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Home My WebLink About185-168Originated: Delivered to:2-Jan-25 Alaska Oil & Gas Conservation Commiss 02Jan25-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24 1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 15-Dec-24 1F-14 50-029-21022-00-00 183-146 Kuparuk River WL PPROF FINAL FIELD 17-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 18-Dec-24 1L-05 50-029-21155-00-00 184-123 Kuparuk River WL IPROF FINAL FIELD 19-Dec-24 1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24 2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24 2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24 1Q-12 50-029-21210-00-00 184-193 Kuparuk River WL LEE-IPROF FINAL FIELD 23-Dec-24 MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24 MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39899 T39900 T39901 T39902 T39901 T39903 T39904 T39905 T39906 T39907T39908 T39909 2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.03 08:13:20 -09'00' Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. L ~ _~- _[ _{4_'~ Well History File Identifier Organization RESCAN O Color items: Grayscale items: Poor Quality Originals: Other: ~"','?"-" - ...... DIGITAL DATA Diskettes, No. Other, .No/Type TOTAL PAGES: ~(~ NOTES: ORGANIZED BYi BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds [] Other ISI Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl PAGES; ~. (at the time of scanning) SCANNED BY; BEVERLY ~ VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYI. MARIA LOWELL DATE: General Notes or Comments about this file: Quality Checked (done) R~l~TScanned.v4xl • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey / Bottom Hole Pressure Survey: 2H -05 Run Date: 8/22/2011 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 211-05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20043 -00 ) .4 O Bottom Hole Pressure Survey Log 1 Color Log r 50- 103 - 20043 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood §k l) ! [1 ; 6900 Arctic Blvd. Anchorage, Alaska 99518 I Office: 907 -273 -3527 Fax: 907- 273 -3535 klinton.wood@halliburton.com Date: ;� S, ll Signed: AZ.,0a4 (,, hr-i 63 STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS RECEIVED .IAN ~ 7 2010 7. operations Performed: Abandon ~'""" Repair w ell Plug Ft'rforations ~`"' Stimulate ~"" Alaska Oil~~l ona. Commigsi~n Alter Casing ~ Pull Tubing ~'"` F~rforate New Pbol ~ Waiver Time Extensic~~~`~~~~ Change Approved Program ~""" Operat. Shutdow n Perforate ~ ~ Re-enter uspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory j"'` 185-168 3. Address: Stratigraphic ~ Service 1 .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20043-00 7. Prop Designation: ber: 8. Well Name and Num ADL 25587 \ ` 2H-05 . Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured ~ 8110 feet Plugs (measured) None true vertical ~ 6451 feet Junk (measured) None Effective Depth measured 7988' feet Packer (measured) 7375, 7599 true vertical 6353' feet (true vertucal) 5888, 6054 Casing Length Size MD ND Burst Collapse CONDUCTOR 100 16 100 100' SURFACE 2942 9.625 2942 2758' PRODUCTION 8085 7 8085 6431' Perforation depth: Measured depth: 7535'-7565', 7647'-7652', 7666'-7694', 7722'-7748' True Vertical Depth: 6004'-6028', 6090'-6094', 6104'-6126', 6147'-6167' Tubing (size, grade, MD, and TVD) 2.875, J-55, 7618 MD, 6068 TVD Packers & SSSV (type, MD, and TVD) PACKER -BROWN 'HB' PACKER @ 7375 MD and 5888 TVD PACKER -BROWN '1 B' PACKER @ 7599 MD and 6054 TVD TRDP -BAKER 'FVL' @ 1771 MD and 1765 TVD 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 336 782 445 -- 203 Subsequent to operation 230 1310 367 -- 220 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory Development Service . Well Status after work: Oil ~`: Gas WDSPL ~"` Daily Report of Well Operations XX GSTOR ~"` WAG "' GASINJ ~"' WINJ SPLUG 16. 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: none Contact John Peirce Cad 265-6471 Printed Name John Peirce Title Wells Engineer Signature .r" ~ ~~, Phone: 265-6471 Date ~t /~ ~ /~ J,( • .~.. f __-__ Form 10-404 Revised 7/2009 RBDMS JAN 2 7 ZOO ~) Submit Original,,O//nly /Z7•!v ,~~ t~T~O 2H-05 Well Events Summary DATE SUMMARY 12/8/09 DRIFT TBG WITH 2.17" CENT, 9 1-7/8" (10' DRIFT) TO TAG @ 7904' SLM;~ST. 167' RATHOLE. READY FOR E-LINE. 12/11/09 COMPLETED PERFORATING A5 ZONE FROM PERFORATED FROM 7647 - 7652' WITH 2-18" DEEP STAR STRIP GUN MILLENIUM CHARGES. PERFORMED SBHP AFTER PERFS AT DEPTH OF 7516 AND 7650 STATS ARE AS FOLLOWS. @ 7516 TEMP = 155.82 DEG; PRESS = 1884 # @ 7650 TEMP = 156.69 DEG; PRESS = 1933 # HAD SWAB SERVICED ONCE ON WELL, BUT STARTED LEAKING AGAIN AS WE WERE RIGGING DOWN. 12/29/09 TAGGED @ 7893' SLM. MEASURE BHP @ 7678' RKB (2603 PSI) & GRADIENT @ 7549' RKB (2563 PSI) COMPLETE. ~cx~o~c~Phsili~s ::__._ wen c r,~.. zH,a§,.1/%z/ao _ _. .Schematic-AOR "nip:,.. .: Y~'~; CONDUCTOR. SAFETY VLV. _ _. 1,771 GAS LIFT, 2.281 SURFACE. 2,942 S GAS LIFT. ( 4,371 t GAS LIFT, 5,749 r GAS LIFT. 6,567 4 GAS LIFT, 6,946 GAS LIFT. 7,321 PBR, 7,363 - t t. ^ ~„ PACKER, 1,375- t -*- _ `~ ~~ PRODUCTION. 7.412 r f PRODUCTION, 7,478 FRAC, 7,535 _ IPERF, __ _ - 7,535-7 565 PRODUCTION, 7.583 y{ C (: - PACKER,7.599 - NIPPLE.76i1 SOS, 7,617 j TTL, 7,616- APE P,F, KUP ~ 2H-05 ell Attributes Max Angle 8 MD TD (bore APUUWI Feltl Name Well Status Inc! (°) MD (kKB) Act Bim (ftKB) 501032004300 ,KUPARUK I-'h.l ~~: '_INIT ( PROD I 48.22 6,40000 8,110.0 nment N25 F,~~'~I Da IF Annotation End Date KB-Grtl (k) Rig Release Dat 1/17/2010 SV: iRDP . I iLast WO: I 3599 ( 1/7/1986 -- End U,Ik Annotation otation Depth (k K8) _. 'ILnst Mod By 'Entl Date ( I a Tao: SLM 7.593.0 12+:: ul (Rev Reason: ADD PERFS 12/11/09 I Imostwr ~' 1/22/2010 na Too Thrd Top (ftKB) (ttRB) (°) Des FI._~.m Comment RunRun Da 1,771 1765.5 17.24 _ SAFE17 Lv Baker'FVL'SSSV 2/10!1986 2.313 2,281 2,234.4 29.61 GAS LIF I CAMCO/KBMG/1/GLV/BK/.156/13001 Comment: STA 1 7/4/2006 2.344 4,371 3,786.0 47.68 GAS LIF( CAMCOlKBMGl1/GLV/BK/.188/1329/ Comment: STA 2 7/4/2006 I, 2.344 5,749 4,756.9 4527 GAS LIFT ! CAMCO/KBMG/1/GLV/BK/.188/13191 Comment: STA 3 7/412006 j 2.344 6,567 5,316.5 47.69 GAS LIF'( ~' CAMCO/KBMG71lGLV/BK/.25l1412/Comment: STA4 7/3/2006 ~ 2.344 6,946 5,577.2 44.50 GAS LIFT CAMCO/KBMG/1/DMVBK/// Comment: STA 5 5118/2001 1 2.344 7,321 5,849.7 43.99 GAS LI p~ ! MMH/FMHOl1 5/OV/RK/.25!/Comment: STA 6 7/3/2006 12.344 7,363 5,879.7 4349 PBR Brown PBR 2/10/1986 2.500 __ 7,375 5,888.3 43.35 PACKET; Brown'HB'PACKER 2/10/1986 3.000 __ 7,412 5,916.3 43.71 PRODL'C11CiPd CAMCO/KBMG/11DMY/BK/1/Comment STA7 6/2012006 2.344 7,478 5,963.8 42.821 PRODUCIIOFJ CAMCO/KBMG/1/DMY/BK///Comment STAS 7/31/2005 2.344 7,583 6,041.5 40.68 PRODLIC: I IT)N CAMCO/KBMG/11DMY/BK4/ Comment STA 9 7Y31/2005 2.344 7,599 6,053.6 ~' 41.14 PACK;EH. Brown'16' PACKER 2/10/1986 3.250 7 611 6,062.71 41.05 NIPPLE Camco'D' Nipple NO GO 2/10/1986 2.250 7,617 6,067.2 40.98 SOS Brown 2/10/1986 12.438 7,618 6,068.0 40.97 TTL TTL ELMD @ 7617 SWS SBHP 6/30/2008 2/10/1986 2.438 Top (ND1 Btno { f dl!11 Dens 'op (kKB) Btrn (kKBJ (ftKB) jkKE';i Zone Date (sh-. Type Comment 7,535 7,565 6,004.1 ~i 0 _ C~4, 2H-05 X2/9/1986 12.0 IPERF 5"Casing Guns 7,6471 7,652 6,090.1 f OJ i 9 A-S, 2H-O5 12/11(2009 4.0 APERF 2 1/8" DEEP STAR STRIP GUN, MILLENIUM CHGS, 45 DEGREE i DOWN PHASE 7,666 7,694 6,104 4 6.12` ;' A-4, 2H-OS _ 2!9/1986 I 4.0 IPERF ~, 4" Casing Guns 7,670 7,685 6,107.5 I" I 1 .'. fi A-q 2H-OS 6/22/2006 6.0 RPERF ~2" ULTRA PACK 7,722 7,748 ' 6,147.2 :'A-3, 2H-OS 2!9/1986 ~' 4.0 ~IIPERF 4"Casing Guns stimulat ions & Treatme nts B.rmrn Min Top Man Bim Top Depth De ptl_i Depth Depth (ND) (TVC~ (kKB) (ftKB) (kK6) (FIKEr Type I Date Comment _ _ _ 7,535.0' 7,565.0 8,004.1 F 0 /FRAC ' 5/25/2001 C SAND FRAC _ 7,670.0 7,685.0 6,107.5 ( 111 *: FRAC 6/29/200G A SAND FRAC 168,000# 16/20 Car6olite, 10PPA or Formation FRAC, 7,670 - _- RPERF. '°a 7,670-7,685 - \_ -. IPERF, ],666-7,694 IPERF, _ 7 ]22-7 748 - -- -- PRODUCTION. 8,1185 TD, 8,110 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record /Shut-in Bottom Hole Pressure: 2H-OS Run Date: 12/11/2009 December 16, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK-99518 2H-OS Digital Data in LAS format, Digital Log Image file tJ 1 CD Rom 50-103-20043-00 /~5 -/(off ~ `~/ ASS PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto~halliburton.com Date: Signed: • ConocoP hiffips Alaska P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 August 17, 2008 RECE~VE® AUG 2 5 2008 Alaska pil & Gas Cons. Anchor~ga COrnr;~iz;,lan Mr. Tom Maunder ; ~ ;~,~~~ ~~ j ~ ~ ~ d ~ $ Alaska Oil & Gas Commission `~~~' ,r~ 1 ~J 333 West 7~' Avenue, Suite 100 ~~ `a / 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 corrosion inhibitor/sealant was pumped August 2-17, 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, Perry Kle ~ ~ Z~~C~ ~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Datp r1 LJ Report of Sundry Operations (10-404) Kuparuk Field ell Name TD # -- Initial top of cement Vol. of cement um ed Final top of cement Cement top off date an Corrosion inhibitor nwva Corrosion inhibitor/ sealant date ft bbls ft al 2H-05 185-168 SF N/A SF N/A 5.10 8/2!2007 2H-17 200-019 6" N/A 6" N/A 1.27 8/2/2007 2K-27 201-169 10" N/A 10" N/A 8.92 8/2/2007 2M-03 191-141 16" N/A 16" N/A 2.13 8!2/2007 1 B-14 194-030 SF N/A SF N/A 1.70 8/13/2008 1 B-18 194-061 9" N/A 9" N/A 8.07 8/13/2008 1 B-19 194-064 SF N/A SF N/A 5.10 8/13/2008 1B-20 203-115 21" N/A 21" N/A 5.95 8/13/2008 1 B-101 203-133 3" N/A 3" N/A 1.00 8/17/2008 1 B-102 203-122 4" N/A 4" N/A 1.00 8/17/2008 1 Y-05 183-087 6" N/A 6" N/A 1.27 8/13/2008 1 Y-07 183-068 6" N/A 6" N/A 1.27 8/13/2008 1Y-17 193-068 SF N/A SF N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 2.12 8/13/2008 1Y-26a 188-116 SF N/A SF N/A 3.83 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 204-091 14" N/A 14" N/A 5.95 8/17/2008 1 E-119 204-031 14" N/A 14" N/A 4.67 8/17/2008 1 E-121 204-246 6" N/A 6" N/A 1.00 8/17/2008 1E-123 204-074 5" N/A 5" N/A 1.00 8/17/2008 ,~ NO.4775 ~? ~--~ ~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # `~~V r~ a7UL ~ Lr LULIU Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/1 0,08 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 1L-20A 10215099 PRODUCTION PROFILE ~QU '~ 06/26/08 1 1 1 G-05 12080389 LDL Cp 06/27/08 1 1 3B-10 12061714 INJECTION PROFILE °I' ~ / - 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 iJ-109 12080390 SBHP SURVEY / / 06/28/08 1 1 2N-323 12061716 SBHP SURVEY 'fir- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY C 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - ` 06/29/08 1 1 2X-14 12080391 SBHP SURVEY 06/29/08 1 1 2X-11 12080393 SBHP SURVEY ~(- ~ 06/29/08 1 1 iG-09 12080401 INJECTION PROFILE (~ - r /(~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~ ~ 06/30/08 1 1 2H-12 12080395 SBHP SURVEY - (~~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY ( 06/30/08 1 1 1b-07 12080398 SBHP SURVEY - 1 07/02/08 1 1 2N-341 12061720 SBHP SURVEY ..- p 06/30/08 1 1 3C-15 11982441 USI7 / ~.j 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `~f - (p 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE ~ p -b 07/10/06 1 1 2W-02 11982446 INJECTION PROFILE - ,5 07/09/08 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. • • . . Mike Mooney Wells Group Team Leader Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 July 18, 2006 RECEIVED JUt 1 9 2006 Alaska Oil & Gas Cons. Commission Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2H-05 (APD # 185-168) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 2H-05. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ~ -£- ~ ,,¿ 1"\co.J~y M. Mooney Wells Group Team Leader CPAI Drilling and Wells SCANNED AUG 1 £12005 MM/skad . RECEIVED . 1. Operations Performed: Abandon D Repair Well 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 Opera!. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 185-1681 . 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20043-00 I 7. KB Elevation (ft): 9. Well Name and Number: RKB 129' 2H-05 8. Property Designat!on: 10. Field/Pool(s): ADL 25587, ALK 2673 Kuparuk River Field 1 Kuparuk Oil Pool , 11. Present Well Condition Summary: Total Depth measured 8110' feet true vertical 6451' feet Plugs (measured) Effective Depth measured 7830' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 100' 16" 100' 100' SUR. CASING 2813' 9-518" 2942' 2758' PROD. CASING 7956' 7" 8085' 6431' Perforation depth: Measured depth: 7535'-7565', 7666'-7694', 7722'-7748' true vertical depth: 6006'-6028',6104'-6126',6147'-6167' Tubing (size, grade, and measured depth) 2-7/8", J-55, 7618' MD. RBDMS 8Ft AUG 092006 Packers & SSSV (type & measured depth) pkr= BROWN 'HB'; BROWN '1 B' pkr= 7375'; 7599' Baker 'FVL' SSSV @ 1771' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7670'-7685' MD Treatment descriptions including volumes used and final pressure: 168,000# of 16/20 carbolite in formation 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation 328 1305 398 -- 216 Subsequent to operation 612 , 766 '. 809 . -- 208 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0' Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Leader. I ¡ Signature -rI2 -A¿:}' ..f6r- 11\.' - fIZ ~"Phone Date i- If> ~ -=-""____ ." , , \<.E:-. 'Q:Y\Jt! PreDared bv Sharon Al/sUD-Drake 263-4612 ~l ~ 7·ZO·D~ . STATE OF ALASKA JUL 1 9 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION . . . REPORT OF SUNDRY WELL OPERA TIO~ska 011 & Gas Cons. Commission Form 10-404 Revised 04/2004 t.ORB\NAL ~ /~ ~11t1 LfJ/. Su6mífc5ñginal Omy . 2H-05 Well Events Summary . DATE Summary 06/19/06 DRIFT TBG W/ 15.5' X 2.125". TAG @ 7830' RKB, EST. 82' OF RATHOLE. SET 2.25" A- 2 PLUG @ 7611' RKB, SET 2.30" CATCHER SUB @ 7601' SLM. PULL DV @ 7412' RKB. OBTAIN SBHP'S 2900 PSI (153 DEG F) @ 7413' RKB AND 2876 PSI (153 DEG F) 7313' RKB. IN PROGRESS. 06/20/06 PULLED GLVs @ 2281',4371',5749', & 6567' RKB. PULLED OV @ 7321' RKB. SET DVs @ 2281',4371',5749',6567', & 7412' RKB. LOADED IA & TBG W/ 105 BBLS DIESEL & 161 BBLS SEAWATER. 06/21/06 SET DV @ 7321' RKB. PULL CATCHER SUB @ 7595' SLM, PULL PLUG @ 7611' RKB. PRESSURE TEST TBG & IA TO 3500 PSI. 06/22/06 PERFORATE THE INTERVAL 7670 - 7685' USING 2.0" HSD LOADED 6 SPF 60 DEG , PHASING WITH UL TRAPACK HMX CHARGES. API SPECS: 4.5" PENETRATION, 0.39" ENTRANCE HOLE. PRESSURE INCREASE OF 100 PSI AFTER FIRING. DID NOT TAG TD. 06/29/06 PUMPED A SAND RE-FRAC. ADJUSTED DESIGN DUE TO REACHING MAXIMUM ALLOWABLE PRESSURE EARLY IN JOB. PLACED 168,000 POUNDS OF16/20 CARBOLlTE IN FORMATION, 10 PPA ON PERFS. FLUSHED TO COMPLETION. RECOVERED ALL TREESAVER RUBBERS. 07/02/06 Performed post frac FCO to hard tag @ 7664' CTMD (all perfs open). Good 1:1 returns throughout job with heavy solids in returns @ tank, 07/03/06 TAGGED @ 7676' RKB, EST. 72' FILL. PULLED DVs @ 5749', 6567', 7321'. SET GLV @ 6946', OV @ 7321' RKB. IN PROGESS. 07/04/06 PULLED DMY'S @ 2281',4371' RKB, SET LV'S 2281', 4371',5749' RKB , GAVE WELL BACK FOT PRODUCTION. . ConocoPhimps Alaska, Inc. . KRU it-OS 2H-05 API: 501032004300 Well Type: PROD Anole (âJ TS: 42 deo (âJ 7534 ìUBING W SSSV Type: TRDP Orig 1/7/1986 Angle @ TD: 38 deg @8110 (0-7618, Completion: 00:2.875, Annular Fluid: Last W/O: Rev Reason: FRAC A SAND 10:2.441 ) Reference Loa: Ref Loa Date: Last Update: 6/30/2006 Gas Lift Last Tao: 7830' TD: 8110 ftKB I ndrel/Pum my Last Taa Date: 6/2912006 Max Hole Anale; 48 dea (âJ 6400 Valve 1 1"__ "".. (2281-2282, OD:4.750) Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 100 100 62,50 H-40 SUR. CASING 9.625 0 2942 2758 36,00 J-55 PROD. 7.000 0 8085 6431 26.00 J-55 T...... "'..1..- Size I Top I Bottom I TVD I Wt I Grade I Thread 2.875 0 I 7618 I 6068 I 6.50 I J-55 I EUE 8RD Interval TVD Zone Status Ft SPF Date Type Comment 7535 - 7565 6006 - 6028 C-4 30 12 2/9/1986 IPERF 5" Casina Guns 7666 - 7670 6104 - 6108 A-4 4 4 2/9/1986 IPERF 4" Casino Guns 7670 - 7685 6108 - 6119 A-4 15 10 6/22/2006 RPERF 2" ULTRA PACK 7685 - 7694 6119 - 6126 A-4 9 4 2/9/1986 IPERF 4" Casino Guns 7722 - 7748 6147 - 6167 A-3 26 4 2/9/1986 IPERF 4" Casina Guns 0 Interval Date Tvpe Comment 7535 - 7565 5/25/2001 FRAC C SAND FRAC 7670 - 7685 6/29/2006 FRAC A SAND FRAC 168,000# 16/20 Carbolite, 10PPA on Formation r,..c St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2281 2234 Camco KBMG DMY 1.0 BK 0.000 0 6/20/2006 ~ 2 4371 3785 Camco KBMG DMY 1.0 BK 0,000 0 6/20/2006 3 5749 4757 Camco KBMG DMY 1.0 BK 0,000 0 6/20/2006 4 6567 5317 Camco KBMG DMY 1.0 BK 0.000 0 6/20/2006 5 6946 5578 Camco KBMG DMY 1.0 BK 0,000 0 5/18/2001 6 7321 5849 MMH FMHO DMY 1.5 RK 0,000 0 U/L I/LUUU St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 7 7412 5915 Camco KBMG DMY 1.0 BK 0.000 0 6/20/2006 8 7478 5964 Camco KBMG DMY 1.0 BK 0.000 0 7/31/2005 9 7583 6042 Camco KBMG DMY 1.0 BK 0.000 0 7/31/2005 Ecuì io. etc.) - JEWELRY Depth TVD Type Description ID 1771 1765 SSSV Baker 'FVL' 2.313 Perf ~ ~ 7363 5880 PBR Brown 2.500 (7535-7565) 7375 5888 PKR Brown 'HB' 3.000 FRAC 7599 6054 PKR Brown '1 B' 3.250 (7535-7565) 7611 6063 NIP Camco 'D' Nipple NO GO 2.250 7617 6067 SOS Brown 2.438 7618 6068 TTL 2.438 TTL (7618-7619, 002.875) - - Perf ~ ~ (7670-7685) FRAC -="7 -"- --š-- (7670-7685) =--= = Perf = F= (7722-7748) - f---- - f---- - ---- ) ~~~~~ : F fÆ~~~~~:Æ ) AT/A~KA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR November 26, 2004 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 \~~ .~llj s'" . Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") received a well safety valve system (SVS) test report from ConocoPhillips at Kuparuk River Unit 2H pad ("KRU 2H") dated November 1 0, 2004. Attached is a copy of the SVS Test Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission policy, 'as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective November 10, 2004 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2H must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, Q~B~~c, James B. Regg ~ II Petroleum Inspection Supervisor Attachment SCANNED IoJAN 11 2005 ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report ) Operator: ConocoPhillips Operator Rep: Noble - AES AOGCC Rep: Waived Submitted By: Brad Gathman FieldlUnitlPad: KRU 2H Separator psi: LPS Date: 11/10/2004 96 HPS '~fr~l~~~#!«~~m Well Permit Separ Number Number PSI 2H-0 1 1840770 2H-02 1840730 2H-03 1840700 2H-04 1840550 2H-05 1851680 96 2H-06 1851690 96 2H-07 1851700 96 2H-08 1851710 96 2H-09 1852590 96 2H-IO 1852600 96 2H-. 1 1852610' 96 2H-12 1852620 96 2H-13 1840960 2H-14 1840950 2H-! 5 1840860 2H-16 1840870 2H-17 2000190 , .,\1~~:~î:i~qi~~" Set LIP PSI Trip , .' .}. ::?~~~~;f '$~~;Ff'. iÄ~~!4{~l~~i1~~lfi~t~ a~lJfllllE' ~~ Test Test Test Date Tested and Or Oil, WAG, GINJ, Code Code Code Passed Retest or SI GAS, CYCLE, SI WAG WAG WAG WAG OIL OIL OIL OIL OIL 11/11/2004 OIL OIL 11/11/2004 OIL WAG OIL WAG WAG WAG 70 50 P P 70 65 P P 70 70 P P 70 50 P P 70 55 P P 70 50 P 4 70 55 P P 70 60 P 4 70 50 P P 96 Wells: 9 Components: 18 Failures: 2 Failure Rate: 11.11o/G 90 Day l~emarks: 2H-I0 & 12 serviced and passed re-test Pad to be re-tested in 90 days RJF 09/19/02 Page 1 of 1 SVS KRU 2H 11-10-04.xls PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 July 24, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2H-05 (185-168) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation treatment on the KRU well 2H-05. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Per/orate _ 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 129 feet 3. Address Exploratory __ 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 168' FNL, 5084' FEL, Sec. 36, T11 N, RSE, UM (asp's 498595, 5948693) 2H-05 At top of productive interval 9. Permit number / approval number 1263' FSL, 1457' FEL, Sec. 25, T11N, RSE, UM 185-168/ At effective depth 10. APl number 50-103-20043 At total depth 11. Field / Pool 3875' FNL, 1120' FEL, Sec. 25, T11 N, RSE, UM (asp's 502557, 5950266) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 81 10 feet Plugs (measured) sand plug @ 7647' WLM true vertical 6451 feet Effective depth: measured 7647 feet Junk (measured) true vertical 6090 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 100' 16" 195 sxAS II 100' 100' SUR. CASING 2813' 9-5/8" eeo sx cs ~ & 350 sx cs ~ 2942' 2758' PROD. CASING 7956' 7" 400 sx Class G 8085' 6509' Perforation depth: measured 7535'-7565', 7666'-7694', 7722'-7748' ~ECEi~/~D true vertical 6006'-6028', 6104'-6125', 6147'-6167' JUL Tubing (size, grade, and measured depth) 2-7/8',6.5#, J-55 Tbg @ 7618' MD. Alaska Oil & Gas Cons. Commission Packers & SSSV (type & measured depth) BROWN 'HB' @ 7375' MD; BROWN 'lB' @ 7599' MD; Anchorage BAKER 'FVL' @ 1771' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) See attachment Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 343 712 132 - 214 Subsequent to operation 406 925 198 191 15. Attachments 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. Questions? Call Mike Moon@y263-4574 Signed ~ ~ Title Wells Group Supervisor Date Michael Mooney ,~/(/~ Prepared by Sharon A//sup-Drake 263-4612 I::nrrn 1 CJ-4(3,4 Ray 6)6/15/88 ORIGIN-AL SUBMIT IN DUPLICATE Date 05/20/01 Upcoming l-- Well Na 2H-05 JoD Num 0517011510.1 AFC 999683 Service Type PUMPING Unit 0 Desc of Work PRE-FRAC SAND PLUG Supervisor ODELL Contractor Key Perso DS-GALLEGOS Complet I'~ Successful r~ Accident I~ Initial Tbg Press 180 FinaITbg Press 40 Injury I-- Initial Int Csg Press 250 Final Int Csg Press 250 Spill [~ Initial Out Csg Press 300 Final Out Csg Press 300 Summary Prop 230DS28H Uploaded to Sen PUMPED PRE-FRAC SAND PLUG. PLACED 30CO# 20/40 RIVER SAND IN WELL DISPLACED LEADING EDGE TO TOP PACKER INCLUDING 12 BBLS DIESEL FREEZE PROTECTION. SHUT-IN TO LET SAND SETELE OUT. Fluid Summary 3000# SAND 12 BBLS DIESEL 20 BBLS GEL 12 BBLS SW Date printed: 07/23/01 at: 14:38:45 Date Well Na Service Type Desc of Work Supervisor Complet Accident Injury Spill Summary 05/21/01 Upcoming F 2H-05 Job Num 0517011510.1 PUMPING Unit PRE-FRAC: SAND PLUG CHANEY Contractor Key Perso DS-GALLEGOS F Successful r~' F Initial Tbg Press 0 F Initial Int csg Press 200 F Initial out csg Press 400 AFC 999683 1 Prop 230DS28H Uploaded to Set, FinaITbg Press 150 Final Int Csg Press 200 Final Out Csg Press 400 PUMPED PRE-FRAC SAND PLUG. PLACED 3000# 20/40 SILICA SAND IN WELL, TBG FREEZE PROTECTED DOWN TO 2000' W/E Fluid Summary 3000# SAND 20 BBLS GEL 12 BBLS OF SW 27 BBLS OF DIESEL Date printed: 07/23/01 at: 14:39:01 Date 05/25/01 Well Na 2H-05 Service Type PUMPING Desc of Work Supervisor Campier r~ Accident C Iduw F Spill F Summary Upcoming F Job Num 0517011510.1 Unit C SAND FRAC GOBER Contractor Key Perso DS-YOAKUM Successful F InitiaITbg Press 640 Initial Inf Csg Press 250 Initial Out Csg Press 300 AFC 999683 0 Prop 230DS28H Uploaded to Sen Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 PUMP 50 BBL 7% DAD ACID SPEAR - LET SOAK ON PERFS FOR 30 MIN - PUMP BREAKDOWN STAGE - PRESSURE DROPPED FRO 7600 PSI TO 7400 PSI BUT THEN IT CLIMBED UP TO 8171 PSI - PUMP SCOUR STAGE W/1 PPA 16/20 CARBOLITE(2011 LBS) - PRES DROPPED FROM 4900 PSI TO 4400 PSI DURING SCOUR - PUMP 100 BBL DATA FRAC - ANALYZE DECLINE - INCREASE PAD TO z BBLS FROM A DESIGN OF 350 BBLS - PUMP FRAC - NWBSO W/5.4 PPA 16/20 ON PERFS - TOTAL OF 47468 LBS 16/20 CARBOLI BEHIND PIPE - LEFT 383 LBS 16/20 AND 9888 LBS 12/18 IN WELLBORE - ******NOTE: LEFT 95% OF TREESAVER RUBBERS IN THE WELLHEAD****** (Frac-Reffac) n~t~ nrint~rl. (t7/~R/l~l .t: 14:37'.41~ MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 2, 2000 THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Safety Valve Tests Petroleum InspeCtor Kuparuk River Unit 2H Pad Saturday, December 2,-2000: I traveled to the KuparUk River Field and witnessed the semi annual safety valve system testing on 2H Pad. . As the attached AOGCC Safety Valve System TeSt Report indiCates .I witnesSed the testing of 9 wells and 18 components with four failures obserVed. The Iow pressure pilots on wells 2H-5,2H-6 and 2H-12 tripped well below the required set point and the surface safety valve on well 2H-12 failed to pressure test. The three failed pilots were adjusted and retested at the time of this test. The failed valVe will be repaired _ and retested by the operator. The 22.2% failure rate will require, a retest of this Pads normal3,20~_day cycle. ' Safety valve System in 90 days rather than the Earnie Barndt conducted the testing today he demonstrated good test prOcedure and was a pleasure to work with · - . Summary: I witnessed the semi annual SVS testing at 2H Pad in the KuParuk River Field. ' KRU 2H Pad, 9wells, 18 components, 4 failUres 22% failure rate Attachment: SVS KRU 2H Pad 12-2-00 CS X Unclassified confidential (Unclassified if doc. RemOved) SVS KRU 2H Pad 12-2-00 CS.doc Alaska Oil and Gas Conservation commiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Emie Bamdt AOGCC Rep: Chuck Scheve .' SUbmitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 2H Pad Separator psi: LPS 96 . HPS 12/2/00 Well Permit Separ Set L/P Test Test I Test Date Oil, wAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or cYcLE 2H-01 1840770 2H-02 1840730 . ' 2H-03 1840700 2H-04 1840550 , 2H-05 1851680 96 70 20 3 P 12/2/00 OIL 2H-06 1851690 96 70 10 3 P 12/2/00 ' OIL 2H-07 1851700 96 70 60 P P OIL 2H'08 1851710 96 70 60 P P ' OIL 2H-09 1852590 96 70 50 ~ P '~ -OIL 2H-10 1852600 96 70 . 50 P P OIL 2H-11 1852610 96 70 50 P P OIL 2H-12 1852620 96 70 10 3 4 remarks 2H~13 1840960 2H-14 1840950 96 70 60 P P : OIL 2H-15 1840860 , 2H-16 1840870 2H-17 2000190 . Wells: 9 Components: 18 FailureS: 4 Failure Rate: 22.0% El90 var Remarks: three failed pilots repaired' and retested, failed SSV to be repaired and retested by op Pad on 90 day test cycle ' - 12/4/00 Page 1 of 1 SVS KRU 2H Pad 12-2-00 CS.xls ARCO Alaska, Inc. Posl Office'~'~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in duplicate are multiple Reports of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 2 B- 0 3 Stimulate 2 H- 05 Stimulate 2 H- 0 7 Stimulate If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 KOE1.4-9 w/o attachments RECEIVE? ARCO Ala_~k.~. Inc. is a Subsidiary of AtlanficRichfieldCompany STATE OF ALASKA ..,~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 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 169' FNL, 196' FWL, Sec. 36, T11N, R8E. UM At top of productive interval 1263' FSL, 1457' FEL, Sec. 25, T11N, R8E, UM At effective depth 1385' FSL, 1220' FEL, Sec.25, T11N, R8E, UM At total depth 1404' FSL, 1121' FEL, Sec. 25, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 81 1 0' feet Plugs (measured) 6 4 4 9' feet 6. Datum elevation (DF or KB) RKB 12~) 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-05 9. Permit numbe~, 10. APl number 5o-1 03-20043 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7988' feet Junk (measured) 6 3 5 3' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 100' 2942' 9 5/8" 8085' 7" measured 7535'-7565' (C Sand), true vertical 6006'-6028', 6104'-6125', Cemented Measured depth True vertical depth 195SxASII 100' 100' 880 Sx CS III & 2942' 2758' 350 Sx CS II 400 Sx Class G 8085' 6509' 7666'-7694', 7772'-7748' (A Sand) 6147'-6167' Tubing (size, grade, and measured depth 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 7618' Packers and SSSV (type and measured depth) Packers: BOT HB 7375', BOT lB 7599', Baker FVL @ 1771' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 7666'-7694', 7772'-7748' Treatment description including volumes used and final pressure 1892 bbls gelled diesel, 120,500 lbs of 16/20 Carbo-Lite, Final pressure 4960 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 793 808 17 840 174 1 600 1 126 1 1000 175 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~' ~ TitJeSR. OPERATIONS ENGINEER Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~.ARCOAlaska, Ir . ,~. Subsidiary of Atlantic Richfield com~a1~ WELL 'ON ~"~RACT(~ REMARKS JPBDT OPERATION AT REPORT TIME WELL SERVICE REPOR'I CC' /7 I'"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE Of ALASKA ~ OIL AND GAS CONSERVATION C_,OMI~SSION~ ~ ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 169' FNL, 196' FWL, Sec. 36, T11N, R8E. UM At top of productive interval 1263' FSL, 1457' FEL, Sec. 25, T11N, R8E, UM At effective depth 1385' FSL, 1220' FEL, Sec.25, T11N, R8E, UM At total depth 1404' FSL~ 1121' FELr Sec. 25, T11N, R8E, UM 12. Present well condition summary Total Depth: measured 81 1 0' true vertical 64 4 9' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 129 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-05 9. Permit number 85-168 10. APl number 5o-1 03-20043 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 798 8' feet Junk (measured) 6 3 5 3' feet None Casing Length Structural Conductor I 0 O' Surface 2 94 2' Intermediate Production 8 0 8 5' Liner Perforation depth: measured 7535'-7565' (C true vertical 6006'-6028', Tubing (size, grade, and measured depth Size Cemented Measured depth True vertical depth 1 6" 195 Sx AS II 100' 100' 9 5/8" 880 Sx CS III & 2942' 2758' 350 Sx CS II 7" 400 Sx Class G 8 0 8 5' 6 5 0 9' 6104'-6125', 6147'-6167' 2 7/8" J-55 EUE, 6.5 Ib/ft, set @ 7618' Packers and SSSV (type and measured depth) Packers: BeT HB 7375'~ BeT lB 7599'r Baker FVL ~ 1771' 13. Attachments Description summary of proposal_ Refrac A Sand with 113~800 lbs of 16/20 mesh carbolite. 14. Estimated date for commencing operation I September. 1989 I 16. If proposal was verbally approved I I Name of approver Date approved Detailed operation program ~ BOP sketch _ (Procedure and Wellbore schematic attached). 15. Status of well classification as: Oil X Gas m Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISi,ned ,/'~~,. /.r~~/_.~.~--,,*-~ Ti,eSr. Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONN!E c. RMITH lO.Z/~ ~- A,p~3roved CoPY Returned IApproval No. , ?- Date SUBMIT IN TRIPLICATE Messrs Sloan and Jack~JO~n August 16, 1989 Page 3 Kuparuk Well 2H-05 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K80518 1. MIRU Slickline unit. Tag bottom. . . Pull GLV's at 2281', 4372', 6567, and 7322'. Pull CV's at 7412', 7478', and 7583'. Run DV's at 2281', 4372', 6567', 7412', 7478', and 7583'. Circulate 2 7/8" tubing and 7" annulus with 9.8 ppg brine with a 500' diesel cap. Set DV in GLM at 7322'. Note that DV's are already run in gas lift mandrels at 5749' and 6949'. Set standing valve in Camco 'D' nipple at 7611' MD-RKB. Pressure test the tubing. Pull standing valve. RDMO. 4. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. . ! . Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. Pump the 200 Bbl pre-pad at 20 BPM. Shut down and determine the ISIP. The A Sand was perforated with 216 shots, 4 spf, at 90 degree phasing). Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure' WHTPE = 5200 psig Fracture Gradient = 0.70 psi/ft (6130' TVD) Tubing Friction = 400 psi/1000 ft (7618' MD) * If excessive treating pressures are experienced, try reducing the rate in small increments adjusting additive rates as appropriate. If treating pressure exceeds 6000 psi, begin flush stage. With brine on the backside, the maximum recommended treating pressure is 6400 psi based on analysis of tubing strength and Brown PBR type. 8. Rig down fracture stimulation equipment. Follow attached flowback schedule. KUPARUK WELL 2H-05 A SAND FRACTURE PUMP SCHEDULE 8117189 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CU M BBLS 1 GW PRE-PAD 200.0 20 0 - - 0 200 / 200 46 ............................................. SHUT DOWN FOR ISIP, FLOW METER CALIBRATION ................................................ 2 GWPAD 1100.0 20 0 - - 0 1100/ 1300 246 3 GW wi2 PPG 73.5 20 2 16/20 M CARBO-LITE 6176 80 / 1380 1346 4 GW w/4 PPG 85.0 20 4 16/20 M CAI~BO-LITE 14282 100 / 1480 1426 5 GW w/6 PPG 83.0 20 6 16/20 M CARBO-LITE 20926 105 / 1585 1526 6 GW w/7 PPG 84.1 20 7 16/20 M CARBO-LITE 24715 110 / 1695 1631 7 GW wi8 PPG 73.9 20 8 16/20 M CARBO-LITE 24841 100 / 1795 1741 8 GW wi10 PPG 34.7 20 I 0 16/20 M CARBO-LITE 14576 50 / 1845 1841 9 GW w/12 PPG 16.4 20 1 2 16/20 M CARBO-LITE 8241 25 / 1870 1891 0 44 / 1889 1891 1 0 SLICK DIESEL FLUSH 44.0 +SV 2 0 0 .- - TOTAL DIESEL IN PAD = 72.9 BBLS 16/20 M CARBO-LITE = 113758 LBS TOTAL GELLED WATER = 1750.6 BBLS TOTAL SLICK DIESEL FOR FLUSH = 44.0 BBLS +SV NOTES: Stage 1 is Gelled Water. Stage 2 is Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. Stage 3 through 8 are Gelled Water with 6 hour breaker WITHOUT silica flour. i~,,~j~ges 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. {,,.,,,,6~age 9 should include a volume adjustment for surface equipment between the wellhead and densimeter. '~"~is job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. ~"~il fluids should be maintained at 100° F on the surface. SUNDRY NOTICE - WELL 2H-05 NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. BOTTOM HOLE PRESSURE (6200' SS) = 3000 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. 1. Type of Request: STATE Of ALASKA ....~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown ~ Stimulate m Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Ali~ska. 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 169' FNL, 196' FWL, Sec. 36, Tll N, RSE, UM At top of productive interval 1263' FSL, 1457' FEL, Sec. 25, T11N, RSE, UM At effective depth 1385' FSL, 1220' FEL, Sec. 25, T11N, RSE, UM At total depth 1404' FSL, 1121' FEL, Sec. 25, T11N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 8110' 6449' feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 129' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2H-05 f/(.o ~ 9. Permit number/approval number 8-22 10. APl number 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7988' true vertical 6353' feet Junk (measured) feet Casing Length Size Structural Conductor 1 0 0' 1 6" Surface 2942' 9 5/8" Intermediate Production 8 0 8 5' 7" Liner Perforation depth: measure Cemented Measured depth 195 Sx AS II 100' 880 Sx CS III & 2942' 350 SX CS II 400 Sx Class G 8 0 8 5' 7535'-7565', 7606'-7694', 7722'-7748' MD True vertical depth 100' 2758' 6509' true vertical 6006'-6028', 6104'-6125', 6147'-6167' TVD Tubing (size, grade, and measured depth) 2 7/8", J-55, EUE, 6.5 Ib/ft, 7637' MD Packers and SSSV (type and measured depth) SSSV: Baker FVL 1771', Packers: BOT HB 7375', BOT lB 7599' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) 7535'-7565' ~as~a, 0il & ~as Cons, C0mm[s¢0~:~ Treatment description including volumes used and final pressure Acidize C Sand with 2000 gallons of 12% HCI. Final Pressure- 3700 PSI Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Produce 410 270 0 --- 125 PSIG Subsequent to operation Produce 550 663 0 --- 150 PSIG 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 I~v 06/15/88 Date '~ ~'~ .t SUBMIT IN DUPLICATE ARCOAlaska, Ine 0 Subsidiary of Atlantic Richfield Compai,..~, WELL SERVICE REPORT WELL PBDT )NTRACTOR REMARKS FIELD. DISTRICT. STATE OPERATION AT REPORT TIME DAYS 1 DATE JJ$~ I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather [Temp. [ Chill Factor [ Visibility[Report OF OF miles Wind Vel. knots ]Signed ARCO Alaska, Inc. Date: April 8, 1988 Transmittal#: 7141 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-11 1 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Bottom-Hole Pressure Survey 2 - 2 5 - 8 8 PBU Receipt DISTRIBUTION: D&M '--' ~"olcs Oii & Gas Cor~s, '~' Anchorage Acknowledged' - .......................... Date: ................... State of Alaska Chevron Mobil SAPC Unocal ARCO Alaska, Inc. Posl Office B ~60 Anchorage, Alaska 99510-0360 Telephone' 907 276 1215 Date: March 15, 1988 Transmittal #: 7119 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2D-I4 2Z-8 3C-15 2D-12 Kuparuk Operations Engineering Water Injection Spinner_Data. Sheet. 2-16-88 Both Sands Kuparuk Operations Engineering Water Injection Spinner Data Sheet 3-2-88 Both Sands Kuparuk Operations Engineering Buildup Analysis Kuparuk Well Pressure Report(Otis) 2-27-88 GRC Amerada Chart(2) Pressure/Temperature 8-26-87 2-16-88/2-19-88 2-25-88 'C' Sand PBU 'A' Sand PBU 'A' Sand PBU 'A' Sand Receipt Acknowledged: DISTRIBUTION: D&M f '~'a Oil & C~as Cons. Commissien '"'~"'" Anchorage Chevron Mobil SAPC Unocal ARCO Alaska. Inc. is a Subsidiary ol AllanlicRichlieldCornpany STATE OF ALASKA ALASK¥,--OIL AND GAS CONSERVATION COMM-,=~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing D Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate n Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P.O. Box 100360~ Anchorage~ Alaska 99510 4. Location of well at surface 169' FNL, 196' FWL, Sec. 36, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB 129' 6. Unit or Property name Kuparuk River Unit -7. Well number 2H-05 At top of productive interval 1263' FSL, 1457' FEL, Sec. 25, At effective depth 1385' FSL, 1220' FEL, Sec. 25, At total depth 1404' FSL~ 1121' FEL~ Sec. 25~ 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical T11N, R8E, UM T11N, R8E, UM UM T11N ~ R8E ~ 8110' 6449' feet feet 7988' feet 6353' feet Casing Length Structural Conductor 100' Surface 2942' Intermediate Production 8085' Liner Perforation depth: measured Size Plugs (measured) Junk (measured) Cemented 16" 195 Sx AS II feet 8. Permit number 85-168 9. APl number 50-- 103-20043 10. Pool Kuparuk River 0il Pool · ,':..:.':'.-- j~!; ?L {',::s Co;'is. '"'-'" True VoP[ib~'~e pt h Measured depth 100' 100' 2942' 2758' 8085' 6509' 9-5/8" 880 Sx CS III 350 Sx CS II 7" 400 Sx Class "G" 7535'-7565' 7606'-7694' 7722'-7748' MD true vertical 6006'-6028' 6104'-6125' 6147'-6167' TVD Tubing (size, grade and measured depth) 2 7/8", J-55, EUE, 6.5 lb/ft, 7637' MD. Packers and SSSV (type and measured depth) SSSV' Baker FVL 1771', Packers' BOT HB 7375', BOT lB 7599' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] See Attached procedure - Acidize C Sand with HCL. 13. Estimated date for commencing operation January, 1988 14. If proposal was verbally approved F:,¢.,:-:/::.:..:-.,. Name of approver L, /[/~ '~' '-~; ""/~1"-'¢~'~::':'~ "' / /-''~ ...... Date approved to the best of my 15.1 hereby certify that the~regoing is true ~nd correct ~ /~ knowledge Signed .~~¢ ~ ~~~..~~ Title Commission Use ~ly Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned ~.~ ~ / ¢- ,r Date ORIGINAL SIGNED BY Approved by Form 10-403 Rev 12-1-85 LONNiE 6. $~iTH Commissioner the commission Date / ~"/ ~0 Submit in triplicate December 29, 1987 .Page 2 Kuparuk Well 2H-05 Acid Stimulation Procedure (12/29/87} . 2. 3. 4. 5. . Ze J e e . Pre-Stimulation MIRU slickline unit. RIH and set BP in D-nipple. Pressure test tubing to ensure all DVs are set. Open well to production. Obtain oil sample and have operations engineering pick up for use in determining if a non-emulsifing agent is needed in the treatment. {Ensure two tubing volumes have been produced so that a representative sample will be obtai ned. ) Check Ph of oil sample with litmus paper and record. Stimulation MIRU acid pump truck, nitrogen truck,and frac tank. RU lines from wing valve through choke manifold into frac tank to allow immediate flowback after job is pumped. RU pump truck and nitrogen truck to swab valve via T connection, pressure test equipment with diesel. Ensure 2 7/8"/ 7" annulus is loaded with diesel to surface. Prior to performing acid treatment contact operations engineering to perform normality check of acid to verify the strength is at 12% HCL by weight. Establish injection into tubing with diesel to ensure ability to pump into zone. Pump +/- 20 BBL and SD. (Max pressure : 2000 psi). Pump 30 BBL )12 (+/-28,000 SCF} down tubing @ +/- 3 BPM (2800 SCFPM). Maintain N2 at 100 Deg F throughout job(. A conversion chart for N2 at various conditions is attached. Max pressure = 2400 psi). Decrease N2 injection to I BPM (+/- 925 SCFPM) and pump the following acid schedule @ 3 BPM. 750 gal 12% HCL MSR 100 W/ 2 gal per 1000 A-250 (inhibitor) and 1 gal per 1000 J-237 (oil soluble resin) Displace acid to perforations with 55 BBL {51,000 SCF) N2 at a rate of 3 BPM. (This is an over displacement of 6 BBL to account for inaccuracies in N2 metering. Max Pressure = 2400 psi.} ARCO Alaska, Inc. Post Offic, ~x 100360 Anchorag¢',--~.~aska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 Transmittal f~ 5926 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-8 2H-6 2H-5 3F-13 3F-12 2H-8 2H-7 3F-14 3K-5 3K-3 3K-4 3F-12 CBL 2-16-87 6195-9264 CET 1-17-86 7400-8873 CET 1-16-86 6525-7959 CET 1-7-86 6160-7920 CET 1-23-86 6946-7250 CET 1-1-86 8000-8650 CET 1-1-86 6800-7938 CET 1-7-86 4700-6760 CET 7-16-86 6988-7990 CET 7-14-86 7595-8800 CET 7-14-86 7793-8787 CET 1-7-86 6050-7416 Anchorage/ A~aska 0il& Gas Cons~ Commission Rec~i.pt A~nowle~ _ ~ 7 . Date: DIS~ . NSK , Drilling State (+ sepia) BPAE Chevron SAPC Mobil Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary o! AllanticRichfieldCompany ~"' STATE OF ALASKA ~ ~ ALASKT~OIL AND GAS CONSERVATION CI~MMISSION ~ ~ ,,' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-168 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20043 4. Location of well at surface 9. Unit or Lease Name 169' FNL, 196' FWL, Sec.36, TllN, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1263' FSL, 1457' FEL, Sec.25, TllN, R8E, UM 2H-5 At Total Depth 11. Field and Pool 1404' FSL, 1121' FEL¢ Sec.25~ TllN~ R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 129' RKBJ ADL 25587 ALK 2673 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 1 2/30/85 01/04/86 01/07/86'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8110'MD,G449'TVD 7988'MD~G353'TVD YE,~x[] NO [] 1790 feetMD 1500' ~Approx~ 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL~ Cal, CET, GCT~ VSP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: 62.5# H-40 Surf 1uu' ;~" 195 sx AS II ~)-.b/8' :~6.U# J-55 Surf 2942' 12-1/4" 800 sx CS III & 350 sx (;S II /" ;~6.0# J-55 Surf 8085' 8-1/2" 460 sx Class G & 180 sx Permafrost C , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7535' -'7565' w/4 spf, 90° phasing 2-7/8" 7637' 7394' & 7618' 7666' - 7694' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7722' - 7748' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27.N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD II~ , Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE * NOTE: Tubing was run & well perforated 2/10/86. JG/WCl :101 /~';~O~'~'~- -,..~.~.~ Form 10-407 Submit in duplicate CONTINUED ON REVERSE SIDE Rev. 7-1-80 GEOLOGIC MARKERS MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. _ Top Kuparuk C 7534' 6004' N/A Base Kuparuk C 7567' 6028' Top Kuparuk A 7634' 6079' Base Kuparuk A 7820' 6221' 31. LIST OF ATTACHMENTS Addendum (Dated 8-06-86) :J2. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~~){-M ~ TitleAss°clare Engineer Date //~~ ~))/~(~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and.log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 1/20/86 2/04/86 7/29/86 2H-5 Rn CET log & GCT gyro. Rn VSP log; had noise interference on 4 tls - suspect noise coming f/free pipe. Arctic Pak w/30 bbls PF "C", followed by 59 bbls Arctic Pak. ' ~D'ri/'~ing Superintendent ° Df re ADDENDUM WELL: 1/20/86 2/04/86 2H-5 Rn CET log & GCT gyro. Rn VSP log; had noise interference on 4 tls - suspect noise coming f/free pipe. MAR 1 ? 1986 Alaska Oil & Gas Cons. Commission Anchorage Drilling ~uperintendent AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion andrepresentative test data in blocks provided. The "Final Report'* form may be used for reposing the entire operation if space is available. Accounting cost center code District ICounty or Parish State Alaska Alaska North Slope Borough I Field ILease orUnit IWell no. Kuparuk River ADL 25587 2H-5 Auth, or W.O. no. ~Title AFE AK0008 I Completion Nordic Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun I Date Complete I Date end depth as of 8:00 a.m. Old TD 2/08/86 thru 2/10/86 2/11/86 Complete record for each day reported 1630 hrs. Released rig API 50-103-20043 W.I. ~otal number of wells (active or inactive) on this 56.24% Icost center prior to plugging and labandonment of this well I ~Hour I Prior status if a W.O. 2/9/86 / 1315 hrs. 7" @ 8079' 7988' PBTD, RIH w/2-7/8" CA 10.6 ppg NaC1/NaBr Accept rig @ 1315 hrs, 2/9/86. ND tree, NU & Cst BOPE. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/7535'-7565'. Perf w/5" gun, 12 SPF, 120° phasing f/7666'-7694' & 7722'-7748'. Unable to get 6.125" gage ring thru "C" perf's. Rn 6" gage ring. Set lB pkr @ 7599', RD Schl. RIH w/2-7/8" CA. 7"@ 8079' 7988' PBTD, RR 6.8 ppg diesel in tbg & ann Fin rn'g 238 jts, 2-7/8", 6.5#, J-55 EUE 8RD IPC tbg w/SSSV @ 1790', lB Pkr 7618', pkr @ 7394', "D" Nipple @ 7611', TT @ 7637'. Set & tst pkr. Shear PBR. Tst pkr & SSSV. Set BPV. NU & tst tree. Displ well to diesel. RR @ 1630 hrs, 2/10/86. New TO Date 2/10/86 I PB Depth 7988' PBTD Kind of rig Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) Single Official reservor name(s) Kuparuk Sands Potential test data Well no. Data Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choice size T.P. C.P. I Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation and(~distribution, see Procedures Manual. Section 10. Drilling, Pages 86 and 87. Date . / ITitle Drilling Superintendent ARCO Alaska, Inc. Post Office B~'x~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2H-5 Dear Mr. Chatterton: Enclosed 2H-5. I details) If you h are the Well Completion Report and gyroscopic survey for have not yet received the Well History (completion . When I do, I will forward a copy to you. ave any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L152 Enclosures FEB 2 8 ]986 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA'O'FL AND GAS CONSERVATION COI~MISSION WELL COMPLETION OR RI=COMPLETION R£ ORT AND LOG 1. Status of Well Classification of Service Well OIL [~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-168 3. Address 8. APl Number P. 0. Box 100:360, Anchorage, AK 99510 50- 103-20043 4. Location of well at surface ~$~ 9. Unit or Lease Name 169' FNL, 196' FWL, Sec.36, T11N, RaE, UN~/~ ~/E~,~FI~.o~.~ Kuparuk River Unit At Top Producing Interval ~~- ~.~~ 10. Well Number 1263' FSL, 1457' FEL, Sec.25, T11N, RaE, UHI"_-., ¢ ~'Surf 2H-5 At Total Depth ~ '11. Field and Pool 1404' FSL, 1121' FEL, Sec.25, T11N, RaE, UN Kuparuk River Field . 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 129' RKBJ ADL 25587 ALK 2673 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore [16. No. of Completions 12/30/85 01/04/86 01/07/86*I N/A feet MSL] 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 8110 'MD ,6449 'TVD 7988 'MD ,6353 'TVD YES ~ NO [] 1790 feetMDI 1500, (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT, VSP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 100' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 2942' 12-1/4" 800 sx CS Ill & 350 s~ CS Il 7" 26.0# J-55 Surf 8085' 8-1/2" 460 sx Class G 24. Perforations open to Productio~ (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER S'ET (MD) 7535' - 7565' w/4 spf, 90° phasing 2-7/8" 7637' 7394' & 7618' 7666' - 7694' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7722' - 7748' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~Ir 28. CQRE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE FEB 26 1986 Form 10-407 * NOTE: Tubing was run & well perforated 2/10/86. DAM/WC48 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUEVERT. DEPTH 6004' 6028' 6079' 6221' 30. FORMATION TESTS 7534' 7567' 7634' 7820' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer 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: Atl;a~ch. ed supplemental records for this well should show the details of any multiple stage cement- ing and the-"lOc~l~.i6~ ~f 1;h~ cementing tool. Item 27: M.etl~od~.qf Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injecl~i0'h, Shut-in, Other-explain. -~i~rt~O~': .~f~,; ~, . .. , Item 28: If no g~,'~bs"t~'k~n;:'i'n~tl6,~'te "none". FOrm 10~07 ARCO Alaska. Inc. Post Office 86X--r00360 Anchorage. Alaska 99510-0360 Tedepnone 907 276 1215 ATTN: Kulak Records Clerk ATO 1119 P. O. 5cx 100360 Anchorage AK 99510-0360 DATE 02-11-86 TRANSMITTAL # 5561 Transmitted herewi~n are the following items. Please acknowledge receipt and return one si~ned copy of this transmittal. Final Prints/ C?e_n Hole/ Schl/ One * of each ~3J-11 5" D2L/S_-~-GR 12-20-85 .~ 2" D2L/S~-GR 12-21-85 5" DenzQ~eu (poro) 12-20-85 2" Den/~eu (poro) 12-21-85 5" .Den/~eu (raw) 12-20-85 2" 'Den/7~u (raw) 12-21-85 Cyberiook 12-20-85 ~3I-1 5" D_~/S_-~ 01-07-86 2" D_--L,'~ 01-07-86 5" D~_n/~Jeu (poro) 01-07-86 2" D~_n/~.;e u (poro) 01- 07- 86 5" Den.~.~eu (raw) . 01-07-86 2" ,~=--n ~eu (raw) 01-07- 86 Cyber!ook 01-07-86 ~3F-15 5" DLL/SFL 12-31-85 ~ 2" D_~r~_ ~/~_-~-.~ 12-31-85 5" De_n/~_~eu (poro) 12-31-85 2" Den/~eu (poro) 12-31-85 5" ~-~_n-/~eu (raw) 12-31-85 2" D~eu (raw) 12-31-85 C_~>e_r!ook 12- 31- 85 ~ 3A-16 5" D~/S_--~,-GR 12-26-85 ~ 2" D~/_-_~-' ~_-GR 12-26-85 5" De_n/~eu-GR (poro) 12-26-85 2" D~_n/q~e u- GR (poro) 12- 26- 85 5" Den,~_{eu-GR (raw) 12-26-85 2" ~en,~.~eu-GR (raw) 12-26-85 CS_~e r look 12- 26- 85 ~4 2H-5 5" ~,./-----i_-GR 01-05- 86 2" _~LL,/SFL- SR 01-05-86 5" 'D~/9_{eu (poro) 01-05-86 2" De_n/".~e_ u (poro) 01- 05- 86 5" .Len/~eu (raw) 01-05-86 2" ~--an,~Jeu (raw) 01-05-86 C~_~-ber ! osk 01- 05 - 86 Rathmell*bl Receipt Acknow!e d_--ed: ~%ate Of Alaska*b!/se Drilling*bi Run 91 2000-78~6 Run #1 2000-7664 Run #1 6900-7830 Run #1 6900-7638 Run 91 6900-7830 Run #1 6900-7638 Run 91 6900-7600 Run 01 2600-8908 Run #1 2600-8908 Run 01 4400-8883 Run 91 4400-8883 Run 01 4400-8883 Run 01 4400-8883 Run 01 8600-8850 Run 01 1590-7536 Run 01 1590-7536 Run #1 4084-7511 R~n 01 6805-7511 Run 01 3297-7511 Run #1 3297-7511 Run 91 3297-7400 Run #1 1890-9142 Run #1 1890-9142 Run #1 4390-9117 Run #1 4390-9117 Run #1 4390-9117 Run #1 4390-9117 Run #1 8390-9100 Run #1 0100-8078 Run #1 01~0-8078 Run 01 3500-8053 Run #1 3500-8053 Run 01 3500-8053 Run #1 3500-8053 Run #1 7400-7800 Date: D&M*bl NSK Clerk*bl Vault* fi lms F ! 1986 ~ ~,-~ 0:,I & ~as Cons. Camm',ss:~n ARC.' &,.,Bm. inc. ;t · Subt~Cliir¥ of AilinticRichftelclCompiny ARCO Alaska, Inc. Post Office BolerO0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for each of the following wells' 2H-5 2H-6 2H-7 2H-8 I have not yet received the 2H-7 and 2H-8 Well Histories. When I do, I will forward them to you. Also, bottomhole locations, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic surveys are run and the wells completed. If you have any questions please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L72 Enclosures A . ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA'----- AND GAS CONSERVATION CC~..,VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name ~f Operator 7. Permit Number ARCO Alaska, Inc. 85-168 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20043 41 Location of well at surface 9. Unit or Lease Name 169' FNL, 196' FWL, 5ec.36, T11N, R8E, UN (approx.) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2H-5 Total Depth 11. Field and Pool A~o be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 129' RKBI ADL 25587 ALK 2673 12.1Date2/30/85Spudded 13.01Date/04/86T.D. Reached 14.01Date/07/86Comp., Susp. or Aband. I 15.N/AWater Depth, if feet offshoreMSL 116. No. of N/AC°mpleti°ns 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set i 21. Thickness of Permafrost 8110 'ND 7988 'ND YES [] NO [~X N/A feet MDI 1500 ' (Approx) 22. Type EleCtric or Other Logs Run D I L/GR/SP/SFL, FDC/CNL, , 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 6Z.b~ H-~U Surf 100' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 2942' 12-1/4" 800 sx CS II1 & 350 sx CS II 7" 26.0~ J-55 Surf 8085' 8-1/2" 460 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I · Date of Test Hours Tested IPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE {GAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c°rr) Press. 24-HOUR RATE 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE .: Form 10-407 TEMP3/~C67 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~' 30. ~1~I~~ · GEOLOGIC MARKERS .FORMATIONTESTS - . NAME __ Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF A~TTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ /,~ (~ ~~6~_j Title Associate Engineer Date ~°L¢°~ 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 i ARCOOIl and Gas Company Jk~ -- Well History:, Initial Report:~ DailF~ Prepare and submJt tho "Initial R~p~t" on the first Wednesday after a well is spudded or workover operations are starled, Daily work prior to sPudding should be eummadzed on the form giving inclusive dates only, Alaska North Slope Borough. J Alaska Field Lease or Unit Well no. Kuparuk River ADL 25587 2H-5 Auth. or W.O. no. itle AFE AK0006 Drill' 26E Nabors. APT 50-103-20043~ :~.'__ - . uperetorA '_ :. lARGO W ..I Spudded Or W.O. begun.c ' .... lO,ts- - " · SPudde4~:c... '" - I 12/3(}/'-8:~:--'-'-'~'-1~':-'~::':'?/-'::13/+5'::~h=~':'-'[~;::':::::~:':~ :':-":~'- Date. and d~l~tllyr:,-...'.. r ' -- ~'ompl'lt~l"re~0rd for each day'm~A~'.' .- : . 1830', (1730'), Navi-O~.~.:-:' w~. 9.0, ~v 9, Y? tr., *~P~ =~s ~ o64~ ~,,. ~/3o/s~. 1345 hfs, 12/30/85. Drl to-1345%~ ~; H:~; ~71E, 1634,9 1/Ol/86 thru 1/02/86 1/03186 1/04/86 thru 1/06/86 9-5/8" @ 2942' " 3371', (1541'), Drlg. Wt. 8.7· PV 3, YP 10, PH 10.5· WL 20, Sol 5 ' Navi-Drl to 2958', wiper trip, C&C, POH. RU & rm 74 its,_ 9-5/8", 36#, J-55 BTC csg w/FS @ 2942'.- Cm= w/80Osx-CS-III, followed by 350 sx CS II Displ using rig-pmps, bump plus-, diverter. NU & tst BOPE~ TIH, DO flt equip.& cmt + 16' new- hole. Conduct formation tst to 12.5 ppg EMW. Navi-Drt 8%" hole to 3371'. 1855', 18.4°,. N70.12E,. 1844.9 TVD, 91VS, 30.ON, 86;0E 2455' 34.5" NTO'.i2E, 2380.8 TVD, 357 VS, 128.6N, 333.1E · 2878', 43.42~, N68.12E, 2709.7 TVD, 622.7 VS, 232.2N, 577.8E' 3205' 44.9~ N68.2E, 2943.3 TVD,-851.1VS, 317.0N, 789.9E · · 9-5/8" @ 2942' 6216', (2845'), Drlg Wt. 9.5, PV 13, YP 6, PH 9~5, WL 6.8, Sol 8 Drl & surv 8%" hole to 6216'. 3707', 43.5°, N66.2E, 3302.0 TVD, 1202.9 VS, 453.4N, 1114.3E 4399', 45.9°, N68.2E, 3790.6 TVD, 1692.8 VS, 641.0N, 1566.9E 5089'· 47.5°, N68.2E, 4280.1 TVD, 2178.9 rS,-821.6N, 2018.2E 9-5/8" @ 2942' 8110' TD, (1894'), Ch$ rams Wt. 10.6· PV 15, YP 10, PM 9.5, WL 6, Sol 9 Navi-Drl & surv 8%" hole to 8100', make cond'g, trip f/logs· TOM. RU SWS, rn DIL/GR/SP/SFL/CAL f/8086'-2942' MD, cont w/G~ to surf. Rn ~DC/CNL f/8086'-3500' MD; Rn West Sak VSP log. RD loggers. RIM & make wiper trip· TOM, LD D~. Chg rams. 6126', 46.3°, N66.2E, 4993.5 TVO, 2931.3 VS, 1111.5N, 6788', 46.6", N68.2E, 5445.7 TVD, 34.14.8 VS, 1291 2N, 7663' 40.3° N67.2E, 6074.3 TVD, 4022.4 VS,. 1533,4N, 3719,1E · · The above Is correct Signature For [orm preparation and I~stribution, see Procedures Manual, S6ctlon 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Weli"Fiistory- Final Report Inslructlons: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAccounting State cost center code Alaska North Slope Borough IWell no. 2H-5 District ~County or Parish I Alaska Field ILease or Unit Kuparuk River I ADL 25587 Auth. or W.O. no. ~Title AFE AK0006 [ Drill Nabors 26E Operator [A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun ~Date Spudded I Date and depth as of 8:00 a.m. 1/07/86 Complete record for each day reported AP1 50-103-20043 I rotal number of wells (active or inactive) on this, ;cost center pr or to plugging and I !abandonment of this well Hour [ Prior status if a W.O. 12/30/85 1345 hrs. I 7" @ 8085' 7988' PBTD, (0'), RR Wt. 10.6, PV 15, YP 10, PB 9.5, WL 6, Sol 9 ~ RU & rn 186 its, 7", J-55 BTC csg wfFS @ 8085', FC @ 7994'. Cmt w/100 sx Class G lead cmt w/2% A-2, 1% R-7 & 2 gal/100 sx FP-dL, followed w/360 sx Class G tail w/l% FL-19, .5% CD-31, .3% A-2 & 1 gal/100 sx FP-dL. Bump plug. ND BOPE, instl pack-off, NU tbg head & tat to 3000 psi. RR @ 0100 hfs, 1/7/86. DS 2A-12. Moving to Old TO New TD Released rig Date 0100 hrs. Classifications (o11, gas, etc.) 0tl Producing method Flowing Potential lest dais PB Depth 8110' TD IKind of rig 1/7/86 I Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7988 ' PBTD Rotary Well no. Oate Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Signature Date ITitle ~ ~ ,,F. Zz.//~,,'~ Drilling Superintendent · For form preparation and ~llstribution, see Procedures Manual, Section 10, Orllling, Pages 86 and 87. SUB-SURFACE DIRECTIONAL URVEY [-~IUIDANCE [~']ONTINUOUS ~"1OOL RECEIVED FEB 2 8 1986 Alasl~ ~i ~, uas Cons. Commtsmon Company ARCO ALASY~ INCORPOP,_A_TED Well Name ~. 2H-5 (169' YN-L, 196' 7-w-b, S36, TllN, R8E) Field/Location ~:~~, NORTH S~O~E, ~AS~ Job Reference No. 71232 Logaecl B~: BEUTLER Date 11-FEB-1986 Computed By: CUDNEY GCT DIRECTIDN~L SURVEY 2USTOMER LISTIN~ ~RC2 ALASKA, INS. 2H-5 KUP~RUK NORTH SLOPE,AL&SKA SURVEY DATE: 17-JAN-86 ENGINEER: BEUTLER METHODS OF CDMPUTHTIO~ TOOL LD:ATI]N: TANGENTIAL- ~VE~A~Eg DEVIATI3N AND ~.ZIM~TH INTERPgLATIDN: LINEAR VERTICAL SECTI]N: qORIZ. DIST. PRgJECTED O~TO ~ T~RGET AZIMUTH OF NORTH 68 DEE 25 MIN EAST ARC(] ~LASKA, I~C. 2H-5 NORTH SLDPE~AL~SKA COMPUTATION DATE: INTERPOLATED VALUES FOR TRUE SJO-SEA ME~SURE3 VERTICAL VERTI2AL 3EPTH DEPTfl DEPTH 0.00 0.00 -129.00 100.00 100.00 -23.00 200.00 200.00 71.00 300.00 300.00 171.00 400.00 400.00 271.00 500.00 500.00 371.00 500.00 600.30 471.00 700.00 700.00 571.00 BDO.OD 800.00 S71.00 900,00 900.00 TTl,OO 1000.00 1000.00 871.00 110.0.00 llO0.DO 971.00 lZO0.O0 1200.00 1071.00 1300.33 1300.00 1171.00 1430.00 1399.99 1270.99 1500.00 1499.84 1379.84 1500.00 1599.01 1470.01 1700.00 1696.98 1567.98 1800.00 1793.20 1664.20 1900.00 1887,95 1755.95 2000.00. 1981.72 1852.72 2100.00 2073.03 1944.03 2200.00 2162.55 2033.65 2300.00 2250.54 2121.84 2400.00 2335.16 2207.16 2500.00 2418.52 2289.82 25'00.00 2500.11 2371.11 2700.33 2578.53 2449.63 2500.00 2654.34 2525.34 2900.00 2727-89 259~.89 3000.00 2799.08 2570.08 3100.00 2869.54 2740.54 3200.00 2940.~6 2811.36 3300.00 3011,50 2882.50 3400.00 3082.97 2953.97 3500.90 3154.74 3025.74 3500.00 3226.79 3097.79 3700.00 3299.32 3170.32 3BOO.OD 3372.13 3243.13 3900.03 3443.73 3314.73 CDJRSE ]EVICTION AZIMUTH ]EG MIN DES 0 0 N 3 0 0 6 S 31 54 0 6 S 13 3 0 7 S 46 5 0 4 S 38 57 0 2 S 84 45 0 13 S 50 25 0 tl S 55 35 0 9 S 52 52 0 9 S 73 17 0 6 N 77 42 W 0 I N 87 27 W 0 8 S 40 55 W 0 10 S 36 53 E 1 $5 N 62 42 E 5 14 N 59 55 E 9 23 N 68 $ E 13 34 N 74 41 E 17 42 N ?5 45 E 19 4 N 71 1E 22 9 N 71 24 E 25 $2 N 68 4 E 26 $3 N 55 4 E 29 $4 N 68 12 E 33 2 N 70 34 E 34 49 N 70 I1 E 36 53 N 68 55 E 39 40 N 55 lB E 41 33 N ,55 45 ~ 43 ~3 N 59 $ E 45 2 N 68 55 E ,45 4 N 58 55 E 44 $9 N 58 31 E 44 28 N 57 45 E 44 15 N 67 23 E 44 0 N 67 29 E 43 $3 q 57 25 E 43 18 N 6? 2~ E 43 ~1 N 67 2? E 44 18 N 5? 33 E 6-FEB-85 EVEN 100 VERTICAL SECTION FEET 0.00 0.03 0.01 -0.17 -0.22 -0.23 -0.46 -0.80 -1.12 -1.37 -1.61 -1.70 -1.82 -1.92 -0.91 5.13 17.77 37.62 64.50 95.35 131.02 171.72 216.05 263.12 315.21 371.46 429.66 491.54 556.75 624.46 594.68 755.54 835.24 906.52 975.45 1045.08 1115.42 1184.25 1252.79 1322.59 FEET OF PAGE 1 DATE OF SURVEY: 17-J~N-85 KELLY BUSHING ELEVATI2N: 129.00 FT ENGINEER: BEETLER ME~SURE 0 DEPTH DOGLEG RECTANGULAR COOR SEVERITY NORTH/SOUTH EAST DES/IO3 FEET FEE OlNATES H]RIZ. DEPARTURE /WEST DI~T. AZIMUTH T FE:T DES MIN O.OO 0.00 N 0.00 0.10 0.05 S 0.05 0.15 0.22 S 0.10 0.0~ 0.39 S 0.02 0.12 0.53 S 0.02 0.17 0.59 S 0.01 O.1D 0.69 S 0.23 0.22 0.94 S 0.49 0.03 1.12 S 0.76 ~.15 1.19 S 1.00 O.OB 1-23 S 1.25 W 0.0~ 1.19 S 1.36 W 0.1~ 1.25 S 1.46 W 0.21 1.50 S 1.47 W 3.55 1.23 S 0.49 W 3.45 1-85 ~ 4.75 E 4.51 7.30 N 15.23 E 4.17 13.38 N 35.17 E 3.39 19.83 q 61.52 E 1.27 29.27 N 92.03 E 40.52 N 124.87 E 54.34 N 163.17 E 71.98 N 203.86 E 90.70 N 247.08 E X08.~7 N 295.07 E 12?.~+2 N 349.05 E 147.$9 N 403.72 E 171.41 N 460.80 E 199.04 N 519.99 E 223.74 N 583.04 E 248.97 N 648.58 E 274.39 q 714.72' E 299.97 N 780.63 E 326.12 N 845.85 E 352.~0 q 910.52 E 379.4~9 N 974.83 E $06-01 N 1038.91 E $32-~4 N 1102.47 E 458.81 N 1165.75 E $85.$8 N 1230.25 E 3.97 3.25 1.67 4.25 3.30 3'52 3.01 3.97 3.99 2.21 3.72 3.28 0.55 0.48 0.20 0.22 0.55 0.40 1.70 0.4¢ 0.00 0.O8 0.24 0.39 0.53 0.59 0.73 1.06 1.35 1.55 q 0 0 E S 45 55 E S 26 33 E S 3 20 W S 2 39 ~ S I 2 S 18 S 27 33 534 S 40 13 W 1.75 S 45 32 W 1.80 S 48 48 ~ 1.92 S 49 14 W 2.10 S 44 30 ~ 1.33 S 21 47 ~ 5.13 ~ 68 49 E 17.79 ~ 65 46 E 37.~3 ~ 69 10 E 64.54 ~ 72 8 E 96.58 N 72 21 E 131.28 171.98 216.20 263.21 315.31 371.59 429.81 $91.65 556.78 524.50 594.72 765.58 836.28 906.55 976.48 1046.09 1115.43 1184.25 1252.79 1322.59 N 72 N 71 34 E N 70 33 E N 69 50 E N 59 52 E N 69 56 E N 63 55 f' N 69 35 ~ 69 3 ~ ~ 69 0 E ZH-5 KJPARJK NDRTH SLDPE,AL~S~ COMPUTATION DATE: 6-FEB-B5 INTERPOL~TE3 VALUES FOR EVEq 100 FEET OF TRUE SD'B-SEA SURED VERTICAL VERTIS~L EPTM OEPTq DEPTH CDJRSE VERTICAL DOGLEG 3EVI~TIgN AZIMUTH SECTION SEVERITY 3EG MIN DES MI4 FEET OEG/IO0 40 41 42 43 44 45 45 41 49 O0.OD 3515.%B 33BS.4B DO.DO 3587.7B 3458.78 00.00 3660.50 3531.60 00.00 3733.57 3604.67 00.00 3804.55 3575.65 DO.O0 3874.93 3745.93 00.00 39~5.~B 3B15.98 00.03 %017.82 3888.82 DO.OD 4090.38 3961.3~ O0.OO 4163.37 4034.37 43 57 N 67 32 E 1392.23 0.35 43 27 N 57 3% E 1451.31 0.4~ 43 7 N 67 32 E 1529.84 0.37 43 32 N 67 39 E 1598.10 2.32 45 ZB N 68 14 E 1668.53 0.77 45 4 N 68 1~ E 1739.67 0.70 44 23 N 6~ 5 E 1810.03 0.65 43 %5 N 67 55 E 1873.59 0.72 43 17 N 57 45 E 1948.40 0.28 42 55 N 67 32 E 2015.74 0.52 50 5! 52 53 55 55 57 58 59 90.03 %236.12 %107.12 O0.OO 4305.10 %175.10 DO.OD 4373.19 %24¢.19 DO.OD ~441.76 4312.76 00.0D ~510.75 %381.75 O0.O0 ~580.29 4451.2~9 00.00 4650.86 %521.86 00.09 4721.85 ~592.85 00.00 4791.77 6662.77 00.00 4861,65 ~732.65 44 %0 N 67 48 E 2085.34 4.23 47 g N 68 26 E 2157.73 0.32 46 54 N 68 23 E 2230.96 0.48 46 33 N 68 14 E 2303.75 3.27 46 12 N 68 10 E 2375.13 0.20 45 28 N 68 8 E ~447,99 0.79 44 39 N 68 11 E 2518.85 1.20 45 28 N 58 44 ~ 2589.27 1.63 45 29 N 68 1~ f 2660.76 0.12 46 13 N 69 ~ E 2732.29 1.50 6O 61 62 63 64 65 65 67 68 69 DO.O0 ½930.54 ~801.54 90.03 4999.76 4870.76 00.00 5069.18 %940.18 00.00 5137.13 5008.13 DO.OD 5203.72 5074.72 00.09 5270-%2 5141.42 DO.OD 5337.58 5208.58 00.00 5~05.~4 5276,44 00.03 5474.07 5345.07 00.00 5543.53 5414.63 46 23 N 69 5 E 2804.77 0.47 46 5 N 58 51 E 2875.93 0.19 46 10 N 68 59 E 2948.91 1.48 48 5 N 70 15 E 3022'24 0.98 48 1::3 N 70 17 E 3096.80 0.17 48 1 N 70 % E 3171.27 0.33 47 33 N 59 49 E 3245.34 0.47 46 58 N 53 30 E 3318.77 0.15 46 12 N 59 ? E 3391.49 O.9B 45 27 N 59 24 E 3463.33 1.90 7000 7100 7200 7300 7400 7530 7500 7700 7330 7900 .00 5614.38 5485.38 44 30 .00 5686.33 5557.33 43 30 .OD 5759-33 5530.33 ~2 ~7 .00 5832.58 5703.68 43 26 · OD' 5905.14 5775.14 43 3 .3~ 5978.54 5849.5~ 42 31 .00 5053.06 5924.06,, ~1 tO · 00 51ZB.)O 5999.90 60 5 · 00 6205,90 6076,90 39 14 .00 5283.98 515%.98 38 6 N 69 3% E 3533.98 1.39 N 69 5 E 3603.42 1.07 N 58 17 E 3671.76 1.07 N 66 59 E 3739.73 2.30 N 65 ~2 E 3808.58 0.86 N 66 53 E 3875.44 1.48 N 67 28 E 3943.11 1.07 N 67 3~ E ~008.26 1.1T N 67 lZ E %072.06 0.99 N 57 4 E %134.52 1.21 P~GE D&TE DF SURVEY: 17-J%N-86 KELLY BUSHIN$ ELE¢~TIDN: 129.00 ~'FT ENGINEER: ~EJTLER MEASURE RESTAN NDRTH! FEE 512. 538 · 564. 590. 517. 543. 569. 595. 721. 747. 773. BO0. 827 · 854. 881 · 908. )34 · ~60. ~ 8 $ · 1012. 1038. 1064. 1090. 1115. 1140. 1165. 1191. 1217. 1242. 1268. 1292. 1317. 1342. 1867. 1395. 1%23. 1649' 1%73. 1%98. 1522. D DEPTH 3ULAR CDORDIY~TES HDRIZ. DEP&RTURE SOUTH E~ST/WEST DIST. ~ZIMUTH T FEET FE:T 37 N 1294.64 E 1392.23 N 68 25 : -- %7 kl 1358.49 E 1461.31 q 68 22 = 59 N 1421.85 E 1529.85 4 68 20 E 7Z ',l 1484.91 E 1598.10 ~ 68 18 E 32 N 1550.25 E 15.58.53 N 58 17 E 39 N 1616.33 E 1739.67 q 68 17 E 55 N 1681.65 E 1810.04 N 68 17,,' 58 N 1746.15 E 1~79.50 q 68 16 54 N 1809.89 E 1948.40 .q 68 15 E 50 N 1873.10 E 2016.75 ~ 68 14 E 71 N 1935.51 E 2085.36 q 68 13 E 54 N 2003.74 E 2157..74 N 68 13 49 N 2071.83 E 2230.97 39 N 2139.46 E 2303.75 ~ $B 13 E 26 ~ 2205.68 E 2376.15 ~ 58 13 E ~5 N 2273.36 E 2~48.01 q 68 13 E 38 N 2339.15 E 2518.86 q 68 13 E 23 N 2404.65 E 2589.28 ~ 68 13 E 52 N 2471.13 E 2660.7? q 58 14 'E 58 N 2537.70 E 2?32.30 q 68 14 E ~9 q 2605.~ E 2804.?7 N 6~ 16 E 39 N 2672.80 E 2876.94 N 68 17 E ' 39 N 2739.92 E 2948.92 N 68 17 E 79 N 2808.73 E 3322.24 N 58 20 E go N 2878.98 E 3096.81 ,~ 68 22 E 14 N 2949.08 E 3171.27 4 68 25 E 51 N 3018.70 E 3245.34 N 58 05 N 3087.56 E 3318.77 ~ 68 29 L 54 N 3155.64 E 3391.49 q $B 30 E 34 N 3222.73 E 3%63.33 ~J 68 31 E 87 N 3289.0 38 N 3353.9 13 ~ 3417.6 88 N 3480.6 69 N 3543.6 25 N 3605.7 O1 N 3667.2 82 N 3727.4 35 N 3786.3 62 N 3843.9 3533,99 4 68 32 E 3503.43 N 68 33 E 3671.77 q 68 33 E 3739.74 N 68 32 E 3808.58 4 58 30 E 3876.%4 ~1 68 27 E 3943.1I '~ $8 26 E 4008.26 ~ 68 25 E 4072.~6 ~ 6~ 24 E ~134.52 N 68 23 E ARCD aLASKA, I~C. ~H-5 KJP~RJK N3RTH SLDPE,~L~SK~ COMPUTATI3N D~TE: 6-FEB-B6 PAGE .3 DATE OF SJRVEY: l?-J~N-85 KELLY BUSHING ELE¢~TI3N: 129.00 ENGINEER: BEJTLER FT ~E~SURED ]EPTH INTERPOLATED VALJES FOR TRUE SJB-SE& VERTICAL V:RTI:AL DEPTq DEPTH 83D0.00 5362.71 6233.71 81DO.DO 5441.~5 6312.45 8110.00 $44~.3Z 5320.32 EVEN 100 CD~RSE VERTICAL )EVI{TI3N AZIMUTt SECTION ]EG lin DES MIN ~EET 38 3 N 67 I E 38 3 N ,67 I E 38 3 N 67 I E 4196.15 425?.79 6263°95 FEET OF MEASURE) DEPTH DOGLEG SEVERITY DEG/1DO RECT&NGUL~R COORDINATES NDRTH/SOUTq EAST/WEST ~EET FEET H3RIZ. DIST. FEET O.OD D.OD 1546.68 N 3900.7D 1570.74 N 3957.47 1573.15 N 3953.1~ E 4195.15 E 4257.79 E 4263.95 DEP~,RTURE AZI~tUTH r3ES MIN N $) 22 E N 6B 21-E N 6B 20 E ARCO &L~SKA, IqC. 2H-5 K~P~RJK N3RTH SLgPE,AL~SK~ CO~PUTATIDN INT:RPOL~TED VALUES FOR TRUE Sj'B-SEA ~E~SURE3 VERTICAL VERTICAL 3EPTH DEPTfl DEPTH 0.00 O.O0 -129.00 1000o00 1000.00 B71o00 2gDO.D2 1981o72 1852.72 3000.00 2799.08 2570,08 4300.00 3515.~8 3385.48 5000.00 4235.12 4107.12 6OO0.OO 4930.54 4801.54 7000.09 5614.38 5485.38 8000.33 5352.?1 5233.71 8110.09 5449.32 5323.32 CDJRSE DEVI&TION ~ZIMUTH DEG ~IN DEG MIN 0 0 N 0 22 g N 7! 24 45 2 N 68 55 43 ~7 N 57 32 46 23 N $9 S 44 30 N 69 34 38 3 N 57 1 38 3 N 57 DARE: 6-FEB-85 EVEq lOOO FEET OF ME~SUR VERTICAL DOS' EG RECTAN SECTION SEVERITY NORTH/ FEET DEGIIO0 FEE 0.00 0.00 O. -1.61 O.OB 1. 131.02 3.9? 40. 694.68 D.72 248. 1392.23 3.35 512. ~085.34 4,23 773. 2804.77 3.47 1~38. 3533.98 1.39 1292. 4196.15 O.OD 1546. ~253.95 O.O0 1~73. P~GE '4 DATE OF SURVEY: 17-J~N-85 KELLY BUSHING ELEVATZON: 129.00 ENGINEER: 3EUTLER FT Eg DEPT GULAR COORDINATES H3RIZ. OEO~RTURE SOUTH E~ST/NEST DIST. AZIMUTH T FEET FEET DES MIN O0 ~ 0.00 E 0.00 N 3 0 E 23 S 1.25 W 1.75 S 45 32 52 .N 124.87 E 131.28 N 72 1 E 97 N 6~.58 E 594.72 N 58 59 E 07 N 1294.54 E 1392.23 ~ 6~ 25 E 71 N 1936.51 E 2085.35 49 N 2605.~4 E 2804,77 87 N 3289.01 E 3533.99 N 6B 32 58 N 3900.72 E 4196.16 15 N 3953.14 E 4263.95 ~ 68 20 E A~CO ALASKA, INC. 2H-5 NERTM SLO'PE,~L~SKA COMPUT&TI3N D~TE: INTERPOLATED V~LUES :OR TRUE SJB-EE~ MEASURED VERTIS~L VERTI'~L ]EPTH DEPTq DEPTH 0.00 0.00 -129.00 28.90 28.98 -100.02 128.95 128.95 -0.05 228.95 228.95 99.95 328.95 328.95 199.95 428.95 428.95 299.95 528.95 528.95 399.95 520,95 628.95 499.95 720.95 728.95 599.95 328.95 825.95 699.95 928.95 928.95 799.95 1028.95 1028.95 899.95 1128.95 1128.95 999.95 1228.95 1228.95 1099.95 1328.95 1328.95 1199.9i 1428.99 1~28.96 1299.9 1529.32 1529.00 1400.00 1530.47 1629.00 1500.00 1733.0&. 1729.00 1500.00 1037,70 1829.00 1700,00 1943.18 1929.00 1800.00 2051.~0 2029.D0 1900.00 2152.43 2129.00 2000.00 227~.91 2229.00 2100.00 2391.45 2329.00 2200.00 2512.40 2429.00 2300.00 2536.35 2529.D0 2403.00 2756.25 2629.00 2500.02 2901.55 2729.00 2600.00 3~42.63 2829.00 2700.00 3103.97 2929.D0 280~.00 3324.52 3029.00 2900.00 3~54.19 3129.00 3000.00 3503.05 3229.00 310~.00 3740.73 3329.00 3200.00 38?9.39 3429.00 3303.00 ~018.77 3529.00 3400.00 4156.65 3629.00 3500.00 4293.59 3729.00 3600.00 ~34.73 3829.00 3700.00 CDJRSE 3EVI&TIEN AZIMUTH ]EG MIN DEG 0 0 0 2 0 5 0 7 0 6 0 3 0 6 0 11 0 11 0 8 N 0 0 N 45 11 S 32 25 S 28 2~ S 24 55 S 33 3~ S 77 28 S 50 ~9 S 53 44 S 78 54 0 0 0 0 0 2 6 10 18 9 5 2 9 11 23 38 ~9 32 S 76 2~ W N 57 22 W S 74 53 ~ S 20 35 W S 54 55 E N 59 63 E N 62 2~ E N 70 43 E N 75 55 E N 73 25 E 1'9 59 N 70 55 E 24 7 N 70 14 E 26 24 N 66 15 E 28 53 N 65 59 E 32 ~6 N TO 37 E 3~ 55 N 70 9 E 37 51 N $7 49 E 41 4 N 55 10 ~: 43 55 N 69 ~ E 45 7 N 58 58 E 44 53 44 26 44 5 43 42 43 13 44 22 43 51 43 14 43 25 45 Z5 N 58 37 E N 67 38 E N 67 27 E N 67 28 E N 57 21 E N 67 33'E N 57 32 E N 67 35 E N 67 37 E N 58 14 E 6-FEB-B5 EVEN 100 FEET VERTICAL DOGL SEC~IDN SErE FEET DES/ 3.00 3 0.01 0 0.04 0 -0.03 O -0.22 0 -D.21 O -0.27 0 -0.56 3 -0.89 D -1.20 D -1.45 9 -1.65 D -1.71 3 -1.87 0 -1.89 D 0.24 3 8.07 ~ 23.12 4 45.68 ~ 75.25 2 1'10.69 3 151.15 ~ 199.34 O 250.78 3 310.56 3 378.52 1 451.73 3 534.49 3 525.54 2 724.76 0 52~.93 3 923.59 0 1021.19 0 1117.53 0 1212.14 0 1308.17 O 1405.25 3 1500.19 D 1593.70 2 1593.29 0 P~GE 5 D~TE 2F SJR~ET: 17-J~N-85 <ELLY BUSHING ELEVATION: 129.00 FT ENGINEER: BEJTLER OF SUB-SE~ DEPTH EG RECTANGULAR RITY NORTH/SOUTH 100 FEET · 03 O.O0 N .09 O.O1 S .09 0.10 S · 10 0.27 S · 37 0.~4 S .09 0.55 S .15 0.60 S · 23 0.?5 S · 09 0.99 S .23 1.15 S .13 1.21 S · 15 1.21 S .05 1.19 S · 20 1.32 S · 73 1.56 S · 3~ 0.57 S .3B 3.29 ht · 39 9.16 N .51 15.44 N .59 22.95 N · 60 34.01 · 23 47.01 · 51 65.19 · 91 86.01 .25 105.93 .05 129.81 .45 155.51 · 16 189.92 · 15 224.13 · 15 259.77 .59 295.85 .35 332.54 · 30 369.95 .56 406.82 .46 443.15 .35 · 53 517.34 · 23 553.2~ · 01 589.04 · 31 526.21 CDOR EAST FEE DINATES HERIZ. DEm&RTURE /WEST DIST. ~ZIIUTH T FEET DEG MIN O. O. O. D. O. O. O. O. O. O. O0 E O.O0 N D 0 E 02 E 0.02 S 51 2 E 08 E 0.13 S 39 39 E OB E 0.28 S 15 55 E 06 W 0.44 S 8 20 W 01 W 0.56 S 0 39 ,I 05 W 0.60 S 4 44 j 31 W 0.81 S 22 17 ~. 57 W 1.14 S 29 46 W 83 W 1.42 S 35 46 W , 1. 1. 1. 1. O. ?, 21. 43. 72. 08 W 1.52 S 41 48 W 30 W 1.78 S 45 52 W 37 W 1.82 ~ 49 4 W 49 W 1.99 S 48 35 W 41W 2.10 S 42 13 W 52 E 0'85 S 37 44 E 37 E 8.07 N 65 56 E 24 E 23.13 N 55 40 E 02 E 45.71 N 70 15 E 92 E '76.~5 N 72 31 E 105. 143. 188. 235. 291. 355. 424. 499. 584. 675. 58 E 110.93 N 72 8 E 95 E 151.43 q 71 54 E 58 E 199.53 'N TO 55 E 57 E 250.87 N 6~ 55 E 67 E 310.56 N 69 52 E 71 E 378,56 ,~ 59 57 = 23 E 451,87 ~i $9 51 ~ 65 E 53~.5~ N 6~ 11 ~, O~ E 525.57 ~ 5~ 0 E 55 E 72~.80 N 68 5~ E 770. 861. 951. 1040. 1128. 1215. 1306, 1394. 1480. 1573. 10 E 824.97 q 68 59 E 75 E 923.72 N 68 53 E 84 E 1021.20 N 68 45 E 86 E 1117-54 N 613 39 E 2Z E 1~12.14 N 68 33 E 94 E 1300.17 N 68 28 E 67 E 1405.25 N 58 24 E 43 E 1500.19 q 68 Zl E 85 E 1593.70 ,ti 68 18 E 25 E 1693.30 N 68 17 E COMPUTATIDq DATE: S-FEB-85 &RCD aLASKA, INC. 2q-5 K 'JP~RU( N3RTH SLDPE,AL~SK~ INTERPOLATED V~LJES FOR EVEN 100 FEET OF TRUE SJB-SE~ ME~SURE3 VERTICAL VERTI'~L ]EPTH DEPTq DE~rH COURSE ~ERTICAL DOGLEG DEVI&TIDN AZIMUT~ SECTION SEVERIT~ DEG ~IN DEG MIN FEET DEG/IO0 ~576.21 3929.D0 3800.00 4715.~5 ~029.00 3900.00 ~53.01 ~129.00 ¢000.00 4989.97 ~229.00 ~100.00 5135.17 ~329.00 ~200.00 5~81.~3 ~29.00 ~30D.O0 5~26.37 ¢529.00 ~00.00 5569.18 ¢$29.00 ~500.00 5710.23 ~72g.00 ~600.00 5~53.07 ~829.~0 ~70D.O0 44 32 N 58 ? E 1793.37 0.55 ~3 38 N 57 5~ E 1590.27 0.42 ~3 7 N 57 39 E 198~.70 0.43 44 14 N 57 ~2 E 2078.28 4.01 47 7 N 58 2~ E !183.52 0.28 ~6 36 N 58 15 E 2290.26 46 9 N 68 ? E 2395.16 3.25 44 ~8 N 58 11 E 14~7.12 0.97 45 36 N 68 42 E 2596.58 1.3~ 45 34 N 68 31 E 2698.59 1.15 5~97.75 ~929.00 ~803,00 61~2.15 5029.00 ~900.00 6287.81 5129.00 5000.00 6~37,9~ 5229.00 5100.00 6587.28 5329.00 5200.~0 6734..51 5429.00 530~. 0 6~79.08 5529.00 ~OO.O0 7020.48 5629.00 5500.00 7t58-58 5729.00 5500.00 7Z~4.95 5829,00 5700.00 46 23 N 59 T E 2803.14 0.42 46 3 N 58 48 E 2907.30 0.21 47 58 N 70 1~ E 3013.17 1.37 48 13 N 70 1.3 E 3125.08 O.l~ 47 36 N 6~ 52 E 3235,95 0.52 46 ~9 N 69 29 E 3343.99 0.~7 45 ~2 N 6~ 13 E 3448,37 1.58 44 14 N 69 25 E 3548.32 1.33 43 2 N 58 42 E 3543.55 43 21 N 57 5 E 3735.27 2.25 7432.59 5929.00 5803.00 7557.95 5029.00 5900.00 7T00.12 $129,00 5000.00 7829.75' $229.00 5100.00 7957.19 5329.00 5200.00 808~.19 5429.00 5300.00 8110.00 5449.32 5320,32 ~2 50 N 55 ~3 E 3830.75 0.69 41 32 N 57 20 E 3921.95 1,33 ~0 5 N $7 34 E ~008.34 1.17 38 ~1 N 57 5 E ~090.83 1.60 38 3 N 67 1 E ~169.77 O.OO 38 3 N 57 1 E ~248.04 0.00 38 3 N 67 I E ~263.95 ~.OO P~GE .6 D&TE DF SURVEY: 17-J&N-85 · KELLY BUSHING ELEVATION: ENGINEER: BEUTLER FT SUB-SE& RmCT&N N3RTH! FEE 563 · 599 · 735 · 771. 810. 849. 888 · 925. }62. 1000. 1D37. 1075. 1112. 1150. 1188. 1225 · 1263. 1297. 1331, 1366 · 1¢04- 1440. 1~73. 1505. 1536. 1566. 1573. DEPTH 3UL~R C9]RDIN&TES SOUTH EAST/~EST T FEET H3RIZ. DEPARTURE DIST. ~ZIMUTH FEZT DE3 MIN 33 N 1655.19 50 N 1756.05 29 N 1943.48 05 N 1929.97 O3 N 2027.72 40 N 2125.94 35 N 2224.3~ 30 N 2318.97 86 N 2411.47 52 N 2505.27 E 1793.38 N 68 17 E E 1890.28 ~ 68 16 E E 1984.T0 N 68 15 E E 2078.29 N 6~ 13 E E 2183.53 N '68 13 E E 2290.27 N 68 13 E E 2395.18 q 69 13~~ E 2~97.13 ~ 68 13.~ E 2596.60 ~1 58 14 E E 259~,50 N 68 14 ~ 91 ~ 2603.92 E 36 N 2701.11E ?3 N 2800.19 E 65 N 2905.51 E 28 N 3009.88 E ~0 N 3111.18 E 04 N 3208.75 E ~8 N 3302.45 E BO N 3391.4¢ E 54 N 3477.40 E 2803.15 N 68 16 E 2907.30 ~ 58 17 E 3013.17 N 68 19 E 3125.08 q 58 23 E 3235.95 N 68 27 E 3343.99 ~ 53 29 E 3%48.38 N 58 30 E 354~.33 q 6~ 32 E 3543,56 N 6~ 33 E 3736.28 N 68 32 E 85 N 3563.85 E 3B30.75 88 fl 36~7.68 E 3921.95 85 N 3727.55 E 4038.34 54 N 3803.67 E 4090.83 38 N 3875.40 E ~169.77 94 N 39~8.49 E 4248.04 15 q 3963.14 E 4263.95 N 58 29 E N 68 26 E ~ 6~ 25 E N 68 24 E q 68 22 E ,~ 6~ 21 E ~RCO ~LASKA, INC. MARKER 'l'gP (UPIIRJK ~ASE KUPARUK C TOP KUP~RUK BASE KUPARJK PBTD TD CDMPUTATIDt INT.-'RPOL~TED VALJES FOR MEASURED DEPTH BELOW KB 753¢.00 7557.00 7534.00 7820.00 7988.00 8110.00 D&~E: 6-F_--~-~$ CHOSEN HORIZONS FROM KB 5003.67 6028.28 5078.72 5221.41 6353.26 5449.32 ORIGIN: TVD SdB-SEA 5)7~.57 5899.28 5949.7Z 6292.~1 5Z2~.Z6 5320.32 DATE DF SURVEY: 17-J~fl-85 · KELLY BUSHING ELEVATION: 129.00 FT ENGINEER: BEJTLER FNL,196' FW S3'RFACE _2C~TION %T L,SEC 36,T11N,RSE,UM RECT~NGUL&R COORDINATES NORTH/SDUTq E&ST/WEST 1432.1¢ N 3626.82 1460.6q. N 1457.53 N 35B?.83 1503.25 N 3798.01 1543.79 N 3893.8~ 1573.15 N 3953.1~ E E E E A2C0 ~L~SKA, IqC. NSRTH SLOPE, ALASKA COMPUTATIgN DATE: 6-FEB-85 P~GE 8 D~TE DF SURVEY: 17-J~N-85 KELLY BUSHING ELEVATION: 12).00 ENGINEER: BEUTLER MARKER TOP KUPARUK 5~SE KUmARUK TOP KUP~RUK SASE KUPARUK PBTD TD 3RIGId: 159' MEAS2'RED DEPTH TVD BELOW KB FROM KB SJB-SEA 7534.00 5003.67 5374.57 T557.00 5028.28 5~99.2B 753~.00 5078.72 5949.72 7820.00 $221.~1 5092.~1 7988.00 $353.26 51Z~.26 8110.00 6449.32 5320.32 FNL~lg6' FW REC ND SJRF~ L,SEC T~NGU RTH/S ~32.1 ~qO.6 457.5 533.2 5&3.7 573.1 CE LgC~FION ~T 36,TllN,RSE,UM L~R COORDINATES ]UTi EAST/WEST 3526.32 35 ~+7.09 3687.83 3798.01 3993.89 3953.1~ E E E E FINAL WELL LDS&TISN ~T TD: TRJE SgB-SEA MEASURE2 VERTICAL VERTICAL DEPTH DE~TH DEPTH 8110.00 54~9.32 5320.32 HORIEONT~L DEPARTURE DISTANC= AZIMUTH FEET ]EG MI~ 4253.95 ~ 68 ZO FT SCHLUMBERGER 0 [ RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. WELL 2H-S FIELO KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE 00007123Z WELL 2H-5 (169' FNL, 196' FWL, S36, TllN, RSE) I~ T ~r _0R~_ZON FAL PROJECTION REF 01313071292 NO,~TH 50[30 __ SCqLE = 1/113130 [N/FT 4000 3000 2000 lO00 7'? SOUTH -3000 -2000 - 1000 0 1000 WEST ~000 3000 4000 SO00 6000 ERST 0 [-~ 0 cD c) iii ' VERT£CAL SCALE = 1/2000 [N/FT ~ I £0000 -~3~ Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · Date ARCO Alaska, Inc. Post Office E~ 100360 Anchorage, Al'~ka 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 ~Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. Is a Subsidiary of AllanticRichfieldCompany RECEIVED F E B 1 1986 Alaska 0il & bus Cons. Ooliimission Anchorage STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~,t41SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-168 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20043 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well 169' FNL, 196' FWL, Sec.36, T11N, R8E, UN (approx.) at surface 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 129' RKB ADL 25587 ALK 2673 10. Well No. 2H-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of January , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1345 hrs, 12/30/85. Drld 12-1/4" hole to 2958'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8110'TD (1/4/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7988'. Secured well & RR @ 0100 hrs, 1/7/86. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 100'. Cmtd w/195 sx AS I!. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 2942'. Cmtd w/800 sx CS III & 350 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/shoe @ 8085'. Cmtd w/460 sx Class G. 14. Coringresumeand briefdescription None 15. Logs run and depth where run DIL/GR/SP/SFL f/8086' - 2942'; GR to surface FDC/CNL f/8086' - 3500' Cal f/8086' - 2942' 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED Alaska 0il & Gas Cons. C0minJssi0r~ Anch0r~.ge 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 4 An~ru , ./-/~,,lu~ . A~so¢iate Engineer 1-2/_~ SIGNED ~ L,&IlUI~/ )~j,,c~.~.,,~...x TITLE ____ ~ DATE NOTE--Report o~this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation~ Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 TEMP3/MR34 Submit in duplicate ARCO Alaska, Inc. Post Office"~0x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 m~/~n~' P.O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items return one signed copy of this transmittal. DATE 02-03-86 TRANSMITTAL ~ 5555 Please acknowledge receipt and Open Hole LIS Tapes plus Listing/ Schl/ One copy of each 2H-5 01-05-86 Run #1 0100.0-8078.0 REF#71146 3F-16 01-07-86 Run #1 1800.0-8432.0 REF#71145 3I-2 01-18-86 Run #1 1800.0-8553.0 REF#71191 Receipt Acknowledged: State of AK*original computations Date: A!~_,.-.!,.,.:_~ ~i! & t~as Cons. Commissio~ -~' :'~ :' ":=9 ARCO Alaska. Inc. ,s · Sul~sidimfy of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B0'x-~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 2H Pad Wells 5-8 Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, vj. Gruber Associate Engineer JG/tw GRU11/L23 Enclosure If RECEIVED AUG o 1985 Alaska Oil & Gas Cons, Cornmissio:~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~00 ~0 01;~ 014. 0~5 016 OI O~ Os 04 DRILL Sl~,~ AS- BUILT 2.H CONDUCTORS LOCATI~S WELL 5 Y= 5,9~8,§93.29 LiT= 70°16; !5.795;'' ×: ~98,59~.98 LONG = l~oOno. ~ &a.~.;:~n?,, 169' FNL, 196' FWL, 93.0'05, 78.8' ~' WELL 6 Y 5 948 693 32 LAT 7n°16'15 -q~5" x= &98,53~.96 LONG= 150°00'~2.6~5'' 169' FNL, 136~ .F~L, 93.000, 98.8 PlO WELL 7 Y= 5,948,693.27 LAf= 70°16'15.7950" X= 498,~74.97 LONG= 150°00'~4.~0i'' 169' FNL, 76' FWL, 92.3 OG, 98.8 P,AC. NELL 8 Y= 5,9~8,693.24 LAT= 70°16'15.79~6'' X= ~98,~t~.98 LONG= 150°O0'~fi.l&8' 169' FNL, LOCATED IN SECTION 36 TII N~ RSE~ UMIAT MERIDIAN. j26 v . ;' SCA RECEIV _AUG Z, 0 ]! Alaska OJl & Gas Cor, s Anchorage ED Comi-nission { " / I flilco.oucTo,'A -.u, , ~,u~ ~ ~ Dra~ntsman: MC ~.no.:NSK 85-15 July 29, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2H-5 ARCO Alaska, Inc. Permit No. 85-168 Sur. Loc. 169'FNL, !96'FWL, Sec. 36, t!lN, R8E, IIM. Btmhole Loc. 1411'FSL, 1089'FEL, Sec. 25, TllN, RSE, UM. Dear I-~. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is.conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewz=~ Kuparuk River Unit 2H-5 -2- .--Ju!y 29, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. 1fhere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enc].osure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Br.~._,t00360 Anchorage, Alaska 99510-0360 'l'elephone 907 276 1215 July 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2H-5 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2H-5, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot Diagram and description of the surface hole diverter system o Diagram and description of the BOP equipment We estimate spudding this well on August 17, 1985. any questions, please call me at 263-4970. Sincerely, JBK/TEM/tw PD/L123 Enclosures If you have RECEIVED JUL 1 7 1 85 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OrE AND GAS CONSERVATION coiwC/ilSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I-~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH I~C~ SINGLE ZONE [] MULTIPLE ZONE ~r~ 9. Unit or lease name Kuparuk River Unit 10 Well number 2H-5 2. Name of operator ARCO Alaska, Irc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 169' FNL, 196' FWL, Sec.36, TllN, RaE, UN (Approx.) At top of proposed producing interval 1281' FSL, 1417' FEL, Sec.25, TllN, RaE, UM At total depth 1411' FSL, 1089' FEL, Sec.25, TllN, RaE, UM 5. Elevation in fe~t (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 129', PAD 98' I ADL 25587 ALK 2673 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088126-27 13. Distance and direction from nearest town 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 8068' MD, 7578' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1391 feet. 14. Distance to nearest property or lease line miles 1089' ¢TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 46 o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 2H-4 well 280' ~ surface feet 18. Approximate spud date 08/17/85 2951 . psig@ RI")°F Surface 3378 psig@ RgB_c; ft. TD (TVD) SIZE I :, Hole ;24" 12-1/4" !8-1/2" / i 6-1/8" J Casing 16" 9-5/8" Weight 62.5# 36. O# 7" 26.0# 5" 15. O# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 I Weld J-55 J BTC HF-ERW J -55/HF- EI~W BTC 7450' K-55 J FL4S 790' MD TOP 80' 29' I 2903' 29' I 28' I. 28' 7278'1 5838' SETTING DEPTH TVD MD BOTTOM TVD 29' 109~ 109' 29' 2932'I 2770' I 7478~ 5976' 8068 ¢, 6323 , I QUANTITY OF CEMENT (include stage data) · 200 cf- 700 sx AS III & 340 sx Class G 165 sx Class G blend 100 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well'-to approximately 8068' MD (6323' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 2932' MD(2770' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Due to gas injection at 2A Pad, Kuparuk "C" Sand pressures :are presently near 3500 psi (@ 6200'SS TVD) and still increasing. To drill the well safely, 7" casing will be set at 7478'MD (5976'TVD) (approximately 100' above the "C" Sand). The 13-5/8", 5000 psi, RSRRA BOPE stack equipped with 3-1/2" rams will be reinstalled and the rams tested to 4000 psi, the annular to 3000 psi. A 6-1/8" hole will be drilled to TD. A 5" liner will be set at TD with a 200' overlap. Expected maximum surface pressure is 2951 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, (see attached sheet) 23. I hereby ce~t the foregoing is true and correct to the best of my knowledge SIGNED / /~~'/¢ TITLE Area Dril ling Engineer The space ~0r *~?~//~n b-Se-/.,/' '-- CONDITIONS OF APPROVAL Samples required I--lYES ~NO Permit number APPROVED BY Form 10-401 I~w 7-1 .RI~ (~D/15D122 DATE Mud log required I Directional Survey required J APl number []YES [~-NO j ~,YES []NO 50-- /O.~ ~ ~- o e ~'~ Approval date ......,07/29~85, '"'""/ / / SEE COVER LETTER FOR OTHER REQUIREMENTS ,OOMMISSIONER DATE .Tu]y 29, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2H-5 (cont'd) including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 2H-5 will be 280' away from 2H-~ at the surface. There are no othe~o~e.w~llbo~r~inos anywhere downhole. Top of cement for the production string will be placed ma~e 1000 MD a~o 5" ve the top of the Kuparuk Sands. The liner will be cemented from TD through the liner lap. After WOC, the liner will be cleaned out and the lap tested to 3000 psi. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the workover rig has moved off location, this well may be fracture stimulated. RECEIVED' J u L 1 7 985 .~,laska Oil & Gas Cons. Commission Anchorage F.~ITIU, t ~ltII~STOCI~ INC.. 'KUIP~ r;'"'"HO' 5 PROPOSED '-~ ,_~.c_U.,' NORTH SLOPE, ALASKA . _ KOP TVD"1:391 THD=1391 DEP=O : ;---a--~ 'PERI'I~ST TVD,'1465 TI'ID=1468 DEP=1 TOP LK~U SI4D$ TVD'IS?O TIdD-1570 DEP'8 l~ BUILD. 3 OEO m :TOP 1~-12' TYD-25~ TI'ID-2~82 OEP-407' 4s EOC (9 $/Ii' CS6 PT) TVD=2?70 TFID=2932 OEP=S89 K-$ TVD,.4$10 TI4D=~ DEP-;404 0 AVERAGE ANGLE 46 DEC t3 MIN I 1 000 20O0 30CC VERT I CAt. SECT I ON 7" CSO PT TVD-5916 TI'ID-Z479 BEP-3871 TOP UPPR SNDS TVD-$985 TI'ID-7578 DEP-3943 TOP-LOWR 914t:)8 TVD-e04~-TI'ID-Te65 DEP-4OO6- TARP~ET CNTR TVD-608S TI'ID,.7723 DEP-4048 BASE KUP SNDS TVD=6185 TI'ID-?868 DEP=415 TD (LOG PT) TVD-6323 TI'ID-8068 DE:P-4297 I I 4000 5000 RECEIVED J U L ! 7 19~5 A!aska Oii& Gas Cons. Commission ' ~" : '' PAD 2H. WELL jNO*: 5 PROPOSED ......... ~:.' ..... } .... ; , .... EA$¥HAN WH PSTO~K. INC.,, ! "~ '} '' ......... ~_~ ...... ~_~.~000. m ' ., ~ ~ , ~ ' 'm m , : m, . ',, ~'-{ "~ I ..... ~-.~--~ ..i ..'r.~ ......... ~ ........ ~ ...... ~ , . ; , { . z ' ' ' { ' i ' .... :-" . .,....,, ..~ ,~.. I:.: ,'~ :~: '~ ......... : ..... ~-j ...... ~boo,-4 ........ ~ .... ~ ........... ~-..-~.--~--~.'. ..... ~.; .... ~.:.-:.,.l ...... 1....-~.--',-~ t..~..-~.-,.-.'--IZ i-...{--I 1-~-..-~'.' { } { ~ ' ' {~ { it',~ I',{ ~!1{ . · ' :,,. · : : , '. · { , '" .... ,: '"~'l','l ..... , .-t-1 ,. . '. ' = ' ' } I , i , ' I , ~ ' ~,. EA9~ .... i'"; .... : .... "r"-i'°"; ....... .: , .............. ~ ~ ~oc~io~,'~ ...... , ·" II ;ill { / : ~ ; ' 25.,{lIN, RSE ........ '""'~'""~ ~ ~ ' /'. ~' ,. { ....... ~. ~su~c[ coc~[o,', ;" . .... , ~ . ~t .{ . . ; :. Ii ; SEC; 36. T IIM, IRBE ......... ~ . ~ ' ; ~ ' ' ~ ' { ' ~ I ', '{ , ~ ' : , i ' ' ", 1 ' ' ' ..i ....... ..... .I..'..~ ..... . .~ ..!...:.' ,. ............................ ' :...,.._~_' 1 000. ~ ...... ' · , ~ ._; ..L..,.. ' . . ~{ ":;,~,~,'~ ~ ,, ,{,i~ ~' ~ ,~ ~' t~ N 68iD · ,., ....... I .................... ~ . ' PAD KUPAI~UK I ~SI 4 344S KUPARUK RI VER UNIT 20" DIVERTER SCHEMATIC DE SCR I PT I ON I. 16' C~TOR. 2. TAM<O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOtNER QUICK-C~CT ASSY. 5. TAM<O UPPER QUICK-COM~CT ASSY. 6. 20" 2000 PSI DRILLING SPO0. W/I O' OUTLETS. 7. I0' NCR BALL VALVES W/lO' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF ANMJLAR PREVENTER. 8. 20" 2000 PSI A~MJLAR PREVENTER. MAI NTENANCE 8, OPERAT I ON 1 4 2 I. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AM~ULAR PREVENTER AI~) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ADaNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF VWELLB(]RE FLUID~ OR GAS IS DETECTED. IF NECESSARY, MAMJALLY OVERRIDE AI~ CLOSE APPROI~IATE VALVE TO ACHIEVE DOV~NWI~) DIVERSION. RECEIVED Do NOT SHUT IN VMELI.. J U L i 7 !gB§ UNOER ANY C I RCUMSTANCE$. A!aska Oil & Gas Cons. Commission Anchorage 7 6 DIAGRAM #1 13-5/8"'-":0;)0 PSI RSRRA BCP STACK I. 16' - 20cx) Psi TAb. CO STARTING ~F_AD 2. Ii' - 3000 F~I CASING HgAO 3. II · - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOCI._ 4. 13-5/8" - 5CX30 PsI PIPE ~ 5. 13--5/8" - 5000 PSI DRILLING ~ W/CHOKE ~ KILL LIFES 6. 1~-5/8' - 5000 PSI DOUBLE R/~ W/PIPE R/~ ON TOP, ?. 13--5/8' - ,5000 PSI A~ ACCUMULATOR CAPACITY TEST I. (]-ECK At~D FILL A(~TOR RF~OIR TO PRC~ LEVEL WI~ ~IC ~UID. 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ I~ ~I ~T~ ~ ~ ~T~. 3. ~~ TI~, T~ ~ ~ ~ITS SIXThlY ~L ~ITS ~ ~~ WI~ ~I~ ~ ~. 4. ~~ ~ ~ ~T, ~ A~T~E L~ LIMIT IS 45 ~~ ~I~ TI~ ~ 12~ ~I ~INI~ P~~. 5 4 2 RECE 13-5/8" BCP STACK TEST I. FILL BOP STACK AI~D ~ MANIF~ WITH ARCTIC DIESEL. 2. Q-E(]( THAT ALL LOCK DC~ S(~ IN ~ELL~F_AD ARE FULLY RETRACTED. SEAT TEST PLUG IN V~9_U-F_AD WITH RI~ING JT A~D RUN IN LC~ SCR~. 3. CLOSE AANJI_AR PREVENTER AI~ ~ KILL .AAD Q-ICI<E LIllE VALVES ADJACENT TO BOP STAQ~ ALL OTI-ER VALVES AN;> CHOKES SHOLI..D t~ OPEN. 4. PRESS~ UP TO 250 PSI ~ HOLD FDR I0 MIN. IN- CREASE PRES,~ TO 3000 PsI A~D HOLD FC~ I0 MIN. BLEED PRES~ TO 0 PsI. 5. OPEN A~ PREVENTER At~D MA~IJAL KILL A~D CHCI<E LI~ VALVES. CLOSE TOP PIPE RAMS A~D HQ~ VALVES ON KILL A~D CHCKE LIN~S. 8. TEST TO 250 PSI AI~ 3000 PsI AS IN STEP 4. '7. CONTINUE TESTING ALL VALVES, LIteS, A~ CHCKES WITH A 250 PSI LGN A~D 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRES._~ TERT ANY ~HOKE THAT IS ~T /~ FULl CLOSING POSITIVE SEAL (~. OI~LY FUNCTION TEST CH(~S THAT DO NOT FI. LLY CLOSE. OPEN TOP PIPE RAMS A~D CLOSE BOTTQ~ PIPE RA~. TEST BOTT(~ PIPE RAMS TO 250 PSI ~ 3000 PsI. OPEN BOTTG~ PIPE RAMS, BAQ< OUT RUt~qlNG JT CLOSE BLIt~D P~ A~D TEST TO 250 PSI A~D 3000 PSI. OPEN BLINO RAMS ANO RETRIEVE TEST PLUG. MAKE SURE MANIFCLD A~D LI~ES ARE FULL OF NCN-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAN3PIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, ~ INSIDE BOP TO 250 PSI AI~ 3000 PSI. __ _V~_EL<LY THEREAFTER FU~IONALLY CI~TE BOPE DAILY. iVED J U L 1 7 i985 Alaska Oil & Gas Cons. Commission Anchorage 0084001 REV. 2 MAY 15,1985 CHECK LIST FOR NEW WELL PERMITS Lease & Well No' fi--/(_G( 3~/~'-,5 Company ITEM ...... APPROVE DATE · · (2) Loc ~g%'~thru 8) I · · 3. 4. 5. 6. Cg/th,ru ~ 10. ~(10 and 1~) ~ 12. (4) Casg ~zT-~ (13 thru ~1)' (22 thrn/' 276) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. (6) Add: //Z/f// r~f~ 27. · YES NO REMARKS . Is the permit fee attached ........................................ Is well to be located in a defined pool ............................ . Is well located proper distance from property line ................ . Is well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool ........... Is well to be deviated and is wellbore plat included ............... Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. ,Is a~conservation order needed ...................................... Is.administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ ,ff~ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production'strings ... Will cement cover all known productive horizons ..................... ~--~' Will surface casing protect fresh water zones ................ Will all casing give adequate safety in collapse, tension and burst.. ~-~ Is this well to be kicked off from an existing wellbore .............. Is old wellbore abandonment procedure included on 10-403 ............ . Is adequate wellbore separation proposed ............................ Is a diverter system required ...................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating- Test to ~ Does the choke manifold comply ,w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. px / 0 HO Geology: EngSneering: ~ K LCS JAL /~. _ ' rev' 03/13/,85 6.011 INITIAL GEO. 'UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. -,- '---SC.HL'JM~ERGER .... LIS ,T~PE VERIFIC6TI2~ LISTiNS LVP 010.H02 VERZFiC~Ti3N LZSTINS PAGE ~ELL SITE O&T& Aqg TASLES ARE NOT INCLU'DED .IN THIS LiSTiN,S NAVEFJRMS ~ND D~ST 'HANNEL DATA ARE NgT ZNCL, JDED IN 'THIS LISTING ~ ~;~ ~;~ ....... ~ ~ ~ ~t ........... " ............... ,',~ ?,~ ~ ............. ~',~ ~ ~ ...... .,~ ~ .,..~ ~ ~;~~. ~:~ ¢ ~ ~ ;~ ~',~ ~2 ~ ,,..,. ~ .. .,~ .,..,~.,..,~ .¢ .,. ~... .,..,..,. LVP OiO.HO~ VER'IFIC~T!O,~ L!STiN,~ P~,.~E 2 ~F:',~ REEL HE&OER ~k~'~ SERVICE NAME :EDIT OAT5 :95/01/130 '3RZGIN : REEL NaME :14934I CONTZNJaTIDN $ :01 PREVIOUS REEL : COMMENTS :LZERARY T6DE '~'~ TAPE HE~DER ..... ,~,- SERVICE NAME :EDIT D~'TE :85/01/30 ORISIN :FS!a CONTZNU&TtON ~ :'01 PR~V'I~U'S T'~PE : COMMENTS :LIBRARY 'T~PE FiLE N~XE :EOIT .001 SERVICE NAME : VERSION .~ : D ~X T E : MAXIMUM LENGTH : 1024 ~iLE TYPE : PREVIOUS FiLE : .'-~:.- 'OM.q,=NTS .,-.,. ~: S CHLUMBER 3~.=R -.- ::: .~L~SKA T, DMPJTI~G CENTER :k-'- ..k -~ ~:~ :,k ,~ :X ....................... ~"- -'o -; ......... ~- '~ ' ' ' ~ .... ~-' SOMD~NY : ~RCD ALASKA INC WELL = FZ=.LD = CD'J~TY = NORT.5 SLOPE 5DR3U~H STATE = LVP 010oH02 VER!FICATIg~ LISTiN~ PAGE 3 JOB NUHBER AT &CC: 711¢$ RU'N ~ONE~ DATE LOGGED: LDP: C." WILKIE CASING = 9.6Z5" ~ 36.00' - SIT SIZE = 8.5" TO TY~E FLjIO = OENSITY : 10..5 LB/~ RM : 3.25 @ 55.0 DF VISCOSITY : ~9,.0 S RMF : 2.45 ~ 66.0 DF PH : 9°5 RMC : 2.77 @ 58.0 DF FLdID LOSS : 8.0 C3 RM &T BHT = 1.,59 @ ~60. DF MATRZX S~N~STDNE ~~ THIS 2AT& HAS N~T SEEN DEPTH SHimT'ED - DVERLAf,S :IELD PRINTS S'HLd~:SE~'.$ER "OGS INCLdDED WITH TtiS' ~&GNETIC DUAL ZNDJ'TI~,~ SPiERIC&LLY F2CUSE2 LOG (OIL) F]RMAT.iDN DENSITY COMPENSATED LOG (FDN) COM'P:ENS~T~D NE,U'TR3N LOG (FDN) G~M,MA RAY IN C,aSZ~G (~R.OI2) LVP OlO.H02 VER.IFIC:&TI2.q LISTiNS PADE 4 '~* D~T& FD~M~T RECORD e ENTRY 3LOCKS Ty~ MNEM SERVISE ID SFLd DZL ILD DIL IL~ DIL SP DIL SR DIL GR FDN CALl FDN RMDB FDN DR~O F3N NR~T RN~ FDN NPMI FDN NCNL :ON ~CNL DP~I DI2 SiZE R'E~ CODE ENTRY 1 65 O 1 55 ~ 4 73 50 ~ 65 olIN 1 66 1 1 65 D .SPECIFICATION BLDSKS SERVICE JNZT ORDER ~ 3~MM 3 MMM D~MM MV G~Pi Z~ ~zC3 DJ CPS CPS ~J ~Pl ~PI ~PI ~PI FILE SIZE SPL LOG TYPE CLASS MOD NO. O0 OOD O0 0 0 4 i' O0 220 O1 0 0 ~ 1 O0 120 45 O 0 O0 120 44 0 0 4 1 O0 010 O1 D 0 O0 310 O1 O0 310 O1 0 0 4 1 O0 280 O1 0 0 4 1 O0 350 02 O 0 O0 356 O1 0 0 O0 420 0.1 O 0 4 1 O0 000 '00 0 0 4 1 O0 890 O0 0 O 4 1 O0 330 31 O 0 ~ 1 O0 330 30 0 0 4 1 O0 890 O0 3 0 O0 310 O1 0 0 4 I REPR PROCESS CDDE (OCTAL) 58 OOOO0000000000 00000000000000 58 O0000000000000 58 00000000000000 OOO00000000000 00000000000000 O00000OO000000 58 O00OO000000000 58 OOO00000000000 5B O00000OO000000 03300000000000 58 00000000000000 58 OOO00000000000 OOO0000000OO00 53 O00000OO00OO00 OOOO00OO000000 58 00000000000000 9EPT SP 8113.0000 SFLJ -4.4.70'70 1.6192 45. 800,8 NC,N= 3EPT NP~I 3100.0000 SFLJ -4!.9553 GR 1.5192 OR,D ~9.5505 NCNL 2.5862 ILl 2000.5575 115.5523 GR 115.6523 O.Ol2T NR~T 3.6~Z8 1814.6875 FC~ 451.1406 2.5823 !LD 2.0979 115.5523 GR 116.6523 0.0127 NR~T 3.6~28 1814.6375 FCNL ~51.1~06 ILM 2.3772 SALi 5.5020 RNR~ 3.9338 DPHI 52.4754 ILM 2.3772 CALi 5.3210 RNR~ 3.9338 DPql 52.4764 LV° 010.H07 V~RIc!C~T!3~ LISTZN3 SP RH3B SP NPH! 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RNR~ DPHI CALl RN2a DPgI CALl RN~ DPqI CALl RNR~ DPWZ 3.5354 -999.2500 -999.2500 -999.2500 3.1448 -999.2500 -999.2500 -999.2500 4.5203 -999.2500 -999.2500 -999.2500 3.18,38 -999.2500 -9'99.2500 -999.2500 3.9495 -999.2500 -999.2500 -999.2500 3.9143 -999.2500 -999.2500 -999.2500 3.3987 -999.2500 -999.2500 -999,2500 3.2834 -999.2500 -999.2500 -999.2500 3.3811 -999.2500 -999.2500 -999.2500 LV~ OlO.HO2 VE~IFIC~TIO~ LI$TIN3 P~GE 7 -999.2500 )EPT 620 SP -8 RHSB -99 NPqI -99 SR -')9 ~EPT 610 SP -? RH3B -99 NPHZ -99 SR -99 DE~T 500 SP -6 RH3B -99 NP41 -99 GR -99 DE~T 590 SP -8 RH35 -99 ~P~I -99 GR -99 SP -.9 SR -99 gEDT 570 SP -$ -99 9EPT' 550 SP -? ~Pql ~ r~R -)9 ]EaT 550 SP -T ,qHDB SR -99 O.O00O SFLJ 4,2227 GR 9.2500 DRH3 9.2500 NCNL 9.2500 0,.0000 SF~ 5.0352 GR 9,2500 DRH2 9.2500 NC~'L, 9,2500 O,O00O SELJ 5.7852 GR 9,2500 DR53 9.2500 NCNL 9,2500 0,0000 SFLJ 4.T2,27 GR 9.12500 ORH] 9,2500 NCNL 9.2500 0.0000 SFLU 1,5352 GR 2,3557 DRHS ~,9!60 NC~ 9,2500 0.0000 SFLJ 6.0352 GR Z.2913 ORqD 2.3340 NCNL 9.2500 0.0000 SFLJ 3.5352 ~R 2.3030 DRH3 7.9004 NCNk 9.2500 0.0000 SF~J 2.7227 2.2971 1.5015 NCX_ 9.25OO ]E~T 5~00.0000 SFLJ SP -83.7227 GR qH]~ 2.3~59 ~qI 35.3515 NCN~ 3,1092 IL3 -999.2500 NR~T -999,2500 FCNL 2.9299 139.3398 -999,2500 NR~T -999.2500 FC~L 17.2393 ILD 90.5273 GR -999.2500 NR~T -999.2500 FCNL 3,7500 ILg 1~2.8125 GR -999.2500 NR~'T -999,25D0 FCNL 3.7014 !73.0525 GR 0.0254 NR~T 1907,6875 FCNL 1.5505 173,9375 GR 0.0103 NRaT 2014.6875 FC~L ~.3562 IL2 182.1875 GR 0.0703 NR~T 1721.5B75 FCNL 1.8572 13!.5875 GR -0.0005 NR~T 2055,5000 FCXL 2.7593 ill 158.5525 SR 0.0015 NR~T 2035.5000 ~C~L 3.6987 -999.2500 -999.2500 -999.2500 2.9944 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999. ~500 3,5721 -'999.2500 -999.2500 -999.2500 3.~05 173.0525 3.4143 491.3906 1.5251 173.9375 3.5198 511.5~06 3.8909 182.1~75 3.8245 422.3906 1.8539 131.6575 3.5002 515.8t25 2.3331 168.5525 3.1~97 529.9125 ILM CALI RNRA DPHI ILM C ,~ L ,l RNR~ DPHI ILM CALl RNRa DPHI ILM CALl RNRA !LM CALI RNR~ DPHI !LM C4LI RN24 OPHI CALI RNR& gPHI iLM C4LI RNR4 CALl DP~I 3..5100 -99'9,2500 -999,2500 -999,2500 3.0852 -999-2500 -999.2500 -999.2500 6,5062 -999.2500 -999.2500 -99'9.2500 3.7815 -99'9.2500 -999,2500 -9'99,2500 3.6702 10.3065 3.8811 17.8~38 .1.7676 9.3145 3.9358 21,7~97 3.7834 9.3145 4.0750 21.03'95 1.9131 9.5488 3.9846 21.3946 2.7092 9.9238 3.310~ 18.4356 tV: OlO.M02 VERIFiCaTIO~ LISTIN3 PA&f 8 -999,2500 3EPr. 530 SP -8 RHDB NPHI 3 GR -99 SP -8 RH2B NPqI 3 SR -99 9E~T SP NPH! ~R DEPT SP NPHI ~R DE~T SP NPqI SR DEPT SP RH35 SR DEPT SP NPHI S? 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ILD -999.2500 GR -999.2500 NR~T -'999.2500 FCNL 4.176S 126,9548 3.6780 G82.8906 ?,Z~29 .-999,2500 -999,2500 -999,2500 4.8210 -999.2500 -999.2500 -999.2500 6,1062 -999,2500 -999,2500 -999,2500 6.1570 -999.2500 -999.2500 -999.2500 6.8289 -999.2500 -999.2500 -999.2500 8.4529 -999.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 ILM CALl DPHI CALl OPql !LM CALl RNR~ DPHi ILM CALI RNR~ OPHI CALl RNR4 OPqI CALl RNR~ DPHI ILM CALI RN~A OPdI IL~ CALl DPHI ILM CALl DP~I 3.9905 10,5566 4.2234 25.1289 6.8445 -999.2500 -999,2500 -999.2500 4.543'7 -999.2500 -999.2500 -999.2500 5,8328 -999.2500 -999.2500 -999.2500 5.5320 -999,2500 -999,2500 -999,2500 6.5046 -999.2500 -999.2500 -999.2500 2000.6875 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,~500 -999.2500 -999.2500 -999.2500 -999.2;00 LVP OlO.H02 VERiFIC~TiQ,~ LI~TIN~ P~GE 11 gE~T 2500.0000 SFLJ SP -999.2500 ~H25 -999.2500 NPqI -999,.2500 NCN'L SR 47.2305 -999,2500 IL3 -999.2500 GR -999.2500 NRAT -999.2500 FC~L 9EPT 2500.0000 SFLJ SP -999.Z500 GR RHD5 -999.2500 DRH3 ~P'qZ -99'9.2500 NC~L GR 57.1580 -999.2500 IL9 -999.2500 GR -999,2500 NR~T -999.2500 FC~L 2E:T 2~00.0000 SFLJ SP -999.2500 RHJ~ -999.2500 DRH2 NPqi -999.2500 NC~L SR 49.0¢30 -999,2500 -999.2500 -999.,2500 -999.2500 FCNL DEPT 2300.0000 SFLj SP -999:.2500 GR qH25 -999.2500 2RH] NPHI -999.2500 NC~L 5R 28.8543 -999.2500 IL2 -999.2500 GR -9~9.Z500 NR~T -99'9,2500 FCNL 3EPT 2200,0000 SFLJ SP -999.2500 GR RH]B -999.2500 DRH2 NPqI -999.2500 NSNL SR -999.2500 -999'.250~ SR -999,2500 NR~T -9~9.2500 FC~L gEPT ZIO0,O000 SFLJ SP -999.2500 GR qd]B -999.2500 DRH2 WP~I -999.2500 NC~ SR 53.3555 -999.2500 IL~ -9~9.2500 8R -999.2500 NR~T -999.2500 FC~L ]E~T 2000.0000 SFLJ So -999.2~00 SR RH]5 -999.2500 DRH3 ~PWZ -999.2500 NCNL gR 35.6992 -999.2500 ILl -999.2500 SR -999.2500 NR~T -999.2500 3EOT !900.0000 S~LJ S~ -999.2500 SR RH3B -999.2500 9R53 ~Pq! -~99.250~ NCWL '3R 51.8867 -999.2500 IL9 -999.Z500 GR -99'9.2500 NR~T -999.2500 ~CWL ]EPT 1800.0000 SFLJ SP -999.2500 GR qH]8 -999.2500 DRH] qPqI -999.2500 NCN~ -999,2500 ILD -999.2500 GR -999.2500 NR&T -9~9.2500 FCic -999.2500 !LM -999.2500 C~LI -999.2500 RNR~ -999.2500 DPHI -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 DP~I -99'9.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 DPHI -999.2500 ILM -999.2500 CALl -999.2500 RNR~ -999.2500 DPt! -999,.2500ILM -999.2500 CALt -999.2500 RNR& -999,2500 DPHI -999.2500 ILM -999.2500 CALI -999.2500 RNRa -999.2500 DPtI -999.2500 ILM -99'9.2500 CALZ -999.2500 RNR& -999.2500 OPWI -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 OPSI -999.2500 -999.2500 SA' I -999.2500 RNR~ -9~9.2503 DPMI -999.2500 -99'9.2500 -999.2500 -9'99.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -'999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -999.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.H02 VERIFIC~TI3~' L!S'TINI3 PAGE 12 DEmT SP NPHI GR SP NPHI ~R SP RHSB NPHZ GR DEPT SP RH3B NP'dI DEbT SP ~PHI DE~T SP NPHI SP RHZ]B SR SP ~.7.57q, 2 1700.0000 SFLJ -999,2500 I3R -999,2500 DRH3 -999,2500 NC~L 17,3D49 1600.0000 SFLJ -999,2500 G~ -999,2500 D~H3 -999,2500 NCXL 33.0117 .1500,0000 SFLg -999,2500 GR -999.2500 DRH3 -999,2500 NCNL 41.0~30 1400,0000 SFL~ -999,2500 GR -999,2500 DRq~ -999,2500 NCNL 27.9268 1300,0000 SFLJ -999,2500 GR -999,2500 DRY3 -999.2500 NCNL 32.7517 1ZO0.O00O SFLJ -999,2500 GR -999,Z500 -999.2500 MCat 37.1367 1100.0000 SFLJ -999. 2500 SR -999,2500 DR't3 -99'9,2500 NCNL 49,9~92 lO00.O000 SFLJ -999.2509 GR -999.2500 DRY3 -999.2500 NCNL ~5.418D ~OO.O000 SFLJ -99'9.2500 GR -999.2500 DRH3 -999,2500 NCN_ -999.2500 ILD -999.2500 GR -999,2500 NRAT -9~9,2500 FCNL -999.2500 ILD -999,2500 GR -999,2500 NR~T -999,2500 FCNL -999.2500 -999,2500 GR -999,2500 NRqT -999,2500 FCNL -999.2500 ILD -999,2500 GR -999.2500 NR~T -9~9,2500 FC~L -999,2500 ILD -'999.,2500 NRAT -9~9,2500 FCNL -9~9.2500 IL3 -999,2500 GR -999,2500 NR~T -9)9.2500 FC~L -999,2500 -9~9.2500 GR -9~9,2500 NR~T -9)9.2500 FCNL -9~9.2500 ILD -9~9.2500 GR -999.2500 NRCT -999.2500 FCNL -999.2500 ILD -9~9.2500 GR -999.2500 NR~T -9~9.2500 FC~ -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -99~,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 .-999,2500 -999.2500 -999,.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -9~9.2500 -999.2500 ILM C~Li RNR~ DPHI C ~L,I RNR~ DPMI ILM CALI RNR~ DPH! ILM CALl RNR~ ILM CALI RNR4 DPHI ILM C4LI RN2& DPqI !LM CALI RNR~ DPHI IL~ CALI DPHI C~LI RNR~ DPEI -999.,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -'999.2500 -999.2500. -999-2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -9~9,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -9)9.2500 -999.2500 -999.2500 -9~9.2500 -999.2500 -999,2500 -999.2500 -99"9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.H02 VER!FIC~TIgi~ LISTINg PAEE 13 GR DEPT SP RH35 NPHZ ER OEDT SP RHgB ~PqI SR 3EPT SP RH]5 NPH! SP RHOB NPHI DEPT SP RH]B NPqI SR DEPT SP NPHI SP S P SR ]EPT SP RH]S NPHI 28,~268 800,0000 SFLU -999.2500 ER -999.2500 DRq] -999,2500 NC~L 49.~B05 700.0000 SFLJ -999,2500 ER -999,2500 DRflJ -999,2500 NCNL 40.251T 600,0000 SFLJ -999,2500 GR -999.2500 ORH]' -999.2500 NCNL 40,.~67 500.0000 SFLJ -999,2500 GR -999.2500 DRHD -999,2500 NCNL 33.~555 %00,0000 SFLJ -999,2500 ER -999,2500 ORMD -999.2500 NCNL 40.5055 300.0000 SFLJ -999.2500 ER -999.2500 DRH~ -999.2500 NCNS 2~.2549 200.0000 SFLJ -999.2500 ER -999.2500 DRY3 -999.2500 NC~_ 34.88,57 100.0000 SFLJ -999,2~00 GR -999,2500 SRO2 -999.2500 NC~_ 21.3955 96,5000 SF~J -999,2500 ER -999.2500 9RH3 -999.2500 -999,2500 ILD -999,2500 SR -999.2500 NRAT -999.2500 FCNL -9~9.2500 -999,2500 GR -999,2500 -999.2500 FCNL -999.2500 !LD -9~9.2500 GR -9~9,2500 NR,~T -999.2500 FCNL -999,2500 IL3 -999,2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999,25D0 GR -999.2500 NR~T -999.2500 FCNL -'9'~9.2500 ILl -999.2500 GR -999.2500 NR&T -9'99.2500 FCNL -999,2500 IL2 -999.2500 GR -999,2~00 NR6T -999.2500 FC~L -999,2500 ILO -999,2500 GR -999.2500 NRaT -9)9.2500 FC~' -999,2500 iL2 -999.2~00 GR -999.2500 NR~T -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -9'99,2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -9'99,2500 -999.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 C4L.I ILM ~AI'.I~ . RNRa OPHI ILM CALl. RNR~ DPHi ILM CALI RNR~ DPHi ILM CALI RNRA ILM CALl DPSI ILM CALI RNR~ DPHi CALl RNR~ DP~i ILM CALI RNRA DP~I -999.2500 -99'9,2500 -999.2500 -999,2500 -999.2500 -999'2500 -999.2500 -999.2500 -999,2500 -9'99.2500 -999,2500 -999,2500 -999.2500 -999'2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2~00 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LV? OlO.H02 VER[F!CATI3~ LI.$TIN3 PAGE 14 22.9393 ......,,-,,- FILE TRAILER FILE N~ME :EDIT SERVICE N&;~E : VERSION ,~ : DATE : ~AXiMUM LE,~GTH : 1024 miLE TYPE : NEXT' FILE .NAME : ;:'-;',: TAPE TRAILER SERVICE NAME :EDIT DATE :85/01/30 3RI~IN :FS1A TAPE NAME : ~.O~T!NUATI3N # :01 NEXT TAPE NAME :, 'O~MENTS :LIBRARY TAPE ~:~:: ~EEL TRAILER ~¢ S;RVICE NAME :'EDIT gATE :85/01/30 ~RI~IN : REEL NA~E :159351 CONTiNUATiON # :01 ~qEXT REEL NAME : COMMENTS ':LIBRARY TAmE