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184-241
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, November 24, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-06 MILNE PT UNIT C-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/24/2023 C-06 50-029-21257-00-00 184-241-0 G SPT 6728 1842410 1682 3675 3677 3677 3676 0 0 0 0 4YRTST P Guy Cook 10/10/2023 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT C-06 Inspection Date: Tubing OA Packer Depth 278 2005 1970 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC231009152524 BBL Pumped:1.4 BBL Returned:1.4 Friday, November 24, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor 7(�Gf FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 21, 2019 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC C-06 MILNE PT UNIT C-06 Ste: Inspector Reviewed By: P.I. SupryMg— Comm Well Name MILNE PT UNIT C-06 API Well Number 50-029-21257-00-00 Inspector Name: Austin Mcleod Permit Number: 184-241-0 Inspection Date: 10/16/2019 Insp Num: mitsAM191017204114 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-06 Type Inj w TyD 6728 Tubing aso I4so 475 1472 1468 " PTD 1842410 ' Type Test SPT Test psi 1682 IA 215 2122 " 2076 2048 - 2044 " BBL Pumped: 1 8 BBL Returned: 1.9 OA 253 458 466 - 459 _ 456 ' Interval 4YRTST P/F P Notes: MIT -LA October 21, 2019 Page I of 1 DATE 10/04/2019 18 y24 1 Debra Oudean Hilcorp Alaska, LLC 3 1 2 9 8 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 Halliburton INJECTION PROFILE 19 JUL 2019 CD 1: i MPU_C-06i_IPROF 19JUL19 7/30,201912:31 PM PDF Dorui MPU_C-06i_IPROF_7''9JUL19 40 DWN 7/30/201912:31 P LAS File j MPU _C-06i_fPROF_19JUL19 40 UP 7/30.1201912,31 PM LAS File 3 MPU_C-06i_IPROF_19JUL19_80 DWN 7{30/26191,:31 PM LAS File MPU _C-06i_[PROF _19JUL19_80 UP 7/30.x201912:31 PM LAS File 2 MPU_C-06i_IPROF_l9JUL19_120 UP 7/30/201912:31 PM LAS File ❑O MPU _C-06i_[PROF _19JUL19_img 7/30/201912:31 PM TIFF File MPU_C-06i_fPROF_19JUL19_STATIONBW 7/30/20191-731 PKI LAS File MPU _C-06i_IPROF_19JUL19_STATION 8400 7,130/201912:31 PPa1 LAS File MPU_C-06i_IPROF_19JUL19_STATION8460 7/30/201912:31PNI LAS File MPU _C-06i_IPROF_ 19JUL19_STATIONSSW 7/30/201912:31 PM LAS File _ MPU_C-06i_IPROF_19JUL19_STATION8550 7130/20191231 PM LAS File MPU_C-06i_IPROF 19JUL79 STATION 8672 7/30./201912:31 PM LAS File MPU_C-06i_IPROF_19JUL19 STATION8715 0/30/201912:31 PM LAS File Please include current contact information if different from above. RECEIVED OCT 0 4 2019 AOGCC Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received8y: - np (//I I Date: • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 DATE: Friday,October 30,2015 P.I.Supervisor l ��' I) SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC p q C-06 FROM: Johnnie Hill �SCAN�� U L. I �) MILNE PT UNIT KR C-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry,:.102— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR C-06 API Well Number 50-029-21257-00-00 Inspector Name: Johnnie Hill Permit Number: 184-241-0 Inspection Date: 10/28/2015 Insp Num: mitJWH151029112433 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well; C-06 Type Inj 1 W TVD ! 6728 - Tubing 1923 1925 1925 • 1925 - 1926 - 4 PTD 1 1842410 ',Type Testi SPT Test psi 1682 IA 311 2521 - 2495 - 2472 - 2480 - Interval4YRTST P OA 300 569 590 - 586 587 : P/F Notes: used 2 bbls of diesel Friday,October 30,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � t Z DATE: Thursday, December 15, 2011 / 1 / 41 SUBJECT: Mechanical Integrity Tests P.I. Supervisor g y BP EXPLORATION (ALASKA) INC C -06 FROM: John Crisp MILNE PT UNIT KR C -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv. NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR C -06 API Well Number: 50- 029 - 21257 -00 -00 Inspector Name: John Crisp Insp Num: mitJCrl 11125100633 Permit Number: 184 -241 -0 Inspection Date: 11/18/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 'Well C -06 , Type Inj, W ' TVD 6728 - IA 460 2750 ' 2680 2760 2760 ' 1 2680 , P.T.D 1842410 ' TypeTest SPT Test psi 1682 - OA 300 570 550 570 600 550 Interval 4YRTST PIF F — Tubing 2152 2152 2149 2154 2155 2153 Notes: 2 bbls ambient diesel pumped to attempt MIT. Injection rate & fluid temp not stable enough to witness MIT. 5taMbiEDFFE 1 0 2012 Thursday, December 15, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, December 13, 2011 P.I. Supervisor 1 \ 7 / l Z( Z2//( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C -06 FROM: John Crisp MILNE PT UNIT KR C -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .15 NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR C - 06 API Well Number: 50 029 - 21257 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr111125101106 Permit Number: 184 - 241 - Inspection Date: 11/18/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well f C -06 - Type Inj. W ' TVD 6728 " IA 480 2740 2700 2700 - P.T.D1 1842410 1 TypeTest S PT psi si 1682 OA 240 480 460 450 -- — ■ Interval 4YRTST P/F P Tubing 2142 2142 2136 2134 Notes: Retest after stable injection rate & temp were achieved. 2 bbls pumped for test. aLAWNEP FFP 1 6 . L z- Tuesday, December 13, 2011 Page 1 of 1 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Piug Perforations ~ Stimulate~ Other 0 gRIGHT WATER Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~lopment r Exploratory ~ 184-2410 / 3. Address: P.O. Box 196612 Stratigraphic ~ Ser~ice ~ i 6. API Number: Anchorage, AK 99519-6612 50-029-21257-00-00 ,~ 7. KB Elevation (ft): 9. Well Name and Number: 52 KB MPC-06 / 8. Property Designation: 10. FieldlPool(s): - ~ ADLO-047437 MILNE POINT UNIT Field/ KUPARUK RIVER SAN S Pool 11. Present Well Condition Summary: ~~;' Total Depth measured 8900 / feet Plugs (measured) None ;~` ;, ~ E~~'~,:; true vertical 7228.78 ~ feet Junk (measured) None Effective Depth measured 8809 feet true vertical 7145 feet Casing Length Size MD ND Burst Collapse Conductor 80 13-3/8" 48# H-40 Surface - 115 Surtace - 115 1740 750 Surface 5606 9-5/8" 36# K-55 Surface - 5641 Surface - 4548 3520 2020 Production 8854 7" 26# L-80 Surface - 8889 Surtace - 7218 7240 5410 0. ~ ~ ~,,~e~ Y mn..i. . . ~ ~-L3~.~s PerForation depth: Measured depth: SEE A'fTACHED - _ _ _ _ True Vertical depth: _ ; _ _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 SURFACE - 8518' 0 0 - ~~ Packers and SSSV (type and measured depth) 7"X3-1/2" S-3 BAKER PKR 8341' ~ ~.~ 7"X3-1/2" FB-1 BAKER PKR 8490' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1514 2306 Subsequent to operation: 1581 2291 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ De~elopment ~"" Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil T~ Gas ~ WAG C~i GINJ ~ WINJ ~ WDSP~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/10/2009 Form 10-404 Re~ed 04/2006 ~~~~~ '~~°~, ~~ ~~ "4;~~~; J~ ~~~ Submit Original _/~~ ~.,,, -~~ 9%~ M PC-06 184-241 PFRF OTTCHMENT n U Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-06 1/21/85 PER 8,457. 8,463. 6,829.69 6,834.97 MPC-06 1/21/85 PER 8,649. 8,666. 7,000.84 7,016.21 MPC-06 1/21/85 PER 8,678. 8,708. 7,027.08 7,054.32 MPC-06 7/24/96 APF 8,457. 8,463. 6,829.69 6,834.97 MPC-06 7/24/96 APF 8,649. 8,666. 7,000.84 7,016.21 MPC-06 7/24/96 APF 8,678. 8,708. 7,027.08 7,054.32 MPC-06 7/26/96 STC 8,341. 8,490. 6,728.34 6,858.76 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE n U ~ ~ MPC-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/24/09 - 8/9/2009~Bright Water pump operations. Began EC9360A (surfactant) pre-flush injection on ; 7/21 /09 with a water injection rate of 1228 BW PD and injection pressure of 2160 psi. Began EC9378A (polymer) injection on 07/24/09 with a water injection rate ~ 1514 BWPD and injection pressure of 2215 psi. Finished pumping EC9378A °08/08/09 with a water injection rate of 1514 BWPD and injection pressure of 2306 ~psi. Finished pumping EC9360A on 08/09/2009 with a water injection rate of 1581 ~BWPD and injection pressure of 2291 psi. Total EC9378A injection volume 16299 ~gallons. Total EC9360A injection volume 5322 gallons. • MEMORANDUM ,---, To: Jim Regg J('>b ~ ; i P.I. Supervisor ~~`'~~~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 27, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (.4L.4SK.4} INC C-06 MILNE PT LNIT KR C-06 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Jy;~ ,- Comm Well Name: MILNE PT UNIT ICR C-O6 Insp Num: mitJCr07ll27112952 Rel Insp Num: API Well Number: 50-029-21257-00-00 permit Number 184-241-0 Inspector Name: John Crisp Inspection Date• 1 U22/2007 Packer Depth Pretest Initial ~ 15 Min. 30 Min. 45 Min. 60 Nlin. Well ~ C-06 jTYPe Inj. ~ w TVD ~ ~ 6~zs ~ IA I3o ~~ zozo ~ I9~o ~ I9so ~ I tsazato ',TypeTest ~~ srT ~ Test psi P.T I ~~ 16sz ~ OA s9o -I 6so 6zo ~ 6to Interval aYRTST p/F P .i Tubing ~ zzso ' z?so i zzso zzso - --- -- Notes: 1.9 bbl's pumped for test. I monitored the tubing & IA pressure before PT of IA was performed. AOGCC pressure test requirements were met for MIT without achieving test pressure above tubing pressure. ~,°v~~~~ ~ E C ~ ~ 2007 / „E >~ ~~ V" Tuesday, November 27, 2007 Page I of 1 (~\~ 6 V-_·n~nn'-'--~jJ ' . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) UjÇ.- /154{- d'-II ;Jt /4Q'-f1 1 BL / EDE Disk MPU C -06i Injection Profile 12-Sep-06 5) 6) 7) Signed: é1~. .f~--- Cltrì.~+ tlA...¿ {}1"k IJ\k.p~V\ Print Name: PRoAcTIVE DIAGNOSTIC SERVICES. INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ?C~~:!¡?';(:::~!':JR.:\-3;:@¡l~'1Œ~¡J1ÜFrn...::;~3., ,~Oi"ijl WEBSITE: '/\j'-j\j1IV,}JiE;jJCJR.V'L,:JG,C;:;Y¿ D:\OO _ PDSANC·2006\Z _ W ord\Distnbution\Transmittal_ Sheets\T ransmit_ Original doc ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '"K~ )i)\7-'2>/D4 P.I. Supervisor Ii DATE: Monday, October 25, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-06 MILNE PI UNIT KR C-06 t'ßt¥--~q;1 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Supr~ Comm Well Name: MILNE PT UNIT KR C-06 Insp Num: mitJJ041 019173631 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21257-00-00 Permit Number: 184-241-0 Inspector Name: Jeff Jones Inspection Date: 10/16/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C-06 Type Inj. s TVD 6732 IA 650 2500 2460 2440 P.T. 1842410 TypeTest SPT Test psi 1683 OA 0 0 0 0 Interval 4YRTST P/F p Tubing 3650 3650 3650 3650 Notes: 1.2 BBLS diesel pumped, 1 well house inspected; no exceptions noted. SCANNED NO\! 0 9 200t} Monday, October 25,2004 Page 1 of 1 Tree: 3 1/8" - 5M FM( ') Wellhead: 11" 5M FMC wI 31/2" FMC Tubing Hanger, EUE lift threads, 3" -- CIW H BPV profile MPU C-06i )rig. KB Elev. = 52.0 Orig. GL Elev.= 12.0' RT To Tbg. Spool =29.95' 13-3/8" , 48 #/ft , H-40 I I ~ KOP @ 1,000' Max. hole angle = 50° @ 3,400' Hole angle thru' perfs = 32° 9-5/8't, 36#/ft,K-55&L-80.Btrc. í I 5.641 ,I 7" 26 #/ft , L-80, BTRC Casing. ( drift 10 = 6.151", cap. = 0.0383 bpf ) 3.5" 9.3 #/ft , L-80 , NSCT. Bbls/ft = .0087 10 = 2.992" Minimum tubing restriction = 2.75" "XN" profile @ 8,479' Stimulation Summary Perf()rationSummary Ref log: DIL Log - ( 1-21-85 ) j' ,j; ~~ .:,-i~ q~ <1[ :)k- '1.1 'I. r:fi :i~ ,K ~~ '~I 'lI \;:~ ~I ::M , 'j~ -:,1 ill .'<1 ::t, ;~':a 'q~, ;:1 80' i 7" x 4.5" Baker" S-3" Packer I 8.341' I 3.5" x 1" Cameo" KBUG " ~ wi dummy valves. I I I ~ 3.5" x 1" Cameo" KBUG " wi dummy valves. I R,~R5' I I 8.422' I Size SPF Interval (TVD) C-Sands (Middle Kup) 8,457' - 8,463' 6,829' - 6,834 8,457 - 8,463' " " "" A3 Sands (LK-1 ) 8,649' - 8,666' 7,000' - 7,015 8,649' - 8,666' "" "" ;;; A2 Sands (lK-2) ~ 8,678' - 8,708' 7,026' -7,053 ~ 8,678' - 8,708' II " " II ~ .. , 3.5" HES XN-Nipple (2.75" id) I 8.479' I J~ I ECP 8,477' I ~ Baker 80-40 "GBH" lac. seal assey R,4RQ' I J' '''''''-'- 'n - - - -'-"'-' 7" Baker" FB-1" Pkr. (85-40) I 8,490' I 1 ECP WLEG I 8.519' I 8,572' Tubing tail ELMO I 8.518' I 5" 12 4,5" 5 2-5/8" 4 4.5" 5 5" 12 4.5" 5 12 spf @ 120° Phasing (1-21-85) 4 spf @ 1800 Phasing (1-21-85) 5 spf @ 1351 45 0 Phasing Alpha jet ( 7-24-96 ) ~~ 7" float shoe I 8.889' I DATE REV. BY COMMENTS MILNE POINT UNIT 1 1 231 84 Cased hole completion WELL C-06i 1125/85 Origanal Completion API NO: 50-029-21257-00 7/261 96 MOO RWO Completion 4ES 06/17/97 M. Linder Added tubing tail ELMD BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations periormed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _X WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchoracje, AK 99519-6612 4. Location of well at surface 4613' FNL, 2289' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 2698' FNL, 4517' FEL, Sec. 14, T13N, R10E, UM At effective depth 2706' FNL, 4488' FEL, Sec. 14, T13N, R10E, UM At total depth 2737' FNL, 4467' FEL, Sec. 14, T13N, R10E, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X (asp's 558175, 6028948) (asp's 561258, 6025608) (asp~ 56128~ 6025601) ~sp~ 561309, 6025570) 6. Datum elevation (DF or KB feet) RKB 40 feet 7. Unit or Property name Miline Point Unit MPC-06 9. Permit number / approval number 184-241 10. APl number 50-029-21257-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 5606' Production 8854' 8900 7228 8809 7145 feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 13-3/8" To Surface 9-5/8" 179 bbls Class 'G', 490 bbls PF 'E' 7" 650 sx Class 'G' Measured Depth True Ve~icalDepth 115' 115' 5641' 4548' 8889' 7218' Perforation depth: measured Open Perfs 8457' - 8463', 8649' - 8666', 8678' - 8708' true vertical Open Peffs 6829' - 6834', 7000' - 7015', 7026' - 7053' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 NSCT to 8518' MD. RECEIVED jAN 5 ;1200J 0ii & Gas uoi~s. G0[;'lmissi0~, Anchorage Packers & SSSV (type & measured depth) 7" x 3-1/2" S-3 Baker Packer @ 8341', 7" x 3-1/2" FB-1 (85-40) Baker Packer @ 8490'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 12/07/2002 Subsequent to operation 01/25/2003 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2828 3646 I -:ANNED FEB 0 4 2003 2554 16. Status of well classification as: Oil_ Gas_ Suspended_ Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledg~ ' )OMS BFL Form 10-404 Rev 06/15/88 · Title: Technical Assistant Date January 27, 2003 Prepared by DeWayne R Schnorr 564-5174 SUBMIT IN DUPLICATE 10/19/2002 01/15/2003 01/26/2003 10/19/02 01/15/03 MPC-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS WAG SWAP FROM WATER TO GAS INJECTION. WAG SWAP FROM GAS TO WATER INJECTION TESTEVENT --- INJECTION PRESSURE, PSI: 2,551 TYPE: PW VOL: 1,850 BWPD EVENT SUMMARY PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUE FLANGES TO SPEC. MIRU. FESCO PT'd TO 5000 PSI. PUMPED 10 BBLS METHANOL DOWN THE TUBING AT 1.0 BPM @ 2850 TO 3000 PSI, AND 1 BPM METHANOL DOWN THE FLOW LINE AT 0.85 BPM @ 3500 PSI FOR FREEZE PROTECTION. RDMO. WELL WAS CONVERTED TO GAS AND PUT ON INJECTION AT 2000 MCFPD. PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR WATER INJECTION AND TORQUE FLANGES TO SPEC. MIRU FESCO. PT'd TO 4500 PSI. PUMPED 5 BBLS METHANOL @ 1.8 BPM AT 3800 PSI AND 80 BBLS SOURCE WATER @ 2.8 BPM AT 3800 TO 2800 PSI AND 2 BBLS METHANOL. RDMO. WELL WAS CONVERTED TO WATER AND PUT ON INJECTION @ 1500 BPD. 01~6~3 TESTEVENT --- INJECTION PRESSURE, PSI: 2,551 TYPE: PW VOL: 1,850 BWPD FLUIDS PUMPED BBLS DISCRIPTION 19 M ETHANOL 80 SOURCE WATER 99 TOTAL SCANNED FEB 0 2003 Page 1 Tree: 3 1/8"-5M FMC Wellhead: 11" 5M FMC w! 3 1/2" FMC Tubing Hanc. lift threads, 3" CIW H BPV profile 13--3/8", 48 #/ft, H-40 ~ MPU C,06i Orig. KB Elev. = 52.0 Orig. GL Elev. = 12.0' RT To Tbg. Spool =29.95' 80' KOP @ 1,000' Max. hole angle = 50° @ 3,400' Hole angle thru' peris = 32° 9 5/8", 36 #/ft, K-55 & L-80 Btm. 7" 26 #Iff, L-80, BTRC Casing. ( ddft ID = 6.151", cap. = 0.0383 bpf) 3.5" 9.3 #/ft, L-80, NSCT, Bbls/ft = .0087 ID = 2.992" Minimum tubing restriction = 2.75" "XN" profile @ 8,479' 7" x 4 5" Baker" S-3" Packer I 8,341' [ J--~8:365' I 8,422' 3.5" x 1" Camco "KBUG" w/dummy valves. Stimulation Summary Perforation Summary Reflog: DIL Log (1-21-85) ;ize -5/8 SPF 12 5 12 5 Interval (TVD) Middle Kup 8,457' - 8,463' 8,457 - 8.463' LK-1 8,649' - 8,666' 8,649' - .8,666' LK -2 8,678' - 8,708' 8,678' - 8,708' 6,829'-6,834' 7,000' - 7,015' 7,026' - 7,053' 12spf@ 120° Phasing ( 1-21-85 ) 4 spf@ 180°Phamng (1-21-85) ~ 5 spf@ 135/45 ° Phasing Alpha .let(7-24-96) 3.5" x 1" Camco" KBUG" w/dummy valves. 3.5" HES XN-Nipple ( 2.75" id ) I 8,479' ECP 8,477' Baker 80-40 "GBH" loc. seal assey.J R,4Rg' J 7" Baker" FB-I" Pkr ( 85~40 ) J 8,490' ECP 8,572' WLEG 8,519' Tubing tail ELMD ] 8,518' 7" float shoe DATE REV BY COMMENTS I / 23/84 Cased hole completion 1/25/85 7/26/96 06/17/97 MDO M. Linder Onganal Completion RWO Completion 4ES Added tubing tail ELMD MILNE POINT UNIT WELL C-06i APl NO: 50-029-21257-00 BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4613' FNL, 2289' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 2698' FNL, 4517' FEL, Sec. 14, T13N, R10E, UM At effective depth 2706' FNL, 4488' FEL, Sec. 14, T13N, R10E, UM At total depth 2737' FNL, 4467' FEL, Sec. 14, T13N, R10E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 558175, 6028948) (asp's 561258, 6025608) (asp's 561287, 6025601) (asp's 561309, 6025570) 6. Datum elevation (DF or KB feet) RKB 40 feet 7. Unit or Property name Miline Point Unit MPC-06 9. Permit number / approval number 184-241 10. APl number 50-029-21257-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 5606' Production 8854' 8900 feet Plugs (measured) 7228 feet 8809 feet Junk (measured) 7145 feet Size Cemented Measured Depth True Vertical Depth 13-3/8" To Surface 115' 115' 9-5/8" 179 bbls Class 'G', 490 5641' 4548' bbls PF 'E' 7" 650 sx Class 'G' 8889' 7218' Perforation depth: Fubing (size, grade, and measured depth) RECEIVED measured Open Perfs 8457'- 8463', 8649'- 8666', 8678'- 8708' DEC 0 4 2002 true vertical Open Perfs 6829' - 6834', 7000' - 7015', 7026'- 70,~I OJJ & ~a$ ~011~. Oomml~ion Anchorage 3-1/2", 9.3#, L-e0 NSCT to 8518' MD. Packers & SSSV (type & measured depth) 7" x 3-1/2" S-3 Baker Packer @ 8341', 7" x 3-1/2" FB-1 (85-40) Baker Packer @ 8490'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 10/09/2002 Subsequent to operation 10/22/2002 OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 1551 225O Casing Pressure Tubing Pressure 2433 3667 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended Service WAG Injector 17. I hereby ce.rtify that the foregoing is t,r. pe and correct to the best of my knowledge. ~,/~~/~~.~ Title: Technical Assistant DeWayne R. Schnorr , C:ANNED DEC 1 2002 '2DH BFL Form 10-404 Rev 06/15/88 · ~. ~ DEC 5 2002 Date November 11, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE MPC-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/20/2002 WAG SWAP WELL FROM GAS TO WATER INJECTION. 05/04/2002 WATER INJECTION PROFILE 05/29/2002 WAG SWAP WELL FROM WATER TO GAS INJECTION. 07/11/2002 WAG SWAP WELL FROM GAS TO WATER INJECTION. 10/19/2002 WAG SWAP WELL FROM WATER TO GAS INJECTION. 11/10/2002 TESTEVENT---INJECTION PRESSURE, PSI: 3,905 TYPE: PW Vol: 2,065 BPD. EVENT SUMMARY 04/20/02 WELL SUPPORT TECHS RIGGED UP AND FLUSHED CENSOR LINES, GREASED TREE & LATERAL VALVES & THEN SWAPPED BLINDS AND TORQUE TO SPEC. HB&R RIGGED UP AND PUMPED 10 BBLS METHANOL, 90 BBLS SOURCE WATER AND THEN 5 BBLS METHANOL TO FREEZE PROTECT THE TRUCK. PUMPED FROM 1.5 - 2.9 BPM FROM 3200 TO 2400 PSI. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT BACK ON INJECTION. PUT ON WATER INJECTION. O5~O4/O2 WATER INJECTION @ 995 BWPD. RIH W/PDS, SPINNER, TEMPERATURE, PRESSURE TOOLS. MADE UP & DOWN PASSES @ 40 FPM, 60 FPM AND 80 FPM FROM 8440' TO 8645' MEASURED DEPTH. MADE STOP COURTS @ 8400', 8490' AND 8600' MEASURED DEPTH. POOH & RDMO. 05/29/02 PJSM. S/I SAFED OUT SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION & TORQUE TO SPEC. MIRU HB&R. PT'd TO 4500 PSI. PUMPED 2 BBLS METHANOL DOWN FLOW LINE & 20 BBLS METHANOL DOWN TUBING @ 1.5 BPM, 2200 TO 2775 PSI. RDMO. PUT ON GAS INJECTION @ 1000 MSCFPD. 07/11/02 WELL SUPPORT TECHS SWAPPED BINDS, FLUSHED SENSOR LINES, AND GREASED TREE. ALL FLANGES WERE TORQUE TO SPEC. HB&R RIGGED UP AND PUMPED 10 BBLS METHANOL FOLLOWED BY 90 BBLS SOURCE WATER AND THEN 2 BBLS METHANOL. PUMPED FROM 3400 TO 3600 PSI AT 2 BPM. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT ON WATER INJECTION. 10/19/02 PJSM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TORQUE FLANGES TO SPEC. MIRU. FESCO PT'd TO 5000 PSI. PUMPED 10 BBLS METHANOL DOWN THE TUBING AT 1.0 BPM @ 2850 TO 3000 PSI, AND 1 BPM METHANOL DOWN THE FLOW LINE AT 0.85 BPM @ 3500 PSI FOR FREEZE PROTECTION. RDMO. WELL WAS CONVERTED TO GAS AND PUT ON INJECTION AT 2000 MCFPD. ,SGANNED DEC 1 9 200 Page 1 11/10/02 MPC-06 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS TESTEVENT --- INJECTION PRESSURE, PSI: 3,905 TYPE: PW Vol: 2,065 BPD. FLUIDS PUMPED BBLS DISCRIPTION 6O METHANOL 90 SOURCE WATER 150 TOTAL Page 2 "--" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4613' FNL, 2289' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 2698' FNL, 4517' FEL, Sec. 14, T13N, R10E, UM At effective depth 2706' FNL, 4488' FEL, Sec. 14, T13N, R10E, UM At total depth 2737' FNL, 4467' FEL, Sec. 14, T13N, R10E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 558175, 6028948) (asp's 561258, 6025608) (asp's 561287, 6025601) ~sp~ 561309, 6025570) 6. Datum elevation (DF or KB feet) RKB 40 feet 7. Unit or Property name Miline Point Unit MPC-06 9. Permit number / approval number 184-2410 10. APl number 50-029-21257-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 5606' Production 8854' 8900 feet Plugs (measured) 7228 feet 8809 feet Junk (measured) 7145 feet Size Cemented 13-3/8" To Surface 179 bbls Class 'G', 490 9-5/8" bbls PF 'E' 7" 650 sx Class 'G' Measured Depth True Ve~icalDepth 115' 115' 5641' 4548' 8889' 7218' Perforation depth: measured Open Perfs 8457'- 8463', 8649'- 8666', 8678'- 8708' true vertical Open Perfs 6829' - 6834', 7000' - 7015', 7026' - 7053' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 NSCT to 8518' MD. Packers & SSSV (type & measured depth) RECEIVED FEB ? 2002_ Alaska 0il & Gas C(ms. Commission. And'~)mge 7" x 3-1/2" S-3 Baker Packer @ 8341', 7" x 3-1/2" FB-1 (85-40) Baker Packer @ 8490'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/23/2002 Subsequent to operation 01/27/2002 OiI-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 1288 1548 Casing Pressure Tubing Pressure 2489 3765 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG In)actor 17. I hereby certify that the foregoing is truce and correct to the best of my knowledge. ~~~~-.~:~~.~1~~)/ Title: Technical Assistant DeWayne R. S(~ifinorr Date February 271 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE"'~~'N~'~~~-~ Form 10-404 Rev 06/15/88 · ORIGINAL MPC-OS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/26/2002 WAG SWAP FROM WATER TO GAS INJECTION EVENT SUMMARY 01/26/02 PJSM. SAFED OUT & BLED DOWN SYSTEM. SUPPORT ROLLED BLINDS TO LINE UP FOR GAS INJECTION AND TOQUED FLANGES TO SPEC. MIRU HB&R. PT'd TO 4500 PSI. PUMPED 20 BBLS METHANOL DOWN THE TUBING @ 1 BPM, 3000 PSI & 2 BBLS DOWN THE FLOW LINE TO FREEZE PROTECT. PUT ON GAS INJECTION AT 1000 MCFPD. FLUIDS PUMPED BBLS DISCRIPTION 22 METHANOL 22 TOTAL Page I MEMORANDUM State of Alaska Alaska Oil and Gas COnservation Commission TO: THRU: Julia Heusser, Commissioner Tom'Maunder, P. I. Supervisor DATE: MaY 19, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne point Unit C Pad May 19, .2001' I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12/98 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy Supplement, I told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells #4,6 & 14 were shut in for repairs. SUMMARY: I witnessed SVS testing in Milne Point Field. ~ 2 wells, 24 components tested. 6failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS MPU C Pad 5-19-01jc Alasi~oii and Gas Conservation Commiss.~a Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme . AOGCC Rep: John Crisp, .. Submitted By: John Crisp Date: Field/Unit/Pad: Milne Point Unit C Pad Separator psi: LPS 140 HPS 5/19/01 Well permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI psI THp Code Code, Code Passed GAS or CYCI~E C-01 " i811430 140 100 110 p p , OIL C-02 1821940 C-03 ' ' 1820500 140 100 951 p ,, P , OIL C-04 1821260 140 100 110 P 4 , , 0IL rC-05A' 1842430 140 100 100 p P OIL C-06 184241'0 4300 2000 1950 P , 4 , WAG C.07 ' 1850020 'i40 100 95 P 4 OIL C'0~ ' 1850140' 4300 2000~ 1900 P 4 WA~[ C-09' 1850360 '140 100 '"105 p p ,, O~£: C-13 1850670 , C-14 '1850880 140 100 100 p ~ , OIL C-15 1851030 , , C-17 1852630 C-20 1890150 C-21 1940800 ,, C-22A 1951980 140 100 95 P P OIL C-23 1960160l C-25A 1960210: 43001 2000' 1900 P 4 WAG C-26 1952060 C-28 196029O , C-36 1980010 C-39 1972480 , , C-40 2OO2130 C-10 1850150 4300 2000 1850 p p ,,, , WAG 24 Failures: 6 Failure Rate: 25.00~90 Day Wells: 12 Components: , , Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor · ..OM' Petroleum Ihspec~r DATE: July 12, 2000 :Safety Valve Tests Milne Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV. failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested,: t failure. :5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate, 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kupamk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 Well Permit Separ Set L/P Test Test Test oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE C-01 1811430 140 100 95 p p OIL C-03 1820500 140 100 95 p p OIL c-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 p p OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL . C-13 1850670 C-14 1850880 140 100 100 p e OIL : C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 p p OIL C-23 1960160 C-25A 1960210 4000 2000 2000. P 4 WAG C-26 1952060 ,C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C~0~2~.,.~ 1821940 4000 1900 p p WAG ~ .... 1842410 4000 1900 p 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%[71 o0 ray Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leake& The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. Q/n mn Pa~e 1 of 1 V lv7irqm.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount '~~ Commissioner THRU: BlairWondzell ~ P.I. Supervisor t~/~oc~ FROM' John Cris¢ ~ ~. Petroleum Inspector DATE: October 1,2000 SUBJECT: Mechanical Integrity Tests BPX B,C,J,L Pads B-05i,C-06i,10i,J-02i,L-24i Milne Point Unit Milne Point Field NON~ CONFIDENTIAL Packer Depth Pretest Initial 15 Min. ~ 30 Min. Notes: Notes: Notes: Notes: Notes: B-05i 1851480 C-06i 1842410 C-10i 1850150 J-02i 1900960 L-24i 1950700 Interval Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I witnessed 5 successful M/T's. No problems encountered. I= Initial Test 4= Four Year Cycle V= Required by Variance ' W= Test dudng Workover O= Other (describe in notes) .I.T.'s performed: 5 Attachments: Number of Failures: 0_ Total Time during tests: 2 hrs. CC: MIT report form 5/12/00 L.G. MIT MPU B,C,J,L Pads lO-01-OOjc.xls 10/3/00 STATE OF ALASKA ALASKA-OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other Change to WAG Injector 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 665' NSL, 2289' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 2580' SNL, 707' EWL, Sec. 14, T13N, R10E, UM At effective depth 2733' SNL, 816' EWL, Sec. 14, T13N, R10E, UM At total depth 2733' SNL, 816' EWL, Sec. 14, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-06i 9. Permit Number / Approval No. 84-241 ¢'~;-/C~/ 10. APl Number 50- 029-21257 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8889' feet true vertical 7218' feet Effective depth: measured 8889' feet true vertical 7218' feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 13 3/8" 5606' 9 5/8" 8854' 7" Plugs (measured) Junk (measured) Cemented 0 R ! G i i",l A L MD TVD To surface 115' 115' 179 Bbls. Class 'G', 490 Bbls 5641' 4548' PF 'E' 650 sx Class 'G' 8889' 7218' Perforation depth: measured true vertical 8457'-8463',8649'-8666',8678'-8708' 6829'-6834',7000'-7015',7026'-7053' APR 2 0 3998 Tubing (size, grade, and measured depth) Packers and SSV (type and measured depth) 3 1/2" 9.3# L-80 to 8519' Alaska Oil & Ga~ Cons. Comrni[.i9.~ 7" x 4.5" Baker "S-3" pkr @ 8341' & 7" Baker "FB-I" pkr @ 8489' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water & Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ,~_,_/~_ ~ ~ Title Engineering Supervisor Date Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplicate~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO Well Name: MPC-06i Rig Name: N-4ES AFE# 339019 Accept Date: 07/19/96 Spud Date: . Release Date: 07/25/96 JULY 20, 1996 ACCEPTED RIG @ 1200 HRS ON 07/19/96. RIG UP, LEVEL DERRICK, BERM & SAFE OUT EQUIPMENT. TAKE ON 11.2 PPG BRINE & RIG HARD LINES TO TREE & TEST LINES TO 3500 PSI. PULL BPV. KILL WELL W/11.2 PPG BRINE & MONITOR WELL FOR 15 MIN ND TREE & NU BOP'S. TEST BOP'S TO 250 LOW & 5000 HIGH. TEST WAIVED BY DOUG AMOS W/AOGCC. JULY 21, 1996 REPLACE HCR VALVE ON KILL LINE. CONT TO TEST BOP'S 250 LOW & 5000 HIGH (WAIVED BY DOUG AMOS). BOLDS, PULL & LD HANGER SPOT 20 BBL ZANVIS PILL TOOK 12 BBL TO FILL HOLE. POOH LD 3 ~" TBG & ACCESSORIES. MU FTA #1 & RIH W/SAME ON 3 Y2" DP. CUT DRLG LINE. CONT TO RIH W/FTA #1. JULY 22, 1996 CONT RIH W/CENTER SPEAR. BRK CIRC ENGAGE SPEAR INTO PKR @ 8305'. RELEASE PKR 2/85K OVER JAR & WORK PKR FREE FROM LOWER PERMANENT PKR. CIRC OUT GAS & OIL INFLUX & WORK PKR HANGING UP & ELEMENT NOT RELAXING ENOUGH TO GET GOOD CIRC. POOH W/FTA #1 (NO RECOVERY). RERUN FTA #1 = FTA #2 & ENGAGE PKR @ 8305' POOH W/FTA #2 VERY SLOWLY DUE TO SWAB SURGES (FULL REC.) MU & RIH W/FTA #3 CUT DRLG LINE. CONT TO RIH W/FTA #3 MILL ON PKR @ 8494'. JULY-23, 1996 MILL ON PKR F/8494'-8496.50' (PKR FELL). RIH & TAG TOP OF PKR @ 8670' CIRC BU. POOH W/PKR & TAIL PIPE MU BHA #4 & RIH TO 8688' TAG FILL. REV CIRC @ 5 BPM & PLUGGED PIPE & CIRC LONG WAY & PIPE PLUGGED ATTEMPT TO UNPLUG NO SUCCESS. POOH W/WET STRING & FOUND PIPE PLUGGED ABOVE SCRAPER W/SLIP SEGMENTS & SAND & UNPLUG SAME. RIH W/BHA #4. JULY 24, 1996 TIH W/BHA #4. REV CIRC SAND & JUNK F/8688'-8782' (4ES KB). CIRC & CONT HOLE REV CIRC 40 BBLS, SWEEP & TOTAL LOSS OF 32 BBL POOH LD 3 Y2" DP. NU PERF FLG. WAIT ON WIRE LINE CREW (CLEAN RIG & INSTALL NEW PIPE RACK) RIG ATLAS LUBRICATOR & TEST TO 1000 PSI. MU 6" GR/JB & RIH W/SAME. JULY 25, 1996 RUN #4 FINISHED RUN W/6" GAUGE RING & JUNK BASKET TO 8600' POH RECOVERED RUBBER & CEMENT. RUN #5 GAUGE RING & JUNK BASKET TO Page 1 of 2 SUMMARY OF DALLY OPERATIONS 8600' POH MU BAKER MODEL "FB-I" PACKER W/TUBING TAIL ASSEMBLY & RIH & SET @ 8490' POH RIG DOWN ATLAS WlRELINE. ND PERFORATING NIPPLE & NU FLOW LINE RU FLOOR TO RUN 3.5" COMPLETION PULLED WEAR RING. MU BAKER 7" "S-3" PACKER W/STRADDLE ASSEMBLY. RIH W/3.5" 9.3# L-80 NSCT TUBING TO 4000" SLIP 42' OF DRILL LINE. FINISHED RIH W/3.5" COMPLETION ASSEMBLY. SPACE OUT SEAL ASSEMBLY IN PACKER. PRESSURE UP ON TUBING 500PSI TO VERIFY. MU HANGER & SPACE OUT PUPS & LAND TUBING ASSEMBLY. RILDS PRESSURED UP TO 500 PSI ON BACKSIDE TO VERIFY SPACE OUT, BACK OUT LANDING JT & SET TWC. NU BOP'S NU ADAPTER FLANGE & TREE, TEST SAME TO 5000 PSI PULL TWC. RU CAMCO RETRIEVING TOOL NEED TO RETRIEVE DUMMY VALVE BROKEN. WAITING ON TOOL FROM DEADHORSE TO ARRIVE. JULY 26, 1996 TEST LUBRICATOR TO 2500 PSI RIH & PULL DUMMY VALVE @ 8433'. POH TREATED W/COREXIT. REVERSED 55 BBLS OF DIESEL DOWN ANNULUS BULLHEADED 18 BBLS DIESEL DOWN TUBING. TEST LUBR TO 3000 PSI RIH & INSTALL DUMMY VALVE IN GLM @ 8433' POH & RIG DOWN CAMCO. DROP 1.313" BALL TO PKR SET PKR & TEST TUBING TO 5000 PSI F/30 MINUTES. BLEED TUBING TO 1500 PSI & TEST ANNULUS TO 5000 PSI FOR 30 MINUTES BLED ANNULUS TO 0 PSI & TUBING TO 1020 PSI. MU LUBRICATOR SET BPV. RD LUB. BLOW DOWN LINES & SECURE WELL. RIG RELEASED @ 1600 HRS ON 07/25/96. Page 2 of 2 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to WAG Injector 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 665' NSL, 2289' WEL, SEC. 10, T13N, R10E At top of productive interval 2581' NSL, 762' EWL, SEC. 14, T13N, R10E At effective depth 2706' SNL, 798' EWL, SEC. 14, T13N, R10E At total depth 2737' SNL, 819' EWL, SEC. 14, T13N, R10E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service Datum Elevation (DF or KB) Plan RTE = 39.6 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-06i 9. Permit Number 84-241 10. APl Number 50-029-21257 11. Field and Pool Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 8900 feet true vertical 7228 feet Effective depth: measured 8809 feet true vertical 7145 feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented 80' 13-3/8" 5606' 9-5/8" ORIGINAL To Surface 179 Bbls Class 'G', 490 Bbls PF 'E' 8854' 7" 650 sx Class 'G' MD TVD 115' 115' 5641' 4548' 8889' 7218' Perforation depth: measured true vertical 8457'-8463', 8678'-8708', 8649'-8666' 6829'-6834', 7026'-7053', 7000'-7015' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 8325' RECEIVED 1995 Packers and SSSV (type and measured depth) Camco TRDP-1A SCSSV at 1967'; BOT HP Packer at 8341'; 2B Packer at 8513' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation May 19, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Contact Engineer Name/Number: Ding Hsu, 564-5061 Prepared By Name/Number Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~~~., ~'~"T, ~ c,J*ll)'~l~,,l (~ Tim Schofield / Title Senior Drilling Engineer Date Commission Use Only IApproval No.?~ .~/~,~.~ Conditions of Approval: Notify Commission so representative may witness Plug integrity__ BOP Test~ Location clearance__ Mechanical Integrity Test ///"' Subsequent form ..r:~r~e~lJA-__/¥OL( Original Signed By Returned . Approved by order of the Commission 0avid W. Johnston -%-//'7/~ ,C. om?ssioner Date ~)'~--/~//~ Form 10-403 Rev. 06/15/88 Submit In Triplicate MP~'~-06i RWO SUNDRY INFORMATi'~N Objective- The objective of this rig workover is to convert well MPC-06i from a water to a WAG injection well with a new string of 3-1/2" 9.2# L-80 NSCT tubing and a 7" latch type packer. The existing straddle assembly will be removed and the Kuparuk "A" and "B" sands will be re-perforated to optimize the injection rate. The C pad WAG is critical for fulfilling future MPU gas disposal requirements and approximately 5 mmcfd of gas injection capacity is needed from MP C-6i. )) Scope- . Pre- rig: Obtained the static bottom hole pressure survey with Amerada gauges. Pulled the dummy valves from both GLMs @ 8,412'MD and 8,453'MD for well kill operation. Record SITP and SICP. Install BPV. Remove wellhouse and flowline for rig move. . MIRU Nabors 4ES workover rig. Perform well kill operation before ND tree and NU BOP. , Pull and L/D the existing 3.5" 9.2# L-80 BTC tubing with SSSV and seal assembly. Recover the straddle packers assembly. Clean out the weilbore to PBTD. 4. Re-perforate Kuparuk "A" and "C" sands as per program. 1 RIH with a 7" latch type packer and 3-1/2" tailpipe on the new 3-1/2" 9.2# L-80 NSCT tubing. Space out bottom of WLEG @ 8,350'MD and land the same. , Freeze protect the well before setting the tubing packer. ND BOP and NU tree. RDMO Nabors 4ES. Tlmincj: Nabors 4ES will move to C-06i on approximately June 1996. This workover should take approximately 12 days rig time. MIRU / Kill well/ND_NU 1.5 days Pull 3-1/2" old tubing and L/D same 1.5 days Fish Straddle assembly 5.0 days (Note: the fishing operation may encounter similar problem as MP C- 09 for retrieving the straddle packer--BOT "2-B" packer) Cleanout wellbore 2.0 days Complete well w/3-1/2" new tubing 2.0 days Total: 12.0 days DH, May 10, 1996, 5:46 AM NOTES: I. Ali MEASUREMENTS ARE FROM KDB OF ALASKA UNITED ~5 KDB-SL = 52' KDB-GL = 35' 2. MAX. Z. ,- 50.6' 0 5408' MD .3. K.O.P. -- 850' 4. SLANT HOLE: YES 5. MIN. / -- 24.7' @ TD 6. TREE TYPE: FMC .3 1/8', APl 5000i~ WITH 5 1/2' 8 RD. TREETOP CONNECTION. 7. MIN. RESTRICTION IS CAMCO 'D' NIPPLE @ 8537' (2.750' ID) 8. COMPLETION FLUID: 10.2 PPG NaCI-NaBr 9. FRACTURE STIMULATION: 7-22-85 LOWER KUP (2) 72.000 LBS 16-20 ISP PERFORATION DATA 12 SPF, 120' PHASING, 5' GUNS (ALL DEPTHS FROM DIL .LOG 1-21-85) MIDDLE KUP 8457'-8463' MD 6829'-6834' TVD LK-2 8678'-8708' MD - 7026'-7053' TVD 4 SPF, 180' PHASING, 2 5/8' GUNS (ALL DEPTHS FROM DIL LOG 1-21-85) LK-1 8649'-8666' MD 7000'-7015' TVD TAG RLL E-UNE ,3-5-87 8752'~ WELL No. C-6 COMPLETION SKETCH MILNE POINT UNIT (I) APl No.: 50-029-21257 PERMIT No.: 84-241 COMPLETED: 1/25/85 LAST WORKOVER: N/A FMC TUBING HANGER W/ 3 1/2' 'H° BPV PROFILE 1/2', 9.2# L-80 BUTTRESS TUBING (2.992' I.D.. 2.-867' DRIFT) 1967' CAMCO TRDP-IA SSA SCSSV (2.812' ID) RECEIVED MAY 1 x 1996 Alaska 01t & Gas Cons. Commission Anchorage 8325' BOT PBR, SEAL ASSEMBLY BOT 'HB' PACKER (2.890' ID) ~8379' CAMCO 'W-I' SELECTIVE NIPPLE (2.812" ID) 8412' CAMCO 'MMG-2' GAS LIFT MANDREL (GLM)=2.920" ID, 1.5" VALVES CAMCO GLM BLAST JOINT (17.$' TOTAL LENGTH, 4.50' OD, 3.OD' ID) 2'=C:L SEAL ASSEMBLY (4.5" OD. 3.00" ID) 3' BOT '2-B' PERMANENT PACKER (5.875' OD, 4.00" ID) WITH X-O END MILLOUT EXTENSION, (5.062' OD, 4.437' ID) 8537' CAMCO 'D' NIPPLE (2.750" ID) TUBING TAIL 8809' PBID (CASING MEASUREMENT) 8889' 7' 26J[ L-80 BTRS (6.276" ID, 6.151" DRIF CONOCO INC. ANCHORAGE DIVISION APPROVED BY: HDS DATE: 03/12/92 DRAFTED BY: SJN CAD FILE: WCOC6 FMC tubing hanger with 3.5" 'H' BPV profile. FMC 3-1/8~ tree with 3-1/2" 8 rd treetop connection. 13-3/8" 48# H-40 I J Conductor Casing 80' MD 9-5/8" 36# K-55, BTRC J5,64.~' MDJ Surface Casing KOP at 900' Hole angle 45-48 deg from 4,000-5,100' Max DLS 7.45 deg at 3,600' '-'lVi P U C-06i KDB-SL 52' KDB-GL 12' 2000' TVD diesel ~ Soume water with 25 gal/100 bbls Corexit 7726 corrosion inhibitor 3.5", 9.3#, L-80, with premium threads DRIFT ID --2.992', CAP=0.0087 BBL/FT STIMULATION SUMMARY 07/22/85 72,000# (8,649-8,708') PERFORATION SUMMARY REF LOG: DIL 01/21/85 JIE SPF MD TVD 12 8,457 - 8,463' 6,829 - 6,834' 12 8,678 - 8,708' 7,026 - 7,053' -5/8" 4 8,649 - 8,666' 7,000 - 7,015' ,, DATE 01/29/96 REV. BY RAE COMMENTS Planned IWAG completion Baker Model SAB-3 7' x 3-1/2' permanent latch-type packer with KBH seal assembly J MD I 3-1/2" X-N Nipple, 2.635" ID I MD I 3.5' WLEG IMD I WLEG set -100' above top perforation. PBTD 7', 26#, L-80 Butt. Csg j8,809' MD J ! IR CEIVED MILNE POINT UNIT WELL C-06i APl NO:'50-029-2 _~.__~yn 011 & BP EXPLORATION (AK) ~ .~ 199~ Ca~s. Commission NOTES: ALL MEASUREMENTS ARE FROM KDB OF ALASKA UNITED #3 KDB-SL = 52' KDB-GL = 35' MAX. /_. = 50.6' @ 3408' MD K.O.P. = 850' SLANT HOLE: YES MIN. /_ = 24.7' @ TD TREE TYPE: FMC ,3 1/8", APl 5000# WITH 3 1/2" 8 RD. TREETOP CONNECTION. MIN. RESTRICTION IS CAMCO 'D' NIPPLE @ 8537' (2.750" ID) COMPLETION FLUID: 10.2 PPG NoCI-NoBr FRACTURE STIMULATION: 7-22-85 LOWER KUP (2) 72,000 LBS 16-20 ISP PI~RFORATION OATA 12 SPF, 120' PHASING, 5" GUNS (ALL DEPTHS FROM DIL LOG 1-21-85) MIDDLE KUP 8457'-8465' MB 6829'-6834' TVD LK-2 8678'-8708' MB 7026'-7055' I'VD 4 SPF, 180" PHASING, 2 5/8" GUNS (ALL DEPTHS FROM DIL LOG 1-21-85) LK-1 864.9'-8666' MD 7000'-7015' TVD TAG FILL E-LINE 5.3-5-87 8732'~ I "-'/(¢ o ¢ WELL No. COMPLETION MILNE POINT C-6 SKETCH UNIT (I) APl No.: 50-029-21257 PERMIT No.: 84-24-1 COMPLETED: 1/25/85 LAST WORKOVER: N/A FMC TUBING HANGER W/ 5 1/2" 'H' BPV PROFILE --5 1/2", 9.2// L-80 BUTTRESS TUBING (2.992" I.D., 2.867" DRIFT) --1967' CAMCO TRDP-IA SSA SCSSV (2.812" ID) --8525' DOT PBR, SEAL ASSEMBLY 8541' DOT 'HB' PACKER (2.890" ID) 6,'"'/'3% T¢.~ ~,~'~ 'TGS~ ~'5% ~8579' CAMCO 'W-I' SELECTIVE NIPPLE (2.812" ID) 8412' CAMCO 'MMG-2' OAS LIFT MANDREL (0LM)=2.920" ID, 1.5" VALVES 8455' CAMCO GLM 8463' BLAST JOINT (17.5' TOTAL LENGTH, 4.50" OD, 5.00" 8512' C.L. SEAL ASSEMBLY (4.5" OD, 5.00" ID) 8515' BOT '2-B' PERMANENT PACKER (5.875" OD, 4.00" .ID) WITH X-O END MILLOUT EXTENSION, (5.062" OD, 4.457" ID) 8557' CAMCO 'D' NIPPLE (2.750" ID) 8540' TUBING TAIL 8809' PBTD (CASING MEASUREMENT) 8889' 7" 26# L-80 BTRS (6.276" ID, 6.151" DRIFT) CONOCO INC. ANCHORAGE DIVISION APPROVED BY: HDS DATE: 03/12/92 DRAFTED BY: SJN CAD FILE: WCOC6 STATE Of ALASKA · ALA'%"KA OIL AND GAS CONSERVATION COMIt~'gSION Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 1. Type of Request: Abandon . Suspend Operation shutdown Re.enter suspended well Alter casing __ Repair well M Plugging_ Time extention Stimulate__ Change approved program __ Pull tubing __ Variance x Perforate __ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development 59' KDB feet 3. Address Exploratory 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic Milne Point Unit Service X 4. Location of well at surface 8. Well number 665' FSL, 2289' FEL, Sec. 10, T13N, R10E, U.M. C-6 At top of productive interval 9. Permit number 2581' FNL, 762' FWL, Sec. 14, T13N, R10E, U.M. 84-241 At effective depth 10. APl number 2706' FNL, 798' FWL, Sec. 14, T13N, R10E, U.M. 50-029-21257 At total depth 11. Field/Pool 2737' FNL, 819' FWL, Sec. 14, T13N, R10E, U.M. Kuparuk River Field 12. Present well condition summary Total depth: measured 8900' feet Plugs (measured) true vertical 7228' feet Effective depth: measured 8809' feet Junk (measured) true vertical 7145' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 13-3/8" To Surface 115' 115' Surface 5606' 9-5/8" 179 bbl Class G 5641' 4548' Intermediate 490 bbl Permf E Production 8854' 7" 650 sx Class G 8889' Uner Perforation Depth: measured 8457'-8463'; 8678'-8708'; 8649'-8666' true vertical 6829'-6834'; 7026'-7053'; 7000'-7015' -r'0t%S' Tubing (size, grade, and measured depth) 3-1/2" 9.3#/ff, L-80, 8325' Packers and SSSV (type and measured depth) CAMCO TRDP-1A SCSSV @1967';BET HB Pkr @8341', 2B Pkr @8513' 13. Attachments Description summaryof proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: N/A 16. If proposal was verbally approved Oil__ Gas M Suspended Name of ap )rover Date approved Service Waterflood Injector _.~ 17. I hereby cef :ifythat ~e foregoing is true and correct to the best of my knowledge. /I, Signed (-~ ,,1il /,~V~ J.H. Andrew Title Production Engineer Date Nov 19, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. ~)/,/ Plug integrity BOP Test __ Location clearancei ~, -'~Z~'J_ '~'-" Mechanical Integrity Test Subsequent form required 10- ,~6~' ~,, ~-- ;?!- -'~, / Approved by order of the Commission L0.~]~.!{~_ C. $1~.~ITH Commissioner Date /,~ ~, ,~..1~ ,~, ~,~i i.,-~A-rr-- .. APPLTCATTON FOR SUNDRY APPROVALS Milne Point Unit C-6 Well The MPU C-6 well is an active water injection well. Pressure on the 3-1/2" x 7" production tubing-casing annulus is currently 2560 psig. This is in excess of the 500 psig maximum pressure guideline established by the Commission for continuous operation of injection wells. Conoco requests a variance to allow injection to continue while diagnostic work is performed. This work is necessary to determine the exact source of pressure communication in the water injection wells. Multiple attempts have been made to control the annulus pressure in the C-6 well by bleeding it off. The pressure can be bled to 500 psig in 10 minutes with less than 3 barrels of fluid extracted. However, annular pressure returns to previous levels within a few days. There has been no apparent improvement in either the build rate or final build-up pressure. The wellhead has also been tested. All seals were determined to be holding. This indicates the source of the pressure is downhole mechanical communication rather than thermal or ballooning effects. Three similar B-Pad water injectors have been worked over within the past four months to resolve similar annular pressure problems. New tubing strings were run in all three wells to eliminate the possibility of leaks due to corrosion and to replace the buttress thread connections with 8rd threads. New packer/seal assemblies were also run in two wells to ensure any leaking production seals would be isolated. Workovers in two wells, MPU B-14 and MPU B-17, were successful. Annular pressure has re-appeared in the third well, MPU B-12. It is not known why workovers were successful in the B-14 and B-17 wells, and not in the B-12 well. It is recommended that remedial work to resolve annular pressure in this well be deferred until the exact source of the communication in the B-12 well is determined. Our current plan is to run additional logs the B-12 well to isolate the leak. This information should enable us to design a workover program to successfully eliminate annular pressure in this well the first time rather than by trial and error. Additional testing is being planned in the interim period to. reconfirm annular fluids are not in communication with uncased hole. We will continue to keep the Commission informed of the results of all testing. SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY . ~,K '3'.CT., ~ GAS CONSgPVA:PiON CC--M.'.'4.T_SSTC, N LOCATION · ~001 PORCU~'~ DR A~ENTION · J'~'~N SCYL~ COMPUTING CENTER PRINT CENTER WELL NAME V/MZLNE POINT UNiT C-6 SERVICES . I PL ADVISOR REPjORr /'.~TTNI~' '~OTNT UNIT C-8 WELL NAME ' SERVICES ' 1 PL ADVISOR REPORT NO. OF BOXES' ALL IN ONE BOX JOB NO. . · 73975 ADD'L TAPES ' -- NO. OF BOXES' ALL iN ..ONE q ,¢ JOB NO. ' 739?4 ADD'L TAPES ' -- WELL NAME .M'MILNE 2OINT JNiT C-12 SERVICES · 1 PL ADVISOR REPORT WELL NAME ¢/ MILNE POINT UNIT C-Il SERVICES · 1 WF/PL ADVISOR REPORT NO. OF BOXES: ALL IN OHE BOX JOB NO. · 73959 ADD'L TAPES · -- NO. OF BOXES: ALL IN ONE BOx 'JOB NO. ' 73973 ADD'L TAPES · -- WELL NAME ' M!LNE POINT UN'"T C-18 SERVICES · ]. PL ADVISOR REPORT WELL NAME v"' M!LNE POINT UNiT ,2-15 SERVICES · 1 WF/PL ADVISOR REPORT NO. OF BOXES: ALL IN ONE ~C~.,~,~%\~9 NO. OF BOXES: AL' iN ONE BOX JOB NO. . 7-~c~a1 JOB NO. · 739~6 ADD'L TAPES ' -- ~~,$S'0~ ADD'L TAPES ' -- __ A~aSka 0~t & GaS -AnCbo¢~e SCHLUMBERGER COURIER: DATE DELIVERED: ~conoco~ Jilm PL ADVISOR Production Logs Interpretation Using a Global Solver (V3) MPU C-6 Company - CONOCO, INC. Field - MILNE POINT Logging date - JUL 15,1990 Processing date - JUL24,1990 Reference - 73975 Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 Alaska Oil & Gas Oons. ~O~T~,tSSCf~': Anchorage CONOCO, INC. Milne Point MPU Production Logs 15-J u 1-90 INTERPRETATION SUMMARY Data From Continuous Flowmeter Surface Injection Rate- 2500 BWPD Zone Injection Water % of Interval BPD Total GLMs 8400 - 8410 8440 - 8450 645 26.2 LK-1 8649-8666 630 25.6 LK-2 8678-8708 1185 48.2 E Total Injected Water 2460 100.0% Zone Water % of Total M. KUP 645 BWPD 26.2% LK - 1 630 BWPD 25.6% LK - 2 1185 BWPD 48.2% ®Surface injection pressure was 2300 psi. ®The water that is passing through the GLMs is going into the middle KUP (8457 8463). eThe well is deviated 51 degrees. 8400 8800 8700 8400 848o 8800 87OO ~o2 (DEGF) 1"¢2 I I CONOCO, INC. Milne Point MPU C- 6 Production Logs 15-Jul-90 COMPUTED CUMULATIVE INJECTION RATES At Down hole conditions Zone Depth Depth Total Water Oil Gas Global # DH Rate DH Rate DH Rate DH Rate Into- Feet Feet Bpd Bpd Bpd Bpd herence 1. 8730.0 8708.5 0. 0. 0. 0. 0.000 2. 8678.0 8666.5 1183. 1183. 0. 0. 0.003 3. 8649.0 8540.5 1811. 1811. 0. 0. 0.001 4. 8490.0 8448.5 1811. 1811. 0. 0. 0.019 5. 8442.0 8408.5 2240. 2240. 0. 0. 0.009 6. 8402.0 8350.5 2455. 2455. 0. 0. 0.002 COMPUTED FLOW DESCRIPTION Assuming a 1 - 11/16" tool presence Zone Water Gas Mixture Friction Liq/Liq Gas/Liq Inject # Holdup Holdup Density Gradient Slip vel Slip vel Regime Gr/cc Gr/cc Ft/mn Ft/mn 1. 1.000 0.000 0.970 0.000 0.00 0.00 Nolnj 2. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 3. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 4. 1.000 0.000 0.970 0.039 0.00 0.00 WATER 5. 1.000 0.000 0.970 0.058 0.00 0.00 WATER 6. 1.000 0.000 0.970 0.068 0.00 0.00 WATER CONOCO, INC. Milne Point MPU C- 6 Production Logs 15-Jul-90 PRODUCTION LOG MEASUREMENTS Zone Depth Spinner Thermo # #1 #1 Feet Ft/mn DegF 1. 8730.0 0.00 110.891 8708.5 105.401 2. 8678.0 25.36 98.048 8666.5 98.098 3. 8649.0 38.55 98.026 8540.5 97.742 4. 8490.0 162.74 97.488 8448.5 97.395 5. 8442.0 200.94 97.387 8408.5 97.377 6. 8402.0 219.97 97.341 8350.5 97.198 MEASUREMENT RECONSTRUCTION QUALITY Measured minus Reconstructed values Zone Spinner Thermo # #1 #1 Ft/mn DegF 1. 0.00 0.000 2. 0.01 -51.607 3. 0.00 -17.889 4. -0.04 -0.122 5. 0.02 -9.559 6. 0.00 -4.366 CONOCO, INC. Milne Point MPU C- 6 ~-~ Production Logs 15-Jul-90 PL Advisor Program Parameters for Zone 1 (at downhole conditions) Zone bottom depth ................................................ 8730. Feet Zone top depth .................................................... 8709. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 51.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 4670. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 150.0 DegF Minimum water rate .............................................. 0.0000 Bpd Maximum water rate ......................... : .................... 0.0000 Bpd Continuous flowmeter # 1 Blade diameter ........................ ~ ............................ 1.688 Geometrical factor ................................................ 0.5190 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF PL Advisor Program Parameters for Zone 2 (at downhole conditions) Zone bottom depth ................................................ 8678. Feet Zone top depth .................................................... 8667. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 51.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 4670. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 149.7 DegF Minimum water rate ............................................... 1183. Bpd Maximum water rate ............................................... 3000. Bpd Continuous flowmeter # 1 Blade diameter ................................................... .. 1.688 Geometrical factor ................................................ 0.8470 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF CONOCO, INC. .~ Milne Point MPU C- 6 Production Logs 15-Jul-90 PL Advisor Program Parameters for Zone 3 (at downhole conditions) Zone bottom depth ................................................ 8649. Feet Zone top depth .................................................... 8541. Feet Pipe internal diameter .............................................. 6_276 Inches Pipe Deviation ..................................................... 51.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 4670. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 149.3 DegF Minimum water rate ............................................... 1811. Bpd Maximum water rate ............................................... 3000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8530 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft./mn DegF PL Advisor Program Parameters for Zone 4 (at downhole conditions) Zone bottom depth ................................................ 8490. Zone top depth .................................................... 8449. Pipe internal diameter .............................................. 2.992 Pipe Deviation ............ - ......................................... 51.00 Pipe absolute roughness ........................................... 0.0006 Average injection pressure .......................................... 4670. Water density ..................................................... 0.9700 Water viscosity .................................................... 0.7200 Reservoir fluid temperature ......................................... 148.0 Minimum water rate ............................................... 1811. Maximum water rate ............................................... 3000. Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8880 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Feet Feet Inches Degrees Inches Gr/cc Cp DegF Bpd Bpd Inches Ft/mn DegF CONOCO, INC. Milne Point MPU C- 6 Production Logs 15-Jul-90 PL Advisor Program Parameters for Zone 5 (at downhole conditions) Zone bottom depth ................................................ 8442. Feet Zone top depth .................................................... 8409. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 51.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 4670. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 147.3 DegF Minimum water rate ............................................... 2240. Bpd Maximum water rate ............................................... 3000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8900 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/m n DegF PL Advisor Program Parameters for Zone 6 (at downhole conditions) Zone bottom depth ................................................ 8402. Feet Zone top depth .................................................... 8351. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 51.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 4670. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .......................... .' ......................... 0.7200 Cp Reservoir fluid temperature ......................................... 146.9 DegF Minimum water rate ............................................... 2455. Bpd Maximum water rate ............................................... 3000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.8910 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF /~]LNE POINT UNIT C-6 CO/~PLETEO ON / -25-85 I I trAX. ANGLE · 58.6 ii 3408' F~C~P · 850' TREE V/ ~ ,/~ xu. TREETOP CONNECT I ON · l:"l' ION Ft.I.Ii~ · F~ NoCl/NoI~ CAliCO TRDP 9~V?'(ID · 2..812 ) 8341' BOT 'HB' 1 ~. 89 ID I PACKER ~ l~.9' CA/',CO V- 1 ECTIVE NIPPLE 812. ID I 8412'DCA~.2 'AAG-2' GLA (I .921 8453'GL~ PERFORATIONS' 8463' BLAST JOINT lid · 3.01 8512' BOT Ct_ LOCATER EEAL A$SEAB_Y 8513' BOT '2B' F'EmAI, ENT PKR. V/ X-O Am ~ILLOUI' EXTENSION (6.2,76 lB. .151 DRIFT Pouch Prudhoe Bay, AK 99734-0069 A~tn: BernJ e/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 A~ent;on' Marc Shannon C~ent[emen. E~o~ed ore_2_RL_pr;nts of the Company CONOCO, Inc. Injection Profile Log, Run 1, 7/15/90 ~'ell MAlne PoAj~t Unit C-6 F~e[d MJlne Po~nt A~Sitio~o! prints ore be;q~ ~mt to: 1 Bi pr;nfs CONgCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George L~mb - OF 2018 PER County Nort? Slope Stote Alaska ~r;nts , 1 RF SepJ. a CDNF)CO; Tr, r_ lO00 South Pine Ponca City, OK 74603 Attn: Log Library 1 BL pr;nfs, 1 RF Sep~.a OXY U.S.A., Inc. 6 Defte Drive M~dland, TX 79710 At,n: John C~rro] *(_91 5/685-5600) 1 BL prints, 1 RF Sepia Chevron U.S.A. 6001 Bo]!Jnger Car:yon Road San R~mc.n; CA 94583-0943 Attn: FrJscJlln MscLeroy *(415:'842-tO00) /3001 Forcupine Drive / / Anchorage ~ 99501 Attn: John Boyle ~ -"T~f~is returned to Conoco, Log Library. V,~e oppreciote the privilege of ~e~;r~g you. pr;nfs prints prints Ve~ truly yours, SCHLUMBERGER WELL SERVICES I. .. 344-3323 FROM ADDRESS CITY '- STATE ZIP SHIPPER ,-. <'-'7--'? DATE '.'? /: > .---/.'/ TIME ',"7',, ADDRESS ~ ,~ :- . ' STATE CITY ZIP ATTENTION '-~: '.. ,' z~ -' ~--I-~-.-'' '/~' PHONE .- " INSTRUCTIONS ..... :- --L ...... ~ 24 HOUR -' ..... ' ' SAME DAY' ' :'-'-" !i:_":'!-';.i . '1--1 P/U BY 3PM ONE HOUR $ SAME DAY $ 24 HOUR $ OTHER $ TOTAL $ CASE NO. .. COURT - .- ¢-. - DOCUMENTS [] ONE HOUR XI DATE /I- TIME conoco ) Tom Painter Division Manager Conoc~ Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Mi!ne Point Unit. There are 19 active and 5 inactive production wells at Mi!ne Point. ACTIVE: B-3, B-4A, B-6, B-9, B-10, ~-~I, x-!3 ~-!~ B-16 .... 16 C-l, C-2, C-3, C-4, C-5A, C-7, 9 ~ C- C- STATIC: B-20, B-21, B-22 C-i7, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil =~ix~ure. The annular fluid levels will be monitored for le=~:~ gas lift valves. necessary the production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Xilne Point Unit ~ ~ ~'; ~ ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-11, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix° The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix ~iil be used to carry the inhibitor. I= you have any questions on the shutdoum procedure ~iease contact Don Girdler at 564-7637. Yours very truly, Painter ~V O ~ ~' /~v.~si . ~.anager //! \.-~ STATE Of ALASKA ALASN--OIL AND GAS CONSERVATION COMk,_.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Otheri -~'¢,,~ 2. Name of Operator Conoco Inc. 3. Add~e¢¢1 C Street, Ste. 200, Anchorage, Alaska 99503 4. Location of well at surface 665' FSL, 2289' FEL, Sec. At t~5 of productive interval 81 FNL, 708' FWL, Sec. At effective depth N/A At t~¢~P~L, 819' FWL, Sec. 10, T13N, R10E, U.M. 14, T13N, R10E, U.M. 14, T13N, R10E, U.M. 5. Datum elevation (DF or KB) 59' KB feet 6. Uni:~,or, Prop,.,erty qam,.e .. mmzne rozn~ unz[ 7. Well number C-6 8. Permit number 84-241 9. APl number 50-- 029-21257 10..POO~uparuk River 11. Present well condition summary Total depth: measured 8900 feet true vertical 7228 feet Plugs (measured) Effective depth: measured N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural Conductor 80' 16" To Surface 115' Surface 5605' 9 5/8" 2275 Sxs 5641' Intermediate Production 8855' 7" 650 Sxs Liner Perforation depth: measured 8457'-8463'; 8649'-8666'; 8678'-8708' true vertical 6829'-6834'; 7000'-7015'; 7026'-7053' Tubing (size, grade and measured depth) 3~"2, L-80, 8502' Packers and SSSV (type and measured ~pRth) SCSSV @ 1967' ~ue Verticaldepth 115' 4547' 8889' 7238' ; Ret.- Pkr. @ 8341'; Perm. Pkr. @ 8513' 12.Attachments Description summary of proposal/~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I herel;~y-c~rtify thitt the foregoing is true and correct to the best of my knowledge Signed -- ~.~----- ~ -)~/~_~ ~x~ L~ Title Sr '~ '1" ¢'~ ~'~ 1 "1 ~"~ '~" 4 ~*'~ 1~ '1~I 'r~ ~r 4 .... Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP 'r_est,..~_.~ Location clearanceI No. Date ,. Approved by =orm 10-403 Rev 12-1-85 Commissioner by order of lq/..,, ~ r?* '/~/_*i I the commission Date/.~_.r/_., ~ Subrhit in 'triplicate ~... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO]~[MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~ OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 84-241 3. Address 8. APl Number 3201C Street, Suite 200, Anchorage, Alaska 99503 5o-029-21257 4. Location of Well 665' FSL, 2289' FEL, Sec 10, T13N, RIOE, U. H. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number 11. Field and Pool Kuparuk River 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 12-13-85, and its suspended status should be removed. 14. I hereby certify that the f?regoing is true and co,~rect to the best of my knowledge. S ig n e,e~'~~ ........ ~" ~~'~' '~'' ' Title ~~~~ The s~~mmission use ~ o~proval, ~ By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 84-241 3. Address 8. APl Number 3201C Street, Suite 200, Anchorage, Alaska 99503 50-029-21257 4. Location of Well 665' FSL, 2289' FEL, Sec 10, T13N, RIOE, U. M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB I 6 . Lease Designation and Serial No. 47434 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 12-13-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed'The ,",~'~''bel~r Commission use Title ~.. -"~ ~-__~~ Conditions o~Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent R. eports" in Duplicate John R. Kemp Manager of Alaskan Operations January 7, 1986 Mr. Robert Burd, Director U.S.E.P.A. Water Division, Region X 1200 Sixth Avenue, M/S 409 Seattle, Washington 98101 Conoco Inc. 3201 (2 Street Suite 200 Anchorage, AK 99503 Dear Mr. Burd: Attached please find a completion report for Milne Point Unit Wells C-6 and C-15 which were issued emergency injection permits in accordance with 40 CFR 144.34(a)(3) on December 21, 1984. Also included are geophysical logs and wellbore diagrams. Thank you for your timely response to our urgent business. Please call Rod Schulz at (907) 564-7633 if you have any questions. I certify under the penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment. Division M_an~ ager Anchorage Division RRS/slt Att cc/att: Hr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 . uao Cons, Commission Alaska Oil & ~'" Anch0ra{j~ · UNI]'F"' STATES ENVIRONMENTAL PROTECTION AGENCY Form Aooroved -- WASHINGTON. DC 20460 OM8 No. 2040-0042 a'~ ,~,~ COMP'LE:~'0N REPORT FOR BRINE DISPOSAL. 4p~rovB, e ..... sS-aO-~ -' '%~--'" HYDROCARBON STORAGE. OR ENHANCED RECOVERY WELL , NAME AND ADDRESS OF EXISTING PERMITTEE NAME AND ADDRES~ OF SURFACE OWNER Conoco Inc. 3201 C Street, Suite 200 State of Alaska Anrhnrng~; A1 ~.~1<~ gg.50.~ LOCATE WELL ANO OUTLINE UNIT ON STATE I COUNTY i PERMIT NUMBER SECTION PLAT -- 840 ACRES __ AKI North Slope Borough! AK-2 ROO78-E N SURFACE LOCATION DESCRIPTION i I I I I i i ]qW '4OF fiW '4OF SE '~SECTIO. 10 TOWNSHIP 13N RANGE 10E' I I I ' --~-- I ~ LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION AND DRILLJNG UNIT i . I I I I I I Loc_~no, ~ 0 ~ ft. from (N/S) ..._~__ Line of quarter section ! I I -1- I I a~.8__._ 9..ft. ~rom(E~. F. Uneo~qua.er I I I I I I WELL,COWrY ~"EOFPERM,T W j t I I I J E ["] Brine D/sm)sol [] Individual Estimated Fracture Pressure __ I I [ _L_J_.._L_ i~l E.l~a.ced Roc~vmV [] Area of Iniection Zone I i I I J I ["] Hydrocarbon Storaqe Number of Wel,s --23 O' 75 p $ i / ~ t I I I x Ave,a , Ma,,,mum Fee, ,o i I a I 3000 lo,ooo 8457I 8708 S Ant/create,ti Daily. Inject,on. .Pressure IPSll, , DeDth to 8otlom of Inwermost Freshwater Formal,on Average I Max,mum (Feet) 19~QI, ?,5~ 3,100' (See UTC Permit) Type of Inlect~on Fluid [¢hec~ the a/~Drol~iate b/octf$# Lease Name i Well Number ~Sa,,Wate. ~arackishWaler ~]Fres. Water Milne Point UnitI, [-] Liclu,d Hydrocarbon D Other Name of Iniect,on Zone Kuparuk River Data Dr,Il,n0 Beg. an I Dale Well Comoleted PormeaD,ht¥ of Injection Zone t/11/85I 1/25/85, 60 - 300 md Dale Drflhng Comolete~l ' · I Porosity of Injection Zone , 1/21/85I 2O70 I CASING AND TUBING I CEMENT HOLE OD S,ze l VV~/F, _ Gr,,de __ New or Used I DeathI Sacks Class I Depth Bit Diameter 13 3/8" 48# - H 40 - New 80' ITo Surface Artic GradeI 100' 17~" 9 5/8" 36# - L 80 - New 5~641'i 1400 Permafrost t 5645' 12-~" 875 G 7" 26# - L 80 - New 8~889' 650 G 8900' 8~" I INJECTION ZONE STIMULATION WIRE UNE LOGS. LIST EACH TYPE Interval Treated Mater,als and Amount Used Log T~pes Lo, ged Intervals 8678 - 8708 72000 lbs. 16-20 US Mesh SP-DIL-SFL 5643 - 8706 ,proppant and 50000 gals LDT-CNL-GR-CAL 8100 - 8690 lwater base gel t i GR-C'NL in csg 4600 - 5643 I CERTIFICATION / cern'fy under the pena/tF o! law that I have persona/if examined and em !am/tier with ~/~'e i~r~n submined in this document end all attachments and that, based on my inquiry of ~h°Se /nd/v/duals ,, mlTIISSIO~ immediately responsible for obtaining the information. I believe that the infor~?~.,~onj$ true~::'a~a~! " and complete, i am aware that there are s/.c;Tificant penalties for submitting fa/se informati8499iif~J;3ding the possi.hility of f/ne and imprisonm,.nt. (Ret. 40 CFR 1~4.32). NAME AND OFFICIAL TITLE [Please type o! JOHN R. KF. HP DATESIGNED · ANCHORAGE DIVISION HANAGER ~/-' rn 520-10 C-6 ATTACHMENTS Be De See attached casing and completion sketches. Pressure tested 9 5/8" casing to 1,500 psi for 30 minutes with no bleed-off. Pressure tested casing-tubing annulus to 1,500 psi for 10 minutes with no bleed-off. Pressure tested tree to 5,000 psi for 10 minutes with no bleed-off. A report was submitted on May 15, 1985, which was approved on June 21, 1985. No defective wells. Included are final prints of the SP-DIL-SFL and GR-LDT-CNL-CAL logs. Alaska Oit & 6as 6ohs, Commiss[o~ ,m ! MILNE POINT UNIT O-6' ACTUAL COMPLETION ;~KETCH COMPLETED 0N"1-25-85 · NOTES: 1. All mealuramontl ire from KDB of AIoBko Unllld ~3 I. KDB - 8L · FMC TU~NO HANGER ,. KDB - GL · 35' 4. Mix. ingle 50.6° at 3408' MD 5. KOP et 850' 3 I/2", 9.2~ L-80 Buttrees tubing (2.992" ID, 2.867" drift) 8lint type hole YES Min. angle · 24.7°(~ TD ~ 1967' CAMCO TRDP-IA $SSV I. FMC $ 11t' APl 80008 tree with 3 1/2' 8 rd. treetop oonnootlon. e. Min. raetrlotlon Il CAMCO 'D' Nipple at 8557' (ID, 2.750") 10. APl No. ~0-029-21257 1 1. ComlMatlon fluid 10.2 pp~] NoCI-NoBr Oiling and cement information luDpll®d on oiling and edmont ekotoh. Alaska Oil & Gas r, ,,o~s. 6omm[ssior[ . A~chora¢e PERFORATIONS 12 SPF, 120° I~e~l~, ~ ~u~ DII. Io9 I-2t-85) MIDOLE KUP 8457'-8463' MD 6829°-68:34~ TVD LK-2 8~78'-- 8708' MO 7026'-7053' TVD (All depthe from 4 SPIr, leo° ~a~l~, 2 5/e" gu~ (AJI d.ep..th~ ~o~ mL ~o~ ;-2~-e~) 8525' BOT PBR, Seal 8:~41' eOT 'HB' packer (2.890" lO) 8379' CAMCO 'W-I' Selective Nipple (P_81:5" ID) --8412' CAMCO 'MM{3-2' G<~ Uti Mandrel (GL.Mi · 2.920" ID, 1.5" volvee 8453' CAMCO GLM --8465' Bla.t Joint [17.3' total langth, 4.5" OD, $.00" ID) LK-I 8649'-8666' MD · 7000'-7015' TVD C.L. Seal Assembly {4.5" OD, 3.00" ID) · --------8515' BOT '2B' Permanent Packer (5.875"00, 4.00"ID), with X-O end millout extension (5.062"0D, 4.457'1D) ORIGINAL N·¥1IIONI Dr/Ok · PBTD ~-~ 8807' -- 8540' · , CAMCO ' D' Nipple (,?..750" ID) Tubing toil 7"t 26;~ L-80 Butlrlse ~ .. , : 8889' (6.2'/1S" ID, 6.151" drift) MILNE POINT UNIT ~.Z.6 (T) :¥ OPERATOR: CONOCO, INC. SURFACE LOCATION: 665' FSL, 2289' FEL, Section 1©, T13N, R10E BOTTOM HOLE LOCATION: 2737' FNL, 819' FWL, Section 14, T13N, R10E SPUD DATE: 01-12-85 NoTEs: 1. All measurements from K DB of Alaska United #3 2. KDB - SL ='-5~' 3. KDB - GL = 35' 4. Max. angle= 50.6° @ 3408' MD 5. KOP at 850' 6. Slant type hole - YES (min. angle at .. .. TD = 24.7°) 9 5/8" Surface Casing / '' ~_~-~_/x~ Es t. TOC ".' '/: 'a 6000'+* ECP 8477' ECP 8572' 7' at 8889' 1. Pumped 36 Bbls of 11 ppg Sepiolite spacer for pre-flush. 2. Pumped 490 Bbls (1400 sx) of 12.3 ppg Permafrost Type "E". 3. Pumped 179 Bbls (875 sx) Class "G" cement with 1% CFR-2 and 1% CaC12. 4. Displaced with 409 Bbls of 9.4 ppg mud. NOTE: Lost returns after circulat- ing out 43 Bbls cement. Re- ciprogated casting during job. Centralizers 1 per 40' 80'- 2400' 1 per 80' 2500'- 4500' 1 per 40' 4500'- 5620' 7" Production Casing 1. Pumped 40 Bbls of Halliburton Desco preflush. 2. Pumped 133 Bbls (650 sx) Class "G" -- cement with 1% CFR-2 and 0.3% Hal-24. 3. Displaced with 336 Bbls 10.2 ppg NaC1-NaBr. Centrali.zers 1 per 80' 40'- 8460' 1 per 40' 8460'- 8887' Alaska Oil & Gas Oons. A = Arctic Pak (60 bbls) B = Arctic Set I ( 180 sx ) C = Mud and Spacer i' " N SCALE IN CONOCO MILN[ POINT UNIT EXISTING DEVELOPMENT NOTES: I. STATE PLANE CO. ORDINATES ARE .-~C'NE 4. Z. ALL GEODETIC POSITIONS ARE BASED O~ N.A.D. 1927.' oFFSETS TO SECTION LINES ARE COMPUTED BASED-ON PROTRACTED VALUES OF T~E SECTION CORNER POSITIONS. LOCATION IN SECTION STATE PLANE C0-ORDS. FROM S. t.IN[r F"R0e~ E. UNE NORTHING'~ EASTINGS II 68' 2256' 6,029,450.20 558,203. 57 1229' 245 9' 6,029,509.93 557,999.98 1395' 2326' 6 ,029 , 677.42 558,151.06 1'3 4 4' . -2494' 6 , 029,624.27 557,963.42 551' 2254' 6 ,028 ,834-07 558 ,211 .74 665" 2289' 6 , 028,947.80 558 , 175.18 1009' 2396' 780' ' 2325' c-B! 6 ,029 ,290.40 558 ,065.29 6,029,062.00 558,158.49 4. LOCATED WITHIN SECT. 10, T 13 N, RIOE, kLM., AK. GEODETIC POSITION LONGITUDE 149O 31" 27.056"W' LATITUDE ,, 70029' 27. 8SB"N. "t0029' 2~. 471" N. 149° 31' 3~034"W'. 70°29' 30. 108"N. 149°31' 29.137"'W. ~o29, 29.598",. i4¢ :~,' ~4.'o8~"~,. 70029, 21. 807"N 149° 31' 26.cJ~7."Uf. 7o°29' ~ .929". 149° 31' 28.007"W. 149° $1' 31. 162 "ti/. 1490 31' 29,060"W. 700:'9, 26. 307"N 70°29' 24.055"N. Ill 4' 2428' 6 ,029,395.22 558 ,031.82 70°29' 27.340"N. 149 894' 2360' 6,029 , 176.48 5.~8 , 101.82 70° 29' 25.184"N. 149°,.N' 30. 113" W. CERTIFICATE OF SURVEYOR : ~ ~ ~"J ~:~ ".~ I HEREBY CERTIFY THAT .I AM P~OPERLY ~"..d'-~ ~--~. ~'~ -- ...:~ ~[G~ST[RED ~D L~CENSED TO PRACTICE .4 ~ ~ ' CHECt(E~ FIELD BOOK 22 -85 24 - 84 I OATE i 6. I ,85 J.B.S. I 10.30,84 d. BJ. I * ' t.. m~ · I 6. I, 85 · · :'2 -85 'C' PA D AS- BUILT WELL LOCATION Su~.veyed for CONOCO SCALE : I SHEET : I' · 400' COUMENTS: ',.. STATE (.)1': ALASKA ALASKA '_ AND GAS CONSERVATION Ge MISSION ONTHLY REPORT' OF DRILLING AND woR"' OVER OPERATIONS - 2. Name of operator 7. Permit No. Conoco Inc. 84-241 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21257 4. Location of Well at surface 665' FSL, 2289' FEL, Sec. 10, T13N, RiOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' 6. Lease Designation and Serial No. ADL 4743/~ For the Month of _Tu!y ,19 85 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 6 11. Field and Pool Kuparuk River Field Kuparuk River 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Pumped 250 bbls. injection test w/180 bbls. X-linked. Frac gradient was Waited 2 hours then ran temp log. Pumped fracture stimulation: 971 bbls. of gel, 72000# 16-20 isp. · 76 psi/ft. 13. Casing or liner run and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run HP/Temp-press and CCL Ran tie-in log 16. DST data, perforating data, shows of H2S, miscellaneous data NONE. Well suspended. RECEIVED AUG 9 985 Alas~;a Oil i~ ~-~.~ ,,, .... ..... o. u0mrrl/ssJ0r/ Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on 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 Submit in duplicate Rev. 7-1-80 John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street ~uite 200 Anchorage, AK 99503 (907) 664-76O0 August 13, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. C-5, C-6, C-8, and C-10. These are being sent in response to your request dated August 2, 1985. If you require additional information concerning these well histories, please contact Kent Stolz at 564-7641. Very truly yours, tions DRILLING WELL COMMENCEMENTS Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 6 -CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-I087 1-11 - AP1 No. 50-029-21257. Ak. Permit No. 84-241. Elevation: 52' KB Location: 665' FSL, 2289' FE~, Sec. I0, T13N, RiOE, U.M.- Skid rig to C-6 (broke some rollers and cinch lines). Skid pipe shed. Set down BOPE, RU cellar. Install Tanko starting head. Hook up all drain line to cellar. NU 20" Hydril and diverter lines. Pump mud from tanks. RU hydraulic valve in diverter system. NU Bell nipple & flowline. Mix mud. Alaska United Rig #3 (0-0-0) Drlg. Foreman - R. Larkin . · Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% -Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-1087 API No. 50-029-21257. Ak. Permit No. 84-241. Elevation: 52' KB Location: 665' FSL, 2289' FEL, Sec. 10, T13N, R10E, U.M.- 1-12 - NU. Function test hydraulic valve & Hydril. Work on rig & prepare to spud. PU BHA. Test 20" Hydril to 100 psi. Drld. ice & cmt. to 80'. PU & service MWD, orient same. Drld to 121', had excessive pump pressure after PU HWD. POOH, checked bit for plugged jet (o.k.). Check float & MWD (o.k.), orient MWD to bent sub. Orient bent sub to dot sub. Drlg. @ 980'. Surveys: Depth Ansle Direction 495' 0° 850' 0° 927' 1.3° S82E 1-13 - Drld, surveyed & oriented to 1400'. Lubricate rig. Drld, surveyed & oriented to 1909'. Ran wire]ine checkshot. Drld, surveyed & oriented to 2528'. Short trip 15 stds. Circ. POOH & change BHA. o Surveys: Depth Angle Direction Depth Angle Direction 1018' 3.8° S67E 1839' 24.5° S49E 1100' 6.8° S65E 1930' 27.1° S51E 1198' 9.1° S65E 2023' 30.3° S5iE 1289' 11.7° S60E 2110' 33.2° S48E 1350' 14.0° S61E 2203' 33.9° S46E 1472' 16.0° S50E 2296' 35.1° S49E 1562' 19.3° S52E 2391' 38.0° S52E 1716' 22.5° S47E l-IL - PU BHA & service MWD. TIH w/packed hole assembly. Drld. & surveyed to 3152'. Service rig. Drld. & surveyed to 3274-' & POOH. Change BHA & TIH w/angle dropping assembly. Dr].d. & surveyed to 3528' & POOH. LD BHA & PU BHA. Service & orient MWD with bent sub. TIH w/NaviDrill & bent sub. Drld. & survyed to 3615'. Surveys: Depth Angle Direction Depth Angle Direction 2578' 40.8° S52E 3154' 48.8° S48E 2886' 45.7° S55E 3280' · ~ 49.6° S43E 3037' 47.2° S49E 3-346' 50.0° S44E 3095' 47.9° S49E '3408' 50.6° S44E Mud Wt.: 9.3 ppg. Visc.: 37 Alaska United Rig #3 (0-3-0) Drlg. Foreman - D. Mount joy Kuparuk River Field-- N~th Slope Borough, Alaska W.~ - 52.05955% Mi]ne Pt. C No. 6 - COI.~._.D.ENTIAL (8452'-Kuparuk River) ~..~FE 10-61-1087 1-15 - Drld. & surveyed to 3753'. Ran wireline survey @ 3753 to check PB~D. Drld. & surveyed to 3792'. POOH & change BHA. TIH w/packed hole assembly. Ream f/3662'-3792'.~ Drld. & surveyed to 4072'. Drop survey, pump slug & POOH. Change BHA & check MWD. TIH w/angle dropping assembly. Ream 30' to bottom. Drld. & surveyed to 4686'. Surveys: Depth Angle Direction Depth Angle Direction 3346' 50.0° S46E 4082 45.7° S~8E 3563' 48.8° S50E 4144' 45.0~ S54E 3743' 41.8° S52E 4269' 45.6° S49E 3834' 41.9~ S57E ! 4329' 46.8° S42E 3945' 44.1 Mud Wt.: 9.3 ppg. Visc.: 36 Alaska United Rig #3 (0-4-0) Drlg. Foreman- D. Mount joy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparqk River) AFE 10-61-1087 1-16 - Drld & surveyed to 5556'. Ran MWD surveys (bad surveys). Ran wireline survey, hole looked o.k. Drld to 5645' & circ. Short trip 15 stds. Drop survey & POOH. Work tight spot @ 2667-2896. TIH & circ. Surveys: Depth Angle Direction Depth Angle Direction 4484' 48.2° S43E 5068' 45.8° S28E 4638' 47.8° S48E 5161' 44.7° S28E 4792' 47.7° S44E 5253' 43.7° S26E 4946' 46.4° S32E 5436' 42.0° S25E Mud Wt.: 9.4 ppg. Visc.: 37 Alaska United Rig #3 (0-5-0) WEATHER: -22°/-80~; Wind: 20 knots NE; Accidents - None Spills - None Kuparuk River Field - North Slope Borough, Alaska Drlg. Foreman - D. Mount joy Visibility: ¼ mile W.I. - 52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-1087 1-17 - Pump pill, POOH LD DC & stabilizers. RU csg. crew, & run 140 jts. 9-5/8" csg. Circ. & reciprocate csg. Pumped 40 bbls. sepeolite spacer, cmt. 9-5/8" w/1400 sks. permafrost type "E" & 875 sks. of Class "G" w/l% CFR-2 & 1% CaCl?. RD cementers & csg. crew. Back out landing joint & cleaned off rig floor. ND 20" stack & diverter system. Install speed head & NU BOP's. Mud Wt.: 9.4 ppg. Visc.: 47 ~ Alaska United Rig #3 (0-6-0) i. Drlg. Foreman - D. Mountjoy WEATHER: -20°/-75°; Wind: 22 knots NE; Visibility: 5 miles Accidents - None ~ Spills - None Kuparuk River Fie]d- North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk_River) AFE 10-61-1087 1-18 - NU BOP & RU to test BOP. Test BOP's, ~est pipe rams, blind rams, choke lines, HCR valve, & kill valve to 5000 psi, test kelly valves. Test annular to 2500#. Witnessed by Bobby Foster, AOGCC. RD test tools & run wear ring. Strap & PU BHA. TIH. Cut drlg. line. TIH & clean out to float collar. Test csg. to 1500#, test o.k. Drld. F.C., 80' cmt. & float shoe. Drld. cmt. & formation to 5691'. Circ. & run 11.5 ppg MW equivalent test, o.k. POOH. Change BHA & orient bCWD. TIH & drld. to 5835'. Surveys: Depth Angle Direction 5762' 37.7° S25E Mud Wt.: 9.4 ppg. Visc.: 35 Alaska United Rig #3 (0-7-0) Drlg. Foreman - D. Mountjoy WEATHER: -18°/-50°; Wind: 10 knots NE; Visibility: 13 miles Accidents - None Spills - None ~ Kuparuk River Field- N~-'th Slope Borough, AlaSka W.T - 52.05955% Mi]ne Pt. C No. 6 - CON-~_~0ENTIAL (8452'-Kuparuk River)~_~.'E 10-61-1087 1-19 - Drld, surveyed & or~iented f/5835' to 5996'. Lost 600# pump pressure. POOH looking for washout. Check Navidrill, o.k. TIH, check jars, o.k., orient MWD & TIH. Repair low clutch & TIH & orient. Drld., surveyed & oriented f/5996' to 6850'. Surveys: Depth Angle Direction Depth Angle Direction 5887' 36.0° S30E 6534' 36.1° S42E 6078' 36.4° S33E 6808' 36.6° S42E 6201' .36.9° S36E 1-20 - Drld. & surveyed f/6~50' to 8204' (make motor run @ 738~' to 7470', had torquing problem after the motor ran). Survey. POOH. Surveys: Depth Angle Direction Depth Angle Direction 7140' 36.9° S44E 7693' 35.2° S50E 7386' 37.5° S44E 7939' 34.1° S52E 7482' 36.2° S48E 8138' 32.9° S52E 1-21 - POOH. LD BHA & service MWD tool. PU BHA & TIH. Reamed f/8164' to 8204'. Drlg. f/8204-8780'. Mud Wt.: 10 ppg. Visc.: 41 Alaska United Rig #3 (0-I0-0) Dr].g. Foreman - D. Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-1087 1-22 - Drld. to f/8780' to 8900'. Circ. & pump pill. Short trip 15 stds. Circ. POOH. RU & run Schlumberger LDT, CNL, DIL, GR, CAL, SP from 566I' to 8700', hit bridge, ran log #2 w/LDT, CNL only. Log bottom 30' of LK2 sand (hit bridge @ 8700'). TIH. Cut drlg. line. Mud Wt.: 10.2 ppg. Visc.: 41 Alaska United Rig #3 (0-11-0) -' Drlg. Foreman - D. Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-1087 1-23 - Repair rig. TIH, circ. & cond. f/csg. POOH, LD DP & BHA. Pull wear ring. Change rams & RU csg. crew. Run 225 jts. of 7" csg. w/no returns after jr. #106. Circ. & recip, pipe w/no returns, csg. shoe @ 8883', pumped 40 bbls. of preflush. Mixed 650 sks. of Class "G" cmt. w/l% CFR-2 & 0.3% HCL-24. Dropped plug, displacing w/10.2 ppg pkr. fluid w/no returns. Mud Wt.: 10.2 ppg. Visc.: 43 Alaska United Rig #3 (0-12-0) Drlg. Foreman - D. Mountjoy Kuparuk River Field - North Slope Borough, Alaska W.I~ --52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-1087 1-24 - Displace cmt. w/336 bbls. 10.2 ppg & land csg; bump plug CIP @ 0800 hrs. Set ECP's w/3200 psi, clean out cellar. RU & do top cmt. job 13-3/8" x 9-5/8" annulus & RD Halliburton. L/D csg. tools. Back out & L/D 7" landing joint & install 7" packoff assy & test. RU Dresser Atlas w/lubricator & MU logging tools. Run #1 - gage ring, junk basket. Run #2 - gyro survey. Run #3 - Perforating Run #1: f/8698' to 8708', f/8457'-8463'. Run #4 - Perforating Run #2: f/8678' to 8698'. RU to run Bot "2B" Perm. Pkr. Note: Well bore taking fluid @ 4 bbls./1 hour initially; 1 hour later well taking fluid @ 1 bbl./hour. Perforations at 8457' to 8463' & 8678' to 8708' Mud Wt.: 10.1 ppg. Visc.: Alaska United Rig #3 (0-13-0) Drlg. Foreman - R. Larkin Kuparuk River Field - North Slope Borough, Alaska W.I, - 52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-1087 1-25 - Run B.O.T. 2B pkr. on wireline. Set pkr. @ 8502 M.D. wireline measurement & POOH w/wireline. RD Dresser Atlas & change rams to 3½". RU & test rams to 5000 psi. Run 3~" 9.2# L-80 Butt tbg. & assoc, equip. Locate in permanent pkr. @ 8502'; pressure up on tbg. - no communication between Lower and Middle Kup. PU to neutral, drop ball, set HB pkr. Shear seal assy. @ 44,000#, space out, install hanger, control line. Displace tbg. w/diesel 94 bbls, final circ. press. 1450 psi, static 1050 psi. Bleed back diesel into annulus, close SSSV. Pressure up back side - 3~" x 7" annulus to 1500 psi. Tested o.k. Alaska United Rig #3 (0-14-0) Drlg. Foreman - R. Larkin Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 6 - CONFIDENTIAL (8452'-Kuparuk River) AFE 10-61-1087 1-27 - Rig picking up & moving material from around wellhead. RU test system to well. ALASKA OIL AND ~A$ CONSEIIYATION.GOMMISSION . / Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.1-3t 9~ TELEPHONE(90?) 279,-.t433 TO: )7~J C D _ We wish to bring to your attention that the Co~ission has no~'" yet received the following required items on the subject well which our records indicated was completed ~/-~-~-~~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. Chairman lc..C.024 John R. Kemp Manager of Alaskan Operations June 17, 1985 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (9O7) 564-7600 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention C. V. Chatterton Gentlemen: Enclosed are the originals and copies of completion reports for Milne Point Unit C No. 6, C No. 8, and C No. 10. These updated completion reports reflect the change in bottomhole location from magnetic to gyroscopic survey. Should you have any questions, please contact Don R. Girdler at 564-7637. Yours very truly, Manager of Alaskan Operations JC/kss Enc cc: D. I. Robertson RECEIVED J U N 2 4 1 85 Alaska Oil & Gas Cons. Commissio~ Anchorage :::51 AI I- UI- ALA~itA - · ALASK/ 'IL AND GAS CONSERVATION C r~IMISSION WELL COMPLETrON OR RECOMPLETIOi I-P. EPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED ~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number CONOCO, INC. 84-241 3. Addr~.~ 8. APl Number 3201 "C" Street, Suite 200, Anchorage, AK 99503' SO-029-21257 _ -- · z~. Location of well at surface 9. Unit or Lease Name 665' FSL, 2289' FEL, Section 10, T13N, PlOt, UM Milne Point Unit At Top Producing Interval 10. Well Number 2581' FNL, 708' FWL, Section 14, T13N, PlOt, UM C No. 6 At Total Depth 11. Field and Ponl 2737' FNL, 819'FWL, Section 14, T13N, PlOt, UM Kuparuk River Field - 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Ku~aruk -River 52'KBI AKL 47434 ~--'~ ---. 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1-12-85 1-22-85 Suspended 1-25-85I NA feet MSLI ORe 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8900 '-7228 ' 8807 '-7142 ' YES RI NO []] 1967 ' feet MD 1800.+. 22. Type Electric or Other Logs Run LDT -CNL-D IL-GR-CAL-SP 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 36# K-55 O' 5641' 12 ~" 1400 sks. Permafros- E O 875 sks. Class G 7" 26# L-80 O' 8889' 8 ~" 650 sks. Class G 0 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) 3~"~. 8502 ' 8502 '/8340' 8457'-8463' (Middle Kuparuk) 8678 '-8708 ' (Lower Kuparuk) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NONE All perforations shot @ 12 JSPF 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUN 2 4 !985 Alaska 0i! & Gas Cons. 00mmissi0n .Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS ' :.ii:!-.-;i-~: :: '- ':'.i:'i ' "i J:;~' FORMATION'TESTS NAME Include interval tested, pressure data, all fluids recovered and grav:~ty, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · KA 4473 3723 DATE SAND BOPD PWH GRAV WATER INT. LA 4731 3895 1~30 LK(1) 150 40 21.4 0% 8678-8708' MA 4864 3986 1-31 MK 184 90 21 . 4 0% 8457-8463 ' NA 5200 4221 OA (West SAK) 5404 4569 L. Kup. Unconformity 8~062 6491 Middle Kuparuk 8456 6829 Lower Kuparuk 8649 6999 31. LIST OF ATTACHMENTS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge 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 STATE OF ALASKA ALASKA %_._ AND GAS CONSERVATION CC:. ,¢llSSlON SUNDRY NOTICES AND REPORTS--ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. Conoco Inc. 84-241 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-21257 4. Location of Well 9. Unit or Lease Name SURFACE: Milne Point Unit OTHER [] 665' FSL 2289' FEL, Sec 10, T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 12. I 6. Lease Designation and Serial No. ADL 47434 10. Well Number C-6 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [-', Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-6 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistantly with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post completiOn flow test left significant fill in the casing. Prior to the fracture treatment each well is to be checked for fill. If the C-6 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. RECEIVED jUN 2 0 1985 -Aiaska Oii & Gas Cons. Commission Anchorage 14. I hC-~b-~c-~rtify that the foregoing is true and correct to the best of my knowledge. ~1 ~ k~ Sr. Production Engineer Signed ~ k' _ ~_ ~ Title The space below for Commissi~o use Date 6-17-85 Conditions of Approval, if any: OR!G!NAL SIGI[B BY ~f}N'.'I[ C. SMITlt Approved by Apl~rOVed Copy By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ' ALASKA ~' ". AND GAS CONSERVATION CC'~ 'MISSION MONTHLY REPORT = DRILLING AND WOR OVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 84-241 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21257 4. Location of Well at surface 665 ' FSL, 2289' FEL, Section IO,T13N, R1OE, U.M. 5. Elevation in fe~ (indite KB, DF, etc.) 52'KB 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 6 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of Hay ,19 85 12. Depth at emi of month, footage drilled, fishing lobs, directional drilling problems, spud date, remarks None. 13. Casie~j o~ t~ne~ run an~ quantities of cement, results of pressure tests None. 14. Cori~j resame and brief description None. 15. Lc, cjs run a~d d~)th where run None. 1 6. DST data. perforating data. shows of H2S. miscellaneous data None. Well is suspended. BPV is not installed; SSSV is open. to follow. Completion report 1 7. I hereby certHy that the foregoing is true and correct to the best of my knowledge. NOTE-Report on 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 10-404 Submit in duplicate Rev. 7-1-80 -' STATE OF ALASKA -: U il ALASKA ~-t,L AND GAS CONSERVATION C,&_,MISSION W;_LL COMPLETION OR RECOMPLETION REPORT Classification of Service Well 1. Status of Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 84-241 3. Address 8. APl Number 3201 C Street, Suite 200 Anchorage, AK 99503 50-029-21257 4. Location of well at surface 9. Unit or Lease Name 665' FSL, 2289' FEL, Section 10, T13N, RiOE, UM '~LOCATiON$~ Milne Point Unit At Top Producing Interval VERIFIED t~ 10. Well Number jSurf. ~j C No. 6 2578' FNL, 705' FWL, Section 14, T13N, RiOE, UM B.H. 11 Field and Pool At Total Depth ' ' ' 2736' FNL, 817' FWL, Section 14, T13N~ RIOE, gM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KBI ADL 47434 Kuparuk River 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No' of Completions 1-12-85 1-22-85 Suspended 1-25-85I _b~A feetMSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)! 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8900' - 7229 ' 8807 ' - 7052 ' YES E~ NO []I 1967 ' feet MD :[800_+ 22. Type Electric or Other Logs Run LDT-CNL-D I L-GR-CAL-SP 23. CASING, IINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 30# E--55 O' 5641' 12 1/4" 1400 Bks. ~ .... ~1-~o. Ft. 0 875 sl~- C1~ 7" 26# f,-flo O' tiff89' 8 1/2" 650 .k.~. ¢.1..~ c 0 ~4. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2" R502' 8~n?'/~40' 8457'-8463' (Middle Kuparuk) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8678 '-8708 ' (Lower Kuparuk) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED All perforations shot @ 1'2 JSPF 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE IGAS-OILRATIO Date TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED I~ OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED MAY 0 6 AlaSka 0ii & G~s Cons. ¢0mmission Anchorage ' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. .: " ' ..- . : , : .... .: ~'. ............... .... ' '. GEoLoGi'c MARKERs ''~ '':' -' :: ':;'"'"t ':":'-: '. ': '" '. : :? -:' i'-' 'FoRMA:ZlLIoN'¥-E'S~s:; iI'- ..... ' ' '-' '~ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Date Sand BOPD PWH Gravity Water IN:T. KA 4473 3769 1-30 LK(1) 150 40 21.4 0% 8678-869~ LA 4731 3828 MA 4864 3916 1-31 MK 184 90 21.4 0% 845'7---846 NA 5200 4184 , OA (west Sak) 5404 4265 L oCret. Unconform- ity 8062 6387 Middle Kuparut 8456 6724 Lower Kuparuk 8649 6896 Note: No Downhole Pressures Available 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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". Directional Services Pressure Services Chemical Transmission Systems April 25, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATT: William Van Alen CONFIDENTIAL Re: Our Boss Gyroscopic Survey Job No. AK-BO-50006 Well: C--6 Milne Pt., Alaska Survey Date: ganuary 25, 1985 Operator: T. McGuire William Van Alen: Please find enclosed the copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Si ncerel y, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure cc: According to distribution list NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 RECEIVED Alaska 011 & Gas Cons. Commission AnChorage F:ONOCO, 'I NC. ........... C-6 ............................................. MILNE POINT ALASKA SPERRY-SLIN WELL SURVEYING COMF'ANY ...... ANCHORAGE ALASKA VERTICAL SECTION CALCLILATED ALONG C:LIz~sI_IRE ..... COMPUTATION DATE '-' JANUARY~'.."~:-, 1 cyo.-.=._, PAGE 1 [~ATE OF F:t_IRVEY_ dANUARY ...'-"-'._-., 1985 BOSS' GYROSCOP I C"- SURVEY ..... JOB NUMBER AK-BO-50006 KELLY BUSHING ELEV - M'~' O0 FT OPERATOR-'MCI_]U I RE- ' ' ............ TRUE .................... SUB=SEA ........... COURSE .... COURSE ........ DCmG=LEG ......................... TOTAL ................................................... MEASURED VERT I C:AL VERT I CAL I NCL I NAT I ON D I REC:T I ON '.SEVER I TY REC:TAN_,I_ILAR L. UUR[ I NATES VERT I CAL r ' SECT I~' DEPTH DEPTH DEPTH DEG M I N DEGREES DEG/100 N _IRTI4 / SC~LITH EAST/WEST ' 0 0.00 -52.00 0 0 N O. 0 E 0 .1.00 100.00 48.00 0 11 N 15.69 E 0 ..... '200 .............. 200;-00 ................. 1'48; O0 ......... 0 13 .............. N'-'28";' 1S) ' W ........... 0 '300 300.00 24:-':.00 0 14 N 6.10 W 0 0.88 N 400 400.00 348.00 0 24 N :-=:4.3? W 0 1.38 N .................... 500 ........ 499;99' 447,99' 0 32 .... N'24.89 W ............ 0 ........... 2.09 N 600 577. ?? 547. ?? 0 31 N 26.80 W 0 2. '.-.-¢:-=: N 700 677.78 647. ?8 0 46 N 22.80 W 0.24 3. ?7 N ..................... 800 7?.9; ~8 ................ 747";'~8 ........ 0 ..... 30 ................ N .......... 2:80 W ................... 0';'3~ ......................... 5;"03"'N .... 'PO0 877. ?6 847.96 1 6 N 8'P. 6'P E .1.. 24 5.4:-': Iq ?50 ~4.9.75 8?7. ?5 i 47 S 77.67 E 1.4? 5.32 Iq 1000 ~??.87 ?47.8? 3 I5 S 70;87"E 1050 1047.77 'P97.77 4 3 S 68.50 E 11 O0 107'.-.-~. 60 1047.60 5 45 S 67.10 E ............................... 1'I'50' 1 I4.9.23 ........10~7, 23 8 ....... 4 ................. S'"'~6";'80 E 1200 .1. 1 ~8.66 114.6.66 ? 13 S 65.10 E 1250 1247·72 1175.72 10 26 S 62.60 E .................................... 1300 ..... 1276.76 12'44'; ~6 ........ 11 ' ' 58 ..................... S '"'~.',1 ;"8~ 'E 1350 1345.71 1273.71 13 36 S 61. 0 E .1. 400 1374.13 .1. 342.13 15 17 S 58.80 E ....................................... 1'450 .............. I"442;"26 ............ I3.90';"25 ........................... 1'6 ............ 4 ............ B-"'56¥ 19 .... 1500 .1. 470.21 1438.21 16 54 S 53.1 ? 1600 1585.08 1533.08 17 53 S 53.30 ......................... 1700 .................... 1678;'57 1626'.'57 .................. 2I ......... 37 .................... S" 52;' 0 1800 1770.7:3 171 ::: · 73 24 0 S 50.80 1 ?00 .1. 861.26 1807.26 26 15 S 53.80 ..................... 2000 ................... 1 .?¢'z~'.9',-7'I ................... 1-877';'"71' ................ ~.9 .......... I".9 .................. S-53';" 6.9 .... 21 O0 2035.46 1 ?:33.46 32 :36 S 50.30 2200 2118.72 2066.72 34 38 S 50.19 ....................... 230'0 ............. 2'200";'-62 .............. 2148';'~2 35 ...... 22 .............. S'"'53 ~"~;0 · 00 0. O0 0. O0 0 .20 0.17 N 0.05 E -0 ; 16 ................... 0;51 N ............ 0',"00- E .................. i 0 ·07 · 22 ;'.1.6 .03 · · 0..0 · 37 ' 0.11 W -0.73 0.3:3 W -1.24 '0,72 W .......... -2' 03 1.13 W -2. ?3 1./_-.0 W -4·01 ...... 1 ,'88'"' W ............................ =4,98 0. ?4 W -4.68 0·31 E -3.71 3,0() 4,67 N 2.42 'E -1.83 1.63 3.57 Iq 5.41 E 1.01 3.3? 1.75 N ?.36 E 4.88 ........... ~ ; '--' ~;0;,41 2. ,:,6 3 4:3 2.57 7 · 2/.-. S 29 · 43: E 25.21 3",'0~ 11~ 79 .S 38'; 03"E ................ 34, 35 :3.2:_--: 17.08 S 47.75 E 44.82 3.5:3 23.35 S 58.53 E 56.72 E E E E E .................... 3 ;08 ....................... 1'56';"73""S .............. Z~:6]'"47--'E ................................ 275 E 3.71 1 :E:8.64 S 27/.'. · 95 E 326 E 2.04 224.04 S 317.51 E 380 E ........... 2' 0.9 ..... 25Sy.'42'"S 364;'65 -"E ............................. z~37 ........... 2; 'I"I ........................... 30";"'$ 2'"' S .................... 69'; ? 3" "E ............................... 6 ?.' 77" 2.3:-=: 38.82 S 81·50 E 83.64 2.79 57.71 S 106.80 E 114.64 I';'77 7.9 ;' 23 "S ................. 1'34 ;-.97"' E 1' 4..o, 53' 2.42 10:3.4:3 S 165.26 E 187.83 2.58 12?. 3/:. S 198.87 E 22?. 64 -"35 · 07 .71 · 47 CONOCO, .INC. ........ C=6 ..................................... MILNE POINT ALASKA :_=;F'ERRY-L--:UN WELL' 'C-;i, IRVE¥ING F:OMPANY ANC:HORAC~E ALA:=;KA VERTIC:AL SEC:TION CALCLILATEI] ALUN_, C:LOSLIRE -COMPLITATI C~N' DATE ...... ! dANLIARY '~'-' '-"'-' = ,-,_-,, 1 ~,:, PAGE 2 I]ATE ,-;F SURVEY ._iAN_IARY '.-'~ 1985 ......... BCi'SS iSYROSCr";F'IiS' S'~LIRVEY ,.Il'lB NUMBER AI<-BO-SA006 KELLY BLI'.E;HING ELEV. = 52.00 FT. ' C~F'ERA'FOR'MC'.GU I RE ........... ................................... TRUE ................... SUB=SEA MEASURED VERT I CAL VERT I CAL DEF'TH DEPTH DEPTH ..... C. OLIRSE ...... COURSE ........ DOG'-LEG ....................... TOTAL ................................. I NCL I NAT I ON D I REC:T I ON ~ EVER I TY REC:TANGULAR F:F~I]RD I NATES VERT I CAL SECT DEG M I N DEGREES DEG/100 NuR FH/...,uLI] H EAST/WEST .I(" ....... ~'600 ............ 2432'; 88 ........... 2380';-88 ............. -4'1 5..,=-- ...... -'Sr"Zl...'.9¥'8?--E ................. 2726' ............. 372';'-~S'0'"-S ................ 5'I-~'J-'&5'-'E ................. &'21~:" 56 ' 2700 2505·77 2453.77 4.4 2:9 S 48·80 E 2.65 417.20 S 568.57 E 671.51 2800 2576.75 2524.75 45 5 S 47.69 E 0.99 464.11 S 621.12 E 761.58 ..... 2.900 ............... '-~646':-76 ............ 25.94';' 76 ................... .~6 .............. 2 ........... S'-4 7;-'69'"E .................... 0 ;' ..'P 5 .................. 5i'-2:-1' ~'"" S ................. 7:.73 Y~-3-'"E .................... 8:_~ 2","68 ' 3000 · 2715 · 61 2663.61 46 56 S 47. 1".-.? E O. 97 561.20 S 727.35 E 904..92 3100 2783·10 2731.10 48 8 S 46·69 E 1. · S200 ........... 284"~-~-2:Z,.'"'- .......... 2-7.97;22 .............. -'4-'P ........ ~- ........... S--'zl."6";-l"r.'? "E ............ 0 ;' 3300 2914.22 2862.22 49 50 S 45- 3'P E 0 · 3400 2978.35 2926·35 50 23 S 45. 0 E O. .......................... 3500 ........ 304'I ';"24 ................ 2.98?; 2'4 ........... 5'1 ........ 37 ............. S-Zl.'4'-::'-80--'E ....... 1; 3550 3072.79 :-=:020 · 79 50 5 S 45.50 E 3. 26 611.57 S 7:-':1.26 E 978.47 99 .................... 6(..,.3726-"S ..................... 83'5T'6-4--E 'I'053'~-'30 5~8 716.2:3 S :B'.,?O. 1 i E 1129.15 6:-=: 770 · 30 S '~44.55 E 1205.8£) 28 ...... 825.37'"'S ' ".-.'~"~'P~ Zl. 3'-"E 1283.46 ¢,:.."-'" ,_'"]._.~,~":'. 72 S1026 .9..'2 E 1322 .20 3600 31£)6.09 3054.09 46 22 S 45. ............... 3~50 ........ 3I-4-1'; 50 .............. 308?.;'50 .................... -43 ...... 2~ ......... ,"S-'Zl.'~S;-30 3700 3178.17 3126.17 ' 42 11 S 4.6.69 3750 3215.26 3163.26 42 2 S 48.30 3800 .................. 3252:' 48 .............. 320'0' '.] '4'8 ................... ~lJ' I ....... "4~' ........... ~'~'-'4 ~ '~" 6 O' 3850 32:=:'P. 69 3237.69 42 5 S 4:_=:. 89 3900 3326.58 3274.58 42 4.8 S 48.1'.-.? ................... 3:~50 .............. 33~2':"'88 ................ 331"0'-.-88-- ...... ~$4- ........... ~ ........... S"47'," 37." E ............................ 2":-'8zi; ...... " .......... 1'038 ;54' 4000 3398.46 3346.46 45 7 S 46.80 E 2.21 1062.45 E 7.45 878.81 S E .............. 5 ;'P'O ....................... 903',"33 'S ...... E 2.5:-=: 926.73 S E 2.17 949.38 S E ........................... i ;'84 ..................... '.~'7'1"~ 30 "S E 1.17 9'P:S:. _1.0 S E 1.71 1015.44 S S 1053·56 E 1359.43 1 o 7,=. ;' ~ 4'-"E ................... -1.2 ~ 4 T( 1 10:3 .=,'?" ' ~'-''-' ~-- -' 1128.31 E 1461.95 ......... 1 :i.'53T'4 $/--'IS ......................... I'495'~' 1"1 117:-=:. 79 E 152:3.28 1204·08 E 1561.83 .............. :L]'2~"::-55-E ...................... 1' 5:.-.? ~ 7'0~ .... .1. 255.28 E 1631.06 4100 3468.81 :'3416.81 45 26 S 46.60 E 0.35 1111.17 S 1307·00 E 1701.93 "420'0 ..... -'--3538;'5.9' ............ .'c3_-.',~86"--5~-' .... '4'6 ........ ~ ....... S' '"Zl. 5';'30 "'"E ............................ 1' ::TI ................ 'I'i"~,'O"-:'--~.~'P'"S ................... 'f358TzI. 8--E ................... 1773 :-" 42 .... 4300 3607.71 3555.71 46 2:-=: S 42.89 E 1.78 1212.88 S 1408.75 E 1845.64 4400 3675.05 3623.05 48 53 S 38.30 E 4.17 1269.0:'-: S 1456.80 E 1919.50 ................... '4~'5'0 .................. 370'8;-04 ............. 3'~56'.;"04 .................. '48 ......... 3'I ........... S 37. 50 E ................. 1'.: 40 .................. 1'2~8';6'7"'S ................. i"47'P'YSL=;--E ...................... 1"~5~ ~"~5 4500 3741.20 :--:689.20 4:-=: 22 S 36.80 E 1.09 1328.50 S 1502.4:_=: E 19'~4.22 4600 3807.83 3755.83 48 3 S 35.30 E 1.16 t 3:_-':8. 78 S 1546.36 E 2068.32 ~.70'0 ........ .S98'7~'-;'"~3 ............... 3822 ;"E;3 ................... ~8 ............. 6' ......... S 33; 6'0' E ................... 1' "'27 ............... 1450'."I'4" S .................... I508';-45-E ...................... 2I'42;; 01 ' CONOCO, .INC. ...... C=6 ............................. MILNE POINT ALASKA ........... SPERRY=SUN'WELL SURVEYING COMPANY ANCHORAGE ALASKA ................................... COMPUTATION [;ATE .......... JANUARY-._'='°R, 1985 VERTICAL 8EC:TION CALCLILATED ALONG CLOSURE ........................ PAGE 3 DATE OF :-';LIRVEY ,_IANLIARY...'~'~:, l'~°F,.. ,..: Bi-i~R'._--; ..... GYROSCOP I C -~i-IRVEY' ........ ,_lOB NI_IMBER AK-BO-50006 KELLY BLISHING ELEV. = 52.00 FT. r~PERA TOR=Mr:GU I RE .............. ................................ TRUE ............ SUB=SEA .................... COURSE ............ f':OURSE MEASURED VERT I CAL VERT I CAL I NC:L I NAT I ON D I REC:T I ON DEPTH DEPTH DEF'TH DEG MIN DEGREE8 4800 3941.78 3889.78 47 31 S 32. 4900 4010.18 3958.18 46 10 S 32. 4~50 ............ 4045;-'0~ .............. 3~93;0~ ............ 45 ....... 13 ........ S'-31': 5000 4080.30 4028.30 45 15 S 30. 5050 4115.38 4063.38 45 36 S 30.50 .................... 5100 ............ 4150,46 ................ 40~8;46 ...... 45 18 ......S"30;" 0 5200 4221.28 4169.28 44 31 S 2~.1~ 5300 4293.20 4241.20 43 29 S 27.89 5400 .............. 4866:"27 .................. 43'I4;27 .............. 42 ............ 37 ........... S"-27;30' 8O 5500 4440.48 4388.48 5600 4515.97 4463.97 ................................. 5700 ......... 4592;92 ............... 4540;92- 5800 4671.3~ 4619.39 5~00 4751.35 4699.35 41 32 S 2'5. 40 24 S 25.50 ...... 38 57 ................... S'"26;'"10' :2:7 3:-': S 27.50 36 10(..1~ .S 30.39 50 E 10 E 50-"E 89 E E . DOG=LEG ..... · '_--:EVER I TY DEG/100 1.01 I. 38 ............. 2 ;07 .......... 1'604:'31 .... O. 86 1634.6:--: O. 90 1665.31 E ..... 0 ;"'P5 .............. 1'696, 0':.-~' E O. 'P6 1757.4'7 E 1.37 1:--:1:3.49 E ..........0;-95 .............. 1878.99 E 1.4:.-': 1 '~:38.9:3 RECTANGLILAR NORTH/SOLITH 1512.24 S 1573.90 S E 1.15 1998.04 E ..... 1;50 ......2055,53' E 1.58 2110.85 E 2.28 2163.38 E 0';8:3 ............ 2213;S~0 E 1.'P1 2263.44 E 1.11 2311.?~ E 0~'~3 .'2359.~2' E 1.37 2406.73 TCrFAL ............................................... C:OORDINATES VERTICAL EAST/WEST SECT~ ' 1628.86 E 2215.11 1667.84 E 2286.93 S ............ 1'686770"'E ............. 2322:10 S 1705.09 E 2356.92 S 1723.28 E 2391.80 8 ...... 1741'-'""'.~o"'E 2426 .64 S 1776.10 E 2495.48 S 1809.31 E 2562.92 S ..... i'840;'74"'~E ................ 2628:'..~3 "' S 1870. 'PO E 26'P3.39 S 18'.-.?'~. 2'.-} E 2756. 17 S 1927;'07 E ................ 2817,36 S 1955.00 E 2877.04 S 1984.04 E 2935.40 ......... ~(') ~..z~,-- ~'' ., ...... ~- .......................... ~-,:1~.-, ...,- · =~ ." . .L I'. ,,..~,L I=. ."~; .....~.~ ,~ .-,(") .-, .-, - ~ ,. -'. 47. :l ... E .:. U._, 1. ,. _ S 2082.15 E 3111.29 " .................. 2'1'"1'8';'5S:-" E ................ 3 I'71; ~.~'- · --, ,'-'- 1 ~' ¢- ':"":' '=' · .,=.. 16 E . ,.,.. ,., 1 15 6500 5232.74 5180.74 36 31 S 41.:2:9 E O.'P2 2452.00 S 2195.02 E 32'P0.79 6-600 ............... 53I'3';-I8 ........ 5261";"'1'8 ................. 3'6' ...... 22 ........... S""~2, 80 E ................... -0';'85 ................ 24'76=0~,3'""S ................ 2234T86-'"E ....................... 3:350;'21 .... 6700 5393.75 5341.75 36 15 S 4:3.:30 E 0.32 2539.36 S 2275.28 E 3407.4.2 6800 5474.16' 5422.16 :36 41 S 4:2:. :30 E O. 45 2582.62 L=; 2:316.05 E ::-:468.86 ......................... 6~00 ............. 5554';"25 ............... 5502 ;'25 ....................... 38 .......... 52 .................. S" 43:, 8S.~"- E 0 ;"'40 .......... 2625. Y~?"' S ............... 2357; 35"' E""- .......... 3528,-73' 7000 563:4.09 55:32.09 :37 11 S 44.60 E O. 5:3 2669.12 S 2:3'P'F*. 37 E 3588.92 7100 5713.80 5661.80 37 5 S 44.8'.-.? E 0.2i 2712.00 S 2441.8:=: E 364¥.-~.25 ................. 7200 ..................... 5'7'F~3733 ............. 57'41";'33 .................. 3'7' ............ 32 ................ S 44;30 E O; 5._-': ............ 2755';'I7'""S'-": ............. 2484'-;'44'"'E ........................ 370?;82' 7300 5872.50 5820.50 37 46 S 4.5.10 E O. 54 2798.5'.-.-~ S 2527.41 E 3770.86 7400 5?51.35 5899.35 :2:8 8 S 45.39 E 0.41 2841.8.....? S 2571.09 E 3832.29 .......................... 7500 ............... E:030';'"97 ................. 5'~78;-'..~'.~ ................ 36 .......... 1'6 .....S'45; 10' E ..... 1 '88 2884;"45-"S ............. 2E;"14; 03-E .............. 38?2, 68 CONOCO, INC. MILNE POINT ~LASI<A VERTICAL SECTION C:ALCLILATED ALONG C:LOSLIRE SPERRY=SUN WELL SURVEYING ' L".'¢IPIPANY ..................... F'AGE 4 ANCHF;RAGE ALASKA DATE FIF E:URVEY ,_IANI_IARY 23, 1'.~'::~--. ,_._, ................................................. C'OMPUTATI ON f]ATE .................... B r~,:L~-~-- G Y R rr.-~F!r~F' I'¢."- ~I-IR vE y - ,JANUARY '=':::, 1'-'-'=' ~_ Fo._, ,JOB NUMBER AK-BO-50C)06 KELLY BUSFIING ELEV. = 52.00 FT. OPERA'I'OR=M C:OL~'.~-RE TRUE ............. SUB=SEA c. or, IRSE ...... C:OLIRSE ............. DOG=-LEG ................................ TOTAL ...................................... MEASURED VERT I CAL VERT I CAL I NCL I NAT I ON D I RECT.]: ON SEVER I TY REr:TANGLILAR CFoRn I NATES; VERT I CAL I-" '-'- '~ ' DEPTH DEPTH DEPTH DEG MIN DEGREES DEE. i/100 N_iR FH/.:,UI.ITH EA... T/WEST E;E~!T ~' 7600 6,111.9'2 6059.99 :35 :31 S 46,. 60 E '7700 61 '.~3. .46 6141 .46, ~,'--'Fi`- 21 S 4.7. 0 E ................. 7800 ...............6...7,.'" .=,-"-'· .-6 ................... ~....-._-~-' .... -'", ..E-' ................. ......... 2~.- ..... mo ............. ,--:, ...... 47. 7900 6357.40 6305.40 8000 6439.85 6387.85 8100 .................. 6522;84 ............. 6470';84 8140 6556.29 6504.29 8200 6606.79 6554.79 8300 ............. 8400 6778.83 6726.83 8500 6866.71 6814.71 1.15 2925.29 S 2656.09 E 3951.20 0.29 2964.98 S 2/_-,98.36 E 4009.02 0 :"'6' 1 ................ 3003':-'9'6'-'- S~ ............. 27'4-0'J'6'7 - "E .......... 4066'"'33 34 '-"-' .'.~.:, ~ ..... ., .~ 1 E 41 '-"-' 06 .=,,=, S 48 80 E 0,67 3041 ,- '-, ,:' .'). '7,:,.:, .:, · . ~ .:, · ,.i · 34 16 S 48·60 E 0.39 3079·2:': S 2825.73: E 4179.31 ............ 33 3'1 ............ S- 49';'30-'-E ....................... 0 :'85 ........ 3I'15':92-'S .............. 28'67;-7'~' E 42E:4,73 :3:.:.: 1 S 49. 10 E 1. :30 :31:30 · 26 S 2884· 40 E 4256.52 :32 19 S 48.19 E 1.42 3151.65 S 2908.72 E 4288.71 ............. 30--37 ........... S-"~'4';--O'--E ................ 2:"77 ......... 3'1-'87]-80-'B ............... 2S.~'~'E, ZB5--E- ............... 43'~0';'78 29 2 S 4.0.19 E 2.4.6 3224.65 S 297'.-?· 70 E 4390.4':? 2'7 58 S 36.10 E 2.23 :3262.14 ~:; 3009.19 E 4438.05 ,:. 6t)U 6 .~ 5`-,, 7 .. ~ .. U.:, · 7 .~ .... 2A_ ............. 2 .............. S'-'"'~' .................. ~'"' ~.~o,_~" ,:,.=;-'-~ ......... .:,(.)'35, ':"or)... .............. E 44,:,.:,'""' 17 700 7046.14 6994 .14 24 41 S .:,4 . ,:,'-'o., E 1 .44 .:,.:,,:'"'-'"":' .... · 75 S 3060 .7:3 E _z~':'.=,`- .. `-. 6,6: q,o,-- '"'"q= 00 24 41 ~ 34 '-'" ,_~00 7137.00 /,.,,_ `-,. -'. ,:,0 E 0.00 '-"-'.:,.:,/:,,:, .'" 05 ._,':' `-'~o':'~. ,_,~. Pi/-,_ _ E 4567 .09 '"'= ........7.."..'7. o6 717~. ~ =, ~z~ z;I .:, ¢z~. ~,0 E 0.0'0 .:,4Oz. ¢._, .=, oiO,_,. 40 E ..... ,:) ;IL') 0 ......... .~_ .... ,~ ................ ~'~-'",¢A~¢. .......... -~ ........................-~--.--~" '--~ ~-, = '-'' 8900 HORIZONTAL DISPLACEMENT 4608.49 FEET AT .=,OUTH 42 DEG. 24 MIN. EAST A'l' MD = THE CALCULATION F'ROC:EDURES ARE BA=,ED'" ON' THE USE OF TFIREE D IMENF;:[ONAL RADIL.=,I'-' OF C:URVATURE METHOD. CFINOCO, ZNC:· ......... 0.=;6 ...................................... MILNE POi'NT ~LASKA SPERRY-SUN WELL SLIRVEYING COMF'ANY ANCHORAGE ALAF;KA ........................ COMPUTATION DATE dANUARY ~:, 1 ...:.._ F'AGE 5 DATE OF SURVEY dANUARY 23, 17:--:5 dOB NLIMBER AK-BA-50C~06 KELLY BLISHING ELEV. = 52.00 FT. · ' OPERATOR=MCGUI RE I NTERF'OLATED VALLIES FOR EVEN 1~:x]0 FEET OF MEA'SLIRED DEPTH 'I'RLIE SLIB-L::EA TOTAL MEASURED VERT I CAL VERT I C'AL RECTANGLILAR COORD I NATE:--: MD-TVD VERT I C:AL ......... DEPTH ................... DEF'TH ............ DEF'TH ..... NORTH/SOLITH .............. EASTT'WEST ' r.ilFFERENRE ..... CORRECTION 0 O. O0 -52. O0 O. O0 O. O0 1"000 ................... 999';'89 .............. 947; 89 ........................ 4';-6-'..~ -"N .................... 2 ;"42 'E 2000 1949.71 1897.71 156. {-.)3 S 27:6.47 E 3000 2715.61 2663.61 561.20 S 727..7:5 E ........................ 40'00 .............. 33.98;'46 ........... 3346;'46 1062;'45-'S .........1'255'; 28 ' E ' 5000 4080.30 4028.30 1634.68 S 1705.09 E 6000 4832.09 4780.09 2213.90 S 2014.51 E ZOO0 ...... 56~z1:';-07 ............... 5582';'-0'? .................. 2zs~;'.9',TI2-""$ ................. 2'3.."~9';37' E 8000 6439.85 6387.85 3079.28 S 2825.73 E 8~00 7227.86 7175.86 3402.35 S 3108.40 E 0.00 ................ 0 .'-'1'1 ................................. 0', I'1 ................................................... 50.29 50.18 284.3'.-? 2.7:4.. 11 · 601. '54 ............................ 317. '14 91'-?.. 70 ,..':'18.16 1167.91 248.20 .............. 1365':'"~I ............................... 198 :'01 1560.15 194.24 1672.14 111.98 ' I THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RA£IUS OF CLIRVATURE METHOD. CONOCO, INC. MIL. NE POINT ALASKA SF-;ERRgC~LiN ~RELL- SURVE~ iN~.~ 'COMF;AN~ ..................................................... : .............. F~'A Oi~ 6 ANCHORAGE ALARKA DATE OF ~,URVEY dANLIARY~'~'-'.~,~ 19q~. ,_ ~ COMPUTAT I ON 'DAT~ dANUARY 28~ 1~'-'=.. o~, dOB NJMBERI ' AK-BO-50006 KELLY BUSHING ELEV. = 52.00 FT. OPERA TOR~FICiE~U i ~ .................. INTERPOLATED VALUES FOR EVEN I OA FEET OF SLIB-SEA DEPTH TRUE MEASLIRED VERT I CAL DEPTH ........................ DEPTH SUB-SEA TATAL VERT I C:AL REL.] ANUL LAR COORD I NATE'.E; MD-TVD VERT I CAL ........ DEPTH ........ NORTHZ'SOUTH ......... EASTTgIEST ..... D'IFFERENCE ............ CORRECTION "'~ 0 O. 00 -52. O0 O. O0 ~ ................. 52; O0 ............... 0700- '0702-N 152 152.00 100.00 0.34 N 252 252.00 200.00 0.69 N ......... 352 ........... -352:O0 ............ 300¥00 .......................... I .--I-I-N 4.52 452. O0 400.00 1.70 N 552 552.00 500.00 2.54 N O. O0 0.00 '0 :O-I--E .................. 0% 00 ............................... O':"O-C~ ............................................... 0.08 E 0.00 0.00 0.08 W 0.00 0.00 0'~ 1'5 ""W .................................. 0':"00 ................................. 07i.9'0 ............................................................... 0.53 W 0.00 0.00 0.'2:3 W 0.01 0.00 752 752.00 700.00 4.5S~ N 1. :34 W 0.02 0.01 852 852.00 800.00 5.44 N 1.79 W 0.0:3 0.01 ..................... ~..~5'2 ................. '.-.-~5'2': '00 ................... ..~0 Cr. O0 ............................... 5'~"30 '-N ............................... 0 ,"3 7' E 0;05 0 ,"03 1052 1052.00 1000.00 3.51 N 5.55 I-- 0.21 0.16 1152 1152.00 1100.00 0.57 S 15.26 E 0.80 0.58 .................... I~254 ................ ~;252': O0 I200:'00 ....................... ."7:~0 '-'S ................... 30', 'O'~'""E 2~,' '15 1',"35 4.-.,¢),-:, E 4.47 '" (" 1 '" = ~ = o :"/ ",=, ":,.~, · .-, ,.., 6 1 00 1300 00 17. ~'-'::' '.=, m ' ~.. ~':- m .1. 460 .1. 452. O0 .1. 400. O0 32.18 S 72.26 E 8.13 :3.67 I'5'6'~''~ ............... 1'552 ,-" 00 .................. I'50'0 ;'00 50";-77 '-'S ............................ W. '7";"z~ 9""-E .......................... i"2:'"~ z~ 4 ,"8'i 16,71 .1. 6,52. O0 16,00. O0 72.74 S 126,. 66 E 1 ~. 41 6,. 47 1779 1752.00 1700.00 98. i6 S 158.79 E 27.50 8.0'2 CONOCO, INC. ~=6 ............................ MILNE POINT ALASKA ANE:HF~RAGE ALASKA DATE OF SURVEY dANUARY 23, 1'.-785 ................................................ CCIMF'UTATI ON DATE .................................................................. JANLIARY 28, 1'.-785 JOB NUMBER AK-BO-50006 KELLY BUSHING ELEV. = 52.00 FT. ............................................ OF'ERATOR=MCGU I RE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEF'TH TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD ..... DEPTH .......................... DEPTH ................ DEPTH .......... NORTH/SOUTH ..... EAST/WEST ........DIFFERENCE .... VERTICAL CORRECT-tON 188~ 1852.00 1800.00 126.67 S 1~5.24 E 37.70 10.20 ~-- ~2002 .......... ~52-;-00 ............... ~00;-00 ...............~57~70--S~- ....... -237;-5~"~ ............ 50;'63 12:~3 ........ 2119 2052.00 2000.00 195.40 S 285.0? E 67.64 17.01 2240 2152.00 2100.00 238.76 S 337.18 E 88.46 20.82 ....................... 23'63 ............. 2252;00 ............... 2200';-00 ................... 281'-;'~8-'S .......... 3~5':'~'I ..... E ........................ 1"1"I-;'83 .................................. 23:'"37 24~2 2352.00 2300.00 328.43 S 461.43 E 140.54 28.72 2625 2452.00 2400.00 383.85 S 529.~3 E 173.85 33.31 27'~'~ .......... 2552';-00 ............... -25C~';'00' ~47';~'(~S .... ~02:'75'-E ............. 2~'2;9~ .............. 3~;-0'S~ ..................... 2~07 2652.00 2600.00 515.82 S 677.~5 E 255.55 42.61 8053 2752.00 2700.00 587.84 S 756.05 E 301.46 45.~1 3204 .............. 2~852-,'00 .......2800;'00 ....................... ~5';'~8-"8 .................. 837";'75E ............................ 352;25 .................................... 50;'7~ 3358 2~52.00 2?00.00 3517 3052.00 3000.00 ~G~ .....---3152%.-'00 ........... 3~00':'00 37~ 3252.00 3200.00 3~34 3352.00 3300.00 ~0'7~ ......... -3o~'52~00 ................. 3400";'00' 421~ 3552.00 3500.00 4365 3652.00 3600.00 747.80 S ?22.05 E 406.68 54.44 835.02 S 100~.01E 465.35 58.66 '~I-O]-.I~--S ......I"0'8'~"2'""~ ......................... 5'1-2¥'~5 ~'7:]"0 .......................................................... ~71 ]'~'" { .¢~ 1153. o 16 E ~ 36 ~47. 34.71 , 1031.44 S 1221.81E 582.88 35.52 1'0~5"~.';-~'~--.-~'------']]?~7'57"-E .......................... 624]03 ................................. 4'1";""I'5 ............................................................... : 1170.77 S 1368.37 E 667.33 43.30 1248.87 S 1440.40 E 713.27 45.73 CONOCO., INC. ~C=.6 .................................................... MILNE POINT ALASKA ............................ Sp E R RV=SFIN- IgEIZL'-- .-sr-iR t2E~¢'I N C¢--C::OMP A N V- .......................................................................... F-~'~j~E 8 ANCHORAGE ALASKA .=.JRVEY .JANUARY '-"'~ DATE OF '-'1-' ,--, 1785 L.~]MPLITAT I ON" DATE ,JANUARY 28, 1785 dOB NI_IMBER AI<-BO-50006 I<ELLY BI_I'.E;HING ELEV. = 52.00 FT. ......................................................... C~PERA'TOR'MCI~I'3'f~P; ............................. I NTERF'OLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRLIE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL ....... DEPTH ................ DEPTH ................ DEPTH ............ NORTHYSOUTH ........ EAST/WEST ........DIFFERENCE ........... CORREOT'~O~ ................................... 4516 3752.00 3700.00 1338.23 S 1507.76 E 46~ .... 3852';"00 ............. 380C~00 'I42..~2--S ................. 4815 3?52.00 3?00.00 1521.65 S 1634.85 E 4?59 4052.00 4000.00 1610.24 S 1670.33 E ............... 5'$02 .......... 4-152-;~0 ................... 4100]"00 ................. '-1-E~7~4'~'-S ............... I"7~270I-E 5243 4252.00 4200.00 1783.82 S 1770.80 E 5380 4352.00 4300.00 1867.32 S 1834.72 E ...... 55'15-~45~00 ................. 4-4(~700 ................ ~9~8;~'$~ ...... 1-875'.--3~-E 5647 4552.00 4500.00 2025.61S 1~12.46 E 5775 4652.00 4600.00 20?7.58 S 1~48.10 E 764.26 50.?? 81~]"I'1 ...................... 4W~iB5 863.13 47.02 907.80 44.68 ~50'=20 ............................. 42'~]~ ?71.06 4.0.87 1028.6,1 37.55 I'0~3';"~0 ................................ 3~]-7..'F/-- ........................................ 10~5.24 31.84 1123.51 28.27 5900 .................... 4752';"00 .............. 4700:'00 ............. 2IE~'~'77-"$ ......... I'W84'='28'"E ................. I"148~'80 .................................... 25';'B0 ............................................................. 6024 4852.00 4800.00 2226.25 S 2022.17 E 1172.65 23.84 6147 4952.00 4900.00 2287.46 S 2063.79 E 1177.14 24.4? 6~'7'~: .....~0527A0' ........ 500'07'0'0 o~.~-~-~-~..--_-o-- ..... ~-n~-n~,'--'-~ ..................... ~'"~'~o-"-~,~ ........................ ~'~'-~-~ .......... 637~ 5152.00 5100.00 2406.44 S' ' 21M= 92 E 1247..~,~'~° ~._,.14'"= 6523 5252.00 5200.00 2462.70 S 2204.46 E 1271.77 24.59 '6-~8 ............. 5352;"00 .........53'0'0';'0'0 ].~EI:"7:~5'".ST", .... ~'Z-'25~TBO'-E ................ I296%'21 .................................... 2'4'Z'2~ ..................................................................... 6772 5452.00 5400.00 2570.60 S 2304.72 E 1320.36 24.14 68~7 5552.00 5500.00 2624.77 S 2356.17 E 1345.18 24.83 .. SPERRY-'SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA CONOCO, INC. ----C=-6 ................................... I'II LNE PO I NT ALASKA PAGE DATE OF SURVEY dANLIARY 2:3, 1'.-785 COMPUTATION DATE ,JANUARY 2.'_--:, 1""'-'=' ..'-,--,.-, d 0 B N U M B E R A K- B 0- 50006 = .=.',-'. O0 FT. KELLY BUSHING ELEV. ~'-: .................................................. OPERATOR=MCGHiRE ...................................... ~ UB-.:.EA DEPTH I NTERPOLATEI-~ VALLE=. FOR EVEN 100 FEET OF ~ '-' TRUE 'SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VER]' I CAL ....... DEPTH ................ DEPTH ........................ DEPTH .......... NORTH / SOUTH ............. E'A.':; T / WE:-':T ....... D IFF ERENC:E ........... E:ORREC:TI ON 7022 5652. O0 5600. O0 2678.80 S 2408. °~1 E 1370.48 25.30 ................ 7'147 ................... 5752';00 .................... 5700':-00 ............... 2732';'50'" S ............. 24/52 ;-27'-"E ................. I'3T;5 ;-~ 1' ........................................ 25';-43 7274 5852. O0 5800. O0 27:--:7.7:7 S 2516.16 E 14.22.07 26.15 7400 5952.00 5~00.00 2842.24 $ 2571.45 E 1448.82 26.76 ......................... 75'26- .............. 6052';;'00 .................... 6000' ','"00 ............................. 2875":-._'3-3-' S ............. 262'4';'75"'1~ ................... I"'4'74", '06' ......................... 25';-2z~' 7649 6152. O0 6100. O0 2944. :-':9 S 2676.85 E 14:-.?7.15 7771 6252.00 6200. O0 2'..~?~3.04 S 2728.67 E ]. 51'.~. 64 22.49 78..c>3 ............ '~35 2;'00 ............ LA-300';-O0 ............... 303?-.-4 8--S'--,'---2780:"z~ O-'E l' 5'4'1-;"'43 ............................. 2 I'¥'77 8014 6452. O0 6400. O0 :::0:::4.76 S 2831.94 E ' 1562.71 21.27 8134 6552' 00 6500.00 3128.43 S 2882.30 E 1582.8'~ 20.18 8253 ................ z5652':"00 ............... z56'00: '00 ................... 3'1"70 =" 7 7'-"S ................ 2~27 ,"28'" E ............................ 1 '6'0'1 ",' 22 18 ;;33 836D 6752.00 6700.00 8483 6852.00 6800.00 ................. ~5~5 ................ ~52;'0E .......... 8706 7052.00 7000.00 8816 7152.00 7100.00 8~0'0 ...... 7227.86 ...... -717~ 3213.27 S 2970.09 E 1617.31 3255.83 S 3004.58 E 1631.35 329 7'.-3~-B ..... 303'4";-81--E .............. ]:'6'4 3:7 8 3335,96.S 3062.26 E 1654.45 3373.71 S 3088.50 E 1664.50 ':,a'n~~---~'rn~"'-'a~T'-'~ ............. ~"~7-~-'-'--',r~ 16.0~ 14.04 q. ~! ..... ~ '~ ....................................... 10.67 10.06 f':ALCULAT ION FRoC. EDURE$ U.=,E ~ LINEAR _'I:NTERF L L. ATI'ON BETWEEN THE""'NEAREST"':20-'F'OOT--'MD (-FROM'-iq~D'YIJS-OF:'CURV'~TURE) ........ POI'NT8 ....... . .................................................................................... SPERRY--' SUN" WEI- E-'-'SLIRVE¥ i NG' Y_-!OMPANV ANCHORAGE ALASKA CONOCO, INC. MILNE POINT ALASKA PAGE 10 I]ATE OF SI_IRVEY JANUARY ~.'T, 3, 1'~'-'~'.. ¢,~, .......... C OMPIj Ti~ T i 0~-'£1~ TE JANUARY 28, 1985 JF~B NUMBER AK-BA-50006 KELLY BL.:,HING ELEV 52.00 FT. INTERPOLATED I '-' '-' ' i-' VALLE.:, FOR .:,F E..I AL SURVEY F'OI NTS ]'RUE SUB-SEA TOTAL MEASURED VERT I CAL VERT I CAL REL. TANuI_ILAR F:Iz~ORI'I I NATES ........ DEPTH ..................... DEPTH .............. DEPTH ............ NORTH/SOUTH ............. EAST/WEST ............ MARl<ER 4473 3723· 27 3671. 27 1312.34 S 14'P0.37 E KA 4527- ...... 375 ..~r~l- 3 ...... 3 707 ;"I ._~-~ ............. I3 4'4 ;--~:; 6-' S ......... 15-1-z~75 7-E KB- 457'R 3807.16 :3755.16 1388.17 S 1545. ?:3 E KC 4687 3865. 'P5 3813,'P5 1442· 08 S 1583.0~? E KD ....................... 4-73~ .................... 38'~5~33 ............... 38~'~33 ................... 1"4'~9';-36~ .......... l~D"Ig--22'"-E ............. UA 4771 3722.20 3870.20 1474.20 S 1617.37 E LB 4864 3'285.24 3933.24 1551.'~0 S 1654.04 E MA ~]P ~3 .............. ~05~ ~ 5 .........: ~'00 2;-'25 ....... i- 6 i"~I"8~'-"~1~52 '": E .................... M B ,, 5030 4101.39 4049.39 1652. t~'~ 8 :, 1716.02 E MC 513~ 4177.8'~ 4125.8'~ 1720.10 S 1755. O'P E Iq 1 5'20~ ........... '422'1]-'28 .................. ~'1'69;'28 .................. '"I'757;-47-S ................ 1'776;" I0'" E ................. NA 5227 4240· 53 4188.53 1774.00 S 1785.34 E NB 5262 4265.63 4213.63 1775.37 S 1797.07 E NC 4~._1 36 1'"'~ 00 ~ ...... 5314 ~,~r,.-, o6 ~ '=' ~.:,~,.:,. ~' . ,:,~. . ;~ 1 ,., lc:. ~ E NE 5360 4336.84 4284.84 1854. tm2 S 1828.52 E NF 5~:0~ ........... ~'3~.~-;"'2'~ ............ 43i"7 ;'21 ................... I' 881'-;"~ O'""S ................. I"B~2'."'18'"E OA 54~5 4436.73 4:384.7:3 1'P35. ?/5 S 1869.46 E OB 55~0 4508.36 4456.36 1792.19 S 18'~6.50 E OE SPERRY~=BUN-WEIZL--SURVEYING-COMPANY .............................................................. PAGE 11 ANC:HORAGE ALASKA L-:ONOCO, INC. C-'-'-6- ..................................................................... MILNE POINT ALASKA COMPUTATi ON-DATE JANLIARY 28, 1'285 [;ATE OF SLIRVEY ,JANUARY 23, 1985 JOB NUMBER AK-BO-50006 K'ELLY BUSHING ELEV. = 52.00 FT. OPERATOR-=MCGU iRE INTERPOLATED VALLIES FOR SPECIAL SURVEY POINTS ]'RUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES ....... DEPTH .................... DEPTH' DEPTH .......... NORTHYSOUTH .......... EAST/WEST ................... MARKER ,=,06.,- A4~ 1 16 6439 16 3102. '.-":_~ 'S ':,p= ~_ : ..--_,._,1 E LOWER K LINC· _ ., · · · i_ mm,i~I --.-',,,-~ ........... ~r.. BI ..-,, ~..,4~ · .."-.- ~z~gz~. 22 ........... 31-25;-9.. 8-S .......... 2879;-475"'E .................. MKR- I'9 ........................ 8300 6692.09 6640.09 3187.80 S 2?46.35 E T/I< LIP INTERVAL 8457 ' '-'"'R '"'" = 84 '"' · .., ...-4,.~. E T/MK 1 ,_-,o.',_. 73 677/:, 73 S 2997 · ................. 8z;'~3 ............ ~5834 ;'"0'3 ...... ~782';"03 ................. 3248', ;'12-'S ................. 2.9~8'.-9. z.:,-- E ................... T'7 UA M; ..... Z ONE ............................................................................................. ,~z.~,~ 6998 92 6946 92 '-"" · ,:,~ 15 '="= .... ' '--' 2'r.? ......" 5 o04o E T/LI':, 1 86,66 7(315 .... 25 6963.,::.._,""'= ._,o ..- ..-":'""~"c' 0'2 '"_-, 30~2_ ./:v-",...- E B / LI':.':. 1 ...... .-, ....... ~ ....... ~, ..~..--..-, ~ 8677- 70.--5...'-,., t5 .. 7..-,. ,:._, o-'e325;B;S- o-S- ....... -3,055';-2~--E .............. T'/EK2 8700 7046 14 69'~4 14 '~'--'-""'--"- - · '-~ I ' , · . . ..-, ..-, o .:, . 75 ~5 3060 73 E ._LRVEY DEFTH 8900 7~.'-7. '=' '"/' "~'~'9~-' 3~ '-' 717..,. 40 E DR I LLER T · D. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL NAME AND NUMBER Reports and Materials to be received by: Date Required Date Received Remarks C~?pletion~__~_._ Report 7C~ ~_~_ ~ __ ~.5~_. f~~ Core Chips ~ Registered Survey Plat y~'~ /~-~ /~~X '' ~V' Inclination Survey .~c~ - ~ ~~ Directional Survey -- O~-~Z~ ~, ~~~ Drill Stem Test Reports ~¢ ~, .~ ~/~ Production Test R~ ~c~ b~j~- Digitized Data y~ Z ~/Z--Z~ 2~¢~ STATE OF ALASKA ALASK/_v_IL AND GAS CONSERVATION C,.~J1MISSION ~'~'",~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS<, . · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 84-241 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503. 50-029-21257 4. Location of Well at surface 665' FSL, 2289' FEL, Section 10, T13~, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KBI ADT, 474~z~ 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 6 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks None 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None. Well is suspended. Completion Report to follow. APR I !985 Alaska 0il & Gas "~:~u~3n,~ L'u~t~]SS/or 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED D. /. ~ /~-, ~-~., TITLE O'~",w',~, ~j ~ J. ~"^.~ r. DATE NOTE--Report on 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 10-404 Submit in duplicate SCH LU M r..,--~.~ ~· ~.-_,c.r,~,.E,< OFF'SHO~E SERV!.C:S'.S A Division of SchlumberG~'~-r Limited I-IOUSTON. TEXAS 77001 1 APR. 85 '~' INC. CONu LO, PLF-A$£ REPLY TO POUCH 340069 PRUDHOE BAY, AK 99734 ATTN: BAR. BDiRA HARRISON PAGE ! OF 2 Gentlemen: Enclosed are_ ~..2. .... prints of the. eom Fie!c: 1! & · We , County_ NORTH FDC/CNL .... on: SLOPE State_.~__._A_S__KA__ Additiono! prints are being sent to: __.~tVL, ... prints & 1RF CO~:~OCO, INC. OFFSi.IORE EXPLORATZON' F w ~. DIViSiON,, P.O. BOX 4444 .... ?_~_ i"' _ ............................................................................. . ........ v ........... - ............. SN,. TX 77252 ATTN: L,A. DINGES ................................................................................. ~ r (~' ~" ' _!lB3: ....... prints & 2RF _c_di~!~P:~!.j!..__s__.__A_,_., zNc. _P__d_,. ....... ~.>.;i._A_o 7_¢_3.,9.. .................................... ~:'_d q iF_.';!~!~S.G{!.~_~S_If ........... _9_~. ~.!_o.._ ................. i~,.,,B" .- ,. & }.RF ............... ' ...... D, CO~';:OCO, INC ............................... r_it.-_':_'_ ................................................................ ~:;? 3 C? '~T~C ~ t~ ~ 7s~ 'T '~ ('' T-~r~ ~'~'~ OFFS}'{ORI~ 8[]II.,t)'ING F.C. BOX 2~°'''~.~.~, / ?~ (.)I ] b TO'.N ~ ...... ~_..~ ........ z _c_~l -~4..~> ....................................... A'i'TN: O.G. KIEL f% %~ '~ '~ l ................................................ _..P.~ (?.~.A__~_TX.,. OK 74603 _AT.[ ............................ ~ ......... 7 ..... ..fN: ~.~. The film is___..r_..eturne¢ t-,,~ __=.Q!..~.,QCO .................... · .......... , .... (-~ g We apprcc;ote the privilege of serving you. ._~.~i[-¢._ .... prints & 1RF ._C_}.~ .,:.?j?_ ~_~_i'.'.4.. ! ~_%.~. QL.~t _C~:~E A_N. !/.l ....... ._P._:_Q_.,__~Q.Z_._!2_~7_ ...................................... ._E_.~_;[:.~2,:~:9_q~_..~La. 8.¢__1_51} ....................... ATTN: DAL~ ~OSSE. RT 1BL prints & 1RF _~AD I N_.G_..__._&_.......B_A~.J~E.S_._.... P.ET_R_O_~..E_U~_~ C_O_ ..... 3200 MID CON FI N...:,NT~ '"P TOWER _T:.._U_5_S_:~ 0 ]K 7 4 ! 0 3 AT. TN: C. E. SEERy_,__..J.R__ RECEIVED BY: .... .., ,., l.. AlE': Nas~ Oil a Gas Cons. commission Ve~ truly yours, Anchorage SCHLUMBERGER OFFSHORE SERVICES A.D'. HUFFMAN ~C) $ ..-. 1565 -A f:;~.HLUMBERGEF< OFFSHORE SERVICES A Division. of Schlumberger Limited HOUSTON. TEXAS 77001 PL~A:3E i:q EPLY' $CHLUIR~E~GER O~F~'{O~ i ~E~4'. iCES CONOCO, INC. 3201. "C' STREET ANCHORAGE , AK '9 9 5 0 3 Attention: DAN ROBERTSON POUCH 340069 PRUDHOE BAY, AK 99734 ATTN: BD~BARA HARRISON PAGE '2 OF 2 Gentlemen: 2 r' Enclosed are ........... p ~nts of the Comp,an'/ CONOCO, INC. Field ...... _MiLNE POINT 2" & 5" D!L_,FDC. Z_C_N.L ~, Welt. _C- 6 ., County. NORTH SLOPE __On ALASKA Stcte_=t~ .......... ::-. Additional prints ore being sent to: 1BL Dr{nfs & 1RF CZ'JTi'ES SERVICE OIL AND GAS CORP. -"~'-]{9"'.,..' .... BOX 939 BAKE.RSFZELD ¢ CA 93302 AfIN: NEIL C/O JIM QUINN ............ .orints ....... prints prints ............... ~prints ___ prints .......... prints __ prints The film is._ _r_~__t_u_¥_n_~..c..~.. to_.__C.._Q._N_OCO We appreciate the privilege of serving you. Alaska Oil & Gas Cons. commission Very truly yours, Anchorage SCHLUMBERGER OFFSHORE 5ERVIC,,~c.S A.D. HUFFMAN SCHLUMBERGER OFFSHORE SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 COMPANY ' ~X-,//?~d" ~yc-/-/~/~_ ~'"~' COMPUT I NO CENTER - LOCATION ' ~'.~/ ATTENTION' WELL NmE ' ~-,~ff.) WELL NAME : · / - ~.?lf f,/.~ SERVICES · NO. OF BOXES' ~-- JOB NO. : ~'~/E/"f ADD' L T~A~I:',ES : /',) ,' l /,,'e ~ ~ -I~ /' SERVICES £ / ~'< WELL NAME \ SERVICES : / , ..... ,~ ' ~ ' .~,, ..? . - ~ .............. NO. OF BOXES' -/-~- ~o~ NO.· ~/~ Ann'~ ~A~SS : .PRINT CENTER.-' NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME : SERVICES : · ~ _ -. NO. OF BOXES: JOB NO. : ADD'L TAPES : il~ ~. C -~ ~I~ Ja3 ~'- 5 - o i~ e~ - z/~q~ - ~~ WELL NAME : WELL NAME · SERVICES · SERVICES · NO. OF BOXES: NO. OF BOXES' JOB NO. : JOB NO. ADD'L TAPES · ADD'L TAPES SCHLUMBERGER COURIER DATE DELIVERED / STATE OF ALASKA d~ ~-, ' ALASKA L AND GAS CONSERVATION C~../MISSION MONTHLY REPORTOF DRILLING AND WORKOVER OPERATION · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 84-241 3. Address 8. APl Number 2525 'C' Street, Suite 100, Anchorage, Alaska 99503 5o- 029-21257 4. Location of Well at surface 665'FSL,2289'FEL, Section lO, T13N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 52' KB I ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNG. 6 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. January ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks TD-8900' Rig released 1-25-85, Spud date 1-12-85 13. Casing or liner run and quantities of cement, results of pressur9 tests Size Wt. Grade From 9-5/8" 36 ~47 # L-80&K-55 O' 7" 26 # L-80 O' To 5691' 8883' Cement ~ 1400 sks' Permafrost type E, 875 sks. Class G w/1% CaC12 and 1% CFR-2 650 sks. Class G w/1% CFR-2 14. Coring resume and brief description NONE 15. Logs run and depth where run Logs LDT-CNL-DIL-GR-CAL-SP From 5661' To 8700' RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data 8457' - 8463', 8678' - 8708' perforations F E B 2 8 i935 ~aska 0~ ,,,,, .. .... ~mmissio~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED '~'~ ~'- /~~ T,TLE Drilling Supervisor DATE NOTE--Report on 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 10~404 Submit in duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 22, 1985 Mr. C. V. Chatterton, Chairman Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached is a Sundry Notice for Milne Point Unit Well C-6. It is proposed that the C-6 well be perforated in the Lower and Middle Kuparuk formations, then completed. A fracture stimulation treatment is planned for the summer of 1985. If you have any questions, please call Don Girdler at 279-0611. Very truly yours, Manager of Alaskan Operations DRG/kr cc: MP C-6 Correspondence File STATE OF ALASKA ALASKA O~ AND GAS CONSERVATION CO~IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL E~ COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 84-241 d~ 8. APl Number 3. Ad 5 "C" Street, Suite 100, Anchorage, AK 99503 50- 029-21257 4. Location_of Well 9. Unit or Lease Name 665' FSL, 2289' FEL, Sec. 10, T13N, R10E Milne Point Unit 5. Elevation in feet (indicate KB, DF, etc.) 52' RKB 12. I 6 . Lease Designation and Serial No. ADL 47~37 10. Well Number C-6 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject we]_l was drilled to a T.D. of 8900' M.D. It is now proposed that the we].], be perforated in the Lower Kuparuk (8646' - 66' and 8676' - 96') and then in the Middle Kuparuk (8456' - 62'). The two formations wi].l be isolated in order to fracture the Lower Kuparuk but co-mingled for production. A sub-surface safety valve wi].] be set at 1950'± M.D. The Lower Kuparuk will not be fractured wntil the summer of 1985. 41as~a Oil & Gas Cons. commis~ioA Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed(~D...~~ ~~ Title Productiol~_ Engineer The space below for Commission use Date 01--23--85 Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 22, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached is a Sundry Notice for Milne Point Unit Well C-6. The Notice is an application to increase measured depth from the permitted 8,840' to 8,900'. The increase in measured depth is a resu].t of higher hole angle. Verbal approval to exceed the permitted depth was given by Mike Minder on January 21, 1985. If you have any questions, please call Don Girdler at 279-0611. Very truly yours, John R.'~p' Manager of Alaskan Operations DRG/kr cc: MP C-6 Correspondence File RECEIVED J AN 2 1985 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA'~.~_ AND GAS CONSERVATION CE MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELLI~ COMPLETED WELL[] OTHER [] 2. Name of Operator Conoco Inc. 3. Address 2525 "C" Street~ Suite 100, Anchorage, AK 99503 4. Location of Well 665' FSL, 2289' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) ~TZ'I~ r_,?, _ 'P~rl 17' i2. 6. Lease Designation and Serial No. ^nT. A7434 7. Permit No. 84-241 8. APl Number 50- 029-21257 9. Unit or Lease Name Milne Point Unit 10. Well Number C-6 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) : (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] ' Stimulation [] Abandonment [] Repair Well [] Change plans X~] Repairs Made [] - Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any : proposed work, for Abandonment see 20 AAC 25.105-170). The subject well was originally permitted for a total depth of 8840' M.D. (7200' TVD). Due to directional control problems in the surface hole (higher hole angle than planned), the measured depth of the well will exceed the permitted depth by ±160' (9000' M.D.). The well is expected to reach T.D. 1-21-85. Verbal approval was given by Mike Minder on 1-20-85. RECEIVED JAN 2 1985 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use~'x~ ~ x, Conditions of Approval, if any: Approved by gllitJ111AL SlGItF. II Title ..... ,_.. __ P~vd~ ..... Engineer Date Ol 21-95 ~pproveCl Co~y Returrmd By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM State-of Alaska TO: THRU: FROM: ALASI~A OIL AI~ GAS CONSERVATION COmmISSION ~. v. ~h~/~t~o~ Ch~a~,L~/ Lonnie C. Smith '~' ~ TELEPHONE NO: Commissioner ~-i Bobby Foster~'=-~, Petroleum Inspector DATE: January 18, 1985 FILE NO: D.BDF.5 SUBJECT: Witness BOPE Test on CONOCO' s C-6 Sec. !0, T13N,Ri0E,UM, Permit No. 84-241. Thursday, January 17, 1985: The BOPE test began at 8:00 am and was ~dnClnded'at 9:00 am As the attached BOPE test report shows there were mo failures. In summary, I witnessed the BOPE test on Conoco's C-6 Attachment 02-00IA(Rev. 10179) O&G It4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspec ~'~ Well Operator /~t~f~ f3 Repros entat ire ~~ ~~~/~ ~ Well ~ ~---~ - Permit t~ ~~-~~/ Location: Sec /~ T~~~ M ~ ~ Casing Set @ ~ ~/ ft. D rillin~ Cont ~actor.~. ~¥~/~i ~/~ ~Rig tI ~ R epres e ntative~~,~z~ ~~,~_~ oj Location, General ~.~ Well Sign ACCUMULATOR SYSTEM General Housekeepin~ Reserve Pit ~.~ Mud Systems Visual Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve .. Rig Audio Test Pressure Test Results: Failures Full Charge Pressure~ir-O psi~ Pressure After Closure/~~ psig Pump incr. clos. pres. 200 psiK _. Full Charge Pressure Attained: --~ Controls: Master L~ Remote~~ Blinds switch cover L~ Kelly and Floor Safety Valves Upper Kelly / Test Pressure ~~ Lower Kelly / Test Pressure ~g~ Ball Typ~ / Test Pressure ~'~z~ Inside BOP / Test Pressure ~-o~f~ Choke Manifoldj~~_Test Pressure~~-~ No. Valves // No. flanges ~G Adjustable Chokes ~ Hvdrauically operated choke / Test Time / ' hrs. ming se=. sec. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector.~~~ ~ ~. ,~~PJ~ December 21, !984 Dan R. Girdler Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503-2689 Re: Milne Point Unit, C-6 Conoco inc. Permit No. 84--241 Sur. Loc. 665' FSL, 2289' FEL, Sec. 10, T13N, R10E, Ut-!. Btmhole Loc. 2676' FNL, 4317' FEL, Sec. 14, T13N, R10E, IR~. Dear }{r. Girdler: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and amd log are.not required. A continuous directional survey is required az 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 spawming or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations prommlgated 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 prommigated 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 Enviro~nnental Conservation. 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, gR~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission 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. Vet_fl tru~L_~ours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION lc Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Doug L. Lowery December 19, 1984 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Chatterton: Attached to this cover letter are applications for "Permit To Drill" for Conoco's Milne Point Unit wells C-6 and CFP-2. The CFP-2 is the first well drilled on the "Central Faci].ities Pad". ~s very truly, D. R. Girdler Production Eng~.neer Attachment RECEIVED DEC 1 Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA'~..c,L AND GAS CONSERVATION CL~_AMISSION PERMIT TO DRILL 20 AAC 25.005 p J~' ~ J"" ! ~ # .,.,,,..... la. Type of work. DRILL REDRILL -DEEPEN I b. Type of well EXPLORATORY [] DEVELOPMENT OIL E~ DEVELOPMENT GAS [] 2. Name of operator Conoco Inc. SERVICE [] R S,NGLE ZONE/ EZ:.. MULTIPLE ZONE-ET I 9~ Alaska Oil &a,,.,._Gas Cons. Commission 3. Address 2525 C Street, Suite 100, Anchorage, AK 99503 .... ',,,urage 4. Location of well at surface 665' FSL, 2289' FEL, Sec. 10, T13N, RiOE, U.M. At top of proposed producing interval 2500 FNL, 4500' FEL, Sec. 14, T13N, R10E, U.M. At total depth 2676' FNL, 4317' FEL, Sec.14, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) RKB 52' Pad 17' 6. Lease designation and serial no. /I/~T~./~,)~ A~ ~ qTq~7 9. Unit or lease name Milne Point Unit 10. Well number C-6 11. Field and pool Kuparuk River 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 Amount $200,000,00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 33 mi. NW of Deadhorse miles 3064' @ Surface feet C--b well 120' @ Surf. .feet 16. Proposed depth (MO & TVD) 17. Number of acres in lease 18. Approximate spud date 8840' MD(7200' TVD) feet 2560 12-22-84 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures .~)~) ~ psig@ Surface KICK OFF POINT 850 feet. MAXIMUM HOLE ANGLE 4~ (see 20 AAC 25.035 (c) (2) 3~00 psig@ 7200 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program t SIZE I Hole Casing Weight i 1 13 3/8 48 I 12k" 9 5/8 36 t 8!~" 7" 26 CASING AND LINER Grade Coupling H-40 PELP K-55 BTRS L-gO BTRS Length SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 80 35 ' I 35 ' 35' i i 35' i 35' I I 35' M D BOTTOM TV d 115' Ii 115' 5430' I 4600' I 8840'1 7200' I I (include stage data) ± 100 cf 1400 sxs. Permfr. E 950 sxs. Permfr, 700 sxs. Class O'Describe_proposed program: noco ~nc. proposes drilling the subject well as a development well in the Kuparuk River Field. Mud system will be a non-dispersed low so]ids with a minimum mud weight in surface hole of 9.0 ppg and a maximum of 9.8 ppg. Mud weight at TD will be 10.2 ppg. A 20" 2000 psi diverter wi].], be instal.led on the 13 3/8" conductor for drilling the surface hole. A 13 3/8", 5000 psi RSRRA MOPE stack will be used on the surface casing. Pressure tests will be done as per state~,~gulatio~s .... Ma~mum .~urface pressure is based on initial r ser ir ,r sur n ~c~c] -n t~ _u~i=- ~ 'ng wi] e ~ ed ___ , ........ c -ny ...... wm..c_c. Arctic Pak will be placed in the 9 5/8 x 7 annulus after disposing of test oil and excess drilling fluids. The well wil be perforated and completed with the drilling rig then fracture stimulated after releasing '~j T he~r~i~y~~r~g~%n~'is t~u~~rr'~c~¢t~ tH~%es%-Df ~y ~o~1~¢ ' ~-- .... , ...... SIGNED~~ ~ k~_~~ !~.-/~-~ TITLE Production Engineer DATE 1]-26-84 The space below for Commission use Samples required [-].,YES ~10 Permit number APPROVED BY ~~~, i Form 10~01 Rev. 7-1-80 CONDITIONS OF APPROVAL Mud[-]YES Icg required I! ¢I~YES Directional []NO Survey requiredAPl 50-- O%~' number Approval date ~ ?J,~'l /P,/..~ ~ SEE COVER LETTER FOR OTHER REQUIREMENTS //~'/_~ ,COMMISSIONER DATE December 21, 1984 Submit in triplicate I. SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. C-6 CEMENTING PROGRAM_ Conoco Inc. 2525 "C" Street, Suite 100 Anchorage, Alaska 99503 RECEIVED rOEc Alaska 0~1 & t~as Cons. Cornrni$~lor~ Anchorage The 13-3/8" conductor wi].], be set at 80' below the surface 115' K. B., then cemented to the surface with permafrost cement. Be The 9-5/8" surface casing will be cemented with 1400± sacks Permafrost "E" cement followed by 950 sacks of Class "G". A top job will be done if is not circulated to the surface. C. The 7" production casing will be cemented in two stages. The primary cementing job will consist of 700± sacks of Class "G" cement pumped around the casing shoe (estimated 2000±' of annular cement, assuming an AHS=ll"). The secondary cement job will consist of 200± sacks of permafrost type "C" cement followed by 60± barrels of Arctic Pack, pumped down the 7" x 9-5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated based of permafrost at 1700±. 5000' - TD Predominately shale until, the Kuparuk sands - expected at 6700± subsea TVD. III. FORMATION EVALUATION A. Sidewall cores to be taken as determined, by onsight geologist. B. Wireline logs for the 8~" hole from T.D. to the 9-5/8" shoe will include: Dual Inspection Laterolog; Sypherically Focused Log; Formation Compensated Density with CNL and GR-caliper. We do not plan to log the 12¼" hole. IV. DRILLING FLUID A high viscosity gel-fresh water mud system 0' - 1000' Low sol. ids non-dispersed mud system 1000' - T.D. V. DIRECTIONAL PROGRAM The well has a proposed KOP of 850' and will build angle in a 44° east direction. ~^~-~ ~-scsc.,_, that-tLe ~-,. '~ ~ ~will--ccmc ~c~ ancthcr w~tq ~rc i~frcm the .surface te~~ k_',.~a4c-~£f d~pth where, thc prc~csad--G-6- ~g 5c !2~_' nnrth;.;agt cf---thc 'axlgtlng C-5 w,=l~:. An MWD too]. is to be run while drilling for surveying purposes. Final hole angle will be 40°. · ~ 'NO ~, ',OPOSED POINT, NORTH SI~OPE, iALA$ NO,WI i' ~00i I'i ; , , . , · , _ . . EASTHAN WHIPSTOCK. INC. PAD C. WELL NO, 6 PROPOSED .......... 'HILNE POIN/...NOF-H SLOPE. ALASKA ; =____~ ....... 200Q._ · ! * . 1 , ..... $0.00.__ . .. ! · . ..... i . .... ! ~ _6000_ . , _ ~ , . . , . . . , . . ..... 2 ............. 7000._ , SURFACE .......... , ............. , .............~ .................... ~. ........................................ .... ........................ ! DE:P :" KOP TVD=850 TMD=850 =0 ~ .--....-..-..--.-~ , ' I ' ' : : ''. ~ ' -! ' · ' , \...-,s.:-.: ........ : .......... : ..... :-.-:-] ............. : ...... ' ..... : .... :._::_:__: :: : L:=::-~:"~ ............... ~ ' PER lO0 FT ' ' ~ ~ : ~ ' - - ~ - ~ · ~ 2S : ' ~ ....... ~ - ~ -.t ' - EOB TVD=2~33 TMD=2463 DEP=545 ~ ; - ~ ~ ~ , ..... ~ : ~ - ~ .- -~ - ~ ; - i . . . { { : · . ~ .. ~ ~ ~ -~ .. ~ ; ~ :, · .:.'' ; N:-' I .:- ~ ".~ _ ~ ' ' : ~.::I.:::~:: .... ~ ~ --~. : ~ ; ..~ ....~ ..... ;. ~.. -~ ..... ;~.. .............. X .............. ~ .... ~ ...... : ............ ~ .......... ~.~-.~ .... ~ ......... ~ ........ ~~~~.. ' ' ' ~ 'X ' J ' ~' ; ' : ~ ' ~' ' , ~ ' ~ i '' · :.:i ..... .... '' ~ '[ ~ '; ' ...... {xA-SANDS .... IVQ~4000;~.B~4650_.DEP_~.~96E~: ;::;::j__~::.:~ . · ; · ~ : - . ~ ....... f ....... ~ - ~OB SANDS :TVD=4400 'T~D=5175 DEP=2300 '-: ..... 40" 'DEG'-' 20 .... H[~UT:~ ...... X-~ ' ' ' 'l ' ' ' ~ ' ~ ' - ' - , . - . _ _ . i ~ ' ~X : - ' - ~ : ' t - I TARGET TVD=6900 THD=8454 DEP=4423 ~_ ':":~:' 3 TD TVD=Z200 THD=S8~8 DEP=~677 I I I I-' ' - - : I . 2000 3000. 4000 . · ; ; I -.HOR"~ONTAL ..... PRoJECIION_., 'SCALE 1 IN = 1000 FEET ; ; PAD C. WELL NOt 6 PROPOSED ' MILNE POINT. NORTH SLOPE, ALASKA ............. ~ ........ ~ .............. - , EASTMAN WHIPSTOCK. INC. · ~000 !.000_ .5000 ..... , · _ .................. ~ ........ :WEST-~EAsT 0 ~ :1 000' ~ 2000 SURFACE LOCATION'* 665T FSL, 2289' FEL ' ' SEC; I0. TI3N. RI OE - i TARGET (M~D KUPARUK)'i : I rVD-eeool ..... ............. T~D-845~.j { DEP=4423t ~ -- ! ! i SOUTH 3165 ~ ...... i ~.EAST~.3089-. · TARGET LOCATION, i' 2500' FNL, 800' SEC.: I ! : S 44 D ~ 442g' I . .' :3000 ~000 5000 i EG 18 .CTO .T 1 CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK Fill-up Line RECEIVED Anchoraoo Flow Line 20" 2000 psi Annular Preventer ValC~ve [ . . :.1 Valve , , _ ~ Drilling~-~_~_. 6" Relic' f 6" Relief Line It~[i ) Spool ( Ill>~ll ] Valve ~ ~ i2o" x 20" , I 2000 psi ,' ', Connect Assembly ' '-i _[Starting l I '.' ''! ~ , J I.". C:i I !.'-' 1. Relief lines .from the drilling spool will be routed for downwind diver s ion. 2. Hydraulic control system will be in accordance with API specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 CONOCO INC. MILNE POINT UNIT BOP STACK Fill-up Line~Fl°w. IAnnular Preventer Line (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressUre tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 claSs 5M requirements. RAM 13 5/8" - 5000 --RAM 13 5/8" - 5000 3" - 5000 Side Outlets 2" - 5000 Side Outlets 3" - 5000 Side Outlets' RAM 13 5/8" - 5000 11" - 5000 - . RECEIVED DEC I Alaska Oil & Gas Cons. Commission Anchorage ALASKA UNITED DRILLING . RIG NO. 3 LIQUID MUD SYSTEM C^P^aT~ES ACTIVE SYSTEM PJ ~ sanu trap tS I Degasser tank 56 bbl Active ~ ~,~.~,~c~on I Desilter su~ion SS bbl I DesiRer discharge 66 Solids removal fun~ion ~uu Tank No. I I Common 38 2 Suction Mud Tank No. 2 4 each: 6"x 6 "centrifugal pumps, 75 hp Receiving 184 bb, Discharge 184 bbl Mud Tank No. 3 240 bbl pi tS SUBTOTAL 768 bbl Resewe ~cr~v~ SYSTEM TOTAL I~S TRIP TANK 150 bbl SURFACE VOLUME GRAND TOTAL I 155 bbl each: Lightnin' mixers, 5 hp ICa~cu,ate~ 4" ~e,o,, tanktop~ CHOKE MANIFOLD' Working Pressure 10,000 psi w/ (2) HCR valves · Choke (1) Type (2,) Manual Choke (2) Type ( 1 ) Automatic ALASKA UNITED DRILLING RIG NO. 3 Bu'rTERFL¥., V, RLVE CLOSED : DESANDER SUCTION CLOSEO Flow path.'-,'.. _.._'] Solids removal ~ · DEGASSING FLOW PATH I Flowline (in) & pass shaker screens 2 Shaker discharge into sand trap (ditch to pit room closed) 3 Sand trap overflow into degasser suction (desander suction closed) 4 Degasser discharge into ditch S Overflow returns to degasser suction (underflow butterfly closed) & Switch desander suction out of degasser t~nk 7 Desilter suction (Normal) 8 Cleaned mud to treatment pit 9 Underflow from treatment to suction pit 10 Gravity-flooded suction WELL J C-I LOCATION IN SECTION FROM S. UNE FROM E. UNE 1168' I c-z I ,229' C - 3 I 1395' C-4 ~ 1344' I c- 5 I 551' C-6 N SI w ~N LAGOON MILN[ PT. UNIT : H - I REC[ V co o o MILNE POINT UNI~ C-7 I 7~O' !. STATE PLANE CO-OROS. GEODETIC NORTHINGS EASTI NGS STATE PLANE CO-ORDINATES ARE zOI~E 4. · ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED I BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. J i c-Bi C-lO J _. 2256' 6,029,450. 18 2459' 6 ,029,510. 13 2326' 6 ,029,677.35 2494' 6 ,029,624.55 G. oz~, ~33.44 947. 7 o 4,.oz? 558,203.55 557,999.90 558 , 131 .12 577 ,963.21 55~, Z~t. 84 555, SSB, 13&.57 ~. oz~, 17G ioo~' 237G' G.oz9 z9o-z~ 55B,OGS. 34 . . ~j 14- 'z.4z$ (~.0z9 595.22 555 o~1. 77 LATI TU DE J 70°29' 27. aEC" N. J 70029. 28.473"~ 7o~z9' 30. ,o8" n. 7o° 29' 29. 599" N. 7o'.zg-zi. SOl. LONGITUDE ! DATE 149°31' 27.056' W. J 4- 20-82 14 9° $1' =j3.036' W. I la-B-aZ 14~ 3l' 29.135~ W. I _4-20-82 149° 31' 34.089"W. J 2 -20-83 147'-51-Z&.gs4-w J Il - I CHECKED FIELD BOOK I0- 82 I LK. L.K. I0- 8? J L x: !0 -SZ j t 24-$4 J 24 -64 CERTIFICATE OF SURVEYOR : I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED lO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION 'SURVEY MADE BY hie OR UNDER MY SUPERVISION, A-ND THAT ALL D~MENSIONS AND OTHER DETAIL.~ ARE CORRECT. 'C' PAD AS- BUILT WELL LOCATION lo ~ 3" I~ ~ %FcT. lo Surveled for CONOCO i SCALE : J SHEET : I" · 400' J I OF 2 COMMENTS; ~JEL. I- c - ~ VJ ~--_:LL LOCA-Ti ON S CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~D~-- / ~- '/~-~ 1 Is Company the permit fee attached ......................................... YES NO REMARKS (2) Loc (Z thru 8) (3) Admin ~t.-- /5 7L87 9. (9 thru 12) 10. nd 12) t 12. (4) Casg (13 thru 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 2. Is well to be located in a defined pool .......... 4. Is well located prOper distance from other wells ..... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .... 7. Is operator the only affected party ......... Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~-- Is administrative approval needed "~ e®®eee®ee,®e®ee®eee®e®®e®eeee~eee·® Is the lease number appropriate ..................................... Is conductor string provided ..... Is enough cement used to circulate'°n'c°nduct°r'and'~A~':::::::::~ Will cement tie in surface and intermediate or production strings... Will cement cover all known productive horizons .......... . ...... ' ' .,~_. ' Will surface casing protect fresh water zones ................... ~- -ff~ Will all casing give adequate safety in collapse, tension and burst..~o*~ 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 eeeeee®®eeeee®®®e~e®eeeeeeee · , Is a diverter system required . ............................... Arenecessa,~7,diagrmas. of diver~er:and~OP'equ~pmen~,attached :::::::~ '- Does BOPE have sufficient pressure rating - Test to ~,ff~ psig .. ~ Does the tho.k· manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable eeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Additional requirements .............................................. Additional Remarks u /AL., ;3£ O ~0 wCe. ology..~/~ ~.~ne,ering: LCS S rev: 10/29/84 6. C~T 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 effod has been made to chronologicallY organize this category of information. , I-r'l bis T~PE VFR!E!CATIOM LISTING LVP 01o,~.~0~. VE:PlFIOA'rlON L]'STIN,'.., PAGE. ~5!0]/1 7 : 135747 ~DNTTN~IA~ION g RFEL : :LIBRARY TAPE SEP~V~Cm ~A~E ;gOT:r DATE :~510~t~7 ~RIGT~ :CO00 rA~E N ~ ~ :0008 CONTI ~.~AmlnN ~ PREVIO~S TAPE COmMeNTS :LIBRARY ~APE ** INF'r~R~,~ATION RE, CORDS ** CN ~ ODNOCO ALASKA WN '~ FN : KUPAR[JK RIVEP RANG: TOWN: SECT: COUN ~ 8T,~T: ~b,~SKA CT~Y~ ** COM~EMTS I~NIT TYPE CATE SiZE CODE 000 000 013 O65 000 000 020 065 000 000 014 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 003 065 bVP Ol~.~O~ vE~I~ICA~]O,.'~ ~'~I$?!~.IG PAGE 2 al]ASKA CO~PUTI~G CFNTE~ ************************************************************************************ ~ELb = ~,ITLr,~E POINT UNIT C-6 PI~LD = K, UP~Rt~K RTV~R COUNTY = ~ORTH S~.OPE B~ROU~H JO~ ~IUt'B~R a.m ~CC: 700n8 RU~', ~1, DATE GDP: TYPE DENS?7[Y PH = 9.b75" 8 5643' - BIT SIZE = 8.5" TS ~900' = PnLYME~/LOW SDLIDS = 1~,? t,I%/G R~ = ?,.590 a 68,0 DF = 41.0 S a~r = 2.560 e 67,0 D? = 9,0 R,"C = 2,230 ~ 67,0 DF -' 5,2 C~ R~ AT BHT -- 1.1,63 ~ lbO,O DF ~ATRTX S~NDSTO~E ******************************************************************************* ,¥P OIO.~q02 v[PI,wiCATJ, r~l',J L, TSTi.~tG PAGg 3 DATUM SPECIFICATION RbOCFS ~NEM SMRVICE SERVICE t)NTT API API API ~P! FILE $I%E SPh REPR DEPT Ibt~ ,n.. IL CALl ~HOB LD~ NRAT NPWI LDT PEF bDT FCNL GR C N: L NRAT CNL RN~A CNL MPHI ~CML CNL PCNL CALl LOG TYPE CLASS ~OD NO, CODE PROCMSS (OCTAL) PT O0 000 O0 0 0 4 OHm~ O0 220 01 0 0 4 OH~ O0 120 46 0 0 4 ~H~F~ O0 120 4,4 0 0 4 ~V O0 niO Ol 0 0 4 GAPl O0 3!0 01 0 0 4 ~AP! O0 3~0 O! 0 ~ 4 IN O0 280 01 0 0 4 0/C3 nO 350 02 0 0 4 C/C3 O0 356 01 0 0 4 O0 420 O1 0 0 4 O0 000 O0 0 0 4 PU O0 890 O0 0 0 4 O0 35~ Ol 0 0 4 CPS O0 330 31 0 0 4 CPS O0 330 30 0 0 4 GAPI O0 310 Ol 0 0 4 O0 420 O1 0 0 4 O0 000 O0 0 0 4 PU O0 890 O0 0 0 4 CPS O0 330 31 0 0 4 CPS O0 330 30 0 0 4 IN O0 280 Ol 0 0 4 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ** DATA ** DEPT SP NPHI GR NCNb DEPT SP -099,~500 GR 16.!875 DR~O 20,9805 PEF -~99,~500 ~R~T -99~,~500 FCNL .4720625 -~99 2500 !LO 5 0156 uR,a.T 1:9854 ~CNL: -9992 s0o 9.6953 '919'0000 GR -099.2500 IbM -919.0000 CALi 2 7383 RNRA 2771~ 0000 FC b -999,2500 NPHI -999,2500 9,3438 IbM -919,0000 CALl -999,2500 ~,5000 2,8262 -9800,0000 -999,2500 0,2969 16,8437 ]VP Ol.q. HO~ vEPtFICAmIr:N LI6TING PAGE 4 ~ P H 1' ~CNL )EPT 5P ~HOB VPHI VCNL DEPT SP RHOB NP,I :R DEPT SP NPHI ~R NCNI., DEPT SP ~PHI NC.L ~EPT RHOB ~P~I ~C~ DEPT SP NPHI NCNL ~EPT 37.~135 DE? -q99.9500 NRAT -099.9500 FCNL 860n.0000 Sf'LU -42.~500 ~R ~.4043 nRHO 2R.4668 PEF -ogq,?500 FCNL 8~00.0000 SFLU 40.50n0 CR ~.~965 DRMO 30.2246 PEF -n99.~500 NR~T -~9~.25n0 FCNL 8400.0000 2:4043 ~RHO 3~ 5938 DEF -q9q:~500 MRAT -999'9500 FCNL 8300.0000 SFLU -53.7500 ~R 2.4551 DRHO 37,6953 PEF 999 ~500 NR. AT 2999:~500 FCNh 0000 .999,2500 FCNL 8100 0000 SFLU -57 7188 ~R 2 3672 DRHO 47 7539 PEW -gg~,~500 ~R~T -~9q,9500 FCNL 8000,0000 SFLU 75 GR 99q,~500 PEF -999,2500 NR.~T -999'~500 ~CML 0.1592 1.92~8 -999.7500 -99q.7500 6,3164 75.4375 2 4473 9 2500 -~9~o2500 77:6250 -0,n088 ~.~8~7 -999.~500 -o99.~500 2 9980 112 8750 0 0361 2 6289 -999 7500 -q9q ~500 2.0801 12!,t875 ,0801 ~5645 -09~,~500 -09.,2500 ~,37~9 113~4375 0.014,2 ~,4082 -999.2500 -q99,2500 2 1406 ~21 2500 -0 0107 3 1445 -999 2500 -999 2500 ? 5430 179 3750 -999 2500 -999 2500 -999 2500 -o99 2500 NRAT ~C~L CAt. I GR NR~T ~CNL CALl GR NRAT CALl NRAT ~CNL CAbI NRAT CALl T bO NR~T NCNb RNRA CALl ! ~R NRAT RNRA CAL, I ,TbD ~R MRAT WCND CALl 2,8145 RNRA 2578.0000 FCNL -999.~500 NpHI -999,2500 5.4492 IbM 75.4375 CALI 2.6641 RNRA 2704:.0000 FCNb -999.~500 NpHI -q99.~500 7.1398 ILM 84.1250 CALI 2.7793 RNRA 2824.0000 FCNL -~99.2500 NPHI -999,2500 ~.1270 IbM ~ ~750 CAbI 3:0273 RNRA {12,0000 FCNL 299q,2500 NPHI -999,2500 2,0996 IbM 122,1875 CALl 3,2773 RNRA 2120,0000 FCNL -999,2500 NPHI -999,~500 113~43 ~ C~LI 4'1445 R, NRA ~897,0000 PCNb · 999.2500 ~PHI -999'2500 1.8936 IbM I2~.,~500 CALI 3,7910 RNR~ 1860,0000 FCNb -999,9500 ~PHI -999,2500 2,2852 IbM -999.2500 CALl -999.2500 RNRA -999,2500 FCNb -999,2500 NPH! -999,~500 3 0273 85~.:5000 -999,2500 5,6406 8 8281 2i6250 030 0000 1099,2500 7.1836 8,78ql 2.9473 959 0000 -999:2500 ~.~207 ~, 328 ,2324 653,0000 '999,7500 2 17q7 9 4297 3 2969 643 0000 '999 2500 1 5723 q 2969 4 1250 459 7500 -099 2500 t.94. 2 9.0156 ,912! .47 ,2500 ~99,~500 2 2949 -999 2500 -999 2500 -999 2500 -q99 2500 PAGE 5 )P '48~75o0 Ga 1.16 ~HOB -Q99.25o0 nRHO q99 ~PHI -998.7500 PEP ~99 ~R -~9~.7500 ~3~aT -990 )EPT 7800 0000 SF!,[,I ~ ~P -65i~125 ~R 1.4! ~HOB -~99 ~500 DRHO -~99 ~P~I -~99.9500 DE~ -~9~ ~R -99~.9500 ~RAT -~9~ gCML -099.2500 FCMh -990 9EPT 7700.0000 ~P -71.1.250 GR 1.65 ~HOB -q9o.2500 OReO -~99 ~PHI o9q,~500 ~R 2999.2500 ~RaT -99~ ~CNb -ogq,~500 WCNb -999 ~E~T 7600 ~P -53 ~HOB ~PHI -099 ~R -o99 0000 SFLU 500O GR 155 :2500 DRuO -99q 2500 PEV -qgq 2500 ~500 WC~L QEPT ~500 0000 SFLU 4 SP -51:8750 ~R ~HoB 99q.~500 DRHO -999 ~PHI -~9q 2500 DEF -999 GR -999i~500 ~RAT -990 NCNb -o9q 9500 wCML -999 DEPT 7400 O00u SFLU 2 -q99 RHOB -999,~500 DRHO NPHi -~99.2500 DEF ~R -099.~500 ~)R~T ~99 NCNb -o99.9500 FCNL q9q DEPT 7300 8P -73 ~HOB NPHI -99~ GR NCNb SP -66 ~HOB -q99 NpHI -q99 fir -999 n6~5 GR 127 ?500 DRNO -q9q 250o DEW ~o9q ~500 VC~I., 999 0000 $~LU 2 ~5o0 DRHO ~500 ~RAT 052'1 :0000 2500 i2500 ?500 .2500 1758 5000 ~500 2500 2500 2500 .3164 ,7500 .2500 2500 25O0 2500 ,n742 .ouoo 25OO :2500 250O :2500 4531 5000 25O0 2500 2500 2500 .1426 2500 '2500 ,2500 ,2500 .2500 .9824 ,5625 .2500 ,7500 ,2500 .2500 .4238 ,7500 .2500 .2500 .2500 TI,:D ~R NRAT ~CNL ~N~A CALI NRAT NCND RNRA CALI ILO ~R NRAT NCNb RNRA CALl NRaT NCNb CAb! NCNb RNRA CALl GR NRAT NCNb DNRA CALI ~R NCNb RMRA NRAT ~CNb RNDA 9.!,133 IbM -999,2500 fALl -99~.~500 FCNL -999.2500 NPHI -99~,~500 2.7559 IbM '999 2500 CALl -999:2500 RNRA '999.2500 FCNb '999,2500 2,B6ql TL~ -999.2500 CALI -99~,2500 RNRA -999.2500 FCNL -999.~500 NPMI -999,~500 1 -999 -999 -999 -999 -999 .22~7 IbM 2500 CALI 2500 RNPA 2500 FCNL ~500 NPHI 2500 2,601.6 Ib~ -999,2500 CALl -099,2500 RNRA -999,~500 FCML ~999,2500 NPHI 999,~500 1.9521 IGM 999,2500 CALI ~99~,~500 RN~A 99,2'500 2.8555 '999,2500 CALi -999,~500 -099,~500 FCNb -999.~500 NpHI -~99,~500 2.5488 Ih~ '999,2500 CALI '~99,2500 RNRA '999,2500 FCNL '999,~500 NPHi 2,2383 '099.2500 '999,2500 '99g.2500 '999,2500 2 8398 -99~ 2500 -999 2500 -999 2500 -999 2500 3,0664 -999,2500 -99q,2500 -999,2500 -999,2500 1,3320 -999'2500 -999,2500 -99 500 2,~043 -999' 500 -q99~,2500 -99 ....,2500 .,999,~500 2 0234 -999 2500 -q99 2500 -999 2500 -999 ~500 ~.9238 -999,~500 -999,2500 -999,~500 -999,2500 2.5391 -999~2500 '999,2500 -q9q. 2500 ~C ~t L -~99,P500 CALI ')EPT ~P ~HnS qPNI ~R ~ICNL 7~0o o0oo 8Ft,,o -999.2500 PASO -~99.7500 PEF' 2.9258 97.0000 5oo - 9 .25oo cat, ~R 61~Kb25 2.8145 92 7500 -999:7500 NRAT 9q:2500 ~NRA -999,~500 CALl ~EPT ~ICNI, ~00 O00O -~99.75n0 -99~.2500 mCNB 2.3848 TLD 111.3750 GR -999.2500 NRAT -o9~,2500 ~ICNL -099,2500 RN~A -999,~500 CALI QEPT SP RHOB WPHI WCNL 6~00.0000 69.8125 ~R -999.2500 DRNO -~99.7500 -~99.2500 -.99,~500 WCNL 2.5684 89.8125 -999,2500 -q99,2500 NCNb -999.2500 ~NRA -~9~,2500 CALl DEPT ~P gPHI ~CNL 6700 0000 SF[~U 3.6152 IbD -8~:3125 eR 86.31~5 GR 99 2500 DRN[] -999'2500 NR~T ~99"2500 DEF -99~2500 NCNb '~9g'2500 ~RAT -999'~500 ~NRA -999~7500 FCNL -099,2500 CALl ~)EPT SP RHOB -999'2500 PE~ -999.~500' ~RAT -~99'2500 ~CNb 3 4199 IbD 89 7500 ~R -999 2500 NRAT -999 2500 NCNb -~99 2500 PN~A -999.2500 CALi DEPT SP RH00 MPW! ~R NCNb 6~00 -69 -999 -gg9 -,~99 -999 0000 SFLU 1,74.80 ILD ~500 GR 93.~750 2500 DRanO -~99,2500 NR~T ~500 PEF -999,2500 ~500 NRAT -99~ ~500 ~NRA 5oo -9 : 5Oo DEPT 6~Od 0000 SF!,U 72~7500 GR -999.25~0 9R~40 2.3027 110.3125 GR -999'2500 ~RAT -999.2500 2,9402 Ih, =999.2500 CA[,I -999.2500 RNRA -999,2500 FCNb -99~,2500 NPHI -999,2500 2.8965 IL~ -999.2500 CALI -999.2500 RNRA -999.2500 FCNL -999 ~500 NPMI -~99:25n0 53J3 -999:2500 CALl -999,2500 rn~A 2500 -999:2500 NPHI -999.2500 2 6719 ILM -~99 2500 CALl -999 2500 RNRA -999 2500 FCNL -999 2500 NPHI -999,2500 3.6953 IbM -999.2500 CALl -999'2500 RNRA -999*2500 FCNb -999,2500 NPHI -999*~500 2,7891 IbM 999.250 RNRA 999,2500 FCN5 ~999,~500 NPHI -999.~500 2.0449 Ib~ -999'2500 CALi -999,2500 PNRA -999.2500 FCML -999,2500 NP~I -999.~500 2,42i9 IbB" 999,2500 CALl ~999.2500 RNRA 2 97~5 -999 2500 =999 2500 -999 2500 -999 2500 2.9121 -999,2500 :999.2500 ~99.2500 '999,2500 2 5449 -999 2500 -999 2500 -999 2500 -999 2500 2 6914 -999 2500 -999 2500 -999 2500 -999 2500 3 8437 -999 2500 -999 2500 -999 2500 -999 2500 2 9121 -999 2500 -999 2500 -999 2500 -999 2500 2 0332 -999 2500 -999 2500 -999 2500 -999 2500 2. 023 '999,~ 500 -999'2500 qP~I -999 2500 OEF ~R -090:2500 mRbT ~CNL -~.9o. 9.500 ~C~IL -99a.2500 MCML -990,~500 CALl 6300.0000 SFLO 74 7500 -u9g ~bnO ~!RAT 2,640b 109.0625 -99~ ~500 -999,~500 ~C~L -~99,7500 -999.7500 CALl DEPT ~P ~HOB ~R 7~5000 ~R -~99.2500 DaDO -999.~500 DEF -999,?b~Q ~!RAT 2,4434 II~D 82 56~5 ~R -O99~2500 NRAT -999,2500 ~CN5 -999,~500 PN~A -999"7500 CAt./ DEPT ~PNI 0100 0000 SF~,U -q99 P500 DRHO -999i2500 -gDO 2500 ~R~T -~9~'~500 2,1~55 94.2500 GR 2500 ~RAT 99~500 NCSIL 1999,2500 999.~5oo NPHI ~R 6000.0000 SFt, U -84,0000 ~R -'~99,~500 DRHO '699.2500 PEF -999.~500 NRAT -~9~500 wC~!h 2 5859 I5O 86 7500 GR -g9g 2500 NRAT -999 2500 ~CNL -999 2500 ~NRA -~99 ~500 CALl DEPT SP gPHI ~R NCNb 5~00.0000 77'5000 GR"' -e99'~506 -999'7500 -g99,~500 ~!RAT -999,~500 FCNb 7109 lbo -999,2500 RNRA OEPT SP ~HOB ~PHI GR NCgb ] 00,0000 SFt.,U 7~,~500 ~R 999'9500 DRHO '999,~500 DEF '999,7500 ~IRAT -099,2500 ~C~L 1.8906 IbD 92 6250 GR -999 2500 RRAT -999 2500 NCNb -999 2500 ~NRA -999 2500 CALl DE'PT SP NPHI NCNb -999,2500 DRHO ~500 PEP '999*~398 2~.03, .... 1.,9238 ILO 75,5000 -999,2500 NRAT -999,2500 3,519B ~NRA 578,8125 CALl: D£DT 5600 -099,2500 -999,2500 FCNb -999,2500 ~!PgI i099,25n0 2,7129 7L~ -999,2500 CALI -999,2500 RNRA '99a,2500 FCNL Z99~,2500 NPNI 999,~500 2,6523 Ibm -a99,2500 CAI,I -~99,2500 -999,~500 FCN~ 2 99. 5oo .~99,2500 ~,4043 Ib~ -999 2500 CALI -999:2500 RN~A -990,2500 FCNL -999,~500 NP~I '999,~500 ~,3223 IbM -999 2500 CALl -999:2500 RNRA -999.2500 FCNb -999,~500 NPNI -999'~500 2,2480 Ibm -999,2500 CALI '999,2500 -999,2500 FCNL -999,~500 N'PHI '999. 500 i 99 2500 · 2 7539 -999 2500 -999 2500 -999 2500 -999 2500 2 6426 -999 2500 -999 2500 -999 2500 i999 2500 2 1797 -999 2500 -999 2500 -999 2500 -099 2500 2 3418 -999 2500 -999 2500 -ggg 2500 -999 2500 2 1387 -999 2500 -ggg 2500 '999 2500 -999 2500 2,3438 -999,2500 CALl -999,2500 RNRA -999 25 O 63 i NP~I 1:0332 -g99.:~500 2 3359 -999 2500 -999 2500 -999 2500 41 2598 '999,2500 )EPT 5900 0000 SFLU ~HOb -o9o.~5no ~PNI -09o,2500 PEP .~R 33,3242 ~R~T 9EPT 5aOO.O000 SF!,U ~P -099.9500 ~HOb -o99.7500 DRgO gpHI -~99 7500 ~R '53~3555 ~CUL 1550'6875 ~CNI, DEPT 5300 0000 SFLU SP -990:2500 CR RHOB -999,2590 DRHO NPHi -990 2500 PEF GR 43!0117 NR~T NCNL ia65 6875 ~C~L DEPT 5100,0000 SF{,U SP -09o,~500 qR RHOB -09° ~5nO DR~O . 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'999,2500 '099,~500 -o9o.2500 4,2234 30~.~906 CALl NR~T NCNL PNDA CALl NR~T N C ~ b RNRA CALl I bD MRAT ~CNb PNRA CALI ~R ~RAT aR NR~T NCMI, RNRA CALI CR NRAT NCNb DNRA CAbI GR DNRA CaLI -999.2500 -990.2500 -999,2500 4'1492 8,a863 -099.2500 -999.2500 : o'25oo .99,2500 5,0554 8,6~26 -999.2500 -999,2500 -999,~500 -099.~500 4.4265 8,595'1 '999,2500 '999.2500 '999,2500 '999.2500 3..0334 8,6113 -999,2500 -999 ~500 ~999:500 -999,~500 3,7385 8,6113 '999,2500 '999.2500 '999,2500 '999,2500 4,1335 ~,5957 -999.2500 -o99.2500 ~999,~500 999,2500 4,0007 8,6113 '999,2500 '999,2500 '~99,2500 '999,2500 4,2585 8.6101 CALl RNRA NPHI CALl RNRA CALI DNRA NPHI IbM CALl RNRA FCNb NPHI IbM CALl RNRA FCNL NPHI IbM CALI RNRA WCNL NPHI CALl RNRA FCNG NPHI C~LI RNRA NPHI -999 2500 -999~2500 -999,2500 59,4727 2500 -999.2500 -~99 2500 59:7656 999,2500 099.2500 999.2500 999.2500 51,1230 -999 2500 -999 2500 -099 2500 -999 2500 37 6465 -999 2500 -999 2500 -999 2500 -999 2500 51 4648 -999 2500 -999,2500 -999,~500 -999..500 57,91,02 -099,2500 -999,2500 -999,2500 -999,9500 55,0781 -999 2500 -999 2500 -099 2500 -999 2500 56 2500 bYP OiO.HO~ VEPlFIC~'ION LTSmlNG PAGE 9 OEPT 48{.)n.0000 gFLO -~99 SP -999 2500 GR -999 ~H~B -99~:~500 DRHO -99g NPMI -q90 9500 DEF -999 GR ~3~01~7 N~AT 3 NCNL 1416~ 6675 wCNL ~2~ - o. 5oo -o9. ~H00 099 ~500 BRiO 999 GR 24 69?4 ~!RAT 4 ~C~]., 1400:~75 FCNh 3X6 DEPT 4600.0000 SFLU -99~ ~HOB -090 9500 BRiO -999 "P"I -o99~7500 PEF' -099 GR 20,8018 ~RAT 4 NCNL 161~,6875 ~CWL DEPT 4500.0000 .~FLO -090 SP '999.2500 GR -999 ~HOB -999,7500 DRHO -999 ~R 20.5205 NRAT 4 NCNL 1448.6875 FC~.IL 310 DEPT 4400 0000 $FLU -999 SP -o99:~500 GR -099 RHOg -999i ~500 DRHO -999 -~99'~500 PEW -999 NPHI ~R 24 7~93 NRAT 3 NC~L 1450~6875 wCNL 316 DEPT 4300 0000 $F50 -g99 Sp -099~500 GR -999 ~HOB -099.2500 DR}tO -999 NP,I -o99.~500 P~F -999 gR 44.5117 ~R,~T 4 NCNb I~4~.68~5 ~CNL ]6~ OEDT 4293,0000 SFI...U -999 ~p 'o99.~500 GR -999 RHOB -090.9500 DRNO -o99 Np~i -o9o 2500 PEF -999 ~R 44:761'? ~RAT 4 NCNL 1536.6~75 WC~L 7500 ~500 ~500 2500 9456 .8906 .~500 .~500 ~500 i2500 4187 .6406 25o0 2500 ~500 2500 5046 3906 2500 2500 2500 2500 5476 3906 :2soo 2500 ,2500 ,2500 .969~ .640 2500 2500 ~500 2500 075O 8906 ~500 '2500 ,2500 .2500 · .5203 .3906 ILD NRAT ~CNL ~N~A rAl,I ~CNb ~NRA CALI NRAT RNRA It, D NRIT NC~L PNRA CA[~I NRAT NCNL RNRA ~A~I NRA~ NCNL RNRA CALI NRAT ~C~L ~NRA CALI -999,2500 -999,2500 -990,2500 -099,2500 4,3992 8.5957 -999 2500 -999:~500 -999.2500 -~99,2500 4.42~6 8.6191 -099 ~500 -999:2500 -999'2500 -o99.2500 4,6179 8.5801 -999,2500 '990,2500 '999.2500 -999~2500 4.6648 816113 -999 2500 :999'2500 99~'2500 , -999'2500 4,5789 ~,5801 999,2500 999,~500 999,2500 ~999 2500 4 5242 8 6191 '999,2500 '999.2500 '990,~500 '999,~500 4,8406 8.595'1 CALl RNRA FCNL CALI RNRA FCNb NPHI CALI ~N~A FCNL NPMI CALl RN~A FCN5 NPHI CALI RNRA FC"5 CALI RNRA CALl RNRA NPHI -999 250O -999'2500 -999'2500 -999:2500 51,2207 -999.2500 -999 2500 -999.2500 -999.2500 59.8633 :~99i2500 .. 99 2500 -999 2500 -999,2500 6~,474~ -999.2500 -999 2500 999' - ,2500 '999,2500 6?,2559 -999 2500 -999 2500 -999 2500 -999 2500 51. 6602 .-999.2500 999,2500 -999,2500 -999,2500 -999 2500 -999 2500 -999 2500 -999 2500 6~, 7188 ** FIL~ TRAILER FILE NA~iE :EDIT SEDVTCF NA~E : ,001 [,VP 010.~07 VEPI~'ICATION LISTING PAGE 10 9ATE ; WAXI~4, U~4 LE~!GTH : 1024 ~ILE TvPw~ ~EXT Fib? ~IA~E : ~E~V!CE ~A~E :EDIT DATE :~5tU~/~7 ORIGIN : ~EEL N~M~ :135747 CONTIN!~ATION # :01 NEXT }~FEL ~A~E ~ ***~****** EOF *$******** ********** EOF
