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189-016
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I(~E~ ~" ~/~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~Bren [] TO RE-SCAN Notes: Vincent Nathan Lowell Date:5'/3'~ Is/ ~ Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd s . • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well LJ Plug Perforations 11 Perforate 11 Other U Packer Squeeze Performed: Alter Casing p Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development © Exploratory ❑ . 189 -016 3. Address: P.O. Box 196612 Stratigraphic 0 Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 21915 -00 — (.0 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADL -47437 . MPB -23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10186 feet Plugs measured NONE feet true vertical 7153 feet Junk measured NONE feet Effective Depth measured 10138 feet Packer measured 8784, 8874 feet true vertical 7123 feet true vertical 6274,6332 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13 -3/8" 46# H -40 30' -110' 30' -110' 1670 670 Surface 6225' 9 -5/8" 47# L -80 29' -6254' 29' -4680' 6870 4760 Production Liner 1322' 5" 18# N -80 8864' - 10186' 6326' -7153' �{ECE iVED Liner MAY 2 3 2012 Perforation depth Measured depth SEE ATTACHED feet AOGCC True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 27' - 8862',... 27'-6324' 7" OTIS HCM PKR 8784' 6274' Packers and SSSV (type, measured and true vertical depth) CPH LNR PKR 8874' 6332' 12. Stimulation or cement squeeze summary: Intervals treated (measured): S . W JUL ' 3 2 O1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SI SI SI SI Subsequent to operation: SI SI SI SI 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory0 Development © " Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. © Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nita Summerhays Printed Name Nita Sum 4 hays Title Petrotechnical Data Technician Signatur 41 �� : ,�/ Phone 564 -4035 Date 05/18/2012 RBDMS MAY 2 #4 Form 10-404 Revised 11/2011 V1-1- 617/, 1.„, 4 Submit Original Only MPB -23 189 -016 - PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPB -23 6/23/89 PER 9,670. 9,734. 6,834.07 6,873.37 MPB -23 7/12/00 APF 10,008. 10,028. 7,041.95 7,054.35 MPB -23 7/12/00 APF 10,048. 10,068. 7,066.78 7,079.22 MPB -23 4/29/09 BPS 8,833. 9,670. 6,305.59 6,834.07 MPB -23 7/5/11 BPP 8,833. 10,068. 6,305.59 7,079.22 MPB -23 7/24/11 BPS 8,833. 9,670. 6,305.59 6,834.07 MPB -23 4/6/12 BPP 8,833. 10,107. 6,305.59 7,103.55 MPB -23 4/28/12 BPS 8,842.6 10,068. 6,311.81 7,079.22 MPB -23 5/8/12 BPP 8,842.6 10,068. 6,311.81 7,079.22 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 • • MPB -23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/5/20121T/I/O = 1100/940/152. Assist Slickline. MITT Passed to 2030psi. Pressured up w/ 1.1 bbls diesel. Tubing lost 34psi 1st 15min, 15psi 2nd 15min, for a total of 49psi in 30min. FWHP's = 1100/956/156. Slickline in control of well. 4/5/2012 * ** WELL S/I ON ARRIVAL * ** (test tbg) RAN 2.54" CENT, 3' X 1 7/8" STEM, 2.79" GAUGE RING. S/D @ 8732' SLM UNABLE TO PASS ( seal bore overshot ) RAN 3.5" OK -6 ( no run /pull tool ) LOC STA #1 © 8588' SLM /8630' MD (42' correction ) SET 3.5" D &D HOLE FINDER @ 8611' SLM ( test failed ) S/D @ 8606' SLM ( test failed ) S/D @ 8601' SLM ( test passed ) RAN 2.75" CENT, GS CORE W/ X -EQZ PRONGS /D @ 8739' SLM.APPEARS TO BE SETTING ON PACKER RAN 2.67" CENT,GS CORE W/ X -EQZ PRONG.S /D @ 8797' SLM. EQZ PRESSURES. ATTEMPTED TO PULL XXN PLUG © 8833' MD W/ GR..SHEARED OFF. * ** CONTINUE ON 4 -6 -12 * ** 4/6/2012 * ** CONTINUED FROM 4 -5 -12 * ** (pull ttp,sbhps) PULLLED 2.75" XXN FROM 8833' MD. RAN 2.60" CENT,S.S & DAUL SPARTEK GAUGES,MADE 15 MINUTE STOP @ 8300' MD & 60 MINUTE STOP @ 8800' MD. STOP @ 8830' SLM. DRIFTED DOWN TO 8830' SLM/8866' MD.NO RESTRICTIONS. ***WELL 5/10N DEPARTURE * ** Pad Op Notified 4/20/2012 ** *WELL SI ON ARRIVAL * * *(ELINE COMPOSITE PLUG/TUBING PUNCH) INITIAL T /IA/OA= 3000/1450/300 INITIAL VALIVE POSITIONS:MASTER,GAUGES TO CASING +OPEN, SSV,WING,SWAB=CLOSED TUBING PRESSURE , JOB CANCELLED LEAVE LOCATION, PE /DSO NOTIFIED OF DEPARTURE FINAL T /I /0= 3000/1450/300 FINAL VALVE POSITIONS: MASTER, GAUGES TO CASING+ OPEN, SSV, WING,SWAB = CLOSED. TREE CAP ON AND TESTED. ** *WELL SI ON DEPARTURE * ** 4/27/2012 T /I /0= 3050/1850/210 Load & Kill Pumped 10 bbl 60/40 spear, 292 bbls 2% KCL down Tbg to knock down WHP for E -Line, Freeze protect W/ 22 bbls 60/40 SV,WV,SSV shut. MV,IA,OA Open 4/28/2012 * **WELL SHUT IN UPON ARRIVAL * ** ( SET COMPOSITE PLUG TBG PUNCH) INITIAL T /I /O = 2000/1100/50 PSI RIH WITH 33' x 2.55" TOOL STRING FIRST ATTEMPT AT SETTING PLUGGED FAILED; A CAUSE IS BEING LOOKED INTO SECOND ATTEMPT SET PLUG SUCCESFULLY AT A DEPTH OF 8842.6 FT RIH WITH TUBING PUNCH 35' X 2.125" TOOLSTRING ** *JOB IN PROGRESS AND CONTINUED ON 29- APR - 2012 * ** • • 4/28/2012 1 Load fluids. Continued on 04 -29 -12 4/29/20121T/I/O= 250/110/80 CMIT Tx IA 2500 PASS. Rigged up to Tree cap and pumped 29 bbls diesel down Tubing to reach test pressure's 2554/2331. T /IA lost 3 61/62 psi in 15 min's, 15/16 psi in 2nd 15 min's, for a total Toss of 73/94 psi in 30 t I min's. Bled back +/- 6 bbls . **Swab, Wing, SSV, IA= closed. Master, 0A= open on departure"* FWHP's= 600/500/40 4/29/2012; * * *JOP CONTINUED FROM 28- APR - 2012 * ** I 'CONTINUE RIH FIRF TI (RING PUNCH: INTERVAL 8751 -8856 FT, ELEMENT TO ELEMENT; POOH 1 'SSV, WING= CLOSED; MASTER =OPEN -- DSO NOTIFIED OF VALVE POSTIONS FINAL T /I /O = 265/100/50 ` ** *JOB COMPLETE ON 29- APR - 2012 * ** 4/30/2012 ; T /1 /O= 670/460/80 Circ Out Well (Pre Coil) Circ out well W/ 5 bbl 60/40 spear, 300 !bbls diesel, 49 bbls 9.8# Inhibited Brine, 25 bbls diesel by pumping down Tbg 'taking returns up IA to surface tank. FWHP = 0/400/200 SV,WV,SSV shut MV,IA,OAI !Open ? } 5/5/2012 Coil 8, 1.75" coil, Job Scope: Cement Packer Sqz !Move CTU to SWS shop and swap BOP's and tractor. Move CTU to MP B -23, 'slow drive due to rough road. Wait on Scaffolding. Rig up CTU. Prep for BOPE testing. «< Job in Progress »> 5/6/2012' Continued from WSR of 05- 05 -12. CTU 8, 1.75" coil, Job Scope: Cement Packer !Sqz. Prep for BOPE test. Fill coil with meth. Pressure / function test BOPE. Good tests, no failures. MU BHA: 1.9" ctc, 2 x 2" stinger, 2.1" x -o, 2" JSN. (.5" Hole, .625" ball JSN) OAL = 8.09'. Tagged plug @ 8824', corrected depth to 8843' (top of composite bridge lu . PU :1 u' and paint tiag. Prepared for '10 bbl diesel circulation, had a frozen dWse1 ;transport. Change transport. PJSM. Pump 10 bbl diesel down backside. Take !returns from IA thru choke to 40 bbl gauge tank. PJSM. PT cement line. Wait for replacement contam vac truck. «< Job in Progress »> 5/7/2012; Continued from WSR of 05/06/12. CTU 8, 1.75" coil. Job Scope: Cement packer Sqz. 'Pump 10 bbl G Cement down coil. Lay in 1:1 in 3-1/2" tubing. Plug set at 8843' Flag at 8833'. TOC at 7690'. Pull to safety. Pump 8 bbl diesel down backside and 1t6ke 8.5 bbl diesel to gauge tank. SI IA at 8.5 bbl returns. Circ 5 bbl Biozan, drop 5/8" ball and circ 3# Biozan to nozzle. 1 jet with Biozan to plug at 8843'. s POH while circ Biozan. Leave Biozan in hole from 8380 - 8843'. Jet across GLM's 'while POH. At surface. Lay out Cmt nozzle BHA. MU milling BHA = 2.25" ctc, 2.14" dfcv, 2.13" jar, 2.13" disco (5/8" ball), 2.13" circ isub (1/2" ball, 5K rupture disk), 2.13" motor, 2.5" mill. (3- blade). OAL = 20.91'. MIT Ix IA to 572 psi passed. RIH to mill CMT and composite bridge plug. First motor work at 8650 psi. Firm cement at 8752'. Mill cement and stringers down to plug at 8822'. Continue cleanout. «< Job in Progress »> • • 5/8/20121 Continued from WSR of 05/07/12. CTU 8, 1.75" coil. Job Scope. CMT Packer Sqz. Mill out cement and composite plug. 1 Milled thru plug at 8822'. Chase plug to bottom at 10102'. Circ sweep. Wiper up to 8600'. Ream tailpipe area up/dwn/up. RIH to bottom. Circ sweep. POH. No P P• P• overpull in tubing. Freeze protect 3-1/2" tubing from 2500' to surface. Close Swab and SSV. Freeze protect surface lines. PJSM. Lay out BHA. PT tree cap to 3500 psi. RDMO. «< Job Complete »> 5/10/2012 T /I /0 = 1760/1080/100. Temp = SI. MITIA to 2500psi PASSED. Pressured up w/ ' 1.6bbls diesel. IA lost 112psi 1st 15min, 16psi 2nd 15min, fora total of 128psi in 130min. FWHP's = 1760/1000/100. Swab, wing = shut. Master, IA, OA, SSV = i open. FLUIDS PUMPED BBLS 368.6 DIESEL 292 2% KCL 1070 1% KCL 112 60/40 METH 36 METH 49 9.8# BRINE 30 3# BIOZAN 1957.6 TOTAL " r- • - WELL No. 8 -23 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50- 029 -21915 PERMIT No.: 90 -395 COMPLETED: 6/23/89 LAST WORKOVER: 8/22/90 1 FMC TUBING HANGER W/3 -1/2" 'H' BPV PROFILE NOTES: 3 1/2 ", 9.3 #, EUE 8rd TUBING 1. ALL MEASUREMENTS ARE FROM KDB OF PARKER 141 523' OTIS 3.5" SERIES 10 TRSV (2.813" 1.0.) KOB - SL = 54' $$$y KDB - GL= 34' 1 '` V 1.. O 5 o 2. MAX. ANGLE = 58.2' ® 6337' 3. K.O.P. = 695' A , ..tN0:114:- 4. SLANT HOLE: YES 2328' GLM 5. MIN. ANGLE = 46.6' AT 8087' 3760' GLM 6. TREE TYPE: FMC 3 1/8" API 5000# W/ Em' 3 1/2" 8rd TREETOP CONNECTION. 5061' GLM 7. MIN. RESTRICTION: 2.675" 0 8833' ID 6201' GLM 8. COMPLETION FLUID: 11.1 PPG NoCL BRINE ' 6964' GLM MACCO SPM - GAS LIFT MANDRELS 9. STIMULATION: 7601' GLM WITH 1" VALVES FRAC; 9/21/89 MK SANDS OD PUMPED 59844# 16/20 MESH I -PROP 7924' GLM a 8277' GLM i 8630' GLM -3is 02iHCE Ser '51101,m .1111. 8769' OTIS SEAL BORE EXTENSION OVERSHOT (2.882" 1.0.) � 1 8764' OTIS 'X' NIPPLE 8784' 7" OTIS HCM PACKER (2.75" MIN ID) 1 8833' OTIS 3 1/2" "X -N' NIPPLE (2.675" ► • II D. eb$7 .-.. 8864' TOP OF PACKER EXTENSION I 10 0 ,,��QQ�) w 4. 1 8867' TUBING TAIL (2.75" I.D.) W /RE -ENTRY GUIDE `b' 8874' CPH LNR PKR W/ 10' EXT ABOVE 1010 6'1 & 10' PBR BELOW 4/1 e .. - 9581' 7" SHOE PERFORATIONS: 6 SPF 0' PHASING - - Fr, Iri ONO& CC*44 ■4 q`N`o MD TVD MK 9670' -9734' 6831' -6871' '11126 r 1 ' � 1i �� c �0 • ■0 d 10OO -• IOOts 2 " 4s ► -- 10.138' PBTD 1004/e--100684 „15.1 ► 10,186' 5” SHOE Ni i CONOCO INC. APPROVED BY: HOS DATE 6/25/92 ANCHORAGE DIVISION [DRAFTED BY: SJ4 /CFP CAI FILE: WC0823 • 4, f r - 0 . WELL No. B-23 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50 -029 -21915 PERMIT No.: 90-395 COMPLETED: 6/23/89 LAST WORKOVER: 8/22/90 1 , t FMC TUBING HANGER W/3 -1/2" 'H' BPV PROFILE NOTES: 3 1/2 ", 9.3 #, EUE &d TUBING 1, ALL MEASUREMENTS ARE FROM KDB OF PARKER 141 523' OTIS 3.5" SERIES 10 TRSV (2.813` ID.) KOB- SL =54' ssSv KDB - GL = 34' 1 '`S t 1� / i L. G I q (ii 2. MAX. ANGLE = 58.2' 0 6337 '� x' ill, , v INnV G.. 3. K.O.P. = 695' 4. SLANT HOLE: YES Mb -2328' GLM n 5. MIN. ANGLE 46.6' AT 8087' 3760' GLM V Jp 6. TREE TYPE: FMC 3 1/8 API 5000# W/ "�' 3 1 /2" 8rd TREETOP CONNECTION. ` 5061' GLM 7. MIN. RESTRICTION: 2.675 0 8833' 6201' GLM ■ 8. COMPLETION FLUID: 11.1 PPG NoCL BRINE MACCO SPM-1 6964' G.wl — GAS LIFT MANDRELS MEM 9. S TIMULATION: 7601' GLM WITH 1" VALVES FRAC; 9/21/89 MK SANDS PUMPED 59844# 16/20 �,C r+ MESH I -PROP 7924' GLM �, t'a`i i ` b ..cO ' Mb 8277' GLM fi - - 8630' GLM -j 02lF►CE Ser 5!'oido i ) It 8769' 0115 SEAL BORE EXTENSION OVERSHOT � �w t( k, 7 It ti (2.882" ID.) ■ -- �,� J'‘ ' �2 ir_ 8764' 011S 'X' NIPPLE \` .l �� t J ti J o �� � I 8784' 7" OTIS NOM PACKER (2.75" MIN ID) /..),... . 9 8833' OTIS 3 1/2" "X -N" NIPPLE 2.16" 2 5 " 'O D D 1 $7 " . " 6 " 8864' TOP OF PACKER EXTENSION �,�QQ� �✓ ' 1 !.' 8867' TUBING TAIL (2.75' ID.) W/RE -ENTRY GUIDE `ti� 8874' CPH LNR PKR W/ 10' EXT ABOVE 4:f• ,O O b1 & 10' PBR BELOW 9581' 7" SHOE PERFORATIONS: Lb° 1 "fi ; MRCP . tI 6 SPF 0' PHASING '- _ F cya Oda MK 9670'-9734' 6831 ', ;; i6i2 (silb >�� ° Iv . ,. Oooe � 10021 A " 1 4 Sir) 10,138' PBTD 1004x'- 1DO68' 1516114 ►. 10,186' 5" SHOE tiL N CONOCO INC. APPROVED BY: HOS DATE 6/25/92 t ANCHORAGE DPASION 1DRAF'tEC OY: SJI /CFP_ CAD• FILE: WCOB23 • >> a • titP& 6-13 • P rJ ' 1oi( Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator ©bp.com] 5 /i3 /rz-- Sent: Thursday, May 17, 2012 6:27 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan; Chmielowski, Jessie Cc: Wills, Shane M; Olson, Andrew Subject: OPERABLE: Producer MPB -23 (PTD #1890160) MIT -IA Passed All, ./ Producer MPB -23 (PTD #1890160) passed an MIT -IA to 2500 psi after a cement squeeze was performed to repair TxIA communication. The passing test confirms two competent barriers to the producing formation. The well is reclassified as Operable and may be returned to production. Thank you, Mehreen Vazir (.':)k rnCati:: (R_T(11(1 Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells t JUNE 2111, Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, July 25, 2011 5:18 AM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; Schwartz Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: McEntyre, Scott R; Townsend, S. Eliot; Reynolds, Charles (ALASKA) Subject: NOT OPERABLE: Producer MPB -23 (PTD #1890160) Secured with Downhole • ug All, Producer MPB -23 (PTD #1890160) has been securz. with a downhole plug. The well passed a CMIT -TxIA to 2500 psi on 07/24/11. The well has been reclassified as N. Operable and will remain shut in until a repair plan is developed. Plan forward: 1. APE: Evaluate tubing repair options for . .entified tubing leaks Please call if you have any questions Thank you, Taylor Taylor Wellman filling in,`or Mehreen Vazir /Jerry Murphy Office: 659 -5102 Pager: 659 -5100 x 1154 1 01 -AUG -2011 Schknaherger No.5774 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD R -28 BJGT -00051 SBHPS 23- Jul -11 1 1 7 I &q — 'Si MPB -23 BJCR -00099 LEAK DETECTION LOG 22-Jul-11 1 1 / Y7 1 06 -01 BBSK -00080 PPROF WI DEFT & GHOST 23-Jul-11 1 1 U -06B BJGT -00053 SBHPS 25-Jul-11 1 1 M -03A BJGT -00052 SBHPS 24- Jul -11 1 _ 1 01 -20 BBSK -00054 LDWG EDIT OF RST 5- Mar -11 1 1 P2 -52 BJGT -00021 LDWG EDIT OF RST 6- Mar -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 III _ r - u , tl RECEIVE AUG 5 2.011 NOT OPERABLE: Producer MPB -23 eD #1890160) Secured with Downhole� lug Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com]�� 7(Z4sf/( Sent: Monday, July 25, 2011 5:18 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: McEntyre, Scott R; Townsend, S. Eliot; Reynolds, Charles (ALASKA) Subject: NOT OPERABLE: Producer MPB -23 (PTD #1890160) Secured with Downhole Plug All, Producer MPB -23 (PTD #1890160) has been secured with a downhole plug. The well passed a CMIT- - TxIA to 2500 psi on 07/24/11. The well has been reclassified as Not Operable and will remain shut in until a repair plan is developed. Plan forward: 1. APE: Evaluate tubing repair options for identified tubing leaks Please call if you have any questions. Thank you, Taylor JuL 9 1J Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy 659 -5102 Pager: 659 -5100 x 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, July 08, 2011 4:30 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift); McEntyre, Scott R Subject: UNDER EVALUATION: Producer MPB -23 (PTD #1890160) Sustained casing pressure on the IA All, Producer MPB -23 (PTD # 1890160) is currently classified as Not Operable due to TxIA communication. On 7/6/11, slickline pulled the down hole plug in preparation for a tubing patch. On 7/7/11, the well was reported to have sustained casing pressure on the IA through the known tubing leak. The wellhead pressures were T /I /O 2320/2320/340 psi. The well will be reclassified as Under Evaluation until repaired or re- secured. The immediate plan forward is for e-line to run a leak detect log and set a tubing patch to restore tubing integrity. A TIO plot and wellbore schematic have been included for reference. « File: MPB -23 TIO Plot 07- 07- 11.doc » « File: MPB- 23.pdf (Compressed) » Thank you, Toxin Roschinger (filling in for Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 7/28/2011 UNDER EVALUATION: Producer M 23 (PTD #1890160) Sustained casing essure on the IA Page 1 of 1 Regg, James B (DOA) • From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] �, , 71t3'„ Sent: Friday, July 08, 2011 4:30 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; A'<, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift); McEntyre, Scott R Subject: UNDER EVALUATION: Producer MPB -23 (PTD #1890160) Sustained casing pressure on the IA Attachments: MPB -23 TIO Plot 07- 07- 11.doc; MPB- 23.pdf All, Producer MPB -23 (PTD # 1890160) is currently classified as Not Operable due to TxIA communication. On 7/6/11, slickline pulled the down hole plug in preparation for a tubing patch. On 7/7/11, the well was reported to have sustained casing pressure on the IA through the known tubing leak. The wellhead pressures were T /I /O 2320/2320/340 psi. The well will be reclassified as Under Evaluation until repaired or re- secured. The immediate plan forward is for a -line to run a leak detect log and set a tubing patch to restore tubing integrity. A TIO plot and wellbore schematic have been included for reference. «MPB -23 TIO Plot 07- 07- 11.doc» «MPB- 23.pdf» ' 6460p Thank you, MCP 2 7.4( c, Lt -L p Torin Roschinger (filling in for Jerry Murphy) co 4 9 Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 �; kN F JUL I d pi CeII (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 II 7/13/2011 MPU B-23 PTD 1890160 7/8/2011 TIO Pressures Plot Well: MP0 4,000 - 1 3,0OO -0—'Tbg —11F—k\ - -A_' —' OOA —°�- �~~~� 1,000- • . . . . . . . . . . . . . . . . . - . . . . . . . . 04109/11 04/ 6M104/23/ 104/30/ 105/07/ 105/ 4/11 05/2 /1105/28/ 106/04/ 106/ 1/1106/ 8/1106/25/ 107/02/ 1 � ' { L______ - ---- -- — --- ---- ---' -� • • r WELL No. B-23 COMPLETION SKETCH MILNE POINT UNIT (P) API No.: 50- 029 -21915 PERMIT No.: 90 -395 COMPLETED: 6/23/89 LAST WORKOVER: 8/22/90 I _ 1 FMC TUBING HANGER W/3 -1/2" 'H' BPV PROFILE NOTES: 3 1/2 ", 9.3 #, EUE 8rd TUBING 1, ALL MEASUREMENTS ARE FROM KDB OF PARKER 1 54' ASV 523' OTIS 3.5" SERIES 10 TRSV (2.813" I.D.) KDB- GL =34' ITS V L 6 e Offil 5 l1 it 2. MAX. ANGLE = 58.2' ® 6337' i� i 3. K.O.P. = 695' ‘.4.. '.. /MOZY , 4. SLANT HOLE: YES 2328' GLM 5. MIN. ANGLE = 46.6' AT 8087' 3760' GLM 6. TREE TYPE: FMC 3 1/8" API 5000# W/ 3 1/2" 8rd TREETOP CONNECTION. al 5061' GLM 7. MIN. RESTRICTION: 2.675" CO 8833' ! 6201' GLM 8. COMPLETION FLUID: 11.1 PPG NoCL BRINE • 6964' GLM M AS C UFT MANDRELS 9. STIMULATION: W ITH 1" VALVES FRAC; 9/21/89 MK SANDS al 7601' GLM PUMPED 59844! 16/20 MESH I -PROP IS 7924' GLM • 8277' GLM 8630' GLM / -3is 02iACE Je. 1 5 12Ol0o .1111 8769' OTIS SEAL BORE EXTENSION OVERSHOT (2.882" I.O.) ' , 8764' 0TIS 'X' NIPPLE ■ 8784' 7" OTIS HCM PACKER (2.75" MIN ID) 1 2.16"10 Pacc4,4464 • 9 1 8833' OTIS 3 1/2" "X -N" NIPPLE (2.675" I.D.) A 7 lie `� .. 8864' TOP OF PACKER EXTENSION ,,��QQ v' b I 8867' TUBING TAIL (2.75' I.D.) WIRE-ENTRY GUIDE II, �b_ 8874' CPH LNR PKR W/ 10' EXT ABOVE 101 'O 0 b1 & 10' PBR BELOW foo OW 9581' 7" SHOE pERF0RAT10NS: Lo W 31 / 9 1P F ; ► ' 1 yK1" vtu Sr 6 SPF 0' PHASING -- - 0,4 F L$'b" Mb.4 44 AMID MD ND . , . 6NER FI L id t26 r'1 (1i f t 1. 6 10 MK 9670' -9734' 6831' -6871' • ��pOO8 % 10029; 2 " F~ ' � 4 S ; ' '• :.,._ 10,138' PBTD ' , ^ ''' ' ► 10,186' 5" SHOE tL Dee. " CONOCO INC. APPROVED BY: HOS DATE: 6/25/92 ANCHORAGE DIVISION AF"TED BY: SJV /CFP CAM FILE: WC0823 FW: LTNDER EVALUATION: ~B-23 (PTD #1890160) Sustained Cas~Pressure on t... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, April 24, 2009 11:20 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSU, ADW Well Integrity Engineer Subject: FW: UNDER EVALUATION: MPB-23 (PTD #1890160) Sustained Casing Pressure on the IA Attachments: MPB-23 (PTD #1890160) TIO.pdf; MPB-23 TIO Plot.doc ~~s ~ 1-c~x Mr. Regg and Mr. Maunder, Please find below the Under Evaluation notice for MPB-23 (PTD #1890160) that indicated an occurrence of IA pressure above MOASP at 2080 psi. My apologies for the inadvertent omission of your email addresses on the original notification. The current plan forward is as follows: 1. Coil: Jet hydrate ice in tubing and pull downhole choke - WORK CURRENTLY ONGOING. 2. Slickline: Pull GLV for circulation. 3. Fuilbore: Circulate tubing and IA to ensure IA is free of ice plug. 4. Slickline: Instaii dummy GLVs, secure well with TTP, MITT, and MITIA. An updated TIO plot has been included for reference. «MPB-23 (PTD #1890160) TIO.pdf» ./ . `"a~`,`~,~ ~~u: '~;.; (~; ~ ~;;. ~~;~,;`~ Please let me know if you have any further questions. Thanks. ,~ason ~. ~DahCem forAndrea .~fughes alternate - Taylor Wellman bp Alaska - Wel! Integrity Engineer office: 907-659-5098 cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, April 08, 2009 8:11 PM To: MPU, Area Manager; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; MPU, Field Lead Tech; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rupert, C. Ryan Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: MPB-23 (PTD #1890160) Sustained Casing Pressure on the IA All, 8/6/2009 FW: UNDER EVALUATION:~B-23 (PTD #1890160) Sustained Cas~Pressure on t... Page 2 of 2 Milne Point well MPB-23 (PTD #1890160) is a long term shut-in well and has been confirmed to have sustained casing pressure on the IA. The wellhead pressures were shut-in/2080/380 on 04/07/09 when the IA pressure was bled to 1350 psi and pressure increased 600 psi overnight. The well has been reclassified as Under Evaluation. The plan forward includes: 1. Operations: IA Pressure Bleed - CONFIRMED COMMUNICATION 2. Production Engineer: Evaluate for possible coil clean out and slickline secure with TTP A wellbore schematic and TIO pfot have been included for reference. «MPB-23 TIO Plot.doc» Please let us know if you have any questions. Thank you, Anna ~u6e, ~P.2. Well Integrity Caordinator GPB Welis Group Phone: (907j 659-5102 Pager: (907) 659-5100 x1154 8/6/2009 • ~ a ,a Qoo c ~-aooao ~~~ ~~ ~ i--i ~ i-. ~ ~ .--i O ~ ~ .--i ~ Q F"' a \~ M N ~Q Q, ~ n ~ L ~ n ~ ~ ~ ~ r ~ a ~ `v ~ ~ ~ N m 0 v~ 0 N C'7 O T O C `m 0 m ~ r~. 0 M 0 m 0 m N ~ N O U] O N N O T O ~ ni 0 m 0 ~ 0 N O Q1 O m 0 o~ c~ v iV O m 0 i 0 m ~ 0 m 0 ~ 0 0 G O O O R C+] N ~ r'" ~ ~ . 39-01 (0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.7Y" DATE: July 12, 2000 Commissioner' 0 //ë;/~c.) THRU: Blair Wondzell, ~~ P. I. Supervisor .fìf1(áJ FROM: ~dt¡ Jeff Jones "'-- SUBJECT: Safety Valve Tests Petroleum'l sp c r 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 8-22 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, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 M::>~ r~-{-:l_5i- 21 well houses were inspected, no failures. - -y 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 ~~ . Alaslm 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: Kuparuk River/MPU/ß-Pad Separator psi: LPS 140 I-IPS ,N/ A 7/9/00 t~:",:';}:: m' Û ij f n;ic,\J:' r~J( ~'~, ";f~:!~!~~i¡:~¡\'1/¡;,;<.,1W:¡ -,.;,¡rR ~t\.,!¡ ~':: "c¡ liv'r ' ',' ïfi\SMt{' ,fSSVi.¡,; í:,¡'~..;:b;",,:¡\çi¡:':' W. e.l{~1ÿpé1?F ""¡'""','" e ' ata ,¡:t, 'r;,"" ",.,..I;":':"i",¡¡":,,,o,,:,-,".',",n':, ,I ot8"1\".' il;',< :'~ ~,::",\..¡ ',':1:"i~".!","\;1~,.!,,¡,::¡'., " "'" ,"",', ",'Yh, ,""it.:' ':',.:,: ,'¡,e, ,.':.':' '1""', ,", , 0 "',:",'ñ',":',":" '" ,,' "i ,f: "",' ',' ,f ' Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil. WAG. GIN.J. GAS or CYCLE B-02 1811420 N B-03 1820560 140 100 115 P P OIL ...) B-04A 1821000 140 100 95 P P OIL N B-06 1850130 140 100 90 P P OIL B-O7 1850620 B-09 1850340 140 100 95 P P OIL B-10 1850170 140 100 90 P P OIL B-13 1850930 B-15 1851210 140 100 95 P P OIL B-16 1851490 B-19 1852300 B-20 1860050 140 100 95 P P OIL B-21 1860230 140 100 95 P P OIL B-22 1853020 140 100 100 P 4 OIL B-23 1890160 Wells: 9 Components: 18 Failures: Failure Rate: 5.5% 090 Day Remarks: Three well SV's recorded slow closing times; B-04A(3:20), B-03(3:03),B-06(3:30). Some of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said he would have these items corrected. THE MATE~AL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24 2000 P M C:LORIWIFILM.DOC E E L E W A T E R IA L U N D ER TH IS M A R K ER . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.7:) DATE: July 12, 2000 Commissioner 'f I/o/bc.) THRU: Blair Wondzell, 41~ P. I. Supervisor .9,'1(oa FROM: ~I:!¡ Jeff Jones .-'" SUBJECT: Safety Valve Tests Petroleum 'I sp c /r 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 8-22 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 8 Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. j JvP.. {"-<-+.l-'5>i- 21 well houses were inspected, no failures. . --y Attachments: SVS MPU 8-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 . . Alask~l Oil anù Gas Conservation COl1l1nission S~lfcty Valvc SYStCl11 Tcst n.cport Operator: BPX Operator Rcp: Larry Niles AOGCC Rcp: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk Rivcr/MPU/B-Pad Separator psi: L1>S 140 I-IPS N/ A 7/9/00 N 10 N ~'~':h; ¡"or:;.-, ~,.~.- :",' . . ~ :) "',; i':".~'¡"/.,Ij"'~ {.,~'.J;.' ,:,.;, ';}1;Wi;'.:~'~;:~;f¡;;:{t~!¡;i:ft;}~!.;~:i!.6i'pii b t$:!)i;f;¡g~):f~B~;;»f1:f.~JW~}j!;i¡j:; :t¡t§~~}r .>5814' ':'!f;::;:~ H~~: ~0~j:!~f{~::~,:,: :W elli~1ÿÌi~!/f~' :::ii.; ~"-;:":Well'-Dåt't(~"(X~1:;~j'" :r\ ' .: ;~.~ 7, '.I'I."':,~' :1. ..\',.:;'.'~~~.,:: '~~ " .,:.: ,,':';. , :~,,:'~'.:' Well Pcnnit Separ Set LIP Test Tcst Test Numbcr Nunlbcr PSI PSI Trip Code Code Code Oil, WAG, GIN.J, GAS or CYCLE 8-02 181 1420 8-03 1820560 140 100 1 15 P P OIL B-04A 1821000 140 100 95 P P OIL 13-06 1850130 140 100 90 P P OIL 13-07 1850620 8-09 1850340 140 100 95 P P OIL 13-10 1850170 140 100 90 P P OIL 13-13 1850930 B-15 1851210 140 100 95 P P OIL 13-16 1851490 8-19 1852300 13-20 1860050 140 ]00 95 P P OIL B-2] ]860230 140 100 95 P P OIL 8-22 ]853020 140 ]00 100 P 4 OIL 13-23 1890160 9 COlllponents: 18 Failures: Failure Rate: 5.5% 090 Day Wells: Rcmarl{s: Three well SV's recorded slow closing tin1es; B-04A(3 :20), 8-03(3 :03),B-06(3 :30). Son1C of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said hc would have thesc iten1S corrected. STATE OF ALASKA A~-,,sKA OIL AN D GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging __ x Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator CONOCO INC. 5. Type of Well: Development .___X Exploratory __ Stratigraphic __ 9973 Service _~. 3. Address P oO. BOX 340045, PRUDHOE BAY, AK 4. Location of well at surface 174' FSL, 868' FWL, SEC 18, T13N, R11E, U.M. At top of productive interval 596' FNL, 19' FEL, SEC 23, T13N, RIOE At effective depth 568' FNL, 93' FWL, SEC 24, T13N, RIOE At total depth 685' FNL, 468 FEL, SEC 23, T13N, RIOE Perforate ~ Other 6. Datum elevation (DF or KB) KB 54 7. Unit or Property name MILNE POINT UNIT 8. Well number B-23 9. Permit number/approval number 90-395 10. APl number 50- 029-21915 11. Field/Pool KUPARUK RIVER feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,255 feet 7,193 feet 9,500 feet 6,725 feet Plugs (measured) Junk (measured) 10,133 NONE Casing Length Structural Conductor 80 ' Surface 6223 ' Intermediate Production Liner Perforation depth: measured 9670' Size 13-3/8" 9-5/8" 11 - 9734' Cemented true vertical 6831' - 6871' Tubing (size, grade, and measured depth) 3-1/2" 9 3#/FT , · , Packers and SSSV (type and measured depth) OT I S 7" 26- 32# Measured depth True vertical depth 110' RKB 110'RKB 6254' RKB 4678' RKB 9581' RKB 4776' RKB PERM PACKER HC g 8779' SSSV, OTIS TRSV g 52; 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 931 1638 986 1260 204 Subsequent to operation 876 894 1301 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~ Oil X_._ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1240 Service 189 Form 10-40~ I~ev(1:)6/15/88 Title SENIOR PRODUCTION FOREMAN SUBMIT IN DUPLICATE AUGUST 12, 1990 COMPLETE RU OF EWS WORKOVER RIG. PULL BPV. BULLHEADED 80 BBL'S OF THE 9.6 SODIUM CHLORIDE DOWN THE TUBING. AFTER PUMPING KILL FLUID TUBING PRESSURE WAS 750 PSI. WITHIN TWO HRS THE TUBING PRESSURE HAD CLIMBED TO 1300 PSI. WEIGHT BRINE TO 10.5 PPG AND PUMP DOWN THE TUBING AGAIN. SURFACE PRESSURE STILL 350 PSlG. RUNNING A STATIC BHP SURVEY TO DETERMINE STATIC PRESSURE. EMW=9.8 PPG. AUGUST 13, 1990 COMPLETED BUILDING BRINE TO 10.5 PPG TO KILL WELL. BLEED TUBING PRESSURE OFF SEVERAL TIMES WELL WOULD CONTINUE TO FLOW. RIG UP SLICKLINE UNIT. RUN THE GRC TOOL FOR BHP. STATIC BHP OF 3501. RU E-LINE, RIH WITH PRESSURE, TEMP. GAUGE TO MID PERF OF 9702' MD, STATIC BHP WAS 3506 PSIA. POOH AND RIG DOWN THE E-LINE UNIT. BLED OFF TUBING 50 PSI AT A TIME AND PUMP 2 BBL.'S OF 10.2 PPG BRINE DOWN TUBING. REPEAT PROCESS UNTIL TUBING IS BALANCED. AUGUST 14, 1990 CONTINUED BULL-HEADING 10.1 PPG SODIUM CHLORIDE/BROMIDE BRINE DOWN TUBING AND BLEEDING GAS OFF AT SURFACE. RIG UP SLICKLINE UNIT. SET XN PLUG IN PROFILE BELOW THE PACKER. ATTEMPTED TO SET WITH NO LUCK. POOH AND REDRESS. RIH AND ATTEMPT TO SET AT 8828' MD, SET PLUG AND POOH. BLED TUBING PRESSURE OFF AT SURFACE TO 70 PSI BEFORE THE WELL STARTED TO FLOW AGAIN. BULL HEADED 70 BBLS.'S OF 10.1 BRINE AFTER WELL HAD GIVEN BACK 65 BBL.'S TO PITS. RIH TO PULL XN-PLUG AT 8828' POOH. RIH WITH X-LINE 2.750 PLUG AND SET IN THE X-NIPPLE 645' ABOVE THE XN PROFILE. POOH. AUGUST 15, 1990 BLEED PRESSURE OFF TBG. RIH & PULL GLV FROM BOTTOM GLM @ 8279' POOH. CIRCULATE 200 BBLS BRINE UNTIL 10.1 PPG BRINE IS COMPLETELY AROUND. RIH & PULL PLUG FROM "X" NIPPLE ABOVE PKR TBG PRESSURED UP TO 150 PSI WHEN PLUG WAS RELEASED AND BUILT UP TO 500 PSI. BULLHEAD 20 BBLS BRINE DOWN TBG PRESSURE DROPPED TO 100 PSI - BULLHEAD 20 BBLS DOWN TBG - SI & MONITOR -TBG PRESSURE BACK UP TO 500 PSI. RIH WITH PLUG AND SET IN "XN" NIPPLE @8828'. BLED PRESSURE OFF TBG TO 125 PSI AND BEGAN FLOWING. WEIGHT UP 10.1 PPG BRINE W/NABR TO 10.5 PPG MIX UP 20 BBL PILL OF HEC @ 3.5#/BBL BEGIN CIRCULATING DOWN TBG W/10.5 PPG BRINE AND MONITOR/WT UP RETURNS. RETURNS CONSISTENT @ 10.3 PPG. SPOT 20 BBL HEC PILL DOWN TO PLUG W/72 BBLS. AUGUST 16, 1990 RIH AND RELEASE/EQUALIZE PLUG IN "XN" NIPPLE, PUMP 15 BBLS DOWN TBG TO SPOT HEC PILL DOWN TO PERFS - TBG WENT ON VACUUM WHEN PRESSURE WAS EQUALIZED ACROSS PLUG BUT TBG STARTED TO PRESSURE UP BEFORE POOH W/PLUG. SI & MONITOR PRESSURES SICP = 40 PSI. BLED GAS OFF TBG UNTIL WELL STARTED TO FLOW. FINAL SITP = 150 PSI SICP=0PSI. HEAT SURFACE FLUID TO 100 DEGREES F AND BEGIN CIRCULATING DOWN CSG TAKING OIL RETURNS FROM TBG CIRCULATED @ 1 BPM KEEPING 100 PSI ON CSG & 50 PSI ON TBG CIRCULATED 112 BBLS 10.5 PPG BRINE UNTIL RETURNS CLEANED UP - SI & MONITOR. SITP=450 PSI, SICP= 100 PSI. WEIGHT UP SURFACE FLUID TO 10.7PPG. MIX UP 20 BBL HEC PILL @ 3.5#/BBL. BLED PRESSURE OFF TBG&CSG. AUGUST 17, 1990 OFFLOAD 300 BBLS 10.7 PPG NACL/NABR. CIRCULATE DOWN TBG - WEIGHTING UP RETURNS TO 10.7. SPOT 20 BBL HEC PILL TO TBG TAIL AND DISPLACED TO PERFORATIONS. SlTP-0 SlCP=0 WELL DEAD - SET BPV ND TREE, NU & TEST BOPE. WITNESS WAIVED BY HAROLD HAWKINS. PU ON TBG HGR 150K TO SHEAR OFF PKR SEAL BORE EXTENSION. PUMP UP CONTROL LINE TO MAINTAIN SCSSV OPEN. POOH AND LD TBG HGR - WELL STARTED TO FLOW CIRCULATE HOLE DOWN TBG - RETURNS GAS CUT WATER. SI AND MONITOR PRESSURE. CIRCULATED 345 BBLS. WELL STAYED DEAD FOR 15 MIN. THEN FLOWED BACK 10.7 BRINE. AUGUST 18, 1990 CONTINUE TO MONITOR WELL SITP =0. ATTEMPTED TO BLEED PRESSURE OFF CSG BUT STARTED TO FLOW GAS CUT BRINE CIRCULATE 60 BBL 10.7 BRINE DOWN TBG @ 1.5 BPM 75 PSI MONITOR STILL GASSY ON CSG. BULLHEAD 40 BBLS 10.7 BRINE DOWN CSG @600PSI WELL DEAD - POOH 8 STDS & LD OTIS SCSSV - WELL BEGAN FLOWING UP CSG BULLHEAD 40 BBLS 10.7 BRINE DOWN CSG @600 PSI- CSG STILL FLOWING GAS CUT BRINE SI & MONITOR PRESSURE. SlTP - 600 PSI SICP-600PSI - BLEED GAS OFF TO 75 PSI & WELL STARTED FLOWING PUMP 6 BBL HEC PILL AND BEGIN CIRCULATING DOWN TBG W/11.0PPG BRINE - WEIGHT UP RETURNS W/NABR TO 11.0 PPG. INITIAL RETURNS GAS CUT WATER AND OIL. PUMPED 270 BBLS & RETURNED 225 - LOST 45 BBLS - OPEN CHOKE UP- DECREASE CSG PRESSURE TO 50 PSI CONTINUE TO CIRCULATE. STOP CIRCULATING - PUMPED 484 BBLS LOST 98 BBLS - GEq-FING 10.9 - 11.0 PPG BRINE IN RETURNS - MONITOR - DID NOT RECOVER HEC PILL. WELL WAS ON VACUUM POOH W/3-1/2 TBG. AUGUST 19, 1990 CONTINUE POOh. PULLED 37 STDS AND WELL BEGAN TO FLOW. CIRCULATED 196 BBLS DOWN TBG - 4 BBLS TO BREAK CIRCULATION - BULLHEADED 20 BBLS DOWN CSG & 20 BBLS DOWN TBG - CONTINUE TO POOH W/3-1/2" TBG & GLM'S PULLED TO #5 GLM & WELL BEGAN KICKING AGAIN. CIRCULATED 50 BBLS DOWN TBG - BULLHEADED 40 BBLS DOWN TBG. CIRCULATED 50 BBLS DOWN TBG - PUMPED 12 BBL HEC PILL & BULLHEADED PILL OUT OF TBG W/35 BBLS - SI & MONITOR SITP = 15 PSI SlCP = 50 - BLED PRESSURES OFF TO OPSl BUT STARTED TO FLOW- FLOWED BACK 5 BBLS GAS CUT WATER. REVERSE CIRCULATED 107 BBLS. AUGUST 20, 1990 SI & MONITOR PRESSURE @ 0700 SITP -- 250 PSI RU TRANS TECH S/L & RIH W/2.25" GAGE RING TO 2000' WLM PU TO LOCATE TBG TAIL UNABLE TO LOCATE POOH - RIH W/TBG TAIL LOCATOR - LOCATE TBG TAIL @1788' WLM (ZERO @ RIG FLOOR) TBG & SBR APPEAR TO BE INTACT. RIH W/XXR PLUG & SET IN TOP OF OTIS SLICK STICK ABOVE PKR @8696 WLM. SlTP = 200 PSI SICP=200 PSI - BLEED PRESSURE OFF TO OPSl & MONITOR. RD S/L UNIT. POOH W/TBG - PULLED TO #6 GLM & FLUID KICKED UP TBG. CIRCULATE 40 BBLS DOWN TBG & CONTINUE POOH KICKED UP TBG - OPEN TBG AND CSG TO SHAKER & ALLOW GAS TO VENT. AUGUST 21, 1990 TBG & CSG CONTINUED TO FLOW GAS & BRINE W/OIL CIRCULATE 50 BBLS DOWN TBG. BULLHEAD 10 BBLS DOWN TBG & 30 DOWN CSG @600 PSI & OPEN BOTH SIDES TO SHAKER STILL GASSING. SI & MONITOR PRESSURE - SlTP = 25 PSI. RU TRANS TECH S/L- RIH TO RETRIEVE XXR PLUG FROM X NIPPLE IN TOP OF SLICK STICK @8696' WLM. COULD NOT LATCH PLUG - POOH & RE-DRESS PULLING TOOL RIH & PULL PLUG. POOH. RIH W/XXN PLUG AND SET IN XN NIPPLE BELOW PKR @ 8764' WLM POOH. BLEED OFF PRESSURE- PRESSURE UP CSG TO 500 PSI FOR 15 MIN. TO TEST PKR -OK. PUMP 10 BBLS DOWN TBG. POOH 8 STDS - STARTED GASSING. PUMP 10 BBLS DOWN TBG & CONTINUE POOH & LD GLM'S AND SBR. SEND GLM'S SCSSV, SBR TO OTIS FOR RE-DRESS & TESTING. AUGUST 22. 1990 PU SBR & RIH W/3-1/2" TBG & GLM'S W/I"DUMMIES & BK LATCHES. MU OTIS FMX SCSSV & RIH W/3-1/2" TBG MU TBG HGR. LAND AND LOCKDOWN TBG HNG. PRESSURE TEST ANNULUS TO 1500 PSI-30MIN-OK. R/U. TRANS TECH S/L UNIT. RIH W/OK-1 KOT. TOOL SE-I-~ING DOWN INSIDE HNG. POOH. RIH W/2.75" OD LIB - SET DOWN IN TBG. HNG BUT JARRED THROUGH. RIH TO SCSSV @505' WLM AND SET DOWN - TOOL APPEARED TO BE PUSHING SOMETHING AHEAD OF IT. POOH - NO IMPRESSION. RIH W/2 PRONG 2.8" OD WIRELINE GRAB. JAR THROUGH RESTRICTION AT THE SCSSV TO 2400' WLM - APPARENT HOLE DRAG. POOH NO RECOVERY. RIH W/OK-1 KOT & ATTEMPT TO PULL TOP GASLIFT VALVE - UNABLE TO LATCH - POOH. RD S/L UNIT. UNLAND TBG HNG AND PICK UP_+25' TO STING OUT OF SBR. CLOSE HYDRIL. REVERSE CIRCULATE 80 BBLS OF BRINE @4.2 BPM. RECOVER SEVERAL LARGE PIECES OF RUBBER FROM OUT OF TBG. ORIGIN OF RUBBER IS THE ANNULAR BOP PACK OFF ELEMENT. RU S/L UNIT. RIH W K' KOT AND RETRIEVE TOP DUMMY VALVE. REVERSE CIRCULATE 70 BBLS OF DIESEL. EQUALIZE INTO TBG. INSTALL BPV & START N/D OF BOPE. STEAM CLEAN PITS. AUGUST 23, 1990 N/D BOPE & N/U PRODUCTION TREE. PRESSURE TEST TREE. R/D WORKOVER RIG. MOVE RIG TO G-3. NOTE: Initial intent of this workover was to change the well from gas lift to ESP completion. Due to the problems encountered attempting to kill the well that resulted from a recent increase in GOR and total gas production, the ESP installation was canceled. The gas lift string was run back in the well with the addition of a tenth gas lift mandrel. TO: THRU: MEMORANDUM Stale of Alaska ALASKA OIL AND GAS CONSERVATION COI~IISSION Lonnie C. Smit~;:~ DATE: August 15, 1990 Conanissioner ! FILE NO: JT. HH. 815.1 TELEPHONE NO: SUBJECT: RIG BOPE Inspection Conoco MPU Kuparuk Rv Field FROM: HaroId R. Hawkins Petroleum Inspector Wednesday August 8, 1990: I made a walk through inspection of EWS RIG 9-4 ~it~'P~e Lang~e~~eld safety and compliance coordinator for Conoco P~U. Purpose of inspection was to check the rig for a pit level indicator. The Conoco operator said they would install it when I checked rig last hitch up. The leveler was not installed. Conoco operator Hal Stevens said rig is to be winterized for winter work and will have a pit level indicator installed then. In summary: Inspection of rig was okay and last BOPE test was made 8/5/90 without a failure. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. MIKE MINDER STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. MINDER, ATTACHED IS THE REQUEST FOR SUNDRY APPROVAL TO CONDUCT WORKOVER OPERATIONS ON THE B-23 WELL. THESE OPERATIONS WILL BE NECESSARY TO CONVERT THE PRODUCTION TECHNIQUE ON THE B-23 WELL FROM THE CURRENT GAS LIFT DESIGN TO ELECTRIC SUBMERSIBLE PUMP DESIGN. RESPECTFULLY, ~- D.~LYA DRILLING FOREMAN ~A~]chora~,a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator CONOCO INC. 3. Address P.O. BOX 3400~.5, 4. Location of well at surface 174' FSL, 868' FWL, At top of productive interval A5~L. 19' FEL Sec 23, t effective aeptli ' 568' FNL, 93' FWL, Sec At total depth 685' FNL, 468' FEL, Sec 12. Present well condition summary Total depth: measured true vertical PRU_nHOE BAY. AK Sec 18, Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 6223' Pull tubing,x_ Variance ~ · Type of Well: Development Exploratory Stratigraphic GGT"4~I Service measured 9670' -9734' Operation shutdown __ Re-enter suspended well __ Plugging ~ Time extension __ stimulate ~ Perforate __ Other '-X- T13N, Rl13, UM T13N, RIOE, UM 24, T13N, RIOE, UM 23, T13N, RIOE, UN 10,255' 7,193' 9,500' 6,725' Size 6. Datum elevation (DF or KB) KB 54 7. Unit or Property name M!LNE PO!MT UN!T 8. Well number B-23 9. Permit number 10. APl nu~%~t ~ 50-- 02g-21915 11. Field/Pool Kuparuk River 13-3/8" feet feet feet feet Plugs (measured) 10,138' Junk (measured) NON E Cemented Measured depth True vertical depth 11 110' RKB 6254' RKB 9581' RKB 110' RKB 4678' RKB 4776' RKB feet truevertica16831,_6871, Tubing (size, grade, and measured depth) 3-1/2", 9.3#/FT, Packers and SSSV (type and measured depth)oT ! S 7" 2 6- 3 2# SSSV · CAMCO TRDP-1A. 3-1/2" l il 503' 13. Attachments Description summary of proposaX~ L-80, EUE e 8864' PERM PACKER 'HC' ~ 8779' Detailed operations program ~ BOP sketcl'~(__ 14. Estimated date for commencing operation .IlIM~' lQ 1QQA 16. i~5;6~os'aTv~as'v~'Eally approved Name of approver Date approved 15. Status of well classification as: Oil X_. Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· Signed /~./ ,~,~~ Title ~l=.ll'lR PR.rlII~TII')N FI'IRF.AN FOR COIVflVIfSS[ON USEONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test ~ Subsequent form required 1"~7'- ¢,:"/'/~ Approved by order of the Commission ORIGINAL SIGNED BY LONNIE O. SMITH Form 10-403 Rev 06/15/88 IAppr°va' N°9~ Approved Copy Returned CommiSsiOner Date su. T d z IL ,d · -; 0 · u - MPU KUPARUK RESERVOIR PROCEDURE FOR CONVERSION OF GAS LIFT WELLS TO ELECTRIC SUBMERSIBLE PUMP 1. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL. WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) B-lO 7026 4370 1629 12.5 B-20 6985 3265 2349 9.5 B-23 6900 3500 2200 10.3 NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP. THE BRINES FOR THE B PAD WELLS SHOULD BE ABLE TO BE DELIVERED FROM TOWN SINCE THE KUPARUK RIVER BRIDGE SHOULD BE BACK IN BY THEN. IF THE RIG MOVES ON B PAD BEFORE THE BRIDGE IS BACK IN PLACE, B-lO SHOULD BE DRILLED FIRST SINCE IT WILL BE THE EASIEST AND MOST INEXPENSIVE BRINE TO BUILD ON LOCATION. ANY REMAINING BRINE CAN BE USED AS A BASE FOR THE B-23 WELL WHICH SHOULD PRECEED THE B-23 WELL FOR THE SAME REASON. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL. BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 30' PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES NOT LESS THAN 500 FT MD. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. (IMPORTANT NOTE: THE COMBINED MEASUREMENT OF THE DIAMETERS OF THE #2 ROUND CABLE DIAMETER AND~THE SCSSV IS $.0? INCHES -- THE DRIFT OF THE ?" CASING IS 6.059" (TO0 LARGE TO FIT). IT WILL THEREFORE BE NECESSARY TO SPLICE APPROX. 20 FT OF #2 FLAT CABLE TO EXTEND ACROSS THE SCSSV.) 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS TO 500 PSIS FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NEXT WELL. THIS PROCEDURE IS IN ACCORDANCE WITH AN EARLIER PROCEDURE WHICH WAS: PREPARED BY STEVE ROSSBERG, SENIOR PRODUCTION ENGINEER (3/23/90) REVIEWED BY MARC SHANNON, SUPV. PRODUCTION ENGINEER (3/27/90) APPROVED BY GARY FLOWERS FOR JACK COPELAND, PRODUCTION SUPT. (4/3/90) J.D. POLYA DRILLING FOREMAN ri F! I I_1_1 N G SEFIVICES TO: Mr. John Boyle DATE: January 1, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 REFERENCE: CONOCO Milne Point B-23 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad. ENCLOSED INFORMATION SUMMARY MD: Digital: Bluelines (1 Set) Neutron- Density Only Sepia (1 Set) Bluelines (1 Set) Neutron- Density Only Sepia (1 Set) 1 LIS Tape 1 LIS Tape Verification Listing Note: Due to minor changes in neutron data processing techniques we are submitting an copy of the updated log. The previous version should be destroyed. Received By: f-':' ~'' A.O.G.C.C. / Date FEB - 5 1990 Alaska 0il & Gas Cons. Anchorage 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 July 21, 1989 Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupi ne Drive Anchorage, Alaska 99501 Gentlemen .' Attached are the original and one (1) copy of the Well Completion or Recompletion Report and Log on Well B-23 at Milne Point Unit. If you have any questions please contact Bernie Barrilleaux or Henry Harrington at 659-6322. Yours very truly, C. G. Steube Production Foreman-Milne Point Unit CGS/vv ~ . ..~ STATEOF ALASKA ALASK/ L AND GAS CONSERVATION C ~-~iMISSION "WELL COMPLETION OR RECOMPLETION riEPORT AND LOG 1. Status of Well Classification of Service Well OIL [~[ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operat(~r 7. Permit Number CONOCO INC. 89-16 3. Address 8. APl Number P.O. Box 340045, Prudhoe Bay, AK 99734 s0-029-21915 4. Location of well at surface 9. Unit or Lease Name 174' FSL, 868' FWL, Sec 18, T13N, RllE, U.M. [~, Milne Point Unit At Top Producing Interval!' 10. Well Number V~R1F~F.O 596' FNL, 19' FEL, Sec 23, T13N, R10E, U.M. s~...r~~ B-23 At Total Depth, ~, ~. ,~ ' 11. Field and Pool 685' FNL, 468' FEL, Sec 23, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Kuparuk River Field KB=54.0' MSLI ADL 47437 , 12. Date Spudded i 13. Date T.O. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/18/89 106/04/89 06~23/89 I N/A feet MSLI One 17. Total Depth (MD+TVD)' 118. p,Ug BaCkDepth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 2i". Thickness of Permafrost 10255 MD/7193 TVD 110138 MD/7120 .~VD YES[~] NOI-~ I 503' RKB feetMD I +1900' RKB 22. Type Electric or Other Logs Run Compensation Neutron Porosity (CN¢) Ail .logs are MWD-electromagnetic wave resistivity(EWR), Dual Gamma Ray (DGR) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 45.9 H-40 Surface ~ll0' RKB 30" Cold Set to Surface N/A 9 5/8" 47 L.80 Surface i6254' RK[ 12 1/4" 1654sks'E'.272sks'G' N/A 7" 39 L.80 Surface 9581' RK[ 8 1/2" N/A 5" 18 N-80 B864 10186'RK~ 6" 272 sks 'G' N/A 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) 9670'-97'34' MDRKB (6831'-6871' TVDRKB) 3 1/2" 8862' RKB 8763 6 JSPF, 0° Phasing, 0.36" EMD .., 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT &KINDOF MATERIAL USED N/A · ,, 27. PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.} 06/27/89 Flowing Date of Test "ours Tested PRODUCTION FOR O~L-BBL GAS-MCF WATER-BBC CHOKE S~ZE I G^s-O~L R^T~O 06/29/89 6 .,, TEST PERIOD I1~ 145 38 6 64/64"11262 Flow Tubing casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 215., ¢ 24-HOUR RATE j~ 580 !52 .. 24 22,7°API. , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None .:~laska 0il & Gas Cons. Form 10-407 Submit in duplicate Rev. 7-1,80 CONTINUED ON REVERSE SIDE ~9., 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Strati~raphic To! s (MDRKB) (TVDRKB) NONE TESTED Kuparuk Interval 9452' 6695' Middle Kuparuk 9677' 6836' (MK) Laminated Zone 9721' 6863' Lower Kuparuk 1 9996' 7032' (LK1) Lower~ Kupa~uk/2 10048 ' 7064 ' (AK2) Base of LK2 10088' 7089' ' 31. LIST OF ATTACHMENTS Daily Drilling Records, Gyro Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~o L~.~~) Title ~~' F~* Date ~7/~/ 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, jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 :-"~laska Oil & Gas Cons, Anchorage DAILY DRILLING REPORTS Kuparuk River Field - North Slope Borough, Alaska W. I. 72.14934% Milne Point B No. 23 (P) CONFIDENTIAL AFE 10-16-1196 Location: 174' FSL, 868' FWL, Section 18, T13N, RllE, UM API No. 50-029-21915 - AK Permit No. 89-16 Elevation: 58' KB 05-18-89: Continue Modification of Diverter Discharge Line. Diverter test witnessed by Doug Amos (AOGCC) - OK. Make up BHA. Drlg with Mud Motor F/280' to 649'. Unable to build any more than 0.5 degrees inclination. POOH, lay down stabilizers and Navidrill with DTV and change out MWD internals. Make up BHAwith Navidrill with 3 degrees bent sub and new bit. Pull and replace swivel packing. RIH with new navigational BHA. Daily mud cost: 1382. Cumulative mud cost: 6295. Daily cost: 29,883. Cumulative cost: 186,084. 05-19-89: Drilling F/ 649' to 1147' using Navidrill and 2 degrees bent sub to kickoff hole angle. Run single shot survey. POOH. Change BHA to Navidrill with DTU RIH. Drilling F/ 1147' to 1592' with mud motor. Hole angle is still building but is not consistent, design build rate equals 2.5 degrees/100' actual average = ±0.8 degrees/100'. MWD Directional Surveys: MD INCLINATION (o) DIRECTIONAL 313 0.1 N o W 465 0.4 S 75 ow 669 1.7 S 49 ow 820 4.9 S 62 oW 1002 9.3 S 62 o W 1163 12.0 S 74 o W 1341 14.3 S 74 o W 1465 15.4 S 75 o W Daily Mud Cost: 1,857 Cum. Mud Cost: 8,152 Daily Cost: 26,736 Cum. Cost: 212,820 05/20/89: Continue drlg f/1594' to 1876' w/Navidrill & DTV. Ream out dogleg f/1786' to 3005' both rotating and sliding the Navidrill bldg angle to 51.9 o . Drlg f/3005' to 3567' rotating straight ahead. Circulate bottoms up. Start short trip. 05~20~89 (Continued) MWD Directional Surveys: MD INCLINATION (o) DIRECTIONAL 1595 18.4 8 77.9 o W 1783 25.5 S 77.4 o W 1973 31.1 S 79.2 o W 2226 39.4 8 81.6 o W 2410 42.1 S 82.3 o W 2661 47.2 S 83.0 o W 3005 51.9 S 84.1 o W 3474 52.1 S 84.8 o W Daily Mud Cost: 1,479 Cum. Mud Cost= 9,631 Daily Cost: 29,786 Cum. Cost: 242,606 05/21/89= Continue short trip to.700g~ RIH to 3567.g. Drlg f/3567' to 5070t. Hole angle is malntaining (slight tendency to drop) but course direction tends to drift right (more than expected) requiring navigational steering periodically. MWD Directional Surveys: INCLINATION (o)... DIRECTIONAL 3631 51.4 8 85.7 o W 3818 51.1 S 87.8 o W 4039 51.0 B 86.6 o W 4288 50.9 S 88.3 o W 4821 51.7 S 83.0 o W Daily Mud Cost= 2,430 Cum. Mud Cost= 12,061 Daily Cost: 32,791 Cum. Cost: 231,397 ~05/22/89: Continue drlg. f/5070~ to 5429~. Circulate bottoms up - ' Short trip 20 stands. Continue drlg. f/5429, to 5637'~ Lost pump pressure. Pump pill. POOH, replace washed out center jet in bit. Some hole restrictions noticed while POOH @ 2832~ to 2274~. Change BHA (eliminate near bit stabilizer). 05/22/89 contwd. MWD Directional Surveys: MD INCLINATION (o) 5166 49.5 5450 48.2 DIRECTIONAL S 83.7 ow 8 05.9 o W (TVD=4197w) Daily Mud Cost: 2,970 Cum. Mud Cost: 15,031 Daily Cost: 34,972 Cum. Cost= 306,369 05/23/89: Continue making up BHA. RIH. Wash and ream through tight hole f/2830w-2900w. Continue RIH. Drlg. f/5637w to 5723~. Pllmp pressure is low and penetration rate is low. Mix and spot pill. POOH. L/D Navidrill and bit. The bits center jet is missing and jet retainer is partially washed out. P.U. new Navidrill and bit. RIH to 4740w. Break circulation. Cut & slip drlg line 80~. Reset orown-o-matio. Continue RIH to 5723~. Jet flowllne to unplug. Ream the bottom 42~. Drlg f/5723w to 5761~. MWD Directional Surveys= MD INCLINATION (o) DIRECTIONAL 5703 53.3 8 89.4 o W Daily Mud Costs 3,081 Cum. Mud Cost: 18,112 Daily Cost= 33,707 Cum. Cost= 340,076 05/24/89: Orient & Dyna drill f/5761, to 6262~. Circ., pump slug & short trip 15 stands. Tag 5, of fill, wash to bottom. Drill f/6262~ to 6277~I ream each joint to drop angle. Circ& condition to run CSG. MWD Directional Surveys= MD INCLINATION (o) DIRECTIONAL 5858 57.8 6047 57.2 6141 56.0 6187 56.4 888 ow 8 83.4 o W (TVD=4197 w) S 81.5 °W 8 82.5 o W (TVD=4197~) Daily Mud Cost: 1,385 Cum. Mud Cost: 19,497 Daily Cost: 69,392 Cum. Cost: 409,468 05/25/89= Circ & condition mud. POOH f/6277' to 230' SLM, several tight spots, 2500' to 2800'. RIH to 6277' to condition for csg. run. Circ bottoms up. POOH f/6277' top 5880', discovered conductor pipe & diverter had fallen 15". PU diverter & conductor & hang off on sub-base. RIH to 6277w. Repair flowline (fell off due to conductor). POOH f/6277'. LD 12 1/4" BH~. RU to run 9 5/87. csg. Conduct safety meeting concerning csg. work w/on tour crew. Run 4 joints of 9 5/8. Troubleshoot rig power failure. Daily Mud Cost= 405 Cum. Mud Cost: 19,902 Daily Cost= 33,700 Cum. Cost: 443,168 05/26/89= Repair Electrical failure between SCR & pipe shed. RU a run 159 joints of 9 5/8", 47 lb/ft NS0 csg w/BTRC thds. Float shoe -6254, MD. Float collar @ 6173.77' MD, ran 82 centralizers. Circ & condition mud. Pump spacer & cmt per attached* report. Lost returns after pumping lead, tail & 31 bbls of displacement. Estimate cement top @ 4400w. Tanko 9 5/8" hgr would not fall to starting head, hence PU 6' & hold pipe in elevators in preparation to use emergency system. Begin RU to run top job W/15.6 ppg Permafrost C. , Preflush 60 bbls of Sepiolite @ 11 ppg. Cement: (Stage 1) Permafrost E w/5 lb/sk gilsonite, 1654 sks (580 bbls) @ 12.3 ppg (Stage 2) Class G w/1% gel, 0.2% CFR-3, 3% NaCl, 272 sks (60 bbls) @ 15.8 ppg. Initial Circ. Press: 320 psi Initial String wt: 135 sO, 260 PU Initial Pump Press: 1000 psi Final Landing Wt.: 250 k lbs Maximum Pump Press: 3200 psi Cementing Pump Rate= 4-5 1/2 BPM Bottom Plug: No Top Plug= Yes Total Volume Pumped for dlspl.= 472 bbls Bumped Top Plug= Yes - Floats held Calculated Displacement Volume: 452 bbls. Test to 3000 psi (surface equip.). Bump plug & press up 1000 psi over & hold 15 min. Lost returns w/cmt top @ 4360'. 05/27/89: RU & pump 100 sks of 15.6 ppg Permafrost type C. Received 100% cmt returns after 50 sks were pumped. 1~t line run through hanger to 88' RKB. W.O.C. Slack off on 9 5/8", conductor falling w/9 5/8. PU csg(s). Weld 4'x4'xl" plate w/4 gussets to conductor. Slack off on 9 5/8" a diverter, RD csg. equipment, diverter, bell nipple, etc. Make finish cut on 9 5/8', csg. Daily Mud Cost= 2664 Cum. Mud Cost: 25,545 Daily Cost: 29,141 Cum. Cost: 779,153 05/28/89: Cut & weld 4'x4'xl" plate around 13 3/8,w w/4, gussets. Wells on slip-on 9 5/8 BTRC. Pin for speed head & allow to cool. Pressure test welds on csg. head to 3500 psi, MU split speed & torque to 11,00 lbs. NU X-O spool to BOP stack, install variable rams in top cavity & function same. Weld extension on choke line. MU test plug, test joint, safety valves & set test plug. Replace i gate valve on kill line. RU test equipment. Daily Mud Cost: 405 Cum. Mud Cost: 25,950 Daily Cost= 27,022 Cum. Cost: 806,175 05/29/89= RU flowline, repair various leaks. following to 5000 pslg. Pressure test the 5" pipe rams 5--7- variable rams Blind rams HCR valve Kill line valves Upper a lower kelly cocks T/W valve Choke line valves Choke manifold Adjustable choke Hydraulic choke Tested annular preventer to 2500 psi. Inside BOP failed test & will be repaired or replaced. Function tested accumulator. State Inspector - Harold Hawkins. LD test joint, install wear bushing, PU BHA & test MWD tools & orient. RIH, tag/cmt @ 6170' (4' above F.C.). Drill float equipment (Note: csg. tested when plug bumped). Drill cmt, shoe & 10, of new hole (6175,-6287,). Perform EMW test to 12.1 ppg (4678m TVD, MW 8.9 PPG, applied press. 785 psig). Drlg & Navidrlg f/6287' to 6683'. Daily Mud Cost: Daily Cost: 405 Cum. Mud Cost: 26,355 Cum. Cost: 05/30/89: Drlg f/6683' to 7278', Navidri11 4 joints to drop angle bldg tendency. Short trip f/7278' to 6253,. No drag noted. Drlg & Navidri11 f/7278' to 7840'. Short trip f/7840' to 7260', no drag noted. Fuel cost to date: 69,751 Daily Mud Cost= 3,905 Cum. Mud CoSt: 3'0,2:60 Daily Cost1126,229 Cum. Cost: 983,13~ ~, ,~: 05/31/89: Drilling and Navidri11 fl 7260' to 8084'. Leak developed in Kelly Hose. Trip out to csg. shoe. Change out Kelly Hose. Slip and cut drilling lime. Test Kelly Hose to 2500 psi-ok. RIH to 8084'. . Re~air conveyor belt for solids control equipment. Drilling F/8084' to 8478'. MD INCLINATION (o) DIRECTIONAL 7305 51.1 581.6W 7650 49.1 583W 8087 46.6 583W 8273 47.1 583W Daily Mud Cost: $ 2,464 Cum. Mud Cost: $ 32,724 Daily Cost: $39,919 Cumulative Cost: $1,021,981 06/01/89: Continue drilling F/8478' to 8806'. Pump pill and short trip to csg. shoe ~ 6287t. Replace sheared bolts on rotary drive clutch sprocket. RIH Ream 18' to bottom. Drilling and Dyna Drilling F/8806t to 9152'. MD INCLINATION (o) DIRECTIONAL 8470~ 47.8 582.5W 8803' 49.7 582.0W Daily Mud Cost: $ 2,204 Cum. Mud Cost: $ 34,928 Daily Cost: $36,383 Cumulative Cost: $1,058,364 06/02/89: Drilling F/9152, to 9276,. Short trip 6 stands. Drilling F/9276~ to 9637". Short trip 4 stands. Conducted BOP drill while tripping. Drilling F/9637' to 9806~. MD INCLINATION (o). DIRECTIONAL 9274 51.6 580.4W 9492 50.9 579.4W 9645 52.0 580.2W Daily Mud Cost: $12,978 Cum. Mud Cost: $ 47,906 Daily Cost: $50,507 Cumulative Cost: $1,108,871 06/03/89: Continue drilling F/9806' to 9991'. Short trip to 9637,. Drilling F/9991' to 10055'. POOH wed due to mud motor malfunction (thrust bearing failure). Verify D.P. tally. Remove R.A. sources F/MWD logging collar. Download survey data, process logs. L/D directional and formation evaluation MWD collars, i NMDC, Nay:drill and bit. P/U bit, lead collar, new formation and evaluation MWD collar. Evaluate log data-TD of 10,255' recommended. Calibrate logging collar, install R.A. sources. RIH. L/D D.P. to relog interval of 9600' to 9740'. MWD DIRECTIONAL SURVEYS ~D INCLINATION (0) DIRECTIONAL 9800 52.1 580.4W 9958 51.6 578.6W-Final Survey 6:00 Depth 10,164 ~ 30 1/hr Daily Mud Cost: $ 3,525 Cum. Mud Cost: $ 51,341 Daily Cost: $41,517 Cumulative Cost: $1,150,388 06/04/89: Ream and log (w/MWD) 9605' to 10,055'. L/D 12 yrs. Drilllng 10055' to 10255'. Circ. hole. Short trip 7 stds. Circulate bottoms up and pump pill. POOH to 9200' R.U. to L/D D.P., POOH laying down D.P. Tight spot @ 7682t. L/D HWDP. No directional surveys taken. Daily Mud Cost: $ 2,472 Cum. Mud Cost: $ 53,597 Daily Cost: $37,551 Cumulative Cost: $1,187,939 06/06/89.: L.D. HWDP and BHA. Pull wear busing RV to run 7" casing. Test pipe rams to 3000 PSI-ok. Hold safety meeting. Change out casing power pack unit. Run 7", 29#/FT, L- 80, buttress casing string. Lost mud returns break circulation - unable to get returns. @ 6650, continue RIH to 6736,.. Circulate'w/almost full returns @ 6736t. Continue runnxng casing to 9000,. Circulate w/al.most full returns @ 9000,. Continue running casing. Bridge @ 9650,. R.U. circulating head - attempt to work through bridge. Can not circulate. Pressure up to 1600 PSI without losing fluid. Unable to move pipe w/350,000 LB pull and 1600 PSI pressure. LOG RESULTS PER STEVE ROSSBERG Middle Kup: NEP = 56' 0 = 33% SW = 19% LAM. Zone: NEP = 8' 0 = 32% SW = 28% Lower Kup: NEP = 56' 0 = 32% SW = 24% Daily Mud Cost: $ 2,495 Cum. Mud Cost: $ 56,092 Daily Cost: $36,458 Cumulative Cost: $1,224,397 06/06/89: Continue attempting to free stuck 7" casing string. Pulling up to 450K pounds and pressure. LSG to 1600 PSI. No movement other than stretch. R.U. Alaska Pipe Recovery free point logging tool w/HLS wireline. Run free point survey. Pipe stuck at 7000' RKB. Pipe free at and above 6950' RKB. POOH w/wireline. Load perforation gun (4") w/6-4~ circulating charges (EHD = 0.46~, 1/4t~ to 3/3~' steel penetration, 120 degrees phasing). RIH w/perf gun to 9480' RKB. Perforate CSG F/9480'-9481o5' RKB. ~06/06/89 (Continued) Daily Mud Cost= $ -0- Cum. Mud Cost: $ 56,092 Daily Cost= $45,539 Cumulative Cost: $1,269,936 06/07/89: POOH w/perforating gun. R.U. circulating head. Attempt to circulate - no returns. Pressure up to 2100 PSI slowly - slow bleed off @ 2100 PSI. R.U. and run 2-1/2wt perforator w/8 deep penetrating charges F/9064t to 9066w (1-1/2 joints above ECP). R.U. circulating head. Break circulation, establish circulation of 6 BPM @ 950 PSI. Circulate and condition while working pipe. Max P/U 170K over string wt. - no change. (450K total hook load). P/U perf. gun r.i.h, and log through ECP(s) w/CCL, perf ECP(s) @ 91831 to 91881 - 10 shots (1 shot/6~) and 10 shots F/9127~ to 9130.5m. POOH, attempt to free pipe - no change. RIHw/free point tool - 100% free @ 6625~, 100% stuck @ 6650~, POOH found logging tool had backed off while TOH. Pump 80 bbls of Envirospot, mix and pump 20 additional bbls, displace w/20 bbls of Envirospot and 315 bbls mud. Now pumping 2 bph and working pipe. Daily Mud Cost: $ 2,500 Cum. Mud Cost: $ 58,592 Daily Cost: $42,000 Cumulative Cost= $1,311,936 06/08/89= Complete spotting of 120 bbl Envirospot pill pump 2 bph and P/U on ?m~. P/U to 485K (as shown on weight iod.) No change. N/D BOP, cut ?~, install slips and packoff. Begin N/~. Daily Mud Cost: $17,274 Cum. Mud Cost: $ 75,886 Daily Costs $110,700 Cumulative Cost: $1,360,636 06/09/89= N/U BOP change top and bottom rams to 3-1/2-. L/D 5" kelly and P/U 3-1/2~ kelly. P/U test plug and set in speed head attempt to test BOP. Test lower pipe rams, upper and lower kelly valve to 5000 psi - choke line connection leaking. Repair choke line and RIHw/overshot and guide to fish freepoint tool. Tools not falling @ 6300I. POOH, P/U weight bars and slot guide, RIH-tag fish @ 9330m, set down @ 94751 - POOH w/fish and R/D wireline unit. P/U test joint and plug, test kill line valves, upper pipe rams, blind rams, inside BOP and all choke valves to 5000 PSI, attempt to test hydrill to 2500 psi - no success. Rubber appears to be bad. Daily Mud Cost: $ 405 Cum. Mud Cost: $ 76,291 Daily Cost: $ 45,500 Cumulative Cost: $1,406,136 06/10/8~: Attempt to test annular preventer, no success, N/D Bell nipple - inspect bag, N/U bell nlpple (Bag and seals ordered - now in Prudhoe). P/U BHA and 3-1/2~w DP. Cement collar and around conductor (w/l- pipe @ 10t below starting head) w/200 sacks of Permafrost type C and 100 06/10/89,: (Continued) sacks of type E. P/U 3-1/2" drill pipe. circulate and condition mud. P/U 3-1/2,' DP. Circulate and condition mud. Drill float equipment and wash F/9581' to 10,255' - no obstructions (cement outside cellar w/150 sacks Type E). Circulate and condition mud. Short trip fl TD to 7" shoe - no tight spots. While working pipe and circulating - stuck and packed off @ 10,215,. Work pipe free and pull up into 7,,. Current operation - raise MW F/10.2+ to 10.5 ppg. Daily Mud Cost: $ 2,020 Cum. Mud Cost: $ 78,311 Daily Cost: $244,496 Cumulative Cost: $1,663,146 06/11/89: POOH to 7" casing shoe (9581'), wt. up f 10.2+ to 105 ppg. RIH to 10,136e and return to 10,236'. Circ. 1OW ViSCOSity sweep for hole cleaning (current circ. rate < critical vel. hence low visc. sweep for turbulent flow). Short trip to shoe, hit ledge @ 9973e. Work to 10014I. Wash and ream 10,172~ to 10,226~. Circulate low risc. sweep and spot high gels pill in open hole. POOH, tight spot @ 10,000'. R/U dresser 4 arm caliper. Daily Mud Cost: $ 4,271 Cum. Mud Cost: $ 82,582 Daily Cost: $ 60,350 Cumulative Cost: $1,723,496 06/12/89: R/Hw/dresser 4 arm caliper, wt bars and 1-3/8', stinger. Set down and worked through 9777,, 9863e, 9990~, 10,006', 10060e, 10150", 10170e. Begin logging up F/10,176,. Average hole size 7.85,,w/numerous washouts, POOH. RIH. Break circ. @ shoe. RIH to 9972~. Ream ledges F/10,000, to 10,036~, wash to bottom @ 10,236~. Circulate and condition. Short trip to shoe and RIH - no obstructions. Circulate and condition mud. While circulating and working pipe at 0100 pipe stuck, can circulate, cannot rotate - kelly bushings out of table. Bit depth 10,180,. Daily Mud Cost: $ 2,424 Cum. Mud Cost: $ 87,430 Daily Cost: $ 40,000 Cumulative Cost: $1,763,496 06/14/89: Circulate and condition mud. While working pipe downward, pipe became stuck @ 10,180,. Cannot get kelly bushings in r.t. to rotate. Attempt to work torque into pipe with tongs - no success, jarring on stuck pipe both up and down, reduce MW to 10 ppg. R/U HLS with A.P.R. string shot, RIH and backoff pipe @ 2420, (200 gram/ft shot). POOH, check pin of bottom joint, RIH, L/D top joint and kelly saver subs, P/U kelly and screw into fish @ 2420'. Continue jarring on stuck pipe, attempt to work torque to bit - no success; reduce mud wt. to 9.8 ppg - now in progress. Daily Mud Cost: $ 1,977 Cum. Mud Cost: $ 89,407 Daily Costs $ 65,000 Cumulative Cost: $1,828,496 06/15/89,: Work stuck pipe - jar up and down and attempt to torque. Drop MW F/10.00 ppg to 9.8 ppg. Perform blind backoff @ 2200t, P/U 12t pup and saver sub - screw into DP and torque. Attempt to run free point, could not get below 5900~, POOH. RIH w/string shot and perform backoff @ 9525w, POOH w/CCL and string shot. POOH w/drill pipe. P/U DC/CT jars, acc. jars and bumper sub and 13 DC. Begin R/H while rabbeting E pipe. 0430 currently jarring on fish and circulating to drop MW to 9.5 ppg. Daily Mud Cost: $ 1,178 Cum. Mud Cost= $ 90,585 Daily Costs $ 80,000 Cumulative Cost: $1,848,053 06/15/89,: Screw into fish @ 9530~, jar on fish-up and down, attempt to work torque to BHA. Circulating and lowering mud wt. F/9.8 to 9.5 ppg. Spot pill across open hole annulus F/10,180w to 9581~ - Envirospot~ begin pumping i bbl/hr. R/U HLS w/CCL and free point tool R/H to 5950 - set down, work to 6700~ and R/H to 9535~ calibrated tool @ 100% free R/H to 9670~ P/U to 200K# on drill string. S/D to 80K then P/U to 160K# tool 100% free, RIH to 9684 perform same - tool ~ 15% free. P/U to 9000~ - work pipe jarring up and down for 30 min. RIH to 9684~ perform free point - tool ~ 50% free. POOH R/D. Continue soaking with Envirospot. Pump I bbl/hr. Work pipe 1 time/hr. Daily Mud Costs $ 1,063 Cum. Mud Cost: $ 91,648 Dail~ Cost: $ 48,000 Cumulative Cost: $1,896,053 06/16/89= Soak fish with Envirospot. Pump i bbl/hr and jar string once/hr. Jarred fish up and down, P/U to 305,000 lb hood load. Free at last! Move pipe while R/D HLS, stand kelly back, L/D pup joint. POOH to 9150t - slowly watching for flow (no flow). Circulate and raise mud wt to 9.8 ppg, pump pill. POOH show, L/D fishing tools. Change Hydrill element. Daily Mud Cost: $ 3,914 Cum. Mud Cost= $ 95,562 Daily Cost: $ 51,076 Cumulative Cost: $1,947,129 06/17/89.: Complete installation of Hydril rubber, install bell nibble and flowline. M/U test joint, pull wear bushing. Test Hydril to 2500 (cycle several times) test lower kelly valve to 3000 psi - install wear bushing. P/U BA~. RIH, held BOP drill while tripping. Slip and cut 80t of drilling line. RIH to 10180~, rotate briefly, clean trip. POOH F/10 180~ to 9194~, no obstructions. Circulate and condition mud, pump 7 bbls of mud into 7" * 9-5/8" Annulus - not frozen. Strip out of hole. R/U and run 30 joints of 5t~ 1S-lb/hr N80 LTC. Circ. 50 bbls. @ 0330 RIH w/DP. Daily Mud Cost: $ 579 Cum. Mud Cost: $ 96,141 Daily Cost~ $ 41,000 Cumulative Cost: $1,988,129 06/18/89: RIH w/5", 18 lb/ft, NS0, LTC casing. Max speed 80 h/min (inside 7"), 40 ft/min (open hole). Ran 7 centrallzers (fully open = 7-1/2-) bow type - every other joint in open hole beginning w/ 1st joint. W/Baker CPH liner top packer w/10~ extension, 10' PBR and HMC liner hanger, V set float shoe, single valve float collar and landing collar type 1. Fill 3-1/2 drill pipe every 10' stands. Note: 7" perts@ 9064 taking fluid when circulating at 325 psi. No fluid lost while RIH. Break circulation and shoe. 30 joints of 5". Circulate mud and incorporate liner 4.0 pm and 1250 psig. Pump 10 bbl of diesel, 40 bbl of sepiolite spaker and 12.5 ppg, 5 bbl H20. Test lines to 3500 pslg. Mix and pump 57 bbls (272 sks) of 15.6 ppg. Class G w/0.2% CFR-3, 0.2% halad 344, 0.9% LWL. Bump plugs and pressure up to 3100 psi to set hanger and release running tool. Rotate to the right 8 turns and POOH. Pull 5 stands (all wet). Reverse out excess LMC. POOH, L/D running tool. P/U 6" bit; casing; scraper; 21 DC. RIH to ' 4000', circulate. Circulate to condition mud and warm 7" x 9-5/8" annulus WOC. RIH 1' tag soft cmt @ 8627.. Pump cement out w/10,000# WOB, 1600 psi to 8678'. Tagged firm cement at 8678; drill w/rotary and 10 KWOB. Note: liner top tagged at 0200 at 8864~, plug back = 10,141'. Daily Mud Cost: $ 547 Cum. Mud Cost: $ 96,688 Daily Cost: $ 60,000 Cumulative Cost: $2,048,129 o6/19/~9: Drilling Cont. F/8678' to 8864', top of liner a 8864'. P/U and circulate bottoms o/p. POOH F/8864t, L/D BHAand 7 joints DP. P/U 4-1/8 bit, 5" casing scraper, 3 3-1/8- DC and 42 joints of 2-7/8" drill pipe. R/H tag cont. at 10064g. Drill out firm cmt P/10064w to 10138'. Circulate and condition mud. Pressure test 7", 5- and liner lap to 3000 psi. No pressure lost for 30 minutes. Circulate, pump pill. POOH F/10138u. Injected 487 bbls of mud into the 7" x 9-5/8- annulus 3 bpm and 800 psi. Initial breakdown 1100 psi. Daily Mud Cost: $ 968 Cum. Mud Cost: $ 97,656 Daily Cost: $ 81,482 Cumulative Cost: $2,129,611 06/20/89: POOH, L/D 3 joints of 2-7/8" DP and 5" scraper R/U and R/H with Sperry Gyro, complete Gyro run and R/D. Surveys in target interval. MD INCLINATION AZ. TVD L~T DEPTH DLS 9600 50.86 258.6 6788 758.165 6,111.38W 0.4 9700 52.21 258.3 6850 773.855 6,188.13W 1.4 R/H with 4-1/8" bit 1250' of 2-7/8 DP, pollshing mill and 94 stands of 3-1/2" drill pipe. Mill and clean out PBR P/8876' to 8885'. P/U out of PBR and displace mud with 20 bbls H20 (after flushing lines and pumps) and 350 bbls of 9.6 Na Cl brine. L/D 3-1/2" drill pipe, slip and cut drilling line. Injected 0 bbl mud into 7" x 9-5/8- annulus. Mud Properties= Type 9.6 NaCl Brine. Daily Mud Cost: $ 2,189 Cum. Mud Cost: $ 95,467 Daily Cost= $ 73,247 Cumulative Cost: $2,205,192 06/21/89= Continue L/D 3-1/2" DP, 2-7/8 ,' DP, 3-1/8" DC and bit. Pull wear bushing and change out kellys. R/U to run TBG string. M.U. seal assembly and locator assembly. R/H with 3-1/3',, 9.2#/FT, L-80, EOE TBG and GLMs. Attempt to locate seal section inside PBR w/o success. Able t6o engage enough seal to hold at lease 1000 psi on the annulus and at least 800 psi on the TBG. But only about one foot of the seals are inside PBR. Pulling up to ~ 50,000 over string wt. When pulling back out of PBR. Verified that 8CSBY was open. Made 8 rotations of the TBG (at surface). Daily Mud Cost= $ -0- Cum. Mud Cost; $ 95,467 Daily Cost: $ 24,320 Cumulative Cost: $2,229,512 06/22/89~ Continue to attempt to locate seals inside PBR w/o success. Clean mixing pit, mud lines and mix 100 bbls of 9.6 PPG NaCl brine. Attempt to locate seals inside PBR while circulating and washing w/o success. Unable to get past 8875,. POOH strabbing TBG. Bottom two sets (of 11) seal ring missing. Bottom seal retainer and third set (of 4 sets) of seals show wear. Exact cause for seal sections not completely locating inside PBR is not known. Rig up HRS E-line unit. R/H with Junk basket and 5.95,, OD gauge ring to (top of liner) 8864~ WLM. No restrictions seen. Recovered parts of 3 seal rings. R/H w/4.00,, OD junk basket inside 5" liner - still in progress at report time. Daily Mud Cost= $ -0- Cum. Mud Cost: $ 95,467 Daily Cost: $ 37,076 Cumulative Cost: $2,266,588 ~6/23/89~ Continue running 4.05~ OD junk basket to 10,131~ WLM. Tool setting down throughout 5,, liner. Recovered a large quantity of seal rings and several small pieces of steel HMG..). Run CCI F/9100' to (pin and parts) F/liner ~ 8500'. Rerun 4.05 junk basket to 10,131~ WLM. Recover several small pieces of seal rings. Rerun 5.95" OD junk basket/gauge ring to top of 5,, liner - no recovery. R/D E-Line unit. M.U. w/1 reentry guide, install standing valve in X-N profile, 7" Hyd. Pkr and SBR. R/H on 3- 1/2~, 9.2/ft, L-80 TBG. Total no. of joints = 277. Otis 3-1/2~ series 10 SCSSY and control line installed and pressure tested. Tag llner top. Install TBG HNG, hook up control line, pressure test to 5000 psi - OK. Land TBG and lock down. Pressure TB~ to 4300 psi to set 06/23/89: (Continued) packer. PKR started setting at 2200 psi, SBR hydraulically sheared at 3100 psi. Bleed TBG pressure to 1500 psi, close safety valve, bleed surface TBG pressur off to 0 psi and perform closure test - OK. Equalize TBG pressure and open SCSSY. P/U TBG 17'. Displace TBG w/76 bbls of diesel, then overdisplace an additional 17 bbls. Reland TBG and lock down. Pressure test annulus to 2000 psi - OK. Back of landing joint and install BPV. Start ND of BOPE. Daily Mud Costs $ -0- Cum. Mud Cost= $ 95,467 Daily Costs $ 96,625 Cumulative Cost= $2,363,213 Top of Otis series 10 SCSSV - 503' RKB Top of 1" GLMss %1 - 2344'RKB #5 - 6970'RKB %2 - 3769WRKB %6 - 7605tRKB %3 - 5068tRKB %7 - 7928tRKB #4 - 6206'RKB #8 - 8279'RKB Note= All GLMs are loaded with 1t, dum~y valves with BK- 2 latches· Top of 7~, HCM PKR - 8757~ RKB Top of 3-1/2" XN NPL (w/275,, profile and 2.635" no go) - 8828'RKB Bottom of re-entry guide - 8862' RKB (Top of S" liner = 8864' RKB) Notes 1. · 0 · Standing valve is installed in X-N profile at 8828tRKB. P.U. wt prior to setting PKR = 80K lbs, s.c. wt = 45.K lbs. Control line banded every other joint. Total number of ss bands = 11. PKR seal elements and slips are located in the middle of & joint of 7w, (i.e. not in a collar). 06/24/89: Change upper and lower pipe rams to 5" ND BOPE. N.U. wellhead. Install double check valve in TBG HMG. Pressure test wellhead to 5000 psig - OK. Pressure test seals and SCSSY to 5,000 psi - OK. Pull double check valve and install BPV. Secure wellhead. Rig released at 0800 hours. Final fuel volume before moving = 11,300 gallons. Daily Mud Cost: $ -0- Cum. Mud Cost: $ 95,467 Daily Costs $103,775 Cumulative Cost= $2,466,988 .06/26/89.= OtiS arrived on location. RU tool string to pull standing valve. Rig up BPU lubricator on tree and pull BPV. Rig down. R.U. Otis w/c lubricator and pressure test to 2;000 psi. RIH. Pull standing valve, POOH valve 06_/26/89: (Continued) at 8799w WLM. Rig down, move to B-3. Daily Cost: $1,500 06/26/89: Schlumberger on location. R.U. to tree. Connection leak. Rig down tighten flange. R.U. pressure test lubricator to 1000 psi. RIH with gamma ray and cc1. Made first pass to tie in depth to MWD log. Made depth adjustment. Run in hole to PBTD. PBTD 10,134e WLM. Log up from PBTD to first gas lift mandrel at 8279w WLMPOOH. Arm enerjet 2-1/8ee 0 degree orientation 6 SPF. Gun 32e long. RIH and shoot from 9702e to 9734e WLM. 500 psi on lubricator POOH. Rig up seoondgun and arm. RIH and locate tubing tail. Tie into collars and shoot second gun from 9670e to 9702wWLM. POOH and rig down Schlumberger. Prepare to flow test well. Daily Cost= $ 54,500 Cumulative Cost: $2,521,488 'spenn - un i~1 ICl I L_I_ I I~ (~ S IE ICl %,' I CIE S June 21, 1989 Mr. Steve Brady Conoco, Inc. Pouch 340045 Prudhoe Bay, AK 99734 Re: Our Boss Gyroscopic Survey Job No. AK-BO-90057 Well: B-23 Milne Pt., Alaska Survey Date: June 20, 1989 Operator: D. Harger Mr. Brady: Please find enclosed two (2) copies of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company SPERRY-SUN DRILLING SERVICA~ ANCHORAGE ALASKA PAGE 1 CONOCO INC. B-23 MILNE POINT ALASKA COMPUTATION DATE: 6/21/89 DATE OF SURVEY: JUNE 20, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90057 KELLY BUSHING ELEV. = 53.79 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -53 100 100.00 46 200 200.00 146 300 300.00 246 400 400.00 346 .79 0 0 .21 o lQ .21 0 12 .21 0 13 .21 0 4 N .00 E .00 .00 .00 N 28.70 E .17 .13N .07E N 72.50 E .15 .32N .32E N 7.40 E .23 .56N .52E S 61.30 W .27 .72N .48E .00 -.09 -.35 -.58 -.57 500 500.00 446 600 599.99 546 700 699.94 646 800 799.78 745 900 899.30 845 .21 .20 .15 .99 .51 0 26 0 57 2 13 4 6 6 58 S 49.60 W .36 .44N .13E S 50.20 W .52 .35S .81W S 56.30 W 1.27 1.96S 3.06W S 59.50 W 1.90 4.85S 7.76W S 60.50 W 2.86 9.66S 16.13W -.18 .85 3.29 8.32 17.23 1000 998.29 944.50 9 10 1100 1096.74 1042.95 10 56 1200 1194.76 1140.97 11 51 1300 1292.37 1238.58 13 12 1400 1389.44 1335.65 14 34 S 62.70 W 2.22 16.30S 28.50W S 67.90 W 2.00 23.53S 44.38W S 72.10 W 1.23 30.26S 62.95W S 72.80 W 1.36 36.80S 83.65W S 73.00 W 1.36 43.86S 106.59W 30.34 47.02 66.30 87.66 111.32 1500 1485.97 1432.18 15 41 1600 1581.57 1527.78 18 22 1700 1675.30 1621.51 22 21 1800 1766.52 1712.73 25 58 1900 1855.52 1801.73 28 13 S 74.30 W 1.18 51.20S 131.65W S 75.40 W 2.70 58.83S 159.93W S 76.20 W 3.99 67.35S 193.68W S 75.90 W 3.62 77.22S 233.40W S 77.40 W 2.35 87.72S 277.73W 137.10 166.13 200.68 241.35 286.65 2000 1942.27 1888 2100 2026.17 1972 2200 2106.56 2052 2300 2184.14 2130 2400 2259.92 2206 .48 .38 .77 .35 .13 31 23 34 31 38 26 39 47 41 39 S 78.60 W 3.23 98.03S 326.36W S 81.40 W 3.47 107.42S 379.93W S 81.50 W 3.92 116.25S 438.71W S 81.60 W 1.35 125.52S 501.11W S 81.80 W 1.86 134.94S 565.65W 336.20 390.53 449.96 513.03 578.24 2500 2333.88 2280 2600 2405.82 2352 2700 2474.12 2420 2800 2538.71 2484 2900 2601.40 2547 .09 42 57 .03 45 0 .33 48 49 .92 50 41 .61 51 39 S 82.90 W 1.50 143.89S 632.36W S 82.70 W 2.04 152.59S 701.24W S 82.00 W 3.86 162.33S 773.60W S 82.20 W 1.87 172~82S 849.21W S 81.80 W 1.02 183.66S 926.35W 645.54 714.97 787.99 864.31 942.21 3000 2663.33 2609.54 51 48 3100 2725.11 2671.32 51 52 3200 2787.08 2733.29 51 31 3300 2849.08 2795.29 51 50 3400 2910.99 2857.20 51 39 S 82.40 W .49 194.45S 1004.12W S 82.70 W .25 204.65S 1082.09W S 82.90 W .38 214.48S 1159.95W S 83.40 W .50 223.84S 1237.85W S 83.70 W .30 232.66S 1315.89W 1020.72 1099.35 1177.84 1256.29 1334.82 ~PERRY-SUN DRILLING SERVICE~ ANCHORAGE ALASKA PAGE CONOCO INC. B-23 MILNE POINT ALASKA COMPUTATION DATE: 6/21/89 DATE OF SURVEY: JUNE 20, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90057 KELLY BUSHING ELEV. = 53.79 OPERATOR: D. HARGER FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3500 2972.94 3600 3035.10 3700 3097.88 3800 3160.90 3900 3224.15 2919.15 · 2981.31 3044.09 3107.11 3170.36 51 46 S 84.50 W .64 240.73S 1393.97W 51 2] S 84.80 W .48 248.04S 1471.96W 50 50 S 86.00 W 1.06 254.28S 1549.54W 51 1 S 86.40 W .35 259.42S 1627.01W 50 30 S 87.90 W 1.27 263.28S 1704.36W 1413.29 1491.58 1569.32 1646.81 1724.02 4000 3287.72 4100 3351.19 4200 3414.06 4300 3476.84 4400 3540.42 3233.93 3297.40 3360.27 3423.05 3486.63 50 33 S 88.10 W .16 265.97S 1781.52W 50 38 S 87.80 W .24 268.74S 1858.74W 51 26 S 87.10 W .97 272.20S 1936.42W 50 47 S 87.90 W .90 275.60S 2014.18W 50 15 S 87.70 W .56 278.56S 2091.31W 1800.89 1877.84 1955.32 2032.88 2109.76 4500 3604.26 4600 3668.19 4700 3731.19 4800 3792.97 4900 3854.69 3550.47 3614.40 3677.40 3739.18 3800.90 50 24 S 85.40 W 1.78 283.19S 2168.13W 50 6 S 85.60 W .34 289.23S 2244.78W 51 46 S 84.60 W 1.83 295.87S 2322.14W 51 55 S 84.80 W .22 303.13S 2400.44W 51 50 S 85.20 W .33 309.99S 2478.82W 2186.54 2263.34 2340.91 2419.50 2498.11 5000 3916.96 5100 3980.34 5200 4045.17 5300 4110.89 5400 4177.53 3863.17 3926.55 3991.38 4057.10 4123.74 51 7 S 85.80 W .85 316.13S 2556.82W 50 12 S 86.50 W 1.07 321.32S 2633.99W 48 57 S 86.90 W 1.30 325.71S 2709.99W 48 52 S 86.80 W .10 329.85S 2785.25W 47 31 S 88.10 W 1.66 333.18S 2859.72W 2576.26 2653.46 2729.40 2804.57 2878.86 5500 4244.81 5600 4310.83 5700 4373.72 5800 4432.33 5900 4487.26 4191.02 4257.04 4319.93 4378.54 4433.47 47 54 S 87.90 W .41 335.76S 2933.66W 49 27 S 87.30 W 1.60 338.91S 3008.69W 52 35 S 87.80 W 3.17 342.22S 3086.35W 55 37 S 88.00 W 3.03 345.19S 3167.31W 57 42 S 86.40 W 2.47 349.28S 3250.74W 2952.52 3027.34 3104.79 3185.46 3268.73 6000 4540.48 6100 4594.04 6200 4648.62 6300 4703.23 6400 4757.25 4486.69 4540.25 4594.83 4649.44 4703.46 57 59 S 85.60 W .73 355.19S 3335.19W 57 13 S 83.90 W 1.62 362.91S 3419.27W 56 36 S 84.50 W .80 371.38S 3502.63W 57 12 S 84.60 W .60 379.34S 3586.03W 57 24 S 84.40 W .26 387.40S 3669.79W 3353.25 3437.63 3521.39 3605.12 3689.23 6500 4812.87 6600 4870.23 6700 4929.20 6800 4989.57 6900 5049.53 4759.08 4816.44 4875.41 4935.78 4995.74 54 59 S 84.10 W 2.42 395.72S 3752.45W 55 0 S 83.60 W .41 404.50S 3833.89W 52 43 S 81.30 W 2.95 415.08S 3913.94W 53 0 S 81.30 W .29 427.14S 3992.74W 53 18 S 81.30 W .30 439.25S 4071.85W 3772.27 3854.17 3934.91 4014.61 4094.62 SPERRY-SUN DRILLING SERVICE~ ANCHORAGE ALASKA PAGE 3 CONOCO INC. B-23 MILNE POINT ALASKA COMPUTATION DATE: 6/21/89 DATE OF SURVEY: JUNE 20, 1989 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90057 KELLY BUSHING ELEV. = 53.79 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 7000 5108.84 5055.05 53 55 S 81.30 W .62 7100 5168.53 5114.74 52 46 S 81.20 W 1.16 7200 5229.20 5175.41 52 31 S 81.40 W .29 7300 5290.93 5237.14 51 13 S 81.50 W 1.30 7400 5353.63 5299.84 51 6 S 81.60 W .14 451.43S 463.63S 475.65S 487.35S 498.80S 4151.44W 4175.11 4230.73W 4255.31 4309.31W 4334.78 4387.10W 4413.43 4464.16W 4491.31 7500 5416.09 5362.30 51 34 S 81.80 W .50 7600 5479.09 5425.30 50 19 S 82.20 W 1.30 7700 5543.80 5490.01 49 1 S 82.40 W 1.31 7800 5609.16 5555.37 49 20 S 82.30 W .34 7900 5674.05 5620.26 49 44 S 82.00 W .45 510.07S 520.88S 531 · 10S 541.17S 551.56S 4541.43W 4569.40 4618.33W 4647.04 4693.87W 4723.27 4768.88W 4798.95 4844.26W 4875.04 8000 5740.94 5687.15 46 16 S 82.60 W 3.50 8100 5809.91 5756.12 46 31 S 82.30 W .34 8200 5878.59 5824.80 46 42 S 82.10 W .22 8300 5946.95 5893.16 47 3 S 82.10 W .36 8400 6014.95 5961.16 47 15 S 81.90 W .24 561.53S 571.05S 580.91S 590.94S 601.15S 4917.89W 4949.35 4989.68W 5021.76 5061.68W 5094.43 5133.98W 5167.42 5206.59W 5240.74 8500 6082.58 6028.79 47 37 S 81.60 W .44 8600 6149.67 6095.88 48 5 S 81.50 W .48 8700 6216.13 6162.34 48 35 S 81.00 W .62 8800 6281.77 6227.98 49 20 S 80.90 W .74 8900 6346.52 6292.73 49 57 S 80.50 W .68 611.72S 5279.48W 5314.38 622.61S 5352.83W 5388.53 633.98S 5426.69W 5463.22 645.85S 5501.18W 5538.63 658.16S 5576.38W 5614.78 9000 6410.98 6357.19 49 46 S 80.50 W .17 9100 6474.77 6420.98 50 57 S 79.70 W 1.32 9200 6537.52 6483.73 51 19 S 79.50 W .40 9300 6599.81 6546.02 51 37 S 79.20 W .38 9400 6662.28 6608.49 51 3 S 79.00 W .58 670.78S 684.03S 698.08S 712.54S 727.30S 5651.79W 5691.18 5727.65W 5768.11 5804.23W 5845.86 5881.11W 5923.96 5957.79W 6001.89 9500 6725.03 6671.24 51 12 S 78.60 W .35 9600 6787.91 6734.12 50 51 S 78.60 W .35 9700 6850.11 6796.32 52 12 S 78.30 W 1.37 9800 6911.36 6857.57 52 15 S 78.80 W .40 9900 6972.72 6918.93 52 2 S 78.70 W .21 742.43S 7 57.80S 773.47S 789.17S 804.57S 6034.16W 6079.57 6110.38W 6157.13 6187.09W 6235.21 6264.56W 6314.05 6342.01W 6392.83 9958 7008.52 6954.73 51 43 S 78.50 W .63 10000 7034.53 6980.74 51 44 S 78.80 W .56 10100 7096.71 7042.92 51 22 S 78.50 W .44 813.59S 820.08S 835.49S 6386.74W 6438.35 6419.07W 6471.24 6495.86W 6549.37 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6549.37 FEET AT SOUTH 82 DEG. 40 MIN. WEST AT MD = 10100 ~PERRY-SUN DRILLING SERVICE& ANCHORAGE ALASKA PAGE 4 CONOCO INC. B-23 MILNE POINT ALASKA COMPUTATION DATE: 6/21/89 DATE OF SURVEY: JUNE 20, 1989 JOB NUMBER: AK-BO-90057 KELLY BUSHING ELEV. = 53.79 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -53.79 1000 998.29 944.50 2000 1942.27 1888.48 3000 2663.33 2609.54 4000 3287.72 3233.93 .00 .00 .00 16.30 S 28.50 W 1.71 1.71 98.03 S 326.36 W 57.73 56.02 194.45 S 1004.12 W 336.67 278.94 265.97 S 1781.52 W 712.28 375.62 5000 3916.96 3863.17 6000 4540.48 4486.69 7000 5108.84 5055.05 8000 5740.94 5687.15 9000 6410.98 6357.19 316.13 S 2556.82 W 1083.04 370.76 355.19 S %335.19 W 1459.52 376.48 451.43 S 4151.44 W 1891.16 431.64 561.53 S 4917.89 W 2259.06 367.90 670.78 S 5651.79 W 2589.02 329.96 10000 7034.53 6980.74 10100 7096.71 7042.92 820.08 S 6419.07 W 2965.47 376.45 835.49 S 6495.86 W 3003.29 37.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE CONOCO INC. B-23 MILNE POINT ALASKA COMPUTATION DATE: 6/21/89 DATE OF SURVEY: JUNE 20, 1989 JOB NUMBER: AK-BO-90057 KELLY BUSHING ELEV. = OPERATOR: D. HARGER 53.79 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 53 53.79 153 153.79 253 253.79 353 353.79 -53.79 .00 .00 .00 .00 .02 N .01 E .00 100.00 .26 N .16 E .00 200.00 .39 N .48 E .00 300.00 .74 N .53 E .00 .00 .00 .00 .00 453 453.79 553 553.79 653 653.79 753 753.79 854 853.79 400.00 .65 N .38 E .00 500.00 .13 N .24 W .01 600.00 1.00 S 1.64 W .02 700.00 3.22 S 5.01 W .11 800.00 7.18 S 11.77 W .42 .00 .00 .02 .09 .31 954 953.79 1056 1053.79 1158 1153.79 1260 1253.79 1363 1353.79 900.00 13.04 S 22.20 W 1.15 1000.00 20.40 S 36.74 W 2.47 1100.00 27.61 S 54.78 W 4.35 1200.00 34.12 S 75.00 W 6.58 1300.00 41.15 S 97.73 W 9.37 .72 1.33 1.87 2.23 2.79 1466 1453.79 1570 1553.79 1676 1653.79 1785 1753.79 1898 1853.79 1400.00 48.75 S 122.94 W 12.78 1500.00 56.54 S 151.23 W 17.01 1600.00 65.28 S 185.30 W 23.03 1700.00 75.74 S 227.48 W 32.09 1800.00 87.52 S 276.82 W 44.25 3.41 4.23 6.03 9.06 12.15 2013 1953.79 2133 2053.79 2260 2153.79 2391 2253.79 2527 2353.79 1900.00 99.40 S 333.34 W 59.75 2000.00 110.33 S 399.22 W 80.02 2100.00 121.83 S 476.10 W 106.71 2200.00 134.16 S 560.25 W 138.00 2300.00 146.18 S 650.76 W 173.42 15.50 20.28 26.68 31.29 35.42 2669 2453.79 2823 2553.79 2984 2653.79 3146 2753.79 3307 2853.79 2400.00 159.21 S 751.09 W 215.72 2500.00 175.31S 867.45 W 270.01 2600.00 192.85 S 992.09 W 330.78 2700.00 209.28 S 1118.31 W 392.64 2800.00 224.53 S 1243.81 W 453.83 42.30 54.29 60.76 61.87 61.19 3469 2953.79 3629 3053.79 3788 3153.79 3946 3253.79 4104 3353.79 2900.00 238.40 S 1369.76 W 515.26 3000.00 250.15 S 1495.25 W 576.15 3100.00 258.87 S 1618.23 W 634.90 3200.00 264.59 S 1740.31 W 692.81 3300.00 268.86 S 1861.91 W 750.31 61.42 60.89 58.75 57.92 57.50 JPERRY-SUN DRILLING SERVICEa ANCHORAGE ALASKA PAGE 6 CONOCO INC. B-23 MILNE POINT ALASKA COMPUTATION DATE: 6/21/89 DATE OF SURVEY: JUNE 20, 1989 JOB NUMBER: AK-BO-90057 KELLY BUSHING ELEV. = 53.79 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4263 3453.79 3400. 4420 3553.79 3500. 4577 3653.79 3600. 4736 3753.79 3700. 4898 3853.79 3800. O0 O0 O0 O0 O0 274.56 S 1985.95 W 279.21 S 2107.37 W 287.90 S 2227.61 W 298.57 S 2350.69 W 309.89 S 2477.68 W 809.75 59.44 867.12 57.37 923.76 56.64 982.73 58.96 1044.75 62.03 5058 3953.79 3900. 5213 4053.79 4000. 5364 4153.79 4100. 5513 4253.79 4200. 5667 4353.79 4300. O0 O0 O0 O0 O0 319.37 S 2602.16 W 326.24 S 2719.87 W 332.32 S 2833.80 W 336.12 S 2943.60 W 341.20 S 3060.82 W 1104.71 59.96 1159.33 54.62 1211.05 51.71 1259.61 48.56 1313.81 54.20 5838 4453.79 4400. 6025 4553.79 4500. 6209 4653.79 4600. 6393 4753.79 4700. 6571 4853.79 4800. O0 O0 O0 O0 O0 346.28 S 3198.67 W 356.82 S 3356.43 W 372.13 S 3510.43 W 386.87 S 3664.41 W 401.88 S 3810.55 W 1384.23 70.42 1471.33 87.10 1555.60 84.27 1639.79 84.19 1717.54 77.75 6740 4953.79 4900. 6907 5053.79 5000. 7075 5153.79 5100. 7240 5253.79 5200. 7400 5353.79 5300. O0 O0 O0 O0 O0 419.97 S 3945.87 W 440.11 S 4077.51 W 460.66 S 4211.56 W 480.45 S 4341.02 W 498.83 S 4464.36 W 1786.81 69.27 1853.34 66.54 1921.84 68.50 1986.63 64.78 2046.47 59.84 7560 5453.79 5400. 7715 5553.79 5500. 7868 5653.79 5600. 8018 5753.79 5700. 8163 5853.79 5800. O0 O0 O0 O0 O0 516.74 S 4588.12 W 532.62 S 4705.27 W 548.24 S 4820.57 W 563.26 S 4931.21 W 577.29 S 5035.61 W 2106.59 60.12 2161.44 54.85 2214.87 53.42 2264.79 49.93 2310.04 45.25 8310 5953.79 5900. 8457 6053.79 6000. 8606 6153.79 6100. 8757 6253.79 6200. 8911 6353.79 6300. O0 O0 O0 O0 O0 591.95 S 5141.27 W 607.11 S 5248.27 W 623.29 S 5357.37 W 640.70 S 5469.04 W 659.59 S 5584.91 W 2356.26 46.21 2403.49 47.24 2452.38 48.88 2503.29 50.91 2557.50 54.22 9066 6453.79 6400. 9226 6553.79 6500. 9386 6653.79 6600. 9545 6753.79 6700. 9706 6853.79 6800. O0 O0 O0 O0 O0 679.40 S 5702.20 W 701.79 S 5824.21 W 725.30 S 5947.47 W 749.50 S 6069.22 W 774.44 S 6191.74 W 2612.91 55.41 2672.25 59.34 2732.70 60.46 2792.10 59.40 2852.21 60.11 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 CONOCO INC. B-23 MILNE POINT ALASKA COMPUTATION DATE: 6/21/89 DATE OF SURVEY: JUNE 20, 1989 JOB NUMBER: AK-BO-90057 KELLY BUSHING ELEV. = 53.79 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9869 6953.79 6900.00 10031 7053.79 7000.00 10060 7071.74 7017.95 799.81 S 6318.21 W 2915.43 63.21 824.82 S 6443.02 W 2977.31 61.88 829.26 S 6465.24 W 2988.26 10.95 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS HORIZONTAL B-23 MILNE POINT ALASKA JUNE 20, 1989 PROJECTION START TVD = 0 FINISH TVD = 7096.71 SCALE IS 1500 FEET/IN 9000 7500 ~I? ~ .-~ DEPARTURE 6000 4500 3000 1500 0 I , , I I , I , , A , 1500 3000 -4500 ,6000 75O0 90O0 P-23 MILNE POINT ALASKA JUNE 20, 1989 VERTICAL PROJECTION START TVD = 0 FINISH TVD = 7096.71 SCALE IS 1500 FEET/IN LLI . 1500 3000 4500 8000 7500 9000 10500 01( 6549.37 ts~)o 30~)0 45~0 60~)0 YERTICAL SECTION DIRECTION = 0.00 9o~o spenn -sun D !::! I I_1_ I N CS TO: Mr. John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: July 24, 1989 TRANS.#: 89713MPT-SSDS REFERENCE: CONOCO Milne Point B-23 TVD The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad>~, ENCLOSED INFORMATION SUMMARY Submittal B-23 1 Set C-20 Bluelines; 1 each: TVD Logs Calculated From Gyro Data 1 Set C-20 Sepia; 1 each: " 1 1 LIS Tape 1 1 LIS Tape Verification '' Received By: A.O.G.C.C. / Date 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company July 18, 1989 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' RE' Application for Sundry Approval Attached please find an Application for Sundry Approval for the Milne Point Unit Well B-23. The revision had been verbally approved by Mr. Mike Minder. As discussed with Mr. Minder the completed work will be included in the Well Completion Report. If you should have any questions, please contact Bob Soptei or Hal Stevens at (907) 659-6327. , Yours very truly, D. F. Rainwater/E. L. Robinson Senior Production Foreman RJS Attachments RECEIVED J U L 2 i989 Alaska Oil & Gas Cons. Comm/sslol'! '~ ;Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program ~ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development X__ KB = 54' MSC Exploratory __ 3. Address Stratigraphic __ 7. Unit or Property name P.O. Box 340045, Prudhoe Bay, AK Service__ Milne Point Unit 4. Location of well at surface 8. Well number 174' FSL, 868' FWL, Sec 18, T13N, RllE, UM At top of productive interval 596' FNL, 19' FEL, Sec 23, T13N, R10E, UM At effective depth 568' FNL, 93' FWL, Sec 24, T13N, R10E, UM At total depth 685' FNL, 468' FEL, Sec 23, T13N, R10E, UM feet B No. 23 9. Permit number 89-16 10. APl number 50-- 029-21915 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total d~pth: measured true vertical 10,255 ' feet Plugs(measured) 7,19 3 ' feet Effective depth: measured 9,500 ' feet Junk (measured) true vertical 6,725 ' feet Casing Length Size Cemented Structural - - _ ConduCtor 80" 13-3/8";45 9#/ft Cold Set · To Surface Sudace 6223' 9-5/8",47#/ft 1654 SKS 'E' Intermediate 272 SKS 'G' -- -- -- Production 7", 39#/ft None Liner _ _ _ Perforation depth: measured Not Applicable true vertical Tubing (size, grade, and measured depth) Not Applicable Packers and SSSV (type and measured depth) Not: Applicable None None Measureddepth 110' RKB 6254' RKB 9581' RKB True vertical depth 110' RKB TVD 4678' RKB TVD 4776' RKB TVD RECEIVED 3 U L 2 4 :t989 Alaska 0ii & Gas Cons. Commissi~ Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 06/17/89 16. If proposal was verbally approved Mike Minder 06/09/89 Name of approver Date approved Service 17. I hereby certify t..,t,,hat the foregoing is true and correct to the best of m'/knowledge. Signed ~/~' ~FoRTitlo/~CO~Y "~ Oil ~__ Gas __ Suspended __ Date '~'//o~/~ Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-, /¢-¢~- '.,-,hr ovect Copy "'~'~Returne, d ,~ ¢) ORIGINAL SIGNED BY ~/ LONNIE C. SMITH Approved by order of the Commission Commissioner lAppr°val N°' Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SUMMARY OF PROPOSAL FOR CHAN~ES TO THE MILNE POINT UNIT B-23 DRILLIN~ PRO~RAM While running the 7" production casing as originally proposed in the Drilling Permit, the pipe became differentially stuck at a depth of 7000' RKB. Circulation could not be established until the casing was perforated at 9064' RKB (above the external casing packers). The external casing packers at 9183' RKB and 9126' RKB were also perforated to deflate them. Additional attempts to free the stuck pipe were unsuccessful. At this time it was proposed to: 1) Hang off the 7" casing in place without cementing it in place. 2) Drill out the 7" float equipment with a 6" bit and re- establish the 8-1/2" hole. 3) 4) Run a 5" liner through at least the productive intervals and tie it back to a point 200' above the top perforation in the 7" casing. The liner would be isolated by a packer between the 5" and 7" at the top of the liner and cement up behind the liner and casing to a point at least 500' above the top of the Middle Kuparuk Formation (top productive interval). Clean out~gthe top of the 5" float collar. Pressure test 7" casing, 5" liner and liner lap to 3000 psig. 5) Run completion string. Made By Ctiecked By Dale Page 1 itle Conoco Inc, Calculation Sheet RECESVED LI tj L 2 4- E~,;'.~Y Alaska Oil & Gas Cons. fiommissiort Anchorage ,JOb NO M EMORAN DU M State df Alaska ALASKA OIL AND GAS CONSERVATION C(IVIMISSION DATE: June 1, 1989 ~missioner~Ai ~us ao: D. ~. O 40 THRU: Sr. Petroleum Engineer TELEPHONE NO: SUBJEC~ BOP Test~ Conoco Milne Pt. B-23 Permit No. 89-16 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum inspector Monday, May 29, 1989, I witnessed the BOP test on Conoco's B-23 ~~~e was ~/i~}'ailure' I filled out an AOGCC Field report which is attached. In s~ary, when the BOP test on Conoco's Milne Pt well B-23 was, completed. The tests were satisfactorily, with the exception of the inside BOP that failed. Attachment 02-001A (Rev. 8/85) O&G 5184 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Re/~rt Date 6~"/w~ ~/'~_~ Well Operator ~ fJ/w'Z~/.--~ Drilling Contractor Location, General General HousekeepinR~ Reserve Pit Mud Systems Visual Trip Tank ~[~ Y' Location: Sec_ Pit Gauge '~lo~Monitor ~-xx~as~Detectors BOPE Stack Annular Preventer _ Pipe- Rams Blind Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Well Sign Rig Audio Test Pressure ,?oo 6 / .. Test Results: Failures: Representative Permit #, ~ f Ca i g Set Ri~ ~ t~[ Representative ACC~ATOR SYST~ Full Charge Pressure ~3~ Pressure After Closure psig, psig / J-~,~ . -- rain //Osec. Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: _~-' min ---sec. Controls: Master Remote~ Kelly and Floor Safety Valves Upper Kellx Lower Kelly Ball Type Inside BOP Test Pressure. ~ Test Pressure., J'~ Test Pressure ~" Test Pressure, ~/~/~ Test Pressure Choke Manifold No. Valves ...... No. flanges / ~ Adjustable Chokes Hvdrauicall¥ operated ,choke Test Time ,~ , hrs. Repair or Replacement of failed equipment to be made within ~'~ days and Inspector/ Co~mffssion office notified. Remarks: ~ ~,-..~-;,{~ ~ '~ - . ~ ~ ~,, :~ ~ ,:. , ' .... Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspectcr MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COlor, fiSSION TO: Lonnie C. Smith?::i~_f DATE: May 30, 1989 Commi ss ioner FILE NO: D. ADA. 0 4 9 THRU: FROM: TELEPHONE NO: Michael T. Minder ~~.~' SUBJECT.' Diverter Test Sr. Petroleum Engineer Conoco MPU B-23 Permit No. 89-16 Kuparuk Rv Fie ld Doug Amos ~ Petroleum Inspector Tuesday, May 16, 1989, I traveled this date from AAI PBU to ~hbeS~' MPU~23~W~i to inspect and test the diverter system on Parker Rig no. 141. with the exception of two 45° turns which were replaced with targeted tee's, the diverter system was in compliance with AOC~C regulations. Please refer to the attached oliverter schematic for this correction. In summary, I witnessed the successful diverter test at Conoco's ~PU B-23 will on Parker Rig No. 141. Attachment ~2-001A (Rev. 8/85) , Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 May 17, 1989 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Sundry Notices for Milne Point Unit Wells Dear Mr. Chatterton: Please find attached Sundry Notices for the following Milne Point Unit Wells: B-23, C-20, E-3, and CFP-1. These notices have all been verbally reviewed by members of your staff. Should you have any questions, please contact either Roy Robinson or Doug Rainwater at 659-6323. Thank you for your time and consideration. D. F. Rainwater/E. L. Robinson Senior Production Foreman STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program ~ Pull tubing ~ Variance __ Perforate __ Other __ 2. Name of Operator CONOCO INC. 3. Address 5. Type of Well: .t201 I'. RT_, STF 2NN; ANNHNI~ARI:' qqRN3 4. Location of well at surface 173' FSL, 853' FWL, SEC 18, T13N, R11E, U.M. At top of productive interval 500' FNL, 200' FEL, SEC 23, T13N, RIOE, U.N. At effective depth N/A At total depth 545' FNL, 625' FEL, SEC 23, T13N, RIOE, U.N. Development _.~ Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KB 28 7. Unit or Property name M!LNE PO!NT UN!T 8. Well number B-23 9. Permit number 89-16 10. APl number 50-- ~n~q-_? ! _q l_ 5 11. Field/Pool Kuparuk feet 12. Present well condition summary Total depth: measured true vertical 10226' feet 7150' feet Effective depth: measured N/A feet true vertical N/A feet Casing Length Size Structural Conductor 13 3/8" Surface 9 5/8" Intermediate Production 7" Liner Perforation depth: measured TO be determined after logging true vertical To be determined after 1 oggi ng Tubing (size, grade, and measured depth) Plugs (measured) N/A Junk (measured) N/A N/A Cemented Measured depth No Change No Change No Change No Change Substitute No Change Dead Oil For Arctic Pak (60 bbl s)* 3 1/2", L-80, g.3 lb/ft., 9840' True vertical depth Packers and SSSV (type and measured depth) Otis HCH Perm-depth to be dtrmnd, SSSV-0tis Series 10 ~ 500' 13. Attachments Description summary of proposal __ Detailed operations program *Only change is Dead Oil in place of Arctic Pak BOP sketch __ 14. Esti mated date for commencing operation M~v 1.~. lqR9 16. If proposal ~vas verbally approved 05/09/89 NC, V, Chatterton ame of approver Date approved 15. Status of well classification as: Oil.x_ Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~-~2 /~,'/~~ Title Senior Prod. Foreman FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date IApproval No. Plug integrity __ BOP Test __ Location clearance __ O Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 App:'ov~(~ C'.: !)y Retu,'ned Commissioner Date SUBMIT IN TRIPLICATE March 6, 1989 Tele¢opy: (907)276-7542 D. F. Rainwater Senior Foreman Conoco !nc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point Unit No. B-23 Conoco Inc. Permit No. 89-16 Sur. ~c. 173'FSL, 853'FWL, Sec. 18, T13N, RllE, UM. Btmhole Loc. 545'FNL, 625'FEL, Sec. 23, T13N, R10E, UM. Dear Mr. Rainwater: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co_n~n_ission may witness testing before drilling below the shoe of the conductor pipe. Very truly ~ours, .,~', ,,1 :.:~.: . / C~iman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA . ,L AND GAS CONSERVATION C,_ ,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ,~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen Service [] Developement Gas [] Single Zone ~ Multiple Zone i~ "2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO, INC. KB 28 feet 3. Address 6. Property Designation 3201 C St. Suite 200, Anchorage, AK 99503 ADL 47437 Kuparuk River Field 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o ^^c 25.0251 173'FSL,853FWL,SEC.18,T13N,RllE,U.M.,NSB,AK. Milne Point Unit Blanket At top of productive interval 8. Well nurpber Number 8086-15-54 500 ' FNL, 200 ' FEL, SEC. 23, T13N, R10g B-23 At total depth 9. Approximate sppd date Amount $200,000 545'FNL,625'FEL,SEC.23,T13N,R10E May _8, 1 989 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth(MD a,d TVD> property line at target ~ 4780 feet B-9 21 feet 2560 [0,226'MD/7150TVD feet ,,, 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 510 Maximum surface 3200 psig At total depth (TVD) 3,800 psig 18. Casing program Setting Depth _ size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ..30" 13-3/8" 48# H-40 WELD 80' 28' 28' 108' 108' -+485 sks Permafrost C 12-1/4" 9-5/8" ,47# t:,L-80- BTRS 6251' 28' 28' 6279' 4650' +1848 sks Permafrost E +272 sks Class G 8-1/2" 7" '' ~9'# L-86' BTRS 10198' 28' 28' 10226' 7150' -+345 sks Class G -+180 sks Permafrost G 19. To be completed for Redrill, Re-entry, and Deepen Operations. -+ 60 Bbls Arctic Pak Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface IntermediateFEB 16 ]989 Production Liner Alaska Oil & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee ~ ProPerty plat ~ BOP Sketch ~.. Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements ~ 21. I her'eby Certify i'hat the foregoing is true and correct to the best of my knowledge Commission Use Only I~ermit 'Number ! APl number JApp J See cover letter ~:~'.- //~' 50-- O;~_., ?- ,~.// ~/,~' ,,, r(~a) ~%'~}89 for other requirements Conditions 6f approval Samples requir.ed [] Yes ~ No Mud Icg required _r&--] Yes ,~.No Hydrogen sulfide measures [] Yes ~rNo Directional survey required ~Yes [] No ' Required working pressure for BOPE I--t2M; [] 3M; [~ 5M; [] 10M; [] 15M Other: ~~. ~.~~~ ~/'~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit i'~ triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT NO. B-23 Conoco, Inc. 320! C Street, Suite 200 Anchorage, AK 99502 I. Casing and Cementing Program A. The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks Permafrost type "C" cement. B, The 9 5/8" surface casing will be cemented with ±1848 sacks of Permafrost "E" cement followed by ±272 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. C, The 7" production casing will be cemented in two stages. The primary cementing Job will consist of ±345 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±180 sacks of permafrost type "C" cement followed by +60 barrels of Arctic Pack, pumped down the 7" x 9 5/8" annulus. II. Drilling Fluid Program A~ 0-500 9.0 ppg freshwater spud mud. B~ C~ D~ III. 5000'-8000' 9.0 ppg-9.5 ppg dispersed. FEB 1 6 1989 8000'-10000' 9.5 ppg-lO.4 ppg dispersed. Atas~ Oil & Gas ~ns. Commission ~chorage D~111&ng P~og~am Conoco, Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be iow solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20", 2000 PSI diverter will be installed on the 13- RECEIVED FEB ! 6 Ala~J(a Oil & Gas Coas. Anchorage 3/8" conductor for drilling surface hole. a 13-3/8", 5000 PSI RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, Upper and Lower Kelly will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is B-9 with a closure of 21' at 1740' MD. As a precaution the B-9 well will have production shut in and the gaslift pressure bled off of the annulus while drilling within 400' either side of this point. The wellbore will also be 60' from the B-10 and B-6 wellbores at surface. The well will be flow tested after the rig is released.* Arctic Pack will be placed in the 7" x 9-5/8" annulus after disposing of test oil and excess drllling fluids. Ae B, Ce Drill a 30" conductor hole to ~80' and set 13-3/8" conductor. Drill a 12-1/4" surface hole to ~4650' TVD (6279' MD) and set 9-5/8" casing. Drlll a 8-1/2" production hole to 10226' MD and set 7" casing. TVD MD Formation Bit Mud Wt YP PV YIS FL O' 0' Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3800' 4885' "K" Sands 1-1-4 9.2 25 15 65 14 4091' 5358' "M" Sands 1-1-4 9.4 25 15 6~ 13 4287' 5676' "N" Sands 1-1-4 9.4 25 15 65 12 4365' 5803' "O" Sands 1-1-4 9.4 25 15 65 12 6506' 9280' Sea Bee 1-1-4 10.2 8 12 40 i0 6649' 9512' Kup Top 1-1-6 10.2 8 12 35 5 6800' 9758' MK 1-1-6 10.2 8 12 35 5 6818' 9787' 5. K. 1-1-6 10.2 8 12 35 5 6906' 9930' L K (i) 1-1-6 10.2 8 12 35 5 7018' 10112' b K (2) 1-1-6 10.2 8 12 35 5 7035' 10139' B L K 1-1-6 10.4 6 12 35 5 7150' 10326' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD a Sundry Notice will be submitted. --2-- COHOCO. ! ~. Pad' B. Uall No, 23 HI Ine Point Unit. Nor'_,~~/ope, Aleeke 0 . RKB ELEVAT[ON~ 28' 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ 8000 KOP TVD"500 TMD=500 DEP=O 5 I0 15 BUILD 2.5 OEO 20 PER 100 FT 3O 35 4O 45 50 EOB TVD=2273 TMD=2528 DEP-840 AVERAGE ANGLE 50 DEG 41 MI N g 5/8' CSO PT TVD=4650 TMD=6279 DEP=3743 TARGET TVD:6800 TMD=9673 DEP:6369 (TOP MID KUPARUK) BASE MID KUPARUK TVD=6850 TMD=9752 DE TD / ?= LINER TVD=7150 TMD=10226 DEP=6796 I 1000 I I I 1 I 2000 3000 4000 5000 6000 VERT ! CAL SECT ! ON I ?000 HORIZONTAL PROJECTION SCALE 1 IN. = I000 FEET 2000 1000 1000 CONOCO, !ne. Pad B. Well No~ HI Ine Point Unit, 23 Propoeed North Slope. Aleeka ZOO0 -- m 6000 5000 4000 I I I TD LOCAT [ ON t 545' FNL. 625' F'IEL SEC. 23. TI3N. RIOE TARGET TVD=6800 TI',tD=g6Z3 DEP=6369 SOUTH 673 I, IEST ~ WEST-EAST ,3000 Ii TARGET LOCAT [ ON t 500' FNL. 2130' F'EL SEC. 23, TI3N. RIOE £ ~..~ S 8:3 DEG 6369' (TO 2OO0 I 56 MIN W TARGET) 1000 0 1000 SURFACE LOCAT [ ON ~ IZ3' FSL. 853' FIJI. SEC. 18. TI3N. RIlE 300 200 100 0 100 200' 300 $00 ?00 600 500 400 300 I I I I I I 900 1 O0 2300 2500 1 gOO 21 O0 200 100 0 I I ~500-- 4100 1100 500 1300 1 500 i;.~ 4500 1 500 1 ?00 2300 5O0 O0 2?'00 100 200 1500 I?'00 ;00 500 1300 oo) ,1 300 200 100 _ 100 _ 200 _ 300 800 700 600 500 400 300 200 100 0 I 100 I 200 TIME ESTIMATE Hours Days Cum. Days A. Rig Up 8 0.33 0.33 B. Drill Surface Hole 96 4.00 4.33 C. Run Surface Casing and Cement 32 1.33 5.66 D. Drill Out and Test 6 0.25 5.91 E. Drill Production Hole 116 4.83 10.74 F. Log Open Hole 34 1.42 12.16 G. Condition, POOH, L.D. 18 0.75 12.91 Run Production Casing 16 0.67 13.58 I. Cement Production Casing 10 0.42 14.00 J. Run Cased Hole Logs & Perf 36 1.50 15.50 K. Run Completion EQ 12 0.50 16.00 L. Move Rig 0.33 16.33 TOTALS 392 16.33 16.33 -1 -2 -5 -4. -5 -6 -7 -8 -9 -10 -11 MILNE POINT UNIT WELL B ,.25 Rate vs.depth 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 RIG DAYS N ~L NE ~1 uqtT BOU~D&qY LAGOON SEC. SEC. SCALE IN MIL.ES CONOCO MILN[ POINT UNIT EXISTING DEVELOPMENT ARE ZONE 4. ARE BASED ON ARE COMPUTED GEODETIC POSITION LATITUDE LONGITUD[ DATE CHECKED It~ ~' 978' 6,022,911.TO .%72,058.98 ?0° ~'22 367" N. 149°24' 41. 176" W. 5.6, 82 L.K. J B'2 I 2' 910' 6,023,1P1.62 571,989.81 70°28'24.4'8'N. 141;°2.4'43.149''w. ,.2,,5 J.B.S. B- 4 I 165'~ 1158' 6,0ZZ ,960,76 572,239.11 7~28*22.83Z"N. 149°24'~5.865"W. 4.22,~ L.K. B-5A ~ 68' II10' 6,023,193. a5 572,178.88 7~ 28'25.1Z4"N. 149024' ST.570"W. 6. 2,85 d.B.S. ~ 115' 877~ 6, 023,238.24 571,955.56 70028'25-588 "N. 149°24'~.129'W. * * ~ 581', 760' 6, ~3,702.33 57 I, 834.~ 700 28' 30.164" N. 149024. 47. 56 I'W. ,, , = ~ 8 ~ 697 731' 6,023,818.~ 57 I ,804.~ ~ 28' 31.511 ~ N. 149024. 48.~8' W. .~ I 348' 819' 6,023, 470.52 571 ,894.74 ~o28, 27.878'N. 149°Z4'45.845'W. - L I II I I I I I I I m , i C 0 N 0 C 0 ,[CT dg. UT.L~S FROM ~ECT. ~8. SHEET ' D'~ENS~UN T~US'~. FROea N. LINL SECT I~. ALL UTl-~L~aS FROM S LINE FIELD BOOK 09-82 21-85 O9-82 09-82 21 4. LOCATED WITHIN SECTION 18 & 19, T 13 N , R II E , U.M. ,AK . OF F SETS BASED ON PROTRACTED VALUES OF SECTION CORNER POSITIONS. SEC. Il SEC. $1 I~r~ON LAGOON CONOCO IdlLN£ POINT UNIT EXISTING DEVELOPMENT I. STA'I'E PLANE COORDINATES ARE ZONE 4. ALL GEODETIC POSITIONS AR/ BASED ON N.A.D. 1921. OFFSETS; TO SECTION LINES ARE COMPUTED I~ASED ON PROTRACTED VALUES OF THE -- SECTION CORNER PDSITIONS. -- I I . LOCATION IN SECTION FROM S. LINF ,., 999' 183' 175' IrRDM W. UNE , 86E' I066' i i STATE PLANE CO-ORD$. NDRTHING$ _, . 6,024,121.~ 6,023,308.02 LASTINGS 571,9~! .99 572,143.63 4. LOCATED WITHIN SECTION 18 & 19, T 13 N,RIIE,U.M.,AK GEODETIC LATITUDE - ?0° 28' 3~. ~76 70O 28' 26. 256 N. POSITION LONG IT UD/ .... 149° 24' 44.56¢ w. 149° 24' 38.573 "W. DATE I. 12,~ II. 27, 85 CHECKED J.S. L.O. FIE LI~ tJOOK 44- 85 44 -85 CERTIFICATE OF SURVEYOR REGI~IER[D AND LICENSED 10 Pn~CT~CE LAND SURVEYING IN THE STATE OF ~ ~."~FESSION ~L ~'~ tiiSSDG, ENGINEERS AND LAND ~LIRVEYOR:S 'B' PA D A$-B ILT WELL LOCATION Surveyed fer CONOCO SI:ALE :. I" · 400' COHla ENT$ 1 D~MEN$10N THL~'I; FROM 'N. LINE SECT. 19, ALL OTHERS fROM S. LINE SECT. IS. ii U i ,i L~~R L~v~c . I. I. CONOCO, INC. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING FILL-UP LIRE FLOW LIRE ANNULAR PREVENTER (1) APl 50004 (2) J' $' - APl SO00 SIOE OUTLET" (3) APl 50004 RAid BOP 1~5/S' APl SO00d · '11' APl 5000 II' APl 5000~' (4) 3' aPw 5000 '" , SIDE OUTLETS SPOOL Threaded Connection R.O.P. stack size rating meets AP1 RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. 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· Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. Choke and kill manifolds shown separately to meet APl RP 53 class 5M requirements. CONOCO, INC. MILN£ POINT UNIT DIVERTER STACK FOR 13 318°...CONDUCTOR fILL UP LINE t ~~i~~"FLOW LINE ,, O' RELIEF VALVE ~0" SELL NIPPLE ~0' APl ~OC)O pei ANNUL~tR PREVENTER OlVERTER QUICK CONNECT ASSEMBLY SAVER 'SUB ASSEMBLY RECEIVED FEB 1 6 1989 s Y A R*r ,. 0 .r Ao Alaska Oil & Gas CoDs. Commission · Anchorage ' 13 3/e' C,&$1N6 1. The hydraulic control syste, will be in accordance with API specifications a~d AOGCC ~equirements. 2. The HCR valve will open ~hen the preventer closes. A single 10" relief li~e will run off of the drilling spool HCR valve a~d will have a targeted downs%ream tee for do~rMind diversion. Valves on both sides of the tee will be full opening and linked toae%he~ to enable on~ to al~ays be open and the other to be closed. , _ _ . ,' ~~__ RF_...SF,_.~RV~,. PiT UTILrT'¥ PO~R CUM~¢ Pi'iS ~^~_~. v^~.v~ ~~ P~PE /~A M I FOL'b_ 5O00 5ooo PSI k4A KIUA, L CHOKE 5OC~ tO, OOO PSI HYD C H4DI4, E.. II con",c Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-63OO February 13, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Attn. Mr. Mike Minder CCMM '-COMM RES ENG SR ENG SR ENG ENG AS.ST ENG ASST -SR GEOL GEOl. ASST GEOl. ASST STAT TECH STAT TECH FILE RE: Revisions to Permit to Drill Applications Dear Mr. Minder: Please find attached three (3) copies each of revisions for Conoco's Milne Point Unit B-23, C-20, and E-3 Permit to Drill. We have addressed your three concerns and have made the appropriate changes as discussed with you on the telephone on February 10, 1989. Should you have any more questions, please contact Roy Robinson or Doug Rainwater at 659-6323. Thank you very much, D. F. Rainwater/E. L. Robinson Senior Foreman RECEIVED FEB 1 6 1989 N. aska 0il & Gas Cons. Commission Anchorage Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 January 27, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 RE' REQUEST FOR PERMIT TO DRILL MILNE POINT UNIT WELLS B-23, C-20 AND E-3 Dear Mr. Chatterton- In accordance with AAC 25.005, Conoco Inc. hereby submits applications for permit to drill wells B-23, C-20 and E-3 in the Milne Point Unit, North Slope Borough, Alaska. Attached is a check for $300 payable to the State of Alaska, Department of Revenue to cover the required permitting fees. Well B-23 is tentatively scheduled to spud in early May and will be followed by wells C-20 and E-3. Conoco Inc. is covered under a $200,000 blanket bond for drilling (Number 8086- 15-54), filed with the AOGCC and approved December 22, 1980. Wells B-23 and C-20 are development wells in the Kuparuk reservoir. Well E-3 is a gas injection/storage well. Drilling the subject wells will increase re- covery from the Kuparuk reservoir and provide a necessary gas injection point; therefore, Conoco Inc. contends that drilling these wells is in the best interest of the Milne Point Unit Owners and the State of Alaska. Questions of a technical nature can be directed to Mr. Paul Grimmer in Conoco's Anchorage office at 564- 7635. Yours v~ ~ Division Manager RSR/cl Att File' 500.21 R CE VED i~lfi~s~.0il &. (;as Cons. Commission ..... ,~,~,, ~chora[!e STATE OF ALASKA ALASKA .)IL AND GAS CONSERVATION C,.,MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill rq! lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenEll Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2'. Na'me of Operator "' 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO, INC. ;KB 28 feet 3. Address 6. Property Designation 3201 C St. .Suite 200, Anchorage, AK 99503 ADL 47437 Kuparuk River Field ',~. Location of well at surface 7. Unit or property Name' 11. Type Bond(see 20AAC 25.025) 173'FSL,853FWL,SEC. 18,T13N,RllE,U.M. ,NSB,AK. Milne Point Unit Blanket At top of productive interval 8. Well nurpber Number 8086-15-54 500 ' FNL, 200 ' FEL; SEC. 23, T13N, R10E B-23 At total depth 9. Approximate spud date .... ~' Amount $200,000 545'FNL,625'FEL,SEc.23,T13N,R10E May .8, 1989. i2. DistanCe to nearest "': 13. Distance to nearest well 14. Number 0i acres in property 15. Proposed depth (MD and TVD) ~:, property line al: tar§et 4780,.. feet ~ B-9 21 feet 2560 L0,226'MD/7150TVD feet 16. To" be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) , Kickoff depth 500 feet 'Maximum hole angle 510 Maximum surface 3,000 psig At total depth (TVD) 3,800 psig ,, 18. Casing program =~. Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD'' TVD MD T'~D (incl'ude stage data) 30" 13-3/8" 48#. H-40 WELD 80' 28' 28' 108' 108'. -+485 sks Permafrost C !2-1/4" 9-5../8.', .... 36# J--55 .BTRS 6251' 28' .28' 6279' 4650' +1848 sks Permafrost E , · +272 sks Class G 8-1/2" 7" " 29# L-80 BTRS 10198' 28'./ 28" 10226' 7150' +345 sks Ciass G ' ~ i-+180 sks Permafrost G 19. To be completed for Redrill, Re-eniry, and Deepen Opera~,i~ns. _+ 60 Bbls Arctic Pak Present well condition summary Total depth: measured ~ feet/"' Plugs (measured) true vertical fee-{ Effective depth: measured ~/~et Junk (measured) true vertical //feet Casing Length Size/ :~Cemented Measured depth True Vertical depth Structural / Conductor ,~ ,?,~. :. Surface ;~/ EC[IVED Intermediate ~ - Production // J~?',[ 2 ? Liner ::" ,~,[as~ Od & Gas Cons. C0mrhissi0n Perforation depth: measured /' true vertical ' 20. Attachments Filing fee ~ property I~lat ~ BOP Sketch [] Diverter SkeiCh Dri ~ e~~d"correct to the best oi my I~'nowledge ' iling fluid progra..m ~~epth plot ~, Refraction analysis ~ Seabed report [] 20 AA(3 25.050 requirements [] 21. I hereb e for .. Signccr //,,/',~/-~"~ ~ "'ZCz'/7 . Title U, Date Commission Use Only , , , PermitNu'mber "IAPlnumber IApprovalOate I See cover letter , , ~'?_,//~' 50-- (:~2.~'---- ~//?/~K' for other requirements (~,onditions of approval Samples required [] Yes /;~ No Mud log requiied L-J Yes /~.No Hydrogen sulfide measures [] Yes ~ No Directional survey required ,,~'Yes [] No Required working pressure for BOPE ~2M; [] 3M; ~ 5M; [] 10M; [] 15M Other: by order of Approved by Commissioner the commission Date .... Form 10-401 Rev. 12-1.85 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT NO. B-23 Conoco, Inc. 3201 C Street, Suite 200 Anchorage, AK 99502 Casing and Cementing Program a. The 13-3/8" conductor will be set at 80' below the surface, then cemen~..dme to the surface with +485 sacks Permafrost type "C" cement . The 9 5/8" surface casing will be cemented with ±1848 sacks of Permafrost "E" cement followed by ±272 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. C~ The 7" production casing will be cemented in two sta~es. The primary cementin~ job will consist of ±345 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist oi ±!80 sacks of permafrost type "C" cement followed by 60± barrels of Arctic Pack, pumped down the ~7" x 9 5/8" annulus. II. Dril!in~ Fluid' Program A. 0-500 9.0 ppg freshwater spud mud. B. 500'-5000' 9.0 pp~-9.8 pp~ freshwater soud mud. C. D. 5000' -8000' 9.0 ppg-9.5 ppg ~dispersed. 8000'-!0000' 9.5 pp~-10.4 opg dispersed. III. Drillin~ Program Conoco, Inc. proposes drilling the subject well as a production well in the Kuparuk River Field% The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20", 2000 PSI diverter will be instgt].ed on the 13-3/8" conductor for drilling surface hole. a 13-3/8", 5000 PSI RSRRA BOPE stack will be used on the surface casin~. Pressure tests will be performed as ocr State Regulations. BOP'S, choke manifold, Upper and Lower Kelly will be tested to 500 psi~ and 5000 psiS, the~.Hvdril to 350 psi~ and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexoanded gas ~ubble, temperature taken into account. The closest wellbore is B-9 with a closure of 21' at 1740' MD. The well will be flow tested after the rig is released. Arctic Pack will be placed in the 7" x 9-5/8" annulus/after disposin~ of test oil and excess drilling fluids. a~ S~ C. Drill a 30" {~ conductor hole to ±80' and set 13-3/8" conductor. Drill a 12-1/4" surface hole to ±6265' MD and set 9-5/8" casin~. Drill a 8-1/2" production hole to 10326' MD and set 7" casinq. TVD 0 500 3800 4091 4287 4365 6506 6649 6800 6818 6906 7018 7035 7150 MD Formation Bit Mud Wt YP PV YiS FL 0 5O0 4885 5358 5676 5203 9280 9512 9758' 9787' 9930' 10142'_z 10139~ 10326' Gravel 1-1-4 Sand/Clay !-1-4 "K" Sands 1-1-4 "M" Sands I-1-4 "N" Sands 1-1-4 "O" Sands 1-1-4 sea Bee 1-1-4 Kup Top 1-!-6 MK !-1-6 L.K. 1-1-6 L K (i) 1-1-6 I, K B LK 1-1-6 10.2 t-1-6~ 10.4 1-1-6 10.4 9.0 32 20 90 15 9.0 25 20 65 15 9.2 25 ." ].5 65 14 9.4 25 15 65 13 9.4 25 15 65 12 9.4 25 15 65 12 10.2 8 12 40 i0 10.2 8 12 35 5 10.2 8 12 35 5 10.2 8 12 35 5 10.2 8 12 35 5 8 12 35 6 12 35 5 6 12 35 5 B-23/WP4A 3/88 CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 318' .CONDUCTOR FILL UP LINE ~_ , FLOat r . NCR VALVE ~ .... 1 ~CR VALVE 20# BELL NIPPLE 2000 )Iii ANNULAR PREVENTER DIVERTER GUICK CONNECT ASSEMBLY t. =. SAVER 'SUB ASSEMBLY ST&RTtt~G Relief lines from the drilling spool will be routed for downwind diversion. e Hydraulic control system will be in accordance with APl specifications and AOGCC regulations. Both HCR valves will open when the preventer closes, then either one may be closed. BOTE: Depending on rig contracted, the two 6" relief lines may be replaced by a single 10" line with a downstream tee. STATE OF ALASKA ALASKa. ,0IL AND GAS CONSERVATION C...MMISSION PERMIT TO DRILL 2O AAC 25.OO5 Re-Entry [] Deepen[]J Service [] Developement Gas [] Single Zone [] Multiple Zone [] 21 Name of 0perat'~r 5. Datum ElevatiOn (DF"~)r KB) 10. Field an~'Pool CONOCO, INC, KB 28 feet 3. Address 6. Property Designati'°n "' 3201 C St. Suite 200, Anchorage, AK 99503 ADL 47437 Kupa~..uk... River Field 4. i~oCatio~ of well at surface " 71"'Unit or propert~ Name 11./7~pe Bond (see 20 AAC 25.025) 173'FS~,853FWL,SEC. 18,T13N,RllE,U.M.,NSB,AK. Milne Point Unit ~Blanket At top~bf produCtive interval 8. WelI nurpber ........ /Number 8086-15-54 500 ' FNL'200 ' FEL, SEC. 23, T13N, R10E B-23 // At total depth 9. Approximate SPud d,~te // Amount $200,000 545'FNL 625'FEL,SEC.23,T13N,R10E May 8, 1989 / 12."Di'~tance to nearest 13. Distance to nearest well 14. Number of aCres in,,l~'r0perty 15. Proposed depth(MD and TVD) property line at target.., ,:. 478,0 feet B-9 , ,, 21 feet 2560 .,; L0,226'MD/7150TVD feet "161 To" be completed for,deviated'wells 17. Anticipated 'pr, e'~ure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 51° Maximum surface 3,sO00 psig At total depth (TVD) 3,800 18~ CaSing pr'~'grarn %..~ Setting,15epth size ~ Specifications Top / Bottom Quantity of cement H°le Casing Weight G~ade Coupling Lengih MD TVD MD TVD (include stage data) 30" 13-3/8" 48# H-4~O WELD 80' 28' .,~8, 108' 108' -+485 Sks Permafrost C_ 12-1/4" 9-5/8" 36# 3--5.5~. BTRS ..... 625!..' 28' i..~''28' 6279' 4650' _+1848 sks Permafrost E ~ / +272 sks Class G 8~i/2" 7"' 29#'"L-80 B~TRS' 10198' 28~.~''' 28' 10226' 7150' -+345 sks'Class G '"'~ ' ' / '"' _+180 sks Permafrost G , , ~ 19. To be completed for Redrill, R'e-e'ntry, ~nd DeePen Operations. _+ 60"Bbls Arctic Pak Present well condition summary ~-~,, Total depth: measured ~ feet Plugs (measured) true vertical /feet Effective depth: measured '" " feet Junk (measured) true vertical i~''/~ feet Casing Length ,iSizer~,. Cemented Measured depth True Vertical depth Structural / Conductor / ,¢ Intermediate / Liner Perforation depth: measure~~ ~$k~ Oj'/& I~aS Corl$o true vedical 20. Attachments .... Filir~g fe~''~ Property plat 58 BOP Ske'ich ~ 'Diverter'Sketch iM Drilling program ~" Drilling fluid program .X ~,~¢..e--~epth plot ~ Refraction analysiS,~ Seabed report [] 20 AAC 25.050 requirements [] '211'1 hereby~e forego)~e"and correct to the best'Of my knowledge .......... ' / / ~ Commission Use Only - Permit Number ' [ APl number ] Approval date j see' cover letter ~-* .~..,,,~ .... j 50- o 2_ ~.- 2_ / ~,~.~'I ..... j for other requirements Conditions of approval Samples required [] Yes ,,~No Mud Icg require~ L-][] o 'YeSN-"~N° Hydrogen sulfide measures [] Yes /'~ No Directional survey required ~r'Yes Required working pressure for BOPE E32M; [] 3M; ,~ 5M; [] 10M; [] 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT NO. B-23 Conoco, Inc. 3201 C Street, Suite 200 Anchorage, AK 99502 Casing and Cementing Program a~ The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with +485 sacks Permafrost type "C" cement. Bo Ce The 9 5/8" surface casing will be cemented with ±1848 sacks of Permafrost "E" cement followed by ±272 sacks of Class "G" cement. A top .job will be done if cement is not circulated to the surface. , The 7" production casing will be cemented in two stages. The Drimarv cementing job will consist of ±345 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±!80 sacks of permafrost type "C" cement followed by 60± barrels of Arctic Pack, pumped down the 7" x 9 5/8" annulus. II. Dril!in~ Fluid Program a. B. C. D~ 0-500 9.0 ppg freshwater spud mud. 500'-5000' 9.0 ppg-9.8 ppg freshwater spud mud. 5000'-8000' 9.0 pp~-9.5 pp~ dispersed. 8000'-10000' 9.5 pp~-lO.4 ppg dispersed. III. Drill±no Program Conoco, Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20", 2000 PSI diverter will be installed on the 13-3/8" conductor for drillin~ surface hole. a 13-3/8", 5000 PSI RSRRA BOPE stack will be used on the surface casin~. Pressure tests will be performed as ocr State Regulations. BOP's, choke manifold, Upper and Lower Kelly will be tested to 500 psi~ and 5000 psiS, the Hvdril to 350 psi~ and 3500 psig. Casin~ will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded qas bubble, temperature taken into account. The closest we!ibore is B-9 with a closure of 21' at 1740' MD. The well will be flow tested after the rig is released.. Arctic Pack will be placed in the 7" x 9-5/8" annulus after disposino of test oil and excess drilling fluids. a~ B~ C~ Drill a 30" conductor hole to ±80' and set 13-3/8" cond.lccor Drill a 12-1/4" surface hole to ±6265' MD and set 9-5/3" casin,q. Drill a 8-1/2" production hole to 10326' MD and set 7" casin~. TVD MD 0 500 3800 4091 4287 4365 6506 6649 6800 6818' 6906' 0~ 500' 4885' 5358' 5676 5803 9280 9512 9758 9787 9930 7018' 10~2 7035' 10139 7150' 10326 Formation Bit Mud Wt YP PV Gravel. 1-1-4 9.0 32 20 90 Sand/Clay 1-1-4 9.0 25 20 65 "K" Sands 1-1-4 9.2 25 ].5 65 "M" Sands 1-1-4 9.4 25 "N" Sands 1-1-4 9.4 25 15 65 "O" Sands 1-1-4 9.4 25 15 65 Sea Bee 1-1-4 10.2 8 12 40 Kup Top 1-1-6 10.2 8 12 35 MK 1-1-6 10.2 8 12 35 L.K. 1-1-6 10.2 8 12 35 L K (i) 1-1-6 10.2 8 12 L K (2) 1-1-6 t0.2 8 B L K 1-1-6 10.4 6 !2 TD 1-1-6 10.4 6 12 35 FL 15 15 14 ~3 12 12 i0 5 5 5 5 5 5 5 B-23/WP4A 3/88 CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 318':CONDUCTOR VALVE ~ 'u #CR VALVE . BELL NIPPLE , , 20' &PI 2000 ~si ANNULAR PREVENTER 0" RELIEF VALVE DIVERTER OUICK CONNECT ASSEMBLY SAVER 'SUB ASSEMBLY ® ® BOTE: Relief l£nes from the drilling spoo! will be routed for downwind diversion. Hydraulic controI system will be in accordance with AP1 specifications and AOGCC regulations. Both HeR ~alve~ viii o~en vhen :he preven:er close$~ then ~lther one may be closed. DependinE on tis contracted, ~he t~o 6" relief lines may be replaced by a sintle 10" lin~ ~ich a downstream tee. STATE OF ALASKA --~ ALASK,..)IL AND GAS CONSERVATION L, MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill E~I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[]~ Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator '" 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO, TNC. KB 28 feet 3. A~ldress 6. Property Designation 3201 C ~St. Suite 200, Anchorage, AK 99503 ADL 47437 Kuparuk' River Field 4. Location ~f well at surface "' 7. Unit or property Name 1'1. Type Bond (see 20 AAC 25.025) 173'FSL,8~3FWL,SEC. 18,T13N,RllE,U.M. ,NSB,AK .... Milne Point Unit Blanket At top of p~'~ductive interval 8. Well nurpber Number 8086-15-54 500 ' FNL, 200'~FEL, SEC . 23 , T13N, R10E B-23 At total depthS, 9. Approximategs~d date Amount $200,000 545'FNL,625'F~,SEC 23,T13N,R10E May _8, 1 "12. Distance to neares"t. 13. Distance to nearest well 14. Number of acres in property 15. ProP'~)'sed depth (MD and TVO) property line at target 4780 f~et ~B-9 2! feet 2560 0, 226 'MI)/7150TVD feet 16. To be completed for de d wells 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Kickoff depth 500 feet '~ Maximum hole angle 5 ! 0 Maximum surface 3,000 psig At total depth O'VD) 3,800 psig 18. Casing program ',., Setting Dep.t.h .... size Sp~cifications Top / Bottom Quantity of cement Hole Casing Weight Grad~.~Coupling Length MD ~VD MD TVD (include stage data) 30" 13-3/8". 48# H-40 '"WELD 80' 28' ,., 28' 108' 108' _+'~85 sks Permafrost C 12-1/4" 9-5/8" 36# J--55 BT~ 6251' ... 28' ~ 28' 6279' 4650' +1848 sks Pe..rmafrost \~ " +272 sks Class G 8'1/2" 7" 29# L-8~) BTRS ~,10198' 28! 28' 10226 7150' _+345 sks Class G "~ :"'~ _+180 sks permafroSt G 19. To be completed for Redrill, Re-entry, and Deepen Operations. _+ 60 Bbls Arctic Pak Present well condition summary Total depth: measured 'k. feet Plugs (measured) true vertical ~'feet Effective depth: measured fee{ ,Junk (measured) true vertical ~ feetk Casing Length Size C~ented Measured depth True Vertical depth Structural Conductor CE}YE Surface RE D Intermediate Production j~N 2 ~) Liner '~ ~ ~ Perforation depth: measured ~t3~ask~.OJl.& Gas Cons. C0mi~is~0R true vertical -.i~,~ ~ch0rage ' 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~, Diverter Sketc~h [] Drilling program Drilling fluid program ~epth plot '~ Refraction analysis [] Seabed report.? 20 AAC 25.050 requirements [] 21. I 'l~'ereb~at/{he~~, ~/~~ correct to the best of my knOwledge ,. " Signed Title , ;j, '... D...ate Commission Use Only ~ ~' --/~' i/ 50--~,~.Z,<7 --- .;~,/ ~'/~' , for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required _r-] Yes ,[:~"No Hydrogen sulfide measures [] Yes .,,~i~fNo Directional.survey required L~ Yes [] No Required working pressure for BOPE E}2M; ~ 3M; ~ 5M; [] 10M; [] 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT NO. B-23 Conoco, Inc. 3201 C Street, Suite 200 Anchorage, AK 99502 I. Casing and Cementing Program a. The 13-3/8" conductor will be set at 80' below the surface, then ~ cement cemen~d to the surface with ±485 sacks Permafrost type "C" . B. The 9 5/8" surface casing will be cemented with ±1848 sacks of Permafrost "E" cement followed by ±272 sacks of Class "G" cement. A top .job will be done if cement is not circulated to the surface. C. The 7" production casing will be cemented in two stages. The primary cementing job will consist of ±345 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±!80 sacks of permafrost type "C" cement followed by 60± barre].s of Arctic Pack, pumped down the 7" x 9 5/8" annulus. II. Drilling Fluid'Program A. 0-500 9.0 ppg freshwater spud mud. B~ C. 500'-500O' 9.0 pp¢[-9.8 ppg freshwater spud mud. 5000'-8000' 9.0 ppg-9.5 ppg dispersed. RECEIVED D. 8000'-!0000' 9.5 ppg-lO.4 ppg dispersed. III. Drilling Program Gas Cons. Commissior~ Conoco, Inc. proposes drilling the subject well as a production well in the Kuparuk River Field. The mud system will be low solids, non- dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20", 2000 PSI diverter will be installed on the 13-3/8" conductor for drilling surface hole. a 13-3/8", 5000 PSI RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, Upper and Lower Kelly will be tested to 500 psig and 5000 psis, the Hvdril to 350 psi~ and 3500 psig. Casin~ will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based, on an unexpanded ~as bubble, temperature taken into account. The closest weltbore is B-9 with a closure of 21' at 1740' MD. The well will be flow tested after the rig is released. Arctic Pack will be placed in the 7" x 9-5/8" annulus after disposing of test oil and excess drilling fluids. a~ B~ Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Drill a 12-1/4" surface hole to ±6265' MD and set 9-5/8" casing. Drill a 8-x/2 production hole to 10326' ~D and set 7 casino'. TVD MD O' O' 500' 500' 3800' 4885' 409i' 5358 4287' 5676 4365' 5803 6506' 9280 6649' 9512 6800' 9758 68i8' 9787 6906' 9930 7018' 10112 7035' 10139 7150' 10326 Formation Bit Mud Wt YP PV ¥iS FL Gravel 1-1-~ 9.0 32 20 90 15 Sand/Clay 1-1-4 9.0 25 20 65 15 "K" Sands 1-1-4 9.2 25 15 65 14 "M"~ Sands 1-1-4 9 .4 25 ~15 6~.. 13 "N" Sands 1-1-4 9.4 25 15 65 12 "O" Sands 1-1-4 9.4 25 15 65 12 Sea Bee 1-1-4 10.2 8 12 40 i0 Kup Top 1-1-6 10.2 8 12 35 5 MK 1-1-6 10.2 8 12 35 5 b.K. 1-1-6 10.2 8 12 35 5 L K (]) 1-1.-6 10.2 8 12 35 5 L K (2) 1-1-6 10.2 8 12 35 5 B L K 1-1-6 10.4 6 12 ~5 5 TD 1-1-6 10.4 6 12 35 5 B-23/WP4A 3/88 CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 3/8'~CGNDUCTOR F~LLUP c~.E~ t · EOTE: ~ ~) FLOW LINE HCR VALVE i~ ' '-~ MCR VALVE 20" BELL NIPPLE 20' &Pi ~000 ~ii ANNULAR PREVENTER OIVERTER OUICK CONNECT RELIEF VALVE SAVER 'SUB A$$EMBL'T STARTING HEAD t~ 5/8' CASI~G Relief lines from the drilling spool will be routed for downwind diversion. Hydraulic control system will be in accordance with AP! specifications and AOGCC regulations· Both HCR valves will open when the preventer closes, then either one may be closed. Depending on rig contracted, the two 6" relief lines may be replaced by a single 10" line with a downstream tee. ITEM (1) Fee (2) Loc _-~ LIST FOR NEW WELL PERMITS APPROVE DATE (2 thru 8)' (8) (3) Admin .,~'FC /~ (9 thru 13) (10 and 13) ( 4 ) C a s g ~z' ~f.f? ~ - ~ ~ ? (14 thru 22) (23 thru 28) Company _~-.~zuTc~'~ Lease & Well No. YES NO REMARKS Is the permit fee attached .......................................... ~, -- 2. Is well to be located in a defined pool ............................. .~ 3. Is well located proper distance from property line .................. ~__ 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ ~_ 6 Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... /~ e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached, Does BOPE have sufficient pressure rating - Test to ~o~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thru 31) (6) Add: ,~...w~...~ ~-~-~9 Geology: Engineering: DWJ~ LCS ,~-~,5 .,' ~BEW ,/, rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE 0 ~0 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 89/07/24 ORIGIN OF DATA: RLL REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: sSDS DATE: 89/07/24 ORIGIN OF DATA: B23 TAPE NAME: MILNE PT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: SSDS REV SERVICE NAME: SSDS VERSION #: REV 1.01 DATE: 89/07/24 MAX. RECORD LENGTH: 1024 FILE TYPE: B2 PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT GRC MWD EWR MWD TVDG GYRO ROP MWD FXE MWD FXN MWD FXD MWD RHOB MWD CAL MWD CNPS MWD TVDM MWD NDIS GYRO EDIS GYRO DEVI GYRO ORDER# L0G TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 OHM~ 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 DEG 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY 255 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT GRC MWD EWR MWD TVDG GYRO ROP MWD FXE MWD FXN MWD FXD MWD RHOD MWD CAL MWD CNPS MWD TVDM MWD NDIS GYRO ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 AAPI 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 FT 0 0 0 0 1 4 0 1 68 EDIS GYRO FT DEVI GYRO DEG 0 0 0 0 i 4 0 i 68 0 0 0 0 i 4 0 i 68 ** 669 DATA RECORDS ** FROM 5000.00 TO ** FILE TRAILER** FILE NAME: SSDS REV SERVICE NAME: SSDS VERSION #: REV 1.01 DATE: 89/07/24 MAX. RECORD LENGTH: FILE TYPE: B2 NEXT FILE NAME: 1024 ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 89/07/24 ORIGIN OF DATA: B23 TAPE NAME: MILNE PT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT 10350.00 FT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 89/07/24 ORIGIN OF DATA: RLL REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SPERRY DATE: 89/09/22 ORIGIN OF DATA: MWD REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 89/09/22 ORIGIN OF DATA: B-23 TAPE NAME: MILNE PT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** COMMENTS ** ********** END OF FILE (EOF # 1) ********** RECEIVED FEB - Alsska Oil & G~s Cons, Anohomge ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: B-23 REV SERVICE NAME: RLL VERSION #: CNOX DATE: 89/09/22 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE ID ORDER# LOG TYP CLS MOD NO. DEPT FT 0 0 0 0 1 GRC AAPI 0 0 0 0 1 EWR OHMM 0 0 0 0 1 TVDG FT 0 0 0 0 1 ROP FT/H 0 0 0 0 1 FXE HOUR 0 0 0 0 1 FXN HOUR 0 0 0 0 1 FXD HOUR 0 0 0 0 1 NFO CTS 0 0 0 0 1 NFl CTS 0 0 0 0 1 NN0 CTS 0 0 0 0 1 NN1 CTS 0 0 0 0 1 NPSC P.U. 0 0 0 0 1 RHOB G/C3 0 0 0 0 1 CAL INCH 0 0 0 0 1 TVDM FT 0 0 0 0 1 NDIS FT 0 0 0 0 1 EDIS FT 0 0 0 0 1 DEVI DEG 0 0 0 0 1 SZE PROC SPL REPR LVL CODE 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 GRC AAPI 0 0 0 0 1 4 0 1 68 EWR OHMM 0 0 0 0 1 4 0 1 68 TVDG FT 0 0 0 0 1 4 0 1 68 R0P FT/H 0 0 0 0 1 4 0 1 68 FXE HOUR 0 0 0 0 1 4 0 1 68 FXN HOUR 0 0 0 0 1 4 0 1 68 FXD HOUR 0 0 0 0 1 4 0 1 68 NFO CTS 0 0 0 0 1 4 0 1 68 NFl NN0~ NN1 NPSC RHOB CAL TVDM NDIS EDIS DEVI CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 P.U. 0 0 0 0 G/C3 0 0 0 0 INCH 0 0 0 0 FT 0 0 0 0 FT 0 0 0 0 FT 0 0 0 0 DEG 0 0 0 0 1 1 1 1 1 1 1 1 1 1 4 4 4 4 4 4 4 4 4 4 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 ** DATA VERIFICATION (every 500 FT) ** DEPT GRC EWR TVDG ROP FXE FXD NFO NFl NN0 NN1 NPSC CAL TVDM NDIS EDIS DEVI FXN RHOB 5000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 7500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8000.000 -999.250 -999.250 5740.963 -999.250 -999.250 -999.250 -999.250 -999.250 5725.335 -20.346 -148.998 -999.250 -999.250 -999.250 -999.250 46.275 -999.250 -999.250 8500 2 9 .000 80.850 3.285 6082.646 .638 -999.250 -999.250 -999.250 .567 6065.656 -70.525 -510.553 84.211 2.511 -999.250 29.660 47.615 2.565 2.968 9OOO 6 8 .000 85.664 3.274 6411.117 .078 -999.250 -999.250 -999.250 .612 6391.119 -129.578 -882.799 65.463 5.859 -999.250 38.338 49.766 5.955 2.359 95OO 10 9 .0OO .064 .052 99.438 2.697 6725.203 616.407 619.331 2394.354 6703.824 -201.215 -1265.153 24.378 9.292 2326.612 47.461 51.200 9.483 2.181 10000 22 9 .000 .677 .605 64.752 7.572 7034.671 615.000 647.000 2664.000 7013.145 -278.699 -1650.130 47.021 22.596 2456.000 31.277 51.734 22.629 2.573 ** 824 DATA RECORDS ** FROM 5000.00 TO 10350.00 FT ** FILE TRAILER** FILE NAME: B-23 REV SERVICE NAME: RLL VERSION #: CNOX DATE: 89/09/22 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ** TAPE TRAILER** SERVICE NAME: RLL DATE: 89/09/22 ORIGIN OF DATA: B-23 TAPE NAME: MILNE PT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SPERRY DATE: 89/09/22 ORIGIN OF DATA: MWD REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT
