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Home My WebLink About184-094 -., in 0 • OCV " m N '� ~ ? r r r r r r O X �1 r CV �o >' Ir.— M `SII CO -0 ro (-7 71) O _ u O 4- E > c° a` a c C o 0 w ra O N > CD Q d _c `) E a 3 CO xt co J WV, co Co Co CO Co CO 0 L a) 0U N Q Q (7 r L L' ' i r-+ -p O r. O Q a a a Q Q -o -' „ k .- w Q Q Q Q Q B C c v) w 2 1n 1- Ma- r °r° NN °0 � o +c' Z Q o v > E cc +c' •u o I- (a LJ _o v, u O 0 0 0 0 0 c CD O p W J J J J J J C U a w w w w w w a) 'L } a v -0 I.- LL LL LL LL LL LL 'Cl _0 > -C a) 1 1- 0 0 0 Q Q Q .a c moi. d z z z z z Z u `0 a) 0 ,„'- Ci 0 a) t a, +, > I LL LL LL LL LL LL CC C C . CO +. U' _C> a'' v -, a) O _C 1 C E Q v u a) O Z > 0 C Ora to C E a m _ u t c r ' E c ro a o o Do z Q a) a 0 c a L) v _ J J u p 0 a)0 0 0 o rmo ) at a' a J r9N J r6 0 L O 4 U U 0 o N c w 3 C M 0 M N al O • Q d �_ Q •a a, tlV[ al• _ z V Y Z O n O Ts C > Z N u ; p~, J >J >J> >J> >J> >J> C •Q) o r M C a' C 3 > > 7 > 3 y 0 4 4 < n14 N o,o C-. 1111),Pill W 0 ` d IIP Cea' a' IXCere tab. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / _~¢- Z~.~/Well History File Identifier ! RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. OVERSIZED (Scannable) [] Maps: D .Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY BR~HERYL Other, No/Type MARIA LOWELL [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other Project Proofing BY: ~REN VINCENT SHERYL MARIA LOWELL Scanning Preparation ,.,] x 30 = BY: BEVERLY BREN VINCEN~ERY~MARIA Production Scanning Stage 1 Stage 2 BY~ BEVERLY BREN VINCE~ MARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) LOWELL ~COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES ~Y~ BREN VINCENT SHERYL MARIA LOWELL DATE:~'~ lSI~' IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO NO DAT?~, ,,i '~ IS~ RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: Is/ Quality Checked ~ ~ • • ~onocoPhill~ps 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: ~~,~~~ ~,~ ^ t ~. Enclosed please find a spreadsheef 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 13~' 2009. The corrosion inhibitor/sealant was pumped October 15~' and 31 St + November 1 St and 2"a 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~ ~ ~,~~ ~~~.~ ~ (.~ ~` ~ ~ ;~,? [p ~ ~~~~~~ ~~~~ ~ ~ ~~ ~~~~:F ~~~~rrrrnissinn ~~~f I~r~~~ ~r, ,..,t ~a~,-;~~,,, ~; f i ~J r~ ~~ ~~ u~ ~~~ ~, ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-4~4) Kuparuk Field Date 11/3/09 2c ~n 27 t~ ~K Pad Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbis 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 50029209740000 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" 10/13l2009 5.52 10131/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 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 10/31/2009 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 50029211640000 1841600 PIS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 5002920960Q000 183080Q 18" NA 18" NA 5.1 11/2/2009 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 11/1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/20Q9 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1l2009 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 Scblullberger ûJJ NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 2, '7 Z007 cmnmlssion Company: 8i, a> ~\j~ 1; '\ ~~~ Field: Well Job# Log Description Date BL 1 R-27 11850425 FPIT /q/ -ID;).. 08/18/07 1 31-08 11839638 LDL )~(~ -rM\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE / IT" '~I_~'::) 07/29/07 1 3G-26 11813071 LDL J~q -r(J~ 07/30/07 1 1R-18 11837482 SBHP/DDL JCj / -' t'I f5--:¡ 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U~ - /'If'3-c5"ó 07/31/07 1 2C-08 11813073 INJECTION PROFILE' / Tf' 11r:~ -(-A"'- 08/01/07 1 3H-32 11837483 LDL .DN"J -Ñ" 08/01/07 1 1Y-10 11837485 INJECTION PROFILE ·U~ 111"?. -ð5""" ) 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' 1~-(JÇ;.fr 08/04/07 1 1A-06 11837486 INJECTION PROFILE U T.."- J"'if I - / If-... 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . qN~ -/fA' 08/06/07 1 2U-08 11813076 LDL WT7t ,K -~ I 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE 1-e-3 - I~d- 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . ()1"7' Iq~ - t"'A::J 08/08/07 1 2N-327 11837491 SONIC SCANNER Be ~ --oto~ 08/08/07 2N-327 11837491 SONIC SCANNER-FMI i")....."'t -'-, L:l 08/08/07 3K-01 11632749 PRODUCTION PROFILE . J"if~ - JDf 08/12/07 1 2X-04 11846430 INJECTION PROFILE (J:ì.t' I~~ -II*' 08/13/07 1 2Z-29 11850419 SBHP SURVEY /1Ýlf ~J::A 08/13/07 1 2X-19 11850420 SBHP SURVEY J q C - I"J..'S- 08/13/07 1 1A·20 11850421 SBHPSURVEY I~~-/~~ 08/14/07 1 1 F-13 11850422 SBHP SURVEY LJ"I.C' J~~ -I4It.J 08/14/07 1 1H-10 11846432 SBHP SURVEY JCj:z.. -~ 08/14/07 1 1Q-10 11846431 SBHP SURVEY I 'Jr4 - It? "$r 08/14/07 1 2U-05 11846433 INJECTION PROFILE I }-rL'_ Hr.~-nL,( 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE /1Il./ -1'"ß4 08/16/07 1 2H-06 11846435 LDL Jìkh -I{AC{ 08/17/07 1 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 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. 08/22/07 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conser\'ation Commi~sion TO: Jim Regg PJ. Supen'isor K,e1{ "'z,¡/iA- DATE: \Vednesday. June 23. ~004 SlIBJECT: ~1echanicallntegrity Tests CONOCOPHrLLIPS AL..:..SK.J\ INC m-l~ FROM: Chuck Scheve Petroleum Inspector KUPARUK RIV UNIT ~D-1 ~ Src: Inspector Rniewed Bv: P.I. SUpf" '.:1~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2D-12 Insp Num: mitCS04062 I 095303 Rellnsp Num: API Well Number: 50-029-21131-00-00 Permit Number: 184-094-0 Inspector Name: Chuck Scheve Inspection Date: 6/20/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2D-12 Type Inj. P TVD 6282 I IA 1-150 2700 .:!MO 2630 P.T. 18-109-10 TypeTest SPT Test psi 1-188.5 lOA 160 260 ~60 260 Inten'al -IYRTST PIF P Tubing 2550 2550 2550 2550 Notes: The prete:)t pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday. June 23. 2004 Page I of 1 ~ ~ ((ù.. l~¡") r~'\ C""-J rC""'.í ,I., I ¿f\ III ", '. ") L \ . ciL L I\..... b (r' re r\ ~'I IT\ (~) rvi !f~\ l~J U-< lð\ ¡J\ 1)' lAU-\.\ -' JLl LnJ æJ ¡ i / i I / I ;' ¡ FRANK H. MURKOWSK/, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION i 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 IS 4* - O~Lf 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 ,of the 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, JH ;Q¡el 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 Date SI Oil,WAG,GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI YeslNo Yes/No I 20-13 1840120 98 70 60 P P I-OIL I.. -' -- : 20-12 1840940 98 70 65 P P I-OIL ,.... ~ 20-09 1841030 98 70 65 P P I-OIL I 20-08 1841270 98 70 65 P P I-OIL ,20-068 1981760 98 70 65 P P I-OIL I 20-03 1841530 98 70 65 P P I-OIL I 20-15 1841600 98 70 50 P 4 I-OIL 1000 1000 150 Yes Yes IA x OA communication L 20-01 1841710 98 70 0 10 P I-OIL ) Comments Performance Pilot on well 20-01 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 ALASKA OIL AND GAS CONSERYA~I~ION CO~SSION Michael B. Mooney Drilling and Wells Department ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 June 25, 2003 CERTIFIED MAIL- RETURN RECEIPT REQUESTED 7002 0510 0000 0453 3497 Re: Notice of Violation FRANK N. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Mooney: On May 17, 2003, AOGCC Inspector John Crisp, accompanied by a CPA-contracted safety valve tester, performed safety valve system (SVS) inspections on 11 wells located on Kuparuk 2D pad. Mr. Crisp noted that the surface safety valve (SSV) on Well 2D-12 had been defeated some time prior to the inspection - the needle valve on the SSV was in the closed position, preventing the SSV from operating with a low-pressure pilot trip or emergency shutdown of the SVS. A copy of his inspection report is attached. ConocoPhillips Alaska Incorporated (CPA) provided by electronic mail dated May 20, 2003, a draft report describing the results of an internal investigation stemming from the defeated SSV on Kuparuk Well 2D-12. You are reminded that Conservation Order 348, Rule 5 modifies the requirements of 20 AAC 25.265 ("Automatic Shut-in Equipment") as follows: (a) E, ach well shall be equipped with a Commission approved fait-safe automatic surface safety valve system (SVS) capable of preventing uncontrolled flow b!~ shutting off flow at the wellhead and shutting down any artificial lift system where an over pressure of equipment may ocCUr. (b) The safety valve system (SVS) shall not be deactivated except during repairs, while engaged in active well work, or if the pad is manned. If the SVS cannot be returned to service within 24 hours, the well must be shut in at the wellhead and at the manifold building. 1. Wells with a deactivated SVS shall be identified by a sign on the wellhead stating that the SVS has been deactivated and the date it was deactivated. 2. A list of wells with the SVS deactivated, the dates and reasons for deactivating, and the estimated re-activation dates must be maintained CUrrent and avaitabte for Commission inspection on request. JUL 0 7 20[B Notice of Violation June 25, 2003 Page 2 of 2 CO 348 replaced the requirements of earlier Kuparuk field rules by providing for the elimination of subsurface safety valves (SSSV) in certain wells. The elimination of the SSSV increases the reliance on the surface safety equipment. The Commission is concerned with the recent increased numbers of defeated safety valve systems discovered during routine inspections Failure to maintain an operable SVS is a violation of State regulations. Within 14 days of receipt of this letter, you must provide the Commission with an explanation of how this event happened and what will be done in the future to prevent its occurrence in CPA-operated fields. The final version of the Incident Investigation Report would likely satisfy this requirement. Should you have any questions regarding this correspondence, please contact Mr. James Regg at (907) 793-1236. / Sincere.ly~ ........ ,;. ~ Sarah Pali-r/ \,) Chair, Alaska Oil and Gas Conservation Commission JR: \ SP: ~jjc Attach MEMORANDUM TO- Randy Ruderich, Commissioner THRU' Jim Regg, P. I. Supervisor FROM' John Crisp, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE' May 17, 2003 SUBJECT: Safety System Defeated Kuparuk River Field 2D-12 May 17, 2003: I traveled to Conoco/Phillips Kuparuk River Field to witness SVS tests on 2D Pad. C/P Representative Bob Noble & Myself conducted SVS test on 2D-12. The LPP indicated a trip @ the control panel well within AOGCC guidelines for Pass of test. The LPP tripped but the SSV failed to close. The needle valve on the SSV was found to be closed; this would not allow SSV to close w/LPP trip or emergency shutdown of system. I requested Mr. Noble to have DSO meet us in the well house of 2D-12. The defeated system was discussed & it was apparent that the hydraulic lines to the LPP were modified to accommodate heat blanket for freezing problems. The lines & pilot had been changed 05-16-03. It was apparent that the SSV had not been closed & tested prior to my witnessing test on 05-17-03. DSO will discuss defeated system w/ALL personnel @ CPF 2. Occasionally the attempts to upgrade systems leads to mistakes being made that are not noticed until Inspections occur. The amount of Human Intervention in upgrading the Safety System was contributing factor for this system to remain defeated after it was upgraded. DSO was informed that State Inspector was required to report the defeated system to His Supervisor. Summary: I witnessed SVS tests on KRU 2D Pad. Safety System Defeated on 2D-12. Attachment: SVS KRU 2D 05-17-03 JC NON-CONFIDENTIAL 2003-0517_SVS_KRU_2D_Defeated- SVS_jc.doc AlaSKa Oil and Gas Conservation Commi~_~n Safety Valve System Test Report Submitted By: John Crisp Field/Unit/Pad: KRU 2D Pad Separator psi: LPS Date: 5/17/2003 Operator: Conoco/Phillips Operator Rep: Bob Noble AOGCC Rep: John Crisp 96 HPS 4000 Well Permit Separ Set L/P Test Test Test Date Tested and or Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, 2D-01 1841710 96 70 80 P P OIL 2D-02 1841520 2D-03 1841530 96 60 80 P P OIL 2D-04 1841510 3700 2000 1800 P WAG 2D-05 1841260 3600 2000 1500 43 P Tested 5-20-03 WAG 2D-06B 1981760 96 60 65 P P OIL 2D-07 1841430 2D-08 1841270 96 70 70 P P OIL 2D-09 1841030 96 70 70 P P OIL 2D-10 1841010 i2D-11 1840990 3600 2000 2000 P P WAG 2D-12 1840940 96 70 75 P 43 OIL 2D-13 1840120 96 70 65 P P OIL 2D- 14 1841590 2D- 15 1841600 96 70 80 P P OIL 2D-16 1841610 Wells: 11 Components: 21 Failures: 2 Failure Rate: 9.52% [--] 90 Day Remarks: 2D-05 tested 5-20-03 due to wing valve replacement. 2D-12 surface safety valve syatem was defeated. ( see attached report ) 14 well houses inspected. RJF 09/19/02 Page 1 of 1 2003-0517_SVS_KRU_2D_jc.xls ~_D-12 Defeated System Subject: 2D-12 Defeated System Date: Tue, 20 May 2003 07:31:02 -0800 From: "Michael B Mooney" <M.Mooney@conocophillips.com> To: tom_maunder@admin.state.ak.us ..... Forwarded by Michael B Mooney/PPCO on 05/20/2003 07:30 AM ..... Michael B Mooney 05/20/2003 07:08 AM To: tom_maunder@admin.state.ak cc: Subject: 2D-12 Defeated System Tom Here is the initial report. Mike W will probably weigh in and ask for more. Mike ..... Forwarded by Michael B Mooney/PPCO on 05/20/2003 07:06 AM ..... CPF2 Prod Supv 05/19/2003 11:35 AM To: Michael B Mooney/PPCO@Phillips cc: Michael W Wheatall/PPCO@Phillips, Bob D Bray/PPCO@Phillips Subject: 2D-12 Defeated System Attached is the draft incident report from 2D-12 where the state inspector found a blocked in safety system this week. The actiOns on this report are in addition to the prior documented event at CPF1. Th°se actions have not been fully implemented as yet. The responsibility for this event is crystal clear and lies with the night DSO. The supervisor will address that issue as per established disciplinary policies with the responsible employee in addition to actions documented on the report. Please feel free to contact me if further information is required. I am onsite until Wedneday this week. Thanks Glynn Jones/Steve Bradley ConocoPhillips Alaska CPF2 Production Supervisor (907) 659-7502 (907) 659-7744 fax (See attached file: 2D-12 Defeated Surface Safety Valve-r1 .doc) 1 of 2 5/20/2003 7:46 AM 2D-12 Defeated System ,_, Name: 2D-12 Defeated Surface Safety Valve-r1 ~2D-12 Defeated Surface Safety Valve-ri.doc Type: WINWORD File (application/msword) 2 of 2 5/20/200: Health, Safety. Environment Trnin~n9, Medh:~l nnd Emergency Servire$ Conoe~Phillips , INCIDENT INVES TIGA TION REPORT INVESTIGATION NO. INCIDENT NAME: 2D-12 Defeated $$V *****DRAFT***** Copying, redistribution and decompilation of this document is restricted by ConocoPhillips Alaska. No part of this document may be reproduced in any form by any means without prior written authorization from the ConocoPhillips Alaska HSE Supervisor. iRisk Rank Injury/Illness Enviromnental .Property/Production Loss Level 4 _ High Level 3 _ MediUm Level 2 - Low X Level 1 - Minor Neat2'Incident* X ,,, *Must also be risk ranked Level 1, 2, 3, 4 TIME AND PLACE OF INCIDiENT & INVESTIGATION: Time & Date of Incident: 1000 hours on 5/17/03 Time & Date Investigation Started: 1600 hours on 5/17/03 Time & Date of Report: (when sent for approval) GKBU Organization: Department / Work Group: Facility: Specific Location: Supervisor Responsible for Report: Estimated Cost/Hours GKA Operations / CPF2 CPF2 Drill Site 2D- 12 Glynn Jones, CPAI, CPF2 Production Supervisor, 659-7502 Man Hours to Investigate Environmental and Complete Report Repair Labor $ Materials Repair $ Production Lost in $ Clean. up $ 4 hours N/A N/A N/A N/A DESCRIPTION OF INCIDENT: The 1/2-inch needle valve on the surface safety valve was found to be closed rather than open during the state valve inspection test. www. ak.ppco.com/HEST/HEST Forms/Incident Investigation Report - Revised November 2002 Positions Involved: State Valve Tester, AOGCC InsPector and Drill Site Operator (DSO) Equipment Involved: Wellhead Surface Safety Valve (SSV) System FINDINGS: 1. Several days prior to the incident, the night DSO was installing a ¼ mm block valve (circled in white) that connects the hydraulic hose leaving the high-pressure pilot to the SSV needle valve. This activity was part of an ongoing effort to increase SVS reliability at CPF2. 2. To complete the job, the SSV needle valve (circled in black) was closed or blocked in. 3. The job would normally only take an hour or two to complete and the DSO had planned to finish it before leaving the area. 4. · Since all the isolation valves were within his immediate control and he expected to f'mish before leaving the area he decided not to flag the needle valve. 5. While he was working on the project, he was called off the job momentarily. 6. After he returned back to the job, he finished the installation but forgot to open the needle valve back up. 7. CPF1 and CPF3 have either removed or are in the process of removing all the needle valves at the SSV's. 8. The only way to tell if a needle valve is open or closed is to manually try it. 9. The well next to where the incident occurred (2D-11) has a ¼ mm block valve rather than a needle valve installed at the SSV that can visually be verified to be open or closed. 10. A similar incident occurred three months ago and is documented on incident report K03NIL3001. Listed below are the causal factors and root causes, which, the teton identified for this incident: WHAT CORR.ECTIV.E MEASU.RES (HAVE .BEEN/WILL .BE) TAK'E.N? Recommended Remedial Action Responsible Party/Internet Address Due Date ~conocophillips.com 1. Discuss the expectations and consequences of CPF Supe~isors 6/15/03 not following the tagging and flagging standard, n1127~ConocoPhillips.com 2. Evaluate and recommend whether or not to CPF2 Supervisors 6/15/03 remove the needle valves from the SSV's or n1127@ConocoPhillips.com replace them with '/4 mm block valves that can visually be verified. OTHER R.EiMARKS OR SUGG. ESTI'.ONS: One of the "'at risk" behaviors identified during this incident was not following the SOP (5.04). INVESTIGATION TEAM: Name/Company/Title , Contact Phone No. lnternet Address Glynn Jones, CPAI, CPF2 Production Supervisor 659-7502 N1127@ConocoPhillips.com Tom Sanchez, CPAI, Safety Specialist 659-7646 N 1169~ConocoPhillips.com REFERENCE NUMBE. R OF OTHER ASSOCIATED REPORTS: K03NIL3001 APPROVALS: Name Date Level 4 (CPA 3ra Line Supv.) ... Level 3 (CPA 2nd Line Supv.) Incident Investigation No. Page 2 www.ak.pp¢o.¢om/HEST/HEST Forms/Incident Investigation Report - Revised November 2002 'Level 2 (CPA 1st Line Supv.)-'~ Glynn Jones "~ Level 1 (CPA 1st Line Supv.) Incident Investigation No. www.ak.ppco.eom/HEST/HEST Forms/Incident Investigation Report - Revised November 2002 Page 3 MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission JulieHeusser,-'~'~"~ DATE: Commissioner TOm Maunder, ~~0.~'~ P. I. Supervisor ~'['5 \'-'0 ~, SUBJECT: chUCk Scheve; · Petroleum Inspector January 28, 2001 Safety Valve Tests Kuparuk River Unit 2D & 2E Pads Sunday, January 28, 2001'.1 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, I failure 5.56% failure rate KRU 2E Pad, 5wellS, 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: Pril~, 'ps Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/PM: Kuparuk / KRU / 2D Pad Separator psi: LPS 99 HPS 1/28/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2D-01 1841710 99 70 65 P p OIL 2D-02 1841520 , 2D-0~ 1841530 · 2D-05 1841260 3750 2000 1750 P 7 WAG , . 2D-06B 19817601 99 70 55 P P OIL 2D-07 1841430: 3750 2000 , 1850 P P .... WAG 2D-08 184'1270 99 70 6'0 p p OIL . . . 2D-09 1841030 99 70 55 P P OIL 2D-10 1841010 , 2D- 11 1840990 - 2D-12 1840940 99 70 60 P P OIL 2D-13 1840120 99 70 60 P P OIL 2D-14 1841590 2D- 15 1841600 99: 70 60 'P P ' OIL 2D-16 1841610 . Wells: 9 Components: 18 Failures: ,, 1 Failure Rate: 5.56% [] 90 Day Remarks: Surface safety on 2D-05 not tested due a slow leaking wi.n, g valve Grove valve could 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: PhilliPs SUbmitted By: Chuck Scheve Date: 1/28/01 Operator Rep: Earnie Brandt Field/Unit/Pad: Kuparuk / KRU / 2E Pad AOGCC Rep: Chuck ScheVe Separator psi: LPS 99 I-IPS Well Permit Separ Set L/P [ Test Test Test Date ~ WAG, GINJ, Numbe, r Number psi PS, I ,~ TriP- Code , Code Code Passed GAS or CYCLE 2E-07 1'9~1040 ,, 2E-08 1931890 99 70 60 "P P ' 2E-09 1842400 . 2E-10 184_2300 99 70 ' 60 P P 2E-11 18479~60 99 70 50 - P P 2E-15 1841890, 99! 70 50.~ P P i2E-16 1841900 99 - 70 50 P , ,4 ...... __ WellS: 5 Components: 10 Failures: 1 Failure Rate: 10.00~/12190 my ' Remarks: Surfa__-ce safety on 2E'l 6 had Slow leak when pressure tested. Valve will be .serviced .a retested by Operator. RJF 1/16/01 Page 1 of 1 SVS KRU 2E Pad 1-28-01 CS.xls STATE OF ALASKA 0 ALASKA OIL AND GAS ~RVATION COMMISSION REPORT OF SUNDRY WELl. OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate X Plugging Perforate _ Repair well _ Pull tubing Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service , R9E, UM , R9E, UM , R9E, UM 4. Location of well at surface 503' FNL, 63' FWL, Sec. 25, T11N, R9E, UM At top of productive interval 1385' FSL, 1344' FEL, Sec. 25, T11N At effective depth 1240' FSL, 1168' FEL, Sec. 25, T11 N At total depth 1204' FSL, 1124' FEL, Sec. 25, T11N feet feet 12. Present well condition summary Total Depth: measured 8 6 2 0' true vertical 6282' 6. Datum elevation (DF or KB) 126' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-12 9. Permit number/approval number 84-~4 10. APl number 50-029-21131-00 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) Effective depth: measured 8505' true vertical 6196' feet feet Junk (measured) Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 4 0 2 1 ' 9 5/8" Intermediate Production 8 5 8 8' 7" Liner Perforation depth: measured 8269' - 8286', true vertical 6015' - 6028', Cemented 224 Sx 1600 Sx 575 Sx 8313' - 8344' 6047' - 6071' Tubing (size, grade, and measured depth) 2 7/8", 6.5 Ibs/ft, J-55, 8220' MD Measured depth 110' 4021' 8588' True vertical depth 110' 3142' 6258' P, EEEJVED Alaska 0ii & 6as Cons. Commission Packers and SSSV (type and measured depth) Camco HPR ~ 8190', 7506', Baker FVL, 2018' (Otis FXE WRSSSV) 13. Stimulation or cement squeeze summary 14. Anchorage Refrac A Sand Intervals treated (measured) 8269' - 8286', 8313' 8344' Treatment description including volumes used and final pressure Pumped 152,300 lbs of light weight proF pant (LWP) in 1 to 9.7 ppa stages. Last WHTP=6530 psi. Reoresentative Daily Average Production or Iniecfion Data Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run t Daily Report of Well Operations X 17. I hereby certify that the foregoing Sicjned · OiI-Bbl Gas-lVlc~ Water-Bbl Casing Press Tubing Press 847 451 45 I 1 0 0 169 2205 1574 116 1 700 198 16. Status of well classification as: Oil X Gas Suspended is true and correct to the best of my knowledge. Ti'de PETROLEUM ENGINEER Date Service Form 10-404 Rev 08/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc" Subsidiary of Atlantic Ricl~field Company WELL I PBDT tTRACTOR WELL SERVICE REPORT FIELD-DISTRICT-STATE~ JDAY~ OPERATION AT REPORT TIME ~DATE o 7-t-9-t REMARKS (2]5 ~ oat.. S E P 2 8 1992 Alaska.0il .& Gas Cons. Oommissi¢ I-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport ]Temp. *F °F miles knotl ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7291 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 D- 1 2 Bottom-Hole Pressure Survey 8 - 2 2 - 8 8 PBU 3 H - 1 8 Bottom-Hole Pressure Survey 8 - 2 2 - 8 8 Flowing Gradient Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska Unocal(+vendor package Mobil(+vendor package) Unocal(+vendor package) SAPC(+vendor package) STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMb~,,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate'J~ 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 503' FNL, 63' FWL, Sec. 25, T,,N, RgE, UM At top of productive interval 1385' FSL, 1344' FEL, Sec. 25, T11N, R9E, UM At effective depth 1240' FSL, 1168' FEL, Sec. 25, T11N, R9E, UM At total depth 1204' 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-Z2 Producer 8. Approval number 9. APl number 50-- 029-2113100 FSL, 1124' FEL, Sec. 25, T11N, R9E, UM 10. Pool Feet Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 8620' feet Plugs (measured) 6282' feet Effective depth: measured 8505' feet Junk (measured) true vertical 6196' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 16" 224 Sx 110' 110' Surface 4021' 9-5/8" 1600 Sx 4021' 3142' Intermediate Production 8588' 7" 575 Sx 8588' 6258' Liner Perforation depth: measured 8269'-8286', 83,3'-8344' ND true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) JUN 2 2 1988 3 1/2" 9.3 lb/ft J-55 8220' . Cons. C~mmissio ' ' ' Nas~ 0It & Gas - Nmhorage Camco WRDP @ 2018', Camco HRP @ 8190'. 12. Stimulation or cement squeeze summaryRefracture A Sand with gelled diesel sand frac. Intervals treated (measured) 8269 ' -8344' Treatment description including volumes used and final pressure 1325 bbls gelled diesel, 83,000 lbs proppant, 4500 psi 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure ~bing Pressure 548 299 0 1200 125 1951 1577 0 1200 400 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 /,.~.~. f/~.~.U.f~.~.~ Form 10-40-4 Rev. 12-1¢'85 Title Date Su bruit ir~ Du~licate~' ARCO Alaska, InP-~ ~ ..Subsidiary of Atlantic Richfield Compa, REMARKS IOPERATIO'..bi AT REPORT, TIMI~ WELL SERVICE REPORT RE, E!VED 1988 nnne._ P, ommissiort Anchorage ['-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Tamp. I Chill Factor I Visibilily Wind Vel. Report °FI °FI~ miles knots ] Signed. L_~ ~,//'~;;~' ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 9, 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 the following Kuparuk wells. Wel 1 Action Anticipated Start Date 2D- !=2 ................... S_.~_i mu 1 ate Q 1H-3 Stimulate 1A-2 Stimulate May, 1988 If you have any questions, please call me at 265-6840. Sincerely, lwood Senior Operations Engineer GBS'pg'0181 Attachments cc: File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary o! AtlanllcRichlieldCompany STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COME. SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend '; Operation Shutdown i ] Re-enter suspended well [TJ Alter casing Time extension Change approved program L! Plugging ~ Stimulate .~ Pull tubing ' ' Amend order [-i Perforate [' Other 2. Name of Operator ARCO Ala_~ka. Inc. 3. Address P.O. Box 100360, Anchoraqe, Alaska 99510 4. Location of well at surface 503' FNL, 63' FWL, Sec. 25, T11N, R9E, UM 5. Datum elevation (DF or KB) ~200' SS 6. Unit or Property name Kupar'uk River' Unit 7. Well number 2D-12 Producer feet At top of productive interval 1385' FSL, 1344' FEL, Sec. 25, T11N At effective depth 1240' FSL, 1168' FEL, Sec. 25, T11N At total depth 1204' FSL, 1124' FEL, Sec. 25, T11N 11. Present well condition summary 8620 Total depth: measured true vertical 6282 , R9E, UM _ , R9E, UM , R9E, UM 8. Permit number 84-94 9. APl number 50-- 02921131_00 10. · P°°lKupar'uk River' 0il Pool feet feet Plugs (measured) Effective depth: measured true vertical 8505' feet 6196' feet Junk (measured) Casing Length Structural Conductor 110 ' Surface 402 ! ' Intermediate Production 8588 ' Liner Perforation depth: measured Size Cemented Measured depth 16" 224 Sx 9-5/8" 1600 Sx 7" 575 Sx . 8269'-8286' 8313'-8344' MD True Vertical depth 110' 110' 4021' 3142' true vertical 6015'-6028' 6047'-6071' TVD Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft, J-55, 8220' Packers and SSSV(type and measured depth) Camco NRRP 0 ?N1R' Cmmcn HRP O glqN' 12.Attachments Description summa~ ofproposal [] Detailed ~perations program 8588' 6258' 4.!--~x,'A-,,~ ~r.". ' :. .rDt?/?r.u. ' BOP sketch [] Stimulate A Sand with xvlene/musol mixture and refracture with gelled diesel sand frac. 13. Estimated date for commencing operation 12/22/87 - Xylene .~'/10/88 - Fr'ac 14. If proposal was verbally approve~d ~._ Name of approver ~3 ~ ~/{~ q'O~'/~ ~. / ~_ ~/' Date approved 15. I hereby certify that the foregoing is true and correct to tl~ best of my knowledge ~ ,/~(~,~ Signed ,.,~;fd),.~.,¢/ ,~ 2/'~,t~.~r.~¢~ Title /X~ ~,~/...,~.~J--¢,~.~ ~'".~.t~ Date/, f-,,~f ~ ~) Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test _l~,.,~,~lti~r~l~aranceI U ~ A~,I~-,~ ~ -' ~Yd~ by order of e~~ Approved b Commissioner the commission Dat Form 10-403 Re~-12-1-85' Sa~omit ~n triplicate SUNDRY NOTICE - WELL 2D-12 A SAND FRACTURE TREATMENT NO BOP'S ARE USED DURING THE FRACTURE. THE FRAC WILL BE PUMPED THROUGH- A MANIFOLD ON SURFACE. A SAND PRESSURE (6200' SS) = 3077 PSI 2/19/88 PBU NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. Messrs. Fontenot and' 5inson December 16, 1987 Page 3 Procedure Well 2D-12 Xylene/Musol Wash CC' 230DS28DG December 16, 1987 1) 2) 3) 4) 5) 6) 7) 8) 9) Shut in well and lift gas. MIRU slickline RIH w/Gauge Ring to ensure tubing is free from asphaltene deposition. RD slickline. MIRU Pump Truck. Pump mixture of 1000 gallons of xylene and 100 gallons of musol. Displace with 51 bbls of hot diesel. Maintain low pump rates to prevent damage to the fracture sand pack. Let soak for I hour, then open well at surface and allow to flow for 1 hour. Pump 40 bbls of hot diesel to displace xylene back into formation, let soak for 12 hours. RDMO Pump Truck. 10) Open well to production to flowback xylene/musol. 11) After well has stabilized for at least 48 hours, obtain a 24 hour well test. ,den and Wade 1988 r~ Kuparuk Well 2D-12 A Sand Refrac Procedure 5/2/88 Charge Code: 230DS28DL A large refracture treatment will be performed to reduce the wells current skin damage of +3. Also, the fracture treatment will reach a small lobe of marginal C Sand above the A Sand interval. 1) 2) 3) 4) 5) 6) 7) 8) 9) MIRU slickline. RIH to pull WRDP. Send to vendor for redress as needed. RIH to replace GLV's at 2645', 4960', 6290', 7158', 7688' and 8126' with DV's. RIH with standing valve and set in "D" nipple. PT tubing to 3000 psi to ensure DV's are in place. RDMO S1 ickl ine. MIRU pump truck. Pump pre-pad musol/xylene spear. Let soak overnight. RDMO pump truck. 10) MIRU fracture equipment. Install "tree saver". 11) Check diesel for contamination prior to gelling for frac. Check Carbolite for fines due to excessive handling. Obtain a sample of the Carbolite and the gelled diesel with breaker. Record the proppant weight before and after the fracture treatment. 12) Pump fracture treatment per the attached schedule. Treating Pressure: Expected Wellhead WHTPE : 4400 psi {Based on previous fracture treatment.) Fracture Gradient = 0.70 psi/ft {6050' TVD) Tubing Friction = 270 psi/lO00 ft {8220' MD) ** If treating pressure during the pad is in excess of 6500 psi, shut down job and confer with Operations Engineering. 13) 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 and Wade 's during flowback period. Inspect samples for frac sand. If frac ~nd 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%. 15) Once well has completed flowback, rerun WRDP and obtain a 24 well test. Contact Operations Engineering for a new gas lift design. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 15, 1988 Transmittal #: 7119 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2I~-t4 2Z-8 2H-5 2H-5 3C-15 ~ i~D~l:2 Kuparuk Operations Engineering Water Injection Spinner_Data. Sheet 2-16-88 Both Sands Kuparuk Operations Engineering Water Injection Spinner Data Sheet 3-2-88 Both Sands Kuparuk Operations Engineering Buildup Analysis Kuparuk Well Pressure Report(Otis) 2-27-88 GRC Amerada Chart(2) 8-26-87 Pressure/Temperature 2-16-88/2-19-88 2-25-88 'C' Sand PBU 'A' Sand PBU 'A' Sand PBU 'A' Sand Receipt Acknowledged: DISTRIBUTION: D&M --- '-~'t'3 Oil & Gas Cons. Commissicr~ Anchorage Chevron Mobil SAPC Unocal ARCO Alaska. Inc. is a Subsidiary of AllanticRichlieldCompany ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 -l-elephone 907 276 1215 July 28, 1987 Ms..Fran Jones Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Miscellaneous GCT Surveys Dear Fran: Enclosed are additional copies of the following GCT surveys: 1L-6 2A-2 1L-15 2A-3 1L-16 2A-4 L1-1 2D-11 L2-28 2D-12 2G-8 2G-10 2G-13 If you have any questions, please call me at 263-4944. Sincerely, D. Gruber Associate Engineer JG:pk JG/78 Enclosures JUL ~ I 1 87 AJ'agka 0il & Oas Cons. Commisslo, Anchorage /HICO Alaska, Inc. Is a Subsidiary of AllanllcRIchfleldCompany Classification of Service Well 1. Status of Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · , , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage; AK 99510 50- 029-21131 4. Location of well at surface 9. Unit or Lease Name 503' FNL, 63' FWL, Sec.25, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1385' FSL, 1344' FEL, Sec.25, T11N, R9E, UM 2D-12 At Total Depth 11. Field and Pool 1204' FSL, 1124' FEL~ Sec.25, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 126' RKBI ADL 25658~ ALK 2584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/01/84 07/!2/84 _ 09/12/84*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TvD) 19.Directi°nalsurvey I20' Depth where SsSv set I21'Thickness°fPermafr°st 8620'MD,6282'TVD 85.08'MD,6196'TVD YES [~ NO [] . 2018 feet MD l~nn' (~ppro~) 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR/Cal, DIL/SFL/GR, Cal. Gyro. CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:; 6z.~ H-40 5urt 110' ' 24" 224 sx Cold Set II ~-b/~" ,~6.0# J-55 Surf 4021' 12-1/4" 1150 sx AS III & 450 sx ;lass G 7" 26.0# J-55 Surf 8588' 8-1/2" 325 sx Class G & 250 sx ~S 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) 8313' - 8344' 2-7/8" 8220' 8190' 8269' - 8286' w/4 SPF 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See Addendum attac~ed to Well Completion 'Report dated 12/31.f85. · . . . , PRODUCTION TEST 27. N/A. . Date First Production J Method of Operation (Flowing, gas lift, etc.) I '' I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MGF WATER-BBL CHOKE SIZE GAS-el L RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~l~ 28. CORE DATA Brief description of tithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit c o~Jl~s. ~ .~ - JUNO $ J986 NONE Alaska Oil & Gas Cons. Comm~.~ A.~.~,:.~,~ ' ...... ~,.~ *NOTE: Workover was completed on 5/29/85 and 10/09/85. (WC1/027) ; "'~" STATE OF ALASKA '~' "~'~ ~ - ALASKA OIL AND GAS CONSERVATION CO,v, MISSlON ~ ¢3 WI=LL COMPLETION OR RECOMPLETION REPORT AND Form 10-407 Submit in duplicate_^/' Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ GEoLoGIc MARINERS . ' '- . ~: ';'~'~ ·FORMATION TESTS " . · . . . NAME Include interval tested, pressure data, all fluids recovered and gravit'y, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8183 ~ 5951 ~ N/A Base Upper Sand 8188 Top Lower Sand 825:3 Base Lower 5and :~- .- 8/+16~ 61267 .... .. ; ." · ' ' ' -t, i : :.. " . ,... : . - ;: · : .. , · _ · . ~ .. ... 31. LIST OF ATTACHMENTS ¥1orkover We] 1 History . . 32. I hereby certify that the foregoing iS-true and correct to the best of my knowledge .. Signed Title 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 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Init{al Rel~rt'; on- the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 904511 Pool 102 ICounty, parish or borough I North Slope Borough J Lea~ or Unit ADL 25658 JTitle I Recompletion State Alaska Well no. 29-12 W/O APl 50-029-21131 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover 9/22/85 thru 9/23/85 9/24/85 9/25/85 9/26/85 9/27/85 9/28/85 thru 9/30/85 10/01/85 Date and depth as of 8:00 a.m. IDate 9/22/85 IHOur Complete record for each day reported IARCO W.I. Prior status if a W.O. 56.24% 0900 hrs. 7" @ 8588' 8506' PBTD, Pull 3½" tbg 10.1+ NaCl/NaBr Accept ri~ @ 0900 hfs, 9/22/85. ND tree, NU & tst BOPE. BPV. Pull tbg hgt. Prep to pull 3½" tbg. Pull 7" @ 8588' 8506' PBTD, POH w/bit/scrpr/JB 10.1+ NaC1/NaBr Fin CBU, POH w/3½" tbg. PU DP, RIH, tag TOF @ 8120', push fsh to 8158', C&C brine, POH. 7" @ 8588' 8506' PBTD, POH w/fsh 10.1+ NaCl/NaBr Fin POH w/bit/scrpr/JB. TIH w/globe bskt, attempt to set RAM w/o success, rev circ& monitor well, POH. RIH w/taper tap to 8158', screw into fsh, POH w/taper tap & fsh. 7" @ 8588' 8506' PBTD, TOH w/FTA #4 10.1NaCl/NaBr TOH w/FTA #2; no rec'y. RIH w/FTA #3, tag fsh @ 7810', mill & chase to 8158', TOH, rec'd partial fsh. RIH w/FTA #4 w/2-1/8" x 4" taper tap, tag fsh @ 8158', pull on fsh & prep to TOH. 7" @ 8588' 8506' PBTD, Wsh pipe over coiled tbg 9.2+ ppg NaC1/NaBr TOH w/FTA #4, rec'd pkr & tailpipe. TIH w/FTA #5 to 8171', wrk ~.~ ,,, ~,~ dn over jnk & coiled tbg to 8178', TOH, rec'd p~r~ta'l f~h, .MU FTA #6, displ hole w/9.3 ppg brine & wsh over tbg. 7" @8588' ~Ska JU/ 'O 3 2585 8506' PBTD, 8620' TD, TIH w/FTA #11 ~ 9.4+ ppg wtr based mud ~ .~...'-"-'"'~,~. (~'?~ .... Cont fsh'g opera~ions f/coiled tbg; rec'd 21.5' co{l~d_.tbg, frac sand & metal debris. 7" @ 8588' 8506' PBTD, 8620' TD, RIH w/3½" magnet 9.4 ppg wtr based mud Cont fsh'g operations w/no rec'y. RU WL, rn 6" impression__A ~'~'~ block; indicates coiled tbg on high side of hole. RIH w/3½" ~ shielded magnet. <~ j~ The above is correct Signature For fnrm nrmn~ratinn ~nd distribution_ Date [ Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: 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" sheels until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequenlly 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 strin§ until completion. 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 10/02/85 District Field Date and deptll as of 8:00 a.m. 10/03/85 10/04/85 i0/05/85 thru 10107/85 lO/O8/85 10109185 State 7" @ 8588' 8506' PBTD, 8620' TD, POOH wet 9.4 ppg Gel/H20/Barite Rn shielded magnet w/no rec'y. MU FTA #13 w/cut lip shoe, RIH, mill on junk & fsh to 8211' POOH wet 7" @ 8588' 8506' PBTD, 8620' TD, Cont fsh'g operation 9.5 ppg Gel/H20 Fin POH. Tst BOPE to 200/3000 psi. RIH w/fsh'g BHA #14, tag top of mill/fish @ 8207', mill & wsh 8207'-8290'. 7" @ 8588' 8506' PBTD, 8620' TD, Cont fsh'g operation 9.5+ ppg Gel/H20 M&P hi vis sweep, POH. RIH w/FTA #15, wrk & wsh over fsh @ 8207' to 8497', circ hole cln, POH. Alaska 7" @ 8588' 8506' PBTD, 8620' TD, Chg over to 9.3 ppg NaC1 9.3 ppg NaC1 POH, LD wsh pipe; no fsh. RIH w/kelo socket, wrk & wsh, POH; no fsh. RIH w/4 jts wsh pipe, RD OS, wsh & rotate f/8254'-8370', POH. MU wsh pipe w/grapple ext, RIH, wsh & mill 8370'-8449', POH. MU mill & JB, RIH, mill & pound 8443'-8470', POH, LD tls. MU bit & JB, RIH, chg well over to 9.3 ppg NaC1. RIH w/R-3 pkr on 3½" tbg, 7" @ 8588' 8506' PBTD, 8620' TD, LD 3½" tbg 9.3 ppg NaC1 Chg over mud & brine. POH, LD DP. tst csg; OK. POH, LD tbg. 7" @ 8588' 8506' PBTD, Displ to diesel 9.3 ppg NaC1 POH, LD 3½" tbg. RU & rn 262 jts, 6.5#, 2-7/8", J-55 8RD EUE tbg w/SSSV @ 2018' MD, HRP Pkr @ 8190', "D" Nipple @ 8209', TT @ 8220'. Set pkr, ND BOPE, NU & tst tree. Prep to displ diesel. Well no. 2D-12 [4/O The above is correct Signature For form preparation'~n(~distribution see Procedures Manual ~ection 10, Drilling, Pages 86 and 87' IOate [Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report': on the first 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 data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space iS available. I Accounting District ICounty or Parish I State Alaska North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25658 Auth. or W.O. no. ~Title AFE 904511 I Recompletion Pool 102 Operator ] A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun IOate I Workover Date and depth as of 8:00 a.m. lO/lO/85 Classifications (oil, gas, etc.) 0il Complete record for each day reported cost center code Alaska JWell no. 2D-12 W/O API 50-029-21131 W.I. rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% Jabandonment of this well IHour I Prior status if a W.O. 9/22/85 ! 0900 hrs. I 7" @ 8588' 8506' PBTD, RR Displ well to diesel, tst orifice, set BPV. lO/9/85. RR @ 1100 hfs, Old TD ] New TD [ PB Depth 10/09/8s I 8506' Released rig Date [Kind of rig ll00 hrs. 10/08/85 [ Rotary Type completion (single, dual, etc.) Single Producing method Flowing Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature~ ~3~~ Date {Title For form preparation and (~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 3, 1986 Mr. C. V. Chatterton Con, hi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 1R-8 20-12 3C-13 3C-14 If you have any questions, please call me at 263-4944. Sincerely, d. ~ruber ^ssoc~ate [ng~neer JG/tw GRUI3/L01 Enci osures ARCC -'.:asks, !nc. is a Subsidiary o1 AllanticRichfieldCompany STATE OF ALASKA · ALASKA (_ J AND GAS CONSERVATION CO. AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL j~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21131 · 4. Location of well at surface 9. Unit or Lease Name 503' FNL, 63' FWL, Sec.25, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1385' FSL, 1344' FEL, Sec.25, TllN, R9E, UM 2D-12 At Total Depth 11. Field and Pool 1204' FSL, 1124' FEL, Sec.25, T11N, RgE, UN Kuparuk River Field · I 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 126' RKB ADL 25658 ALK 2584 12' Date Spudded07/01/84 13. Date T.D. Reached07/1 2/84 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re I 16' N°' °f C°mpleti°ns09/1 2/84* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8620'MD,G282'TVD 8508'MD,6196'TVD YES []X NO [] N/A feetMDI 1500' (approx} 22. Type Electric or Other Logs Run DIL/FDC/CNL/GR/Cal, DIL/SFL/GR, Cal, 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 Cold Set II 9-5/8" 36.0# J-55 Surf 4021' 12-1/4" 1150 sx AS Ill & 450 s~ Class G 7" 26.0# J-55 Surf 8588' 8-1/2" 325 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) 8313' - 8344' N/A 8269' - 8286' w/4 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Adde~dum~ dated 12/11/85, for frac data. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Test'ed PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ FloWTubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "~ 28. CORE DATA Brief description of lith°logy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ; , '.~.,,7~,... ~. Form 10-407 * NOTE: Workover was completed on 5/29/85. GRU12/WC18 Submit induplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . Top Upper Sand 8183'- 5951 ' N/A ' Base Upper Sand 8188' 5954' Top Lower Sand --..8253' 6000' .- .... Base Lower Sand 8416' 6126' . . . 31. LIST OF ATTACHMENTS ~ Addendum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed ~ ~ ~ Title Associate 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 24 show the producing intervals-for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ADDENDUM WELL: 2D-12 8/26/84 8~27~84 10/22/84 10/23/84 10/24/84 11/01/84 11103184 11/05/84 11/07/84 11/08/84 Rn CBL/JB f/8496' WLM-6900'. Est top of cmt @ 7210'; goOd bond. Rn GCT gyro f/surf-8450'. 8508' PBTD, Flowing RU Dowell on 2D-12. Instl tree saver. Tst Ins to 5400 pSi. Pmp 1100 bbls of gelled H?0 pre-pad @ 20 BPM, 4400 psi. ISIP = 1540 psi. Pmp 27 5bls gel H.0 pad @ 15 BPM, 3800 to 4000 psi. ISIP = 1800 psi. PerfZfriction press = 650 psi. Flush w/73 bbls gelled diesel @ 1/2 to 10 BPM, 3600 to 5000 psi. ISIP = 2100 psi. SI, RD Dowell. RU CTU & N_. Tst BOP & ins to 4000 psi. Jet hole dry w/No. Hea~ No to 180° - 200° F & wrk up & dn thru perfs. Well started ~aking fluid. Displ w/diesel & POOH, RD. Well started flowing & stabilized @ 12.5 BPH. Cont flowing, rec'd 120 bbls. 8508' PBTD Flowed well to tank. Rec'd 433 bbls. 8508' PBTD Flowed well to tank. Rec'd 202 bbls. 8508' PBTD, Well SI RU Dowell & gel tanks. Pmp 40 bbls hot diesel, followed by 100 bbls pre-pad. Pmp 5 bbls pad. Pmp 42 bbls 100 mesh @ 1 ppg. Pmp 40 bbls spacer. Pmp 26 bbls 12-20 mesh @ 2 ppg. Pmp 40 bbls 12-20 mesh @ 7 ppg. Pmp 20 bbl flush. Screen out @ 5600 psi. RD, secure well. RU CT & nitrogen unit. Cln out to 8486'. Stuck @ 8486'. Wrk CT; no movement. Shut dn, secure well. (11/5/84) Att to circ thru CT. Pmp total of 51.6 bbls of brine, followed by 1.2 bbls diesel. No rtns. Flowing well thru CT to tank. Well flowing thru 1-1/4" CT, pmp 13 bbls of 10.8 brine @ 2600 psi (10.3 bbls to displ CT). Att to pull CT free & circ dn 1-1/4" tbg & up 3-1/8" x 1-1/4" ann w/o success. Observe well. Both ann & CT dead. Pull 15,000 on CT. Cut CT w/mst vlv. SI well & RD CTU. i' WELL: 2D-12 11/09/84 11/08/85 Well flowing thru 1-1/4" CT, pmp 13 bbls of 10.8 brine @ 2600 psi (10.3 bbls to displ CT). Att to pull CT free & circ dn 1-1/4" tbg & up 3-1/8" x 1-1/4" ann w/o success. Observe well. Both ann & CT dead. Pull 15,000 on CT. Cut CT w/mst vlv. SI well & RD CTU. Frac well w/299 bbls diesel, 1000# 100 mesh & 8184# 20/40 sand @ avg rate of 20 BPM, 4400 psi. Left 384# 20/40 sand in csg, as per procedure. Dri~rintendent DAte ARCO Alaska, Inc. ~-..~., Post Office B~ 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton- Enclosed are the October monthly reports for the following wells' 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C-14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L80 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · STATE OF ALASKA ALASKAO AND GAS CONSERVATION COk ,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation~)~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-94 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21131 4. Location of Well at surface 503 ! FNL, 63' FWL, Sec.25, TllN, RgE, UM 6. Lease Designation and Serial No. ADL 25658 ALK 2584 5. Elevation in feet (indicate KB, DF, etc.) 126' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2D-12 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of October ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 0900 hfs, 9/22/85. ND tree. NU BOPE & tstd. Pulled 3-1/2" tbg. Fished & recovered pkr & tailpipe assy. Recovered 122' (approx) coiled tbg. Pushed remaining tbg to 8445' (lowest perf ~ 8344'). Displaced well to NaC1. Tstd 7" esg to 3000 psi - ok. Ran 2-7/8" completion assy. ND BOPE. NU tree & tstd. Displaced well to diesel. Set BPVo Secured well & RR @ 1100 hfs, 10/8/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 2-7/8", 6.5#/ft, J-55, 8rd, EUE tbg SSSV ~ 2018', pkr ~ 8190' TT ~ 8220' 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE 6. DST data, perforating data, shows of H2S, miscellaneous data NONE RECEIVED 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-12 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 2D-12. I have not yet received the Workover Well History. When I do, I will forward a copy to you. Also, the tubing details will be submitted when the well is completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L08 Enclosure AUG 3 0 l B§ AlasV, a Oil & Gas Cons. knchors9e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ---- STATE OF ALASKA ---. ALASKA C ,. AND GAS CONSERVATION CO; ]ISSION 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. 84-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21131 4. Location of well at surface 9. Unit or Lease Name 503' FNL, 63' FWL, Sec.25, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1385' FSL, 1344' FEL, Sec.25, T11N, RgE, UN 2D-12 At Total Depth 11. Field and Pool 1204' FSL, 1124' FEL, Sec.25, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 126' RKBI ADL 25658 ALK 2584 i 2. Date Spudded07/01/84 13. Date T.D. Reached07/12/84 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns09/12/84* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'FVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8620'ND,6282'TVD 8508'MD,6196'TVD YES F~X NO [] N/A feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/Cal, DIL/SFL/GR, Ca1, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SE'I-I-lNG DEPTH MD i.CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 224 sx Cold Set II 9-5/8" 36.0# J-55 Surf 4021' 12-1/4" 1150 sx AS III & 450 s: Class G 7" 26.0# J-55 Surf 8588' 8-1/2" 325 sx Class G & 250 s: AS I -~4. 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) 8313' - 8344' N/A 8269' - 8286' w/4 s, pf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A' PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD 'Flow Tubing Casing Pressure CALCULATED.~ 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. gECEIvED Alaska 0il &g~a~s COns. ',.flor~,~ Commission Form 10-407 * NOTE: Workover was completed on 5/29/85. TEMP/WC87 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :,--~-:::,:. :':: ~Eo,:b~,'~'~'2~:-~ .:--:;'~ :.:¥~: 'i, ::":-: ~. i,~ ~:i~ -:-~.:-:!,:.:'L:~i:' :~-:" ;~:':::,': ~'.-"~oi~Z~;°N'~s~'' :" "'~--i? '~ .-.: :-" :" .... . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 818:3' 5951~ N/^ --':; · :".", '" Base Upper Sand 8188' 595~' Top Lower Sand 8253' 6000' :.' Base Lower Sand 8b, 16' 6126~ : ; , - . · : [~ ': i , , , ' '- · , : · - ; . ', -.~-i. : , , ' ' :' .. : · .. . .. . :>; . . - . '::F ... · 31. LIST OF ATTACHMENTS None - · · :~ -' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /'t INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from' ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells: 2D-12 WSP-9 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU10/L77 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L LXI~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 503' FNL, 63' FWL, See.25, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 126' I 6. Lease Designation and Serial No. ADL 25~5R Al K 9_584 7. Permit No. 84-94 8. APl Number 50- 029-21131 9. Unit or Lease Name 10. Well Number ?D-l? 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ,,[] Abandonment Well [] Change Plans [] Repairs Made ~; Other Repair Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig 8 1500 hrs, 5/20/85. Killed well. ND tree. NU BOPE & tstd - ok. Pulled hanger & 3-1/2" tubing. Recovered 3'5" of coiled tubing. Milled on fish. Milled on inside of pkr f/8149' - 8154'. Recovered 1.45' of the pkr (inner mandrel parted ~ base of slips on pkr). POH & LD fishing tool. Ran 3-1/2" completion assy. ND BOPE. NU tree & tstd. Secured well & released rig ~ 1500 hfs, 5/29/85. RECEIVED J U L 1. 198 /'~ ..... Wii ,~, r. ,', .,,'- CoF. lm}ssi0n ·. ~ ..-,- ~.,_..[:, ,.], ,. ) /" ,-~ .;, ,~;; 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed {~ ~ ~ Title Associate Engineer The space b~tw for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10403 GRU10/SN10 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 9, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Kuparuk 2D-12 Dear Mr. Chatterton: Enclosed is a Sundry Notice for Kuparuk 2D-12. We propose to retrieve a string of coiled tubing and packer, and run a 3-1/2" single completion string for the subject well. If you have any questions, please call me at 263-4970 or Jeff Quintana at 263-4620. Sincerely, Area Dril ling Engineer JBK/JLQ/tw SN/L031 Enclosure RECEIVED M4y o 985 Oil & Gas Cons. Commission AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLxI~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360~ Anchoraqe, AK 99510 4. Location of Well Surface: 503' FNL, 63' FWL, Sec.25, TllN, R9E, UM 7. Permit No. 8. APl Number 5O- 029-2! ! 3! 9. Unit or Lease Name V.~n~.,',..b D-~,~ I1~-'~-- 10. Well Number 2D-!2 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 12R': PAD 89' I ADL 2565~ ^LK 25~q 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well J~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to retrieve a string of coiled .tubing and packer from the subject well and run a 3-1/2" single completion. The procedure will be as follows: 1. Well will be killed with 10.2 ppg brine. 2. Current 3-1/2" workstring will be pulled. 3. 1-1/4" coiled tubing and 7" retrievable packer will be retrieved. 4. The 7" casing will be tested with a retrievable packer. 5. A 3-1/2" single completion string will be run. 6. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 500~'psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: May 20, 1985 RECEIVED MAY 1 0 Alas~ Oil & 6as Cons. commis AnchoraBe 14. I hereby certj,f~that the foregoing is true and correct to the best of my knowledge. /~ ,~/.~ /~~.~~~ Title Area Drillinq Engineer Signed '-~ _ . _ / . f~r ~or~mission u~ee The space ~oTM Date . . J Cond,t~ons of Approval, if any: Approved by COMMISSIONER ~pproved Cof~y Returned By Order of the Commission Submit "Intentions" in Triplicate ~ion Form 10-403 Rev. 7-1-80 (JLQ) SN/055 and "Subsequent Reports" in Duplicate ARCO Alaska, h Post Office Box 360 · ' Anchorage, Alaska 99510 Tele. phone 907 277 5637 5; E; E! ti ti;; ?-4 C 1,":; (;) I::' E V E; i',! T 5' ; :3 F' ¢, [:: :," i :E', C U i::,' F"..' I !i;: F :-: -:,'.'- 'i C !"! El 'v' I:;-' E) N ':'"-' 'i :i.'., & N ':,'.'-i ARCO Alasl(a Inc .s 3 subsidiary of At!.'ml~cR!cnf;eldC°mP'~:'tY ARCO Alaska, Inc~'~'' Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 27, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-12 Dear Mr. Chatterton. Enclosed are addendums to the 2D-12 Well History to include with the Well Completion Report dated 10/03/84. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU4/L198. Enclosures R C IV D MAR 0 8 ]9 5 Alaska 0il & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office" '360 Anchorage,/.,aska 99510 Telephone 907 277 5637 Date: 12/12/84 Transmittal No: 4911 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 ,~0rage,~ AK 99510 ' ~ansmitted herewith, are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES = Schlumberger J #69837 2~12 7/10/84 Run 1 3994.5 - 8476.5 .~'#69835 2G-2 8/08/84 Run 1 2707.5 - 6627 z..#69779 2W-7 11/15/84 Runs 1, 76.5- 6358 2 ~-#69782 2E-15 11/17/84 Runs 2, 2603 - 6956 3 (Recomputed 12/10/84) (Recomputed 12/10/84) (Reco~puted 12/10/84) · . (Rec~mput ed 12/11/84) · , /cat Receipt Acknowledged: DISTRIBUTION Alaska 0ii & Gas Cons. Commission Anchorage Date: B. Currier Drilling W. Pasher State of AK : BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union . · · D & M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. i$ ~ subsidiary O! /-,l~nhCR,Ch~,el¢Con~Da.--~ ARCO Alaska, Inc. ~ _ · :.' ~.. ~ 3{ -. -''.c:,; 9C-7 277 5637 Date: 1.0./~84 Transmittal No: 4765 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B /aTn, P.O. Box 100360 Anchorage, AK 99510 nsmitted herewith are the following items. return one sio~ned copy of this transmittal. Please acknowledge receipt CBL' s FINALS/Schlumberger 2V-8A "Variable Density" "GCT" · 2G-1 / " " " 8/01/84 Run 1 8/27/84 " 7400 - 8909 5151 - 7991 8~27/84 " 8/27/84 ~" 4275 - 6536 5950 - 8526 8/27/84 " 5070 - 7650 7/31/84 " 6500 - 7830 7/30/84 " 7/30/84 " 6100 - 7720 7200 - 8732 2H-16 . " " " '2D-11 ~ " " " 2D-9 ~ " ,, i, 2D-12 /' " " '" 2D-lO ~ " " " Receipt Acknowledged: B. Adams · F.G. Baker P. Baxter BPAE Chevron 7/30/84 " 6100 - 7422 7/30/84 " 8/25/84 " 8/25/84 " 8/25/84 " 8/25/84 " DISTRIBUTION 7000 - 8410. 5900- 7588 6700- 7768 oz.o~ 6900 - o~ou Date: '~, ~.'. D&M Drilling Geology ------~ ° Mob i 1 W.V. Pasher G. Phillips Phillips Oil J.J. ?mthmell Alaska Oil & Gas Cons. Commissk C. R. smith" $ ta ~e' ="of' 'i6~ a ~k~~ Sohio Union NSK Operations Well Files ARCO Alaska, t/~-'~ Post Offk,,. ~-lox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 16, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2D-12 Dear Mr. Chatterton' Enclosed are the 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 GRU2/L15 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA "~" ALASKA ~ --'~-AN D GAS CONSERVATION WELL COMPLETION OR RECOMPLETION i. EPORT AND LOG Classification of Service Well 1. Status of Well OIL dX GAS ~ SUSPENDED [-! ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-94 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21131 4. Location of well at surface 503' FNL, 63' FWL, Sec.25, TllN, R9E, UP, At Top Producing Interval 1385' FSL, 1344' FEL, Sec.25~ TllN, R9E, UM At Total Depth 1204' FSL, 112h' FEL, Sec.25~ T11N, RgE, UP, 5. Elevation in feet (indicate KB, DF, etc.) 126' RKB 6. Lease Designation and Serial No. ADL 25658 ALK 2584 12. Date Spudded 07/01/84 17. Total Depth (MD+TVD) 8620' HD,6282'TVD 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2D-1 2 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 13. Date T.D. Reached07/1 2/84 .I 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns09/1 2/84 N/A feet MSL 18.Plug Back Depth (MD+TVD)I 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8508'MD,6196'TVD I YES r~ NO [] 1893 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/FDC/CNL/CR/Cal, DIL/SFL/GR, Gal, Gyro, ~_,~L 23. CASING, LINER AND CEMENTING RECORD SE'I-FIN( DEPTH MD WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 62.5# H-40 Surf 110' 24" 224 sx Cold Set II CASING SIZE 16" 9-5/8" 36. O# J-55 Surf 12-1/4- 4021' 1150 sx AS III & 450 s> Class O 7" 26.0# J-55 Surf 8588' 8-1/2" 325 sx Class G & 250 s~ AS I 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 8313' - 8344' 8269' - 8286' w/4 spf SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8183' 8158' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR Gl L-BBL GAS-MCF TEST PERIOD I~ Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE Gl LoBBL GAS-MCF 28. CORE DATA IWATER-BBL i CHOKE SIZE IGAS'OILRATIO WATER-BBL IOILGRAV'ITY-API (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Ancitora[ia Form 10-407 GRU1/WC14 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate .......... '- ~' .... ' ...... 'GE_OL.O(~Ic MARK:~'~i:~~''''. ' " ' ' ' '~:'-~bRMATION :rESTS~ .. '' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and zirne of each phase. Top Upper Sand 8183~ 5951' N/A Base Upper Sand 8188' 5954' Top Lower Sand 8253' 6000' Bas:e Lower Sand 8416' 6126' I I 31. LIST OF A'I-I'ACHMENTS Well History; Workover Well History'; Gyroscopic Survey '(2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Alq~-' 902144,~ -- Slope Boroush. ADL f25658 8~ Drill, Complete & Perforate Alaska D-12 AaCO ~Uka, Tnt. S~dd~d or W.O. tmgu~ Spudded O~t~ md de~l~ 7/01/84 7/02/84 7/03/84. 7/04/84 thru 7/05/84 The ~ io oorr~-t [Hour 7/01/84 Complete mc~rd for emeh d~y mpo~t~d 1300 Hrs. 56 24~ IPdor ~tmtus If · W.O. 16" @ 110' 1596', (1486'), DD Wt. 9.5, PV 15, YP 36, PH 9.0· WL 16.5, Sol 8 Accept tis @ 2400 hfs, 6/30/84. Nil diverter sys. Spud vel1 @ 1300 hrs~ 7/1/84. Drl & surv 12¼" hole to 1596'. 505', Assumed vertical 748', 6°, S48.50E, 747.67 TVD, 12.72 rS, 8.438, 9.52E 1112'· 18.6°, S45.50~, 1102.84 TVD, 89 27 rS, 62 07S, 64 28E 16" @ 110' 3975', (2379'), Drl$ Wt. 9.8, PV 13, ¥P-13, PH 8.5, WL 15.5, Sol 9 Drl & surv 12¼" hole to 3975'. 1474', 30.9°, S48.50E, 1430.59 TVD, 241.43 VS, 1958', 42.3°, S49.50E, 1814.11TVD· 535.67 2358', 50.7°, S47.50E, 2090.39 TVD, 824.54 rS, 2848', 51.3°· S46½E, 2396.17 TVD, 1207.33 VS, 3587', 50.2°, S44½E, 163.02S, 178.13E 355.65S, 400.57E 549.18S, 615.05E 809.39S, 895.91E 2862.98 TVD, 1779.68 VS, 1207.32S, 1308.00E 9-5/8" @ 4021' 4227', (252'), RIH w/DD Wt. 8.8, PV 6, YP 6,--PH 11.5, WL 28, Sol 3 Drl 12-1/4" hots to 4041' CBU, 10 std short trip, circ· TOH · · au & rn t~j.t$,~9--5/F', 36f, J-55· HF-ERW BTC cs8 w/FS @ 4021', FC~=.~=3939'. Cmt w/1150 sx AS III· followed by 450 sx C1 "G" w/21 S-! & .2~ D-46. Displ w/tiS pmp, bump plu8. tIP @ 0030 hfs, 7/4/84. ND Hydrl & diverter lns, NU & tst BOPE. RIH w/BHA, tab FC @ 3939', tst cs8 to 1500 psi. DO FC, cmt· FS @ 4021' + 10' new hole. Conduct formation tst to 11.5 EMW. Displ to polymer mud. Dr1 8½" hole to 4227' POOH· PU DD · · 3925', 49.9°, S44.50E, 3080.02 TVD, 2038.18, 1392.13S, 1489.62E 399t'~. 4~.7°, S45.50E, 3122.62 TVD, 2088.50, 1427.77S, 1525.26E · - , . 9-5/8" @ 4021' 5538' ), DB · (121I' Wt. 8.9· PV 9, iT 5, PH 11, WI, 24, So1 4 DD & surv 8½" hole to 5538'. 4180', 49°, S46E, 3245 TVD, 2231 rS· 1527S, 1628E 466~~', 47.5°, S41E, 3568 TVD, 2591VS, 1782S, 1882E 5349', 45.2°, S47E, 4041TVD, 3085 VS, 2134S, 2231E 7/20/84 Drillin8 Superintendent i ARCO Oil and Gas ComPany Daily Well Histor~--.Interim Iflattuctlene: This form ia used during drilling or workover operations. If testing, coring, or perforating, show formation namo 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" sheetl until final completion. Report official or representative te~t on "Final' form. 1) Submit "lltllHm" sheets when filled out but not lese frequently than avery 30 days, or (2) on Wednesday of the week in which oil ~tring ia set. Submit w~ldy for workover~ and following setting of oil string until completion. District Field Date and clepth 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 7/07184 thru 7/09/84 7/10/84 7/[1/84 7/12/84 IState Alaska no. 2D-12 9-5/8" @ 4021' 7965', (2427'), Drlg Wt. 10.1, PV 17, YP 14, PH 10, WL 16, Sol 9 Drl, DD & surv 8½" hole to 7503', wt up mud. Drl to 7965'. 5629', 44.5°, S48-1/2E, 4239 TVD, 3283 VS, 2266S, 2378E 6123', 43.6°, S46-1/2E, 4596 TVD, 3624 VS, 2498S, 2628E 6548', 51.91°, S59-1/2E, 4886 TVD, 3933 VS, 2685S, 2875E 7461', 50.0°, S58-1/2E, 5451TVD, 4637 VS, 3051S, 3492E 7774', 47.0°, S59-1/2E, 5658 TVD, 4867 VS, 3172S, 3693E 9-5/8" @ 4021' 7965', (510'), Wiper trip to re-rn logs Wt. 10.3, PV 15, YP 11, PH 10, WL 6.6, Sol 13 Drld to 8475'. C&C f/logs. Ran DIL/FDC/CNL/GR/CAL to 8467' WLM. (Had to spud thru f/6627'-6637'; DIL/FDC/CNL f/8467'-7950'. CAL would not open, unable to get density tool, repeat, unable to get below 6646'. RD Schl, prep make wiper rn. 8122'MD, 42.9°, S54-1/2E, 5905' TVD, 5110 VS, 3305S, 3899E 8435'MD, 39.6°, S51-1/2E, 6140' TVD, 5316 VS, 3430S, 4063E 9-5/8" @ 4021' 8604', (129'), Drlg Wt. 10.3, PV 13, YP 7, PH 9.5, WL 8, Sol 10 Make wiper trip to 6700', C&C hole. Log DIL/SFL/GR f/8470'-4021'; FDC/CNL f/8470'-7900'; Cal to 7100'. rat hole to 8620'. Drl add'l 7" @ 8588' 8620' TD, (16'), C&C Mud & Hole Wt. 10.3, PV 13, YP 7, PH 9.5, WL 8.0, Sol 10 Fin drlg to 8620', 5 std sht trip, TOH. Chg rams to 7", tst doors to 1800 psi; OK. Rn 221 its 7", 26#, J-55 HF-ERW BTC csg w/FS @ 8588' & FC @ 8508'. C&C mud & hole prior to cmt'g. The above ia correct For form p~'~parati~-n and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate 7/23/84 Drilling Superintendent ARCO Oil and Gas Company A Daily Well History-Final Report Instructions: Prepare and submit the "Final Re~t" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Repert- should be submitted also when operations ere suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and repre~ntativ~ test date. in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field State North Slope Borough Alaska ADL #25658 Drill, Complete & Perforate Well no. 2D- 12 I County or Parish Kuparuk River IiLease or Unit Auth. or W.O. no. ~Title AFE 902144 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I Spudded or .W.O. begun l Date Spudded Date a~d depth as of 8:00 a.m. 7/13/84 7/14/84 Complete record for each day reported ~7" @ 8588' 8508' PBTD, (0'), RR Wt. 10.2, NaC1/Br 56.24% 7/01/84 I otal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well our ~ Prior status if a W.O, 1300 Hrs. Fin C&C hole. Cmt 7" w/325 sx Class "G" w/3% KC1, .8% D-60 + .2%, D-46 @ 15.8 ppg. Disp w/315 bbls 10.2 ppg brine using rig pmps. Bump plug. ND BOPE, NU tbg spool & vlv. Tst 7" pack-off & 11" flange to 3000 psi; OK. RR @ 1630 hfs, 7/13/84. Arctic Pak w/250 sx AS I, followed by 55 bbls lightwt Arctic Pak. Old TD New TD PB Depth 8620' (7/12/84) 8508' Released rig Date Kind of rig 1630 Hrs. 7/13/84 Rotary Classifications (oil. gas. etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas I~er day Pump Size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above ia correct Signat~~~__~~.%. JDate JTitle 8/03/84 Drilling Superintendent AFE 90214~ ='~orough -ADL: f25658~-~. ' Completion API 50'029-21131 Alaska 2D-12 Orm~or ARCO Alaska-, Inc. S;udded or W.O. bosom Completion 9/10184 D~m ~ ~1~ u of 8.'00 ~.m. 8/26/84 8/27/84 9/11/84 9/12/84 1600 Hrs. lA,Co w.t. . 56 24% Prior ~t~ If · W.O. Rn CBL/JB f/8496'-6900' WLM. Rn GCT-gyro f/surf-8450'. Accept ri~ @ 1600 hfs, 9/10/84. NU BOPE. 3-1/2" @ 8183' 8508' PBTD, NU tree 10.2 pp~ NaC1/NaBr ND master vlv, NU BOPE & tst to 250/3000 psi. RU DA, tst lub to 1000 psi. RIH, perf 8313'-8344', 8269'-8286' @ 4"/4 SPF, POH. RIH to PBTD w/OB & 6.125" gage ring, POH. PU compl BRA, PU 196 Jts, 3½" tbg & ind. ND BOPE, NU tree. 10/04/84 Drilling Superintendent ARCO' Oil and Gas Company Daily Well History-Final Report Inltructh~ta: Prepare and submit the "Final Reg~ft" on ~ f[rij~,Wednescl~y after allowable has been assigned or well is Plugged, Abandoned, or Sold. "F~M R~' should ~ submi~ed al~ wh~ o .... for ~ indefinite or appreciable length of time. On workove~ when an o~clal tett i; not required u~n completion, m~ completion ~~~ In block; provided. The '*Flnel R~' fo~ may be u~d for reposing the entire operstion i~ apace is available. ' ~~ ~ District ICounty or Parish Alaska I North Slope :Borough Field ILease or Unit KuParuk RiVer I ADL tt25658 Auth. or W.O. no. ~Title AFE 902144 I Completion wwS Operator IA.R.Co. W.I. ARCO Alaska, Inc. Spudded or W.O. begun loam I Complet ion IAccounting coat center code State Alaska IWell no. 2D-12 AP1 50-029-21131 ITotal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% labandonment of this well I IHour I Prior statue if a W.O. 9/10/84 / 1600 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 9/13/84 3-1/2" @ 8183' 8508' PBTD, RR Crude oil NU & tst tree to 3000 psi. Displ w/30 bbls diesel, followed by 290 bbls crude oil. Set pkr, tst tbg w/2700 psi. Set BPV, R_~R @ 1800 hfs, 9/12/84. [ . ~ ' Old TD New TD PB Depth 8620' (:7/11/84) 8508' Released rig Date I K nd of' rig 1800 Hrs. 9/12/84 I Rotary Classifications (oil, gas, etc.) . I Type completion (single, dual, etc.! - oil I Single - Producir~g method I Official rese~ir name(s) Flowing I Kuparuk sands · Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production . Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is corr~lct! Signature ~'d/ · Date ITitle d"_L'J,.l.~ C.-G)_~~. 10/04/84 Drilling Superi.tendent For form preparation and distribution, ADDENDUM WELL: 2D-12 8/26/84 · 8/27/84 Rn CBL/JB f/8496' WLM-6900'. Est top of cmt @ 7210'; good bond. Rn GCT gyro f/surf-8450'. Drilling Superintendent ADDENDUM WELL: 2D-12 8/26/84 8/27/84 10/22/84 10/23/84 10/24/84 Rn CBL/JB f/8496' WLM-6900'. Est top of cmt @ 7210'; good bond. Rn GCT gyro f/surf-8450'. 8508' PBTD, Flowing RU Dowell on 2D-12. Instl tree saver. Tst ins to 5400 psi. Pmp 1100 bbls of gelled H~0 pre-pad @ 20 BPM, 4400 psi. ISIP = 1540 psi. Pmp 27 ~bls gel H20 pad @ 15 BPM, 3800 to 4000 psi. ISIP = 1800 psi. Perf friction press = 650 psi. Flush w/73 bbls gelled diesel @ 1/2 to 10 BPM, 3600 to 5000 psi. ISIP = 2100 psi. SI, RD Dowell. RU CTU & N?. Tst BOP & Ins to 4000 psi. Jet hole dry w/No. Heat No to 180° - 200° F & wrk up & dn thru perfs. Weis started ~aking fluid. Displ w/diesel & POOH, RD. Well started flowing & stabilized @ 12.5 BPH. Cont flowing, rec'd 120 bbls. 8508' PBTD Flowed well to tank. Rec'd 433 bbls. 8508' PBTD Flowed well to tank. Rec'd 202 bbls. MAR 0 8 1 85 Alaska Oil & Gas Cor~s. Commissior~ Anchorage Dr il 1-ing~Sup erint end ent WELL: 2D-12 ADDENDUM RECEIVED, MAR 0 8 1985 Alaska Oil & Gas Cons. Commission Anchorage ~ 8/26/84 8/27/84 10/22/84 10/23/84 10/24/84 11/01/84 11/03/84 11/05/84 11/07/84 11/08/84 Rn CBL/JB f/8496' WLM-6900'. Est top of cmt @ 7210'; good bond. Rn GCT gyro f/surf-8450'. 8508' PBTD, Flowing RU Dowell on 2D-12. Instl tree saver. Tst ins to 5400 psi. Pmp 1100 bbls of gelled H?0 pre-pad @ 20 BPM, 4400 psi. ISIP = 1540 psi. Pmp 27 ~bls gel H20 pad @ 15 BPM, 3800 to 4000 psi. ISIP = 1800 psi. Perf friction press = 650 psi. Flush w/73 bbls gelled diesel @ 1/2 to 10 BPM, 3600 to 5000 psi. ISIP = 2100 psi. SI, RD Dowell. RU CTU & Nh. Tst BOP & ins to 4000 psi. Jet hole dry w/N?. Hea~ N~ to 180° - 200° F & wrk up & dn thru perfs. z Well started making fluid. Displ w/diesel & POOH, RD. Well started flowing & stabilized @ 12.5 BPH. Cont flowing, rec'd 120 bbls. 8508' PBTD Flowed well to tank. Rec'd 433 bbls. 8508' PBTD Flowed well to tank. Rec'd 202 bbls. 8508' PBTD, Well SI RU Dowell & gel tanks. Pmp 40 bbls hot diesel, followed by 100 bbls pre-pad. Pmp 5 bbls pad. Pmp 42 bbls 100 mesh @ 1 ppg. Pmp 40 bbls spacer. Pmp 26 bbls 12-20 mesh @ 2 ppg. Pmp 40 bbls 12-20 mesh @ 7 ppg. Pmp 20 bbl flush. Screen out @ 5600 psi. RD, secure well. RU CT & nitrogen unit. Cln out to 8486'. Stuck @ 8486'. Wrk CT; no movement. Shut dn, secure well. (11/5/84) Att to circ thru CT. Pmp total of 51.6 bbls of brine, followed by 1.2 bbls diesel. No rtns. Flowing well thru CT to tank. Well flowing thru 1-1/4" CT, pmp 13 bbls of 10.8 brine @ 2600 psi (10.3 bbls to displ CT). Att to pull CT free & circ dn 1-1/4" tbg & up 3-1/8" x 1-1/4" ann w/o success. Observe well. Both ann & CT dead. Pull 15,000 on CT. Cut CT w/mst vlv. SI well & RD CTU. WELL: 2D-12 11/09/84 Well flowing thru 1-1/4" CT, pmp 13 bbls of 10.8 brine @ 2600 psi (10.3 bbls to displ CT). Att to pull CT free & circ dn 1-1/4" tbg & up 3-1/8" x 1-1/4" ann w/o success. Observe well. Both ann & CT dead. Pull 15,000 on CT. Cut CT w/mst vlv. SI well & RD CTU. RECEIVED' ~,4A~ 0 8 1985 Alaska u~ ~ ~ uo~. o~omli~slor] Anchorage Drilling ~Superintendent Date S:?/-North Slope Boroush. ADL f25658 A '902i4 - Drill, Complete & Perforate ARCO AlaSka, Inc. or W.O. ~ Spudded om 7/01/84 1300 Hfs ~ of ~."00 7/01/84 7/02/84 7/03/84. 7/04/84 thru 7/05/~4 Compt~t~ ~ tot ~ ~l~y ml~emed IAROO W.I. · 56 24% Prior ~t~t~ If · W.O. 16" @ 110' 1596', (1486'), DD Wt. 9.5, PV 15, YP 36, PH 9.0, WL 16.5, Sol 8 ~ccept ri~ @ 2400 hfs, 6/30/84. Nil diverter sys. Spud well @ 1300 hrs,.7/1/84. D:l & surv 12¼" hole to 1596'. 505', Assumed vertical 748', 6°, S48.50E, 747.67 TVD, 12.72 VS, 8.43S, 9.52E 1112', 18.6°, S45 50E, 1102.84 TVD, 89 27 VS, 62.07S, 64 28g 16" @ 110' 3975', (2379'), Drlg Wt. 9.8, PV 13, YP 13, PH 8.5, WL 15.5, Sol 9 Drl & surv 12¼" hole to 3975'. 1474', 30.9°, S48.50E, 1430.59 TVD, 241.43 VS, 163.02S, 178.13E 1958', 42.3', S49.50E, 1814.11TVD, 535.67 VS, 355.65S, 400.57E 2358'; 50.7°', S47.50E, 2090.39 TVD, 824.54 VS, 549.18S, 615.05E 2848', 51.3~, S46~E, 2396.17 TVD, 1207.33 VS, 809.39S, 895.91E 3587', 50.2°, S44½E, 2862.98 TVD, 1779.68 VS, 1207.32S, 1308.00E -'-~I0678.~' 9-5/8" @ 4021' 4227', (252'), RIH w/DD Wt. 8.8, PV 6, YP 6,-PH 11.5, W'L 28, Sol 3 Drl 12-1/4"'hote to 4041', CBU, 10 std.short trip, circ, TOH. RU & rn t~-jts, 9-5/8", 36~, J-55, HF-ERW BTC csg w/FS @ 4021', FC@'3939'. Cmt w/ii50 sx AS III, followed by 450 sx Cl "G" w/22 S-! & .22 D-46. Displ w/rig pmp, bump plug. CIP @ 0030 hfs, 7/4/84. ND Hydrl & diverter lns, NU & ~/B~A, tag FC @ 3939', est csg to 1500 psi. DO FC, cmt, FS @ 4021' + 10' new hole. Conduct formation est to I1.5 EMW. Displ to polymer mud. Drl 8½" hole to 4227', POOH, PU DD. 3925', 49.9*, S44.50E, 3080.02 TVD, 2038.18, 1392.13S, 1489.62E 3991';~.7", S45.50E, 3122.62 TVD, 2088.50, 1427.77S, 1525.26E 9-5/8" @ 402['- -' 5538', (121I'), DD Wt. 8.9, PV 9, YP 5, PH 11, WL 24, Sol 4 DD & surv 8~" hole to 5538'. 4180' 49~; S46E, 3245 TVD, 2231VS, 1527S, 1628E 4664'~ 47 *, S41E, 3568 TVD, 2591VS, 17825, 1882E 5349', 45.2', S47E, 4041TVD, 3085 VS, 2134S, 2231E :".. "' '~ '~ 7/20/84 ,.I/,/~ ,/ Drilling Superintendent ARCO Oil and Gas Company ~> ' .: ~':aily Well History--Interim Instructions: This torm ia u~ed during drilling or workover Ol:~rations_ It telting, coring, or Deriornting, show iormetion name in describing work perlormed. Number all drill Item te~ll ,~e~uentially. Attach delcription Of all cores. Work performed by Producing Section will be repotted on "Interim" Iheetl until final completion. Report official or reoreaentative test on "Fie, el" form. 1) Submit "latertm" sheets when filled OUt but not lel~ frecluently than every 30 Oays, or (2) om Weenes~e¥ of the week in which oil string ie ~L Submit weekly for workovem and Iollowing setting ot oil string until comDlelion. District Field Date eno OaDth as of 8:00 a.m. J County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL #25658 Complete record for each Osy while c!rilling or workover in progress 7/07/84 thru 7/09/84 7/10/84 7/11/84 7/12/84 IStale Alaska Well no. 2D-12 9-5/8" @ 4021' 7965', (2427'), Drlg Wt. 10.1, PV 17, YP 14, PH 10, WL 16, Sol 9 Drl, DD & surv 8½" hole to 7503', wt up mud. Drl to 7965' 5629', 44.5°, S48-1/2E, 4239 TVD, 3283 VS, 2266S, 2378E 6123', 43.6°, S46-1/2E, 4596 TVD, 3624 VS, 2498S, 2628E 6548', 51.91°, S59-1/2E, 4886 TVD, 3933 VS, 2685S, 2875E 7461', 50.0°, S58-1/2E, 5451TVD, 4637 VS, 3051S, 3492E 7774', 47.0°, S59-1/2E, 5658 TVD, 4867 3S, 3172S, 3693E 9-5/8" @ 4021' 7965', (510'), Wiper trip to re-ri logs Wt. 10.3, PV 15, YP 11, PH 10, WL 6.6, Sol 13 Drld to 8475'. C&C f/logs. Ran DIL/FDC/CN%/GR/CAL to 8467' WLM. (Had to spud thru f/6627'-6637'; DIL/FDC/CNL f/8467'-7950' CAL would not open, unable to get density tool, repeat, unable to get below 6646' RD Schl, prep make wiper ri. 8122'brJ), 42.9°, S54-1/2E, 5905' TVD, 5110 VS, 3305S, 3899E 8435'MD, 39.6°, S51-1/2E, 6140' TVD, 5316 VS, 3430S, 4063E 9-5/8" @ 4021' 8604', (129'), Drlg Wt. 10.3, PV 13, YP 7, PH 9.5, WL 8, Sol 10 Make wiper trip to 6700', C&C hole. Log DIL/SFL/GR f/8470'-4021'; FDC/CNL f/8470'-7900'; Cal to 7100' rat hole to 8620'. Drl add'l 7" ~ 8588' 8620' TD, (16'), C&C Mud & Hole Wt. 10.3, PV 13, YP 7, PH 9.5, W-L 8.0, Sol 10 Fin drlg to 8620', 5 std sht trip, TOH. Chg rams to 7", tst doors to 1800 psi; OK. Rn' 221 jts 7", 26#, J-55 HF-ERW BTC csg w/FS @ 8588' & FC @ 8508'. C&C mud & hole prior to cmt'g. The above is correct For form ~'el~aration ln(:10iltriDution see Proceclures Manual Section 10, Drilling, Pages 86 and 87 IDa~e 7 ]Title /23/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report. in..tn~cti~.~l: Prepare and submit the "Final RI~I'I" on the fi~t Wednesday atte[ allowable has been assigned or well Is Plugged. APandonsd. or Sold. "Final Relsert" should be eubmitled also when ODeratiOnl are suspended for an inOelinile or appreciable length of time. On workovers when an Official test is not reguired uPOn combletion, ret)orr completion end l~prlNntalJv~ test data ih blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center cools Dislr, ct I State A~aska Field Kuparuk River Auth. or W.O. no. AFE 902144 OPerator ARCO Alaska, Inc. ICounty or Parish Lease or Unit Title North Slope Borough Alaska Well no. ADL #25658 29-12 Drill, Complete & Perforate W.I. ~otal number of wells {active or inactive) on this Icost center prior to plugging and I 56.24% labancionment of this~ well I IHour I Prior status if a w.o. / 1300 Hrs. Spuode(3 or W.O. begun 7/13/84 I A.R.Co. Date Spudded Cate al~d depth as of 8:00 a.m. 7/14/84 Complete record for each day reporteo 7/0[/84 7" @ 8588' 8508' PBTD, (0'), RR Wt. 10.2, NaCi/Br Fin C&C hole. Cmt 7" w/325 sx Class "G" w/3% KC1, .8% D-60 + .2%, D-46 @ 15.8 ppg. Disp w/315 bbls 10.2 ppg brine using rig pmps. Bump plug. ND BOPE, NU tbg spool & vlv. Tst 7" pack-off & 11" flange to 3000 psi; OK. RR @ 1630 hfs, 7/13/84. Arctic Pak w/250 sx AS I, followed by 55 bbls lightwt Arctic Pak. Old TD New TD 8620' (7/12/84) Released 1630 Hrs. Cate 7/13/84 tPB Debth Kind of rig 8508' Rotary Classilications (oil, gas, etc.) O£1 Producing method Flowing Type completion (single, clual, etc.) Single Official reservoir namels) Kuparuk Sands Potential lest data . Well no. i Date Reservoir Producing Interval !Oil or gas Test time ;Production Oil on test Gas per Jay Pump size, SP~ X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective {tats corrected , ,, The above l$ correct Date ITitle 8/03/84 Drilling Superintendent Kup'~x'*uk "--" w.~ .~ Completion AYE 90214~ WWS ~1 AP1 50-029-21131 ARCO Alaska-, Inc. Completion 9/10/84 1600 Hrs. ,.,w.,. 56.24% ~ If ~ W.O. D~te m'~ Clel:~'~ Gom~me r.,c~ra ~ each u of ~**00 ,m,.m. 8/26/84 8/27/84 9/11/84 9112/84 .- Rn CBL/JB f/8496'-6900' WLM. Rn GCT-gyro f/surf-8450'. Accept ri~ @ 1600 hfs, 9/10/84. NU BOPE. 3-1/2" @ 8183' 8508' PBTD, NU trem 10.2 ppg NaCl/NaBr ND master vlv, NU BOPE & tst to 250/3000 psi. RU DA, est lub to 1000 psi. RIH, perf 8313'-8344', 8269'-8286' @ 4"/4 SPF, POR. RIR to PBTD w/JB & 6.125" gage ring, POH. PU compl BRA, PU 196 its, 3½" tbg & ind. ND BOPE, NU tree. lO/O4/84 Drillin~ Superintendent ARCO Oil and Gas Company Daily Well History-Final_Report. Inatructt~e~e: Prepare and submit the "Final RIDer1" on th~ flrl~. We~ ~er allowable has ~en a~igned or well is Plugge~. Abandoned. or ~ld. "F~ R~' ~ould ~ ~bmi~e~ al~ wh~ o ' ' Ior ~ inOefinite or appreciable length of time. On worKo~m when an official le~t is not ~Quim~ u~n C~Dletlon, m~ com~lltion ~ ~-~ 1~ ~l~k~ o.,.ti~ it SD.Ce ,, ay.ii.bi.. ~~- : p~v,ded. Th. "F,..I R~' fo~ may be u., for reDo.lng the .nfl. District ICounty or Pa.sh Alaska Field ILease or Unit Kuparuk RiVer Auth. or W.O. no. JTitle I AFE 902144 WWS #1 AR.Co. W.I. ODerator ARCO Alaska, Inc. SpuDDed or W.O. Begun Date Completion Date and depth Complete record tor each Day reDorted as of 8:00 a.m. North Slope Borough 9/13/84 O10 TD J New TD Releaseo rig Date 1800 Hrs. Classifications (oil. gas, etc.} . ADL #25658 Completion IAccounting cost center coOe State Alaska API 50-029-21131 rTotal number of wells (active or inactive) on this Icost center prior to pluggJng an0 56.24% labandonment of this well IHour I Prior status if a W.O. 9/10/84 ~ 1600 Hrs. 3-1/2" @ 8183' 8508' PBTD, RR Crude oil NU & tst tree to 3000 psi. Displ w/30 bbls diesel, followed by 290 bbls crude oil. Set pkr, tst tbg w/2700 psi. Set BPV, RR IWell no. 2D-12 @ 1800 hrs, 9/12/84. PB Depth 8620' (7/11/84) 8508' KinO of' rig 9/12/84 Rotary Oil Producin~ methocl Official reserv, cir name(s) Flowing Kuparuk Sands . Potential test data Type comDletion (single, Oual, etc.) Single Well no. Date Reservoir Producing Interval Dil or gas 3'esl time ProDuction Oil on test Gas per Day , Pump size. SPM X length Choke size T.P. C.P. Water % GOR i Gr. vity Allowable Effective date ...... cor~cteci Signature ' WELL: 2D- 12 ADDENDUM 8/26/84 - 8/27/84 Rn. CBL/JB f/8496' W-LM-6900'. Est top of cmt @ 7210'; good bond. Rn GCT gyro f/surf-8450' Drilling Superintendent ~)ate Suggested form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. Operatdr, %~ell Name and N6~r Reports and Materials to be received by: Required Date Received Remarks Ccmpletion Report Yes · Registered Survey Plat ~~ ?~/' --~ ~~ -- Inclination Survey Drill Stem Test Reports _~:cddctiOn Test Re .... ;"'-~' ' ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 20, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2G-1 2H-13 2D-10 2V-8A 2G-7 2H-14 2D-11 2B-4 2G-8 2H-15 2D-12 Thank you. Sincerely, J. B. Kewin Area Drilling Engineer JBK:ih L01 06/28/84 Enclosures RECEIVED AUG 2 7 1984 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ALASK.. ~.,~ AND GAS CONSERVATION L..~,..,VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of Well 503' FNL, at surface 5. Elevation in feet (indicate KB, DF, etc.) Pad 89, RKB 126 99510 63' FWL, Sec. 25, TllN, R9E, UM 6. Lease Designation and Serial No. ADL 25658 ALK 2584 For the Month of July ,1 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 7. Permit No. 84-94 8. APl Nu~{~r_21 131 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2D-12 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 84 Spud well @ 1300 hrs 07/01/84. Drld 12-1/4" hole to 4041'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 8475'. Ran logs. Drlg 8½" hole to 8620'TD as of 7/12/84. Ran, cmtd & tstd 7" csg. Secured well & released rig @ 1630 hrs 07/13/84. 13. Casing or liner ryn and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HF ERW BTC csg w/shoe @ 4021'. 7" 26# J-55 HF ERW BTC csg w/shoe @ 8588'. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/FDC/Ct~/GR/CAL f/8470'-7900', DIL/SFL/GR f/8470' to 4021' CAL f/8470' to 7100' 1 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. Cmtd w/450 sxs Class "G". Cmtd w/325 sxs class "G". ,,2ECEIVED AUG 2 7 19t~4 Uil ~x (JaS Cons, Commission Anchorage ~ ~/~/ ./~/~7 ~ Area Drilling Engineer~ ~ NOTE--Reporfl/on this forum requ'/ed for/e/ach calendar month, regardless of the status of operations, and must b~/file~dr'in c~uplicate with the Alaska Oil and Gas Conservation~ommission by the 15th of the succeeding month, unless otherwise directed. / Submit in duplicate ~ ~~ ENGINEERING'- KUPARUK Transmittal ************************-********** Date Run ~ -_ DISTRIBUTION NSK oPeration Blueline ~~ Dr fl!ing Blueline GeolOgy/L. J. ~ ~~/~ R&D~.-~-' /'- Blueline ~,,~ ~~S t ~t e :~n e F.G. Baker ' Blueline Geology/Ken · - "/ED Sign & return the attached copy .as Ancnoruge Return to' ARCO ALASKA, INC. ATTN ~ ATO-1115B P.0. Box 100360 Anchorage, AK 99510 1 ~ell Name: KUPARUK ENGINEERING Type of Tape Date '2t-j-13 ~ " o ~ ~-/_s 7/~/~ q Tape Number DISTRIBUTION Sig~ & ~-r.eturn~ the attached C0 ' ; ~-, .; ,.. State of AK Geoiogy/C. Smith Ala~Oi/ & Gas Cuns. gommJssion ~ Retu~t'6~ ~CO A~S~, INC. ATTN: ATO-1115B P.0. Box 100360 Anchorage, AK 99510 note: Blueline, Sepia,~ Tape, Photocopy Please OH LIS ARCO Alaska, Inc'~-~' Post Office ,...,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservati on Commi ssi on 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, vj. Gruber Associate Engineer JG/tw GRU8/L24 Enclosure .Alaska Oil & Gas Cons, Commission a, nChor~e ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany E DRIL SITE 2,-D CONDUCTORS AS-BUILT .~L~TIONS ~.,5,954o 367.!02 .C, ac. 70°17'£i .045a' X 5~9,214.1642 Long. 14.9°45'48.797- 168 FSL 550 FEL EL. 88.8' .O.G. 79.4' %~LL 6 Y--5,954,323.069 Lat. 70o17 '£0 .$112' X~ $29,254.7648 Long. i4.~ 45 '47.618" 124 ESL 510 FEL EL. g8.7' O.G. 79.2' 6~LL 7 ~5,954,279.047 Lat. 70°i7'10.i766' 529,295.2738 Long. 149°¢$'46.443" ~0 FS~ 470 FEL EL. 88.6' O.G. 79.3' ~-5,9~,234.884 LaC. 70°17 '09. 7407" ~- 529,$3~.9398 Long. I49°45'45.263" 36 FSL 429 FEL .~L. 88.5' O.G. 79.2' '. ,% WELL 9 o . .F'5,953,830.605 Lat. 70 17'05.7498" - ~ ~ 529,708.4131 Long. 149045'34.458" ..TT'O ~ 59 FE& ~L. 89.0' O.C. 83.9' i!~.' '.. ~LLWELL 1110 ~5,955,756 .478 Lat. 70°17'05.3143" X- 529,749.0452 Long. 149045'33.279~ 414 FNL 18 FEL EL. 89.0' O.G. 83.! F-5,953,742.418 Lat. 70°i/'04.8793 X- 529,789.6305 Long. !4~ 45'32.102" ~ 45g FML 22 FWL ~L. 89.0' O.G. 83.3' ~ F~5,953,698 .i$3 La=. 7~17'04 ....._ Z- 52g,~.3U77 ~ng. i4~45'30.922' ~3 ~L 63 ~L ~L ~i' Q.G. 83.3' · ~ . . 'T~ Z'C 23 .................. ___ mmlmm I I ! H~IqEg¥ CFRTIFY THAT ~ A~ PRO~RLY REGISTERED LJCEI%$£C) 99D lmMmq~9'lCE LAND SURV~Y)NG ~N THE 11[$,2D ,: · :..- 18SSIIg UNDER MY I:]~.~, SUPeRViSION a THAT ALL DETAILS ARE ~ILL SI~ Z,D NDUCTOR AS. BUILT ATIONS Date: JUImlE!), itB4 ~¢ale~ i'=400' MEMORANOUM .State of Alaska ALAS~flL .AI~D GAS CONSERVATION CO~R~ISSION 8.° ~,..~ .... F~Ls NO: D. 11.23 THRU, Lonnie C. Smith Commiss loner ~ZELEPHONE FROM: Ben LeNorman~ SUBJECT: Witness BOPE Test on Petroleum Inspector. ARCO's Kuparuk 2D-12, Sec. 25, TllN,R9E,UM, Kuparuk River Unit. F~iday,_ June 29, 1984: I departed my home at 1:50 pm for a 2:20 pm Showup-and 3:2~ p~n d~parture via Alaska Airlines, Flt. #61 for Deadhorse, arriving at 5:00 pm. Weather: +41°F, overcast, .light wind. Saturday, jUne 30, 1984: BOPE tests on Sohio's U-7 were completed, the~S-~bject of"a' sepa'rate report. Sunday, July 1, 1984: FOur SSSV's were retested for ARCO Prudhoe Ba~ Unit,"~he--subje-~t of a separate report. .Monday ,_ Juiy .2, 198_4: BOPE tests on AZRCO DS 15-17 began at 5:40 pm Tuesday, July 3, 198~: . . . and were completed at 8:00 am, the ~ub~"e'ct of a separate report· WednesdaY, Ju!~v 4,,.1984.: BOPE tests on ARCO's Kuparuk 2D-12, began at 1:00 pm and were completed at 2:15 pm. BOPE inspection report is attached. BOPE tests on ARCO's Kuparuk 2H-15 began at 11:40 pm . . . %hursday, July 5, .1.984_: . . . and were completed at 12:50 am, the Subject of a separate report. Z departed Deadhorse via Alaska Airlines, Flt. #66 at 9:50 am, arriving in Anchorage at 11:30 am and at my home at 12:00 noon. In summary, I witnessed successful BOPE test on ARCO's Kuparuk 2D-t2. Attachment 02-00IA(Rev. 10/79) O&C- #4 4/8i · ~'TE OF ALASKA ALASKA OIL & GAS OONSERVATION CCMMISSION B .O.P.E. Inspection Report .InspeCtor' Z ~ ~-~F~ ~ J Operator. /~w~ ~.~ Representative. Location: Sec ~ %-- T//JR ~ -M C;~;'/ 7~Casing Set 'Drillinq Contractor ~z'~/~~ Rig ~-/~Representative Location, General Well Sign C~neral Housekeeping__~_~__ Reserve pit Rig BOPE Stack Annular Preventer Pipe Pams Blind Rams ChOke Line Valves.__ H.C.R. Valve Kill Line Valves- Check Valve. TeSt Pressure ACCUML~ATOR SYSTEM Ful 1 Charge Pressure ~ (p ~' Pressure After Closure /~ ~ 0 Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: N2 Controls: Master ~/~ Remote psig psig Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Lower Kelly. aii Type. . Ins ide BOP Choke Manifold No. Valves Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure No. flanges .~O Adjustable Chokes ~ Hydrauically operated chcke Test Results: Failures. ~) Test Tim~'/~.~ hrs.. Repair or Replacement of failed equipment to be made within days and Inspector/ccmmission office notified. Remarks: Distribution orig. - AO&OCC cc - Operator cc - SupervisOr Inspector June 27, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaskm, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2D- i2 ARCO Alaska, Inc. Permit No. 84-94 Sur. Loc. 503' FNL, 63' F~,~, Sec.25, TIlN, R9E, Btmhole Loc. 1163' FSL, 1144' FEL, Sec. 25, TllN, R9E, UM. Dear Mr. Kewin: 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 con~ainzng 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 spa%ming 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 to commencing operations you may be contacted by the Habitat Coordinator'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 fiald work, please notify this office 24 hours prior to commencing installation of the blowout prevention Kuparuk Ri~er Unit 2D-12 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~ours, C. V. Chatterton Chairman of Alaska Oil and Gas ~nservation Commission lc Emclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Envirot~ental Conservation w/o encl. ARCO Alaska, Inc./~--. Post Office. _ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 26, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-12 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2D-12, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore 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 2, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG/tw GRU8/L13 Attachments RECEIVED J U N 2 7 i984 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '~. ALASKA O,L AND GAS CONSERVATION CO,,~MISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL E~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~[X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE E~X 2. Name of operator 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or ,ease name JU~l 503' FNL, 63' FWL, Sec.25, T11N, RgE, UM At top of proposed producing interval 1376' FSL, 1384' FEL, Sec. 25, TllN, RgE, UM At total depth 1163' FSL, 1144' FEL, Sec. 25, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 126', PAD 89' 6. Lease designation and serial no. ADL 25658 ALK 2584 Kuparuk River Unit 10. Well nurrt~l~r~ ~" tx ~a vu..o, v~ ........ 2D-12 Anchorage 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company I_Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi, NW of Deadhorse W,S,#3 well 4742' ¢ surface feet 16. Proposed depth (MD & TVD) 8500' MD, 6138' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 14. Distance to nearest property or lease line miles 503' ~ TD feet 17. Number of acres in lease feet 2560 ' 20. Anticipated pressures MAXIMUM HOLE ANGLE 49 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 07/02/84 2756 psig@ RO°F Surface 3093 psig@ ~1~6 ft. TD (TVD) I SIZE !Hole Casing i 24" I 16" 12-1/4" 9-5/8" 8-1/2" 7" Weight 62.5# 36. O# 26. O# 22. Describe proposed program: CASING AND LINER Grade Coupling/ Length H-40 Wel I J-55 BTCI 3926 H F- ERW J-55 BTC~ 8466 HF-ERW SETTING DEPTH MD TOP TVD 35' I 35' I I 80 35' 35' I 34' I I 34' MD BOTTOM TVD 11511 115' 3961~ 3146' I 8500" 6138' I 1 QUANTITY OF CEMENT (include stage data) + 200 cf 1410 sx AS III & 280 sx Class G 400 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8500' MD (6138' 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 3961' 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 2756 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#, J-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 hereb cer,~I/that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Drilling Engineer The space b~v~ ~ ~'sion 'useV - CONDITIONS OF APPROVAL DATE Samples required I-lYES ~'NO Permit number APPROVED BY Form 10401 n~.. G~03 / Mud Icg required []YES ~,NO Approval date ~. 06/27J,8~ Directional Survey required J~YES UNO IAPl number 50- ~zq' ~I1,~1 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ._Tu_ne 27, ]984. by order of the Commission Submit in triplicate ,sion PERMIT TO DRILL 2D-12 installed and tested upon completion of the job. 2D-12 will be the first we~l drilled on the pad. It is 4742' away from West Sak #3 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 7073'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 JUN 2 7 ]984 Alaska Oil & Gas Cons. Commission Anchorage I ' I TI ' ~ ~ [ I ~ ' ~ I ' i ~ [ , ' ' ' t] ' ~ , ; ' I ~ ! - ! , 1~ I, . ~; ~ ~ , t t ,, ;. I I I l . . . ~ ~ '. ~ ~ ~ ~ ~i ~ --i i I : j i i i : : , :! : ; i : ~?~'~-~ ! ~! "---**'~-' ..................... ~'4-~~ H--fi*--?''' ';-'; .............. ; i i i i I i J i ; i i i i i i , : ; ~ ; , ; : ; ': ! ~ ..... ~ I ......... T I t ...... ' ' ~ ' ' ' ~ : i ~ ~ ' I ~ ; ~ ' ' T 1 j , , '~ ~-~ ' ' ~ I i I ! ~ i : ~ : i~, . . _ ~: , : : :~- I i ~ i~ -.-~t- ' ~ i ~ ] ; ' ~ '. ~ ......... ~-'-~ : ~7~i i i ~f t~ ~ . '--f-~-~4-~m,~t ~ -~ .... ~ ~-t' ....... ~'-~ ....... , ...... [_. L_; - ? ~ ~] ;~:~ ZZ' ~. ; i ~.: ~ i ~ ..... ~;--~-_~.--~ ................................ ~ ..... ~'-~ '~'-'~- i ~ :~; ~' +*-~- . , ~: , , : . ~ , . , ' ~ ~ --~ .... ~_~ ...... ~ ............ ; ~ . , . - ~ : : . ; ~ , , , ............... ~ .... ~--~-~4~ ......... L_~ ..... ~-~ . - - ..... .__~_L ....... 4_~ ; ~-~_-~~ ......... L_~.~1~-~ ; ........... . - I ; ...... I I I I [ I i I . : I -- , I .... ~ ~ ................... ~ - .-~ .... ~ ..... ; . ~ ~ ......... ; ........ ' _ ..... g · ,, : ~ , ~ ; i i ~ i ~ ~_ , i . , . ~ ~ : , ~,, ~, , :- , ' ' ', .... , , ~ , , ~ , , ~ , , , , ............... ANNULAR 9 ' PIPE DIAGRAM dl 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/B" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/B" - 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 BLIND ~ ~ $R ILLIIIG , S ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC ~UID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 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 MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY REFRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND '~'~6J~¥~S U1)S~ OF C~-IOI<]~S. DON~T T~'ST 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 10 S. ~J~'PRESSURE DOWNST~ OF CHOKE ISOLATION VAL.V~S. 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 DF PIPE P~AMS AND CLDSE BO1-FOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOt-FOM 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 POSITION. 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 COMPLEFE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUN 2 7 19B& Alaska Oil & Gas Cons. Commission Anchora.qe Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. .16" X-20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lC" 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. ?. 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 RECEIVED JUN 2 7 19 4 Alaska Oil & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~~ ~ ~ IT EM APPROVE DATE YES NO REMARKS (2 thru 8) (8) (3) Admin ~/ ~-~-~ ~(9, thr~ 11) (10 and 11) (12 thru 20) (21 thru 24) 1. Is the permit fee attached .......................................... 2. Is ~ell to be~located in a defined pool ............................. 3. Is well located proper distance from property line .................. 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 .......................... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 2,3. 24. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... L ..... 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, tenslgn and ~urst 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 ................... g ................... ~ Are necessary diagrams of diverter and BOP equipm nt attached , Does BOPE have sufficient pressure rating - Test to ~,~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78)..' ............... 25. Additional requirements ............................................. Additional Remarks: 0 ~0 Geology: Engiqeeting: LCS WVA --- JKT~ HJH ,~ JAL --- MTM~/ j~ rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special *effort has been made to chronologically organize this category of information. ONTO A TARGET AZIMUTH Of SOUTH 48 DEG 25 NIN EAST ,N,! SLf, IPE, AbASKA .:~EPTH DEPTH O0 33 67 & 4. OO ~092 1 ~300,00 1500,0o O0 2000, O0 2200 O0 O0 O0 OO 00' DATE OF SURVEY: 26-AUG-84 KEbbY BluSHING ELEVATION: 126,00 FT . ENGINL['.., .: MURTBAND/MCBRIDE O0 FgET of ~.~LAsURED DEptH :~,:. ,, ~:T:Y :~ UT ST/W ES D I S T, A Z I M UT H O0 FEET FEET ' FEET DEG g o s o o 0 04 0 0 2;,75 :~': :06"S 20 E 85 8 45 58 E t 2,~al , ll,'Ob S 1 .45 g i 92 $ 45 58 E 3.22 21;96 S 21"96 E 31 06 S 45 0 E 56;: 3;57 80;64 S 78'93 E 112'84 $ 44 ~3 E' 67 4.26 107, 17 S 107,67 E 151,92 S 45 8 E 3~17 171,87 5 176,70 E 246~50 $ 45 -- E 1.92 250 18 S 261,30 E 361.75 S 46 ~ E ?6:8 2~I0 291 ~0 ~ :307,59 E 423'9! S 46 E .41 1.~7 335 Ob $ 355.65 g 488'63 S 46 ,2 E ,, 53 5 2400 2;500 2~ ~ 2900 1 2 39 0 47 0,50 0,55 0,,i6 ().~8 g :' 4~6 0,34 0,b9 0,35 0.43 0,25' 1,22 0,33 0,54 0;52 0.36 30 $ 405,25 g 555 75 S 46 49 E 5 S 731.28 E 1005, 46 3 E 58 $ '842 E 1161,86 $ 46 0 E 28 S ':'.:898,60 E t239,87 $ 46 26 E 909 ,'06 964~08 ~ [009 1074,30 1184,96 134~,'22 $ 1'396 1403.87 S 1442 ',g4:' E' 1]1'/.'72 B 46 22 E 07 g 1395,59 $ 46 18 E f?'3 Z 1473 $ 46 13 ~ E ~7 E 1550 ~gE 1628 23 E 1705 96'E 1936 6O E 20t2 3 7 $ 46 42 $ 46 4 E 94 5 46 0 E 78 $ 45 56 E 64 $ 45 53 E 38 $ 45 49 E 94 S 45 46 E PAGE 2 DATE OF SURVEY: 26-AUG-84 KELLY BUSHING ~LEVATION: 126,00 FT ENGINEER: ~URTLAND/~CBRIDE TRUE SUB-SEA DEPIH DEPTH. ~OURSE 745; 0 , 0 0 :;'$i"0~:00.0'o 3799:3 5100, O0 {t :oo ~700,00 ~2 ;:"$'"mB~:O 0" 0 0 ' 6200~00 ' 6]00. 6400,00 4796 oo,o.o 660O. O0 ~' '~'.;00 :' ,.,,,., . .... ,:.' ,,' T ', ~,,, 00 FEET ()F MEASURED DEPTH DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SEVERITY NORTH/SOUTH:EAST/WEST DIST. AZIMUTH FEET FEET FEET DEG DEG/1 t)0 0.~2 o ~.~] S,.,::~549 8:, ~40 s ~6o2 ~8 E I: 64 ' 0 34 1827 84 S 1865,67 E 2611 0,43 1B7..o 48 S 1917,56 E 2685 0.66 1930 85 S 1969.20 E 2757 0.29 36 0.0,l :'::6:8, 0 ' '~ 2 6? 65 1496,16 E 2089 22 8 45 44 E 94 $~ 42 E 49 40 E Ill"! 20 85 $ 45 35 05 $ 45 34 E 88 S 45 33 E 2032.85 S 20'7j,07 g 2902,03 S 4532 E 2083;03 8 2121.89 E 2973,45 E 45 3~ E 0.3'7 2132,27 S 2173 12 ~. 3044'50 S 45 32 E 0;29 2180.9682224:34~ 3115 178 45 3'3 E 49 2278~ ' ~ o~ o~ ,: : , 9,34 2469'92 S 2526.36 E 3533 13 S 45 38 E 2,~,0 256'5~43 S 2625.74 g 3670 96 S 45~- E 3-t9 E 3740 20 S 45 44 E 2;77 2654,42 S 2736.28 E 3812 24 S 45 52 E 1.52 2741 . .90 E 3963:98 S 46 14 E 0.31 2827 02 S2997,36 E 4120,22 S 46 40 E 0,62 2869 48 S 30"64:e~O'E 4198.23 $ 46 52 E 0 84 '2911,84 0,2~ 2953,85 S3197~2 g 4353,38 S 47 16 E 1,05 3036 1 5 E 4507 25 S 47 ~5 3117. g 4658 89 S 47 59 t, '.'25~19'5 E 4733 58 8 4B ' E I,~2 3158,24 1.o2 3198.00 S 89,39 E 4807 38 S 48 E 1,39 3237,50 S ')65'~.'~7'3 E 4880 22 3 48 E 1.07 3276.79 S 3712.79 E 4951 98 S 48 34 E PAGE 3 TRUE DEPTH DEPTH ~'':'i ~ '.. :,',, .':/' ~i,,: O0 oo i,'~ : DATE OF SURVEY: 26-AUG-84 KELt, Y BUSHING EbEVATION: 126,00 FT ENGINEER: MURTLAND/MCBRIDE '~:~:::.F~ ET ' 0'~ i' ~,~$U,~'~D' ~'E PTH i~'";:: R~C~'ANGU~AR COORDX"ATES": .,:,,., r::', ...... '. . ''.,:, ' .',H.ORxz.:.'. ' DEpARTuR~ EG/tO0 FEET FEET DEB NXN ,, 0,~0 339 42 $ 3881~98 E 5160~02 $ 48 47 E ~ 1,51 348 2'5 $ '3984,03 E 5292~02 S 48 50 ~ r 0,00 356 88 ~ 40~2,83 E 5420,14 $ 48 52 0,00 ' 35'73 04 $' 4092;71E 5432,94 $ 48 52 E ,ASKA TR[ SUB'SEA., D,I 438 3 6 PAGE 4 DATE OF SURVEY,I 26-AUG-B4 · KELbY BUSHING EGEVATION: 126,00 FT . " ENGINEER: MURTLAND/MCORIDE 1000 FEET OF MEASURED DEPT :AL DOGbEG RECTANGULAR COORDINATES HORIz, AZZM~ TH ER I'TY' NORTH~SOUTH' 'EAS~/WE. ST DIST /100 FEET ' FEET FEET DEG IN 0 .3: 55 E. ,'52~'36 1 25 E 555~75 S 46 49 E 0 84 2911;84 S 3131 39 E 4276 03 $ 47 4 E 2 S5 3316.68 S 3772.18 E 5022 92 S 48 40 E g 0,00 3573.04 S 4092;71 E 5432 94 2D-22 "K U P :A Rr"U'K '"' ?' ''[ N, SL, OPE',:, ALASKA TRUE DEPTH DEPTH SUB-;;EA DE )TH DEG M 52~I :(~0 526 O0 :?:Fr ~:~ 3' ::6'26:, ~ ~S 726 O0 1242~76 1 :1'353;03 ~1326: 1466,7~ 1426 ':"'1585;8~ 152:6:' ~,1710~4~ 1626 1 1972,23 182 ::2256:4! 2 2412,41 2.120 2573,87 2734 26 23 2526 .as29:4s 3841 '~996 4149 4452 4747 75 79 7081 ...,. O~ 55 )0 0 8 E PAGE 5 DATE OF SURVEY~ 26-AUG-B4 KELL, Y BUSHING ELEVATION: 126.00 FT ENGINEER: MURTLAND/NCBRIDE ~0 FEET (3F SUB-SEA DEPTH CAI, DOGLE<; RECTANGULAR COORDINATES HORIZ. DEPARTURE ',EVERITY NOR?./SOU'TH EAST/WEST 'DIST. 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F; I-.: T FEET EAST/WEST DI~T. 0.04 ,S 0.02 E 0 u..ll &; o.05 w 0 (i.17 $ 0,37 W 0 0.i'! .5 0.67 W 0 0.10 S 0,87 W 0 0.i, 2 $ 0.11 £ 0 4.06 $ 4.20 E 5 11,0o S 11.45 E 15 21,,90 ,5 21,96 E 31 DEPARTURE AZIMUTH DEC ~IN 37.50 S 36.55 g 52.36 ~7..t0 $ 55.30 E 79,64 ~o,64 $ 78,93 g 112'84 1o7,';7 5 ]o7,67 E 151,92 1. ~7,44 $ 1~0,81 E 196,77 !71,87 5 1"16.'?0 E 246,50 210.11S 216.96 E 25U,18 5 261,30 E 361,75 291,70 5 307,59 g 42~.91 335.;~o $ 35b,6b E 488 1,~;t, 42'7.50 S 456;16 E z.';9 476.62 S 508...49 E 2, ~9 b27~90 5 bb2,53 E u,~7 5a1.14 $ 618.~9 E o,. 60, 6~5.48 5 6't4,98 E U,'~5 ~',90.i,b, S 731.28 E O,t6 '1.44~B4 5 787,11 E ~.:~t~ '799,b8 5 842,97 E t),'!P t~54.2~ 5 89B.60 E !409.00 $ 953,(~74 964.08 ~ 1009, 1131.9,, 11 ,5 1063 73 1074.30 5 111.8~37 1129,64 S 1.172,89 1184.96 5 1227,23 1239 67 5 12~1~21 1..t49,22 8 1388,96 1,sO3.e;7 5 1442,60 55575 625 17 69694 77144 848 60 1005 1083 56 1161 86 1239 87 E: 1317 E 1395 E 147] E 1550 E 1628 E 1705 E 178~ F: 185 E 1936 E 20i2 0, ,.~ 4 O. . ~ 1, 0.33 0,54 0'52 0; 36 ~ 4) 845 8lc $ 4541 £ $ 4547 £ S 46 14£ 72 $ 46 22 ,~ 59 S 46 18 E 77 $ 469 E 94 S E 78 S 45 56 E 64 54545 !~g] 38 5 45 g 94 $ E Iii '". ,q!.f k-'t , !~:t,~ I'l tH P ,,} T .'l'l t) h'!'E: 2.t-St.'P-'~4 PA(if: -' I ~ Old'ri-.: oF SURVEY: 2b-AUG-84 KUL. I,'f t~I~SH[NG Eb£VATI(]N: 126,00 FT i-]aqI ~KF~: aUE'I'LAND/NCBEIDE · 75 22 ~rcTz,.~.lGbi,.a.;~ Ct)i~RDINA'I'ES IIORIZ~ i.i ~.~ ii T tl/SCI !J T .H f I.: Hq' [.' F; I-.: T FEET EAST/WEST DI~T. 0.04 ,S 0.02 E 0 u..ll &; o.05 w 0 (i.17 $ 0,37 W 0 0.i'! .5 0.67 W 0 0.10 S 0,87 W 0 0.i, 2 $ 0.11 £ 0 4.06 $ 4.20 E 5 11,0o S 11.45 E 15 21,,90 ,5 21,96 E 31 DEPARTURE AZIMUTH DEC ~IN 37.50 S 36.55 g 52.36 ~7..t0 $ 55.30 E 79,64 ~o,64 $ 78,93 g 112'84 1o7,';7 5 ]o7,67 E 151,92 1. ~7,44 $ 1~0,81 E 196,77 !71,87 5 1"16.'?0 E 246,50 210.11S 216.96 E 25U,18 5 261,30 E 361,75 291,70 5 307,59 g 42~.91 335.;~o $ 35b,6b E 488 1,~;t, 42'7.50 S 456;16 E z.';9 476.62 S 508...49 E 2, ~9 b27~90 5 bb2,53 E u,~7 5a1.14 $ 618.~9 E o,. 60, 6~5.48 5 6't4,98 E U,'~5 ~',90.i,b, S 731.28 E O,t6 '1.44~B4 5 787,11 E ~.:~t~ '799,b8 5 842,97 E t),'!P t~54.2~ 5 89B.60 E !409.00 $ 953,(~74 964.08 ~ 1009, 1131.9,, 11 ,5 1063 73 1074.30 5 111.8~37 1129,64 S 1.172,89 1184.96 5 1227,23 1239 67 5 12~1~21 1..t49,22 8 1388,96 1,sO3.e;7 5 1442,60 55575 625 17 69694 77144 848 60 1005 1083 56 1161 86 1239 87 E: 1317 E 1395 E 147] E 1550 E 1628 E 1705 E 178~ F: 185 E 1936 E 20i2 0, ,.~ 4 O. . ~ 1, 0.33 0,54 0'52 0; 36 ~ 4) 845 8lc $ 4541 £ $ 4547 £ S 46 14£ 72 $ 46 22 ,~ 59 S 46 18 E 77 $ 469 E 94 S E 78 S 45 56 E 64 54545 !~g] 38 5 45 g 94 $ E Iii ^ R t.'. [.~ Al.. 21),.,, 1 2 DATE ~JF' ,SU~VEY~ 26-AUG..84 KI?]I~I,:f ~(I,.SHING Eh~VATION~ 126,00 ~T ~.:r,~G I r~ ~ ~: ~: ~,URTI,AND/MCBRI DE F, r' i': T ' '., :.~ '; 7 .. ~"~ ,2 o ',5 '.;092. h, 226.64 i .'7, 6 ~':~ 2 {) 1 . ~4 ¢, 1 , :.'~ .1 5365.95 0. 5432 ,'7'/ 3357. 3 399. 34~1, · ~'-* 33. 3524, 3573' GL, I,A[,~ S 0 (J T H 74 S 25 5 IlS 04 S ARCG ?i;-l? I.;I, PAGE" 4 DA'rE Ul; SURVEY: 26-AUG..84 KEbI.,Y t.:ObH.{NG EUEVATION= 126.00 IrT ~'3 il'I, 50 5 52,22 3, . ] 31b.¢t° d, 34 9~)q,Ob S 2876.6! 0,79 I q~'2, O0 S ~274,87 0,~4 291 t,~4 s 3131;39 5~3~,';7 C).Ot) 3573.0:~ 8 ~U92'71 CO;,Ar).INA'rE$ HORZZ, DEPARTURE KAST/WEST DIST~' AZIMUTH F'EFT FEET DEG .oo o , 5 2., 405,25 E 555, 953.94 E 1317.,~L~::~ ~96,1~ E 2089~' 8 '45 . 2o20,27 E 2830~: 2520,36 g 3533,13 8"~5 38 E ~32: s 52 ARCG ?i;-l? I.;I, PAGE" 4 DA'rE Ul; SURVEY: 26-AUG..84 KEbI.,Y t.:ObH.{NG EUEVATION= 126.00 IrT ~'3 il'I, 50 5 52,22 3, . ] 31b.¢t° d, 34 9~)q,Ob S 2876.6! 0,79 I q~'2, O0 S ~274,87 0,~4 291 t,~4 s 3131;39 5~3~,';7 C).Ot) 3573.0:~ 8 ~U92'71 CO;,Ar).INA'rE$ HORZZ, DEPARTURE KAST/WEST DIST~' AZIMUTH F'EFT FEET DEG .oo o , 5 2., 405,25 E 555, 953.94 E 1317.,~L~::~ ~96,1~ E 2089~' 8 '45 . 2o20,27 E 2830~: 2520,36 g 3533,13 8"~5 38 E ~32: s 52 AR~.Ti) AL.A.SKA, I"JC. 2t:- ! '2 K I]P A.q!~ ~ x;, ,'~I P.,.)r , ER'ri FA L, !.', ~;' i. '['~ ~ 5323.6 .i 54~4 67 412L.'~' 5605.' 3 '~, 4. 22 ~. 00 5745,5~' 4376. F.., 602! .3~ 6159,~t 4626,U. 0 6445,03 6603,4~ 4926,00 6933.42 70q6.0'., 522 7257.03 5326.00 7415,34 7570.15 552b'O0 7721 , 13 7867,9/ ,. 1' i.) A 'T }:2: 2 .% '" S t.' P - t~ ,4 VE. PI']CAL DEVIA'I'IC~ A'ZI!',!t:Th [ :.'(':I.'H D~.i(.; M~ ; ,. C:.: "ir' 3 (.)..5.7, 3255,75 t~, 52 3 ~49,27 9, %8 3638, 3"134.7~, 3.5i7 3842, I 5 125 . 9 'I 5216.42 5385.9? '3 4 3 2 . '1 '7 PAGE , 6 t)At'f-: ti[:' ~3I~RVE:Y: 26-AUG-84 gl:.:bl..f bL).%IttNG EiI, EVATION: 126,00 ~,;,'~c]l,~,~Lkt:: MURTLAND/MCBRIDE ~... ¢"' Af'~(;IJl ,iR C('JF)R ~,1 t.~ ~ 't' H/S 0 t J':' Ft EAST I, ?...: g T F'EE D:I N A'.f ES ~ORIZ, /~EST DIST, '.t' 1" F', E T >.:u13.'/9:5 21!2.41 E 2960 71'4.!t.t~4:3 2185.26 E 3061 '22.~2,-~8 6 7257,21 E ~160 2281.!3 8 2328,57 E 3259 Y3%i~,79 & 239q.64 E 3]57 24'[4,91 S 2q68,58 g 3453 2,iH~),.l(~ :L, 2536.94 g 3547 ~54~.07 S 2605,20 E 26*~w,3g :~ 2(>77.70 E 3738 20'1,i.~9 ~ 2763.26 [ 3845 22 E 3966,70 39 g 4095.87 90 E 4224 26 29 E 4350; 32 :;.4 ~2 4474 35 68 E 4595 04 85 E: 471134 68 P; 4822 85 32 It: 4929 04 75 g 5030 87 40 't 4 21 55 71 5126.01 5216 54 5302 67 5386 08 5432 94 DEPARTURE A~IlqUTH DEG MIN Il: It :' ::1:?II Il" l'll" 44 72 84~ 55 SS 464 8 4~ 847 8 47 8 S S 4~ 46 ~ 4~ S 4~ 50 I:~ A .S [<U ? P E t';~ ;5 A.',: ~-/i'~ T i) 4 b C 8 . ,);: i)I~TK ~)~' SURVEY'- 26','AUG-84 " .'<~:l,l,~ hJ.;[;i{lf,:G k',bEVATIONI 126,00 F{ }.:N(;.ti,,EPt~ i MIJR'I'J.,A/';D/MCBRIDi;~ 582[].27 5999,56 6156,?! .ON ~! q3.,;,'> ~ '1 Ii 8. <)':: 8o20. OC ~ Y.?t' aL` 59~'9 ' b~, ~ 0 7 9,2 (~ VER't'ICAb t ~ 1~ F' T ti F,.1