t~ 21::"1.9~ 45 ~1 2700,00 2353.34 2227,3~ 4o 14 800,('i0 2422.30 22~6.30 40 33 ~900.00 2~90,7~ 2364,7~ 46 53 3000.00 2559.07 2433.07 4't 2 3100,00 2627,'tl 2501,11 4'1 1~ 3200.00 2694.91 256B'91 47 15 3300 Ob 2'762,t. 1 2636.61 4,7 30 3400 O0 2829.83 2703'83 48 9 3500 O0 ~95,98 2'1~9~9~ 48 56 ~600 0U 2961.25 28~5,25 49 32 3700,00 ~026.0o 2qO0.Oo 49 44. ~800,()0 3090.&9 2904,49 49 55 ~900.00 1154.~"? ~0x8,97 4~ 2O S 69 54 E ~84.69 $ b9 i3 E 955.65 S 6~ ~0 g 1027 13 $ 6c~ 21 E 1098:91 S 68 5 g llT1.0b S 6~ 1E 12q3,34 $ 6~i 17 E 1315.88 S 66 8 E 1388,66 S 67 49 E 14ol,4~ S 67 31 E 1534,68 S 07 23 E 1608,79 $ 67 14 E 168],6! S 66 59 E 1758.8q S 6~ b6 E 1834.2'7 S 6~ 36 E 1909o6(. RECq'ANGUuAh COORDINATE6 HORIZ, DEPARTURE NORTH/~LIOTIi ~AST/W~$T FEET FEET FEET DEG : , O.oO N u.o0 g 0.00 N'"":O 0 E u.l] ;~ 0,02 E 0.~' N' '8 56 E 0,11 N 0,05 E O,,!l:~:..,#i,~2 49 E O,lb a 0,11 g 0,20 N'"'~5 36 E 0,11 N 0.41 E O, .. 2 24 g 0.20 $ 1,52 E 1. $ .... E 1.47 S 5.60 E 5,79 4.54 S 14.00 E 14.72'" 7,96 ~ 27.a2 E 28.9.4 ~7,~Z S 73~20 E .~.29 8 76 27 2~,38 $ 104,97 E 107,54 30,6b $ 142,~5 E 145.90 3~.96 S 1~6.13 E 190 16 s 17 9~,22 $ 39'/'27 E 409 23 $ 76 6 E 117.1~ S 456,13 E 470 93 S 75 35 E . 137,02 $ 517,54 E 535,37 S 75 10 58,23 $ b~1.32 E 602.47 8 ~80.3b $ 647~14 E 671,8! S E 203,09 S 714,05 E 742 37 $ ~4 ? E 22~.o~ S 781;60 E 813:80 1.78 250,79 $ 849,46 E ~85'~1 0,76 2'15,95 S 91,~,39 g 957. 4 $ U,32 301,7, $ 9U3,06 E 102,.a9 0.81 328,13 S 1051,10 E 1101,13 $72 39 0,40 355.1~ 5 1118,76 E 1173,79 $ 72 25 E 0.36 382.5~ S 1.186.49 E 1246,64 $ 72 7 g 0,51 409,~4 S 1254.51 E 1319,75 S 71 54 E 0,~2 437.04 $ 1322,79 E 1393.12 8 7! ~3 E 1,01 492,";4 S 1459,51 E 1540.44 $ 2 E 0,72 521,55 S 152~,76 £ 1615,27 S E 0,49 550,72 $ 159~.Ub g 1690,86 $ ~9 ~ E 0,42 580,39 S 166B.86 E 1766,91 S70 49 E 0,52 O10,2b S 17~9.22 E 184~,~7 ~ 70 39 E 2.91 ~40.33 $ ~b09"49 E 1919.44 $ 70 ]0 E A~CO ALASKA iNC. 2b-q KUPA~tJ~ NO~Ttd ~L~)PE, ALASI"A DATE; OF' ,SURVEX: 26 AUGUST kr~bLY HUSIilNG EI~EVA'I'Ii~N~ 125,00 F'I' ~NG]i',EER: NURTGAND/NCBR]DE MEA6UREU 'VERTICAL VERTICAL DEVIATzO~ AZiMUTt~ V~.~I'.[CAI, ['.)t~GuEG KECTANGULA~ C()O[~DINATES HORIZ, DEPARTURE FEET OEG/100 FEEl' FEE%' FEET DEG 4000,Ou 3221.,',3 3(39%.63 40 '%,6 4100.OU ]292,28 3166.28 43 4200. ()0 336~.'17 32.'i0.77 40 26 %3U0.00 3q43.,8 3317.88 39 4400.00 [{521,49 3395.49 39 4500. O0 3599,11 347 ]. 11 39 5 4600.00 35'16.66 ~550.60 39 4700.o0 3754.1~ 30~8.14 4800 00 3~3~.';~ 3755.'1~ ]9 8 4900:0u ]90~.37 ~7S].37 J~ 5 ,q b~ 34 E 1.9a3.12 ,S 60 32 E 2Vt32,84 S 6~ 22 E 211~,6b S '1~ 40 i 2182.07 S ~0 44 F' Z~45.04 S 81 10 E 2307,87 S ~1 9 E 2370.77 S ~1 g E 2433.76 S bz 2~ F. 2496.54 $ 81 28 E 2559.39 5000.00 3987.02 38~1.02 38 58 9~ 3938 98 3~ 34 5100,00 4064, , 5200.00 4143.34 4017.34 38 17 5300.00 4222.12 i096.12 37 47 5400,00 4~01,]~ ~175,38 37 17 5500,00 4381,34 4255,34 30 38 5600,00 4~61,89 %335.89 36 8 5700,00 4~41~84 'i41.5,84 3/ 't0 5800.00 4619.92 t493.72 4U 45 5900,0~ 4~94~91 45b8.91 4[ 18 S 81 29 E 2622,14 $ 8i 41 ~: 2~84.50 $ 81 49 g 27i6.34 S Bi 54 E 2807.67 S 81 57 E 2808,33 $ ~2 15 ~ 2928,08 S 82 26 E 2987,01 5 ~], 24 E 3046,77 S 79 ~1 E 3109.28 S 79 12 E 3175.1,2 6100:00 484~:50 4'/18'58 41 37 6200.00 4~19,27 ~793.2'i 41 40 6400,00' 5069 ~u 4g~3.3u 4(d 37 6500.00 5145:~0 5o.L9.80 39 32 6600,0U 522.5,23 513'37.23 39 5 5700.00 5300,93 51 }4,93 38 58 6800,00 5378,'~3 5252.63 3~ b~ 6900.00 5455,65 53,30,60 ]~ 26 S 79 15 E 3241.28 S 79 7 E 3307.60 S 79 6 E 3.~Y4.03 S 7~ 59 E $440,4~ S 79 38 E 3506,09 S 79 26 E 3570,40 S 79 22 E 3633.55 S 79 27 E 3696.45 5 79 36 E 3759,30 $ 79 4'1 k,; 3821~73 7000.00 5535,21 5409,2i 38 100,00 5614,23 ~468.23 3'1 38 O0.OU 5693.07 5507,67 30 54 7400.00 5855,04 5729,04 35 56 7500.00 59]°.22 7600'00 601~,09 5~92,09 34 17 7700,00 610I,~5 ~975.55 32 7800,00 6180,29 60~0,29 32 0 7900,00 6~71,U~ 01~5,08 32 0 S 79 39 E 3883,51 $ 79 bl E 3944,b7 $ 79 45 g ~005,29 S 79 39 E ~004.45 S 7~ 31 E ~123,26 S 77 35 E: q181,64 S 77 34 E t239,04 8 77 44 E 4294.10 S 77 24 E t147,18 S 77 24 E 4400.18 3.92 3.~4 4.83 4.99 U.26 0.38 0,70 0,25 0.17 V.38 0,~4 0,35 0.68 0,91 0,35 0,58 u,43 0.23 0.56 t~,20 U,~4 1.36 ,57 ,42 0,78 0,54 0,94 0,32 1,51 0,99 1,15 1,26 2.74 0,00 0,00 724.20 $ 7004,14 E 2130 99 $ 0 7 E 744,0~ $ 2Obi,bO E 2194'57 ~ 0 10 g 't5b,03 S 2120.48 E 2255,88 S 0 25 E 765,77 $ 2188.78 E 2318,$, .: $ ::~0 43 E '175.~8 S 2251.15 E 2380.98S 70 59 El' 785,16 S 2313,63 E 2443,23.. ~:?l 15E~ 794.55 $ 2375,93 E 2505.30 $71 30 E ~04.09 $ 243~,32 E 2567,48 ~ 71 44 E 813.4b S 2500,63 E 2629,61 $ 71 58 E ~22 O! S 2552 57 E 2691,39 $ 72 12 E 831259 S 2624:05 E 2752.67 $ 72 24 i ~40,35 S 2685,03 E 2813,46 $ ~2 37 E ~48,~7 $ 2745,40 E 2873.~4.2 $72 49 E 857,1~ S 2804,87 E 2932,9 $ 7] 0 f 865,0b $ 2~63.61 E 2991,42 $ 73 11 E u?~.49 S 2923 U6 g 3050,78 S 73 21 ~ ,83,49 $ 2984:96 E 3112.97 S 73 30 E 895,74 s 3049,74 E 3178~56 S 7] 37 E ~08.17 S 31.14,81 E 3244.50 945,83 S 3310,59 E 3443 05 ~ 74 3 g 95~.02 $ 33'75.23 E; 3508 55 $ 74 9 E 969,73 $ 3438,56 98i.3't $ 3500,76 992,97 ~ 35~2,64 1004,~3 S 3624.53 E 1015,b9 $ 3686,0b 1025,'1'1 $ 3'146,94 g 3~85,07 S 74 40 E 1037,O5 $ 3807,24 E 3940.11 ~ 74 45 E 104~.35 $ 35.67,02 E 4006,61 & 74 49 ~ 1058,95 $ 3925.34 E 4055.66 fi74 54 E 1069.99 S 398],17 E 4124,$8 $ 74 S7 E 1082,20 $ {040,28 E 4182,71 S 75 '0 E 1094,68 S 4096,33 E 4240,07 $ 75 2 E 1106,22 S 4150.18 E 4295,08 S 75 4 E ~.117,7~ S 4202,00 E 434~,13 S 75 ~ E 1129,34 $ 4253.74 E 4401.10 $ 75 7 E 'm ARCO AL, ASKA il'lC. 2D-9 KUPARlJK NORTh ,51.,GPk:, NI..'A~UREU VE~?ICAh VER~'ICAI~ DF~VIATION AZAMUTM CDHPLtI'ATIOt~ DA'rE; 13 ~gP'ZEMHgR PAG~ DATE OF ~URVg~ 2b AUGUST 1984 K~LL~ HLSHING ELEVATIONI ~26.00 VbR'iICAI, [)LJ(;LktG MECTANGULAF C()bRD1NATE~ HORI~t DEPARTURE 6EC~ION SEV~RIT~ NO~TH/SOUTb ~A~T/WEBT DlS~,' AZIMUTH f'E'ET D~G/] u0 FEET FEF,'I FEEX PEG ~q 0 0 F' 0.0u S 7'i 23 F. 49.15 S 71 b3 E. 5~5.2b S 68 1 E 1243.34 S ~t: 34 F 19~3.12 $ 81 29 g 2622o $ 'I'.~ I5 E 32~il $ 7~ 39 [< J~83.51 ('). OO U ,, 0(.) -126,0U 0 2000,00 l~Sb,Og 1'132,09 3000.00 2559.0'1 2433.07 47 5000.Ou 3987,02 3801.02 ~8 58 6000,00 4769.~1 45q3,81 41 35 7000.00 5535.21 5409,21 O.uO O.Ou N o.O0 E 0.00 N 0 0 E J,,2:0 12.31 $ 47.59 E 49.i6. ,.::75 29 E 1,90 13'/,02 S 517.54 E 535.37 ~ 75 10 E 0.36 382.5J S 1186.49 E 1246~64 '5? ~2 7 E 3.92 069.97 8 1877,~7 ~'. 1993,81 S~0 21 E O.j8 ~13,4b S 2500,63 E 2629,~,. I .~ 58 E u.23 90b.l'/ $ 3114.ul f 3244, ' 44 E/ 0,94 102~.71 S 374b,94 E 3885,07 '~'Lr~4 40~. I ARCO AI, A,SKA ,[NC, 2D-9 KUPARUK DATE UF SUR~E¥1 26 AUGUST 1984 KELLY GUSHlkG EhE'V'ATION; 126,00 FT /Ni'EKPOLATI~:[) VAIL, Eg) r'l'ik EV~.I~ 100 ['mET ~J~ SUB-~I:.A DEP%'}I VERIICAb DU(.;UEL, I{EC'I'ANGUbAh COURDINATE,S iiORIZ, DEPARTUR~ &ECTLUN 8~V~RI'IY ~D~'I'h/~U~TH gA~TtW~ST DIST,' AZIMUTH FEEl' [. C;<;/1 UP F E. F'I' FEE3 FEET DEG MIN MEA,SURED VERTICAL VER'I'ICAI~ DlgVIA'I_'IOh AZIMU'Fki DJc, P'I'h ultt l,i DEP'IH DEG Mit, i)I;'.G ;qll~ O,O0 u,JO -lzb.dO 0 0 ~. u U F 26,00 26o00 -100,00 O. ~ S 43 23 g 126,00 ~26.u(, o.o0 0 ~ ~' 45 lb r 226.00 22b.00 lO0.O0 0 ~ S 41 ~O [ 326,00 326,00 200.00 0 ~ I~ 57 37 E 426,00 426.00 300.00 0 7 S 61 10 E: 526.00 520.00 4VO.O0 0 25 S 79 I ~' 626,02 626,00 bO0,O0 ! 43 $ 74 ql E 726.1b 720.U0 hOO.O0 4 28 $ 69 16 f. 826.72 ~20.00 700.00 7 25 S 74 26 E 928.01 ~26,00 800.00 10 51. S 7¢ 49 E 1030 55 1~26,00 ~00o00 14 29 S ?~ 54 F 11 4 41 37 122~.00 1100.00 22 12 S 78 b9 E 1351 lb 1326,00 12OO.Ov 26 26 S 79 15 1464 22 1581.1~ 152b.00 1400,00 33 36 S 74 18 E 1703,78 lb26,0/,) 1500.()0 36 14 S 72 18 1828.84 1726.00 1600,00 37 47 i957,62 1B2~,60 1700,00 40 21 $ 72 3 F 0.00 u.U¢ 0.00 N 0.¢0 0.00 0,00 ¢.00 N O,O0 -0.02 0.14 t,Ob N 0,01 -0,01 0,12 0,14 N 0,03 O,Ob 0.16 0,12 N 0,08 0,11 U,31 0,14 N 0,14 0,53 0.09 0,09 N 0,57 2.1'1 i~,43 0,~/ 5 2,15 7.6~ 2.69 2,13 S 7,37 17,91 3.67 5,4U S 17.10 2091,59 ~92~.U0 1800,00 43 6 2230,81 2020,00 1900.00 44 47 2373 14 2126,00 2OO0.O0 45 ,1~ 2517 07 2220,00 2100.00 45 39 2660 49 ' 2326.00 Z2OO,O0 4~ ~ 2805 39 2426.00 2300,00 46 35 2951 bO 252o.00 2400.o!3 40 ba 3098 3~ 2026.00 25~0,0~ 47 18 3245 ~7 2726.60 2bOO.O0 47 2~ 3394,20 282~,00 2700.00 ~ 6. 33,93 4.06 56.54 3.03 85,78 122,60 4,02 107,79 3,04 220.40 281.0'1 4,73 351'8~ 0,~6 426,76 1,77 507'67 1,93 3545.85 292b,00 2~O0'Oo 49 12 j700 OU 302~,00 2900.00 49 44 3855:14 3126,00 3000.00 49 51 4006.34 3220,00 3100.00 40 3l 4145.86 332b.00 3200'00 41 54 4276.94 3426.00 3300.00 ]9 12 4405.$1 3526,00 3400,00 ]9 6 4534,65 3620.00 3500,00 39 7 1663.68 3720,00 3600,00 39 12 4792,54 3~20,01.) 3700,00 39 7 S 71. 24 F 596.52 S 71 21 f' b93.01 $ 70 41, [ 793.80 $ 69 36 E B96.82 8 66 59 ~, 99B,Sb 8 66 19 E 1102.78 S 67 5~ ~ 120~.24 $ 6~ 16 ~' 1314,69 S 6~ 0 ~ 1422.04 $ 67 32 ~ 1530,40 S 67 20 ~': 1643,02 $ 6C, b9 ~ 1.768.84 S 66 48 E 18'15.88 S flu 34 fl. 19B7.Sb $ 66 44 f: 2083,49 S 73 54 ~. 2167.52 6 80 49 E 224~.69 $ 81 b El 2329.64 $ B1 14 E 2410,89 S B] 24: ~' 2491.85 0 O0 N 0 0 g o:o0 o 0.06 N 8 15 ~ 0,.14 N ~iO 27 f 0.14 N33 8 ~ N 46 47 E O't~''N8 E O. 0 49 , 3 51E 17,9~ S 72 13 g 9,00 S 32,73 E 33,94 $ 74 37 g 13.90 S 54,80 E 56,54 875 46 g 19.50 S 83,54 E 85,79 S 76 51 g 2b.2~ $ 119,~0 E 122.04 S77 39 E 34,'1b 8 164,23 E 167,87 S 78 -~ E 45,32 S 215.87 E 220.58 S 78 8 E 59,9b $ ~';4,b8 E 281 15 S 77 41 E 00,05 S 042.49 E ~51:B5 S 76 44 = 1.81 0,42 0,96 0,55 O,~l 0.52 O.b2 0,36 15~.40 S 575.86 g 590,72 S 74 48 g 220.2B S 763,41 E 794,55. S 73 54 E 255,02 $ ~b0.91 E 897,89 ~ 7~ 29 E 291.48 S 957,05 E 1000.45 5 73 3 E 329,5~S 1064,~4 E 1105,03 S 72 38 E 369,23 $ 1153.02 g 1211,26 $ 72 15 E · 4o9,3v s 1253,]9 t]is, s s 71 449.04 $ 1364.07 g 1420,77 S 71 37 491,11 $ 1455,56 E 1536,18 & 7! 21E 0.46 3,d{.. 2,~3 O, 16 0'~ 0,35 b34,85 $ 1.560,75 E 1649,85 fi 71 5 E 580,39 S l. b6U,~6 E 1'166,91 S 70 49 g 626,80 S 1778,02 E 1885.27 ~ 70 34 E b71.79 S le~2,09 E 1998,39 6 70 21 E 710,45 $ 19'11,~1 E 2095 43 5 70 10 E 740,20 S 2050,55 E 2),80~06 5 70 9 E 756,~2 S 2130,10 E 2260,49 ~ 70 2~ ~ 769,13 S 2210.37 E 2340.~6 $ 70 48 E 7H1,04 S 2290 94 E 2~20,bl S 71 9 E 793.95 $ 2371:28 E 2500,66 $ 71 29 E ARCO AbASKA INC. 2D-g KUPARUK NORTti 5bC, Pr;, AbAbKA COFtPu'.[A'ri(.)i,, DATE: 13 b~PI'E)-~BEF J.N'I~Pt]L, ATr.~) VAIL. F.5 ?~';~: ~.VgP 100 T R MEASURED VERTICAl, V~R'f]CAL DEVlA?IOh AZIMUTh DEPTH V}..RTICAL L'WGbEG FFriT 0.10 0.48 u,17 0.57 1,2a 1.33 0.7~, 0,16 0,57 0,62 t),~('l 0.29 0,81 0,00 0, U (i 4921.45 3926,0() 3HuO,OU 39 ,~6 5050.07 4026.00 39U0.00 38 5177,90 412b, O(, 4000,00 )8 20 5430~90 432~, 0(,, 5555~53 44~6,00 4300.00 36 19 5680 O0 46'26.~0 ~40(;.06 37 28 594~.45 4726,00 ,.~UO.()O 4! 28 b075.~7 4S26.~0 4700.00 41 37 6209 02 492~,00 ~800.OU 6342:72 5026,00 49uO.OU 4~ 6474~: 27 5126,00 bO00. O0 6603 57 5~26.00 blO0.O0 39 5 6732 26 532~,0~ 5200,00 3B 56 0860,80 5426.00 P3C~O,()U ]8 39 6988,]1 5526.~0 5460.00 3~ 4 114,8m 562~,0U bSO0,Ou 37 36 7240.23 5726.00 6600.00 ~]64.09 5~2D.00 5700.UU 3o 3 7487,39 592~.0() 7609.57 6026,00 6900.00 34 , 728,9u 6126,00 bO00.Ou ~846,83 62~6,00 6~00'00 32 7900,00 ' 627~,~ ul~5.0~ .~2 0 79 b I:, 3380.02 79 29 E 3553.99 79 22 ~ 3635.83 79 28 L 3'/16.72 'i9 38 F _t79'i,3b 79 ]9 ~ 3876,32 79 bi F 3953.73 79 42 ~: q029.20 79 .t } ~.1U2.17 S 77 ~b F S 7'7 2,4 F 4309.50 S 77 24 ~.: q372,00 KECI'ANGUUAR COORL, 1NAI'ES liORl~., DI~PARTURE NO~TH/6OOTt~ EAI~'I'/WE$I DiS~, : AZIMUTH F~E:T FEET FEET DEG MIN ~Ot,,O9 S 2~51.70 F. 2580 82' S 71 47 E bl~,lO S 2531'71 E 2660 029.ot 8 2~10,4B E 84~.'t~ S ~8~,01 E ~51.45 S 2763.89 E 2~92 ~61,56 S ~37,57 [ 2965 671.~7 5 ~91~.99 E 3038 ~,4'1 S 2990,32 E 3118 9U(..9~ S 3076,~6 E 3205 917,b4 S 31~3,~6 E 3294,22 fi 7~ 49 g ~3~.38 S 3251.22 E 3382.8~ $ 7] 57 E 9bl,21 S 333~.35 E 3471,22 S 74 5 E 96b,71 5 3422,40 E 3556,~1 ~ 74 13 E 9~I,7~ S 3b02.97 E 3037,95 fi 74 20 E 990,67 S 3582.00 E 3718.65 S 74 27 g 1011.34 S 3662 01 E 3799,10 lU2b,ib 5 3739:85 g 3877'89 S 74 39 E 1039,24 S 38~D'~7 E 3955.15 1052,60 8 3U90,b0 ~ 4030,47 1.065,~9 S 3952.66 E 4103,32 S 74 56 E lo~(.~,b2 ~ 4u~3,06 f 4175,32 S 75 0 E 1096,~2 8 %101,5fl E 4245,44 S 75 2 E l lUg.bb $ a165.21 E 4310,47 1123.19 6 4~25.23 E 437~,94 1129.38 & 4253,74 E 4401,10 I ARCO AL, ASKA 2D-9 KUPARUK INCo IN~]'I~:kP[j[,A'][.:[:' V,~I' L,F:,~ p'I')F; I~ARi,,EN T ¥ 1¢ [-'RDM t, li 126. b922.45 b976.gb 6089.76 6 1 'l 5.2 '1 627 1 O,OO b'19~,45 565u.gb ~963,76 6145.0U PAGE b DATE OF SURYE¥: 2b AUGUST 1984 ~5LLY [~USHING EbEVATIUN: 12b,00 ~NGII]F:ER; F'ILIRTLAI~I)/~CBRIDE F~ SUBFACE bUCATION AT' " ORIGIN=SE:C. 26 TWP' ~IN RGE, RECTANGUbAR CO01~},:[.~ATg8 N~R'£H/SUU~H EAM~/wgST ...... , ';,~ .~ ,,., ~,,'. zo8o.o7 s. ~9~9;51 E 1088,49 $ 9?99,59 g ~16,27 $ 4~95,~7 E ARCO AGASKA 1NC. 2D-q EUPARU~ MARKER TOP TOP BA,SE TO'fAb D[*CPTti (D~IbL~',R) C()mPU,..'aq_'l~)a L)A'i'E: i3 br~"1'El,lbE, R PAGE 7 PA'r~ OF ~URVE¥: 26 AUGUST lgB~ k~I.,bY DUS~ING EbEVA~ION~ 12~,00 F~ ~NGtIiE~R: mUN'rbAND/MCBRIDE T V D 5922, ~;b ~'lgu. gb 5976,9b b850', 95 C(.)bg. 76 5963,76 u271 ,()S 0145,08 SURFACL [,UCATION AT P, RiG]N:$EC. 26 TWP~ RECTANGUUA~ COORDINATES NOR'£H/,SOLI'IH ' EAST/WEST 1080.07 8 4030',54 1129,34 5 4Z~74 E RGE 'm SCHLUMBEROER ARCO ALASKA INC, 20-9 KUPARUK NORTH SLOPE, ALASKA 26 AUOUST 1984 TVW PLOT FROM OCT DATA dOB REFERENCE 69S08 · WELL' 2D-9 SURFACE LOCATION- 370' FNL &'FEL @ SURFACE HORIZONTAL PROJECTION NOR'~H ] 000 REF 69,~08 SCA1.E: = l / ] 000 I N/FT ...... ~ ~ ~ ~ ~ ~ ~ ~ ~ ..... ' : : : ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ : ~ : ~ : : ~7...~ .... ' ' · ...... .... ..... : -3000 ~ : : : ~- : ~ ~ ~. ~ : - ~ ~ : ~ : ~: :~: .~ : ' ':::;~'. .... ~---~----~----~---~'--?---~--'-?'-~ .... ~----~'--'~----c--~----; .... ....... ?-? ' - ....... ~---~ ................... : .... ; ....... ;--~ ........... -'? -- ? ---? "'?-'-~'-'-~"-'~ '--? "-' ...... ~-'-'~'"-?'?'"'?-? ......... ..-~.--~...~-.--~--~.---~-.-~...~..-.~--~---;-.--~-..-~----~---k-k-~---~-~-~---,---~---~----;---~---~--.~---~---~---~ ;-; ...;.--~...;-.-.~.~-L.;---;.-.;.---; ..... ~---~....~.-..~...F~.-.~.-.~.~-~... "+'+'+'+"?'+"e'"~ ...... ~'"~'"~'"'~'"]"'~'"~'"~'"~ ...... ~'"e"+'+"'"'~'"~"+-"~ ...... l'"l'"i'"!'T?'"';'"':'"'~ ....... :'"~'"?"??"?'?"';'"~"'~'"';' ?'"'~'"?'?"?'"; ...... ~ ....... ~"~'"r";'"'; ...... : '""~ ......... ~' ~' ~ "'- '"J -"~'--;---~--'-~ ........ ~-'-;---~--'-~ ...... ~--~-'--~--'-~---~-'-~---~-'-~'-'~' ....... -~"'i'"~"'~'"~"J'"~"'~'"~ ...... ~'"~'"'b'"~-'~"'~'"~'"~'"~ ....... F"F'~"'~"'l'"t'"t'"t'"~ ..... t---~---~--'t--,t---~-- t--'?----~ ....... :---? ........ ~"~'-'?'"~""~"'~'"?"'""-~-"'~ : : : : I : : : - : : ~ : s : : : : - : - : ; - : : : : : : : i ; : : : . , . : : ~ : - : · .?.?.?.?..~...?.,?.t...~ ....... ~...T..:~...~-?..?.?.~ ....... t...?.t...t...~,..~...?.t...t ....... ?.?,..?..~...~...t ......................... ~ :"? ........ ~ .................... ~ ............ t... ~ ....... ~ ................ . ........... : ......................... ..~...~,..~...~...~._.~..,~...~._.~...~ ~..~.. ~ ..~...~ Z...~. ~ . .. ~ ~...~ .~... ~...Z.. ~...~ ...... ~ ....... ~_..; ....... :...L...:....~...f ........ ~ .......... ;...: ......... ~ ........... ;....~ ........ ~ .......... : ..... ..~...= ......... ~...+...,--,~-..~..-, ....... ~-..~ .-~...~..+.-.~...~.--~ .... ....... ~...~...~ -.~..-+,.. ~-..-~ ....... ~...+ ......... ~..-~.-.?-....---~ ......... ~.--.~ ............. ; ............ t ............................... , ............. 4 ................. ~ ....... , ....... : , . : : : : . · .?;-...~...?.f-.-?.~...~-..~ ....... ~-..~...~..,~...~....~ ....... 4,..~ ....... ~...~ ............ ...~..-~...~-..-~...~...~...~...~..-~ .... ........ ............. .......... ........... ................ -~ooo - ~ ooo o ~ ooo 2ooo aooo 4ooo soo~ -400O -5000 -6000 SOUTH -?000 -3000 WE:ST WELL' -2D-9 SURFACE LOCATION: 370' FNL & 59' FEL @ SURFACE VERTICAL PROJECTION NH -3000 -2000 -i000 0 0 I000 2000 3000 4000 .~000 SE PROJECTION ON VERTICAL PLANE OF AZIMUTH 103 SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/I000 IN/FT .Required_ .Date Receivsd' Rem. arks ' ·. C~letion, .. Rei:::ort Yes ~ - ¢ "' ~ , . / , , ..~ o ~, , , · · f ARCO Alaska i,.'~c. · "'-' ': ~ ~ ' ' ,' :~ .. /~.,.'..k:~ oo:-....,l~ '. :..- ,::':.c 9~,T =77 5C37 Return To: Date: 10/~/84 Transmittal No: 4786 PAGE 2 o£ 2 ARCO ALASKA, Inc. ATTN: Records Clerk AT0-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2O-2 2"/5" DIL-S~L/GR 2"/5" FDC-(~/GR "Poro" 2"/5" " ""Raw" CPL Cyberlook c/05/ mm z 8/08/84 " 6090 - 6570 8/08/84 " 6090 - 6570 8/08/84 " 6090 - 6570 2D-9 2"/5" DIL-SFL/~ 8/08/84 Run 1 2"/5" Density Neutron Poro 8/08/84 " 2"/5" " " Raw 8/08/84 " CPL Cyberlook 8/09/84 " 3895 - 7834 7250 - 7809 725O - 7809 7450 - 7710 /c~t Receipt Acknowledged: B. Adams Date: D&M DISTRIBUTION W.V. Pasher C. R. Smith. F.G. Baker P. Baxter BPAE Dr ill ing Geology Mobil G. Phillips Phillips 0il J.J. Rathmell State of Alaska Sohio Union Chevron NSK Operations R & D Well Files ARCO Alaska, Inc. .... · . .;'-c:... £,:.7 2r7 Transmittal No: 4765 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 / Anchorage, AK 99510 Transmitted herewith are the following it,s. Please acknowledge receipt and return one signed copy of this transmittal. CBL's FINALS/Schlumberger 2V-8A "Variable Density" "GCT" 8/01/84 Run 1 7400 - 8909 2G-1 '" " " " 8/27/84 " 5151 - 7991 2G-2 "' " " " 2G-3 " " " 8/27/84 " 8127/84 :" 4275 - 6536 5950 - 8526 2G-4 _ " " " 8/27/84 " 5070 - 7650 2G-8 " " " 7/31/84 " 6500 - 7830 2H-13 ' " " " i4f - . 2H- " " " 7/30/84 " 7/30/84 " 6100 - 7720 7200- 8732 2H-15 " " " " 7/30/84 " 6100- 7422 Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron 7/30/84 " 8/25/84 " 8/25/84 " 8/25/84 " 8/25/84 " DISTRIBUTION 7000 - 8410. 5900- 7588 6700- 7768 6900 - mAmA Date: D&M Drilling Geology Hob i 1 W.V. Pasher G. Phillips Phillips Oil J.J. Pmtb~ell Alas,'<a Oil & Gas Cons. Commissk c. ~. S~?~ Sohio Union NSK Operations R& D Well Files ARCO Alaska, II~_. ~.... Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001Povcupine Drive Anchorage, Alaska~ 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2G-2 1L-5 2D-9 2B-3 2G-3 1L-6 2D-8 2B-2 2G-4 1L-7 2D-7 2B-1 Thank you. Sincerely, Area Drilling Engineer JBK: ih LO1 06/28/84 Enclosures ARCO Alaska, inc. Is a Subsidiary of AllanllcRIchlleldCompany STATE OF ALASKA ALASJ A OI" L AND GAS CONSERVATION D-mMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit'No. ARCO Alaska, Inc. 84-103 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21137 9. Unit or Lease Name 370' FNL, 59' FEL, Sec. 26, TllN, R9E, UM Kuparuk River unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) Pad 89, RKB 126 6. Lease Designation and Serial No. ADL 25658 ALK 2584 10. Well No. 2D-9 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of August ,19__84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well @ 0700 hrs 08/01/84. Drld 12-1/4" hole to 3905'. Ran, cmtd & tstd 9-5/8" csg. Drld 8½" hole to 7850'. Ran logs. Drld 8½" hole to 7900' TD as of 08/09/84. Ran, cmtd & tstd 7" csg. Performed Arctic pak w/250 sxs. AS I & 59 bbls Arctic pak. Secured well and released rig @ 0600 hrs, 8/10/84. 13. Casing or liner rgn and quantities of cement, results of pressur9 tests 9-5/8" 36# J-55 BTC csg w/shoe @ 3887' cmtd w/1065 sxs AS III & 700 sxs class "C". 7" 26# J-55 BTC csg w/shoe @7870'. Cmtd w/300 sxs class "G". 14~C/o~ng resume and brief description ~51J'I°~y:~)~/~t.~/~_~C_NI~_/7840' to 3895' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. bl~l'~-u C/~~ ~ ~ ,~-w~ /l/~~ ~ ~ DATE NOTE--Re~t~_ ~n [~orm is required for each calendar month, regardless of the status of operations, and must b~file~ in duplicate with the Alaska Oil and Gas Conserv~on Commission by the 15th of the succeeding month, unless otherwise directed, Form 10~04 Submit in duplicate ...... ~ HILL/MR 183 ARCO Alaska, · -. .~.:, E-~ 3~.~. ;...':c ~o~ ag,.. A,aska 'i. ( !c.F, ho:~e 907 277 5637 Date: 8/23/84 Transmittal No: 4704 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 /.horage, AK 99510 ~/~_[~n~ted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS (TAPES) Schlumberger ~ #69460 8/15/84 · ---#69457 8/14/84 '-'#69405 8/01/84 '--#69456 8/08/84 -~ #69458 7/06/84 7/01/84 , 6/24/84 6/19/84 Run 1 2104.5 - 8497 1L-6 --~.r'~ ~.~c~./,~, " 3091.5 - 8457.5 29-3 3871 - 7829.~ 2D-9 ' Au~ 1-4 117 - 6482.5 2G-7 / Alask~ 0il & Gas Cons. Commlss[ori Ancho,-ag3 /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE I Chevron Date: DISTRIBUTION D&M Drilling Geology Mobil NSK Operations W.¥. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D C. R. Smith ..... :stat o Sohio Union Well Files MEMORANDUM State of Alaska DATE: FILE NO: TELEPHONE NO: SUBJECT: August 9, 1984 103/K ~-.tLtness ~OPE Test on ARCO's Kuparuk 2D-9 Sec. 26, TllN, R9E, LI~I. Permit 84-103 Parker P-~g 191 .S~...turday,- August 4, 1984: I traveled this date f~om ARCO's Pmadhoe Bay DS 15-20, subject of another report to AROD's'Kupart~ 2D-9, Parker Rig 191 to witness a BOPE test. The drilling contractor was in tb~ process of nippling up. The BOPE test comnenced at 3:00 a.m. and w~s concluded at 4:30 a.m. There ~re no failures. I filled out the A.O.G,C.C. EOPE report ~i-'ch is attached to this report. In mmmary, I witnessed the BOPE test on ARC0's Kup~ 2D-9, Parker Rig 191. 02-001AfRev. 10/79) Inspector Operator ALASKA OIL '& GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ~~r _J O- q Location: Sec ~..~ Drillin~ Contractor Ri Weii ~g)- ~ Representative ~ ~~-~ Permit f/ ~--/D ~' ~/~ Casing Set ~ ~'~8~ ft. Representative ~ ~/~/~ .f'- -j!::j::& _ Location, General D ~ General Housekeeping 6 ~ Reserve Pit 0 ~ Mud Systems Visual Trip Tank . ~ ~ Pit Gauge ~ Flow Monitor ~ Well . Rig Audio Gas Detectors .,A/o BOPE Stack ! Test Pressure ~mnu~lar' Preventer 0 . j ~O0 e Rams I ,.~o Biin4 Ra~ ~ 3OOe H,C.R. Valv~ e~ ~ ~ Kill Line Valves O~ 3~oo Check Valye ~ ~ [~ ~ Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure ~/~ psi~ Pressure After Closure /~ psig Pump incro clos. pres. 200 psig ~ Full Charge Pressure Attained: _~ Controls: Master ~j4z ~ ~[.**~t fcu,~cf~ Remote Y~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly L'~ ~..Test Pressure Lower Kelly~'"~K Test Pressure__ Ball Type~/~ ~ Test Pressure Inside BOP ~'~ Test Pressure Choke Manifold ! ~ No, Valves /~ No, flanges~ Adjustable Chokes ~L~ O Y,. Hvdrauically operated choke q~ ~o0~ Test Time ~l_hrs. ,,,~ (~'~" ~ :-.. Test Pressure ~.<,~ o 0 rain. sec. rain ~ Repair or Replacement of failed equipment to be made within~ days and Inspector/ Commission of/ice notified~ , ~ Discr±but~on orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~~ ~], ~ ~ / I '-dl- July 10, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-036 Re: Kuparuk River Unit 2D- 9 ARCO Alaska, Inc. Permit No. 84-103 Sur. Loc. 370'FNL, 59'FEL, Sec. 26, TllN, RgE, UM. Btmhole Loc. 1366'F~L, l125'FEL, Sec. 25, TllN, R9E, %rM. Dear Mr. Kew!n: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a.one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior t? commencing operations you may be contacted by the Habitat Coordznator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the. Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. K~wtn Kuparuk River Unit 2D-9 -2- July 10, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very .truly ~q,ur~s, ¢. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~..~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-9 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2D-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plat A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on July 28, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ~e~"J~j~ ~'ng Engineer JBK/JG/tw GRU8/L28 Attachments RECEIVED JUL 0 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA ~I"L AND GAS CONSERVATION CO'f~IVilSSlON PERMIT TO DRILL DRILL E~X REDRILL [] DEEPEN [] 20 AAC 25.005 SERVICE [] STRA~-'~GRAPH lC S,NGLE ZONE [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 370' FNL, 59' FEL, $ec.26, T11N, RgE, UH At top of proposed producing interval 1304' FNL, 1388' FEL, Sec. 25, T11N, RgE, UN At total depth 1366' FNL, 1125' FEL, Sec. 25, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF etc.) RKB 126', PAD 89' 6. Lease designation and serial no. ADL 25658 ALK 2584 9. Unit or lease name Kuparuk River Unit 10. Well number 2D-9 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles I 370' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7754' HD, 6197' TVD fe~t 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 41 oI (see 20 AAC 25.035 (c) (2) Amount $500,000 tl 5. Distance to nearest drilling or completed D-10 well 60' @ surface feet 18. Approximate spud date 07/28/84 2775 psig@ 80°F Surface 3114 psig@ ~n46 ft. TD (TVD) Hole i24" 2-1/4" SIZE Casing Weight 1 6" 62.5# 9-5/8" 36.0# 8-1/2" 7" 26.0# 22. Describe proposed program: Proposed Casing, Liner and Cementing Program :ASING AND LINER Grade Coupling/ H-40 I Wel~ aTe/ HF-ERW HF-ERW SETTING DEPTH 3676' Length MD 80' 36' I 36' I 36' TOP TVD 7719' 36' I I 35' I ~ 35' MD BOTTOM TVD 116' II 116' 3712' I 3146' I 7754' I 6197' I I QUANTITY OF CEMENT (include stage data) + 200 cf 1065 sx AS Ill & 400 sx Class G 400 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7754'MD (6197'TVD). A 20" 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3712'MD (3146'TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2775 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 3-1/2", 9.2#, 5-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby c,~-~ that the foregoing is true and correct to the best of my knowledge The space/,t~l~w~for/'y,~/'nis'~o~J t~se - CONDITIONS OF APPROVAL Samples required f-lYES [~ Permit number APPROVED BY Form 10401 GRU8/PD09 Mud Icg required []YES ~ Approval date /84 Directional Survey required I APl number I SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSI ON ER DATE by order of the Commission July lO, 1984 Submit in triplicate PERMIT TO DRILL 2D-9 installed and tested upon completion of the job. 2D-9 will be the fourth well drilled on the pad. It is 60' away from 2D-lO at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6342'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. RECEIVED J U L 0 9198~ Alaska Oil & Gas Cons. Commission Anchorage RECEIVED JUL 0 9 !994 Alaska Oil & Gas Cons. Commission Anchorage IANNUL. J ?SE¥[ TE PIPE BLIND ' RAM~ S HD 2 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco startin§ head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/'choke and kill lines 7.- 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE !S 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. 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 NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MA3tIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND 'V'~6JbYq~S UPS~ O1~ CI-IOI<]~S. DON*T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0 B. ~.~I~'PRESSURE DOWNSTREAM O1~ CHOK~ ISOLATION V. AJL.VES~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PI PE RAMS. 10. INCREASE PRESSURE TO 3DO0 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P. AMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSiT]ON. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WiTH KOOMEY PUMP. 15.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- R E C E IV E D JUL 0 9 1954 Alaska Oil & Gas Cons. Commission. Anchorage 7 Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick ~onnect assy. 16" X 20" 2000 psi double studded adaPter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify Ghat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor r- C F__ IV ED jUL 0 Atas~-',a Oil & G~s Cons, Commission Anchorage ARCO Alaska, Inc. Post Office ~m-o-x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2D Pad - Wells 5-12 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU8/L24 Enclosure i .,~,.~ska Oil & Gas Cons. Commiss/on Anchor~..~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ . __ I I _ __m m i DRIL.._~,$1TE 2-D CONDUCTORS AS 'BUILT LOCATIONS M-s,g$4o3&7.Z02 Lac. 70°17'!i .045B' X-- 529,214.1642 Long. 149045'48.797. . 168 FSL 550 F~L EL. 88.8* .O.G. 79.4' ~LL 6 ~5,954,323.069 ~=. 70017 '~0 ~ 529,254.7648 ~ng. 14~45'47 124 ~L 510 ~EL ZL. g8.7' O.G. 79.2' ~%LL 7 ~5,954,279 .047 ~t. 70°17'10 X- 529,295.2738 ~ng. 14~45'46.443" ~ ~ 470 FEL ~. 88.6' O.G. 79.3' ~-5,~,2~.884 ~t. 70°17 '09. 7407" ~ 529,33~.9398 ~ng. I4~45'45.263" ~ ~ 429 FEL ~L. 88.5' O.G. 79.2' ~LL 9 .~5,953,~.605 ~t. 70017'05.7498" ~ 529,708.413I ~ng. 14~45'34.458" ~0 ~ 59 ~L ~L. ~9.0' O.G. 83.9' ~ 10 ~5,953,786.478 ~. 7~17'05 X~ 529,749.0452 ~ng. 14~45'33.279" 414 ~L 18 FEL EL. 89.0' O.G. ~3.!' ~LL 11 F-5,953,7~ .418 ~t. 7~i7'04.8793" ~ 529,789.6305 ~ng. 14~ 45'32.102" 458 ~L 22 ~ ~L. 89.0' O.G. 83.3' . ~LL 12 ~,953,698.183 Lat. 7~17'04.4426" X- 529,$~.3~77 ~ng. i4~45'30.922' ~3 ~L 63 ~L fA. ~.l ' Q.G. 83.3' --- - ............. i i I ~REBY CERTIFY THAT I AM PRO~Y REGISTE~D ~~ED ~ ~~tCE gAND SURVEYING IH THE ~ATE OF Ii$.Z.C IX$.2D . THIS PLAT REPRESENTS A SURVEY MADE e/~/B4. , I~C. Kup=ru~ ~OjeCt Nort~ Sta~e Oritl{~ DRILL Z.D NDUCTOR AS. BU I LT ATI ONS ~ele: i"= 400' CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (2' thru 8) t ! , ,, (3) Admin fY:' ..... '",' .-"'; 2,~ (9"' thru 11) ,,4,7f (10 and 11)' (12 thru 20) (5) BOPE .:'?/,,.~ (21 thru 24) (6) Add: h~/~ , e 10. 11. YES NO 1. Is the permit fee attached .......................................... .~__~,_ / 2. Is well to be-located in a defined pool ............................. ~,__~_ 3. Is well located proper distance from property line ............. '~7-, 4. Is well located proper distance from other wells .............. 5. Is sufficient undedicated acreage available in this pool ........ ~,-,,[~,~ 6. Is well to be deviated and is well bore plat included ......... ~,?~'*~_,__ 7. Is operator the only affected party ........................... 8. Can permit be approved before ten-day wait ....................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. REMARKS 25. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... · ,, Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension an~ burst ''~z7-~ '' Is this well to be kicked off from an existing wellbore . ' . Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~_~_~.'__ Are necessary diagrams of diverter and BOP equipment attached . Does BOPE have sufficient pressure rating - Test to ~d'~'Z) psmg Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. c) mm Geology: Engineering: HWK~, LCS '~(:~.~-~EW ,~w WVA JKT OHJH ~_ JAL , MTM ~ "- rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, 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 APPENDIX. No special effort has been made to chronologically organize this category of information. I I I I I I I I I I I I I I I I I I I e e Memory Multi-Finger Caliper Log Results Summary k9- ~\\ Il~-ob Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. Novernber13,2005 6040 1 3.5" 9.3 lb. J-55 EUE Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 2&Ø9 Kuparuk Alaska 50-029-21137-00 Surface 7,530 Ft. (MD) \ <61~ -\D~ Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: ~C)L-\ \J/~c..·-Oç This caliper data is tied into the liD" Nipple @ 7,520' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5..ttJbin5t~iDGdtu !J(,jðètcortdfttonwittr respect to corrosive damage, with the exception of ~ãnct'~walr'penetrations in joints 209 and 121 (6,413' - 3,727'). The damage recorded in the 3.5" tubing appears in the forms of isolated pitting, a ring of corrosion in two joints, and a few areas of general corrosion. Cross-sectional wall loss of 20% and 18% are recorded in joints 121 and 209 (3,727' - 6,413'). No significant areas of 1.0. restrictions are recorded in the 3.5" tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WAll PENETRATIONS: Ring of Corrosion Ring of Corrosion ( 28%) ( 23%) Jt. Jt. 209 @ 121 @ 6,413 Ft. (MD) 3,727 Ft. (MD) No other significant penetrations (> 17%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: Ring of Corrosion Ring of Corrosion ( 20%) ( 18%) Jt. Jt. 121 @ 209 @ 3,727 Ft. (MD) 6,413 Ft. (MD) No other significant areas of cross-sectional wall loss (> 8%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing logged. 'j(' R,\\*,~~~~n \Jvn~,""'Ç-I.:., l(~;' I I Field Engineer: D. Cain Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.colìì Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 REf'" t~=:D .....:>. f'Oh . ...1 ,J NOV Make 0., c:,¡ Í,j~¡a, . . ;,,;¡mmtSSi An¡;i¡¡;¡j{¡ija I I I Well: Field: Company: Country: 20-09 Kuparuk ConocoPhillips Alaska, Ine. USA I Tubing: Weight 9.3 pf Grade & Thread j-55 Nom.OD 3.5 ins I Penetration and Metal loss ('Yo wall) I penetration body melall05s body 250 I 200 150 100 I 50 01 o to 1% 1 to 10% 10 to 20% 20 to 40% 40 to over 85% 85% I o o 2 I I Damage Configuration ( body) 20 I 10 I o I Isolated plttmg general line nng hole / po",s corrosion corrosIon COIT051(1) ¡ble ¡)ole I o I I PDS Report Overview Body Region Analysis Survey Date: Lool I"ype: 1"001 Size: No. of Fingers: Nom.ID 2.992 ins November 13,2005 1.69 24 Nom, Upset 3.5 ins Upper len. 1.2 ins Lower fen. 1.2 ins Damage Profile (0/0 wall) penetration body o o CLMI CLM 2 GLM 3 GUv! 4 metal loss body 50 100 GLMS Bottom of Survey = 244.7 Analysis Overview page 2 I I I I Pipe: Body Wall: Upset Wall: NominaIID.: I I I I I I I I I I I I I I I Bottom of I I Correlation of Recorded Damage to Bore Ie Profile 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 20-09 Kuparu k ConocoPhillips Alaska, ¡ne. USA November 13, 2005 Appro\(. Tool Deviation Appro\(, Borehole Profile CLMI CUY'\ 2 ClM ClM 4 (~LI'V\ 5 50 Damage Profile ('Yo wall) / Tool Deviation (degrees) = 244] 7528 100 1 ,'j ,) 743 1486 2293 3069 o ~ 3813 .,.; w- e ..c .,.., D- ID o 4571 5335 6108 61369 I I I I I I I I I I I I I I I I I I I PO EPORT JOINT TABULATION EET Pipe: Body Wall: Upset Wall: Nominal J.D.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2,992 in Well: field: Company: Country: Survey Date: 20-09 Kuparuk ConocoPhillìps Alaska, Inc. USA November 13, 2005 ¡oint Jt Depth p. Pen. Pell, ,1¡k'lal Min, Damage Profile No. (ft) Body ID. Comments (%)wall) I (Ins,) (Ins. ) 0 50 100 ,1 8 n 0.01~ 2 ') 2.91 PUP I i I 1'" n OJJ2 9 I ')89 !II .> I 2 45 n 0,02 B 1 ),89 55 H- /6 II 0,03 10 2..2l, III! .) 4 108 C 0,02 II 1 2,89 55 ___ 5 _______ ~ ~140 n (J.O 2 ß ~2,92 55 ... 6 171 n 0.02 I II 1 2.89 11II 7 202 n OJJ3 11 2 2.92 !II i 8 234 n 0.03 !1 I 2.91 11II 9 265 £!.Q2 I ') _2.92 !II i 10 297 0,01 i I 2.90 32ì 0.01 ) 2.91 357 0,02 { 1 2,91 : 386 0.03 J:) I 2.90 416 0.02 c I 2.90 : 445 0.02 c I 2.90 , 476 n 0.03 [) I 2.91 55 , 506 0 0.02 ~ ....:L2Q~ ¡¡¡ 18 ,535 0,02 _2.92 - 19 564 0.01 2.91 I 20 594 O)l:L 2,88 55 I 21 624 0.00 2.89 22 654 I 0.02 2.89 11II Hi 683 1 0.02 2.89 11II ~, 1 .,. -~, '>4 713 0.01 2.9J ." I_.=~.~,- --~,.~.- 25 741 0 0,01 i 2,88 _26 ~. 773 n O.ül 1 2..91 ,~ 27 802 I n 0,01 ) 2,91 ~_4.B~_~ ~~831 1 0.02 q I ,2·90 11II '>9 861 n 0.01 2,91 ---'3!:¡ -~~ 891 C 0,01 2.91 31 .._2:LQ~ n 0.04 I 2,8C? Shallow pitting lower body at upset Lt Deposil'f"! ----"'--'--,~ ~~32 __ 949 0 0,01 2.89 ~,... . 0 ---- 33 978 0.01 2.90 34 1008 0 0.02 35 1038 C 0.02 EI 36 1068 0 0.03 37 1099 C 0.02 I 38 1128 0 (J.O 2 2 2.91 39 _JJ5L I 0.02 2 2.90 -~-- ---- ______________mn___ ~~~--"- 40 118} 0 0.01 .5 2 2.90 I~ 41 12JL n 0.02 9 ) 2,89 iíIí 42 1247 C (J.O 2 (; 2 2.91 II 4" 1276 0 0.01 4 I 2.92 .) 44 1305 0 0.02 9 2 2.93 iíIí 45 1335 I) 0.01 ,) l-+ 2.88 ~ .....12_~ 1365 0 0.00 '-")i-~ 2,90 --~.~--~-----~--------~ ------------~--- ~Æ.~.. _M_ 1395 0 0.00 2 2 , :L(¿L~ 48 1424 0 0.02 9 1 2.91 III _49 1455 0 0.03 I) 2 2.89 Shallow Dittim2:, III Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION 5 EET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 20-09 Kuparuk ConocoPhillips Alaska, Inc. USA November 13, 2005 I Pen ------ ,\'le\;11 Damage Profile loint It Depth Pen. Min. I No. (Ft) \ Body I.[) , Comments (%wall) ! (Ins (IllS.) (IllS,) 0 50 100 50 ~JAJJ(l_ ø 9 2,95 ------- --- 3 51 1518 ; 2.96 52 1549 4 4 2,9;; , 53 158! 4 ; 2.95 54~ ___10L'L. o 0.t)1___ 5 1 2,95 ~_55 1645 0 0.t)4 15 5 2.91 Shallow Díttiml:. ')6 1676 0 OJ) I 4 2,95 57 1708 0 0.01 5 ) ).93 ~~^~-~-~. 58 1740 0 0,02 , ),95 59 1772 0,02 2,96 __60 _ _J 803_ O.OL_ 2,95 61 1835 0.02 ( 2.91 CJ 1867 OJ)] 2,91 - )k _Q.:u...... ~6 0.D1 0 2.9,5 PUP ____m_._~.~.____..._._ -~---~-- I 62.2 1902 ( 0 ( 0 2.81 SSSV 62.3 1916 ( ~i~~~:T~~~JP : 63 1922 0,02 :3 2,94 Shallo,~ pitting, ._.~._.. I 64 1952 0,03 J~4,1 T 1988 0 ( ( ili± GlM 1 (latch @ 12:30) 65 1991 0.01 66 2022 0.02 2.90 67 2052 ----.- ~ 0.02 ì 2.91 68 2082 0 0,01 2.90 I 69 2112 0 O.D1 I 2.89 _._-,-~~,.,.,~~~~~~~~~~-~ I 70 2143 0 0.02 2.90 · 71 2173 0 0,03 ¡ 1 ì 2.88 · 72 2202 0 0.t)1 4 4 2.89 Lt, Deoosit5. ì3 2232 ( 0,02 9 I 2,91 · 74 2262 ( O.D1 4 \ 2.89 75 2293 0 0.02 9 (, 2,94 --~---- 76 2325 0 0.02 9 2 2,94 -~_._.._~~.~~ 77 2356 ( . 0.02 9 I 2.91 78 2388 0 0.03 II 5 2.93 7fI1 79 2420 ( 4 ) ~ ----~ ~------- 0.01 2.93 80 2451 ( 0.03 12 4 <JI 81 2484 0 0,02 9 8 ,93 I 82 2515 () 0.03 10 7 ,95 83 2547 () 0,01 4 .. .92 84 ')579 () 0.02 9 4 2,92 .-----. I 85 2611 () 0.02 £) I 2,93 I 86 2643 0 0.02 9 4 2.91 II '- I 87 2674 () 0.01 6 2 2.91 88 2706.._ i~Q- 0,03 11 2 2.91 · 89 2738._ () 0.02 9 I 2.92 11II -----. 90 2767 0 0.D1 4 ,1 2,90 91 2798 () 0.03 10 2 2.88 · ~- I 3 I 2.91 92 2828 0.01 93 2858 () (W1 3 ') 2.91 94 2888 0 0.02 9 I 2.90 11II -------~~- II 95 2918 () (W2 ß 3 2,90 Body Metal loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION SHEET Pipe: Body Wall: UpsetWa!l: NominaIID.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 20-09 Kuparuk ConocoPhillips Alaska, Ine USA November 13, 2005 PPH, i\k,t:11 Min, -^^- joint Jt Depth Pel Pen. Damage Profile No, (Ft.) I Body 1.0. Comments (%wall) (Ins,) I (Ins,) 0 50 loí) 96 0 3 ) .~-~... IIII! I 2949 0.03 2.9') SIEUIOw,J)itting. 97 2979 I CUB 10 2 2.88 IIII! 98 3009 n 0,02 9 ) 2,89 IIII! . 99 3039 ( 0,0; 10 2 2.91 IIII! 100 3069 0 0,01 4 ) 2.90 .-.. 0 'I I _mL~ ~J098 0.02 2,88 10') 3128 0 0.01 4 ) 2,90 I ~'" 0 9 103 3157 OJJ2 I ~2.88_ 104 3188 n 0.02 {) 2 J89 105 3218 0 0.01 I I 2.93 106 .3247d I) 0,01 3 2.91 107 3278 0 '0.02 ) 2.89 108 3308 0 0,01 ) ..... 2.90 109 3339 I 0,02 ( ) 2.87 110 3368 I 0,01 ) 2.91 .~ 111 3398 I 0,03 ) ! 2.89 Shallow pitting, 3427 I 0.03 n I 2,89 3457 I 0,02 2 2.86 It. I'=nn..;+'· 3488 I CUJ2 ) 2.89 ^----- _.~~..._-_.,_.~,..,..._~~ I 3518 /, 0.02 2 2.93 I 116 3547 n 0.01 4 ) 2.90 117 ddJ.2?i.J n QJJ2 .dJL . , 2.90 I ~--~- , ^_.~~ 118 1606 0 0.01 6 ) 2.89 .JJ.2.__ ". 3636 __. 0 0,03 -7"'~ ! 2,89 ----"~---,,-~._~ 120 .36QZ_ 0 0,01 I 2.90 121 3§'l0. (I ."O.ll9_ 23 20 2.9L .RiDK.Qf c()!IQsioIlJQ~ver body aHIQ.s,¡¿t. ^ ^ ~-~~..^~,.~.. I 122 3728 (I 0,02 6 ) 2.92 123 ' --1757 . (I 0.01 4 4 2,91 124 3786 (I 0,01 ') :' 2.88 125 3818 (I 0.ü2 (, 2 2,87 126 3847 0 0.01 4 'j 2.88 127 3876 0 0.01 4 ) 2.90 _____m_ 128 3906 (I 0.ü2 .. 9 2 2.89 129 3936 (I 0.01 4 2 2.89 I 130 3966 (I 0.02 ß 2 2,87 ^~ M~~ _ 131 3996 0 0.01 ') ) 2.86 I 132 4025 () 0,02 7 2 2.87 133 4055 () 0.ü2 9 " 2,90 133,1 4085 0 ° (I 0 N/A ClM 2 II Meh (iì) 2:0m 134 4092 0 0.03 12 2 2,92 ~135 4122 0 0.02 7 I 2,91 136 4151 0 0,03 12 4 2,86 137 4183 0 0.0') 9 2 2.86 ____n_^___n_n_____n__m__________ . ",--""",,-- 138 4212 0 - 0.0 ! 2.86 _______~~_____~___^M____^M~_.~....,~,.,_ 139 4241 II - ~.Qm (, I 2.89 -~.~ ~.l.1ÇL ..~. 4271 Ii 0.01 4 2 2.91 141 4301 (I 0.01 ') 4 2.90 142 4331 (I 0.02 II I 2.87 143 4361 (I 0.ü2 --t~ ) 2.89 !II 144 4390 0 OJ)! ) 2.91 II Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 35 in 9.3 ppf )-55 0.254 in 0.254 in 2.992 in 20-09 Kuparuk ConocoPhillips Alaska, Inc. USA November 13, 2005 Well: Field: Company: Country: Survey Date: Joint Jt Depth 1'('11, Pen, Pen, ;v\etll Min. Damage Profile No, (Ft) \ ,\ Body ID. Comments (',/" wall) ) (Ins,) (Ins,) 0 50 100 145 4421 0 0.01 j i .. ".C)O 146 4451 0 0.02 _'L ! " ,c)2 !II 147 4482 0 (U "J ) ".89 I IIJ!I .,148 4512 0 "J,92 .. 149 4540 0 3 ) 2.91 150 4571 0 0.03 I ') 2.86". ' 151 ,.. 4600 0 0.03 10 2.87 152 4630 0 0.01 2.88 153 4659 0,01 '),91 _.154_ 4688 0.02 2.94 I 155 4ì20 0.03 1 2.93 LL Deposits, L 156 4752 0.02 2.94 .-...- 157 4783 0,02 2.95 158 4815 0,02 2. C)2 59 4847 0.03 2.94 160 4879 0 0.03 I 2.92 161 4910 0 OJ () 162 4941 0 OJ 2 163 4971 0 0.(1 4 164 5001 0 OJ 3 11 (; 2.91 I' 165 , . .'iQ34 0 0,02 (} I 2.93 ~ ... 166 5064 0 0,02 13 2 2.91 I 167 50e)).. 0 0.02 9 ) 2.91 , 168 5123 0 0.1)1 6 j 2,92 .169, 5154 ( ') 6 2 2.91 170 5185 0 (, 2. c)2 1 _.."~~~ , I !ìl 5214 0 12 2.88 f'MI I 1ì2 5245 0 6 I 2,90 II ~.. 5274 : 2.90 Lt. Denosits, 5306 ~~ ) 2,C)0 175 5335 7 ) 2.92 176 5367 2 2.91 ~_._.... 10 j 177 5398 0 0.03 2,92 ~ 5430 0 0.03 10 ") 2.93 Lt 6: D Ö:in I 4 2ell 80 D O. J3 Ii) ) 2.e11 Lt. 81 0 O. )2 ) 2(11 1 ;1.1 D 0 N.A GlM 3 (latch @12:00\ 82 0, )2 2 2.92 In (lO3 1 2.87 Shallow nittimL 184 5627 0.ü1 2 2.93 185 5658 0.01 3 2.C)2 . 186 5688 0.01 2 2.90 187 5719 0,02 13 ) 2.95 188 5750 0.01 4 2.92 189 5780 0 0.01 4 ") 2.89 ~ìO" 5809 OJJl ) 2.91 liL 191 5839 0,01 ) 2.c)1 _192 5869 0,02 2 2.86 _193 5899 QJU 1i) ) 2.91 Body Metal loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf J-55 0.254 in 0.254 in 2.992 in 20-09 Kuparuk ConocoPhillips Alaska, Ine USA November 13, 2005 Well: Field: Company: Country: Survey Date: Joint It. Depth Pen, Pen, Pen ;\¡lel;;1 Min. Damage Profile No. (Fl.) JIN'¡ Body I.[) , Comments (%wall) ¡ (Ins,) (Ins.) ° 50 100 194 5928 0 0.03 12 2.88 ¡t!!! I 195 5959 0 0.ü1 " I 2,87. 196 5989 0 0,02 9 ') 2.90 ¡t!!! 19: 6018 0 0,00 2 -tiE .-.. 191 6048 0 0.03 10 19' 6079 0 0.01 (, ,I 20( (~168 ,.. 0 0,02 (, 2 2,88 "."",." ,.".,.,_... II ... ?01 6140_ 0 0.02 8 )2 6170 0,03 10 4 2.91 Lt. Denosits. 03 .. 6201 0,03 13 (, . 2,93 Shallow pitting, ....- 204 6231 0,02 3 2.90 205 6261 0.02 J 2.93 206 6291 0,02 J 2.89 207 6322 0,03 3 4 ?89 Shallow nittin&_......... 6354 0.02 b ) 2.88 ~ 6384 fi=t :8 Iß Ring at Unset. 6414 ) 6444 0 is 11 Shallow Unner body at tinsel. ~ 212 6474 0 0,01 J -~.^ --~~ 21:¡ 1:'';1)2 0 ) .,. 0.02 ...__...~.._......_..~~-- 214 6534 0 0.ü1 2.88 215 6565 0 0,03 2,89 ~_.~~ I I 0 ...,...,~- 216 6595 0.03 2,90 217 6623 0 0.03 2.89 ........... -~_._...- 21R 6653 0 0.02,. 2,88 2113.1 6683 0 ° 0 0 N/A ClM 4 Wltch @ 3:00) 219 6690 0 . 0.02 B ) 2,84 .~._- .. 220 6721 0 0.01 S ) 2·.2IL ...._~.._-_.~,-,~.._,- -.--------- 221 6750 0 0,01 4 ) 2.91 =fuCt 6780 0 0.02 7 ') 2.89 6810 0 0.03 If) ') 2.88 . 8 ) 2 6841 0 0.02 2,91 ....l2L 6869 0 0,01 4 2 2,90 226 6900 0 0.02 9 ;: 2.90 6930 0 0.01 .3 ;: 2,91 6959 Ii OJ)1 5 ) 2. 6988 0 0,00 I 2 2. 701B 0 0.01 6 ;: 2. 7050 Ii 0.02 (, I 2. I 7079 0 0.03 11 ;: 2.91 7108 0 0,03 10 ;: 2.90 7137 0 0,02 9 4 2.91 7168 0 0.02 9 4 2,90 0 --..-- f¡ ;: 7197 0.02 2,91 7228 0 0.04 14 4 2.89 Shallow corrosion, Lt. Denosíts, 238 7259 0 0.03 II 1 2,92 Shallow corrosion. 239 7291 0 0.02 (, 2 2.94 I 240 7323 0 0.03 13 J 2.92 Shallow nittinQ, 241 ". 7354 0 0.03 13 3 2.90 Shallovv corrosion. 242 7386 0 0.04 14 .3 2.91 SI1 allo~\I.[>i!til1\<. Lt. Deoosits. I Body Metal loss Body Page 5 I PDS REPORT JOINT TABULATION SHEET I 3.5 in 93 ppf J·55 0.254 in 0.254 in 2.992 in Pipe: Body Wall: Upset Wall: NominaILD.: Well: Field: Company: Country: Survey Date: 20-09 Kuparuk ConocoPhillips Alaska, Inc. USA November 13, 2005 I I Joint No. Comments I I I I I I I I I I I I I Page 6 I I Damage (%wall) o 50 100 Body Metal Loss Body .. .. .. .. .. .. Well: field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. .. .. P S Report ross S ons 20-09 Kuparuk ConocoPhillips Alaska, Inc USA 3,5 ins 9.3 November 13, 2005 MFC 24 No, 99628 1,69 24 Tool speed = 57 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 82 % Tool deviation = 49 0 Survey Date: Tool Type: Tool Size: No, of Fingers: 209 at depth 6412 7 ft Finger 1 Penetration = 0,07 ins Ring of Corrosion 0,07 ins = 28% Wall Penetration 18% Cross-sectional Wall Loss HIGH SIDE = UP -- Cross Sections page 1 .. .. --~ .. .. .. .. .. Well: Field: Company: Country: Tubin : Cross Tool speed = 55 Nominal 10 = 2.992 Nominal 00 3.500 Remaining wall area 80 % Tool deviation = 54 0 .. 20-09 Kuparuk ConocoPhillips Alaska, Inc. USA 3,5 ins 9,3 f)-55 .. for .. .. .. .. .. .. Finger 4 Penetration = 0,058 ins Ring of Corrosion 0,06 ins = 23% Wall Penetration 20% Cross Sectional Wall Loss HIGH SIDE = UP .. .. .. .. P S Report ross S ns Survey Date: Tool Type: Tool Size: No, of Fingers: November 13, 2005 MFC 24 No. 99628 1.69 24 depth 3726.95 ft Cross Sections page 2 .. .. KRU 2D-09 I ~ 211)'*09 API: 500292113700 Well Type: PROD Anale@TS: 36 dea @ 7484 SSSV Type: LOCKED OUT Orig 811011984 Angle @ TO: 32 deg @ 7900 sssv Completion: (1921-1922, Annular Fluid: LastWIO: Rey Rea~son: TAG FILL, GL V 00:3,500) CIO ~Reference Loa: Ref Loa Date: Last Updal~ 11 11112005 Last Tag: 7583 TO: 7900 ftKB __~___,_______~____~~_m~_ LastTaa Date: 812712005 Max Hole Ana Ie: 50 dea @ 3800 .,iL\.l Gas Lift DescriPtion Top Bottom TVO Wt 1 Grade Thread MandrelNalve UK I 16,000 0 110 110 62.50 1 H·40 1 SUR. CASING I 9.625 0 3887 3148 36.00 1 J-55 (2002-2003, PROD. CASING 1 7.000 0 ~~7870 ~ - 6246 26,00 1 J-55 'LlDlI1a'''''''' -~^ ~ Size I Too I Bottom I TVO I Wt I Grade I EL~~~ö 3.500 1 0 I 7532 1 5963 1 9,30 I J·55 I Gas Lift /. MandrelNalve Interval TVD 1 lone I sœw'~' I 2 (4095-4096, i 7563 - 7579 . 5989 - 6002 I A-5 1 1 4 110115119891 APERF 12 118" Ener Jet 7592 - 7641 i 6012 - 6053 I A-4 I 1 4 191161198411PERF 14" Ores ~ St MO TVO Man Man Type V Mfr V Type V OD Latch Port Date Vlv Gas Lift 1ftrt Mfr Run Cmnt Mandre!Nalve 1 2002 186_º- MH FMHO GLV 1.0 BK 0.125 1305 101612005 3 2 4095 3290 ., MH~ ,- FMHO- GLV 1.0 BK 0.156 1330 101612005 (5564-5565, 3 5564 4434 MH FMHO -- ..~~~--~ GLV 1,0 BK 0.188 1355 10/6/2005 4 6684 5289 MH FMHO GLV .. ~.l:Q. BK 0.188 1345 10/6/2005 5 7448 5895 MH FMHO . -----ov- 1.0 BK 0.188 0 101612005 Gas Lift ~Depth TVO Type Description ID MandrelNalve 1921 1798 SSSV Baker 'FVL' - locked out 10111199 2.810 4 7492- , 5931 PBR Baker wi 10' stroke 3.000 (6684-6685, 7507 5943 PKR :>"'K"" 'nl' hyd set RetL 3.000 f~!=t 5955 NIP :::amco '0' Nipple NO GO 2,750 5962 SOS Baker 2.992 5963 TTL 2,992 Gas Lift I MandrelNalve 5 (7448-7449. 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