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184-127
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 2BͲ01 50Ͳ029Ͳ21147Ͳ00 184115_2BͲ01_PPROF_18Feb2023 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 2DͲ07 50Ͳ029Ͳ21169Ͳ00 184143_2DͲ07_IPROF_10Jun2023 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 2DͲ15 50Ͳ029Ͳ21184Ͳ00 184160_2DͲ15_PPROF_04Jun2023 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 2FͲ13 50Ͳ029Ͳ21032Ͳ00 183156_2FͲ13_WFL_29Jun2023 2HͲ02 50Ͳ103Ͳ20032Ͳ00 184073_2HͲ02_IPROFͲWFL_13Jun2023 6 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38362 T38363 T38364 T38365 T38366 T38367 T38368 T38369 T38370 T38371 T38733 216-087 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:48:05 -08'00' WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϰϭϮϳϬ Ͳ^Ğƚ͗ϯϲϭϳϯJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 v2-1 • ! 2Co 5 3o WELL LOG TRANSMITTAL#902850948 To: Alaska Oil and Gas Conservation Comm. December 3, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED v v3al2o1 wi.K.BENDER RE: Production Profile: 2D-08 Run Date: 10/23/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2D-08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21158-00 Production Profile Log 1 Color Log 50-029-21158-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ifr2A.124 `eftes WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 2D-08 Run Date: 3/20/2010 April 9, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2D-08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-21158-00 Production Profile Log 50-029-21158-00 Production Array Log (RAT) 50-029-21158-00 1 CD Rom 1 Color Log 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 I ~,~ ~ ! a ~- Office: 907-273-3527 Fax: 907-273-3535 rafael.barr 1 ~~,°R i ~ Z~1r Date: ,: e ~~543 Signed: ConocoPhillips aa~ka P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 a~-off Dear Mr. Guy Schwartz: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). 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 November 10th, 20t1i and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 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. ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 01/01/10 Pad 2A. 2C_ 2D & 3K Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" n/a 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2D-05 50029211570000 1841260 SF Na 24" Na 4.45 12/30/2009 2D-08 50029211580000 1841270 SF Na 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12!30/2009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 06/08/07 Schlumberger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 ".00'1 -, II -, SCANNED JUN 142007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 V ~J Field: Kuparuk I~ÁI-I{)~ Well Color CD Job# Log Description Date BL 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1 C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V-08A 11629013 PM IT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1 H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y-11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 10-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 1"""'\ !"""'\. (6) l"l" 'r"l fh'\ t::'I'--rJ re ',\, Ib, ,'¡ cQJ UlfÙU U: [TfJ' ~c ~i~\ r jF\ (~~\') rvl It"\\ u ¡g\ l1Lru n\'1 U~Lr\~ - LJ U ~ I i ! ¡ / ,I I I I / FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATI ON COMMISSION May 12,2004 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279.1433 FAX (907) 276.7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 t<ttr-léÁ 7 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, JW ;{¿¡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_2D Inspection Dt 5/6/2004 Inspected by Chuck Scheve Interval: InspectNo: svsCS040507072635 Src: Inspector Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Reason 90-Day Well Number Permit Number Sepal 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 Yes/No Yes/No I 20-13 I 1840120 98 70 60 P P I-OIL -- -- 2D-12 1840940 98 70 65 P P I-OIL I 2D-09 1841030 98 70 65 P P I-OIL 20-08 1841270 98 70 65 P P I-OIL 20-068 1981760 98 70 65 P P I-OIL 2D-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 2D-OI I 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 We1l2D-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 Conservation Commission Safety Valve SYstem Test Report Operator: Prillips Operator Rep: Earnie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2D Pad Separator psi: 'LPS .9_9 HPS 1/28/01 Well Permit Separ Set L/P Test Test Test Date ' Oil, WAG, GI~J, Number Number PSI PSI Trip C,o, de ,C, ode Code ,, P,assed, GAS,or ,CYCLE 2D-01 1841710 '991 70 65 P P OIL 2D-02 1841520 2D-03 1841530 2D-05 1841260 3750! 2000~ 1750 P 7 ' " WAG 2D-06B 1981760' 99 " 70 .... 55 P 'P ' 'oIL 2D-07 ' 1841430 3750 '"2000 i'850 .' ~P 'P .... WAG 2D-08 1841270 99 '70 ' ' 60 'P P ........... 2D-09 18zi1030 9'9' "70 55 P ';"P ....... OIL 2D-10 1841010 ........... 2D-11 1840990 2D-12 1~40940 99 70' 60 ' P 'P ...... OIL 2D-13 1840120 99 70 . 60 P P OIL 2D-14 1841590 ......... 2D-15 184'1600 "' 99 "70' '60 'P "P ' ' ' - ' OIL 2D-16 1841610: Wells: 9 Components: , ,18 Failures: 1 Failure Rate: 5.56% [390 Day Remarks: S, .urface, ,safety on 2D-05 not tested due a slow leaking wing valve Grove valve could be closed due to snow drifts. DE G 200t RJF 1/16/01 Page 1 ofl SVS KRU 2D Pad 1-28-01 CS.xls MEMORANDUM TO: THRU: FROM: Julie Heusser, ~'~\~" Commissioner Tom Maunder, P. I. Supervisor Chuck Scheve; State of Alaska Alaska Oil and Gas Conservation Commission DATE: SUBJECT: Petroleum InspeCtor January 28, 2001 Safety Valve Tests Kuparuk River Unit 2D & 2E Pads Sunday, january 28, 2001' I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2D & 2E Pads. As the attached AoGcc Safety Valve System TeSt Report indicates I witnessed the testing of 9 wellS and 18 ComponentS with one failure on 2D Pad and 5 wells and 10 components with one failure on 2E Pad. The SUrface Safety Valve on Well 2E-16 · had a slow leak when pressure tested. This valve will be serviced and retested by the operator. The Surface Safety Valve on well 2D-05, a WAG injector, could not be tested due to a leaking wing valve. This valve will be tested as soon as the wing valve is repaired. ' Earnie Barndt conducted the testing today he demonstrated good test procedure and was a Pleasure t© work with All the wellhouses entered at these locations were clean and all related equipment appeared t° be in good conditiOn. · .Sum. mary: I WitneSsed the semi annual SVS testing at 2D & 2E Pads in the Kuparuk River Field. KRU 2D Pad, 9. wells, 18 comPonents' 1 failure 5.56% failure rate KRU 2E Pad, 5 wellS, 10 components, 1 failure 10% failure rate 24 wellhouse inspections · Attachment: SVS KRU 2D & 2E Pads 1-28-01 CS · X UnclasSified , Confidential (Unclassified if doc. Removed) SVS KRU 2D & 2E Pads 1-28-01 CS doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Prillips ,,, Operator Rep: Eamie Bamdt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: K, uparuk / KRU / 2D Pad Separator psi: 'LPS 99 HPS 1/28/01 .. . i . _ i i . i i i i .... '-: .............. i':-i~ ....... i ....... ~ .... "1",', ...... :~' : - -m'--['-'-~1'-'7''='~'-~- --'' - x % :~¥; '~:~=%-"~;~'(', , , , Well Permit Separ Set IdP Test Test Test Date Oil, WAG, Gll~IJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYC~t 2D-01 1841710 .....-99 ' 70 65 i3 P ' ~ ' OIL 2D-02 1841520 12D-03 1841530 ' ' 2D-05 1841260 3750 . 2000 1750 P 7 WAG ,, 2D-06B 1981760 99 70 55 P P , OIL 2D-,07 1841430 3750 2000 ,1'850 . P P ' 'WAG 2D-08 ,~-~1841270 - 99 70 60 P P ' ' OIL , , 2D-09 1841030 99 70 55 P P OIL , , , 2D-10 1841010 , , i . 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% r-190 Day Remarks: Surf, a~ ,safety on 2D-05 not tested due a slow leaki~, wing valve Grove valve could be closed due to snow &ffis. RJF 1/16/01 Page 1 of 1 SVS KRU 2D Pad 1-28-01 CS.xls Operator: Phillips Operator Rep: Eamie Brandt AOGCC'Rep: Chuck Scheve Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Submitted By: Chuck Scheve Date: Field/Unit/Pad: K, upamk / KRU / 2E 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 PS, I, Trip -. Code , Code Code Passed GAS 9r CYCLE 2E-07 1931040 . , 2E-08 1931890 99 70 60: "p p . 2E-09 1842400 2E-10 1842300 99 70! 60 P P , 2E-1 ! - 1842260 99 70: 50 -- P P ~ , 2E-15 1841890 : 99 70 50 e P 2E-16 184~900 99 ' . 70 "50 P. 4 ' ' , , Wells: 5 Components: 10 Failures: 1, Failure Rate: 10.00°/13 90 my Remarks: Surface saf,eW on 2E-16 had Slow' leak when pressure tested. Valve will be serviced a retested by operator, RJF 1/16/01 SVS KRU 2E Pad 1-28-01 CS.xls page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 19, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action 2D-08 Variance Anticipated Stad Date 2/94 - 9/94 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED k ;'.:. :; ,.. ,; ...,,1 & Oas Cons. Commission Anchorafl~: AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well -- casing __ Repair well _ Plugging_ Time extension _ Stimulate__ Alter Change approved program __ Pull tubing __ Variance ._.X_ Perforate __ Other 2. Name of Operator 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 36' FSL, 429' FEL, SEC.23, T11N, R9E, UM At top of productive interval 1318' FSL, 1358' FEL, SEC.24, T11N, R9E, UM At effective depth 1354' FSL, 1164' FEL, SEC.24, TllN, R9E, UM At total depth 1364' FSL, 1112' FEL, SEC.24, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth' measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 5. Type of Well: Development Exploratory _ 6200' SS feet Stratigraphic _ 7. Unit or Property name Service __ Kuparuk River Unit 8. Well number 2D-08_ 9. Permit number 10. APl number 50-029-2115800 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 8220' feet Plugs (measured) 6743' feet 8127' feet Junk (measured) 6 2 64' feet Length Size Cemented Measured depth True vertical depth 1 10' 1 6" 224 SX CS II 1 10' 1 10' 3753' 9 518" 1790 SX 3753' 3158' 8210' 7" 350 SX G & 41 BBLS AS I measured 7770'- 7798', 7906'-7922', 7938'-7976' true vertical 5968' - 5990', 6080'-6092', 6105'-6137' Tubing (size, grade, and measured depth) 3 1/2", 9.3 LB/FT, J-55 7853' Packers and SSSV (type and measured depth) BAKER FHL 7618', BAKER FVL 1970', BAKER FB-1 7833' 8210' 6334' R ECEIVEP d.('~'! I .... J-r ·: -..',.,~. ',..,~i &/:ia:~ Cur~s. Commission A ] .. ,9 ,3.u . 13. Attachments Description summary of proposal ~ Install sub-surface, sprin~ controlled safety valve in production 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved Detailed operation program well· 15. Status of well classification as: Oil X Gas Service BOP sketch Suspended__ 17. I here~v~certify tha~ the foregoing is true and correct to the best of my knowledge. Si~lned ~/~'J~,~ Title Senior Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test _ Subsequent form require 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 IApproval No. Original Signed By ~, ~. ,;,q ill Approved Copy Returned Commissioner Date ('~ 7-.--5-/"~ ~ SUI~MIT I1~ YRIPLICATE Attachment 1 Request for Variance Kuparuk Well 2D-08 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval for a variance to install a subsurface, ambient-type safety valve in Well 2D-08. This valve replaces the original subsurface safety valve because the surface control line has failed. The replacement valve operates by remaining open until flowing well pressure falls below a predetermined limit. Should such an event occur, the valve automatically closes, thus preventing uncontrolled flow. This valve, refered to as a storm choke, does not require a hydraulic control line from the surface to the subsurface valve. Its fail-safe design as normally-closed provides the same level of protection. Attached is a schematic of the "K" valve, an Otis Engineering storm choke. Attachment 2 Storm Choke Schematic OPEN · WELL PRESSURE CLOSED TC~o SUB HOUSING VALVE HEAD O RING TEFLON RING VALVE PISTON · INTERNAL CHAMBER PRESSURE ~A~R ~00Y GA..~rr Figure 1 - Otis "lC Valve RECEIVED ARCO Alaska, Inc. Post Office BOx ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~¢~.-- r~-/ 2D-08 Stimulate 3A-10 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,~- ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 36' FSL, 429' FEL, SEC.23, T11N, R9E, UM At top of productive interval 1318'At effectiveESL' 1358'depth FEE, SEC.24, T11N, R9E, LI~/~,~///~4~:M~ 1354' FSL, 1164' FEL, SEC.24, T11N, R9E, At total depth 1364' FSL, 1112' FEL, SEC.24, T11N, R9E, 12. Present well condition summary Total Depth: measured 8220' feet true vertical 6743' feet Plugs (measured) Effective depth: measured 8127' feet Junk (measured) true vertical 6264' feet Casing Length Size Cemented Structural 110' 1 6" 224 SX CS II Conductor 3753' 9 5/8" 1790 SX Surface Intermediate Production 821 O' 7" 350 SX G & Liner 41 BBLS AS I Perforation depth: measured 7770' - 7798', 7906'-7922', 7938'-7976' Plugging Perforate _ Other 6. Datum elevation (DF or KB) 62OO' SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-08 9. Permit number 10. APl number 50.029-2115800 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 110' 110' 3753' 31 58' 8210' 6334' true vertical 5968' - 5990', 6080'-6092', 6105'-6137' Tubing (size, grade, and measured depth) 3 1/2", 9.3 LB/FT, J-55 7853' Packers and SSSV (type and measured depth) BAKER FHL 7618', BAKER FVL 1970', BAKER FB-1 7833' 13. Stimulation or cement squeeze summary Fracture stimulation Intervals treated (measured) Kuparuk A Sands Treatment description including volumes used and final pressure 1576 bbl seawater/90 bbl diesel/228,000 lbs proppant/FTP=5163 psi~l 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure Tubing Prior to well operation 241 123 1 3 520 157 Subsequent to operation 898 71 6 47 1 520 155 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 7. I hereby ,ee~rtify that the foregoing is true and correct to the best of my knowledge. i ll O ,, /_L.- Si~lned k/~'~ 6'' /~~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date /'/7~? SUBMIT IN DUPLICATE RECEIVED JAN 1 9 1994 Ai~.ska 0il & Gas Cons. Commission Anchoraee ARCO Alaska, Inc. ~ Subsidiary of Atlantic Richfield Company 2D-08 DATE 10/25/93 DAy 1 ~r. scmerxos o~ WOaK CONTRACTO~ / KEY'PERSON DOWELL-YOAKUM PB~D' i'RKB) iLAST TAG'iRI~')'- D'ATE 8127' LOG ENTRY KUPARUK RIVER UNIT WE~ SERVICE REPORT AFC/CC# . scA# 9982O9-8O729 I [SSSV TYPE/STATUS [BAKER FVL L.O., K-VALVE OOH. 1200 1340 1403 MIRU FRAC EQUIPMENT, QC GEL, HOLD SAFETY MEETING. PRIME ~ P/Y EQUIP .MENT TO 8670 PSI. PUMPED STAGES AS FOLLOWS: STAGE FLUID WHTP 7" AN. SLK-WTR 6730-6175 3340 DXL-GW 5800-5700 3460 BD PI #1 PI PI 83 BD FL NXL-GW 5685-5250 3534 DATA DXL-GW 5053-5500 3520 DF FL NXL-GW 5220-4950 3511 XF: 1100 MTR: 97% FE: 36% COMMENTS: STAGE FLUID WHTP 7" AN. PAD DXL-GW 4900-5230 2 PPA DXL-GW 5150-5100 3465 4 PPA DXL-GW 5000-4970 3480 6 PPA DXL-GW 5100-5040 3470 8 PPA DXL-GW~- 5100-4725 3480 .. 10 PPA DXL~-:~' 4725-4680 3420 12 PPA DXL-GW 4747-4950 3500 13 PPA DXL.-GW- 4890-4907 3500 16 PPA - - - FLUSH DXL-GW 4550 '' 3500 FLUSH NXL-Gw 5127 3500' FLUSH SLK DIESEL 5120 3500 CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK We~the. r Report ISIP-FG CLOSURE/CO~ 2595 /.87 4980 / 36 % FL. EFF. 2467 /.85 ISIP-FG 4970 / 36 % FL. EFF. REDUCE SLURRY 35% COMME~: Anchorage II i~ [ Ii i Temp. [cm. [w,.,,v.,. [S .d .m=! mobI _ JIM MOORE INCOMPLETE .J ~RItTI 5120[~SIP: 2500[FG: LOAD TO RECOVER: TOTAL PROPPANT PUMPED: EFFE~ PROPPANT: PROPPANT LEFT IN CASING: 1772 bbls 227,566 # of 16/20 lwp 226,466g 1100~ 1800 * CUT 35 % OVERALL SLURRY FROM SCHEDULE DUE TO FLUID EFF., HOWEVER TREATING PRESSURES ALLOWED ADDING IT BACK ON - TO 12 PPA STAGE * FINAL +- 15 BBLS OF STAGE INCREASED TO 13 PPA II * SLURRY UNDERFLUSHED BY 2 BBLS. SUCGRED WELL, BLED 7" ANN. TO 550 PSI. SUMMARY: REFRACTURED KUPARUK "A" SAND WITH YF-140D GEL SEAWATER AND 226,466 # OF 16/20 LWP PROPPANT. SECURED WELL FOR GEL BREAK AND SLICKL~ TAG. RECEIVED ,JAN 't 9 1994 /,..i~,..~J.',a OJJ & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION CO, .... dSSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program_ Pull tubing _ Variance _ Perforate X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ARCO Alaska. Inc. Exploratory _ §200' SS feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 36' FSL, 429' FEL, Sec. 23, T11N, R9E, UM 2D-~ At top of productive interval 9. Permit number 1318' FNL, 1358' FEL, Sec. 254 T11N, R9E, UM 84-127/9-547 At effective depth 10. APl number 1354' FNL, 1164' FEL, Sec.24, T11N, R9E, UM 5o-029-21 At total depth 11. Field/Pool Kuparuk River Field 1364' FSL, 1112' FEL, Sec. 24, T11N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8220, feet Plugs (measured) true vertical 6743' feet _. Effective depth: measured 81 27' feet Junk (measured) true vertical 6 2 6 4' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 0' 1 6" 224 Sx CS II 1 1 0' 1 1 0' Surface 3753' 9 5/8" 1790 Sx 3753' 3158' Intermediate Production 821 0' 7" 350 Sx G & 8 21 0' 6 3 3 4' Liner 41 bbls AS I Perforation depth: measured 7770'-7798', 7906'-7922', 7938'-7976' true vertical 5968'-5990', 6080'-6092', 6105'-6137' ,- Tubing (size, grade, and measured depth ~,., ~] ~ ~ ,:.:" 3 1/2", 9.3 Ib/ft, J-55, 7853' Packers and SSSV (type and measured depth) Baker FHL 7618', Baker FVL 1970', Baker FB-1 7833' 13. Stimulation or cement squeeze summary Intervals treated (measured) ..~rlcfiotag,~ Perforated the A5 Sand from 7906'-7922'@ 60° phasing. Treatment description including volumes used and final pressure 14. Representative Daily Averaoe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 0 3 0 7 4 0 7 0 0 9 5 0 294 Subsequent to operation 930 1 1 5 0 91 5 1 2 5 0 2 2 5 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run~ Water Injector Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si, ned ~'~~J ~ ' ~ Title Sr. Operations En,ineer Date5'''[3 ~'~) Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE AHC;U AlaSKa, Inc. Subsidiary of Atlantic Richfield Co~ --IPBDT CONTRACTO~ _ nEMARKS IOPERATJ.~N AT REPORT TIMI~ e57 co.5 / 77-~!'. oo WELL SERVICE REPORT IDATE T / I--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots Type of Request: STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown __ Stimulate X Plugging ~ Perforate _ Pull tubing ~ Alter casing ~ Name of Operator ~ Type of Well: Development ARCO Alaska, Inc. Exploratory 3. Address I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service Location of well at surface 36' FSL, 429' FEL, Sec. 23, T11N, R9E, UM At top of productive interval 1318' FNL, 1358' FEL, Sec. 24, T11N, R9E, UM At effective depth 1354' FNL, 1164' FEL, Sec.24, T11N, R8E, UM At total depth 1364' FSL, 1112' FEL Sec. 24 T11N R8E UM 2. Present well condition summary Total Depth: Repair well .__ measured 8220' feet Plugs (measured) true vertical 6743' feet =ull tubing_ Other 6. Datum elevation (DF or KB) 6200' SS 7. Unit or Property name Kuparu. k River Unit Effective depth: measured 81 27' feet Junk (measured) true vertical 6264' feet Casing Length Size Cemented Structural Conductor I 1 0' 1 6" 224 Sx CS II Surface 3753' 9 5/8" 1790 Sx Intermediate Production 8 21 0' 7" 350 Sx G & Liner 41 bbls AS I Perforation depth: measured 7770'-7798', 7938'-7976' true vertical 5968'-5990', 6105'-6137' feet _ 2D-08 Producer 9. Permit number 84-1 27 10. APl number 50-029-21158 /9-424 11. Field/Pool Kuparuk River Field K..~.garuk River Oil Pool ~ Measured depth True vertical depth 110' 110' 3753' 3158' 8210' 6334' Tubing (size, grade, and measured depth 3 1/2", 9.3 lb/It, J-55, 7853' Packers and SSSV (type and measured depth) 40 bbls diesel w/2 bbls 8660 50 bbls produced water w/5 bbls S289 13. Stimulation or cement squeeze summary Intervals treated (measured) 8172'-8198', 8240'-8252' Treatment description including volumes used and final pressure 50 BBIs 15% HCL; Final treatin~L~ressure of 1500_.psi 14. OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Prior to well operation 6 1 3 1 9 4 4 8 0 I 2 0 0 Subse~eration 8 4 7 2 9 3 9 2 2 I 3 5 0 '---'--~16. Status of well classification as: 15. Attachments Surveys run__ ~ Water Injector.___ Copies of Logs and Operations X Oil x Gas Suspended Daily Report of Well -- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned Title Senior Operations Engineer Form 10-404 Rev 05/17/89 Service Tubing Pressure 172 171 SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT R~;MARK$ O,'/ I"-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' i Chill Fact I VisibilityIWindVel'Report 'F °r~F miles STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 36' FSL, 429' FEL, Sec. 23, T11N, R9E, UM At top of productive interval 1318' FNL, 1358' FEL, Sec. 24, T11N, R9E, UM At effective depth 1354' FNL, 1164' FEL, Sec. 24, T11N, RSE, UM At total depth 1364' FSL, 1112' FEL, Sec. 24, T11N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 8220' feet Plugs (measured) 6743' feet 6. Datum elevation (DF or KB) 6200' SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-08 Producer 9. Permit number 84-127 10. APl number 5o-029-211 58 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth.' measured true vertical 8127' feet Junk (measured) 6 2 6 4' feet Casing Length Structural Conductor 11 0' Surface 3 7 5 3' Intermediate Production 8 21 0' Liner Perforation depth: measured 7770'-7798', true vertical 5968'-5990', Size Cemented Measured depth True vertical depth 1 6" 224 Sx CS II 1 1 0' 1 1 0' 9 5/8" 1790 Sx 3753' 31 58' 7" 350 Sx G & 8210' 6334' 41 bbls AS I 7938'-7976' 6105'-6137' RECEIVED Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7853' Packers and SSSV (type and measured depth) Baker FHL 7618', Baker FVL 1970', Baker FB-1 7833' Ano~,,ragc Detailed operation program 'jUi',i 2 2 ]939 Alas~¢-3 Oil & Gas Cons. CommissJa~ BOP sketch 13. Attachments Description summary of proposal _ A Sand perforations. 14. Estimated date for commencing operation June 12, 1~)89 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended Service P r o d u c e r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Conditions of approval: Plug integrity m BOP Test Mechanical Integrity Test__ Notify Commission so representative may witness Location clearance Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 IApproval No. Approved C~opy . -~.~eturneo Commissioner ~ Date" ~_.~,-, 2.,~-,~'~ SUBMIT IN TRIPLICATE SUNDRY NOTICE - WELL 2D-08 Perforate the A5 zone with 4 spf and 90 deg phasing from 7910' to 7922' MD. A Sand Pressure (6200' SS) = 2550 3/12/85 SBHP NO WORKOVER FLUID WILL BE USED DULLING THIS PROCESS. 1.) 2.) 3.) 4.) 5.) 6.) 7.) 8.) 9.) 10.) 11.) 12.) 13.) 14.) 15.) 16.) Well 2D-08 Pre-perf PBU / Perforate A5 Sand / Post-perf PBU 6/8/89 CC: 230DS28DL MIRU Slickline unit. RIH with standing valve and set in D nipple @ 7848' MD. Pressure test tubing to ensure that the C Sand is isolated from the tubing. RIH and retrieve blanking plug. RDMO slickline unit. Obtain at least 3 A Sand only production tests. Once rate has been stabilized for at least five days the PBU procedure can begin. RU KDGS to record FTP for at least 4 hours prior to MI Automatic Echometer and associated equipment to ensure well is stable. (PVID No. 10502) Leave well flowing after AE is installed and manually check flowing tubing pressure with the AE pressure transducer to ensure close agreement with KDGS prior to initiating the test. Program equipment to perform 10 acoustic surveys per time Icg cycle and record a chart every tenth survey. Shut in well and leave shut in at least 48 hours. Check operation of AE Equipment periodically throughout test. On site analysis by Operations Engineering personnel will determine appropriate completion of the test. RD Automatic Echometer equipment. MIRU E-line perforating unit. Tie into and perforate the following depths. Perforate underbalanced with the well flowing (just enough to lower the bottom hole pressure by 300 to 500 psi). DIL/SFL (MD-RKB) CBL (MD-RKB) Shot Dens./Phase Length 7910 -7922 7910 - 7922 4 SPF / +90 deg 12' 7910 -7922 7910 - 7922 4 SPF / -90 deg 12' After shooting, flow the well to clean up perforations. RDMO E-Line perforating unit. Return well to A Sand production and repeat steps 10 through 14 to obtain production and post perforation PBU tests. MIRU Slickline unit. RIH and pull C Sand DV's @ 7655', 7722', and 7831' Oil & gas Oozes." ...... ' ' 17.) 18.) 19.) RIH and set C Sand CV's. Tag fill. Perform 2D-8 C Sand Scale Inhibitor Squeeze and Change Bottom Orifice Valve Procedures. 4 1. 5000 PSI ?" WELLHF, AD CONNECTOR IrLANGE 2. 5000 PSI WIR[LIN£ RAMS (VARIABL£ SIZE) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE P^C~-orr 2 H]REL]NE BOP EQU]PHENT A. _.,A OIL AND GAS CONSERVATION ~ .... ,ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate × Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 36' FSL, 429' FEL, Sec. 23, T11N, R9E, UM At top of productive interval 1318' FNL, 1358' FEL, Sec. 24, T11N, R9E, UM At effective depth 1354' FNL, 1164' FEL, Sec.24, T11N, R9E, UM At total depth 1364' FSL, 1112' FEL, Sec. 24, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8220' feet Plugs (measured) 6743' feet 6. Datum elevation (DF or KB) 6200'SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-08 Producer 9. Permit number 84-127 / 10. APl number 5o-02921 15800 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 81 27' feet Junk (measured) true vertical 6 2 6 4' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 0' 1 6" 224 Sx CS II I 1 0' 1 1 0' Surface 375 3' 9 5/8" 1790 Sx 3 75 3' 31 5 8' Intermediate Production 8 21 0' 7" 350 Sx G 8 21 0' 6 3 3 4' Liner 41 bbls AS I Perforation depth: measured 7770'-7798', 7938'-7976' MD true vertical 5968'-5990',6105'-6137' TVD Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7853' Packers and SSSV (type and measured depth) Baker FHL 7618', Baker FVL 1970', Baker FB-1 7833' i' 13. Stimulation or cement squeeze summary ~,..'/." . .... ' '- .: Scale Inhibitor Squeeze Treatment Pumped into C Sand ~' ~' Intervals treated (measured) 7770'-7798' Treatment description including volumes used and final pressure 250 bbl seawater, 107 bbl diesel, 110 gal solvent, 165 gal inhibitor 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 3 4 9 2 4 0 5 6 0 5 8 0 Tubing Pressure 196 Subsequent to operation 728 493 944 1275 190 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Date $-- -~- % ~ $ '? SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL IPBDT ,~.[3 - ~ I <5727 ,',ITRACTOR REMARKS ' WELL SERVICE REPORT FIELD- DISTRICT- STATE. OPERATION AT REPORT TIME ,.7,%-~_~,--[--eb P~p/ [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK w,,,~,, I'" I~'"'' v,,,~,,,,~ iw,~v,. Report f' /d OF - Z- °F ,~ miles //0 knots ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 17, 1989 Mr. C. V. Chatlerton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Ancho?age, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 1 G-06 Tbg. Comm. April, 1989 2D- 14 Stimulate April, 1989 2 D - 0 8 Scale Treatment April, 1989 2D-15 Fracture April, 1989 WSW -2&7 Conversion May, 1989 WSW -8&9 Conversion May, 1989 WSW -10&11 Conversion May, 1989 2V-16 Perforate April, 1989 If you have any questions, please call me at 265-6840. Sincerely, (~. B. ~m~' Iwood Senior Operalions Engineer GBS:kr Attachments CC: H. F. Blacker ATO 1126 J. Gruber ATO 1478 KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AllanticRichlieldCompany ~, OIL AND GAS CONSERVATION COMN .... ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 13. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service !4. Location of well at surface 36' FSL, 429' FEL, Sec. 23, T11N, R9E, UM At top of productive interval 1318' FNL, 1358' FEL, Sec. 24, T11N, R9E, UM At effective depth 1354' FNL, 1164' FEL, Sec.24, T11N,. R9E, UM At total depth 1364' FSL, 1112' FEL, Sec. 24, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6. Datum elevation (DF or KB) 6200'SS 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-08 Producer 9. Permit number 84-127 10. APl number 50-02921 15800 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Structural Conductor 1 1 0' Surface 3 75 3' Intermediate Production 8 21 0' Liner Perforation depth: measured 7770'-7798', true vertical 8220' feet Plugs (measured) 6743' feet 81 27' feet Junk (measured) 6 2 6 4' feet Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 110' 110' 3753' 3158' 8210' 6334' 224 Sx CS II 1790 Sx 350 Sx G 41 bbls AS I 7938'-7976' MD 5 968'-5 990',6105'- 6137' TVD Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7853' . Packers and SSSV (type and measured depth) Baker FHL 7618', Baker FVL 1970', Baker FB-1 7833' 13. Attachments Description summary of proposal _ C Sand Scale Inhibitor Squeeze 14. Estimated date for commencing operation 15. 2/17/89 16. If proposal was verbally approved Name of approver Date approved i Service Pro d u c e r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~ ¢/~ ~-"~2 Title ¢ r¢'~/,~ --~---m-~ ~,.-?7, /¢~' FOR COMMISSION I~E ONLY Detailed operation program _ BOP sketch Status of well classification as: Oil __ Gas __ Suspended Plug integrity_ Mechanical Integrity Test Conditions of approval: Notify Commission so representative may witness BOP Test Location clearance m Subsequent form require 1 Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LOI~!~J!E C. SMITH IApprOval r~'....C:::~ ~' y 009¥I · ~,¢~~' SUBMIT IN TRIPLICATE SUNDRY NOTICE - WELL 2D-08 Pump a C Sand scale inhibitor squeeze treatment. NO BOP'S WILL UTILIZED DURING THIS PROCEDURE. The treatment will be pumped through a surface manifold. C SAND PRESSURE (6200' SS) = 2659 PSI 12/27/85 SBHP NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. lYlessrs. Lyden and Wade February 7, 1989 Page 2 C SAND SOC TREATMENT WELL 2D-08 2/9/89 CC: 230DS28DL 1. Mix 3 drums S-289 (165 gallons) with 1680 gallons (40 bbls) seawater. 2. MIRU Slickline. . RIH with standing valve and set in D nipple at 7848' MD. . . MIRU pump equipment. Spear ahead of inhibitor pill with 10 bbls of seawater followed by 40 bbls of diesel containing 2 drums of SA-8660(Chemlinks Mutual Solvent). Follow spear with pre- mixed inhibitor pill pumping at 2 to 4 BPM rate. Overdisplace pill with 200 bbls of seawater to push pill out into formation pumping at 2 to 4 BPM rate. Follow seawater overflush with 67 bbls of diesel to displace tubing. 7. RIH and pull standing valve from D nipple. 8, RDMO pump equipment. . Shut-in well for 24 to 36 hours to allow the chemicals to soak. Bring well back on production at 500 BFPD for the first 24 hours. Open well fully and turn on gas lift after the first day. Leave gas lift scale inhibitor off(if applicable) to allow inhibitor residuals to be measured. 1 0. Sampling for residuals will be coordinated by the Kuparuk Corrosion group. r 1. ~000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. ~000 PSI WIR[LINE RAMS (VARIABLE SIZE) 3. 5000 PSi 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr H]REL]NE BOP EoUIPMENT I r · /-. ~or~ OIL AND GAS CONSERVATION COM~,..~. APPLICATION FOR SUNDRY APPROVALS <~uspend _ Operation Shutdown _ Re-enter suspended well_ ')air well _ Plugging _ Time extension _ Stimulate X ..~isgram _ Pull tubing _ Variance _ Perforate _ Other 1. Type of Request: Abandon Alter Chan¢, 2. Name of Operator 5. Type of Well: Development X.~ 6. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Exploratory Stratigraphic Service 4. Location of well at surface 36' FSL, 429' FEL, Sec. 23, T11N, R9E, UM At top of productive interval 1318' FNL, 1358' FEL, Sec. 24, T11N, R9E, UM At effective depth 1354' FNL, 1164' FEL, Sec.24, T11N, R9E, UM At total depth 1364' FSL, 1112' FEL, Sec. 24, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 8 2 2 0' true vertical 6743' i feet Plugs (measured) feet 6200'SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-08 Producer 9. Permit number 84-127 10. APl number 50-02921 1 5800 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 81 27' feet Junk (measured) 6 2 6 4' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 110' 3753' 1 6" 9 5/8" 821 0' 7" measured 7770'-7798', 7938'-7976' true vertical 5968'-5990',6105'-6137' Cemented 224 Sx CS II 1790 Sx 350 Sx G 41 bbls AS I MD TVD Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7853' Packers and SSSV (type and measured depth) Baker FHL 7618', Baker FVL 1970', Baker FB-1 7833' 13. Attachments Description summary of proposal C Sand Scale Inhibitor Squeeze Measured depth True vertical depth 110' 110' 3753' 3158' 8210' 6334' ,, _ Detailed operation procam _ BOP sketch 14. Estimated date for commencing operation 6/4/89 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _ Suspended Service P r o d u c e r 17. ! hereby certify that the foregoing is true and correct to the'hbest of my knowledge. I ' (-/ ' ' - FOR COMMISSIOR USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test Subsequent ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission form require 10-.4~-¢~' ~,pproved CoPY Returned Commissioner _.pproval No. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SUNDRY NOTICE- WELL 2D-08 Pump a C Sand scale inhibitor squeeze treatment. NO BOP'S WILL UTILIZED DURING THIS PROCEDURE. The treatment will be pumped through a surface manifold. C SAND PRESSURE (6200' SS) = 2659 PSI 12/27/85 SBHP NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. Messrs., Lyden' and Wade May 4, 1989 Page 2 C SAND INHIBITOR SQUEEZE TREATMENT WELL 2D-08 5/4/89 CC: 230DS28DL 1. MIRU Slickline, 2. RIH w/gauge ring to ensure tubing free of scale, 3. RIH with standing valve and set in D nipple at 7848' MD, 4. MIRU pump equipment. . , Spear ahead of inhibitor pill with 10 bbls of seawater followed by 40 bbls of diesel containing 2 drums of SA-8660(Chemlinks Mutual Solvent), Mix 3 drums S-289 (165 gallons) with 1680 gallons (40 bbls) water, Follow spear with pre-mixed inhibitor pill pumping at 2 to 4 BPM rate, Overdisplace pill with 200 bbls of seawater to push pill out into formation pumping at 2 to 4 BPM rate, Follow seawater overflush with 67 bbls of diesel to displace tubing. 7, RIH and pull standing valve from D nipple, 8, RDMOpump equipment, , 10, Shut-in well for 24 to 36 hours to allow the chemicals to soak, Bring well back on production at 500 BFPD :for the. first 24 hours, Open well fully and turn on gas lift after the first day, Leave gas lift scale inhibitor off(if applicable) to allow inhibitor residuals to be measured, Sampling for residuals will be coordinated by the Kuparuk Corrosion group, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 26, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. Well Action 2 E- 1 1 Refracture 1 Y- 1 Conversion 1 Y-1 2 Conversion _?~ D-~_.~14 Perforate Refracture 2 D- 1 Refracture 1 H - 7 Perforate If you have any questions, please call me at 265-6840. Sincerely, G. B. Srfiallwood Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 Alaska Oil & Oas Got:... "' '-¢~',-~ .... Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~"-" STATE OF ALASKA ALA,~r~,-~ OIL AND GAS CONSERVATION COMN,,,.4SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARC. O Ala$1~8 ~ TDC_. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 36' FSL, 429' FEL, Sec. 23, Tl!N, RgE, UM 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well number 2D-8 Producer Feet At top of productive interval 1318' FSL, 1358' At effective depth 1354' FSL, 1164' At total depth 1364' FSL, 1112' FEL, Sec. 24, T11N 11. Present well condition summary 8220 Total depth: measured true vertical 6743 FEL, Sec. 24, T11N FEL, Sec. 24, T11N , R9E, UM , R9E, UM , R9E, UM 8. Approval number 9. APl number 50-- 029-2!15800 10. Pool Kuparuk River 0il Pool , feet Plugs (measured) I feet Effective depth: measured 8127' feet Junk (measured) true vertical 6264' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 16" 224 Sx CS II 110' 110' Surface 3753' 9-5/8" 1790 Sx 3753' 3158' Intermediate Production 8210' 7" 350 Sx 6 & 8210' 6334' Liner 41 bbls AS I Perforation depth: measured 7770'-7798' 7938'-7976' MD true vertical 5968'-5990' 6105'-6137' TVD Tubing (size, grade and measured depth) 3 1/2" 9 3 lb/ft J-55 7853' Packers and SSSV (type and measured deDt~er FHL 7618', Baker FVL 1970' , Baker FB-1 7833' 12. Stimulation or cement squeeze summar~Refracture A Sand with gel led diesel Intervals treated (measured) sand - ~"~ s ~ ~ .' :'_~ Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ;:Tub~g~Pressu re 16 64 0 1200 156 Subsequent to operation 262 174 0 1200 154 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 ..~/~ Title Date ~/~ (./< Submit in Duplicate (~ ARCO Alaska, Inc. ~ ~. Subsidiary of Atlantic Richfield C~'~-~' .EMARKS WELL SERVICE REPOR; DAYS / 1':''~':' / 6-// / - / /530 I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I SIgned knotsI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon Suspend "; Operation Shutdown i } Re-enter suspended well [; Alter casing L-l Time extension ' Change approved program L} Plugging ~ Stimulate .~ Pull tubing ' ' Amend order F-! Perforate [' Other ! 2. Name of Operator ARC(1 Ala_~ka: Inc, 3. AddFess P.O. Box 100360~ Anchorage, Alaska 99510 4. Location of well at surface 36' FSL, 429' FEL, Sec. 23, T11N, RgE, UM 5. Datum elevation (DF or KB) 6200' SS 6. Unit or Property name Kuparuk River Unit 7. Well nu~r~._e(~8 Producer At top of productive interval 1318' FSL, 1358' FEL, Sec. 24, At effective depth 1354' FSL, 1164' FEL, Sec. 24, At total depth 1364' FSL, 1112' FEL, Sec. 24~ 11. Present well condition summary Total depth: measured true vertical TllN, R9E, UM TllN, R9E, UM T11N, R9E, UM feet 8220' 6743' feet feet Plugs (measured) 8. Per m i t~l~.u._r~ ~)~r 9. APl number 50- 0292115800 10..Pool Kuparuk River 0il Pool Effective depth: measured 8127' feet true vertical 6264' feet Junk (measured) Casing Length Size Structural Conductor ll0' 16I' Surface 3753' 9-5/8" Intermediate Production 8210 ' 7 II Liner 7770'-7798' Perfora, tion depth: measured Cemented 224 Sx CS II 1790 Sx 350 Sx G & 41 bbls AS I , 7938'-7976' MD Measured depth 110' 3753' 8210' ~ue Vertical depth 110' 3158' 6334' true vertical 5968'-5990' 6105'-6137' TVD Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft, J-55,-.7853' Packers and SSSV (type and measured depth) Baker FH[ 761R'_ Raker FV[ 1970'. Baker FB-1 7833'. 12.Attachments Description summery of proposal~ Detailed operations program Refracture A Sand with gelled diesel sandfrac. 13. Estimated date for commencing operation 5/20/88 14. If proposal was verbally approved ;,~mm~i~.~ ~~ ~b~~~ Name of approver j~ . ~J ,'/~ Date approved 15. I hereby certify that the foregoing is true and correct to the...best of my knowledge Signed ~.~ ~,{,../~ ¢ ~."~ .¢~ ~ Title/~'~ ~.~% ~,.,t~ ..,~,~ .~ Commission Use Onl~ BOP sketch [] Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test ~] Location clearance Approved by ORIGINAL SIGNED BY ! d~,NIF C, SMITH Aporoved Copy Returned Commissioner JApproval No. ~(~ 4~. ~'"-- by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Messrs. Lyden and Wadable. May 10, 1988 Page 3 Kuparuk Well 2D-8 A Sand Refrac Procedure 5/10/88 Charge Code: 230DS28DL A small refracture treatment will be performed to increase the productivity of the A Sand. The small job size is designed to prevent height growth into the overlying C Sand which produces 60% water. 1) MIRU slickline. 2) RIH with a gauge ring to tag fill and check tubing for scale. 3) RIH to replace GLV's at 2050', 4065', 5693', 7254', 7560' with DV's. 4) RIH with standing valve and set in "D" nipple. The well contains scale which caused a plug to be stuck in the "D" nipple for the month of April. Please take necessary precautions. 5) 6) PT tubing to 4000 psi to ensure DV's are in place. RDMO Slickline. 7) MIRU pump truck. 8) 9) Pump pre-pad musol 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. Expected Wellhead Treating Pressure- WHTPE = 3200 psi (Based on previous fracture treatment.) Fracture Gradient = 0.70 psi/ft (6120' TVD) ' Tubing Friction = 175 psi/lO00 ft (7853' 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 - May 10, 1988 ~_-~. Page 4 10 BPH (120-240 BPD). Record tank straps(rates), choke settings, and WHP's during flowback period. Inspect samples for frac sand. If frac sand is produced, SI well and begin flowback again after 4 hours. 14) 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, obtain a 24 well test. Contact Operations Engineering for a new gas lift design. SUNDRY NOTICE - WELL 2D-8 A SAND FRACTURE TREATMENT NO BOP'S ARE USED DURING THE FRACTURE, THE FRAC WILL BE PUMPED THROUGHT A MANIFOLD ON SURFACE. A SAND PRESSURE (6200' SS) = 2548 PSI 12/26/85 SBHP NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. ARCO Alaska, In¢~-'' .... Post Office ..,~, .00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 30, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent following wells at the Kuparuk River Field: notices Well Action Date Performed 1G-2 Acidize 7/12/85 1R-5 Fracture 7/16/85 1R-6 Fracture 7/19/85 1R-7 Fracture 7/17/85 1R-8 Fracture 7/17/85 2D-7 Acidize 6/21/85 2D-8 Acidize 6/21/85 2H-3 Acidize 6/21/85 2H-13 Fracture 7 / 23 / 85 2 X-5 Perforate 7 / 23 / 85 3B-1 Acidize 7/22/85 on the If you have any questions, please call me at 263-4212. T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) RECEIVED o e 985 Ou ~ .Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~nMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. LOcation of Well SURFACE LOCATION' 36' FSL, 429' FEL, SEC. 23, T11N, RDE, UM BOTTOMHOLE LOCAT ION- 24, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 126' 12. 1387' FSL, 1088' FEL, SEC. UM 6. Lease Designation and Serial No. 7. Permit No. 84-127 8. APl Number 50- 029-21158 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-8 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER O I L (RKB) APL 25653 POOl_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] X[-] Abandonment [] [] Other [] 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). On June 21, 1985, the "C" sands of Kuparuk well 2D-8 were acidized improve production. The treatment consisted of 36 bbls of 12% HCL. Diesel was used for flushing and nitrogen to aid well cleanup. to Prior to starting job, equipment was pressure tested to 4000 psi. RECEIVED AUG 0 219B§ Alaska 0il & Gas Cons. o0mmissi0n Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~ ~'~ Title KUPARUK Date 7 / 29 / 85 _4. Signed OPERAT IONS COORD I NATOR (~ --~ ..... The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B~., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 07-08-85 TRANSMITTAL NO: 5242 RETURN TO: ~ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ~ ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED RECEIPT AND SEQUENCE OF ACID DATA SAND ACID HEREWITH ARE THE RETURN ONE SIGNED EVENTS FROM ~LL FOLLOWING ITEMS. pLE/A~E ACKNOWLEDGE COPY OF THIS TRANSMITTAL. SERVICE REPORTS FLU ID AND lQ-5 'C' iQ-6 'C' SAND ACID 2D-7 'C' SAND ACID STIMULATION 2D-8 'C' SAND ACID STIMULATION 2H-3 'A' SAND ACID STIMULATION 2H-3 'A' .SAND ACID STIMULATION 2H-3 'A' SAND ACID STIMULATION 3B-3 FLUID I. Do 3B-3 FLUID I. D. PRESSURE DATA 1E-25 BHP WORKOVER lQ-13 STATIC AND MISCELLANEOUS lQ-14 STATIC AND MISCELLANEOUS iQ-15 STATIC AND MISCELLANEOUS iQ-16 STATIC AND MISCELLANEOUS 2E-9 BHP STATIC SURVEY 2E-10 BHP STATIC SURVEY 2E-11 BHP STATIC SURVEY 2E-12 BHP STATIC SURVEY 2F-10 FLO¥~ING BHP AND MISC. 2U-14 'C' SAND PBU--START 2U-14 'C' SAND PBU--FINISH 2U-16 'A' SAND PBU--START 2U-16 'A' SAND PBU--FINISH 2V-5 'A' SAND PBU--START 2V-5 'A' SAND PBU--FINISH 2V-13 INITIAL BHP & MISC. ~V-13 INITIAL ~BHP & MISC. 2V-14 INITIAL BHP & MISC. ~V-15 STATIC BHP 2V-16 STATIC BHP 2X-2 E-LINE BHP 2X-2 E-LINE BHP 2X-5 BHP FOR WORKOVER ~B-2 STATIC PRESSURE & MISC. ~.B-3 STATIC PRESSURE & MISC. ~B-5 STATIC BHP PRIOR TO Fl{AC B-6 STATIC BHP PRIOR TO FI{AC .ECEIPT ACKNOWLEDGED: ~PAE* MOBIL* iHEVRON* PHILLIPS OIL* ~ & M* J.RATHMELL* 06-23-85 NOWSCO/HALLIBURTON 06-24-85 NOWSCO/HALLIBURTON 06-21-85 B.J.HUGHES 06-21-85 B.J.HUGHES 06-23-85 CAMCO/HOT OIL 06-21-85 DOWELL 06-22-85 NOWSCO 06-23-85 OTIS 06-20-85 OTIS 06-12-85 06-24-85 06-23-85 06-21-85 06-21-85 06-13-85 06-13-85 06-13-85 06-13-85 06-14-85 06-18-85 06-18-85 06-17-85 06-17-85 06-26-85 06-26-85 06-22-85 06-21-85 06-22-85 06-19-85 06-19-85 06-16-85 06-14-85 06-12-85 06-14-85 06-15-85 06-26-85 06-26-85 SOHIO* OTIS CAMCO CAMCO CAMCO CAMCO OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO/OTIS o s OTIS CAMCO CAMCO CAMCO CAMCO DATE: K. L. WELL AI~SK~ Oil & G~s Cons. Gommission TULIN/VAULT JOHNSTON FILES RETURN TO: AP~'~ A~laska, Inc. st Office Box 100360 ~nchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 06-19-85 ........ TRANSMITTAL NO:5230 PAGE 1 OF 2 ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. 'BOX 100360 ANCHORAGE, AK 99510 lB-1 lB-2 lB-4 lB-4 1E-iA 1E-5 iE-11 1E-23 1E-23 1E-27 1E-27 1G-6 TRANSMITTED HERE~4ITH .ARE THE RECEIPT AND RETURN ONE SIGNED COPY OF THIS SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE, FLUID,. AND ACID DATA SBHP 05-30-8 1H-6 1L-5 1L-5 lQ-1 .!Q-1 !Q-3 iQ-4 lQ-4 lQ-4 lQ-5 lQ-7 !Q-9 lQ-9 1Y-12 2A-2 2A-4 2A-4 2A-4 2A-5 SBHP- SBHP PRE-WORKOVER SBHP TUBING LEAK COMP PBU ETC. LEUTERT BI{ SMPL SBHP SBHP TEMP/SPIN-LEAK TUBING LEAK PRESSURE FALL- OFF SBHP PBU W/E-LINE PBU ISIP SBHP 'A'SDS TAG FILL BHP SBHP 'C' SD ETC SBHP ETC ACID JOB" ISIP TEST ACID JOB 'C ' SD PBU PBU 'C 'SD ETC FALL-OFF TEST BHP 'A 'SD BtIP 'A ' SD BHP 'A 'SD BHP FOLLOWING ITEMS. PLEASE ACKNOWLEDGE 5 05-30-85 05-16-85 05-24-85 04-29-85 05-03-85 04-28-85 06-02-85 05-22-85 05-23-85 05-03-85 05-04-85 05-07-85 04-29-85 04-27-85 04-29-85 05-30-85 05-26-85 05-18-85 05-10-85 05-14-85 05-17-85 04 -29-85 05-26-85 05-12-85 05-13-85 05-05-85 05-27-85 05-10-85 05-09-85 05-i1-85 SBHP - 05-05-85 ***CONTINUED ON THE :FOLLOWING PAGE* RECEIPT ACKNOWLEDGED: TRANSMITTAL. (ONE COPY OF CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO CAMCO EACH ) CAMCO CAMCO CAMCO B. J. HUGHES CAMCO CAMCO CAMCO CAMCO NOWSCO/B . J. HUGHES B. J. HUGHES NOWSCO/DOWELL CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO D I5'Tl{'lf~ U T ION: W. · PASHER EXXON PHILLIPS OIL* J. P~ATHMEL L.~ BPAE* DRILLING B. CURRIER L. JOHNSTON CHEVRON* MOB IL* D & M.~' NS K CLERK DATE: ~"STATE OF .ALA'SKA.~. 'SOHIO* UNION* ~ U-,IN/VAULT ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompan¥ ARCO Alaska, In,~''-~' Post Offic~ ..._ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 31, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached are our notices of intention to fracture Kuparuk field wells 2D-5, 2D-6, 2D-7, and 2D-8. if you have any questions, please call me at 263-4543. _~l~uparuk Operat ions / kmc Coordinator Attachment (In Triplicate) RECEIVED M/ ys i Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-127 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21158 OTHER [] 4. Location of Well SURFACE LOCAT ION' T11N, RgE, UM 36' FSL, 429' FEL, SEC. 23, BOTTOMHOLE LOCATION' 24, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 126 ' (RKB) 12. 1387' FSL, 1088' FEL, SEC. UM 6. Lease Designation and Serial No. ADL 25653 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-8 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOl 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 ]~f Abandon [] Stimulation '~ Abandonment [] Repair Well [] 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). It is proposed that the "C" sand in Kuparuk well 2D-8 be acidized to improve production. The treatment will consist of 12% HCL. The acid is to be pumped by coil tubing unit and displaced with nitrogen to aid well cleanup. Prior to starting work, equipment will be pressure tested to 4,000 psi. Fluid Requirements. 12% HCL Diesel 36 BBLS 57 BBLS ANTICIPATED START DATE- JUNE 5, 1985 Subsequent Work Reported RECEIVED MAY ,I, 3.985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK The space below for Commission use Date 5/31/85 Conditions of Approval, if any: Approved by .jkpproved Co~. Returned By Order of COMMISSION[R the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, , "- Post Office ,.,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ;"',"i"T;'.~ - l"..l::.L.t..l?,,~/,:':.,~"'~, r",",l-'.. ,., ... i . ' I'~- '- - . .... :1; ,.-'-: "!" ~ ..... .- .. . ...... ~ 'i ~ q T.'-,' iL', "i 7', .'--, ,<-- :: .-- ,: ..-.....--. ,. '..' ~. ."; !.J ,-, i ~-" -%: :':- ~'::, '- .~ , -:, ;'-: f': ,'..~ ('i r, _,-. '- r" .". ~-: ..-;~ .-:D c..- :~ -- , I f ~ , ;...: [ ;.., i-% I--~ ;.;. ,;:. ,~ i -; I--. · : .... , .. . 3"~::'-'"'--;"-~":.';'~<T "r";"c:';"-, {_.!c'c;,r:-t,j-r' "" '";'" , :' ...... ~ ......... '~ ......... .. .............. 7' H ~-~1', c. 'i"l'l F:' 0 L. L 0 !.'J ]; N r.'.; 'r 'i" !i!; H 5.' ""r' I... r..:." f.~" ,'? Ii!; ?.-~ c P.: N ;'" ~ ~ '~: "' ' .!- . . . ·" ~' '....': ... h...'...' ..Y ... r? I!~. i-: IT. Lr, c' -r, ,.:-.-...,:u r-, ~.:,.. .... r:' '~"i, ,..--, :.,-.:~:" ~' 0 N Ii'-' :!;: '- ;'- '-.j r"'r';l ..-.-I-.. ,:: .... F.' ...... f')F' Y .""::. ...... r:' .... I [-i T ,:.':.' '~- , ,,.-,,,:r" ..... ;" ~ ,.':.."' ~'~, ]; ~', ..... I ,..~l"' ..... · . <"::"r;~ i~":-,;',,--' f.-j[:. ,:"~;~::';,~"r -::' ' ,:- I . ~:;' ;.. '_.. 1 '-" '-..- ~;;. I... · i...~ .'. I ,.:- ARCO Alaska, Post Office Box 360 · · Anchorage, Alaska 99510 Telephone 907 277 5637 ]: ].-:.' I":" f' ,? ,S:' T-'.,' H F:' 7! 'T' :1: ,'.';' :1:/.';' 'r F' )":.: F;-.' ~-''' '*".' ~,: i"-] 'F r:' ? 'T' r; f"] t,J Iii; I_ I._ .I. . ,-. .... I....-. I... ,..- ..: ... I:: R,':'-'~ C'- I:;~ Iii: i::' (:)I::1 'T' :() 0 I;J Ii;: I... I... ' r': ' :."../ ¢.,f..!'r", 'r-'-:'-'~/¥",~,!i,.! I--I r,-.,-, :E',' . I Fill"" [:',? ,i'-.-': ~:' I"I I::' f" r.'~'~ i"i r~ I"i 71; <" ;[ F:' 'r,'~:;'l.'-: ;",l.:ii"..~ )'.)f"~hllii:l...I... ~.- ... ; · 2¢' .. ..... H Y D '"' "' ' ' F:' F;: r:'-'-~ I"': ' r--~ ' :;.' ,:.'~ i",~ '-"; ,:'-;.' 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' ' "' i'--! f':, ' "" :OU/' ,,'"-'~ ' :::--: i. ,~;.'?'.~ ... t:)'T :,r. ,:; ARCO AlasKa Inc ,S a subsidiary of ~!!ant~cClfcnheldCompany . ARCO Alaska, Post Offim_ ox 360 Anchorage. Alaska 99510 Telephone 907 277 5637 .. ,--~ I-,.- ...... f::~ Z ?'J :"' I'-I b_ l-'i ~':- ,', .~ , -..... ,. ,.--:.: -)--,r i'-,! · r-;.' I-.']: E.'- O F;:.f.) ,!-.:.' C I... Iii; !:;.' r.":-: "f' (::: ..... i i 'i 5; E; ' F:' .. O, !-;; (:) X t 00..'5 ..:.":, O ~-"'-~ i-...-' F- H (3 I-;: ¢-: f.; l:.Z ¢.: ~...-- o ,-;,::. i ,"-", · ~-- -. ~ i · ¢* '.:-' ...: .. · .-~-' .. -"::: ,i {" f'~ I I"~ "".,"~ .... '7, / "; .... ; ....... --, ,.'., .o,-'1," :.2 i) .... ;7; '" i .2' '~."'. '? -- S-q- ;:7- E: !-i !::' '.'::' r., - --' /'i '"" i i ..... :; --'~ ,":: li-:H F:' ...... "'"¥ ' ' L. -'~' · '~ ~; u:- ~'~ ...... - .... i 5? "3 5' '" ~:? -!- ..... '"" ...... .:..'o l-'~ ?' .{ r-I i I . 1 · '"i' 4 '.."': '¢"! ! ! "l " ;:.L J... l.. :..:) ~ , ~ . _ '<"l--Il'--' =:;'~--'~ ,":; ":>% ':? .. "::; ":. 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(.., } .... :. :77} 'T' "' ~'' ['", "r 'r .-.', (;} 'i" Il t..-, }:, .'[ ;i;.' 'f' i:-:-.' ':' ?'::: :..J 'f' :i; (:) i"-j · ""'"' .... '"'" ¥",'"' "! ) "' '-'" ........ ,';'.? )TTa..r0'..~t°.. .~f4~ A.?k .L' ~"....]. . .. .. ...... ::..: t.'.- ~ i':u ~-:: ]: L.. ')~' i l::': Jill': I ':' '"','.'il' l:,.. 'i ,.. ill "'" '. I ..... ~ , i '.,..1. I.,. · ' ;.,,[ '.,.: I : '% r .- ,-.,..-,~ ,-. ! · - ~ ,,, .. i .,.:1 .- /;l'tt "1" .'F) ('.'_ i'l! ')'-"'I ..'.J'?'l:' ('_';I..~:-.I-';-Ii,~ ,.j., [::.::-5,"l-I. li',;,r:.-I...L.v-'i I ' ]' ' ~. J . . ; ~ i Il t. '.,,:: . l , ., · ARCO Alaska, h. Post Office B~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-8 Dear Mr. Chatterton' Enclosed is an addendum to the 2D-8 Well History to include with the Well Completion Report dated 12/20/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L32 Enclosure ECEIVED Wm, R 2 7 1985 Alaska 0il & Gas Cons, Commiss[or~ Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, I,r' '-,,--. .. Post Offic:: -_:_ )100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 22, 1985 Mr. C. V. Chatterton Commi s s i One r State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: ~Well Completion Reports Dear Mr. Cha Enclosed are tterton' Well Completion Reports for the following wells' 2D-5 2D-6 2D~-8'~ If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU5/L50 Encl osures ARCO Alaska, Inc. is a Subsidiary ol AllanlicRichfieldCompany .; ~.~-.~, STATE OF ALASKA ~---.- ALASK AND GAS CONSERVATION ~ ,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ElXX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ' 84-127 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21158 4. Location of well at surface 9. Unit or Lease Name 36' FSL, 429' FEL, Sec.23, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1318' FSL, 1358' FEL, Sec.24, T11N, R9E, UM 2D-8 At Total Depth 11. Field and Pool 1364' FSL, 1112' FEL, Sec.24, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 126' RKB ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 08/11/84 08/20/84 09/18/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8220'MD,6343'TVD 8127'MD,6264'TVD YES [][ NO [] 1970 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC, GR/CNL, Cal, CBL/VDL/GR/CCL/JB, Gyro, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD ~AMOUNTPULLED 16" 62.5# H-40 Surf 110' 24" 224 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3753' 12-1/4" 1090 sx AS III & 700 s:~ Class G 7" 26.0# J-55 Surf 8210' 8-1/2" 350 sx Class G & 41 bb 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) 7956' - 7976' 3-1/2" 7852' 7833' & 7619' 7938' - 7956' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7790' - 7798' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7780' - 7790' w/12 spf See Addendum 7770' - 7780' 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 I~ I 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. !'~ :" -~'" -'~ ~ :: ? ~.. ~ 'i .~ NONE ;': :~' ~ ' ~'~ ! "; ;-~'::: { 'H :-,~-, ~": '~ ' ....... i-'t?.-. · .~. Form 10-407 GRUS/WC32 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE i,~ , :~ .GEoLoG.i::C~i~iAF~K'ER'S '~:'~'~ '":?.' :! ':~.~.-~:~:':"¥ '~"-~ :';: :- :. : :::.~ ::.: ~. "FOFiMATi'ON.-i:'~S-i-'~;.' '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 7767' 5966' N/A Base Upper Sand 7794' 5988' Top Lower Sand 7896' 6071' Base Lower Sand 8038" 6189' . 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the. best of my knowledge Associate Engineer Date INSTRUCTIONS General' This form is designed for submitti,ng a complete and correct well completion report and log on all t~/pes of lands and leases in Alaska. item 1' CI.assi,..fication 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 r. eference (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- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~,07 ADDENDUM WELL: 2D-8 8/28/84 10/23/84 10/24/84 10/25/84 10/29/84 1/15/85 Arctic Pak w/41 bbls AS I, followed by 56 bbls Arctic Pak. 8127' PBTD, Open to tank RU CTU & N^. Tst BOP & ins to 4000 psi; OK. RIH w/CT, jetting ho~e dn w/350 scf/min to 8090'. Wsh perfs several times, POOH, RD CTU. Flowing to tank, rec'd 135 bbls. 8127' PBTD, Open to tank Left open to tank. 8021' PBTD, Open to tank RU Fracmaster & BJ & tst. RIH w/CT, jet N2 to blow well dry, POH w/CT & RD. Monitor well f/flow. No indication of flow. Total fluid rec'd = 78 bbl. Monitor well. 8127' PBTD RU Dowell frac equip, press tst ins to 6000 psi. Start br dn w/ gel/diesel, use 50 bbls. Pmp 50 more bbls into formation @ 2.0 BPM w/4500 psi. SI for ISIP 3300 psi. Calc frac grad @ 0.89, perf fric @ 800 psi. RU, press tst lub. Re-perf w/2-1/8" Enerjet guns, 4 SPF, 90° phasing 7939'-7976'. No. 1: 7956'-7976' @ 2 SPF (2-1/8"), No. 2 rn, 7939'-7956' @ 2 SPF, (2-1/8"), No. 3 rn, 7956'-7976' @ 2 SPF, (2-1/8"), No. 4 rn, 7939'-7956' @ 2 SPF, (2-1/8"). POH, RD SOS. RU Dowell & equip f/breakdn. Press tst to 4500 psi. Could not pmp due to cross linked gel. Break gel, att to breakdn formation f/frac. Max rate 10.5 BPM/4600 psi. 115 total bbls pmp'd. ISIP = 2650 psi, fric press 700-1100 psi; unable to frac. RD Dowell. Open well to flow. WH press = 0 psi - 0 BPD. 8090' PBTD Est IR of 3 BpM @ 2720 psi, 4 BPM @ 2840 psi, 5 BPM @ 2920 psi. Shut dn f/ISIP (2400 psi). Second ISIP = 2480 psi. Total gelled diesel pmp'd = 111 bbls. Flow well to tank. (cont ' d) ADDENDUM WELL: 2D-8 1/28/85 1/29/85 Frac well in 8 stages w/total of 55 bbls of hot diesel, 344 bbls gelled diesel, 2016# 100 mesh & 10,000# 20-40 mesh, leaving 300# 20-40 mesh in csg. Rn Temp log f/8050'-7650' tag 80' of fill Secure well Turn over to Production. Drillin~ Superintendent Date ARCO Alaska, Ir Post Office Bo,, f00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 20, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2D-8 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L162 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ?---. STATE OF ALASKA ------, · ALASK ..... AND GAS CONSERVATION t... vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Irc. 84-127 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21158 4. Location of well at surface 9. Unit or Lease Name 36' FSL, 429' FEL, Sec.23, T11N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1318' FSL, 1358' FEL, Sec.24, TllN, RgE, UM 2D-8 At Total Depth 11. Field and Pool 1364' FSL, 1112' FEL, Sec.24, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126' RKB ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/11/84 08/20/84 09/18/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21.Thickness of Permafrost 8220'HD,6343'TVD 8127'HD,6264'TVD YES [] NO [] 1970 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC, GR/CNL, Ca1, CBL/VDL/GR/CCL/JB, Gyro 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 3753' 12-1/4" 1090 sx AS III & 700 s~ Class G 7" 26.0# J-55 Surf 8210' 8-1/2" 350 sx Class G & 41 bbls 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) 7956' - 7976' 3-1/2" 7852' 7833' $ 7619' 7938' - 7956' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7790' - 7798' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7780' - 7790' w/12 spf See Addendum 7770' - 7780' .. 27. N/A PRODUCTION TEST Date First ProductionI Method of Operation (Flowing, gas lift, etc.') Date of Test Hours Tested PRODUCTION FOR OIL-BBL GASoMCF WATER-BBL CHOKE SIZE IGAS-OILRATI© TEST PERIOD- I~ Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATEI~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED FEB2 1 ]985 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 GRU4/WC39 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · :t.: G'-EO~OGIC.i~A:RI~I~i~-S:; ~: .':'--'[ : " - ' .... ' :'" :" "FORMATION TEST~': '" · 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 7767' 5966' N/A Base Upper Sand 7794' 5988' Top Lower Sand 7896' - 6071' Base Lower Sand 8038' 6189' 31. LIST OF ATTACHMENTS Arlrlenrh ~m 32. · I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/0~ ~J-~ Title Associate Engi neet 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- ing and the location of the cementing tool. Item 27: Method of-Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 2D-8 8/28/84 10/23/84 10/24/84 lo/25/84 10/29/84 1/15/85 Arctic Pak w/41 bbls AS I, followed by 56 bbls Arctic Pak. 8127' PBTD, Open to tank RU CTU & N_. Tst BOP & ins to 4000 psi; OK. RIH w/CT, jetting ho~e dn w/350 scf/min to 8090'. Wsh perfs several times, POOH, RD CTU. Flowing to tank, rec'd 135 bbls. 8127' PBTD, Open to tank Left open to tank. 8021' PBTD, Open to tank RU Fracmaster & BJ & tst. RIH w/CT, jet No to blow well. dry, POH w/CT & RD. Monitor well f/flow. ~No indication of flow. Total fluid rec'd = 78 bbl. Monitor well. 8127' PBTD RU Dowell frac equip, press tst Ins to 6000 psi. Start br dn w/ gel/diesel, use 50 bbls. Pmp 50 more bbls into formation @ 2.0 BPM w/4500 psi. SI for ISIP 3300 psi. Calc frac grad @ 0.89, perf fric @ 800 psi. RU, press tst lub. Re-perf w/2-1/8" Enerjet guns, 4 SPF, 90° phasing 7939'-7976'. No. 1: 7956'-7976' @ 2 SPF (2-1/8"), No. 2 rn, 7939'-7956' @ 2 SPF, (2-1/8"), No. 3 rn, 7956'-7976' @ 2 SPF, (2-1/8"), No. 4 rn, 7939'-7956' @ 2 SPF, (2-1/8"). POH, RD SOS. RU Dowell & equip f/breakdn. Press tst to 4500 psi. Could not pmp due to cross linked gel. Break gel, att to breakdn formation f/frac. Max rate 10.5 BPM/4600 psi. 115 total bbls pmp'd. ISIP = 2650 psi, fric press 700-1100 psi; unable to frac. RD Dowell. Open well to flow. WH press = 0 psi - 0 BPD. 8090' PBTD Est IR of'3 BPM @ 2720 psi, 4 BPM @ 2840 psi, 5 BPM @ 2920 psi. Shut dn f/ISIP (2400 psi). Second ISIP = 2480 psi. Total gelled diesel pmp'd = 111 bbls. Flow well to tank. Dr-il 1 in-g' S~pe-ri~tendent R £F. IVED 1985 3/.s__p'.~/ · Date ~aska Oil & Gas Cons. Commission Anchorage ADDENDUM WELL: 2D-8 8/28/84 10/23/84 10/24/84 1o125184 10129184 1/15/85 Arctic Pak w/41 bbls AS I, followed by 56 bbls Arctic Pak. 8127' PBTD, Open to tank RU CTU & N_. Tst BOP & ins to 4000 psi; OK. RIH w/CT, jetting ho~e dn w/350 scf/min to 8090'. Wsh perfs several times, POOH, RD CTU. Flowing to tank, rec'd 135 bbls. 8127' PBTD, Open to tank Left open to tank. 8021' PBTD, Open to tank RU Fracmaster & BJ & tst. RIH w/CT, jet N2 to blow well. dry, POH w/CT & RD. Monitor well f/flow. No indication of flow. Total fluid rec'd = 78 bbl. Monitor well. 8127' PBTD RU Dowell frac equip, press tst ins to 6000 psi. Start br dn w/ gel/diesel, use 50 bbls. Pmp 50 more bbls into formation @ 2.0 BPM w/4500 psi. SI for ISIP 3300 psi. Calc frac grad @ 0.89, perf fric @ 800 psi. RU, press tst lub. Re-perf w/2-1/8" Enerjet guns, 4 SPF, 90° phasing 7939'-7976'. No. 1: 7956'-7976' @ 2 SPF (2-1/8"), No. 2 rn, 7939'-7956' @ 2 SPF, (2-1/8"), No. 3 rn, 7956'-7976' @ 2 SPF, (2-1/8"), No. 4 rn, 7939'-7956' @ 2 SPF, (2-1/8"). POH, RD'SOS. RU Dowell & equip f/breakdn. Press tst to 4500 psi. Could not pmp due to cross linked gel. Break gel, att to breakdn formation f/frac. Max rate 10.5 BPM/4600 psi. 115 total bbls pmp'd. ISIP = 2650 psi, fric press 700-1100 psi; unable to frac. RD Dowell. Open well to flow. WH press = 0 psi - 0 BPD. 8090' PBTD Est IR of'3 BPM @ 2720 psi, 4 BPM @ 2840 psi, 5 BPM @ 2920 psi. Shut dn f/ISIP (2400 psi). Second ISIP = 2480 psi. Total gelled diesel pmp'd = 111 bbls. Flow well to tank. Drilling S~perintendent RECEIVED MAR 2 ? 19 8 5 D a t e Naska 011 & Gas Cons. Commission Anchorage ADDENDUM WELL: 2D-8 8/28/84 10/23/84 10/24/84 10/25/84 10/29/84 Arctic Pak w/41 bbls AS I, followed by 56 bbls Arctic Pak. 8127' PBTD, Open to tank RU CTU & NA. Tst BOP & ins to 4000 psi; OK. RIH w/CT, jetting ho~e dn w/350 scf/min to 8090'. Wsh perfs several times, POOH, RD CTU. Flowing to tank, rec'd 135 bbls. 8127' PBTD, Open to tank Left open to tank. 8021' PBTD, Open to tank RU Fracmaster & BJ & tst. RIH w/CT, jet N2 to blow well dry, POH w/CT & RD. Monitor well f/flow. No indication of flow. Total fluid rec'd = 78 bbl. Monitor well. 8127' PBTD RU Dowell frac equip, press tst ins to 6000 psi. Start br dn w/ gel/diesel, use 50 bbls. Pmp 50 more bbls into formation @ 2.0 BPM w/4500 psi. SI for ISIP 3300 psi. Calc frac grad @ 0.89, perf fric @ 800 psi. RU, press tst lub. Re-perf w/2-1/8" Enerjet guns, 4 SPF, 90° phasing 7939'-7976'. No. 1: 7956'-7976' @ 2 SPF (2-1/8"), No. 2 rn, 7939'-7956' @ 2 SPF, (2-1/8"), No. 3 rn, 7956'-7976' @ 2 SPF, (2-1/8"), No. 4 rn, 7939'-7956' @ 2 SPF, (2-1/8"). POH, RD SOS. RU Dowell & equip f/breakdn. Press tst to 4500 psi. Could not pmp due to cross linked gel. Break gel, att to breakdn formation f/frac. Max rate 10.5 BPM/4600 psi. 115 total bbls pmp'd. ISIP = 2650 psi, fric press 700-1100 psi; unable to frac. RD Dowell. Open well to flow. WH press = 0 psi - 0 BPD. RECEIVED Alaska Oil & Gas Cons. CommiSSiOn Anchorage Drillin~ Superintendent D~te ARCO Alaska, InC., Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Commission Attached in duplicate are subsequent notices on the fOllowing wells at the Kuparuk River Field' Well Action Date Performed 1E- 15 Fracture 12/17/84 1F-6 Stres sfrac 1/11/85 1L-4 Fracture 1/9/85 1L-5 Fracture 1/10/85 2C-5 Perforate 12/22/84 2C-6 Perforate 12/25/84 2D-1 Perforate 1/13/85 2D-2 Perforate 12/15/84 2D-3 Perforate 12/16/84 -21~~:~ Stressfrac 1/9/85 .If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED FEB 0 6 19 5 Alaska Oil & Gas Cons. Corrlrnission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL EX, OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-127 3. Address 8. APl Number P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21;[58 4. Location of Well 9. Unit or Lease Name SURFACE LOCATION: 36' FSL, 429' FEL, SEC. 23, KUPARUK RIVER T11N, R9E, UM 10. WellNumber UNIT BOTTOMHOLE LOCATION' 24, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 126' (RKB) 12. 2D-8 1387' FSL, 1088' FEL, SEC. 11. Field and Pool UM KUPARUK 6. Lease Designation and Serial No. KU PARU K ADL 25653 i P001_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation XF-) Abandonment [] Repair Well [] 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). On January 9, 1985, the "A" sands of Kuparuk well 2D-8 were stressfractured to improve production. The treatment consisted of three runs with the stress frac tools. Prior to start, equipment and lines were tested to 3000_psi. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title 0 P E R A T I 0 N S The space below for Commission use COORDINATOR 2/4/85 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaskm ~ Post Office Anchorage, Alaska 99510 Telephone 907 277 5637 December 20, 1984 Mr. C. V. Chatterton, Chairm~gn Alaska Oil and Gas ConS'ervat,~'on Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to ~erforate Kuparuk Field wells 2C-5, 2C-6 and 2C-8. Also attached is a notice of intention to. perform a stressfrac on well ~-~~. If you have any questions, please cai1 me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) ARCO Alalk&, Inc. Ii I gub$1dlary of AllilntleRIohfleldCompilny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-127 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21158 4. Location of Well SURFACE LOCATION: TllN, R9E, UM 36' FSL, 429' FEL, SEC. 23, BOTTOMHOLE LOCATION: 24, TllN, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 126' (RKB) 12. 1387' FSL, 1088' FEL, SEC. UM I6. Lease Designation and Serial No. ADL 25653 9. Unit or Lease Name · KUPARUK RIVER UNIT 10. Well Number 2D-8 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 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 [] Repair Well [] 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). It is proposed that the "A" sand in Kuparuk well 2D-8 be stressfrac'd to improve production. Lines and equipment will be pressure tested to 3000 psi prior to starting job. ANTICIPATED START DATE: January 1, 1985 14. I hereby certify, that the foregoing i~,true and correct to the best of my knowledge. Si§ned Title OPERATIONS COORDINATOR The space below for Commission use Date 12/20/84 Conditions of Approval, if any: BY lONfl![ C. $1diIlt Approved by COMMISSIONER ~pprovea ~ ...... By Order of the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Iny Post Offk -~ 360 Anchorage, ,~,aska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETLFRN TO: ARCO ALASKA, INC. ~ ATTN: Records Clerk ATO-1115B P.O. Box 100360 T/ran~Chorage, AK 99510 mi,ted herewith, are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL's/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 ,1 ,, 11 Il ti ,, ,, f, ,, ,1 1, ,! ,! ,! ,1 I, I, 'I II II oo Il ti Il Il II 11 It Il II II II II It Il Il Il II II II II II II "GCT" 10/07/84 "GCT" 10/07/84 "GCT/JB/GA" 9/31/84 "GCT/JB/Ring 9/17/84 "GA/JB/GCT" 9/19 " 9/17 ,GCT" 7/21 "GCT" 9/21 "GCT/GA/JB" 9114 " -"GCT/JC" 10/12/84 " lO/15/84 " lO/12/84 "_ 10/13/84 "GCT/JB/GA" 10/22/84 " 10/22/84 "JB/GA" 8/19/84 " 8/20/84 9/21/84 "GCT/JB" 10/14/84 " 1o/14/84 " lO/O5/84 "GCT" 10/05/84 "Per, 4"~ 9/10/84 5 1/2"/PPS/JB" 11/o5/84 Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: /84 /84 184, /84 /84 /84 B. Currier BPAE Chevron Run II Il Il Il Il 1! Il l! l! II It 11 It It ti t, II ?I ~un Burl Run 1 DISTRIBUTION · Drilling W. Pasher 6597 - 8292 ~2B-3/ 7000 - 8460 ~/2B-!6/ 4950 - 7004 32B-13vz 5750 - 8408 ~-2B-14 5700 - 7970 '~2B-15/ 5348 - 6824 ~2B-2 7250 - 9182 5055 - 6487 --2B-l~/ 6200 '- 7866 ~2D-5~/ 6800 - 8954 --2D-6 5054 - 6650 -2DZT/ 5597 - 8084 --'2D~8-/ 5650 - 7951 ~2G-9~/ 5840 - 8524 --2G-11~ 4940 - 6765 ~ 2G-10~ 5730 - 7950 --2G-12~ 5790 - 7814 - 2G-13~ 5989 - 8624 --2G-14~/ 8650 - 9334 8650 - 9562 1F-6~ 5692 - 6742 5150 - 7252 .~-'iL-1/ 4500 - 6550 ~lL-2~ 6800 7518 'tL-4V'~ 7000 - 821o --15-3/ 7961 - 8941 --2V-8A 6100 - 6992 ~1E-24 S ca t e' 6'f"'~' Sohio Mobil Phillips Oil Union D&M NSKOps. J. Rathmell Well Files' , : · -:c.:;..o.i .~k~ 9.q$1C ', :<-;.::eric ~.T7 $C37 Re Cum To: ARCO ALASKA, Inc. AT/N: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 1~ . Transmittal No: .~. 815 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. o · · OH FINALS Schlumberger DIL-SFL/GR:;~?~,~;~.::~~ 8/15/84 : Run 1 2110 FDO-~/GR' ~w ~:-~.~:~..~.~:~~..~2~10 - 842 4' ok ~ ~:'~ .......... '~ ...... " 7700 -' 8424 ....... "~":~"~Z'?CPL Cyberlo ..~_?~.: -. ....... --..-~ ~ :: z , 2D-8 2"/5" DIL-SFL/GR 8/20/84 Run 1 3754 - 8160 ,~" 2"/5" Density Neutron "Raw" " " '3754 - 8133 " 2"/5" " " "Poro" '" " 3754 - 8133 " CP.L Cyberlook 8/19/84 " 7550 - 8150 2D-11 2G-4 2"/5" BHC Sonic/GR "DIL/~DC/CNL/GR" 2"/5" DIL/SFL 2"/5" FDC-CNL/GR "Raw': 2"/5" - " "Poro" CPL Cyberlook 7/21/84 'Run 1 7150.- 7590 8/24/~4 " 2810- 7795 '-" " 6190- 7795 " " 6190- 7795 8/22/84 " 7090 - 6950 2B-2 .2"/5" DIL-SFL/GR 8/22/84 Run 1 "2729 - 6926 " 2"/5" Density,, Neutron,, "Raw". ,," ,," - RECEIVED b .~ " 2"/5" "Poro" 5500 - 6900 " CPL Cyberlook " " 6300 - 6900 Nov o 8 ~ ~ ~'~--~" 'i~"~-'~ ---I'-- -~- ~' ~"~""~'"'/""~'~ .... o ,,,,.o. Commission Receipt Acknowledged: · --~,~ ~ Dat~: ~ Anchorage . DISTRIBUTION B. Adams F.C. Baker -P. Baxter W.¥. Pasher C.R. Smith " C. Phillips Phillips Oil Sohio BPAE Mobil J.J. Rathmell Union R & D 'Well Files Chevron -NSK Operations _ ARCO Alaska, · Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 30, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-8 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU2/L47 Enclosures RECEIVED NOV 0 1 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~r''-'~--. STATEOF ALASKA f- ~--'- ALAS ,, _ AND GAS CONSERVATION ~ ivllSSION 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. 84-127 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21158 4. Location of well at surface 9. Unit or Lease Name 36' FSL, 429' FEL, Sec.23, TllN, R9E, UM ~LOC~,¥~'t-"~"":"i Kuparuk River Unit At Top Producing Interval VF_?,it-[c° ! 10. Well Number 1318' FSL, 1358' FEL, 5ec.24, T11N, R9E, UH 2D-8 At Total Depth 11. Field and Pool 1364' FSL, 1112' FEL, 5ec.24, T11N, R9E, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool 126' RKB ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/11/8/+ 08/20/8/+ 09/18/8/+ N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set ] 21. Thickness of Permafrost 8220'MD,6343'TVD 8127'MD,6264'TVD YES [~ NO [] 1970 feetMD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC, GR/CNL, Cal, CBL/VDL/GR/CCL/JB, Gyro 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 3753' 12-1/4" 1090 sx AS III & 700 s.~ Class G 7" 26.0# J-55 Surf 8210' 8-1/2" 350 sx Class G & 41 bb 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) 7956' - 7976' 3-1/2" 7852' 7833' & 7619' 7938' - 7956' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7790' - 7798' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7780' - 7790' w/12 spf N/A 7770' - 7780' 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA -Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED o 1984 lilaska Oil & Gas Cons. Commission Anchorage ,- Form 10~,07 GRU2/WC0/+ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~-29. ,.." :..~....-;~,.-'.: '~' ~':~ ]'". - . :.-' ,30, · · ~ - · ' ':' '~ ' -: 'OEof'OGl'd MARKERS ~ - ' - FoRMAT:ION'TESTS " ~:' 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 7767' 5966' N/A Base Upper Sand 7794' 5988' Top Lower Sand 7896' 6071' Base Lower Sand 8038' 6189' 31. LIST OF ATTACHMENTs Well History ~including addendum), Workover Well History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signedj/ - v/,/(///~~~' Title Area Drilling Engr. Date /d///~/~/'/~~' 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- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fnrm 11')-z~r)7 ARCO 011 and Gas Company Well History- Initial Report- Dally Prepare and submit the "Initial R~t" on the flret Wednesday after a well is spudded or workover operations are started. Dally wor~ prior to sPudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 902101 I~un~, ~fi~ or borough North Slope Borough ILeaaeorUnit ADL 25653 ITItle Drill, Complete & Perforate Parker #191 API 50-029-21158 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDle Spudded ! 8/11/84 Date and depth as of 8:00 a.m. 8/11184 thru 8/13/84 8114184 The above is correct IState Alaska IWell no. 2D-8 8/15/84 8/16/84 Complete record for each day reported IHour 2200 hrs IAaCO W.,. 56.24% Prior status if a W.O. 16" @ 110' 1867' (1763') DD w/Bit #3 Wt. 9.6, PV 17, YP 16, PH 10.5, WL 12, Sol 6 Accepted rig 1530 hrs 8/11/84. NU diverter sys. Spudded @ 2200 hrs, 8/11/84. Drl 12¼" hole to 500', DD to 1867'. 500', Assumed vertical 759', 6.9°, N79.5E, 758.28 TVD, 17.54 VS, N7.48, 16.09'E 904', 9.4°, N74.5E, 901.80 TVD, 38.06 VS, N12.11, 36.11E 995', 12.2°, N75.5E, 991.18 TVD, 55.10 VS, N16.52, 52.58E 1085', 14.5°, N75.5E, 1078.74 TVD, 75.87 VS, N21.72, 72.70E 1177', 17.3°, N77.5E, 1167.22 TVD, 101.04 VS, N27.61, 97.20E 1384', 23°, N78.~E, 1361.33 TVD, 172.55 VS, 43.36N, 167.10E 1750', 31.4°, N74 5E, 1685.17 TVD, 341 73 VS, 77 laN, 333 47E 16" @ 110' 3618', (1751'), Drlg Wt. 10.1, PV 24, YP 27, PH 10.0, WL 9.8, Sol 8 Drl, DD & surv 12¼" hole to 3618'. 1933', 36°. N75.5E, 1837.38 TVD, 443.21VS, 103.45N, 431.52E 2240', 40.9°, N69.5E, 2077.47 TVD, 634.2~ VS, 162.64N, 613.21E 2632', 45°, N67.5E, 2362.91TVD, 901.60 VS, 261.59N, 862.87E 3127', 44.9°, N70.5E, 2713.38 TVD, 1249.81VS, 388.33N, 1188.60E 3436', 45.4°, N71.5E, 2931.30 TVD, 1468.63 VS, 459.65N, 1395.73E RECEIVED 9-5/8" @.3753' 3774', (156'), NU BOPE Wt. 10.0, PV 17, YP 8, PH 10, WL 10.2, Sol 7 Drl 12¼" hole to 3774', 24 std short trip, C&C f/csg. RU & rn 94 its, 9-5/8", 36#, J-55 HF-ERW BTC csg w/FS @ 3753', FC @ 3671'. M&P 1090 sx AS III, followed w/700 sx Cl "G" w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. CIP @ 0030 hrs, 8/15/84. Perform top job w/l17 sx AS I. NU BOPE. 3653', 45.2°, N71.5E, 3083.94 TVD, 1622.76 VS, 508.60N, 1542.00E 9-5/8" @ 3753' 774', (0'), Drlg w/Neyrfor turbine Wt. 9.1, PV 8, YP 2, PH 10, WL 12, Sol 3 Fin NU & tst BOPE. RIH, tst csg to 1500 psi, DO 'cmt & flt equip + 10' new hole. Conduct leak-off tst to 14.4 ppg EMW. Drl 8½" hole to 3774. 3892', 45.6°, N71.5E, 3251TVD, 1792VS, 562N, 1703E Signature IOate 9/05/84 ITitle Drilling Superintendent ,~, Daily Well History--Interim ARCO Oil and Gas Company ;~truclions: This lorm IS used dunng drilling or workover operations If !esting. coring, or perforating, show formation name in describing work performed. ,,iumber all drill stem lests sequenlially_ Atlach description Of all cores. Work performed by Producing Section will be reported on "lnlerim" sheets unlil final :omplelion. Report official or representalive test on "Final" form. 1) Submit "lnlerim" sheels when filled out but not less Irequently Ihan every 30 days, or {2) Wednesday of !he week in ,which oil sir.rig is set. Submit weekly Ior workovers and following selling o! OH siring unlil complehon. 3istrict ~e!d and depth 8:00 a.m. I County or Parish Alas[ca NorEh Slope Borough I Lease or Unit Kuparuk River 'ADL 25653 Complete record lor each day while orilling or v,'orkover ;n crogress 8/17/84 8/18/84 thru 8/20/84~ ~8/21/84 JStale Alaska Well no DS 2D-8 9-5/8" @ 3753' 5126', (1352'), Drlg w/Neyrfor turbine Wt. 9.2, PV 11, YP 7, PH 10, WL 11, Sol 4 Drl & surv 8½" hole to 5126' 4003', 45.5°, NT1E, 3350 %VD, 1893 VS, 594N, 1798E 4494', 43.5°, N68.5E, 3680 IVD, 2214 VS, 71ON, 2099E 4994', 46.4°, N73.5E, 4029 TVD, 2572 VS, 819N, 2439E 9-5/8" @ 3753' 8175', (3049'), CO rn Wt. 10, PV 20, YP 15, PH 10, WL 7.6, Sol 9 Drl & surv 8½" hole to 7734', C&C f/csg. RU Schl. Log DIL/SFL/FDC f/8133'-7550', GR/CNL 8118'-3753', CAL f/8167'-6500' Cut DL, prep f/CO rn. 5328', 45.9°, N72.5E, 4198 TVD, 2748 VS, 871N, 2600E 5798', 48.4°, N73.5E, 4577 /VD, 3160 VS, 983N, 3004E 6361', 47.7°, N74.5E, 4952 /VD, 3579 VS, ll00N, 3407E 6734', 46.5°, N74.5E, 5206 /VD, 3853 VS, 1173N, 3671E 7196', 44.8°, N72.5E, 5529 /VD, 4183 VS, 1268N, 3987E 7" @ 8200' 8220', (45'), Prep to cmt 7" csg Wt. 10.I, PV 16, YP 8, PH 10.5, WL 7.4, Sol 10 RIH to 8130', wsh 5' to btm, drl to 8220', circ hole cln, pmp pill, short trip, rm f/8129'-8200' C&C hole f/7" csg, POOH, LD HWDP & BHA. RU & rn 209 jts, 7", 26#, J-55 BTC csg. 8178', 31.30°, N70.5E, 6299.91, 4788.12, 1406.62N, 4561.52E The above is Correct Signature For form preparation and,,~stribdtion see Procedu-re$: Manual S~::tion 10, Drilling. Pages 86 and 87 Date ITitle 9/05/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Preoare 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 bi 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 ,f space ,s avadao;e. IAccounting cost center cboe State Alaska District Alaska Field Kuparuk River County or Parish North Slope Borough Lease or Unit IWell no. ADL 25653 I 2D-8 Auth. or W.O. no. Title AFE 902101 Drill, Complete & Perforate Parker #191 AP1 50-029-21158 Operator AR.Co W.L rTotal number of wells (active or ,nactive) on th~s, icost center prior tO plugging and I ARCO Alaska, Tnc. 56,24% labandonment of this'well Spudded or W.O. begun Date IHour Prior status mi a W.O. I Spudded 8/11/84 I 2200 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 8/22/84 7" @ 8210' 8220', 8127' PB, (0'), RR Cmt 7" csg w/350 sx Class G. CIP @ 0800 hrs 8/21/84. ND BOPE. NU tree & tst to 3000 psi. Released Rig @ 1300 hrs. 8/21/84. Operations suspended - wait on completion rig. Old TD New TD 8220' (8/20/84) Released rig Date PB Depth IK nd of rig RECEIVED o 119 1 Alaska Oil & Gas Cc, nj.. Commission 8127' Anchorage 1300 Hrs. 8/21/84 Rotary Classifications (oil, gas. etc.1 .. Type completion (single, dual, etc.) O-[1 S'[agle Producing method Official reservoir name(s) Flowing Kuparuk Sands - Potential test data Well n,o. Date Reservoir Producing Interval Oil or gas Test time Production Cd on test Gas Der day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity . Allowable Effective date corrected The above is correct Drilling Superintendent ADDENDUM WELL: 2D-8 8/28/8z, Arctic Pak w/41 bbls AS i, followed by 56 bbls Arctic Pak. Drilling Superintendent ' Date Field Kupurak River Auth. or W.O, no. AFE 902101 wws #1 Operator ARCO Alaska, Inc. Well History - Initial Report - Dally liter I will Is spudded or workov~r ol~ratlone ere It~-led. Inclusive dite~ only. Unit Nor[h SloPe Borough ADL #25653 lState Alaska Well no. 29-8 ITitle Completion API 50-029-21158 tARCO WI. Prior status ff a W.O. Spudded or W.O. begun Completion IDate I Hour 9/16/84 Date and depth as of 8:00 a.m. 9/16/84 9/17/84 The above is cor/~lect 0 Signature //I V Complete record for each day reported 56.24% 0630 Hrs. Rn CBL/VDL/GR/CCL/JB f/8127'-5700'. Rn gyro f/8127'-surf. 7" @ 8210' 8127' PBTD, Rn'g 3½" CA Top of perf pkr @ 7833' 10.1+ NaCl/NaBr Accept ri~ @ 0630 hrs, 9/16/84. ND tree, NU & tst BOPE to 3000 psi. RU DA, tst lub to 1000 psi. Perf 7956'-7976' 7938'-7956', 7770'-7780' @ 4 SPF w/4" gun. Perf 77~0'-7798' 7780'-7790' @ 12 SPF w/5" gun. RD DA. Rn 6.125" gage ring/JB to 8072' W-LM. Rn FB-1 perm pkr, set @ 7833'. ND lub. RU & begin rn'g CA. RECEIVED Nov 0 Alaska Oil & Gas Cons. Commission A.chorage 10/04/84 For form preparation and_distribution, -t Drilling Superintendent ARCO Oil and Gas Company Daily Well History- Final Report Inelruclione: Prepare and submit the "Final Re~3rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operationa a~ ~l~3eflded for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report comlMetion and representatl'~-te~t date. in blocks provided..The "Final Repf3rl" form may be used for reporting Ihe entire operation if space is available. District I or Parish Alaska County Field I Lease or Unit Kupurak River Auth. or W.O. no. ~ Title I AFE 902101 North Slope BorOugh ADL #25653 JAccountin cost center code Stale Alaska JWell no. 2D-8 Completion WWS Opera[or ARCO Alaska, Inc. Spudded or W.O. begun Completion Date and depth Complete record for each day reported a'~ of 8:00 a.m_ API 50-029-21158 A.R.Co. W.I. ~'olal number of wells (active or ,nact~ve) on th,s, ~COSt center prior to plugging and 56.24% labandonment of this well Date [Hour IPrior Slatus ,I a W.O. 9/16/84 / 0630 Hrs. I 9/18/84 7" @ 8210' 8127' PBTD, Tbg Tail @ 7852', RR Top of perf pkr @ 7833' Crude oil Rn 254 jts, 3½", 9.3#, J-55 IPC EUE 8RD tbg. N~ BOPE, NU & tst tree to 5000 psi. Displ well w/30 bbls diesel & 270 bbls crude oil. Set BPV. RR @ 0400 hrs, 9/18/84. Crews on stand-by to move rig. Bkr FB-1 perm pkr @ 7833' - "D" Nipple @ 7848' Shear sub @ 7852' Old TO Releasec rig 0400 Hrs. Classifications (oil. gas. etc.) Oil . Produciqg method New TO Date I P8 Depth 8220' (8/20/84) IX~ndo,,,g 9/28/84 I Type completion (single. dual, etc.) single Official reservoir name(s) Flowing Kuparuk Sands Potential '.est data Well no. Date !Reservoir Producing Interval Oil or gas Test time Production 8127' Rotary Pump si. ze. SPM X length Choke s~ze T¸P. :-.P. J Water % 10/04/84 ITM Oil on ;esl Gas per day GOR Gravity Allowable Effective ca;e correcled Drilling Superintendent $ UB-S URFA CE DIRECTIONAL SURVEY F~ UIDANCE ~-~ ONTINUOUS [-~'-~ CO l Company Well Name Field/Location ATLANTIC RICHFIELD CO.HPANY 2D-8 (36' FSL, 429' FEL, S23, T11N, RgE, U.H) KUPARUK. NORTH SLOPE. ALASKA Job Reference No. 69531 Log{led By: BAUMEISTER RECEIVED NOV o ! 1~. nil ~, Gas Cons. commission Anchorage Date 08-0CT-84 Computed By: S. STEVENS N()~,'.q'H ~'51,1.')Pi-;~ AL&,.StcA ~;dlqvE¥ bh'l'l~: I.b-SEF-84 averaqed deVlatlorl cqD,t TARGET AZ I ;.ltJ 1'14 (:' F EAST ARC(") A).,ASKA, IN(].", 2D-B KUPARI. IK NORTH :3L, OPE, AbASKA P. AG~ 1 OA"['M F)F SURV~Y: 15,-$EP,-84 KEI,,I..,)/ BUSHIi'.~G E.bEVATION: 126,00 FT ] b A l R U 'v A l, U t:: 5 [-' 0 H,. t:.: V E P4 1 () 0 F i:: ti.;'iF 0 f' t',,1E A B l.; H E l,:) i.) E P MF. ASIJRVD VERT'fCAI, ¥[:RTIC~L D~VIATIfIN D E P 11t t} 1-.: P '[' H i) i~' P 'r H D E G ~4. 1 I'~ i) I:: G a 1 i; 1000,o¢) 9t17,05 ~71.,().5 i 1 47 1100.0(; 1()94,~5 968,45 1,1 22 1200.0(,~ 1'190.63 1064,63 17 28 1300,00 1285,19 1159,19 20 20 1400,00 I ~7~.'~5 1252,15 22 53 15UO,O0 1469 32 1343,32 25 ]4 1600'0() 155H~44 1.43~ 44 ~g 15 1700,0U 1645,ob 1519.~6 3,.) 12 1800.00 1731.26 1605.26 3Y 10 2000 Ou 1895,47 1'169,-t7 37 32 21Oo:OO !974,~)4 :184H,O4 Ia 33 2200,00 2051,J~ 192b. 3,! ~(~ 14 2300.00 2126.90 2(.)0o. 9() 41 36 2400,00 220U 96 20'14.c~(: 42 54 2500,0U 2273:09 2147,0q 44 "~8 2600.00 2343.9U 2217.9(~ ,t5 1. 2700,00 2414.5b ?2HH.b6 44 55 280n O,J 2485,33 2359,33 "{5 4 2900'0U 2555 95 247,9 ~5 44 5q Vk:teTl(.:Al. l)OGI,kG R,YC'.I'ANGULAR (.:O(:i~tOI~,,:~ATt~,:$ HORII,, DEPARTURE .... TIf]N SEVERITY NC)RTH/S[~UT}~ EAST/wES DIST, FEET 1.)g(;/100 F~:ET FEET FEET DEG MIN 300o.oo 2e, 2~,. b2 25o0.~,2 4% 3 31OO.Ou 2o9'/,42 25'11,42 ,~,1 50 ]2On. 0(, ~7&~, 27 ~6~2.27 44 49 .~400, O0 ?q0g,74 27H3,74 45 IH 350().~0 2t~'19. ~5 2853.95 45 27 3600. (')() ]050.14 2924.1~ 45 20 3'/O0.OU 312,.), 5L 2994.58 4b 9 ]800,00 ~191 .42 30o5.~2 4% ~6 3900.0u 3~61 .'1(, 3135.7t) 4b 36 u 0 N 0,00 O.U() 0.00 (')'01 N (~.06 -(.), 05 (), 30 O, -0,31 0,23 u,()9 N (),35 -0.6! 0,05 0,24 a U,71 -0.74 0,15 ~,q4 fu 0,90 -0,74 0,46 .,76 N U,99 0,54 2.01 1,31 N 0,1~ 5,06 ~,44 1~87 N 4,73 13.58 1.81 3,03 N 13,26 26.36 3,10 5,b6 g 25,~1 44,1,~ 2.94 lO,l.~ i,~ 43,03 66,'14 2,93 15~b6 ;,~ b4,~b q4,05 2,~0 21,72 N 91,63 126.4f~ 2,90 28,0g a 123,36 lb3.1.6 2,79 3b.24 N 1.59,39 204,07 3,22 44,:]2 i~ 199,~6 249.03 2,61 5, 1..29 N 244,,46 29'1.65 2,96 59,99 a 292,58 ]49.3~ 2.25 72,64 N 342.70 404,41 2,b7 86.9,J N 395,9] !~ bd 4 Fi iu()O,,b2 t; 6a 53 P: ~F)71,11 44,22 I'; 76 41. E 66,~i2 N 76 26 E 94,17 N 76 39 E 12b,65 N 76 54 E 163,46 N 77 11 E 204,52 *~ 77 29 E 249,79 N 78 8 E 298,66 N 78 24 E 350,31 N 78 I E 405,36 l~ ~7 36 ~ 2 , 7'1 :! 8 q 2: (.)0 1,75 2,22 1, t7 U.42 O, 71 0.31 1,05 ]Ut) 74 ~ 453,20 E 464,26 I'~ 77 28 E 116 3~ N 513'02 E 526,06 N 77 13 E '135 1~ ~,~ 573 61 g 589,]2 N 76 q4 E 156 39 N 635 57 g 654,53 N 76 10 E 180 41 ~ 698 33 E 721,26 N 75 30 E 206 37 N 762 53 ~ 78q,96 N 74 51 E 233 bO i,4 827 68 E,',860,01 I~ 74 14 E ~60 ~1 N 893 08 E g30,32 ~ 73 43 E 287 15 ~'~ 9h~ 56 k: 1000 64 l~ 73 19 E 313 2~ ~ lo~37 F 1071:20 ~ 72 59 E 0.23 O,2b O. 28 ~).33 t~ . 27 0,47 0.27 1,24 0,26 337.90 N 1oq0.66 301 45 ,~ 1151.2b [:: 1212,40 tv 72 39 E 384~72 14 1223.88 ~': 1282,93 ,I()7,8~ ~ 1290,52 k. 1353.43 ~',{ 72 27 E 43],t)2 N 1357.a6 E 1424,25 N 72 23 E 453.~g .~ 1424,9~ 47b,3t tq 1492.50 498 9~ ,~ 155t, 9b E 1617 b5 N 72 ~6 E 520,2] N 1~27,08 541.9~ .'~ 1~94.'1b K U P fi P, t,! F NOI4'J'ti St,,i')Pti;, CF;~;Pti'!'A'I']()i~ DATE: 5-I.,C"T-841 T R U E 5 I~ b - 5 t<i A C C' t! I~ ,5 ~, aEASIIPI,'I') V~RT'I'¢,'~,I, YER'i'IPAL DEVIA'I'It,~,I DF]PTt,i DE'PTit DIS[.' l'tt DEG Mil',: I') t?, G 400(.i, C.(~ 3.332,26 ..{ 2(~(,. 26 45 4100.Pt) 3403,16 3277,16 44 38 4200,(.>(.) .3474,7~ .334B,78 43 57 4300,00 3547, l.r) 3421.10 43 25 4400.0() 3619,bl 34:93,81 43 32 4500,0o 3692.1~ 3566.18 43 34 4600 O0 3764,~ 36]~,B~ 44 3 4700"0~'~. . 3834.61 3707.61 ' 46 4fi 4800,(,0 3902,97 37'16,97 46 52 4900.0(' 3971.36 3845.3~ 46 46 YE;itTiCAi I)I]GI.~;(.; Rt, CTAN(,;UI.,AR C[,DR[>INATIg,5 HORIZ. DEPARTURE SE:CTI(.'.)I'.~ SYVERIT1 NORTH/fir)t.tTH EAST'i/WESTE' DIST, AZIMUTH t;'gET I)E(.;/IO0 'Fb.:ET ~"g FEET DEG M.IN 1,14 0 ,,, 50 3,23 l O,lO 0.58 5000,00 4,040,o6 391.4, ()fl 45 32 5100, P,,. (3. 410~,,99 .:19~2,99 t4 Il)17 5200.00 417~,17 4:052,17 5300,00 424'1,b6 .4121,ha 4!) 57 ~4()0.()0 4317,12' 4101 ,12 46 24 5500,0() 4384 a2 4258,82 4'1 49 5600,00 4451:9~ 4125,93 47 53 5700.00 4blfl,91 4392,91 47 5800,00 4585,72 4459.'72 5900,00 4652,1b 4526.16 4~ 24 O, 1 t) 0 48 ~m 3,12 O. 09 O. 19 0, .~ fl 0.24 O. 43 6000.00 4718,54 ,tb92,54 4~ 29 6100 0(') 4784 98 4658,9a 48 6200:0{) ,1851:d3 4'125.83 4'1 4'7 6300.00 4919'04 4793.04 47 42 6400. (),.) 49~(>.40 4 BO0..:.tt~ 47 6500.0t) 5053,88 4977.~;a 47 b600.O0 5121 .50 4995,5~- ,~7 'l 6700,00 51fl9.9~ 5('){, 3. g~i 4~ 40 68(;(),0U 525~.~4 5~32.U4 46 b900.O0 5327.~3 5201 ('! 75 13 E 2554.'77 l,,~ 75 5 g 2627.2(, t',, 74 38 E 2699.39 l~.'74 1(, E 2"171,29 N '14 44 E 2843.23 m 77 11 E 2916 74 ~,~7~ 58 E ~990:73 ~ 7fi 48 E 3064,8!~ ,~ 76 34 F 3139,19 i':7o 20 g 3213,~4 0,14 0,67 r) '47 U,16 O, 85 0,95 0.24 O, 56 O, 54 7000.0,) %J9'1. 19 5711.1~ 4_%. 55 7100.()0 54b'1,21 53ql.21 45 13 7200.01) 5537.97 541.1.97 44 42 730(~.00 5609.50 54~ 3.5(-, 4~ 7400,(>0 5682.85 5556.8q 42 7500.C~ 5757 bl 56~1.51 40 7600.00 5833~97 5707,97 3'~ ~4 7700,(~C, 5912,,1U 573b.4u 37 7800.C,~ 5992'5R 5~66.5f; 36 7900.(>0 r~u73.96 5947.96 34 i6 ~ 76 2 E J363.23 r,~ 75 3a E 3437,55 N 75 33 E 3511,55 ~, 75 29 E 35H5.43 :' 7b .3U F. 37t2.77 :',~'/~ 38 E 3805.~6 t, 'lb 21 E 3878,15 e 74 59 F 3950.49 9.53 0,59 1 91 1'.4~ 1 5B 2,13 2,53 1,23 1,82 7,4 30 F 40'2..2.53 73 51 ~. 4093 92 7~ 2.6 [< ,~'164~59 '/3 7 E; '1~34,46 73 47 F ~i3~2.43 75 2a E 4433.38 77 :1 g ,~995.~5 7a 53 F 4554.~3 79 1 3 E, ~612.7~ 5(,4,[2 a. 17~,~2.12 E 1850 58'1.,45. N 1828,66 E 1920 611.28 i~ lb94,27 [~; 1990~ 635,23 N 1959'04 ~ 2059 b59,19 ~ 202~.38 E 2128 ~8~,'77 N ~OSS,59 g 2197 704'29 [',,~ 2153.67 E 2265 724.55 N 2222,20 E 2337 743,3] N 2~92,73 ~; 2410 762,09 N 2363,23 ~;; 24[{3 780.7() N 2433,47 E 2555 63 I,,t 72 12 E 799'19 Iq 2503,52 [~; 2627 99 N 72 17 E ~]8,('.}2 N 2573,23 E 2700 12 N 72 21 E 837,35 N 25~.2 49 E 277~ 98 N 72 25 E ~57,01 N 271~:69 E 2843 90 N 72 27 E S74,3u N 27~3,22 E ~9~7 31 N 72 33 E 890,87 N 2855.47 E 2991 2~ N 72 40 E 9()7.7U N 2927,80 E 3065,28 N 72 46 E 924,88 N 300U,20 E 3139,52 N 72 52 E 942,~9 N 3072,86 f', 3214,12 ~ 72 57 E 96U,23 N 3145.49 g 3288,79 N 73 1 E 978,24 N 3218,02 F 3363 42 N 73 5 E 990,42 N 3290,13 E; 3437~71 N 73 9 E 1014.81 N 33t~1.86 E 351.1,68 N 73 12 E lu33,J2 N 3433 41 E 3585 54 h 73 15 E 1051,91 N 3504~83 f.: 3659:28 N 73 17 E 1070,4/ a 3576.06 E 3732,85 l~ 73 20 k 10D8,70 ~ 364b,68 k 3805,72 N 73 22 E 11()~,77 N 371b 92 ~ 3878,20 N 73 25 f' ) 1125.'3U N 3786179 E 3950,46 N 73 26 E, lt44.21 ;~ 3h56.40 I~' 4022.56 N 73 28 F: Jl6J.bo N 3'~25,¢)9 l:: 4093,95 {,,73 29 E 11fl3.5~ N 3992.89 E 4164,61 ~ 73 29 E 1203.6~ ,~ 4059 75 E 4214.4~ N 73 29 E 1~3 10 N 4124:95 E 4]02.46 ~ 7] 29 ~ 1241' ,4U ~ 41S~,90 f, 436b,98 N 73 29 E 1258,37 N 4251,06 E; 4433,40 N 73 30 E 1273 11 :~ 4311 32 ~ 449~ 3~ ~ 73 32 E 1285:50 ~ 43e9:77 ~' 4554:94 fl 73 36 E 12~6,4~ N 442h,86 k 4612,7~ N 7~ 40 E C[~PL.~TAT[Ot .... [~A'IF.: b-()C'li~~4 PAG~ ~ AR(;(') A[.,A$~A, I!,JC. :2. P - 8 K Il P A l::re U K i~EL, I.,¥ ~USHIN(; EbEVA'I'IO~ 12~,00 FT ~[<A$11R~.:D VFR.I'ICAI, 'VJ.{iRTICAI., DF;VI/~TIOI',~ AZI, aII'I/FI D E P '[' H D E [" T ii D ~ P "i' H D E~ G H ..[ ,~ L., i~. (] ~ 1 ~.~ ViSR'i.'.I'CA[., [) I I ('.; [, t!; G R[';C'I'ANGL~I,A[,: CL'~ORL.)Ii,IA'£E,S HOR~IZ,, DEPARTURE S[{:CTT(..I.~ SEVERITY ~'~O~TH/SO!.ITIt EAST/WE~T [')IST~ AZINUTH t.;'E~..:T 10~:(;I 1 O0 F~£~.:'I~ ~'t~:1.' I~ EET DEG NJLN 8000.OU 61b~),gU 603('.), 9U 33 7 8100 no 6241,45 6115,4.5 31 56 8200:00 6326.31 ~2()(;, 31 31 56 8220.00 6343,28 6217.28 31 56 1,; 7g 38 Ii: q77.1,47 h 79 3~ E ,4784,61 . () 0 0,00 (.) :, i)0 CLiI~PI, ['AT] Of t,,)ATt: 5-C'CT-f~4 PAGE 4 A~(.'.C'I A[,ASKA, INC, 2I~-8 I<i.j p A ~lJt.( ~'~lt.]t~l.'t..t ,.'S i., [) P I< ,, AL, ASK A I')A'.l.'t".~ i.}[.,' SbiqVEY: 15-SEP-84 KLL,},~' t-..,,OL-;H!a(; I-,L, EVATIJ]NJ 12b, 0.0 FT M E A ,~ U R F t> V E R T I C' A L ',/E R 'r I ¢' A I., D Fi' V I A 'C t 0 N A Z 1' 1,4 ~ .'.'1' t.~ D k. l- ']. h D E '1' J i I'> ~.. P T ~t D E G M [ r..~ b E: ('~ ~,~! I O. O0 O, (,lO - 126, O0 O 0 1000.00 997.05 g"ll ,05 11 47 200() {,'~O 1895~47 1769,47 37 32 3000]00 2626~62 2500,62 45 '~ 4000' OU 3332,26 3206,26 45 0 5000,00 4040,06 ,"~914.06 46 32 6000.00 42~B,54 4592.54 4B 28 TO00,OC, 5'397,1 q 5271'19 45 55 8000,0() 6156,~0 60,10 90 33 7 9220,00 6343,2a 6212~2~ ~1 56 O, O0 2,94 2,77 ,99 O, :14 0,60 2,(.)9 0,00 0,00 i~ 0,00 k 0 10.18 N 4],0] E 44 100,74 i~ 45],20 E 464 337 96 l:,J 3090,66 E 1141 564 12 k 1762~12 E 1~50 780 70 N 24,]3,47 [{; 2555 9~0 2,J /,1 ~1~5,49 E 3288 1144 21 N 3856,4() F. 4022 1306 71 N 44,81,75 E 4668 1397 73 N ~596,72 E 4784 ARCO ALA~,KA, INC. 2D- ~ KUPAR{IK NOR"I"H 515(~Pti:. A£,AS~A MEA~I.)HFI'> VERTICAL VERI.'iCt%I: I')EVI IDA'[E: E~GINEER: bAi,JNEISTER I~'IEt~P~)I.,ATEb VA.L, bF.S r'Oi'~ l=vEr~ 1uO kEt,'.[' IlF 5LJL~-&~A V k.R]..' 1 CAI, iS~.lG LEG RECTAN(iUbAR CO[]kDINATE& SEC'FI, UN 5H:VERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEk, T {>E~/100 FiEf ~'~,:~,,'1' F['.~T DEG MIN O, 00 0 ,, OO ' 12 b, UO 26,00 26, ()() '1()0,00 126.0(; 126.()0 U.O0 75 23 E 30.7..%.' 2.f',9 '15 51 F~ 50°42 1 76 56 E 75,0H 3,05 77 37 E ~05.55 3.18 78 9 E 142.02 2,23 78 30 L 1~3.96 4.1.8 fll 28 F 232,Ug 2,68 7H 45 ~, 2~6.34 2,80 74 48 E 346,04 75 38 E /12,27 2,95 226. O0 226. ()0 1 ~)(). 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SLOPE;, ALA.,51*A PAGE 6 4833,69 3926.U0 3800 O0 46 52 4979.55 4026.00 3900:00 46 33 5124,bl 4126, U(.; 40~.iCt. 00 46 13 526~.~5 4220.0(.) 4100,00 45 54 5q12,90 432,',. O0 4200.00 46 41 5561.3q 4426,()0 4300.00 47 50 5710,5~ 4526,00 4q~o,O0 47 58 5860.6f) 4626,o0 45()(~. 00 48 24 6011,25 4726,00 46t)0,00 48 27 6161.45 4826'00 4700.00 48 2 126.0.0 FT 749 (}5 6] 231.6 49 ~, 2~34 '1'1691 N'~42.191! E 2540 8(.)5 'ld ~ 252070 E 2645 83127 f~ 262095 F 2749 85945 [~ 2720 72 g 2853 88442 N 2827 53 E: 296 24 N 72 28 g 63 N72 37 g 6310.33 4926.00 480(),0~, 4'1 40 6458.74. 502 (,?, 0 () 49 ()t.). 0 (,', ,I 7 ~t 3 6606.5 ]. 5126. flO 5000. O0 47 4 6762,41 522t, O0 51U(),0~ 46 25 6897,21 5326:00 52o0,00 46 14 7041,32 5426,U0 93u0,0C, 45 37 7~83.14 5526.00 5400.(')0 44 46 7322,60 5626,0(.~ 550(;,()0 4t 8 7458,0e 5'126' O0 5600. t)() 41 ]7 7589,06 582~,00 5700.00 39 25 0,19 O, 49 0~44 0,28 0,35 0,25 0.86 7717.0~J 592b.Ot', 58t;0,0(,) 37 12 7841.27 602~.00 5900.00 35 40 7962,90 6120,00 60()(). 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T k L, V A L ti lC :5 [' L) k C t"t t} 5 l"i I'.~ ' "' MEA$1~RF, i) !~F:PTrt 7'7 b7, ('10 '1 '194, 0 0 i~ 127, ()f) 8220,00 "' 429' (.J 1~ .,1.. L; 1. I',, = 31)~ T V [) [~ i;gtJ[u', ]'.Lt ~!,J b,-'~}[i:/~, 59h5,99 5839.99 5987,74 5961,,74 607(~,6'1 5944,67 ~I~8.85 6062.85 64..~6 6138,36 6343,28 6217,28 8 U RI"'ACE bOCATIUN FI:.[,, SEC 2~1. TIIN ~9Em UM R~YCTAI~GUI,~AR COORDI~A.ES No~'rH/SOUTtt EA~I~LST 1294.81 N 30 [ 1295.99 N 4424 6] g 1310,42 N 4501 98 E 1927:73 N ~596 72 E ~RCLT, AbASKA~ I)'~C,, 2f)- B KIJPAi~t)K ~ARKI~R RASE LOWER SAND P B T [) TOTAI~ I)EPTH 5 "' 0 ('. :1' .,, ~t 4. SU[{FACE hOCATION AT FEL, S~C 23. TI1N R~E, OM .E',CTANGULAR COORDInATeS N(]k'fFt/SO[JT~ gAST/~EST , 1284,81 N 30 g 1318,89 ~ 4548 32 E 1327,73 N 4596 72 E 5955,9!:) 5gfl7.74 6070.6 '1 61a8.85 ~, 264,3 b 5839,99 5861'74 5944.67 6062.85 61.38.36 6217,28 [') .J.:: P T H 8 22 O, 0 U v ER']' 1. 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' ...... ~'"'=?"1''~'''''''-r-=''-~''';'''''''''~''i-+''~'-~-'~ .....J '-:'"?'i''~''''?'': .....1~ ?'"'?'"=:'"i''-:-?'-''''-''~ .... -2000 - 1000 0 1000 2000 =1000 4000 SO00 EAST Suggested form to be inserted in each "Active" well folder to d:eck for timely ccmpliance with our regulations. · ' - Operat6r, wei 1' Name and Number Reports and Materials to be received by: Date Required. Date Received Remarks · Completion Report Yes .. ! Well History Yes //--0/'--~¢ "~'/~=' - ' ,, · ~ , · · · _S~es ~/x -PI .... O/~ .. . _- . Core Chips -' /,.~/j/.¢.~, ~._ · Core Description .~ ;~,,f~ .~'- ""¢.5~ Registered Survey Plat T.~ /~___ // __~::~ ~ .... --. Inclination Survey ~/~ Directional Survey yC~--~] Drill__Stem Test Reports ~/~ ,/~. _. ~. ~. -, ARCO Alaska, Ir Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29-, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached is our notice of intention to perforate Kuparuk Field well 2D-8. If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (in Triplicate) £CEI v£b 41aska 0il & Gas Con- AnChorage' Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL i-IX OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 36' FSL, 429' FEL, SEC. 23, T11N, R9E, UM BOTTOMHOLE LOCATION. 1387' FSL, 1088' FEL, SEC. 24, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 126 ' (RKB) 6. Lease Designation and Serial No. ADL 25653 7. Permit No. 84-127 8. APl Number 50- 029-21158 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-8 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOl 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 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). Per telephone conversation wit'h AOGCC(Jim Trimble), it is proposed that the "A" sand in Kuparuk well 2D-8 be re-perforated. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. Proposed Intervals (MD)- 7938-7984' (4 SPF) ANTICIPATED START DATE- October 27, 1984 RECEIVED OCT 2 91984 ~qlaska Oil &.~aS~nchoran,,Cons. Conlmission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .... Title OPERATI ONS COORD I NATOR The space below for Commission use Date 10/29/84 Conditions of Approval, if any: Approved by , '! · Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska" :-.:. f:.~:-.:- E::> 36f Anchorag£. Alaska 99510 'T,. ~!(-pbonr 907 277 5637 Date: 9/05/84 Transmittal No: 4713 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 itted herewith are the following items. Please acknowledge receipt turn one signed copy of this transmittal. OH LIS/Schlumberger #69485 8/24/84 Run 1 2780 - 7700.5 2G-4/ #69484 8/22/84 " 2720 - 6953.5 2B-2 / #69468 8/20/84 " 3745 - 8189 2D-8~' /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D&M Dzilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Union Well Files ARCO Alaska, I, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska~' 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2G-2 1L-5 2D-9 2B-3 2G-3 1L-6 2D-8 2B-2 2G-4 1L-7 2D-7 2B-1 Thank you. Sincerely, JBK: ih LO1 06/28/84 Enclosures "-" STATE OF ALASKA -~ ALASK~_ OIL AND GAS CONSERVATION ~_,MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-127 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21158 9. Unit or Lease Name 36' FSL, 429' FEL, Sec. 23, TllN, R9E, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in feet (indicate KB, DF, etc.) Pad 89, RKB 126 6. Lease Designation and Serial No. ADL 25653 ALK 2579 10. Well No. 2D-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of August ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well @ 2200 hrs 08/11/84. Drld 12-1/4" hole to 3774'. csg. Performed top' job. Drld 8½" hole to 7734'. Ran logs. as of 8/20/84. Ran, cmtd & tstd 7" csg. Secured well and 8/21/84. Ran, cmtd & tstd 9-5/8" Drld 8½" hole to 8220' TD released rig @ 1300 hrs, 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36#'J-55 HF-ERW BTC csg w/shoe @ 3753' cmtd w/1090 sxs AS III & 700 sxs class "G". 7" 26# J-55 BTC csg w/shoe @8210'. Cmtd w/350 sxs class "G". 14~/oz~ng resume and brief description GR/CNL/F/8113 ' -3753 ' CAL/F/8167'-6500' 6~ff data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~~,~~z/-f~ T,~,~rea Drilling Engineer //z~,~ SIGNED/~////' /_~g,,¥/x,,r,~,~,_-/.?r~,,~/-, , ...... DATE-7~-/ _ N OTE--Repo~o~/~rm is required for each calendar month, regardless of the status of operations, and must be filed'in/duplicate with the Alaska Oil and Gas Conserva~on Commission by the 15th of the succeeding month, unless otherwise directed. ~nrm 1R~Q~ Submit in duplicate MEMORANDUM TO: FROM: Sta e of Alaska ALASKA OIL" AI~D GAS CONSERVATION CO}~ISSION C. V.~~'t~rton' ')/~] DATE: September 10, 1984 Lo~ie C, Smith t~ Co~ s s loner ~ FILE NO: D. 41 o 35 TELEPHONE NO: Doug Petroleum Inspector SUBJECT: Witness BOP Test at ARCO' s Kup 2D-8 Well, Sec. 24, TllN,RgE,UM, Permit No. 84-127 on Parker Rig No. 191. ~Tu_epday, August 14, 1984: After witnessing the BOP test on Rowan Rig No. 35' I tra~e'iad ~o ARCO Kup. 2D-8 well to stand by for the BOP test there. Wednesday, August 15, 1984: The BOP test commenced at 8:30 am and {~as cO~eiuded at 2:'00 pm. The upper pipe rams failed during this test. %"ne pipe rams were replaced and retested. I filled out an AOGCC BOP test report which is attached. In summary, t witnessed the BOP test at ARCO's Kup. 2D-8 well. Attachment 02-00IA(Rev. 10179) STATE OF .ALASKA ,'ALASKA OiL & GAS CONSERVATION. COMMISSION BiO.P E. InspeCtion Report Inspector ~,~9 l~ 0 ~_ Operator ~ I ' · Well ~o, ~__f) --~ LOcation: .Sec 'g ¢ Ti~D R~ Drilling Contractor ~v~ ,~_~v~ Date Wel 1 zD - ~ Representative ~ , .~ _/-~/~___,_~ erm t #' 'l?---J ~/~ .Casing Set @ ~~ ft. RepreSentativ~ ~ ; .~__1 Location, General Well Sign General Housekeeping ._.._ Reserve pit · ... Rig .. . . . . ~ BoPE Stack Annular Preventer. Pipe Rams Blind 'Rams ' ~ Choke Line Val v~sO// ~ Kill' Line val ve~ Check Valve' J' Test Pres sure %1 Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure. .~7 00~ psig · Pressure After Closure /~O psig 200 psig Above Precl]arge Attained: Full Charge Pressure Attained: ~ · N2 ~kP~D;'jT~ I' J~l~9~% J~.ZIOO psig Controls: ~aster ~ Remote 'O~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly /·4Test Pressure Lower Kelly I ~est Pressure ~ ~00 Ball Type ~'"1 Test Pressure Inside BOP ~ I Test Pres sure Choke Manifold ~ ~Test Pressure __min 4l sec min 0-7 sec NO. Valves j 5 NO. flanges ~-- ~ Adjustable Chokes Hydrauically operated choke Test Time ~ hfs ~ Repair or Replacement of failed equipment to be made within days and Inspector/Commission office notified. . Distribution orig' - AO&GCC - cc cc - Operator - SuPervisor Inspector July 31, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2D-8 ARCO Alaska, Inc. Permit No. 84-127 Sur. Loc. 36'FSL, 429'FEL, Sec. 23, TllN, R9E, UM. Btmhole Loc. 1387'FSL, 1088'FEL, Sec. 24, TllN, R9E, ~. 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 containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified-as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior 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, A~ticle 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. .Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid~us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention ~-~r. Jeffrey B Kewin Kuoa~k. River th~it ~° D-8 '2- July 31, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, o!ease also notify this office 24 hours prior to commencing ~quipment 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 yours, I/ !/' I/ ;-.- Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~IISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. ARCO Alaska, Inc. ~ ' Post Office B(~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-8 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2D-8, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on August 11, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/JG/tw RECEIVED JUL2 5 GRU8/L65 Attachments Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany · '~ STATE OF ALASKA ALASKA ~,,L AND GAS CONSERVATION CO,¢IMISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 36' FSL, 429' FEL, Sec.23, TllN, R9E, UM At top of proposed producing interval 1291' FSL, 1418' FEL, Sec. 24, TllN, RgE, UM At total depth 1387' FSL, 1088' FEL, Sec. 24, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 126', PAD 89' ADL 25653 ALK 2579 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name ~ Kuparuk River Unit 10. Well number 2D-8 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1088' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8132' MD, 6267' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 44 Ol(see2OAAC25.035(c) (2) 15. Distance to nearest drilling or completed 2D-9 well 550' ~ surface feet 18. Approximate spud date 08/11/84 2810 psig@___8_0°F Surface 3153 _psig@ 612:3 ft. TD (TVD) 21 I Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT i SIZE i Hole Casing 124" 16" il 2-1/4" 9-5/8" [8-1/2" 7" Weight 62.5# 36.0# 26.0# 22. Describe proposed program: CASING AND LINER ~ Grade Coupling Length H-40 [WelI 80' J-SS I"TC/ I/ "-ss I H -E W I / MD TOP TVD 36' I 36' 36' I 36' I I I 35' I 35' MD BOTTOM TVD 1161 116' 3799'I 3146' I 8132'1 6267' I I (include stage data) ± 200 cf 1090 sx AS Ill & 700 sx Class G 400 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8132' MD (6267' 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 3799' 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 2810 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 hereby certi/~ that the foregoing is true and correct to the best of my knowledge 7/ SIGNED /~/J.~,f,¢~,~. ~~'~ TITLE Area Drilling Engineer The space.,~'o~$~'r~/~iss~use CONDITIONS OF APPROVAL DATE Samples required I~YES []~O Permit number APPROVED BY Form 10-40t _ . --_ I Mud Icg required Directional Survey required I APl number [~YES J~NO ~-Y E S []NO Approval date .:,_,,; Y ~,/" ~v~~'~,*~'~/ by order of the Commission GRU8/PD33 s Submit in triplicate PERMIT TO DRILL 2D-8 installed and tested upon completion of the job. 2D-8 will be the fifth well drilled on the pad. It is 550' away from 2D-9 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 6638'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. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JUL251, Alaska Oil & Gas Cons. commission Anchorage m Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify Ehat 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 JUL2 IgB4 Alaska Oil 8, Gas Cons. Commission Anchorage 9 ' PIPE 8 DIAGRAM ~.1 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 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" -.5000 psi annular BLIND ' ~ ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC F1. 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 MAJtIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEIU). RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND VJsJ~'V'ES UI~ST1RJ~/IjVi O1~ C~-IC)KES. DON'~T TBST '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 8. ~~'?RBSSbY~E DOWNS~IiRBAM OP CHOKB ISOIATION I~.ALV~S.. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLP.VALVES, I~ ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9.OPEN TOP SET O~ PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD [OR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BO~70M SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT O[ HOLE. CLOSE BLIND RAMS AND TEST TO 2000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P,~4S 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. 1~. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLE'TE 80PE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUL 2 5 Alaska Oil & Gas Cons, Commission Anchora.qe 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 Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 2D Pad - Wells 5-12 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU8/L24 Enclosure Oil ,'.~, Gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~ ---- i i · DRIL._ :SITE Z-D CONDUCTORS AS -BUILT LOC~TIONS , w~.L .... -- II I ' _ y~5,954,367.102 LaC. 70°17'£I X- 529,214.1642 Long. 14-9°45'48.797' 168 FSL 550 FEL EL. 88.8' .O.G. 79.4' %,~ELL 6 y~5,954,323.069 Lat. 70°!7 '~0 F~ 529,254.7648 Long. i4-~ 45'47.618" 124 FSf, 510 FEL ZL. 88.7' O.G. 79. ~LL 7 D. 5,954,279.047 Lat. 70o17'10.1766' X-' 529,295.2738 Long. 149045,46.443" 80 FSL 470 FEL EL. 88.6' O.O- 79.3' ~ELL $ )~,,5,~G,234.884 Lat. 70°17 '09. 7407" ~,. 529,335.9398 Long. i49°45'45'263" 36 FSI, 429 FEL .~L. 88.5' O.G. 79.2' WELL 9 .F..5,~53,830.605 Lat. 70017,05.7498" ~ 529,708.4131 Long. 149045'34-458' ~ 9~ ~0 ~ 59 ~& ~L. ~9.0 O.C. 83. ~LL 10 ~5 953,786 478 ~c. 7~17'05.3143" X- '529,749~0452 ~ng. 14~45'33.27~" Y-5 953,7~.418c ~C. 7~17'04.8793" ~ '~ 7 9 6305 ~ng ~4~ 45'32.102" ~ ,,_,_8_. ~L ~L 89 O' O.G. S3.3' 458 ~L ~2 . · ~LL 12 ~5,953,698 .is3 Lac. 7~17'04.4426" X- 52g,$~.3077 ~ng. I4~45'30.922' CE~T1FY THAT I AM P~o~Y ~ ~~ICE LAND SURVEYIN~ IN THE ~ATE 0F ~~ SU~VISION a THAT G$.2D : ' :': .', 4: " " " 185SIIE AE iosko, I n¢, Kuparul~ Project Norttt Sto~e Oritjiru: DRILL SITE Z.D ~NDUCTOR AS.BUILT ~ATIONS rte: JUIIEg,I~84 ~.¢ale: 1'=400' -. (2) Loc (3) Admi~ (.~.~ (g thru 11) '(10 and (4) Casg (i2 thru 20) me '. Company ~a:i Lease &/Well No. YES NO (21 thru 24) Is the permit fee attached .......................................... Is well to be. located in a defined pool ............................. Is well located proper distance, from property line .................. ~ Is well lodated 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 ............... L 7. Is.operator the only affected party ................................ '.~ 8. Can permit be approved before ten-day'wait .......................... { REMARKS 9. Does operator have a bond in force .................................. ~ 10. Is a conservation order needed .................................. · .... -~ ~ 11o . 12. 13'. 14. 15. 16. '17. 18. 19. 20. 21. 22. 23. 24. Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ..... ' Will cement tie in surface and intermediate or production strings .'. Will cement cover all known productive horizons ..................... Will surface casing protect fresh.water zones ...... Will all casing give adequate safety in Collapse,'tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment proCedure included on 10-403 .......... Is adequate well bore separation proposed ................ ' ......... Is a diverter system required .................... ......... Are necessary diagrams of.' diverter 'and BOP equipm~n~'attached psig' Does BOPE have sufficient pressure rating - Test to ~~ Does the choke manifold comPly w/API RP-53 (Feb. 78) ................ (6) Add: /0~'//{/ ?-gl~-~ f 25 Addit iq ' · ional r uirements ............................................ Additional Remarks: Geology: Engineering: WVA~ JKT~HJH~-~ JAL rev: 12/08/83 6. CKLT INITIAL GEO. UNIT dN/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. · · .... $CHLUffiBERGER ..... -~ LXS TAPE YERZF]:CAT']EON LZS, TZNG LVP OIO.HO2 VERIFICATION LISTING PAGE ',~ATE :84/08/30 ORIGIN : REEL CONTINUATION # :01 PREVIOLIS REEL : COMMENTS ~, TAPE MEAOER ** SERVICE NAME :EOIT DATE :84/08/30 ORIGIN :O000 TAPE NAME :9468 CONTINUATION # :01 PR~¥IOUS TAPE : ** FILE HERDER FILE NAME :EDIT .001 SERVICE NA'ME : VERSION # : ,~ATE : MAXIMUM LENGTH : lOZZ~ FILE TYPE PR1EV IOUS FILE : ::I,:, INFORMATION RECOROS '"*~: MNF_M CONTENTS CN : ARCO ALASKA INC WN : 20,-8 FN : KUPARUK RANG: 9E TOWN: 11N SECT: 23 COUN: N,. SLOPE ST AT: AL it SKA' CT~RY: USA .** CDMMENT$ ** 000 000 016 O6S BO0 000 004 065' 000 000 008 065 000 000 OOg 065 000 000 00~ 065 000 OOO OOZ 065 000 000 012 065 000 000 006 065, 000 000 003 055 : $ CML,UMB ERGE'R : ~'-'"]~ ~ 1~ lin'm1 ,iQ i[~ [:-¥.mm LVP OZO.HO2 VERIFICATION LISTING PAGE ALASKA DIVISION COMPUTING CENTER COMPANY = ~0 ALASKA INC ~ELL ~,"'~Z~' FIELD COUNTY = N.SLOPE STATE : ALASK SECTION = 23 TOWNSHIP RANGE = 9E TAPE DENSITY = 800 BPZ BDTTDH LOG I~r~RVAL = 8160 FT. TOP LOG I'NTERVAL = 3754 FT. CASING-LOGGER = 9.625 .~No @ 375,~ FT. 'BIT SIZE = 8.50'0 IN. 'TYPE HOLE PLUIO = X-~ POLYH~R DENSITY = 1.0..00 V~SCgS~TY = ==:~ LVP OZO.HO2 VERIFICATION LISTING PAGE 3 PM = 10. O0 FLUID, LOSS -- 7.60 RM ~ MEAS. TEMP. = 5.170 @ 50 F RMF ,g MEAS. TEMP. = 5.660 g 50 F RMC ~ ME~S. TEMP. = 3°660 · 50 F RM '~ BflT = 1.938 ~ 1~5 F LDP: T ~ALSTEAD ** DATA FORMAT RECORO ENTRY i3LOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 ~ 1 66 1 8 4, 73 60 9 ~ 65 .liN 16 ' I 66 0 I 66 0 DATUM SPECIFICATION BLOCKS M'NEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR ID ORDER J LOG TYPE CLASS DEPT FT O0 000 O0 SFLU OIL OHMM O0 220 01 ILD OIL OHMM O0 120 46 ILM OIL OHNM 0,0 XZO .~ SP DIL MV O0 010 O1 GR OIL GAPI O0 310 01 GR FON GAPI 00" 310 CALI FO'N IN O0 280 01 ,RHOB FDN G/C3 0:0 35'0 02 D.RHO FDN G/C3 'OD 356 01 N P M I ,F 0 N P'U 0 O: 8 0 00 NC~L FON CPS O0 330 FC~L FON CPS O0 330' ',: 30 PRgCESS CODE (OCTAL) 68 O.O0000000gO000 68 O0000OO0000000 68 000000-00000000 68 00000000000000 6,8 O00.OOO00000000 68 00000000000000 68 O00O'O000000000 68 O0000:O000'O000O 68, 0000'0000000000 68 00000000000000 68 00000000000000 68 O00O'O00OO0000O 68 000.00'000000000 68 00000000000000 68 00000'000000000 DATA DEPT SP RHOB NP H I 8189. 0000 SF'LU '1:~° 9'7,66 'GI~ :,,: '-99 9,. 2500 OR,HO - 99 9' 2500 NCNL: 3.0254 ,ILO -999'250'0 NRAT '-999'2500 ~'CNL 2.5625 ILM 3~.68'75 CALI -999..2500 RNR~ - 99'9. Z5 00 2.5313 8.5000 -993.2500 L"~ ~ lmliil LVP 010.HO2 VERIFICATION LISTING PAGE DEPT sP DEPT SP RH~B SP RHDB SP RHOB NPHI DEPT sp RHDB NPHI DEPT SP RHDB NPflI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT sP RHDB NPHI OEPT SP RHOB DEPT sP RHDB NPHI 8100.0000 SFLU -18.0156 GR 2.316~ DRHO · Z.3828 flCNL 8000.0000 SFLU -30.0000 ~R Z.4570 DRHO 32.91'02 NCNL 7900.0000 SFLU -30.4844 GR Z.4473 DRHO 31.2988 NCNL 7800.0000 SFLU -3~.0000 GR Z.4063 DRHO 3Z.3730 NCNL 7700. 0000 SFLU -33.5000 FaR 2. 5703 ORHO 44. 3359 NC:NL 7600.00.00 SFLUr -36.Z500 GR 2.3477 OR'NO 42.7734 NCNL 7500.0000 SFL'U -37.0000 GR -999.2500 DRHO 37.9883 NCNL 7~00.0000 SFLU -36.5313 GR __999' Z'SO0 O'RHO 999 . ,2500 N C N L 7300.0000 SFLU -999°2500 DRHO -999.2500NCNL 7200.0000 SFLU -46.7500 GR -999o~25009RH0 -gggog500 NCNL 7100.0000 SFLU -999.25'00 ORHO -999.2500 NCNL 2.3770 ILO 100.7500 GR 9.1187 NRAT 1879.0000 FCNL 5.6719 ELD 84.3750 5R 0.0679 NRAT 2388.0000 FCNL 5.7930 ILD 83.6,875 GR 0.0469 NRAT 2538.0000 FCNL 6.6992 ILO 90.5000 GR 0.0308 NRAT 2534.0000 FCNL 1.6934 ILO 115.3750 GR 0.01~6 NRAT 1957o0000 FCNL 3.2988 1LD 152.750.0 5R 0'0435 NRAT ZOOa. O000 FCNL 3.2031 iLO 217°,0000 GR -9'99.2500 NRAT -999'2500 FCNL Z" 9961 Z43,. 1Z50 3.6895 ILD 1~9,'7500 G:R -999. Z500 NRAT -999'2500 FCNL 7°6523 102.9375 GR -999.25~0 NR:AT -999.2500 FC'NL 3o.9355 [LD GR ~RRT -999.Z500 FCNL 2.1523 100.7500 3.6387 521.5000 4.4844 B4.3750 2.9570 769.0000 5.0Z73 83.6875 Z. 8496 963.0000 '7.1250 90.~000 2.9277 836.0000 1.5039 115' 3'750 3.5586 563.0000 2.8&91 152.7500 3.54,49 533.000'0 2.~766 217.0000 -999.2500 -@99..2500 243.1250 -999'Z500 -999.2500 3.3555 149-7500 -999.2500 -999-2500 4. 9961 ,102. 9375 -999,.2500 -999.2500 3.4336 135.2.5 O0 · -999. 2500 -999. Z500 CALl RNRA ILM CALI RNRA ILM CALI RNRA ILM CALI RNRA ILM CALI ~NRA ILM CALI RNRA ILM CALI RNR~ Il) CALI RNRA ILM CALl RNRA I L M CALI RNRA ILM CALI RNRA 2-2617 10.3437 3.5016 ~.~648 8.7813 3.1094 5.1055 8.7734 2.945~ 6.7930 8.$437 3.0293 1.5996 8.4609 3.~746 2.8984 9.3125 3.,'76S6 2.5859 g.578! --999. ZSO0 Z.5449 -999-250.0 3. ~Z38 10 ,. 7"10'9 -999. Z500 4,.7969 10.3435 -ggg..ZSO0 3,. ~2:38 9. 343,8 -'999. 2500 LVP 010-HOZ VERIFICA?ION LIS'TING PAGE 5 DEPT 7000.0000 SFLU SP -38.2500 GR' RHOB -999.2500 DRHO NPHI -999.2500 NCNL DEPT 6900.0000 SFLU SP -¢8.0000 GR RH3B -999,..2500 DRHO flPHl -999,. 2500 NCflL DEPT 6800.0000 SFLU SP -54°2500 GR RH38 -999.Z500 DRHO NPH! -999.2500 NCNL DEPT 6?00°0000 SFLU SP -55.7188 GR. RHDB -999oZ500 DRHO. NPHI -999. Z5'00 NCNL. ~EPT 6500.0000 SFLU SP -4Z.5000 GR ~HOB -999.Z500 ORHO NPHI -999.2500 N'CNL OEPT 6500.0000 SFLU SP -55°7500 GR RHOB -999.250'0 DRHO NPH[ -99'9.'Z5!'00- NCNL OEPT 6~O0.O000SFLU, SP -49.2500 gR ~HOB -999.ZS00 DRH-O NPHI -99'9.2500 NCNL D'EPT SP RHOB DEPT SP RHOB NPHI 9EPT S,P 'RH OB NPHI OEPT SP eHOB 6'30.0.0000 SFL'U _'~66o50:00 99.250,0 OR~O '9'99'Z500 NCNL 6ZO0. O000, SFLU -5~.0000 GR ~.3672 ILO 13~.5000 GR -999.2500 NRAT -999.Z500 FCNL 3.9590 ILD 140.1259 GR -999°2500 NRRT -999.2500 FCNL &.1836 ILD 1ZB..3750 -999.250.0 NRAT -999oZ500 FCNL 4.2539 IL9 177o7500 GR -999°2500 NR.AT -999o2500 FCNL 3°5664 ILO 19~.0000 GR -999.2500 NRAT -999. Z500 FCNL ~..16~1 ILD 22B.7500 GR -999.2500 NRAT -999.2500 F'CNL 75'00 GR -999' ZSO0 NRAT -99'9.2500 FCNL 5.48,~4 500 ILD ,GR, NR,AT FCNL 104o125.0 6100.0000 SFLU Z,,. 9102 TLO -&g-is:00: G-R 93.5000: GR. '- 9'99. ZSO0 DRHO -'99~. Z 500 NRAT - 99 9,. ZS,OO NCNL ~. -999'Z500: F'CNL 6000.0000, SF:LiU -53'78130R -999.2500 : Z'8~39:8 ILO t :1 '4.2500 G R -999'2500 NRAT 2°9980 ILM 13~.$000 CALI -999.2500 RNRA -999. Z500 3.701Z [LM 140-1250 CALI -999.2500 ~NRA -999. Z500 4.~8,~¢ ILM 128.3750 CALI -999°2500 RNRA -999.2500 3.5801 177.T500 CALI* -999.Z500 RNRA -999. Z500 2.8008 ILM 19~.0000 CALI -999. Z500 RNRA -999°2500 ZZB.?500 CAL! -99'9.2500 RNRA 2.2500 ZLM 96.7500 CALl -999.2500 RNRA -999.2500 3. 9238 ILM 13:1.2:5.0:0: CALI -999.2.500 RNR,A -999.2500 ILM CALl ,-99:9'Z500, RN'RA -999.2500 3.0176 ILM 93 o '5000 C AL I -999.2500 ~NR,A - g 9-9, 2:500 . 2,, 9.199': ILM 11 '4.2 $ 00 'C A L 'I -999. 2500 RNRA 3.~023 9.Z891 -999.2500 3.7070 10.B984 -999oZ50~ 4. ~063 1/L.1406 -999.Z500 3.5977 10.1875 -999. Z 500 2.8848 9.0156 -999.2500 4.1094 9o7109 -999.2500 2.3301 -999. Z500 4.0430 2.3184 -99'9.2.500' 3.5,3:9I 2.3105 -99*3. gSO0 Zo 9395 2,.3223 -999. Z 50..0 2.8867, 2.3154 - 9.99 ° 2 500: LVP 010.HOZ VERIFICAIlON LISTING PAGE NPHI -999.2500 NCNL -99).2500 FC~L DEPT 5900.0000 SFLU SP -53.0000 GRI RH3B -999.2500 ORHO NPH! -999.2500 NCNL 2.2520 ILO 91.8125 ~R -993.2500 NRAT -999.2500 FCNL OEPT 5800.0000 SFLU SP -53. 0000 ~R EHDB -999. 2500 DRHO NPHI -999.2500 NCNL 2.015'6 ILO 126.$000 ~R -999.2500 NRAT -999°2500 FCNL DEPT 5700,.,0000 SFLU SP -49.7500 GR ~H'3B -999.2500 DRHO NP. HI -999.2500 NCNL' 2.3516 ILD 105.3125 GR -999.2500 NRAT -999°2500 FCNL OEPT 5600.0000 SFLU SP -~7.7188 GR RHOB -999.2500 DRHO NPHI -999. Z50§ NCNL 2.37S0 ILD 87.9375 GR -999.2500 NRAT -999°2500 FCNL DEPT 550,0.0'0 O.O SFLU. SP -5 t., 000'0 GR RHOB -999.2500 O'RflG NPHI -999.2500 NCNL 2..5410 ILD 99.06:2.5 GR -999.2500 NRAT -999.2500 FCNL DEPT 5~00.0000 SFLU SP -49.5313 GR RHDB -999o250.0 DRHO NPHI -999o2500 NCNL 96.9375 GR -999,.2500 ~tRAT -999.2500. FCNL DEPT 5300.000-0 SFLU SP -50.7813 GR RHOB -999.2500 DRH.O NPHI -999.2500 NCNL Z.7~61 IL~ 96-7500 GR -999.2500 NRAT --999*2500 FCNL OEPT 5Z00.0000 SFLU SP -53,2187 GR RHDB -99'9.'2500 ORHO NPHI -'999o250'0 NCNL Z,o 355 $ ,' !:L 0 B 3.8125 GR - 999' 2 500 ~RAT -999.2500 FCNL DEPT 5P NPHI 5tO0, O000 SFLU -'53':28~3~ GR 2..443,4 [LD 9,5"9375 GR -999.2500 NRAT -999°2500 FC:NL. DEP'T SP RH~B NPHI 5000.0000~ SFLU -55.2500 GR -999.250,0 : DRHO -999°2500 NCNL 2.,aOOB I.LD 103.9375 GR --999'2500 N, RAT -999°2500 FCNL OEPT SP 4900.0000 SI=LU 5313: GR 'Z.3457 ILO 93,. 0;0.00 GR -999.2500 2. 5957 91.8125 -999.2500 -999.2500 2.06q. 5 126.5000 -999.2500 -999.2500 2.6328 105.3125 -999.2500 -999.2500 2.5820 87.9375 -999.2500 99.0625 -999o2500 -999.2500 2.7207 96.9375. -99'9,. 2500 -999°2500 3.1543 96'7500 -999.25'00 -999.2500 2,-7031 83.8125 -999o2500 -999°2500 2.79,~9 95-9375 -999.2500 -999.2500 3,1660 103o 9375 2.'7773 93.0000 ILM CALI RNRA CALl RNRA ILM CALl RN~A . ILM CALI RNRA ILM .CALI RNRA ILM CALI RNRA ILM CALI RNRA CALI ~NRA ILM CALl RNRA ILM CALl RN~A ILM CALl Z.5508 Z.318~ -99~.2500 2.1133 Z. 31 ~3,r, -999.2500 Z. 55'98 3223 -gg9.ZGO0 2.5'176 2.318~ -999.Z500 2.7'773 2.3301 -999.2500 2.5-34, 8 Z. 3145 -999. 2500 3.0703 2.32,52 -999.25'00 2.6113 Z. 3223 -9'9 9,. 2500 2.6777 2:.3223 -999°2500 3.0703 2.. 32 23 -999o 25'00 2.6582 2. 3262 .VP OlO.H02 VERIFICATION.LISTING PAGE ? ~HO8 -999.2500 ORHO ¢'PHI -999. 2500 NCNL' )EPT 4800,.0000 SFLU gP -55.5000 GR ~H~B -999. 2500 ORHO ~PHI -ggg. 2500 ~CNL )EPT 47,00.0000 SFLU ~HOB -'999..,2500 D'RHO qPMI -999.2500 NCNL 3EPT ~600-000,0 SF.LU 5P -5~.7813 ~HOB -999.2500 DRHO ~PMi -999.2500 NCNL DEPT 4500.0'000 SFLU SP -59.:7500 ~HO~ .-999. 2500 ~PHI -999,. 2500 NCNL ~EPT 4~00.0000 SFLU $'P -60.0000 GR RH08 -999.25,00 OReO NPHI -999°2500 NCNL DEPT 4300.0000 SFLU SP -65'.0000 GR RHDB -999.2500 DRHD NPMI -999.25,00 NCNL OEPT ~200. 0000 SFLU NPH2 -999. 2500 NCNL CEPT 4100o0000 SFLU SP -62.0000 GR RHOB -999.2500 ORHO NPHI -999.2500 NCNL DEPT ¢BO0.O000 SFLU SP -6¢°5000 GR RHDB' -999.2500 DRHO NP~I -9gg. ZEO0 NCNL DEPT 3~00.0000 SFLU SP -61.2813 GR ~H~B -999.2500 DRHO NP~I -399.2500 NCNL DEPT 3800o0000 SFLU -999.2500 NRAT -999.2.50'0 FCNL 3°:5684 [Lg -999.2500 NEaT -999.2500 FCNL 7.,3086 ILD -999.2500 NEAT --999.2500 FCNL. 3,.,,, 3086 ILD 77°9375 GR -999- 2500 NRAT --999~2500 FCNL 2. 8320 ILO 115:,.56Z5 GE - 999.25 0'0 NR AT -999.2500 FCNL 3.130'9 ILD 89°2500 GR -999.2500 NRAT -999°2500 FCNL 3.4238 ILD 112. 875:0 GR -999.2590 NRAT ,-999,. 25'00 FCNL 2.3203, ILO 97.9375 'GR -999.250.0 NRAT -999.2500 FCNL 3.9668 ILO 106.6250 GR -999.2500 NRAT -999o2500 FCNL · 5.2930 ILO 86.0000 GR -999.2500 NRRT -999.2500 FCNL ~.7578 ILO 80.6250 GR -999o2500 NRAT -999°2500 FCNL 3oT578 ILO -999.2500 -999.2500 92'000'0" -999.2500 -9'99.2500 69°6250 -999°2500 -999°2500 77o93~5 -999.2500 -999.'2500 3.2012 -999.2500 -999-2500 3.5078 89.2500 -999.2500 -999.2500 3°9004 112.8750 -999.2500 -999.2500 ,Z. 6680 97.9375 -999.2500 -999.2500 106.6.250 -999. Z500 -999.2500 5.Z500 86.0000 -999.2500 -999°2500 7.3789 80.6250 -999.2500 -999.2500 5o1016 CALI RNRA ILM :CALI RNRA CALI ~NRA ILM CALl RNRA ILM CALI RN RA ILM CALl RNRA ILM CALl RNRA ILM CALI RNRA ILM C A'LI RNRA ILM CALI RNRA -999. 2500 3. 8633 Z. 32'62 -9'99. 250-0 -999,. 2500 3.9727 2.32'23 -999°2500 3.. 04~9 2.3262 -999° 25 O0 .3.2461 2.3301 -999°2500 3.6504 2.3340 -999.2500 2.5,078 2.3535 -999.2500 Zo371! -999.2500 5.2187 2.~180 -999.2500 5,.9375 -999.2500 4.5195 VERIFICATION LISTING PAGE 8 ;P )HgB IPHI -6~.0000 GR -999.2500 -999.2500 NCNL )EPT 37~5.0000 SFLU ;P -[Z.5078 GR tHgB -999°2500 DRHD IPHI -ggg. ZSO0 NCNL 76.5000 GR - 9919o 2 500 N R AT -999.Z50.0 FCNL 2000.0000 ILD 55-7B13 GR -999.25:00 NR~T --g99'2500 FCNL 7&.5000 CALI -999.2500 RNRA -9~9,.2500 lz,. 35gq. ILM 55.7813 CALI -999. 2500 RNRA -999,. ZSO0 20OO.O00O Z.5117 ,-999.2500 FILE TRAILER *~: :ILE NaME :EDIT ,00:! ;ERVICE blAME ?ERS'ION J' E ': I~:XIMU'M LENGTH : :ILE TYPE XT FIL'E '~ME :, TAPE 'TRAILER ;ERVICE NAME :EOIT )ATE :84/0B/30 )RIGIN :0000 '.APE NAME :9458 :ONTINUATIDN '.e :01 ~EXT TAPE NAME : :OMMENTS : ~-~ REEL TRAILER iERVICE..NAME :EDIT )ATE : 3R IGIN : 2EEL NAME :ONTINIJATI~N # :01 IEXl REEL .NAME : :OMMENT$ :
