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197-134
Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1L-09 50-029-22025-00 910180917 Kuparuk River Plug Setting Record Field- Final 15-Jul-25 0 12 1R-33 50-029-22529-00 910219407 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 13 1R-33 50-029-22529-00 910218799 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1Y-06A 50-029-20958-01 910277376 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 23-Aug-25 0 15 1Y-06A 50-029-20958-01 910180481 Kuparuk River Leak Detect Log Field- Final 22-Jul-25 0 16 1Y-06A 50-029-20958-01 910180481 Kuparuk River Plug Setting Record Field- Final 22-Jul-25 0 17 2B-02 50-029-21154-00 910151022 Kuparuk River Packer Setting Record Field- Final 3-Jul-25 0 18 2G-17 50-029-23134-00 910157884 Kuparuk River Leak Detect Log Field- Final 14-Aug-25 0 19 2K-23 50-103-20125-00 910180916 Kuparuk River Plug Setting Record Field- Final 12-Jul-25 0 110 2X-12A 50-029-21189-01 910262801 Kuparuk River Plug Setting Record Field- Final 24-Aug-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:190-034194-156197-134184-122202-243190-014195-176T40827T40828T40828T40829T40829T40829T40830T40831T40832T408338/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:51:45 -08'00'194 156197-134184 122Leak Detect Log with4 1Y-06A50-029-20958-01 910277376Kuparuk RiverIntelliScopeField & Processed23-Aug-25015 1Y-06A50-029-20958-01 910180481Kuparuk RiverLeak Detect LogField- Final22-Jul-25016 1Y-06A50-029-20958-01 910180481Kuparuk RiverPlug Setting RecordField- Final22-Jul-2501 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-08-12_16046_KRU_1Y-06A_VividLeakDetectLog_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 16046 KRU 1Y-06A 50-029-20958-01 VIVID Leak Detect Log 12-Aug-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 197-134 T40787 8/18/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.18 10:39:56 -08'00' ORIGINATED TRANSMITTAL DATE: 5/30/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5465 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5465 1Y-06A 50029209580100 Leak Detection Log 25-May-2025 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 197-134 T40512 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.30 13:17:41 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 11 B Ͳ16 A 5 0 Ͳ02 9 Ͳ22 4 5 7 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 7 ͲDe c Ͳ23 0 1 21 D Ͳ13 0 5 0 Ͳ02 9 Ͳ22 8 1 5 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲDe c Ͳ23 0 1 31 D Ͳ14 1 A 5 0 Ͳ02 9 Ͳ22 9 6 7 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲDe c Ͳ23 0 1 41 H Ͳ10 2 5 0 Ͳ02 9 Ͳ23 5 8 0 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 4 ͲJa n Ͳ24 0 1 51 Y Ͳ06 A 5 0 Ͳ02 9 Ͳ20 9 5 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 0 ͲFe b Ͳ24 0 1 62 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 9 0 9 1 7 6 6 9 3 K u p a r u k R i v e r P e r f o r a t i o n R e c o r d F i e l d Ͳ Fi n a l 2 6 ͲFe b Ͳ24 0 1 72 C Ͳ12 5 0 Ͳ02 9 Ͳ21 2 2 2 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲDe c Ͳ23 0 1 82 F Ͳ15 5 0 Ͳ02 9 Ͳ21 0 4 8 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 2 5 ͲFe b Ͳ24 0 1 92 U Ͳ05 5 0 Ͳ02 9 Ͳ21 2 8 1 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d & P r o c e s s e d 8 ͲDe c Ͳ23 0 1 10 2 W Ͳ01 5 0 Ͳ02 9 Ͳ21 2 7 3 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲDe c Ͳ23 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 7 5 T3 8 5 7 6 T3 8 5 7 7 T3 8 5 7 8 T3 8 5 7 9 T3 8 5 8 0 T3 8 5 8 1 T3 8 2 8 2 T3 8 5 8 3 T3 8 5 8 4 21 8 - 1 5 5 19 7 - 1 8 3 20 8 - 0 1 6 21 7 - 0 9 7 19 7 - 1 3 4 22 3 - 0 9 2 18 4 - 2 0 6 18 3 - 1 7 2 18 5 - 0 1 8 18 5 - 0 1 0 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h G u h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 1 9 : 5 8 - 0 9 ' 0 0 ' 197- 1 34 1Y Ͳ06 A • • 2,329 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2015 Attn.: Makana Bender DATA LOGGED 10 A3/2015 333 West 7th Avenue, Suite 100 .n.K.BENDER Anchorage, Alaska 99501 -4``.s uci 0 U 2b1',4 RE: Production Profile: 1Y-06A Run Date: 8/20/2015 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 1Y-06A Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20958-01 Production Profile Log 1 Color Log 50-029-20958-01 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. SC04/45 1 Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: I 2 ' ✓`e.-'""C WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 1, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1Y-06A Run Date: 7/24/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y-06A Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20958-01 Production Profile Log 1 Color Log 50-029-20958-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Klinton Wood 6900 Arctic Blvd. NOV 0 8 2016 Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: c[ (\°[17-- Z4-41 Signed: d • . • • ConocoPh i l ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 14, 2011 PIECEI` � �' Commissioner Dan Seamount FEB 1 7 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 <<i & GCS COOS - C! re sins Anchorage, AK 99501 Anct ° an; q r) / � Commissioner Dan Seamount: ' ©b Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 corrosion inhibitor /sealant was pumped February 10 -12, 2011.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. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor . 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 2115/2011 1B,1D,1E,1Q,1Y / 3F,3G,3J PAD ,, At Corrosion lnitial Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date _ ft bbls ft gal 1B -01 50029204650000 1800400 SF N/A 19" j N/A 1.4 2/11 /2011 1D-119 50029228360000 1972220 2 - . lf' N194 23" N/A 4.2 2/10/2011 1E -117 50029232510000 2050260 12" N/A 12" N/A 4.2 2/12/2011 1E-121 50029232380000 2042460 6" N/A 18" N/A 4.4 2/12/2011 1Q -21 50029225910000 1951330 5" N/A 5" N/A 5.2 2/1 2/2011 1Q-22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y -06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y-08 50029209440000 1830620 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A 18" N/A 3 2/11/2011 3J -17 50029227000000 1961460 SF N/A 19" N/A 3.3 2/11/2011 STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair w ell F Plug Perforations r Stimulate l- Other Alter Casing Pull Tubing Perforate New Pool r — Waiver r Time Extension Change Approved Program Operat. Shutdown Perforate r7o Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development l o Exploratory M 197 -134 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50- 029 - 20958 -01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25646 1 1Y -06A 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8494 feet Plugs (measured) None true vertical 6435 feet Junk (measured) None Effective Depth measured 8393 feet Packer (measured) none true vertical 6373 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 116 16 116 116 SURFACE 2427 9.625 2458 2200 PRODUCTION 6099 7 6130 4769 LINER 2577 3.5 8492 6434 D .08ZLA ,doelo Perforation depth: Measured depth: 7762'- 7792', 7902'- 7912', 8098'- 8138', 8168' -8188' True Vertical Depth: 5971'- 5991', 6071'- 6077', 6191'- 6216', 6234' -6247' RECEIVED Tubing (size, grade, MD, and TVD) 3.5, J -55, 5944 MD, 4629 TVD 1Q D EC 0 8 Q Packers & SSSV (type, MD, and TVD) NIPPLE - CAMCO'DS' NIPPLE @ 505 MD and 505 TVD Alaska Oil & Gas Cons• cpm3ission 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 116 598 385 -- 178 Subsequent to operation 145 484 323 -- 182 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory Development '. Service ] Stratigraphic 15. Well Status after work: .Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR WINJ WAG GINJ SUSP r SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce (c) 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 2' RBDMS DEC 0`8 2010 Form 10-404 Revised 10/2010 Submit Original Only i DATE SUMMARY 10117110 DRIFTED TBG WITH 15'x 2.72" OOMY GUN TO 8000' SLM. READY FOR . 10/31/10 LOGGED 24 -ARM CALIPER FROM 7900' TO SURFACE. WELL RETURNED TO PRODUCTION. DATA SENT TO PDS FOR PROCESSING. 11/7/10 PERFORATE C4 SAND FROM 7772' -7792' WITH 2 -1/2" MILLENIUM II, 6 SPF, 60 DEG. v KUP � 1Y -06A - _ PS Well Attributes Max Angle & MD _ TD Wellbore API/UWI Field Name 1well Star,, Inc/ ( °) MD (HKB) IAt arm (ftKB) Ata,w, Inc, 500292095801 KUPARUK RIVER UNI F _ PROD 52.00 8,394 00 8,494 0 + Comment IH2S (ppm) Date An otatlon End Date KB - Grd (ft) Rig Release Date SSSV. NIPPLE 100 81612009 Last W0' f 36 01 _ 5141_7983 _ We1l COnfg - 1Y -06A 1 (22(201Q1 Schema c Acfual .. - - Annotation Depth (ft K6) I Date Ann let n -- Last MOtl By End Date Last Tag SLM 8,3000 l 8/29/2009 Rev Rea AD D PERFS I I 1 L Imosbor _ 11/27/2010 Casino Strincis - -- - - String OD String ID Set Depth Set Depth (ND) String Wt ' String Casing D cription _ _ (tn) - im) _ Top (ftKg (ftKB) (HKB) (Ii Grad Stri Top Third (QC) i6 15.060 30.9 116.0 116.0 65.00 H-40 WELDED SURFACE (QC) 95/81 8.835 30.9 2,458.1 2,199.9 40.00 J -55 BTC P (Q RODUCTION C) 71 6.151 29.5 8,064.0 6,170.4 26.00 J -55 BTC �LINER(OC) 31/2 ' 2992 5,914.7 8,492.0 64339 9.30 L -80 EUE8RDMOD Tubing Strings . CONDUCTOR _ -.. TUBING Description Stri String 9 Set Depth Set Depth (ND) String Wt String ( I Top (ftKB) (h S) (HKB) (Ibs/ft) Gmde String Top Thrd 2 992 0.0 5,944.0 4,629 2 9.30 J 55 ABM EUE Other In Hole All Jewelry: Tubing Run $ Retrievable, Fish etc. _ NIPPLE, 505 - -- Top Depth (TV' Top Intl T KB HKB) ( °) Description _ _ Comment Run Date ID in) 1 i 505.0 505.0 0.19 NIPPLE Camco'DS'Nipple 8/26/1997 2.812 3,061.0 2,599.8 46.76 GAS LIFT CAMCOlKBUG/1 /GLV /BK/.156 /1393/Comment: STA1 4/2511999 2.860 4,944.0 3,909.2 46.08 GAS LIFT CAMCO /KSUG/l /GLV /BK/.188 /1450 /Comment: STA2 4/25/1999 2.860 SURFACE _ 5,865.0 4,570.1 41.99 GAS LIFT CAMCO /MMM 11.5 /OV/RK/.188// Comment STA 3 4/2511999 2.860 (OCI. 2.458 >; 5,911.0 4,605.0 42.27 NIPPLE I E Camco'D'Nipple NO GO 8126/1997 2.750 :. 5,920.0 4,611.6 42.20 SEAL Baker'GHB-22 Assembly 86611997 3.000 GASLIFT. 3,061 Perforations & Slots Shot Top (rVD) Btm (TVD) Dens To ftKB "Aftl( (ftKB) (ftKB) Zone Data (sb° Comment 7,762.0 7,782.0 5,971.3 5,984.5 C 1Y - 06A 2/13/2005 6.0 APERF 2.5" PJ HSD, 60 deg Ph GAS I I FT, a,9aa 7,772.0 7,792.0 5,977.9 5,991.0 C4, 1Y -06A 117/2010 6.0 RPERF 2.5" MILLENIUM II, 60 deg phase 7,902.0 7,912.0 6,070.6 6,076.8 6-1, 1Y-O6A 1/25/2000 4.0 APERF 2.5" HC, 180 deg. phasing, oriented -1- 90 deg. from the low side 8,098.0 8,138.0 6,191.3 6,215.9 A4, tY-06A 7/10/1998 4.0 APERF 180 deg phasing, orient. 90 deg Mow side; 2 112" HC, DP GAS UFr, _.. 8,098.0 8,138.0 6,191.3 6,215.9 A4, tY-O6A 2113/1999 s.0 RPERF 60 deg phasing, 2 i/2" HC BH 5,865 8,168.0 8,188 0 6,234.4 6,246.7 A -3, 1Y -O6A 9!15/1997 4.0 IPERF 180 deg. phasing; Oriented 25 deg. CCW F/ High Side; 2 1/2" HSD BH Notes: General 8 Safety _ End Date Annotation NIPPLE, 5,911 8/4/2002 NOTE WAIVEREDWELL: IA x OA ANNULAR COMMUNICATION 10/22/2010 NOTE: View Schematic wl Alaska Schematic9.0 SEAL, 5,920 -- q fi I APERF, 7,762 -7,762 RPERF, _ 7,772 -7,792 APERF, 7,902 -7,912 1 PRODUCTION (Ock 8.064 RPERF, 8,098 -8,138 APERF, 8,098 -8,138 IPERF, 8,168 -8,188 I LINER 8,46 .� 6,492 ■` TD(1Y -06Ak -- 8,494 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 10, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1 Y -06A Run Date: 11/8/2010 i The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Minton Wood Halliburton Wireline & Perforating, Arctic Blvd. Anchorage, AK 99518 g, � g , 1Y -06A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20958 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Minton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907-273-X535 a klinton.woodghalliburton:corn Date: Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 4, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MIT Caliper Log: 1 Y -06A Run Date: 10/31/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. i Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y -06A Digital Data in LAS format, Digital Log Image file _ 1 CD Rom 50- 029 - 20958 -01 MIT Caliper Log I Color Log 50- 029 - 20958 -01 ` lu PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 � Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @hallib rton com 0 Date: Signed: r WELL LOG TRANSMITTAL PROAc7ivE DiAgmmic SERViM, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE: Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt b returning 9 Y 9 a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 Z 1) Caliper Report 31 -0ct -10 1 Y -06A 1 Report / EDE 50-M :209 --- 2) Caliper Report 01-Nov-10 2G-13 1 Report/ EDE 2-0 9 21160 -00 �- It e -t - r29 N Signed : Date : j Print Name: ska s . z sit 3gA PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAx: (907)245 - 88952 E-MAIL: Pdsanchoragea- memorVlom.com WEBSITE : ww+N.mernoryloG.com CADocuments and Settings\Diane Williams \Desktop \Transmit_Conoco.docx t . • ' Multi- Finger Caliper Log Results Summary I' Company: ConocoPhillips Alaska, Inc. Well: 1Y -06A Log Date: October 31, 2010 Field: Kuparuk Log No.: N/A State: Alaska Run No.: 1 API No.: 50- 029 - 20958 -01 Pipet Desc.: 3.5" 9.3 lb. J -55 ABM EUE Top Log Intvl1.: 36 Ft. (MD) Pipet Use: Tubing & Liner Bot. Log Intvl1.: 7,616 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is correlated to a Schlumberger Production Proble dated November 17, 2008. This log was run to assess the condition of the 3.5" liner in the vicinity of the potential rate- adding additional perforations (7,782'— 7,792') for use in patch setting operations planning. A 3 -D log plot of the caliper recordings across this interval (7,700' - 7,840') is included in this report. The caliper recordings indicate the 3.5" tubing is in good condition with respect to corrosive and mechanical damage. No significant wall penetrations, areas of cross - sectional wall loss or 1. D. restrictions are recorded throughout the 3.5" tubing. ' The caliper recordings indicate the 3.5" liner logged is in good condition with respect to corrosive and mechanical damage, with the exception of a 24% wall penetration recorded in an area of pitting in joint 247 (7,943'). No other significant wall penetrations, areas of cross - sectional wall loss or I. D. restrictions are recorded throughout the 3.5" liner logged. ' This summary report is interpretation of data provided by Halliburton Well Services. ' MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting ( 24 %) it. 247 @ 7,943 Ft. (MD) ' No other significant wall penetrations (> 19 %) are recorded throughout the 3.5" tubing and liner logged. MAXIMUM RECORDED CROSS- SECTIONAL METAL LOSS: ' No significant areas of cross - sectional wall loss (> 6 %) are recorded throughout the 3.5" tubing and liner logged. ' MAXIMUM RECORDED ID RESTRICTIONS: No significant I. D. restrictions are recorded throughout the 3.5" tubing and liner logged. Field Engineer: M. Biery Analyst: M. Lawrence Witness: B. Boehme ' ProActive Diagnostic Services, Inc. / P.O. Sex 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 �_ � � ^73 PDS Multifinger Caliper 3D Log Plot Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 1Y -06A Date : October 31, 2010 Description : Detail of Caliper Recordings Across Patch Interval Over Perforations Comments Depth Maximum I.D. 3 -D Log Image Map 1ft:240ft 2.5 inches 3.5 0. 0 90° 180° 270° 0 Minimum I.D. 2.5 inches 3.5 Nominal I.D. ' inch ........................... ........................ Joint 239 — . - - +- -- -- a.. 7710 7720 ' Joint 240 7730 7740 Joint 241 7750 — Perforations -- -- , -- 7760 ' 7770 t Joint 242 7780 Perforations 7790 7800 1 - 7810 - -- Joint 243 (. _ 7820 ' 7830 Joint 244 I 9 011 Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (36.1'- 79715) Well: 1 Y -06A Field: Kuparuk ' Company: Conoco Phillips Alaska, Inc. Country: USA Survey Date: October 31, 2010 �i ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 36 25 791 50 1571 75 2356 GLM 1 100 3169 125 3979 Z s 'o GLM 2 150 4787 p ' 175 5603 GLM ', 200 6457 i 225 7238 I i 249 7971 0 50 100 ' Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 249 ' PDS Report Overview Body Region Analysis ' Well: 1Y -06A Survey Date: October 31, 2010 Field: Kuparuk Tool Type: UW MFC 24 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 ' Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 ppf -55 ABM EUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) Damage Profile (% wall) ' M penetration body M metal loss body penetration body metal loss body 0 50 100 200 1 ' 150 100 50 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% I' Number of joints analysed total = 254 pene. 0 161 89 12 1 loss 105 148 0 1 0 0 GLM 1 Damage Configuration ( body ) 40 150 GLM 2 ;n ' 20 GLM 3 I 10 196 0 isolated general line ring hole /poss pitting corrosion corrosion corrosion ible hole 246 Number of joints damaged total = 38 33 5 0 0 0 Bottom of Survey = 249 e 2 Analysis Overview a ' Y page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 ABM EUE Well: 1 Y -06A Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 31, 2010 Joint Jt. Depth I'en. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 36 0 0.01 2 2 2.92 1.1 67 0 0.03 13 4 2.93 PUP Shallow pitting. 2 77 0 0.02 9 1 1 2.90 3 109 0 1 0.03 12 2 2.89 Shallow pitting. 4 140 0 0.03 12 3 2.89 ' 5 172 0 0.01 5 1 2.89 6 202 U 0.01 6 1 2.90 7 233 0 0.01 4 1 2.92 8 264 0 0.01 2 1 2.92 9 296 0 0.01 5 1 1 2.91 10 325 0 1 0.03 10 1 2.92 11 356 0 0.01 5 2 2.90 12 388 0 0.01 4 2 2.91 ' 13 418 0 0.02 9 4 2.90 14 449 0 0.03 11 1 2.90 15 479 0 0.01 5 1 2.91 15.1 508 0 0 0 0 2.82 Camco'DS' Ni le I 16 509 0 1 0.03 10 2 2.89 17 540 0 0.03 11 2 2.92 18 572 0 0.03 10 2 2.89 19 603 0 0.02 9 2 2.90 20 634 0 0.02 9 2 2.92 21 666 0 0.01 4 3 2.89 22 697 0 0.02 9 1 2.90 23 728 0 0.02 9 2 2.92 24 1 760 0 0.03 13 1 2 2.92 Shallow pitting. 25 791 0 0.02 8 2 2.91 26 823 0 0.03 11 2 2.91 Lt. Deposits. 27 854 0 0.02 9 2 2.90 28 886 0 0.03 10 2 2.90 ' 29 917 0 0.04 15 2 2.91 Shallow corrosion. 30 948 0 0.04 15 1 2.91 Shallow pitting. Lt. Deposits. 31 979 0 0.03 10 1 2 2.89 32 1011 0 0.03 12 1 2 2.89 Lt. Deposits. 33 1042 0 0.04 15 2 2.87 Shallow ittin . Lt. Deposits, 34 1074 0 0.03 11 2 2.90 Lt. Deposits. 35 1105 0 0.04 16 2 2.91 1 Shallow pitting. 36 1136 0 0.03 12 2 2.90 1 Lt. Deposits. 37 1167 0 0.03 10 2 2.91 1 38 1199 0 0.03 11 3 2.90 39 1231 0 1 0.04 15 1 2 2.90 Shallow corrosion. 40 1262 0 0.03 10 2 2.89 41 1293 0 0.03 11 2 2.90 42 1323 0 0.02 9 2 2.89 43 1354 0 0.03 11 2 2.92 44 1386 0 0.03 11 2 2.91 Lt. Deposits. 45 1416 0 0.05 19 1 3 2.88 Shallow corrosion. Lt. Deposits. ' 46 1448 0 0.03 12 2 2.90 Lt. De osits. 47 1479 0 1 0.02 9 1 1 2.89 48 1510 0 1 0.03 11 1 2 2.90 Penetration Body 1 Metal Loss Body Page "I i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 ABM EUE Well: 1 Y -06A Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 31, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 49 1540 0 0.03 11 2 2.93 50 1571 0 0.02 9 2 2.89 51 1603 0 0.02 9 2 2.92 52 1634 U 0.01 4 2 2.90 Lt. De osits. 53 1665 11 0.03 10 2 2.90 ' 54 1698 0 0.03 10 2 2.91 55 1728 U 0.02 9 4 2.90 56 1759 0 0.01 3 2 2.93 57 1790 0 0.03 10 2 2.91 ' 58 1820 0 0.03 13 2 2.90 Shallow corrosion. 59 1851 0 0.03 10 2 2.90 60 1882 0 0.03 10 2 2.93 61 1913 0 0.01 5 2 2.94 62 1944 0 0.02 9 2 2.91 63 1974 0 0.03 12 1 2.91 64 2005 0 0.01 4 1 2 2.91 65 2036 0 0.02 8 1 2.95 66 2067 0 0.01 2 1 2.90 67 2098 0 0.01 2 2 2.90 68 2130 0 0.02 7 2 2.93 69 2161 0 0.03 13 1 2.89 Shallow pitting,. 70 2193 0 0.03 11 1 2.89 71 2226 0 0.03 12 1 2.88 Shallow pitting. 72 2258 0 0.03 10 2 2.93 73 2291 0 0.03 12 1 2.89 74 2323 U 0.02 7 1 2.88 75 1 2356 1 0.02 7 1 2.91 76 2388 t) 0.04 14 1 2.88 Shallow pitting. 77 2421 0 0.02 9 1 2.91 78 2453 0 0.02 9 1 2.89 ' 79 2485 0 0.03 12 2 2.89 80 2518 0.03 12 1 2.89 Shallow pitting. 81 2 548 t ) 0.02 9 1 2.89 82 1 2581 U 1 0.03 11 1 2.89 ' 83 2613 0 0.02 9 1 2.88 84 2645 0 0.03 11 1 2.92 85 2677 0 0.03 11 1 2.92 86 2710 0 0.02 9 1 1 2.93 87 2741 0 0.02 9 1 2.88 88 2774 0 0.03 11 1 2.87 89 1 2806 0 1 0.02 8 1 2.89 90 2839 l) 0.02 8 1 2.90 91 2871 0 0.03 13 2 2.89 Shallow pitting. 92 2904 0 0.03 10 1 2.93 93 2935 0 0.03 12 1 2.90 Shallow pitting. 94 2968 0 0.02 9 1 2.91 95 3001 0 0.03 13 1 2.88 Shallow pitting. 96 1 3033 0 0.02 8 2 2.92 96.1 3065 0 1 0 0 0 N/A GLM 1 Latch @ 2:00 97 3072 t) 1 0.03 13 1 2.90 Shallow pitting. Penetration Body ' Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 ABM EUE Well: 1Y -06A Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 31, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 98 3104 0 0.02 9 1 2.92 99 3136 0 0.02 9 1 2.89 100 3169 U 0.02 8 1 2.93 101 3201 0 0.02 9 1 2.92 102 3234 0 0.02 9 1 2.92 103 3266 0 0.03 13 1 2.89 Shallow pitting. 104 3298 0 0.02 9 1 2.90 105 3331 0 0.02 9 3 2.89 106 3363 0 0.02 9 1 2.90 107 3396 0 0.03 12 1 2.88 108 3428 0 0.02 7 1 1 2.91 109 3460 U 0.02 9 3 2.89 110 3493 0 0.02 9 1 2.88 111 3526 0 0.02 7 1 2.91 112 3558 0 0.03 10 1 2.89 113 3591 0 0.03 10 1 2.91 Lt. Deposits. 114 3623 0 0.02 8 1 1 2.93 115 3655 U 0.02 9 1 2.88 116 3687 0 0.02 9 2 2.89 117 3720 0 0.02 9 2 2.89 118 3752 U 0.03 11 4 2.89 119 3785 O 0.03 13 1 2.87 Shallow pitting. 120 3817 U 0.01 6 1 2.90 121 3849 0 0.03 11 1 1 2.89 122 3882 0 0.03 11 2 290 123 3914 0 0.02 8 1 2.91 124 3947 0 0.03 11 1 2.88 125 3979 0 0.02 8 1 2.89 126 4011 0 0.02 9 1 2.88 127 4044 0 0.03 12 1 2.92 128 4076 0 0.04 14 1 2 2.87 Shallow pitting. 129 4109 0 0.02 9 1 2.93 130 4141 0 0.02 9 1 2.91 131 4173 0 0.04 17 1 2.90 Shallow pitting. 132 4205 0 0.02 9 2 2.88 133 4239 0 0.03 10 1 2.90 134 4270 t - t 0.02 9 1 2.92 135 4303 0 0.03 12 1 2.89 Shallow pitting. 136 4335 (t 0.02 8 1 2.91 137 4368 0 0.03 11 1 2.88 138 4398 0 0.03 11 1 2.89 139 4431 0 0.01 5 1 1 2.93 140 4463 0 0.03 10 1 2.89 141 4495 0 0.02 8 1 2.94 142 4528 0 0.02 7 1 2.93 143 4560 0 0.01 4 1 2.89 144 4593 0 0.02 8 1 2.93 145 4625 0 0.03 1 11 1 1 2.87 146 4658 U 0.03 1 11 2 2.90 147 4690 1 1 0.02 1 9 1 2.92 Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.3 ppf J -55 ABM EUE Well: 1 Y -06A Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc.. Nominal I.D.: 2.992 in Country: USA Survey Date: October 31, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 148 4721 0 0.02 9 1 2.92 149 4754 0 0.02 9 1 2.92 150 1 4787 0 0.02 9 1 1 2.90 151 4819 0 0.02 9 1 2.89 152 4852 0 0.02 9 1 2.88 153 4884 0 0.02 9 1 2.93 154 4916 0 0.03 12 1 2.88 Shallow pitting. 154.1 4948 0 0 0 0 N/A GLM 2 Latch @ 1:30 155 4955 0 0.03 11 2 2.88 156 4988 0 0.03 11 1 1 2.91 157 5020 0 0.03 12 2 2.91 158 5052 0 0.02 7 1 2.92 159 5084 0 0.03 10 3 2.92 160 5116 0 0.03 12 1 2.87 161 5149 0 0.04 14 2 2.87 Shallow pitting. 162 5182 0 0.03 10 2 2.91 163 5213 0 0.03 11 1 2 2.87 ' 164 5247 0 0.03 13 1 2.88 Shallow pitting. 165 5279 0 0.02 9 2 2.88 166 5312 0 0.03 11 2 2.88 167 5344 0 0.02 8 1 2.93 168 5375 0 0.03 12 1 2.88 ' 169 5408 0 0.02 7 1 2.92 170 5441 0 0.02 1 9 1 2.92 171 5473 U 0.03 10 2 2.88 172 5506 0 0.03 13 2 2.87 1 Shallow pitting. Lt. De osits. 173 1 5538 0 0.02 9 2 2.91 174 5570 0 0.03 12 2 2.87 Shallow pitting. 175 5603 0 0.02 9 1 2.92 176 5635 0 0.02 9 1 2 2.88 ' 177 5668 0 0.03 10 2 2.92 178 5699 0 0.03 10 2 2.87 179 5733 0 0.02 9 2 2.90 180 5764 0 0.02 9 2 2.91 181 5796 0 0.03 11 2 2.87 1 182 5829 0 0.03 10 2 2.87 182.1 5861 0 0.01 4 1 3 2.88 PUP 182.2 5867 0 1 0 0 0 N/A GLM 3 Latch @ 9:00 182.3 5876 0 0.03 10 0 2.93 PUP 183 5881 0 0.02 9 1 2.89 183.1 5914 0 0 0 0 2.75 Camco'D'Nipple NO GO 183.2 5916 0 0.01 4 1 2.91 PUP 183.3 1 5922 0 0 0 0 3.00 Baker'GHB -22' Seal Assembl 1814 5949 0 0.02 9 2 2.93 PUP 184 5956 0 0.02 8 1 2.93 185 5986 U 0.02 9 2 2.92 186 6017 t) 0.03 11 2 2.91 187 6049 0 0.03 10 2 2.94 ' 188 6081 0 0.02 9 1 2.93 189 1 6112 0 0.03 10 1 2.93 Penetration Body ' Metal Loss Body Page 4 I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 ABM EUE Well: 1Y -06A Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 31, 2010 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 190 6143 0 0.03 11 2 2.90 191 6175 0 0.02 9 1 2.94 192 6206 0 0.02 9 3 2.93 193 6237 0 0.03 10 2 2.92 194 6269 0 0.02 7 1 2.93 195 6301 0 0.02 7 2 2.95 196 6332 0 0.02 7 2 2.94 197 6363 0 0.02 8 2 2.93 198 6394 0 0.02 7 2 2.92 199 6426 0 0.03 11 2 2.91 200 6457 U 0.03 13 3 2.92 Shallow pitting. 201 6487 0 0.03 12 2 2.91 202 6519 0 0.02 9 2 2.92 203 6550 0 0.01 6 2 2.93 204 6582 U 0.02 7 2 2.91 205 6613 0 0.04 14 2 2.91 Shallow pitting. 206 6645 0 1 0.02 8 2 2.91 207 6676 0 0.03 11 4 2.90 208 6707 0 0.04 14 2 2.91 Shallow pitting. 209 6738 0 0.02 7 3 2.91 210 6771 U 0.02 7 5 2.92 211 6802 0 0.02 8 4 2.93 212 6833 0 0.02 7 4 2.92 213 6864 0 1 0.02 8 2 2.93 214 6896 0 0.01 5 2 2.93 215 6927 0 0.03 10 2 2.93 216 6959 0 0.02 9 1 2 2.92 217 6990 0 0.03 11 3 2.92 218 7022 0 0.03 10 2 2.92 219 7052 0 0.03 11 3 2.91 220 7083 0 1 0.03 11 2 2.95 221 7115 0 0.03 13 3 2.90 Shallow pitting. 222 7144 0 0.03 10 4 2.92 223 7175 0 0.03 13 1 2.92 Shallow pitting. 224 7207 0 0.02 8 3 2.92 ' 225 7238 U 0.03 10 2 2.91 226 7270 0 0.04 15 3 2.91 Shallow )ittin . 227 7301 U 0.03 12 4 2.95 228 7332 0 0.02 8 2 2.91 229 7364 0 0.03 11 3 2.91 230 7395 0 0.03 10 1 3 2.91 231 7427 0 0.03 10 3 2.91 232 7458 0 0.03 10 3 2.91 233 7489 0 0.02 9 3 2.91 234 7521 0 0.04 14 4 2.93 Shallow pitting. Lt. Deposits. 235 7552 0 0.03 13 3 2.92 Shallow pitting. 236 7583 U 0.03 12 2 2.92 ' 237 7612 0 0.02 8 2 2.93 238 7644 U 0.03 10 4 2.91 Lt. Deposits. 239 7675 0.03 1 10 2 2.93 Penetration Body 1 Metal Loss Body Page 5 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 ABM EUE Well: 1 Y -06A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 31, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 240 7707 1) 0.03 11 2 2.92 241 7738 0 0.13 49 6 2.90 Perforations. Lt. Deposits. OM 242 7768 0 0.12 47 1 5 2.88 Perforations. Lt. Deposits. 243 7800 0 0.03 10 2 2.93 244 7831 0 0.04 15 3 2.93 Shallow corrosion. Lt. Deposits. 245 7863 0 0.03 10 3 2.92 246 7893 0 0.22 88 22 2.79 Perforations. 247 7924 U 0.06 24 4 2.91 Isolated pitting. 248 7956 0 0.02 7 1 2 2.91 Marker Joint. 249 7971 1 0.02 9 2 2.93 Marker Joint. Penetration Body Metal Loss Body i ' Page 6 Ci PDS Report Cross Sections Well: 1Y -06A Survey Date: October 31, 2010 Field: Kuparuk Tool Type: UW MFC 24 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 ' Tubing: 3.5 ins 9.3 ppf J -55 ABM EUE Analyst: M. Lawrence Cross Section for Joint 247 at depth 7943.19 ft Tool speed = 43 Nominal ID = 2.992 ' Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 50 " 1 Finger 11 Penetration = 0.06 ins Isolated Pitting 0.06 ins = 24% Wall Penetration HIGH SIDE = UP ' Cross Sections page 1 ' `. KU P 1Y-06A ConocoPhillips In I Attributes A MD le & m ore APVUWI Fldtl Name Wd1Starus In (1 ND(RKB) AMBhn (RKB) 500292095801 KUPARUK RIVER UNIT PRODUCING 52.00 8,394.00 8,494.0 Comment N2S (ppm) Date Mnaration End Date KB-Ord (R) Rlg Release Dare Wan Conn 1Y -06A, 3L30/2009 12 47 55 PM SSS\/: NIPPLE 100 8/182008 Lest WO: 36.01 524/1983 5gF Mnotation Depth (M(B) End Date Mrtdatfon Last Nbtl By Erltl Date Lest Tag: SLM 8,300.0 829/2009 Rev Reason: TAG SLM triplwj 8/302009 Casino Strin s String UD String ID Set Depth Set Depth ITVD) String Wt String Casing Description (in) on) Top (ft B) (nKB) (CBI (Ibsflt) Grade string Top Thrd ' CONDUCTOR 16 15.060 36.0 116.0 116.0 65.00 W40 SURFACE 95/8 8.765 0.0 2,458.0 2,199.8 40.00 J -55 PRODUCTION 7 6.151 0.0 6,130.0 4,772.4 26.00 K -55 LINER 312 2.867 5,915.0 8,492.0 6,433.9 9.30 L -80 CONDUCTOR 16 Tubing Strings StntKJ OD stung ID Set Depth Set Depth (TVD) Stung Wt stung Tubing Description (In) (in) Top MKB) IRKB) (RKB) gbsreq Gratle String Top Third TUBING 1 312 2.992 0.0 5,944.0 4,629.2 9.30 J -55 ABM EVE NIPPLE, 505 Other In Hole All Jewelry: Tubing Run & Retrievable Fish etc. Top Depth ' (TVD) Top In Top (Will (CBI ( °) I Description Comment Run Date ID on) 505 505.01 0.19 NIPPLE Camco'DS Nipple 826/1997 2.812 3,061 2,599.8 46.76 GAS LIFT CAMCO/KBUG/l /GLVBK/.156 /1393 /Comment: STA1 425/1999 2.860 4,944 3,909.2 46.08 GAS LIFT CAMCO/KBUG/l/GLVBK/.188 /1450 / Comment: STA 4,25/1999 2.860 SURFACE, 5,865 4,570.1 41.99 GAS LIFT CAMCO/MMW1.5 /0V/RK/.188/ /Comment: STA3 425/1999 1860 ahe 5,911 4,605.0 42.27 NIPPLE Camco'D' Nipple NO GO 826/1997 2.750 5,920 4,611.6 42.20 SEAL Beker'GH &22' Seal Assembly 826 11997 j 3.000 GAS LIFT. Perforations & Slots U61 &het ' Top KS) &(A (7VD) Dens To Itl(B Btm B (NKB) (tnce) Zone Date (sh-- Type Comment 7,762 7,782 5,971.3 5,984.5 C-4, 1Y -06A 21132005 6.0 APERF 2.5" PJ HSD, 60 deg Ph 7,902 7,912 6,070.6 6,076.8 C-1, 1Y -06A 1252000 4.0 APERF 2.5" HC, 180 deg. phasing, oriented +/- 90 deg. from the low side cns LIFT, 8,098 8,138 6,191.3 6,215.9 A-4, 1Y-06A 7/10/1998 4.0 APERF 180 deg phasing, orient. 90 de fAm 4,944 g ' side; 2 12" HC, DP 8,098 8,138 6,191.3 6,215.9 A-4, 1Y-O6A 2/13/1999 6.0 RPERF 60 deg phasing, 2 12" HC BH 8,168 8,188 6,234.4 6,246.7 A-3, 1Y -O6A 9/15/1997 4.0 IPERF 180 deg. phasing; Oriented 25 deg. cns LIFT, CCW F/ High Sde; 2 1/2" HSD BH s,e6s Notes: General & Safet ' End Date Annotation 8/42002 NOTE: WAIVERED WELL IA OA ANNULAR COMMUNICATION riiPPLL, x,911 SEAL. 5,920 PRODUCTION, 6,130 PPE ' l 702 -7 182 82 RPERF, 7,902 -7,912 RPERF. 8 098-8,138 RPERF, 8O 9".138 IPERF, 6.16 &8.188 LINER.. TD( 1Y - 8,494 s,a9a trola /os NO. 5414 Schfumberger -DCS � C f11 j)4t 2525 Gambell Street, Suite 400 i 1�„�"" ).} 1., �' !� Lv Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2836 4d' Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99601 Field: Kuparuk Well Job A Log Description Date SL Color CD 1Y -06A AP30-00056 CH EDIT CFRT 09105109 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 ~3 (~C~ {~d~`~ r~~` ~ r~a ~~ rb~53 Scdlwnberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorege, AK 99503-2836 ATTN: Belh Well f~ ~1 ~ ~3 `~ - ~~ ~r c~ ~ ~ Job a Log Description Date NO. 5359 Company: IUaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Mcborage,AK 99501 Field: Kuparuk BL Color CD iJ-105 1J-136 tE-i66 ~~'~72A 1Y-a;A B2WY-00017 B2WY-00020 B2WY-00025 AXBD-00042 M30-00056 MEMINJECTIONPqOFILE MEMINJECTIONPROFILE ~ MEMPHODUCTIONPpOFILE MEMPRODUCTIONPpOFILE - SFRT - 07/23/09 08/24/09 pgrz5~pg 08/29Po9 09/OSPo9 1 1 ~ 1 1 1 ~ ~ 1 7 Please sign antl return one copy of this transmittal to Belh at the above atltlress or fax to (907) 567•8317. Thank you. osii uos ; ~;. , ° ~ ' k : ~' °~~:'~:~ ! ~f :`-,!~)f, ~ • y~ ` ,.. ...~ ~ ~~,« ti`~~`` ~~~~~tt'.t "„ ~li ~ ~ ~ ~~ il~i~~~~~~~~ NO. 5005 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ' ~: ;' + ~, z ~ ~ ~ ` . _ Attn: Christine Mahnken ATTN: Beth ~~.:~ ~~~a~ ,~~„' 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE / - ~ • 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE 9 ~ 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE - 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL _ / 11/28/08 1 1 30-01 12097434 LDL -~ ~- 11/29/08 1 1 1E-04 12097436 LDL 'T 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE l - 11/27/08 1 1 1 H-16 12096581 PRODUCTION PROFILE ) - 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE L - 1 12/02/08 1 1 iG-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE 12/08/08 1 1 iJ-102 12086701 INJECTION PROFILE ( 12/14/08 1 1 1 D-07 12114999 USIT 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE ) 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE _ ~ 12/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ConoeoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 30, 2008 ~ AUG ~. 2008 Mr. Tom Maunder Alaska Oil & Gas Commission ~~' ~ .. 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 July 27, 2008. The corrosion inhibitor/sealant was pumped July 3 and July 30, 2008. 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. Sincerely, ~~ ~ M.J. Loveland 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 r Date 7/30/2008 Well Name 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 1Y-O6A 197-134 6" NA 6" NA 1 7/3/2008 1 Y-08 183-062 6" NA 6" NA 1 7/3/2008 1Y-18 193-106 15" NA 15" NA 1.7 7/3/2008 1Y-19 193-107 25" NA 25" NA 4.25 7/3/2008 1 Y-23 193-071 14" NA 14" NA 1.7 7/3/2008 1 Y-25 188-089 12" NA 12" NA 2.5 7/3/2008 30-01 188-073 SF NA 16" NA 3.5 7/30/2008 30-02A 207-158 SF NA 15" NA 3.1 7/30/2008 30-03 188-075 SF NA 16" NA 3.2 7/30/2008 30-06 188-060 18' 4.90 18" 7/27/2008 5.25 7/30/2008 30-08 188-064 9' 4" 9.50 36" 7/27/2008 25 7/30/2008 30-10 188-059 15' 3.00 16" 7/27/2008 6.3 7/30/2008 30-11 188-042 53' 5.90 46" 7/27/2008 12 7/30/2008 30-13 188-040 SF NA 12" NA 2 7/30/2008 30-15 188-031 32' 5.80 23" 7/27/2008 5.3 7/30/2008 30-18 188-026 39' 5.30 18" 7/27/2008 10 7/30/2008 Schlumbepger 08/24105 NO. 3456 /q-7- 3'( Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 1 E-18 }/»)3 ··C ì (" 11015713 LEAK DETECTION LOG 08/06/05 1 1 F-01 J SJ.. -.1 ¡'I 11047354 PRODUCTION PROFILE W/DEFT 07/31/05 1 1Y-06A 19-r--1 J 'i 11015712 PRODUCTION PROFILE W/DEFT 08/05/05 1 3J-06 ¡ $S'- - Á I 'i 11056679 PRODUCTION PROFILE W/DEFT 08/19/05 1 1Y-31 ; '}3 - 0'10 11015708 PRODUCTION PROFILE W/DEFT 08/03/05 1 1 B-1 0 iSí -) J~' 11056671 PRODUCTION PROFILE W/DEFT . 08/12/05 1 3G-10 ; eft.·· C ¿h 11056670 INJECTION PROFILE 08/11/05 1 2Z-23 } q f;-- () I Ù 11015717 INJECTION PROFILE 08/10/05 1 2X-06 S ~ - 11 D 11015711 INJECTION PROFILE 08/04/05 1 2X-07 I (n '.' /J J 11015710 INJECTION PROFILE 08/04/05 1 1 Y -04 I J 3- , {, ~ 11047351 INJECTION PROFILE (REDO) 07/27105 1 SIGNED: µoiLJ DATE: ;SÇf-\NNEf SEP O? 2005 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD _.' r~7 J/)' 4~ S-· STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D RepairWell D Plug Perforations D Stimulate 0 Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 197-1341 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-029-20958-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 97' 1Y-06A 8. Property Designation: 10. FieldlPool(s): ADL 25646, ALK 2577 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8494' feet true vertical 6435' feet Plugs (measured) Effective Depth measured 8098' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 116' 16" 116' 116' SUR. CASING 2361' 9-5/8" 2458' 2200' PROD. CASING 6033' 7" 6130' 4769' LINER 2577' 3-1/2" 8492' 6434' RECEIVED Perforation depth: Measured depth: 7902'-7912',8098'-8138',8168'-8188' OCT 1 92004 true vertical depth: 6061'-6068',6186'-6211',6230'-6243' 0" & '"'as Cons. Commission Ala:>ka " \J Anchorage Tubing (size, grade, and measured depth) 3-1/2" , J-55, 5944' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP 505' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7880'-7925' MD Treatment descriptions including volumes used and final pressure: 7.5% HCI acid job 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation nla -- Subsequent to operation 267 240 403 -- 176 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name #;Ooney Title Wells Group Team leader Signature --I1~ Phone Date /Y6/oí' " hRrron AllcolJro-nrak" 2R.~-4R 12 Form 10-404 Revised 04/2004 OR'G'¡\~AL ~ ~ ~riginal Only 1Y-06A Well Events Summary Date Summary 04/21/04 FCO TO TAG @ 8373' FOLLOWED WITH 7.5% HCL C SAND ACID JOB DOWN COIL. [Other Stim] . ConocoPl'lIIl"'" AWI,,-, Inc. KRU 1Y-O6A 1Y-O6A API: 500292095801 Well TVDe: PROD Anale (â) TS: 49 dea (â) 7761 SSSV Type: Nipple Orig 8/27/1997 Angle @ TD: 52 deg @ 8494 Completion: Annular Fluid: Last w/o: Rev Reason: TAG FILL MIT NIP (505-506. Reference Loa: Ref Loa Date: Last Update: 4/27/2004 00:3.500) Last Taa: 8098 TD: 8494 ftKB lUBING Last Taa Date: 4/1212004 Max Hole Anole: 52 dea (â) 8494 (0-5944. Casino StrIne - ALL STRINGS 00:3.500. Description Size Top Bottom TVD Wt Grade Thread 10:2.992) CONDUCTOR 16.000 0 116 116 65.00 H-40 SUR. CASING 9.625 0 2458 2200 40.00 J-55 PROD. CASING 7.000 0 6130 4769 26.00 K-55 LINER 3.500 5915 8492 6434 9.30 L-80 Tubing String ~ TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 5944 I 4629 I 9.30 I J-55 I ABM EUE Gas Lift Perforations. SummarY MandrelNal"" Interval TVD Zone Status Ft SPF Date Type Comment 1 (3061-3062, 7902 - 7912 6061 - 6068 C-1 10 4 1/25/2000 APERF 2.5" HC, 180 deg. phasing, PROD. oriented +/- 90 deg. from the CASING low side (0-6130, 00:7.000, 8098 - 8138 6186 - 6211 A-4 40 10 2/13/1999 RPERF 60 deg phasing, 2 1/2" HC Wt26.00) BH 8168 - 8188 6230 - 6243 A-3 20 4 9/15/1997 IPERF 180 deg. phasing; Oriented 25 deg. CCW F/ High Side; 2 1/2" HSD BH Gas Lift MandrelsNalves Gas Lift St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv MandrelNal"" Mfr Run Cmnt 2 1 3061 2600 Cameo KBUG GLV 1.0 BK 0.156 1393 4/25/1999 {4944-4945. 2 4944 3909 Cameo KBUG GLV 1.0 BK 0.188 1450 4/25/1999 3 5865 4570 Cameo MMM OV 1.5 RK 0.188 0 4/25/1999 .... Other (I duase oul o,.....ete;l...JEWELiR'( ....... . DeDth TVD Tvee Description ID ...... 505 505 NIP Cameo 'DS' Nipple 2.812 ... 5911 4604 NIP Cameo 'D' Nipple NO GO 2.750 5920 4611 SEAL Baker 'GHB-22' Seal Assembly 3.000 ... General Notes Date INote Gas LIft D 8/4/2002 I WAIVERED WELL: IA X OA ANNULAR COMMUNICATION MandrelNal"" 3 (5865-5866, NIP (5911-5912, 00:3.500) SEAL {592D-5921 , 00:3.500) LINER (5915-8492, 00:3.500, Wt9.30) - - Perf (7902-7912) - - - - Perf (8098-8138) - - Perf - - (8168-8188) - - Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~iIIi ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 15, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1Y-06A (APD # 197-134) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 Y -06A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, Nt, JJ/~ M. Mooney Wells Group Team leader CPAI Drilling and Wells RECFIVEO OCT 1 9 2004 MM/skad Alaska Oil & Gas Con:.. t;omíH¡$siQn Anchorage O\-Z \ b\\~¡-\L MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor DATE: FROM: John Crisp, SUBJECT: Petroleum Inspector May 17-18, 2001 Safety Valve Tests Kuparuk River Unit 1Y Pad May 17 & 18,2001: i traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. ! witnessed one failure, the LPP failed to trip above 50% of primary separator pressure. The pilot was re-tested & passed the re-test. The AOGCC test report is attached for reference. I conducted 25 well house inspections on 1Y Pad. The majority of the houses were in good shape w/no problems witnessed. Well houses # 30 & 22 were found w/the well house lids resting on the tree cap gauges. The VSM for the flow line on well # 29 looked as if it had shifted up & had the line in a slight bind. ! asked Phillips Rep. Pete Nezaticky to inspect this line. Prudhoe Bay Field has had problems w/VSM's shifting up & ! wanted to make sure KRU Rep's were aware of this problem. SUMMARY: I witnessed SVS testing in Kuparuk River Field. 16 wells, 32 components tested. 1 failure witnessed. 3.13% failure rate. 25 well house inspections conducted. Attachments: SVS KRU 1Y 5-17 & 18-01jc C,C,; NON-CONFIDENTIAL SVS KRU 1Y 5-t7 & 18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Ernie Barndt AOGCC Rep: John Crisp Submitted By: John Crisp Date: 5/17 & 18/01 Field/Unit/Pad: Kupamk River Unit 1Y Pad Separator psi: LPS 85 HPS i i i . ?~ ~?~-~: ~.-:._.~/ ~!~--~!~:~-~i'~ ~i~ ..~SSVi~::~ SSSV .:'~: Rete~. 'weft. Type .:~ ,~?~_:-~_:-~¢.~;~:.7~:¢:~:;:.-.~:;~.;.~>¢;~:¢~:~:; ~/;55.-¢~x~/?:~--:-:.;C-~z-~'/fZ.;:~-;.?~:~;-::~ ~-:,:~-/-?.:c/.1~>;~:;:i?-,~'.~:,- 'j.~.:'-~" --~::~ i:;: :,; 'r~ :, v . .I . . ' u : ' . .... ': ' Well Pemit Separ Set L~ Test Test Test Date Oil, WAG, G~J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCLE 1Y-01 1830500 ~ ,, 1Y'02 1830590~ 1Y-03 1830610: 3750 2000 1800 P P WAG 1Y-04 1830660 ,1.Y;05.~:;,:~_ :.._. 1830870 ["..Y~06A::~ ~ ;/1971340 85 70] 55 p p OIL 1Y-07 1830680 , , 1Y-08 1830620 . 1Y-09 1830520 1Y-10 1830510 37~0 ' . 2000 1750 P 'P W~G 1Y-11 1830410 1Y-12 1830260 1Y-13 1830150 1Y-14 1830230 1Y-15A 1981860 85 70 50 P P OIL 1Y-16 1830420 1Y-17 1930680 85 60 60 P P OIL , 1 Y- 18 1931060 1Y-19 1931070 85 60 65 P P OIL 1Y-21 1931020 85 70 65 P P OIL 1Y-22 19307~ 85 60 55 P P OIL . 1Y-23 1930710 85 70 28 3 P 5/18/01 OIL , , , 1Y-24 1930720 85 70 78 P P OIL 1Y-25 1880890 1Y-26A 1881160 85 70 50 P P OIL 1Y-27 1930880 85 70 ~ P P OIL 1 Y-28 1930890 , 1Y-29 1880910 85 70 60 P e OIL 1Y-30 1880900 85 70 70 P P OIL 1Y-31 1930900 1 Y-32 1880930 85 701 70 P P OIL , 1Y-34 1930910 85 70 65 p p OIL Wells: 16 Components: 32 Failures: 1 Failure Rate: 3. ~ 3% [2] 90 var ,~ RJF ~"l~/~rl~: Pege I nf9 qyq 1~11 1V q_1'7 ,t~ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE RJF 1/16/01 Page 2 of 2 SVS KRU 1Y 5-17 & 18-01jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 97 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 571' FNL, 1911' FWL, Sec. 1, T11 N, R9E, UM (asp's 531579, 5974755) 1Y-06A At top of productive interval 9. Permit number / approval number 2324' FSL, 542' FEL, Sec. 1, T11 N, R9E, UM (asp's 534419, 5972386) 197-134 At effective depth 10. APl number 50-029-20958-01 At total depth 11. Field / Pool 2580' FNL, 97' FEL, Sec. 1, T11N, R9E, UM (asp's 524862, 5972761) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8494 feet Plugs (measured) Tagged PBTD (5/19/00) @ 8382' MD. true vertical 6435 feet Effective depth: measured 8382 feet Junk (measured) true vertical 6366 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 116' 16" 280 Sx AS II 116' 116' SURF CASING 2361' 9-5/8" 1000 Sx AS III & 2458' 2200' 368 Sx AS I PROD CASING 6033' 7" 900 Sx G, 150 Sx AS I 6130' 4769' LINER 2577' 3-1/2" 448 Sx Class G 8492' 6434' Perforation depth: measured 7902 - 7912'; 8098 - 8138'; 8168 - 8188' i ECEIYED true vertical 6061-6068'; 6186-6211'; 6230-6243'FEB1 32001 Alasl(a 0il & Gas Cons, Comrnissior Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tubing @ 5944' MD. Anchorage Packers & SSSV (type & measured depth) No Packer. Camco 'DS' @ 505' MD. , 13. Stimulation or cement squeeze summary .... ' ! ~ ~ ;~ ~ i i :'./ /i , Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 277 0 14 - 156 Subsequent to operation 374 23 156 - 177 15. Affachmants 16. Status of well classification as: Copies of Logs and Surveys run _ 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. Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE'~ 1Y-06A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/25/00: MIRU & PT equipment. RIH w/perforating guns & shot 10' of perforations in the 'C1' sand as follows: Added perforations: 7902 - 7912' MD Used 2-1/2" Hollow carriers & shot the perfs at 4 spf at 180 degree phasing. POOH w/guns. RD. Returned the well to production & obtained a valid well test. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2 001. M PL A T E E IA L U N D W E R T H IS M ARK ER C:LORI'hMFILM.DOC AOGCC Geological Materials Inventory ._ . PERMIT 97-134 ARCO Log Data Sent Recieved 8140 ~RRY GR/EWR4 10/15/97 10/15/97 DGR/EWR4-MD .~60-8494 10/22/97 10/22/97 Box DGR/EWR4-TVD ~4q88-6450 10/22/97 10/22/97 MWD SRVY /~PERRY 6101-8494 ]~ ~.~/, ,~ i~.,; 9/30/97 10/1/97 MWDSRVZ t~pPERRy 6101-8494 I~")t~7~/.:~:~J. jTi~'~' 10/31/97 11/3/97 ~'~407 Completion Date ?//3'/ 7 ? Daily well ops f:"~ ;w43~/~' 2 Are dry ditch samples required? Was the well cored? yes ~ffo Analysis description recieved? Are tests required? yes ~.~,~ no Received? r.~-~eS~--~ no Well is in compliance ~J-4) Initial Comments yes ~o And received?,.~.~___y~--~----~ no Thursday, September 23, 1999 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__~_X Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name bf Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 32' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service _~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 571' FNL 1911' FWL, Sec 01, T11N, R9E, UM 1Y-06A At top of productive interval: 9. Permit number/approval number: 2324' FSL, 542' FEU Sec 01, T11 N, R9E, UM 97-0134 At effective depth: 10. APl number: 2631' FNL 175' FEU Sec. 01, T11N, R9E, UN 50-029-20958-01 At total depth: 11. Field/Pool: 2580' FNL 97' FEU Sec 01, T11 N, R9E, UM Kuparuk River Field/Pool 12. Present well condition summary Total Depth: measured 8494 feet Plugs (measured) true vertical 6435 feet Effective Deptt measured 8393 feet Junk (measured) true vertical 6373 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 84' 16" 280 Sx AS II 116' 121' Surface 2426' 9-5/8" 1000 Sx AS III & 2458' 2200' 368 Sx AS I Production 6098' 7" 900 Sx Class G& 6130' 4769' 150 Sx AS I Liner 2577' 3.5" 448 Sx Class G 5915'-8492 4607'-6434 Perforation Depth measured 8098'-8138'; 8168'-818E true vertical 6186'-6211" 6230' - 6243 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, @ 5943' ME Packers and SSSV (type and measured depth) Baker GBH-22 Packer @ 5920' MD; NO SSSV ..... . 13. Stimulation or cement squeeze summary Addedperfinterva, 8098'-8138' ~'~"~ "" i ~i Z/iL Intervals treated (measured) A4 Frac 8098'-8138' Treatment description including volumes used and final pressure PLACED 52576# OF 12/18 PROPPANT TO 6 PPA IN PERFS. LEFT 17040# IN PIPE. SHUTDOWN ON MAX. TREATING PRESSURE OF 700O PS 14. Representitive Daily Average Production or Injection Data Oil~Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 164 82 82 1267 196 Subsequent to operation 475 36 238 92 206 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ 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. Signed ~S~ Title: ~ ~~ Date ~'/~r~'/~'~ SUBMIT IN DUPLICATE~~~ Form 10-404 Rev 06/15/88 ARCO Alaska, Inc. '-' KUPARUK RIVER UNIT v~ELL SERVICE REPORT 1Y-06A(4-1)) WELL JOB SCOPE JOB NUMBER 1Y-06A PERFORATE, PERF SUPPORT 0701981849.2 UNIT NUMBER DATE 07/1 O/98 DAY 1 FIELD ESTIMATE DAILY WORK PERFORATE "A4" SAND OPERATION COMPLETE ISUCCESSFUL~ Yes O No ~ Yes O No IKEYPERSON AFC# ICC# I DALLY COST ACCUM COST KAWWRK 230DSl 0YL $20,492 $22,504 I OA IFinalOA ITTLSizo Initial Tbg I Final Tbg l Initial IA Final IA l Initial 1150PSII 700 PSII 1400PSl 1400PSII 0 PSI 0 PSI I 0.000" SUPERVISOR SCHWENDERMAN Signed Min ID I Depth 0.000" I 0 F-I- DALLY SUMMARY RAN PERF GUN ASSEMBLY #1. 2-1/2" HC, DP, 4 SPF, 180 DEG PHASING. TIE IN AND PERFORATE 3.5" LINER F/ 8138' TO 8118'. POH. RAN PERF GUN ASSEMBLY #2 SAME AS ABOVE. TIE IN AND PERFORATE F/8118' - 8098'. [Perf] TIME LOG ENTRY 13:00 MIRU SWS (STEPHENSON AND CREW) TGSM CHECK OUT EQUIPMENT, TO BE IN GOOD SHAPE. COMMENCE RADIO SILENCE. MU #1 PERF ASSEMBLY 20' (2-1/2" HC, DP, 4 SPF, 180 DEG PHASING, 90 DEG FROM LOWSIDE, CCL, WT) TL= 27', PT 3000 PSI. 15:30 RIH. TAG BOTTOM AT 8371' RKB. TIE IN W/SCHLUMBERGER PERFORATION LOG DATED 9/15/97. WITH WELL FLOWING AND GAS LIFT SHUT OFF, PERFORATE F/8138' - 8118', GOOD SURFACE INDICATIONS. POH 18:30 AT SURFACE RD. ALL SHOTS FIRED. MADE UP PERF GUN ASSEMBLY #2 SAME AS ABOVE. RIH, ANDTIE IN AND PERFORATE WITH WELL FLOWING F/8118' - 8098'. GOOD SURFACE INDICATIONS. POH. 21:30 AT SURFACE RD, ALL SHOTS FIRED. RETURN WELL BACK TO DSO AND ON PRODUCTION. 'SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $120.00 APC $200.00 $200.00 HALLIBURTON $0.00 $892.00 LITTLE RED $0.00 $1,000.00 SCHLUMBERGER $20,292.00 $20,292.00 TOTAL FIELD ESTIMATE $20,492.00 $22,504.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT · ~ ~LL SERVICE REPORT 1Y-06A(4-1)) WELL JOB SCOPE JOB NUMBER 1Y-06A DRILLING SUPPORT-EXP WORKOVER 0207990512.1 DATE 02/13/99 DAY 1 FIELD ESTIMATE DAILY WORK REPERFORATE A4 SAND FOR FRAC OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ('~ Yes ¢'~ No ~ Yes O No SWS-VETROMILE AFC# ICC# I DAILY COST ACCUM COST 999354 230DS 10YO $16,799 $26,870 InitialTbg IFinalTbg InitiallA IFinallA IlnitialOA IFinalOX ITTLSize 1100PSII 1050PSI 200PSI 200PSI 0PSI 0PSI] 0.000 " UNIT NUMBER 8345 SUPERVISOR LIGENZA Signed Min ID I Depth 0.000" [ 0 FT DALLY SUMMARY PERFORATE A4 SAND FROM 8098' TO 8138' W 2-1/2" HC, BH, 6 SPF, 60 DEGREE PHASE. [Perf] TIME LOG ENTRY 08:00 MIRU SWS. TGSM. 09:00 CRANE BOOM WILL NOT RAISE/LOWER, EXTRACT. CALL FOR MECHANIC. 11:00 CRANE REPAIRED. RESUME RIG UP. NOTIFY SECURITY AND ALL PAD PERSONNELL OF RADIO SILENCE. 11:45 PRESSURE TEST LUBE / BOPS TO 3,000 PSI. 12:20 RIH W/20' BY 2-1/2" HC, BH,6 SPF, 60 DEGREE PHASE, SAFE, CCL. 9.5' FROM TOP SHOT TO CCL. TOTAL LENGTH=32.6'. 13:20 MAKE TWO TIE IN PASSES AND LOCATE AT 8108.5'. 13:55 LOCATE AT 8108.5'. PLACING TOP SHOT AT 8118' TO SHOOT FROM 8118' TO 8138'. ONLY MINOR INDICATION SHOTS MAY HAVE FIRED. LOG UP. POH 14:50 ON SURFACE, SHOTS DID NOT FIRE. NO PROBLEMS FOUND. CHANGE OUT SHOT CARTRIDGE. 15:30 RIH W/SAME TOOL STRING. 16:30 MAKE TIE IN PASSES. 16:50 MADE SEVERAL ATTEMPTS TO FIRE. NO INDICATION SHOTS FIRED. POH. 17:45 ON SURFACE. NO SHOTS FIRED. EXAMINE TOOL STRING. RETIED HEAD. 19:20 RIH W / SAME TOOL STRING. 20:20 MAKE TIE IN PASSES. 20:30 LOCATE AT 8108.5'. PLACING TOP SHOT AT 8118' TO SHOOT FROM 8118' TO 8138'. INDICATION SHOTS FIRED. LOG UP. POH. 21:20 ON SURFACE, ALL SHOTS FIRED. 21:45 RIH W / SIMILAR TOOL STRING. 9.5' FROM TOP SHOT TO CCL. 22:45 MAKE TIE IN PASSES. LOCATE AT 8088.5' TO PLACE TOP SHOT AT 8098'. INDICATION SHOTS FIRED. LOG UP. POH. 23:45 ON SURFACE, ALL SHOTS FIRED. RDMO SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $720.00 APC $0.00 $3,000.00 HALLIBURTON $0.00 $3,271.00 LITTLE RED $0.00 $3,080.00 SCHLUMBERGER $16,799.00 $16,799.00 TOTAL FIELD ESTIMATE $16,799.00 $26,870.00 ARCO Alaska, Inc. ~-'~ KUPARUK RIVER UNIT ,.CELL SERVICE REPORT 1Y-06A(4-1)) WELL JOB SCOPE JOB NUMBER 1Y-06A FRACTURING. 0702991559.6 UNIT NUMBER DATE 02/20/99 DAY 4 FIELD ESTIMATE DAILY WORK PUMP "A" SANDS FRAC OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ~ Yes ~ No ~ Yes ~ No DS-YOAKUM AFC# ICC# I DAILY COST ACCUM COST 999354 230DS 10YL $126,876 $142,620 I I OA IFinalOA ITTLSize Initial Tbg I Final Tbg I Initial IA Final IA Initial 1240 PSII 500 PSII 500 PSI 500 PSI 0 PSI 0 PSII 0.000 " SUPERVISOR JOHNS Signed Min ID I Depth 0.000" I 0 FT DAILY SUMMARY PLACED 52576# OF 12/18 PROPPANT TO 6 PPA IN PERFS. LEFT 17040# IN PIPE. SHUTDOWN ON MAX. TREATING PRESSURE OF 7000 PSI. [Frac-Refrac] TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LITTLE RED SERVICES 08:00 HELD ON SITE SAFETY MEETING, MUSTER AREA BEHIND FRAC TANKS. 08:30 PUMPED BREAKDOWN, 1PPA & 2 PPA SCOUR AND FLUSH. TOTAL 404 BBLS MAX. 8223 PSI AT 30 BPM, MIN 6115 PSI AT 15 BPM FLUSH. 08:53 SHUTDOWN FOR ISIP 2138 PSI. 09:40 PUMPED DATA FRAC AND FLUSH. TOTAL 184 BBLS 10:01 SHUTDOWN FOR CLOSURE CALCULATIONS 11:04 PUMPED 400 BBLS PAD, 5 TO 15 BPM. MAX. 5923 PSI. 11:23 PUMPED 426 BBLS FLUIDS WITH 2PPA TO 6PPA 12/18 PROPPANT. MAX. TREATING 7000 PSI. TOTAL OF 52578# TO PERFS AND LEFT 17040# IN PIPE. 12:14 PRESSURED OUT AND SHUTDOWN FRAC. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $160.00 APC $6,000.00 $8,660.00 ARCO $500.00 $500.00 DIESEL $0.00 $42.00 DOWELL $115,776.00 $121,560.00 HALL I BU RTO N $0.00 $3,948.00 LITTLE RED $4,600.00 $7,750.00 TOTAL FIELD ESTIMATE $126,876.00 $142,620.00 STATE OF ALASKA AU,_. ,A OILAND GAS CONSERVATION COMMIS,;.. ~N. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well 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 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 2324' FSL, 542' FEL, Sec. 1, T11N, R9E, UM At effective depth 2631' FNL, 175' FEL, Sec. 1, T11N, R9E, UM At total depth 2580' FNL, 97' FEL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8494 6435 8393 6373 feet feet feet feet 6. Datum elevation (DF or KB) RKB 32 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-06A 9. Permit number/approval number 97-134 10. APl number 50-029-20958-01 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) None ORI61NAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 2421' 6096' 2577' measured 16" 280SxAS II 116' 116' 9-5/8" 1000 Sx AS III & 2458' 2200 368 Sx AS I 7" 900 Sx CI G/150 SxAS I 6130' 4769 3.5" 175 Sx Class G 8492' 6 4 3 4 7565'-7659',7796'-7800',7809'-7834',7859'-7863',8168'-8188 true vertical 5843'-5904',5994'-5996',6002'-6018',6035'-6037',6233'-6245' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft. , J-55 @ 5943' Packers and SSSV (type and measured depth) Pkr: Baker GBH-22 Locater @ 5919'; SSSV: None, nipple @ 505' 13. Stimulation or cement squeeze summary Fracture stimulated "A" sands on 9/17/97. Intervals treated (measured) 7796'-7800',7809'-7834',7859'-7863',8168'-81 88 Treatment description including volumes used and final pressure Pumped 117 Mlbs of 12/18 ceramic proppant into formation, fp = 9300 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1288 Subsequent to operation 6 7 6 416 126 1302 187 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily/J;14~ort of Well Operations X Oil X Gas Suspended 17. I h/Creby ~ertify that the foregoing is true and correct to the best of my knowledge. S ignedl~'~_~7( / ~,,~~.¢ Title Wells Superintendent Service SU Md N bU UCA ARCO Alaska, Inc. KUPARUK RIVER UNIT ~-~ '' WELL SERVICE REPORT '~ KI(Y-06A(W4-6)) WELL JOB SCOPE JOB NUMBER 1Y-06A FRAC, FRAC SUPPORT 0915971814.8 DATE DAILY WORK UNIT NUMBER 09/17/97 PUMP INITIAL "A" SANDS FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O No O Yes (~ No DS-YOKUM JOHNS ..., ESTIMATE 998757 230DS10YG $151,675 $168,275 Initial Tb.q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial OutePAn'n . FinallC;~te, Ann DAILY SUMMARY PUMPED INITIAL "A" SANDS FRAC WITH 117,000 # UP TO 9.7 ppA 12/18 PROPPANT AT PERFS. WELL PRESSURED OUT EARLY. LEFT 22619# IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LI'I-I'LE RED PUMP AND APC VAC TRUCK. 07:30 HELD SAFETY MEETING 07:56 PUMPED BREAKDOWN, SCOUR AND FLUSH STAGES WITH 416 BBLS FLUIDS AT 30 TO 15 BPM AND 8200 TO 2885 PSI. 08:57 PUMPED DATA FRAC AND FLUSH WITH 183 BBLS FLUIDS, 5 TO 15 BPM AND 5490 PSI. 10:19 PUMPED 237 BBLS PAD OF 50 # X-LINKED GEL AT 15 BPM AND 4940 PSI. 10:44 PUMPED 11579# OF 20/40 PROPPANT AT 2 PPA AND 15 BPM, 4501 PSI. 10:54 PUMPED 12/18 PROPPANT FROM 2 PPA TO 10 PPA AT 15 BPM, WELL PRESSURED OUT AT 9.7 PPA TO PERFS. MAX. TREATING PRESSURE 9300 PSI. 11:34 SHUTDOWN AND RDMO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $3,000.00 $9,000.00 ARCO $340.00 $340.00 DOWELL $147,035.00 $156,035.00 LITTLE RED $1,300.00 $2,900.00 TOTAL FIELD ESTIMATE $1 51,675.00 $168,275.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Y-06A (Permit No. 97-134) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1Y-06A. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Development WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS ~-~ SUSPENDED [] ABANDONED~ SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-134 3 Addr~s 8 APl Number . P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20958-01 ://.;...:., /, 4 Location of well at sudace 9 Unit or Lease Name ;" r ' AtTopProducinglnte~al~ ~~~ ~ ~1 ~ : 10 WellNumber 5 Elevation in foot {indicale KB, DF, olc.)I~ koase Dosi~nation and Sodal ~o. ~ordic ~i~ ~K8 32', ~a0 ~5'~ A~k 25~4~ AkK 2577 ~2 Dato Spuddod ~ ~ Date T.D. 8oachod ~4 ~ato ~omp., Susp. or ~band. I 15 Walor ~epth, if o~shoro 1 ~ ~o. o[ Gomplofions 18-Au~-O7 28-~u~-~7 ~ 5-Sop-07~ ~A ~eot MSk 17 Total ~ep~h {M~+~D) ~8 ~lu~ Back Depth {MD+~D) 1~ Dirocflon~ Su~oy 20 Depth whero SSSV sot I 2~ Thicknoss o~ permafrost I 8494' MD & 6435' ~D 8393' MD & 6373' ~D YES ~ NO U NA feet MD 1465' APPROX 22 Type Electdc or ~her Logs Run G~R~ 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5~ H-40 SURF. 116' 24' 280 sx AS II 9.625' 40.0~ J-55 SURF. 2458' 12.25' 1000 sx AS III & 368 sx AS I 7" 26.0~ J-55 SURF. 6130' 8.5' 900 sx Class G & 150 sx AS I 3.5' 9.3~ L-80 5915' 8492' 6.125' 448 sx Class G 24 Perorations open to Produ~ion (MD+~D of Top and BoEom and 25 TUBING RECORD internal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 5943' 8168'-8188' MD 6233'-6245' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8168'-8188' 117,000~ up to 9.7 ppf 1W18 proppant at peals 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 9/21/97 Gas Lift Date of T~t Hours T~ted PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 10/21/97 12 TEST PERIOI: 475 584 ~ 176~ 329 FlowTubing Casing Pr~sure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Pr~ 178 ]2~ ~24-HOUR RATE: 879 289 120 24.3 28 CORE DATA Brief d~cfiption of lithology, porosity, fracture, apparent dips and pr~ence of oil, gas or water. Submit core chips. ORIGINAL N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. :.-, }.' Top KupamkC 77~a' 5072' ' ~,' BoSom Kupamk C 7916' 6070' r~],.. Top Kuparuk A 8087' 6179' .- BoSom Kupa~k A 8278' 6300' ¢~ r~;:,. ~.¢ .j~?,., 31. LIST OF A~ACHMENTS Summaw of Daily Drilling Repo~s, Su~eys 32. I hereby ~i~ that the foregoing is true and ~rrect to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 Date' 10/8/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page' 1 WELL:iY-06A WELL ID: AK8885 TYPE: -- AFC- AK8885 AFC EST/UL:$ STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: RIG:NORDIC 908M/ 1135M API NUMBER: 50-029-20958-01 BLOCK: FINAL: 08/26/97 08/03/97 (D1) TD: 0'( 0) SUPV:RLM DAILY:$ 08/04/97 (D2) TD: 0' ( SUPV: RLM o) DAILY' $ 08/05/97 (D3) TD: 0'( 0) SUPV:DLW DAILY:$ 08/06/97 (D4) TD: 0'( 0) SUPV:DLW DAILY:$ 08/07/97 (D5) TD: 0'( 0) SUPV:DLW DAILY:$ 08/08/97 (D6) TD: 0'( 0) SUPV:DLW DAILY:$ 08/09/97 (D7) TD: 0'( 0) SUPV:DLW DAILY:$ 08/10/97 (D8) TD' 0' ( 0) SUPV' DLW DAILY: $ 08/11/97 (D9) TD' 0' ( 0) SUPV' DLW DAILY' $ 08/12/97 (D10) TD' 0'( 0) SUPV' DLW DAILY'$ MW: 0.0 VISC' 0 PV/YP: RIG MAINTENANCE Secure pad. Pull rig off lB pad. 27,149 CUM:$ 27,149 ETD:$ o/ o APIWL: 0.0 0 EFC:$ 935,149 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG MAINTENANCE Move rig 4 miles from lB pad to 1Y pad. Prep rig to lay down derrick. 7,148 CUM:$ 34,297 ETD:$ 0 EFC:$ 942,297 MW: 0.0 VISC: 0 PV/YP: RIG MAINTENANCE Rig maintenance. 7,148 CUM:$ 41,445 ETD'$ 0/ 0 APIWL: 0.0 0 EFC:$ 949,445 MW- 0.0 VISC' 0 PV/YP: RIG MAINTENANCE Rig maintenance 7,149 CUM'$ 48,594 ETD.$ 0/ 0 0 EFC:$ APIWL: 0 0 956,594 MW' RIG MAINTENANCE Rig maintenance 7,149 CUM'$ 0.0 VISC: 0 PV/YP: 55,743 ETD'$ o/ o AP IWL. 0 0 0 EFC:$ 963,743 MW. RIG MAINTENANCE Rig maintenance 7,149 CUM'$ 0.0 VISC' 0 PV/YP' O/ 0 62,892 ETD'$ 0 EFC:$ APIWL' 0 970,892 MW' 0.0 VISC' 0 PV/YP' RIG MAINTENANCE Rig maintenance 7,149 CUM'$ 70,041 ETD-$ o/ o 0 EFC' $ AP IWL' 0 0 978,041 MW: RIG MAINTENANCE Rig maintenance 7,148 CUM'$ 0.0 VISC: 0 PV/YP: 77,189 ETD'$ o/ o 0 EFC:$ APIWL: 0 0 985,189 MW' RIG MAINTENANCE R~g maintenance 7,149 CUM'$ 0.0 VISC' 0 PV/YP' 0/ 0 84,338 ETD'$ 0 EFC'$ APIWL' 0 992,338 MW- RIG MAINTENANCE Rig maintenance 7,148 CUM'$ 0.0 VISC: 0 PV/YP: 91,486 ETD:$ o/ o 0 EFC:$ APIWL: 0.0 999,486 Date: 10/8/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/13/97 (Dll) TD: 0'( 0) SUPV:DLW DAILY:$ 08/14/97 (D12) TD: 7335' (7335) SUPV: DLW DAILY:$ 08/15/97 (D13) TD: 7020' ( 0) SUPV:DLW DAILY:$ 08/16/97 (D14) TD: 6150' ( 0) SUPV:DLW DAILY:$ 08/17/97 (D15) TD: 6150' ( 0) SUPV:DLW DAILY:$ 08/18/97 (DIS) TD: 6167' ( 17) SUPV:DLW DAILY:$ 08/19/97 (D17) TD: 6750' (583) SUPV:RLM DAILY:$ 08/20/97 (D18) TD: 7627' (877) SUPV:RLM MW: RIG MAINTENANCE Rig maintenance. 7,148 CUM:$ 0.0 VISC: 0 PV/YP: 98,634 ETD:$ 0/ 0 APIWL: 0.0 0 EFC:$ 1,006,634 MW: 9.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 NU BOPE Finish with the rig maintenance. Accept rig for operation @ 1100 hrs. 8/14/97. Pump water and mud down tubing. Well dead. 25,465 CUM:$ 124,099 ETD:$ 0 EFC:$ 1,032,099 MW: 9.6 VISC: 46 PV/YP: 11/15 APIWL: 10.2 L/D TBG N/D tree and N/U BOPE, function test. Test BOPE 300/3500 psi. Pull tubing to rig floor. Pump cement to P&A the well. Continue to pull and lay down tubing. 54,813 CUM:$ 178,912 ETD:$ 0 EFC:$ 1,086,912 MW: 9.5 VISC: 68 PV/YP: 16/29 APIWL: 8.0 MILL WEDGED WORKING TO FREE Continue to pull 3.5" tubing. RIH with whipstock. 47,343 CUM:$ 226,255 ETD:$ 0 EFC:$ 1,134,255 MW: 9.5 VISC: 60 PV/YP: 15/31 APIWL: 7.2 M/U DRILLING BHA & RIH Continue RIH w/whipstock assembly on 3.5" DP. Set whipstock w/bottom @ 6150' and top @ 6130'. Shear off whipstock wedged mill @ whipstock face was unable to rotate. Work and torque milling assembly to free up. Came free after 6 hrs. Start cutting window from 6130' to 6149' Was unable to shut off pump %2 continued to run while controls turned off. Continue cutting window from 6149' to 6160' Perform FIT, EMW of 11.7 ppg. 44,100 CUM:$ 270,355 ETD:$ 0 EFC:$ 1,178,355 MW: 9.7 VISC: 50 PV/YP: 12/15 APIWL: 6.8 DIRECTIONAL DRLG 6.125" @ 6270 Slide thru window @ 6130' to 6143'. MWD malfunction tool face jumping around all over. Unable to correct problem. Recalibrate MWD and rerun BHA #2. Broke air lines to hydromatic. Continue RIH w/BHA #2 to 6129' Slide thru window from 6130' to 6143' without pump. Start pump. Drill 6.125" hole from 6162' to 6167' 110,620 CUM:$ 380,975 ETD:$ 0 EFC:$ 1,288,975 MW: 9.7 VISC: 47 PV/YP: 13/17 APIWL: 5.2 DIRECTIONAL DRLG 6.125" @ 6924 Directional drill and survey with MWD from 6167' to 6367' Having problems making hole rotating or sliding. Circulate bottoms up while adding drill-n-slide. Still not able to make hole. Directional drill and survey with MWD from 6367' to 6750' 57,851 CUM:$ 438,826 ETD:$ 0 EFC:$ 1,346,826 MW: 11.2 VISC: 47 PV/YP: 21/21 APIWL: 4.0 CIRCULATE BOTTOMS UP Directional drill and survey with MWD from 6750' to 7627'. Perform OH LOT to 12.1 ppg. Date: 10/8/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 DAILY: $ 08/21/97 (D19) TD: 7914' (287) S UP V: RLM DAILY'$ 08/22/97 (D20) TD: 8422' (508) SUPV: RLM DAILY:$ 08/23/97 (D21) TD: 8494' ( 72) SUPV'RLM DAILY:$ 08/24/97 (D22) TD: 8494' ( 0) SUPV:RLM DAILY' $ 08/25/97 (D23) TD: 8494' ( 0) SUPV: RLM DAILY:$ 08/26/97 (D24) TD: 8494' ( 0) SUPV:RLM DAILY:$ 60,121 CUM:$ 498,947 ETD:$ 0 EFC:$ 1,406,947 MW: 11.2 VISC: 50 PV/YP: 24/21 APIWL: 3.8 WELL SHUT IN ON KICK Directional drill and survey with MWD from 7627' to 7669'. Losing mud. Reduced pump rate from 160 spm to 100 spm, no improvement in losses. Performed OH LOT to 12.6 ppg. Increased mud weight to 11.2 ppg. Directional drill and survey with MWD from 7669' to 7914' 59,795 CUM:$ 558,742 ETD:$ 0 EFC:$ 1,466,742 MW: 11.8 VISC: 50 PV/YP: 26/21 APIWL: 3.8 CONDITION MUD TO TRIP OUT Directional drill and survey with MWD from 7914' to 8173' Well flowing, shut in well. Increase mud weight from 11.2 to 11.5 ppg. Circulate kick out through choke. CBU. Bottoms up gas and oil cut to 10.7 ppg. Directional drill and survey with MWD from 8173' to 8295' Increased mud weight to 11.8 ppg while drilling. Directional drill and survey with MWD from 8295' to 8422' 58,732 CUM:$ 617,474 ETD:~ 0 EFC:$ 1,525,474 MW: 12.9 VISC: 49 PV/YP: 30/18 APIWL: 3.6 TRIP IN ON SHORT TRIP Directional drill and survey with MWD from 8422' to 8494' Circulate bottoms up. Monitor well, flowing. Weight up from 11.8 to 12.8. Monitor well, dead. Short trip to window at 6130' extremely tight from 7843' to 7688' Had to work, pump and ream to get through this area. Had intermittent severe packing off problems. 59,975 CUM:$ 677,449 ETD:$ 0 EFC:$ 1,585,449 MW: 12.9 VISC: 49 PV/YP: 33/20 APIWL: 3.8 RIH W/3.5" LINER Continue POOH. Work, pump and ream out from 7790' to 7843' RIH slow to minimize surge pressures, hole free, no fill. Circulate bottoms up, mud cut to 12.2 ppg. Drop tandem single shot survey. Retrieve survey. Run 3.5" liner and make up liner hanger and packer. 37,069 CUM'$ 714,518 ETD'$ 0 EFC'$ 1,622,518 MW: 12.3 VISC: 50 PV/YP: 30/18 APIWL: 4.0 LAY DOWN DP Run 3.5" liner to window at 6130' Circulate bottoms up mud cut 12.9 to 12.6 weight up to 12.8 ppg. Lost all returns, well taking 2-3 bbls/minute. Run liner to bottom at 8484' Cement liner with shoe at 8492' Circulate long way to remove oil and gas cut mud from well. 122,203 CUM:$ 836,721 ETD:$ 0 EFC:$ 1,744,721 MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO NIPPLE DOWN BOPE Lay down drill pipe. Run in with drill collars and remaining drill pipe. Run in hole with completion to liner top at 5915' Test casing, liner and liner lap to 2500 psi with 12.3 mud for 30 minutes. 102,241 CUM:$ 938,962 ETD:$ 0 EFC:$ 1,846,962 Date: 10/8/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/27/97 (D25) TD: 8494' ( 0) SUPV'RLM DAILY:$ MW: 8.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Test 3.5" tubing and 7" x 3.5" annulus with diesel. OK. ND BO?E. NU tree. Test packoff to 5000 psi, test tree to 250/5000 psi. Release rig at 1430 hrs. 8/27/97. 21,183 CUM:$ 960,145 ETD:$ 0 EFC:$ 1,868,145 End of WellSummary for Well:AK8885 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl((W4-6)) DATE 09/15/97 DAY 2 JOB SCOPE JOB NUMBER DAILY WORK UNIT NUMBER INITIAL PERFORATING 8337 OPERATION COMPLETE I SUCCESSFUL I KEYPERSON SUPERVISOR YES YES SWS-MAJCHER BLACK Initial Tbg Press [FinalTbgPress { Initial Inner Ann I Final Inner Ann I Initial Outer Ann I Final Outer Ann SIDE).PERFORATE F/8168 - 8188' ELM W/2.5" HSD BH @ 4 SPF, 180 DEG PHASED (2 SPF 25 DEG CCW F/HI SIDE & 2 SPF 155 DEG CW F/HI TIME LOG ENTRY 13:30 MIRU SWS UNIT #8337 W/MAJCHER, LEVY, HUSEMAN, TGSM. 14:45 PT BOP AND RISER TO 3500 PSI. RIH W/2.5" CARRIER GUNS LOADED 4 SPF X 20', PGGC GAMMA RAY/CCL FOR CORRELATION. TOOL LENGTH 43.4'. 16:00 TIE-IN TO 8/24/97 MWD SPERRY LOG AND TAG BOTTOM AT 8390'. MWD DEPTH PROBLEMS NOTED THROUGHOUT LOGGING. 17:00 19:00 19:30 MAKE SECOND PASS OVER PERF ZONE TO CONFIRM DEPTH DIFFERENCE W/ MWD LOG. TIE LOG IN W/MWD AT PERF ZONE (8168-8188'). NOTE: MWD DEPTHS ABOVE THIS ARE OFF DUE TO PRINTOUT OF MWD LOG. PRESSURE UP VIA TRIPLEX TO SHOOT 200 PSI OVER. PERFORATE 8168 TO 8188' ELM W/2.5" HSD, BH @ 4 SPF, PHASED 180 DEG, AND ORIENTED 25 DEG CCW (2 SPF) AND 155 DEG CW (2 SPtt) F/HIGH SIDE OF HOLE. GOOD INDICATION OF FIRE AT SUrRFACE AS WHP RISES AND DROPS. LOG COLLARS OF PERF DEFFH & POOH. 1 9:00 20:00 AT SURFACE, SIWHP 1550 PSI ALL CHARGES FIRED. BEGIN RD. 2 t: 0 0 OFF LOCATION. TURN OVER TO PRODUCTION F/AM FRAC. SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 1Y-06A 500292075801 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/22/97 DATE OF SURVEY: 082497 MWD SURVEY JOB NUMBER: AN-MW-70243 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA, 97.00 FT. INC. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6101.00 4746.71 4649.71 40 55 S 29.30 E .00 2684.67S 1951.81E -15.18 6130.00 4768.65 4671.65 40 45 S 29.18 E .65 2701.22S 1961.07E -17.51 6321.35 4919.75 4822.75 35 32 S 50.65 E 7.41 2791.47S 2034.90E -11.39 6417.19 4998.85 4901.85 33 29 S 64.71 E 8.57 2820.47S 2080.43E 8.14 6512.64 5078.80 4981.80 33 2 S 79.90 E 8.72 2836.31S 2129.94E 38.68 6608.94 5158.28 5061.28 35 54 N 87.20 E 8.13 2839.54S 2184.08E 80.42 6704.11 5234.96 5137.96 36 58 N 74.28 E 8.13 2830.41S 2239.59E 130.56 6798.34 5308.32 5211.32 40 55 N 63.43 E 8.35 2808.90S 2294.55E 187.60 6892.91 5378.89 5281.89 42 39 N 54.64 E 6.46 2776.47S 2348.43E 250.23 6986.84 5446.65 5349.65 45 0 N 50.70 E 3.83 2737.00S 2400.11E 315.24 7083.93 5515.03 5418.03 45 27 N 49.76 E .82 2692.91S 2453.09E 384.04 7179.66 5582.14 5485.14 45 31 N 50.05 E .23 2648.94S 2505.30E 452.15 7273.38 5646.76 5549.76 47 17 N 48.83 E 2.11 2604.81S 2556.85E 519.82 7370.28 5712.60 5615.60 47 5 N 48.86 E .20 2558.02S 2610.38E 590.66 7466.26 5777.57 5680.57 47 42 N 49.21 E .68 2511.71S 2663.73E 661.07 7562.49 5841.67 5744.67 48 45 N 49.60 E 1.14 2465.01S 2718.23E 732.63 7657.51 5903.48 5806.48 50 4 N 49.79 E 1.40 2418.33S 2773.26E 804.62 7766.05 5973.98 5876.98 48 54 N 51.81 E 1.78 2366.17S 2837.19E 887.02 7816.19 6006.84 5909.84 49 12 N 51.50 E .78 2342.68S 2866.89E 924.86 8394.00 6373.53 6276.53 52 0 N 50.00 E .52 2060.11S 3212.55E 1370.72 8494.00 6435.09 6338.09 52 0 N 50.00 E .00 2009.46S 3272.92E 1449.35 THE CALCULATION PROCEDURES THREE-DIMENSION MINIMUM ARE BASED ON THE USE OF · CURVATURE METHOD HORIZONTAL DISPLACEMENT = 3840.56 FEET - AT SOUTH 58 DEG. 27 MIN. EAST AT MD = 8494 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 53.72 DEG. TIE-IN SURVEY AT 6101.00' MD WINDOW POINT AT 6130.00' MD PROJECTED SURVEY AT 8494.00' MD ORIGlt ,a,L OCT 0 ] 1997 aska Oil & Gas Corm. SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 1Y-06A 500292075801 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/22/97 DATE OF SURVEY: 082497 JOB NIiMBER: AN-MW-70243 KELLY BUSHING ELEV. = OPEKATOR: ARCO ALASKA, 97.00 FT. INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6101.00 4746.71 4649.71 2684.67 S 1951.81 E 1354.29 7101.00 5527.00 5430.00 2685.05 S 2462.37 E 1574.00 219.71 8101.00 6190.30 6093.30 2205.94 S 3036.47 E 1910.70 336.70 8494.00 6435.09 6338.09 2009.46 S 3272.92 E 2058.91 148.21 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP.~ Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 1Y-06A 500292075801 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/22/97 DATE OF SURVEY: 082497 JOB NUMBER: AN-MW-70243 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA, 97.00 FT. INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6101.00 4746.71 4649.71 2684.67 S 1951.81 E 1354.29 6167.04 4797.00 4700.00 2721.61 S 1973.40 E 1370.04 15.75 6293.29 4897.00 4800.00 2780.63 S 2022.57 E 1396.29 26.25 6414.97 4997.00 4900.00 2819.89 S 2079.34 E 1417.97 21.68 6534.43 5097.00 5000.00 2838.04 S 2141.80 E 1437.43 19.46 6656.84 5197.00 5100.00 2836.50 S 2212.10 E 1459.84 22.41 6783.45 5297.00 5200.00 2813.08 S 2285.83 E 1486.45 26.62 6917.67 5397.00 5300.00 2766.56 S 2362.10 E 1520.67 34.22 7058.23 5497.00 5400.00 2704.74 S 2439.11 E 1561.23 40.56 7200.86 5597.00 5500.00 2639.23 S 2516.90 E 1603.86 42.63 7347.36 5697.00 5600.00 2569.07 S 2597.74 E 1650.36 46.49 7495.13 5797.00 5700.00 2497.76 S 2679.90 E 1698.13 47.77 7647.42 5897.00 5800.00 2423.33 S 2767.35 E 1750.42 52.29 7801.13 5997.00 5900.00 2349.78 S 2857.97 E 1804.13 53.71 7955.15 6097.00 6000.00 2276.58 S 2949.43 E 1858.15 54.02 8111.56 6197.00 6100.00 2200.77 S 3042.79 E 1914.56 56.41 8270.52 6297.00 6200.00 2122.20 S 3138.15 E 1973.52 58.96 8432.12 6397.00 6300.00 2040.80 S 3235.56 E 2035.12 61.60 8494.00 6435.10 6338.10 2009.46 S 3272.92 E 2058.90 23.78 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D FI I I--I-- I I~ [~ S ~:: i:t ~' I C ~: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 22, 1997 1Y-06A, AK-MW-70243 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1Y-06A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-20958-01 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20958-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company September 30, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re' MWD Survey 1Y-06A Dear Sir/Madam, Enclosed is two hard copy of the above mentioned file(s). Well 1Y-06A MWD survey Tie-In point at 6101.00', Window point at 6130.00' and a Projected survey at 8494.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM TO: David john, ' Chairman THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: ,~t) 15, 1997 FILE NO: aavlhoef.doc FROM: John Spaulding,~"~ SUBJECT: Petroleum Inspv~-~ BOPE Test Nordic 2 ARCO, KRU, well 1Y-06 PTD97-134 Friday~ A~_~j 15, 1997: I traveled to ARCO's KRU to witness the BOPE Test on Nordic rig f~2. The AOGCC test report is attached for reference. I departed the office at 10 pm on 8/14/97 to witness the BOPE Test at approximately 12 midnite. Upon my arrival I was informed that the well had not been completely killed and was being circulated one more time. I hung around the office and napped until 5 am when we commenced testing, the test was completed at 9 am. All components tested well and the rig was in very good shape. Summary:. I witnessed the successful BOPE Test on; Nordic 2, 8115/97,Test Time 4 hours, no failures Attachments' aavlhoef, xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: NORDIC / CALISTA Operator: ARCO Well Name: 1Y-06 Casing Size: 9 5/8" Set @ Test: Initial X Weekly Rig No. 2 PTD # 97-134 Co. Rep.: Rig Rep.: Location: Sec. Other DATE: Rig Ph.# Don Wester 8/15/97 659-7115 Shane McGeehan 1 T. 11N R. 9E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Sec. OK Quan. Test Press. P/F I 250/3, 000 P 1 250/3,500 P 'I 250/3,500 P I 250/3,500 P 1 250/3,500 P 2 250/3,500 P 1 250/3, 500 P NA FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 250/3500 250/3500 2 250/3500 P 2 250/3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 12 Test Pressure P/F 25O/3000 P 36 250/3000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3, 000 I P Pressure After Closure 2,500 I P VIUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 20 Trip Tank ok ok System Pressure Attained minutes 38 Pit Level Indicators ok ok Blind Switch Covers: Master: X Remote: Flow Indicator ok ok Nitgn. Btl's: 4 ea. @ 2250 avg. Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok sec. sec. X ..-.. TEST RESULTS Number of Failures: 0 /'' ,Test Time: '~3.5 ') Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AAVLHOEF.XLS TONY KNOWLE$, GOVERNOR ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 17, 1997 Michael Zanghi Drilling Superintendent ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit I Y-06A ARCO Alaska. Inc. Permit No. 97-134 Sur. Loc.: 571'FNL, 1911'FWL, Sec. 01, T11N, R9E, UM Btmholc Loc: 2629'FSL. 158'FEL, Sec. 01, T11N, R9E. UM Dear Mr. Zanghi: Enclosed is thc approved application for permit to redrill the above referenced well. The permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of thc Conmussion mav witness the test. Notice may be given by contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. David W Johnst Chairman BY ORDER OF THE COMMISSION dl~'enclosures Department of Fish & Game. Habitat Section wm cncl. Department of Envinonm~¢nt Conservation w/o encl. STATE (DF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X i b Type of Well Exploratory r'1 Stratigraphic Test r~ Development Oil X Re-Entry E] Deepen r"'! Service D Development Gas [~] Single Zone X MulfipleZone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 97', Pad 65' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P, O. Box 100360, Anchorage, AK 99510-0360 ADL 25646, ALK 2577 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.025) 571' FNL, 1911' FWL, Sec. 01, T11N, RDE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2482' FSL, 357' FEL, Sec. 01, T11N, RDE, UM 1Y-06A #U-630610 At total depth 9. Approximate spud date Amount 2629' FSL~ 158' FEL~ Sec. 01, T11N, RDE, UM 8/06/97 $2001000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 16. Proposed depth (MD and TVD) properly line 1Y-31 8398' MD 357' @ Tarcjet feet 30' @ surface feet 2560 6435' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 61 1 9' feet Maximum hole angle 45.4° Maxirnumsurface 2770 psig At total depth ('1-VD) 3450 pslg 18. Casing program Settin(:,l Depth size Specifications Top Bottom Quantitl/ of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sla~le dala) 6- 1/8" 3-1/2' 9.3# L-80 EUE-rnod 2429' 5969' 4647' 8398' 6435' 434 sxs Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 8120 feet Plugs(measured) :J [.J L, true vertical 6436 feet Effective depth: measured 7982 feet Junk (measured) Alaska 0il & Gas Cons. Comrniss true vertica 6314 feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 1 6 ' 280 Sx AS II I 10' 110' Surface 2427' 9-5/8" 1000 sx ASlII, 368 sx AS I 2458' 2199' Intermediate Production 8034' 7 ' 150 sx AS I, 900 sx Class G 8064' 6387' Liner Perlorationdepth: measured 7565'-7659', 7796'-7800', 7809'-7834', 7859'-7863' MD true vedical 5942'-6027', 6149'-6153', 6161'-6183', 6205'-6208' TVD 20. Attachments Filing fee X Property plat r-] BOP Sketc~ X Diverter Sketch I-'] Drilling program X Drilling fluid program X Time vs depth plot F'~ Refraction analysis ~] Seabed report [] 20 AAC 25.050 requirements X Signed21' I hereby certify th~.e~g is true and correct to the best of my knowledge, \ ~''rJl' ~._~ CommissionTitleuse Only Drillin~(C°ntact William Isaacson at 263-4622 with questionS.~superintendent Date.~,."~'" _/ Pe,_rrrmit Number -AEJJa~'mber_ I Approval date , .,, /", ..., I See cover letter forJ .~¢-~, ... ~,~,~,~, ~,," 50' 4:2)'2" ~ -' '~-- O ~'"~-~'- <:::~ ~)I "~J/'/fT'/ J other recluJrements Conditions of approval Samples required E] Yes ]~ No Mud Icg required [--I Yes ]~ No Hydrogen sulfide measures I~ Yes [~ No Directional survey required I~ Yes E] No Required working pressure for BOPE [-1 2M [],~/.E] 5M D 10M D 15M Other: ijr .,:j nai Signed By David W. Johnston by order of ~/ / Approved by Commissioner the commission Date / Fnrm 113-4N1 Fl~.v 7-24-R~ R~l ~ trinlir, ntn REDRILL PLAN SUMMARY Well 1Y-06A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location- MD: TVD- Rig- Estimated Start Date- Operation Days to Complete: Producer 571' FNL, 1911' FWL, SEC 01, T11N, R9E, UM 2482' FSL, 357' FEL, SEC 01, T11N, R9E, UM 2629' FSL, 158' FEL, SEC 01, T11N, R9E, UM 8398' 6435' Nordic Rig 2 08-06-97 11 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Window in 7" casing 9.4 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to weight up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casin(E'l'ubina -- -- Hole size 6-1/8" Proclram: Csg/'rbg Length 3-1/2", 9.3#, L-80, EUE-Mod 2429' Tubing 3-1/2", 9.3~, J-55/L-80, EUE-Mod 5940' Too (MD/TVD) 5969? 4647' Btm (MD/I'VD 8398? 6435' 297 29' 5969'/4647' Cement Calculations: Casing to be cemented: 3-1/2" in 6-1/8" open hole Volume = 434 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 46%, & 150' liner lap. Well Contro!: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,770 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.0 ppg EMW. With an expected formation pressure in the Kuparuk of 3450 psi and a gas gradient of 0.11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2,770 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling H~zar.ds: Lost CircuJation: OverDressu red Intervals: .Other. Hazards: Directional: KOP: Max hole angle: Close approach: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 1Y-06A, will kick off out of the 7" casing below both the K-10 and K-5 intervals. The 7" casing has good quality cement up to and above the planned kick-off window, which should isolate the K-10 and K-5 from the sidetrack operations. If the Formation Integrity Test shows that the K-10 and K-5 intervals are not isolated and will not hold the desired equivalent mud weight, a cement squeeze at the window could be performed to help isolate these intervals. Off-set ddlling data shows that wells in the area of 1Y-06A have been drilled to TD with 11.7 ppg mud and no loses. The kick-off point in 1Y-06A is below any zones which would be of pressure concem prior to weighting up for the Kuparuk interval. None 6119' MD / 4760' TVD 45.4° (in sidetrack portion) No Hazards Page 2 Loqging Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL Notes- All ddll solids generated from the 1Y-06A sidetrack will be hauled to CC-2A in Prudhoe Bay for gdnd and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 1Y-06A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU slickline unit. RIH and isolate C Sand behind pipe by setting an isolation sleeve in AVA nipple (which is incorporated into merla patch across C Sand mandrel at 7428' MD RKB). . RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in 3-1/2" tubing immediately below top production packer. Mix cement. Circulate the cement down coil to immediately above circulating valve on top of retainer. Close circulation valve and down-squeeze cement below retainer into A Sand perfs. Use sufficient volume to fill 3-1/2" tubing down through tubing tail and 7" casing from top of fill to tubing tail, plus excess to squeeze away into perfs if possible. Unsting from retainer and circulate well clean on top of inflatable retainer. RDMO CTU. 3. RU slickline unit. RIH and pull dummy valve from bottom GLM at 7284' MD RKB, leaving an open pocket. WO RKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. 2. Vedfy well is dead. Load pits w/water. Circulate well to water. 3. Pressure test wellbore to 2500 psi testing cement squeeze and retainer, to ensure isolation from perforations. Set BPV. 4. ND tree. NU and test BOPE. 5. Screw in landing joint. Pull tubing hanger to dg floor. Spot a 150' cement plug on top production packer. Pull above cement plug top and reverse circulate tubing clean. POOH laying down all 4" tubing and standing back 3-1/2" tubing. 6. RU E-line unit. Run gauge dng through bddge plug setting depth. RIH and set permanent bddge plug at 6138' MD-RKB. Test 7" casing above bridge plug to 3500 psi. 7. MU and RIH with bottom tdp whipstock and window milling assembly. Tag bddge plug and set down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and mill window in 7" casing. POOH LD milling assembly. 8. RIH w/6-1/8" bit, mud motor, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off well, and directionally ddll to total depth as per directional plan. Short tdp to window in casing. POOH. 9. Run 3-1/2" liner to TD w/150' of ovedap to top of milled window. 10. Cement liner. Set liner hanger and liner top packer. POOH w/DP. 11. Pressure test casing and liner lap to 3500 psi for state test. 12. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 14. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Page 4 Lower Limit: Expected Case: Upper Limit: 9 days 11 days 18 days No problems milling window, drilling new hole, or running completion. Difficulties encountered milling window, or ddlling new hole. WSI 7/8/97 Page 5 ARCO ALASKa, !nc. Structure : Pod 1Y Well: 6A Created by jones For: H IsaaesonI Field : Kuparuk River Unit Location : Nodh Slope, Alaska Oate plotted : 26-Jun-g7 ,,o, Re, ...... ,s~,v~.,,on~6. East (feet) -> Coordinotes ore in feet reference slot ~6. t 1650 1800 1950 21 O0 2250 2400 2550 2700 2850 3000 3150 3300 3450 true Verticol Oepth~nce RKB (Nordic II). I I I I I I ! I I I I I I I I 1 I I I I I I I I I 53.72 Azimuth 1357' (TO TD) 4650 4800 4950 51 O0 Q~ 5250 t- -4~EL 5400 "~ 5550 '- 5700 5850 I V 6000 6150 6300 6450 7 Cosing TARGET KOP - SlD~RACK PT ~D=4760 TMD=6119 DEP=-17 36.85 35.29 31.69 DLS: 9.00 deg per 100 ft 32.32 55.08 39.51 45.12 EOC TVD=5315 TM0:6804 DEP:223 AVERAGE ANGLE 45.37 DEG C30 TV0=5599 TMD=720g DEP=511 B/ HRZ TVD=5772 TMD=7455 DEP=686 K-1 MARKER TVD=5882 IMD=7611 DEP=798 T/ pNIT D TVD=5957 TMB=7718 DEP=874 T/ UNIT C¢ TVD=5962 TMD=7725 DEP=879 T/ UNIT B TVD=6052 TMD=7853 DEP=970 1800 1950 2100 2250 0 2400 2550 ._~ I 2700 V 285O 3000 3150 T/ UNIT A TVD=6172 TMD=8024 DEP=1091 A4 INT. TVD=6190 TMD=8050 DEP=lll0 A5 Interval TVD=6227 TMD=8105 DEP=1147 El/ KUP SANDS TVD=6294 TMD=8198 DEP=1215 TD TVD=6435 TMD=8398 DEP=I357 450 300 150 0 150 500 450 600 750 900 1050 1200 1550 1500 1650 Vertical Secffon (feet) -> Azimuth 55.72 with reference 0.00 N, 0.00 E from slot #6 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST ~J fANNULAR L_- 6 P PE RAM I I 5 BLIND RAM~ MUD I I 3 P PE RAM I I I 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 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 THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. Bop STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO~-FOM PIPE RAMS. TEST Bo~-FOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11"- 3000 PSI CASING HEAD 2.11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16"- 5000 PSI SINGLE GATE W/ BLIND RAMS 6, 7-1/16"- 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16" - 5000 PSI ANNULAR PREVENTER NORDIC RIG//2 LEVEL 1 7' z 12'-4' = EMSCO F-800 TRIPLEX MUD PUMP SPIRAL , STAIRS CONTROL )CONSOLE , [ i 53'-0' 1 28'-6" NORDIC RIG g2 LEVEL 2 NORDIC RIG g2 LEVEL 3 MUD TANK 750 BBI..$ CHOKE: MANIFOLD OFFICE WATER TANK /GLYCOL TANK 15'--6" H'fl~RAUIJC 15'-6" Name of O ~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS andon X Suspend _ Iter casing _ Repair well _ hange approved program _ ARCO Alaska. In~, 3. Address P. O. Box 100360, Anchorage, AK 99510 '4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1277' FSL, 1044' FEL, Sec. 1, T11N, R9E, UM At effective depth 1098' FSL, 982' FEL, Sec. 1, T11N, R9E, UM At total depth 1036' FSL, 962' FEL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 8120 (approx) true vertical 6436 Pull tubing_ Operation Shutdown Re-enter suspended well Plugging .~_ Time extension Stimulate Variance Perforate Other 5. Type of Well: Development Exploratory Stratigraphic Service feet feet 6. Datum elevation (DF or KB) 96' RKB. Pad §7' 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-06 9. Permit number 83-78 10. APl number 50-029-~0951~ 11. Field/Pool ; Kuparuk River Plugs (measured) None Plugback for X Redrill feet Effective depth: measured 7982 (approx) true vertical 631 4 feet Junk (measured) Top of fill @ 7817' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 16" 280 sx AS II 2427' 9.625' 1000 sx AS III & 368 sx AS I 8034' 7 · 900 sx Class G & 150 sx AS I measured 7565'-7659', 7796'-7800', 7809'-7834', 7859'-7863° true vertical 5942'-6027', 6149'-6153', 6161'-6183', 6205'-6208' Tubing (size, grade, and measured depth) 4', 11#, J-55 @ 4007', 3.5', 9.3#, J-55 @ 7359' Packers and SSSV (type and measured depth) Measured depth True vertical depth 1 10' 1 10' 2458' 2199' 8064' 6387' '~: ~-.' '- 1997 Alaska .Oil & Gas Cons. Anchorage 4' Camco TRDP-4A SSSV @ 1798', Camco 7x 3.5' HRP-1-SP retr. packer @ 7349' & Baker 7' FB-1 perm. pkr @ 7741' 13. Attachments Description summary of proposal Contact William Isaacson at 263-4622 with an~/questions. 14. Estimated date for commencing operation Julv 1{i, 1997 16. If proposal was verbally approved Name of appr.~ver / 17. I hereby c;,~/~the[oregoing Sic, lned lv !.' ~ Detailed operation program__ BOP sketch_ 5. Status of well classification as: Oil Gas Date approved Service is true and correct to the best of my knowledge. Title Drill-Site Development Supv Suspended _ FOR COMMI~ION USE ONLY Date Conditions of approval: I~fy Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test _ Subsequent form require 10- IApprova Approved by the order of the Commission Form 10-403 Rev 06/15/88 commissioner Date SUBMIT IN TRIPLICATE · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~/~'<::~.,/~::~'e> INIT CLASS WELL NAME .~A¢2.:~ / Y-~ GEOL AREA PROGRAM: exp [] devyredrll [] serv [] wellbore seg rj ann. disposal para req I:i'l UNIT# /,,2/(~) ON/OFF SHORE ~'~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate .................... 3. Unique well name and number .................. 4. Well located in a defined pool ................... 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DA)-E 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Y N '"% Surface casing protects all known USDWs ........... Y N) ~ ~ CMT vol adequate to circulate on conductor & surf csg ..... Y N ,/ CMT vol adequate to tie-in long string to surf csg ........ ~Y N × CMT will cover all known productive horizons .......... Y(~N Casing designs adequate for C, T, B & permafrost ....... (-.~N Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to REMARKS Choke manifold complies w/APl RP-53 (May 84) ........ '~i Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOLOGY APPR DA.TE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N ~ 31. Data presented on potential overpressure zones ....... ~/~/ 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ .//Y N 34. Contact name/phone for we,ekly,pro~ress repqrts ..... .,/Y N lexp~ora~ory omy] GEOLOGY: ENGINEERING: COMMISSION: JDH _r~',~/ - RNC~ -" Comments/Instructions: HOWIIjt - A:\FORMS\cheklist rev 07/97 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. Sperry-Sun Drilling Services LIS Scan Utility Thu Oct 09 15:59:08 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 97/10/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL N~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 3 AK-MW-70243 T. FLYNN B. MORRISON ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1Y-06A 500292095801 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 09-OCT-97 1 lin 9E 571 Date 1911 62.20 60.70 30.80 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 8494.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. NO FOOTAGE WAS MADE ON MWD RUN 2 AND IT IS NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBES, AND ELECTROMAGNETIC WAVE PHASE-4 RESISTIVITY (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM B. ISAACSON OF ARCO ALASKA, INC. ON 10/06/97. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8494'MD, 6450'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED DUAL GAMMA RAY. 'SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET .5000 START DEPTH 6105 0 6113 0 6113 0 6113 0 6113 0 6160 0 STOP DEPTH 8437 5 8445 5 8445 5 8445 5 8445 5 8445 5 ROP 6162.0 8493.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 6160.0 8494.0 $ R~ARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 ROP MWD FT/H 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 RPS MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 6105 8493.5 7299.25 4778 6105 GR 33.7075 525.499 125.988 4666 6105 RPM 0.0932 2000 14.2404 4666 6113 ROP 6.4178 539.691 69.5542 4664 6162 RPX 0.1782 2000 4.83954 4666 6113 RPS 0.0853 49.5167 4.54161 4666 6113 RPD 0.05 2000 6.0188 4666 6113 FET 0.585 14.9011 2.02147 4572 6160 Last Reading 8493 5 8437 5 8445 5 8493 5 8445 5 8445 5 8445 5 8445 5 First Reading For Entire File .......... 6105 Last Reading For Entire File ........... 8493.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCRemENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6105 0 RPD 6113 0 RPM 6113 0 RPS 6113 0 RPX 6113 0 FET 6160 0 ROP 6162 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH 8437 5 8445 5 8445 5 8445 5 8445 5 8445 5 8493 5 23-AUG-97 MSC 1.32 / ISC 5.06 2.O42 / 5.74 MEMORY 8494.0 6160.0 8494.0 33.0 500.0 TOOL NUMBER P0717SP4 P0717SP4 6.000 DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT M3LX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 6.0 LSND-LT 11.80 50.0 9.0 900 3.8 1.700 2.200 1.350 2.200 .6 RE~ARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code ~f~set Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 AAPI 4 1 68 8 3 RPX MWD 3 OHMS4 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 OH~ 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 63.3 First Name Min Max Mean Nsam Reading DEPT 6105 8493.5 7299.25 4778 6105 ROP 6.4178 539.691 69.5542 4664 6162 GR 33.7075 525.499 125.988 4666 6105 RPX 0.1782 2000 4.83954 4666 6113 RPS 0.0853 49.5167 4.54161 4666 6113 R?M 0.0932 2000 14.2404 4666 6113 RPD 0.05 2000 6.0188 4666 6113 FET 0.585 14.9011 2.02147 4572 6160 Last Reading 8493 5 8493 5 8437 5 8445 5 8445 5 8445 5 8445 5 8445 5 First Reading For Entire File .......... 6105 Last Reading For Entire File ........... 8493.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
