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194-114
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC J-11 MILNE PT UNIT J-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/01/2024 J-11 50-029-22502-00-00 194-114-0 W SPT 3892 1941140 1500 2250 2250 2254 2255 402 460 464 467 4YRTST P Adam Earl 1/14/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT J-11 Inspection Date: Tubing OA Packer Depth 1188 1670 1655 1657IA 2255 467 45 Min 1657 60 Min Rel Insp Num: Insp Num:mitAGE240117080911 BBL Pumped:0.4 BBL Returned:0.4 Friday, March 1, 2024 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor rr FROM: Austin McLeod Petroleum Inspector Well Name MILNE PT UNIT 1-1I Insp Num: mitSAM200131161728 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 4, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC 1-11 MILNE PT UNIT 1-11 API Well Number 50-029-22502-00-00 Permit Number: 194-114-0 Packer Well 1-11 Type Inj w ' TVD PTD 1941140 Type Test SPT ITest ps BBL Pumped: 0.8 BBL Returned: Interval I 4YRTST P/F Notes: MIT -IA Ste: Inspector Reviewed By: P.I. Supry G Comm Inspector Name: Austin McLeod Inspection Date: 1/31/2020 - lepth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3892 Tubing 2378 - 2:79 - 2177 - 2,77 2776 Isoo IA 580 1338 1783 - 0 0.9 OA 62 197 203 -_1752- 193 134 P Tuesday, February 4, 2020 Page 1 of 1 • MEMORANDUMState of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 14,2016 TO: Jim Regg &'71q Z /(14 '/(o P.I.Supervisor 1q SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-11 FROM: Jeff Jones MILNE PT UNIT KR/SB J-11 Petroleum Inspector Src: Inspector Reviewed By: �� P.I.Suprvj(pp,--- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR/SB J-11 API Well Number 50-029-22502-00-00 Inspector Name: Jeff Jones Permit Number: 194-114-0 Inspection Date: 1/8/2016 Insp Num: mitJJ160110123245 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J-11 ` Type Inj W'TVD 3892 - Tubing f 2321 - 2321 - 2321 - 2320 - - PTD( 1941140 Type Test;SPT Test psi' 1500 - IA 340 1835 - 1793 . 1777 - Interval 4YRTST P/F P / OA 90 272 - 266 258 — Notes: 1.1 BBLS diesel pumped. 1 well inspected,no exceptions noted. i SCO . " ' ', 111 Thursday,January 14,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 07,2016 TO: Jim Regg 'i- . 11141/(0 P.I.Supervisor ( I SUBJECT:Mechanical Integrity Tests HILCORP ALASKA LLC J-I 1 FROM: Matt Herrera MILNE PT UNIT KR/SB J-11 Petroleum Inspector Src: Inspector Reviewed B+ P.I.Supry =Jb — NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR/SB J-11 API Well Number 50-029-22502-00-00 Inspector Name: Matt Herrera Permit Number: 194-114-0 Inspection Date: 1/5/2016 Insp Num: mitMFH160106130418 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J-11 Type Inj W TVD 3892 - Tubing 2330 2336 - ' 2334 - 2334 - 23491 2355 - PTD Type Te 1900 3 �-_--— � - 1910 -' 1879 - 194i14o yp SPT Test psis 1500 IA 620 1924 1913 -- - Interval 4YRTST PAF I •/ OA H 149 312 325 342 - 349 - 342 Notes: Due to unstable injection operations and thermal conditions,it was determined well bore not stable enough to get a conclusive test.Will retest at a later date.Test to 1900 PSI per operator request. SCANNED 2 '" ' r Thursday,January 07,2016 Page 1 of 1 MEMORANDUM to NDUM S to of Alaska Alaska Oil and Gas Conservation Commission TO: JimRegg DATE: Wednesday, January 11, 2012 ((II P.I. Supervisor ) SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC J - 11 FROM: Chuck Scheve MILNE PT UNIT KR/SB J - 11 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Jige- NON CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR/SB J - 11 API Well Number: 50 029 22502 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS120108081525 Permit Number: 194 - 114 - Inspection Date: 1/7/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well J-II - Type Inj. W ' TVD 3892 IA 180 2010 1960 1960 ' P.T.D 1941140 'TypeTest SPT Test psi 1500 O 10 210 200 180 Interval 4YRTST p/F P ' Tubing 2400 2400 2400 2400 Notes: pretest pressures observed and found stable. S t. /WNW FER 16 2012 Wednesday, January 11, 2012 Page 1 of 1 ~r~L~ L ~~~~~~~ g, PeoacrivE DiAyn~ic SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907j 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 , qK-!l U ~i ~` 9 «~ 1 ] Injection Profile 01-0ep-09 MPU J-11 2j Signed Print Name: BL / EDE 50-029-22502-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL : -~ sJ, .~+ 1, WEBSITE C:\DocumenG and Settings\Diane Williams\Desktop\Transmit_BP.decx MEMORANDUM TO: Jim Regg ~~~' ~ 1' j ~~ ~~ `b P.I. Supervisor FROivt: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Cas Conservation Commission DATE: Tuesday, January I~, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC J-Il MIL~,B PT UNIT KR/SB J-t 1 Src: Inspector NON-CONFIDENTIAL Reviewed By: ~~ P.I. Suprv ~, P~ Comm WCII Name: MILNE PT UNiT ICR/SB J-1 i API Well Number: so-oz~-zz5o2_o0-0o Inspector Name: Bob Noble Insp Num: mitRCN0801 1 1 1 74220 Permit Number: 194-I 14-0 - Inspection Date: 1/11/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ I I ~ Type Inj. `h' TV-D ~I sa9z IA i Ioso ! I6oo ~_ ~ oo -~-••~.,oo ~ ~~ _ P.T % t941140 ~TypeTeS[ ~ SPT ~ TCSt psl '~ 1600 i QA ~ 320 ~ 390 390 390 4YRTST P Interval P/F / TUbin ~ 2760 ?160 g: ~ 2160 ~ 2160 i Notes: _. - - - ~~1~ i ~~~ .~~~ ~ ~ ~~~~ Tuesday, .Ianuary l5, 2008 Pale 1 of 1 ( () <1'-1 -I 1 L,! WELL LOG ~II. TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson BP Exploration(Alaska), Inc. ProActive Diagnostic Services, Inc. Petro-Technical Data Center LR2-1 P. O. Box 1369 900 East Benson Blvd. Stafford, TX 77497 Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUEllNE Open Hole 1 1 1 MP J-11 i 1-2-03 Res. Eva!. CH ð\ ~, I 1 1 1;-j.~ -, L , ~ . Mech. CH 1 Caliper Survey ""'~ .... ~ Signed: " '~fj \ U./Ý\ \~~ '- 0 ct). ~ ~JV--..... Date: HEGEßlED \. Print Name: ! ,', [', I 2 (J 2004 ~J ,. I . ,AJaska Oil & Gas Cons. Comm- Aochorage PRoAcTivE DiAGNOSTic SERvicES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~CA~~El): ¡FEE {p2 200L~ ~~~D~~ .( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~¥1) 11f'5)(ýj DATE: January 8,2004 P. I. Supervisor SUBJECT: Mechanical Integrity Tests FROM: Jeff Jones 8P{XA Petroleum Inspector 8, J Pads 8-12, 8-1 8, J-11, J-1 5 MPU Milne Point Field NON- CONFIDENTIAL 4 P 4 P 4 P 4 P Type Test Interval M= Annulus Monitoring 1= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details January 8, 2004: I traveled to BPXA's Milne Point Field wells B-12, B-18, 1-11 and 1-15 to witness MITIs. Lee Hulme was the BPXA representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with each well passing the MIT. Four well houses were inspected with no exceptions noted. Summary: I witnessed successful MITIs on BPXA's Milne Point Field wells B-12, B-18, 1-11 and 1-15. Four well house inspections conducted, no exceptions noted. M.I.T.'s performed: ! Number of Failures: Q Total Time during tests: 6 hrs Attachments: cc: c..;¡,rr' Ii" ¡",Ii!¡,\utC:k- J; f\ 11\\1 9~ c\ '~f\~, ",J;'\¡ß¿rM'\JÜ~~i.c... "ß-tj ~ &., 'di ~JJlH MIT report form 5/12/00 L.G. MIT MPU 8-12, 8-18, J-11, J-151-8-04 JJ.xls 1/1Sf2004 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test :Je,€- 111/ò4 Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration - Alaska Milne Point Unit / B-pad & J-pad 01/08/04 Packer Depth Pretest Initial 15 Min. 30 Min. Well B-12 Type Inj. P TVD 6,998' Tubing 2,140 2,140 2,140 2,140 Interval 09:38 P.T.D. 1850800 Type test P Test psi 1,750 Casing 550 1,800 1,760 1,750 P/F Pass Notes: 1 bblsdiesel to 1800 OA 650 750 750 750 Bled back to 500 Well B-18 Type Inj. P TVD 6,854' Tubing 2,550 2,550 2,550 2,550 Interval 10:40 P.T.D. 1852290 Type test P Test psi 1,714 Casing 500 2,200 2,180 2,170 P/F Pass Notes: 2 bbls diesel to 2200 OA 300 480 480 480 Bled back to 500 Well J-11 Type Ini. P TVD 3,913' Tubing 1,920 1,920 1,920 1,920 Interval 13:45 P.T.D. 1941140 Type test P Test psi 1,500 Casing 740 2,600 2,550 2,550 P/F Pass Notes: 1.2 bbls diesel to 2600 OA 650 750 750 750 Bled back to 500 Well J-15 Type Inj. P TVD 3,839' Tubing 1,180 1,180 1,180 1,180 Interval 12:45 P.T.D. 1991070 Type test P Test psi 1,500 Casing 500 2,025 1,980 1,950 P/F Pass Notes: .7 bbls diesel to 2025 OA 650 750 750 750 Bled back to 500 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) ~~E[). JAN 1 41 2004 MIT Report Form Revised: 06/19/02 2004-01 08_MIT _MPU_J-15.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ CHG INJ STATUS F/WAG to H20 Pull tubing_ Alter casing_ Repair well_ Other_X CHG Inject Status 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2650' FNL, 3366' FEL, Sec. 28, T13N, R10E, UM At top of productive interval 2344' FNL, 3738' FEL, Sec. 21, T13N, R10E, UM At effective depth 2276' FNL, 3693' FEL, Sec. 21, T13N, R10E, UM At total depth 2119' FNL, 3718' FEL, Sec. 21, T13N, R10E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 551951, 6015027) (asp's 551526, 6020609) (asp's 551570, 6020678) (asp's 551544, 6020834) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Milne Point Unit 8. Well number MPJ-11 9. Permit number / approval number 194-114 10. APl number 50-029-22502-00 11. Field / Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2571' Production 9819' 9849 feet Plugs (measured) 7414 feet 9433 feet Junk (measured) 7029 feet Tagged TD @ 9433' (05/28/2002) Size Cemented Measured Depth 13-3/8" 250 sx Arcticset I (Approx 112' 9-5/8" 551 sx PF 'E', 250 sx 2782' Class 'G' 7" 470 sx Class 'G' 9849' True Vertical Depth 112' 2476' 7414' Perforation depth: measured Kuparuk Open Perfs below tubing tail 9330'-9360', 9426'-9490' Schrader Perfs behind closed dummied off GLMs 5310'-5350' true vertical Kuparuk Perfs 6935' - 6962', 7023' - 7082' Schrader Perfs 4057' - 4083' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 to 9221'. Packers & SSSV (type & measured depth) 7" x 3-1/2" HES TNT Packer @ 5053', 7" x 3-1/2" Baker S-3 Packer @ 9189'. No SSSV in well. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 02/08/2001 Subsequent to operation 06/18/2002 15. Attachments I I Copies of Logs and Surveys run __ Daily Report of Well Operations __ --. ....... ._Oil __ Gas __ 17.1 hereby certify that the fore~goi)~ is~rue a~ (~erl~Ct~t,e ~q~j~e~ (:~y knowledge. ~,- u.,,,.-,-- -',7/' "'- "' ~ v Title: Technical Assistant eWayneR. Schnorr JUN 2 4 2002 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 1618 2314 Casing Pressure Tubing Pressure 1394 2228 16. Status of well classification as: Suspended __ Service WATER INJECTOR Date June 20, 2002 Prepared b]/DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 Alaska 0il & Gas Cons, Anchorage SUBMIT IN DUPLICATE MPJ-11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/01/2001 SLICKLINE: ISOLATE SCHRADER, AND OPEN KUPARUK FOR INJECTION. 02/03/2001 SLICKLINE: PULL PLUG, SBHP SURVEY. 05/28/2002 SLICKLINE' DRIFT AND TAG EVENT SUMMARY 02/01/2001 PULL CV's, SET DGLV IN BOTH MANDRELS AT 5156' AND 5218'. PRESSURE TESTED TUBING TO 1000 PSI. 02/03/2001 PULLED XXN PLUG @ 9181'. PERFORMED SBHP SURVEY WITH BHP OF 2076 PSI @ ~ 7008' TVD. APPROXIMATELY 25' (DEPTH 9465') OF LOWER PERFORATED INTERVAL IS COVERED WITH FILL. O5/28/O2 RIG HES UP. RIH WITH 2.6" SWAGE, 2'x 1.875", TEL, 2.70" GAUGE RING TO TTL @ 9202' WLM (9217' ELMD) 15' CORRECTION. TAG TD AT 9418' WLM (9433' MD). RDMO.) 57' OF BOTTOM PERF INTERVAL COVERED WITH FILL. FLUIDS PUMPED BBLS 0 NO FLUIDS PUMPED. 0 TOTAL Page I SCANNED JUL ! 0 2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: CHG INJ F/Schrader to Kup 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2650' FNL, 3366' FEL, Sec. 28, T13N, R10E, UM At top of productive interval 2344' FNL, 3738' FEL, Sec. 21, T13N, R10E, UM At effective depth 2150' FNL, 3713' FEL, Sec. 21, T13N, R10E, UM At total depth 2119' FNL, 3718' FEL, Sec. 21, T13N, R10E, UM 12. Present well condition summary Total depth: Operation shutdown_ Pull tubing _ Stimulate _ Plugging _ Perforate _ Alter casing _ Repair well _ Other _X Inject into Kuparuk , 5. Type of Well' 6. Datum elevation (DF or KB feet) Development__ RKB 65 feet Exploratow__ 7, Unit or Pr(~perty name ' Stratigraphic__ Service X (asp's 551951, 6015027) (asp's 551526, 6020609) (asp's 551549, 6020803) (asp's 551544, 6020834) measured true vertical 9849 feet 7414 feet Plugs (measured) Milne Point Unit 8. Well number MPJ-11 9. Permit number / approval number 194-114 10. APl number 50-029-22502-00 11. Field / Pool Milne Point Unit / K.uparuk River Sands Effective depth: measured 9764 feet true vertical 7335 feet Junk (measured) Casing Length Size Conductor 80' 13-3/8" Surface 2571' 9-5/8" Production 9819' 7" Cemented Measured Depth True Vertical Depth 250 sx Arcticset I (Apprm< 112' 112' 551 sx PF 'E', 250 sx 2782' 2476' Class 'G' 470 sx Class 'G' 9849' 7414' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) No SSSV in well. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. measured Kuparuk Open Perfs below tubing tail 9330'-9360', 9426'-9490' RE6E~VED Schrader Perfs behind closed dummied off GLMs 5310'-5350' true vertical Kuparuk Perfs 6935'- 6962', 7023' - 7082' Schrader Perfs 4057'-4083' :~t[..Ji~,,! !~l ~ 7" x 3-1/2" HES TNT Packer @ 5053°, 7" x 3-1/2" Baker S-3 Packer @ 9189'. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 2756 1254 16. Status of well classification as: Suspended~ Service WAG Injector Prior to well operation 01/30/2001 Subsequent to operation 02/20/2001 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations __ Oil__ Gas__ 17. I hereby certify that the foregoing is_ true and correct to the best of my knowledge. .~~~~.,/~~~. V~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Tubing Pressure 1748 1513 Date May 07, 2002 Prepared by DeWayne R. Schnorr 564-5174 $C N ED JUN 4 2002 SUBMIT IN DUPLICATE MPJ-11 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/01/2001 SLICKLINE: ISOLATE SCHRADER, AND OPEN KUPARUK FOR INJECTION. 02/02/2001 SLICKLINE: BAIL, PULL PLUG. 02/03/2001 SLICKLINE: PULL PLUG, SBHP SURVEY. 02/03/2001 VALVE REMOVAL: REMOVE HYD. ACTUATOR FROM FLOW CROSS & INSTALL BLIND FLANG. 10/06/2001 CHANGEOUT CHOKE: 03/29/2002 FREEZE PROTECT: BOOSTER PUMP INSTALLATION. EVENT SUMMARY 02/01/01 PULL CV's, SET DGLV IN BOTH MANDRELS AT 5156' AND 5218'. PRESSURE TESTED TUBING TO 1000 PSI. COULD NOT EQUALIZE PLUG DUE TO FILL IN TUBING. RETURN IN A.M. TO BAIL TO PLUG. 02/02/01 BALLED TO PLUG. ATTEMPTED TO PULL PLUG TWICE, SHEARED OFF BOTH TIMES. LAY DOWN TOOLS AND LET WELL EQUALIZE OVERNIGHT. 02/03/01 PULLED XXN PLUG @ 9181'. PERFORMED SBHP SURVEY WITH BHP OF 2076 PSI @ - 7008' TVD. APPROXIMATELY 25' (DEPTH 9465') OF LOWER PERFORATED INTERVAL IS COVERED WITH FILL. ASSISTED SUPPORT TECHS PULL ACTUATOR. 02/03/01 REMOVED ACTUATED VALVE FROM WELL MPJ-11 FLOW CROSS (VALVE WAS USED FOR MPJ-23 POWER FLUID), AND INSTALLED BLIND FLANG, TORQUED TO 480 FP AND PT'd TO 5000 LB. PUT BACK ON INJECTION. 10/06/01 WELL SUPPORT RIGGED UP AND CHANGED OUT THE CHOKE. ALL FLANGES WERE TORQUE TO SPEC. JOB COMPLETED WITH NO PR©BLEMS. O3/29/O2 FREEZE PROTECT WELL FOR BOOSTER PUMP INSTALLATION. WELL WILL HAVE HIGH PRESSURE SPOOL INSTALLED. PUMPED 22 BBLS METHANOL DOWN TUBING. WELL IS FREEZE PROTECTED. FLUIDS PUMPED BBLS 29 METHANOL 29 TOTAL Page I JUN 2002 r.---. STATE OF ALASKA --~ ALASK;...,IL AND GAS CONSERVATION C~,MMISSION REPORT OF SUNDRY WELL OPERATIONS ~1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Operation Shutdown [] Stimulate [] Plugging [] Pull Tubing []Alter Casing [] Repair Well []Other 5. Type ioJ] well: Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 2630' NSL, 1914' EWL, Sec. 28, T13N, R10E, UM At top of productive interval 2935' NSL, 1541' EWL, Sec. 21, T13N, R10E, UM At effective depth 3129' NSL, 1566' EWL, Sec. 21, T13N, R10E, UM At total depth 3157' NSL, 1561' EWL, Sec. 21, T13N, R10E, UM [] Perforate Convert to Injector 6. Datum Elevation (DF or KB) KBE = 65' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-11 9. Permit Number / Approval No. 94-114/399-198 399-198/399-214 10. APl Number 50- 029-22502 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 9849 feet true vertical 7414 feet Effective depth: measured 9764 feet true vertical 7335 feet Casing Length Size Structural Conductor ,.9.oot~' !,,l.~5870'1' Surface lq ~.c.¢,¢/ Intermediate ,~u ' Production f~-¢l~ ~ 7" Liner /;~ Plugs (measured) Junk (measured) Cemented 13 3/8" 250 sx Arcticset (approx) 9 5/8" 551 sx PF 'E', 250 sx Class 'G' 470 sx Class 'G' MD TVD 112' 112' 2782' 2476' 9849' 7414' RECEIVED Perforation depth: measured true vertical Schrader: 5310'-5350' Kuparuk: 9330'-9360', 9426'-9490' Schrader: 4057'-4083' Kuparuk: 6935'-6962', 7023'-7082' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 to 9221' OCI'2 o, !999 & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 7" HES TNT packer at 5053'; 7" Baker 'S-3' packer at 9189' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water & Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Terrie Hubb~e . Title Technical Assistant III Prepared By Name/Number: Date I~)"O~-,?-~ .;',~ Terrie Hubble, 564-4628 ~.'~ Submit In DuPli~ Form 10-404 Rev. 06/15/88 Facility Date/Time 19 Oct 99 20 Oct 99 21 Oct 99 M Pt J Pad Progress Report Well MPJ-11 Page 1 Rig Nabors 4ES Date 27 October 99 18:00-03:00 18:00-03:00 03:00 03:00-06:00 03:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-11:00 08:00-11:00 11:00 11:00-12:30 11:00-12:30 12:30 12:30-14:00 12:30-14:00 14:00 14:00-16:00 14:00-16:00 16:00 16:00-16:30 16:00-16:30 16:30 16:30-18:00 16:30-18:00 18:00 18:00-01:00 18:00-21:00 21:00 21:00-01:00 01:00 01:00-06:00 01:00-06:00 06:00 06:00-12:00 Duration 9hr 9hr 3hr 3hr 2hr 2hr 3hr 3hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 2hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 7hr 3hr 4hr 5hr 5hr 6hr Activity Move rig Rig moved 100.00 % Move Rig from MPF-38 to MP J-11 & rig up & safe out equipment. At well location - Slot rig accepted @ 0300 hrs. 10/20/99 Wellhead work Removed Hanger plug Rig lines to tree & set tiger tank & take on seaH20 7 rig lubricator & pull bpv. Stopped: To hold safety meeting Wellhead work (cont...) Rigged up Well control test lines to tree to 3000 psi. & open well & sitp=1200 psi. sicp=1100 psi. Equipment work completed Well control Circulated closed in well at 9212.0 ft displace well bore with 8.5 ppg. seah20 & could not get complete circ. well bore free of influx & set twc & test to 2500 psi. Influx Out of hole Wellhead work Removed Xmas tree Equipment work completed Nipple up BOP stack Rigged up BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi test witnessed by john spaulding with aogc. Wellhead work Removed Hanger plug Equipment work completed Wellhead work Removed Tubing hanger Equipment work completed Fluid system Circulated at 9213.0 ft attempt to fill hole from surface (No good.) wait on lcm & Stopped: Spot sample Circulated at 9214.0 ft Mix 25 bbl. kuparuk pill & pump out tbg. & fill back side with 100 bbl. plus seah20 & did not see fluid. Mix and spot another 25 bbl. of kuparuk pill & got returns as pill was being put into place. & monitor well taking 12-bbl. hr. LCM spotted downhole Pull Single completion, 2-7/8in O.D. Laid down 6300.0 ft of Tubing Stopped: To hold safety meeting Pull Single completion, 2-7/8in O.D. (cont...) Facility Date/Time 22 Oct 99 M Pt J Pad 06:00-12:00 Progress Report Well MPJ-11 Page 2 Rig Nabors 4ES Date 27 October 99 12:00 12:00-14:00 12:00-14:00 14:00 14:00-03:00 14:00-18:30 18:30 18:30-00:30 00:30 00:30-03:00 03:00 03:00-04:00 03:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00 06:00-14:00 06:00-14:00 14:00 14:00-15:00 14:00-15:00 15:00 15:00-16:00 15:00-16:00 16:00 16:00-17:30 16:00-17:30 17:30 17:30-22:00 17:30-22:00 22:00 22:00-00:00 22:00-00:00 23 Oct 99 00:00 00:00-03:00 Duration 6hr 2hr 2hr 13hr 4-1/2 hr 6hr 2-1/2 hr lhr lhr 2hr 2hr 8hr 8hr lhr lhr lhr lhr 1-1/2 hr 1-1/2 hr 4-1/2 hr 4-1/2 hr 2hr 2hr 3hr Activity Laid down 9225.0 ft of Tubing LAY DN TBG & ESP EQUIPMENT. Completed operations Well control Worked on BOP - Lubricator NIPPLE DN BELL NIPPLE & NIPPLE UP SHOOTING FLG. Completed operations Electric wireline work Conducted electric cable operations TOP OF CMT. EVALUATED BY GRAHAM STUART APP. 3900-+ Completed logging run with Cement bond log from 9350.0 ft to 1500 Perforated from 5310.0 ft to 5350.0 ft Make two runs with sws.(seen no change in fluid level. Interval perforated Conducted electric cable operations Completed run with Junk basket/gauge ring from 0.0 ft to 9390.0 ft Well control Worked on BOP - Lubricator rig dn lub & nu bell nipple Equipment work completed Pull Single completion, 3-1/2in O.D. Ran Tubing to 1200.0 ft (3-1/2in OD) Pick up baker "s-3" & inspect. Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. Ran Tubing to 9220.0 ft (3-1/2in OD) install hanger. & land. Hanger landed Wellhead work Installed Hanger plug set twc & test to 2500 psi. Equipment work completed Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Rigged up Xmas tree install tree & test to 5000 psi. Equipment work completed Fluid system Freeze protect well - 75.000 bbl of Diesel rig lines & test to 5000 psi. & pump 200 bbl. seah20 treated with nalco@ 25-gal. per 100 bbl. & follow with 75-bbl. diesel taking returns at tbg. & U-tube same for freeze protection. Completed operations Pull Single completion, 3-1/2in O.D. Serviced Permanent packer drop ball & rod & attempt to set packer ball would not seat. Setting tools failed - Change operation Slickline wireline work Oft Facility Date/Time Progress Report M Pt J Pad Well MPJ-I 1 Page 3 Rig Nabors 4ES Date 27 October 99 00:00-03:00 03:00 03:00-05:00 03:00-05:00 05:00 05:00~06:00 05:00~06:00 06:00 Duration 3hr 2hr 2hr lhr lhr Activity Conducted slickline operations on Slickline equipment - Tool run ran in hole with 2.75" impression block & found ball & rod in top glm & knock out & chase to rhc plug & set & test to 500 psi. to verify on position. pooh & rig dn wire line. Completed run with Setting tools from 0.0 ft to 9189.0 ft Test well control equipment Monitor pressures Pressure tbg. to 5000 psi. in increments & monitor for 30 minutes test good. & change to annulus & pressure to 3500 psil & monitor for 30-min. good test. pkr's set. test waived by Larry Wade with AOGC. Resumed operations Wellhead work . Installed Hanger plug install bpv & secure tree. Rig Released @ 0600 hrs. 10/23/99 . Equipment work completed ---.. STATE OF ALASKA -'--. ALASKA, .,iL AND GAS CONSERVATION C,,..,MISSION APPLICATION FOR SUNDRY APPROVAL REVISED: 10122/99 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to Injector 2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I [] Development KBE = 65' [] Exploratory 7. Unit or Property Name 3. Address []Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 2630' NSL, 1914' EWL, Sec. 28, T13N, R10E, UM At top of productive interval 2935' NSL, 1541' EWL, Sec. 21, T13N, R10E, UM At effective depth 2926' NSL, 1512' EWL, Sec. 21, T13N, R10E, UM At total depth 3157' NSL, 1506' EWL, Sec. 21, T13N, R10E, UM 8. Well Number MPJ-11 9. Permit Number 94-114 / 399-198 10. APl Number 50- 029-22502 1. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 9849 feet true vertical 7427 feet Effective depth: measured 9764 feet true vertical 7335 feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Size Structural Conductor 80' 13 3/8" Surface 2571' 9 5/8" Intermediate Production ~ 7" Liner q~% Cemented MD TVD 250 sx Arcticset (approx) 112' 112' 551 sx PF 'E', 250 sx Class 'G' 2782' 2476' 470 sx Class 'G' 9849' 7427' Perforation depth: measured 9330'-9360', 9420'-9490' true vertical 6935'-6962', 7017'-7082' Tubing (size, grade, and measured depth) (Pulled) Packers and SSSV (type and measured depth) None RECEIVED OCT 2 2 i999 Alaska 011 & Ga Conm. c~ml~lon Anchorage 13. Attachments [] Description summary of proposal ~] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: October 21, 1999 16. If proposal was verbally approved [] Oil [] Gas I-1 Suspended Blair Wondzell 10/20/99 Service Name of approver Date approved Contact Engineer Name/Number: Robert Laule, 564-5195 Michael Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~./~ Robert Laule Title Operations Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test Subseo, Jjo~form required 10- _ ~oqe6 Approved by order of the Commiss'~J;~lGINAL SIGNED ~¥ v,~' ,,'1 .., ~1..,>~ Commissioner Form 10-403 Rev. 06/15/88 Hobert N. Chdstenson J,Appr°va' N°' '~ '"' ~ l¢ J I Date/'i~ "'~ Submit In Triplicate k. are, d rwces rilling To: Blair Wondzell - AOGCC From: Bob Laule Subject: Date: Reference: MPJ~ll Application for Sundry Approval- REVISED Re-Completion Operations 22 October 1999 API #50-029-22502 Milne Point Well J-11 was drilled in September 1994 by Nabors 22E. The well was frac'd and a screen assembly and LLCV were hung on a packer above the perfs. A coiled tubing ESP completion was installed in November 1994. The ESP failled in 1996 and a RWO was performed in September 1996 to pull the CT completion, remove the packer assembly, and run a new ESP on jointed pipe. The current ESP failed on July 29, 1999. Due to the wells location, conversion to an injector for support of MPJ-06 has become a better option than pursuing restoration as a producer. The MPJ-11 conversion began on October 20, 1999. This memo and 10-403 are requesting a change to the completion program to perforate the Schrader 'OA' sands and for a straddle packer completion. Pre Rig Work: 1) Obtain pressure survey. 2) Dummy off upper GLM. 3) Punch circulation holes in tubing above ESP. 4) Set BPV. Rig Operations: 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) 14) MIRU. Pull BPV. Circulate well. Set TWC ND tree NU and test BOP. Pull existing completion. Run Bond log. Perforate the Schrader Bluff 5310-5350' (Contingent on Bond log results) Make GR/JB mn to below packer setting depth. Run 3-1/2" tubing with Straddle completion with 2 GLM Packers at 5100 and 9200'. Set TWC, ND BOP, NU and test tree, Pull TWC. Freeze protect well and set packer. Test packer. Packer test to be witnessed by AOGCC. Bullhead tubing freeze protection and set TWC. Rig down and move off. i TREE: 3-1/8" 5000psi "~'= .a ,a ~',~ m ,J KB F'-~';on = 65.2 FT WELLHEAD: 7-1/16"/5000 ps. 11" WKM THRU-BORE [OLD CONOCO STYLE] CONDUCTOR ~ :~ ~, 'X' Nipple 9-5/8", 40#/ft, L-80, Btrs I 2781' ~ii~ I -2200' I 3.5", 9.3 ppf, L-80 ~UE Mod. tubing I:: ' Baker $-3 ~acker .-5.~100.~' M__~.D_ ~ I~ ~O--~ppe~s 5310T-5--~0';'-~md,-- ~i i ~ Deplhs,rom Sept 8-14, '~4 open ~ i~ lithologv, 0epths will be different. Mid Kuparuk per[ = 7010' tv0~:..~ :': 1 9410' MD WLEG IBc.om at-9225 PERFORATING SUMMARY: NOTE: Allow 75 between Ref. Log: AWL GR-CCL OF 09-30-94 !~ WLEG and top per[ co SIZE SPF INTERVAL STATU~c Propose~ 5310 - 5350 ~ Exsisting Kuparuk B perfs Exsistina Atlas 3-3/8 6 9330-9360 Open Atlas 3-3/8 6 9420-9490 Open Exsisting Kuparuk A per[s 7332' TVD PBTD I 9759' I Date By Comments MILNE ~OINT Will. l.: 11/0~/94 RRW 3OIL fiS~ GOMPLI=TION 09/06/96 M. Cinder ES~ Replacement CO'PI-ETlON DIAGRAM 8/26/99 TC Proposed Conversion 10/21/99 TC Revsion of Proposed conver. B.P. EXPLORATION (ALASKA) INC, -~-- STATE OF ALASKA .... ALASK,, ,~IL AND GAS CONSERVATION CL,,v, MISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well ~Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change to Injector 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [] Development [--I Exploratory [] Stratigraphic []Service 4. Location of well at surface 2630' NSL, 1914' EWL, Sec. 28, T13N, R10E, UM At top of productive interval 2935' NSL, 1541' EVVL, Sec. 21, T13N, R10E, UM At effective depth 2926' NSL, 1512' EVVL, Sec. 21, T13N, R10E, UM At total depth 3157' NSL, 1506' EVVL, Sec. 21, T13N, R10E, UM 6. Datum Elevation (DF or KB) KBE = 65' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-11 9. Permit Number 94-114 10. APl Number 50-029-22502 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 9849 feet true vertical 7427 feet Effective depth: measured 9764 feet true vertical 7335 feet Casing Length Size Structural Conductor 80' 13 3/8" Surface 2571' 9 5/8" Intermediate Production 12824' 7" Liner Plugs (measured) Junk (measured) Cemented MD TVD 250 sx Arcticset (approx) 112' 112' 551 sx PF 'E', 250 sx Class 'G' 2782' 2476' 470 sx Class 'G' 9849' 7427' Perforation depth: measured 9330'-9360', 9420'-9490' true vertical 6935'-6962', 7017'-7082' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9213' Packers and SSSV (type and measured depth) None 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation October 15, 1999 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [--) Gas [] Suspended Service Name of approver Date approved Contact Engineer Name/Number: Robert Laule, 564-5195 Michael Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Robert Laule Title Operations Drilling Engineer Commission Use Only Conditions of A?ol~roval: Notify Commission so representative may witness I Approval No. j~.. ,~.~. Oo.. Plug integrity BOP Test '~ Location clearance ~%~O~. Mechan,cal Integr,ty Test ~ Subsequent form required 10- ~~ ORIGINAL SIGNED'BY I~ /~ A~ed by o~er of the Commission Rnh.. N Ohd,te,so, Commissioner Date ~U-[~ Form 10-403 Rev. 06/15/88 Submit In Triplicate red rvices rilling To: Blair Wondzell - AOGCC From: Michael Triolo Subject: MPJ-11 Application for sundry permit - recompletion operations Date: 5 October 1999 Reference: API #50-029-22502 Milne Point Well J-11 was drilled in September 1994 by Nabors 22E. The well was frac'd and a screen assembly and LLCV were hung on a packer above the perfs. A coiled tubing ESP completion was installed in November 1994. The ESP failled in 1996 and a RWO was performed in September 1996 to pull the CT completion, remove the packer assembly, and run a new ESP on jointed pipe. The current ESP failed on July 29, 1999. Due to the wells location, conversion to an injector for support of MPJ-06 has become a better option than pursuing restoration as a producer. The MPJ-11 conversion is currently scheduled for Nabors 4ES following the MPE-09 ESP pump change out. The rig is expected to finish operations on MPE-09 on the 15s' of October. The pre- rig work for the MPJ-11 conversion is planned to begin soon pending Sundry approval. Pre Rig Work: 1) Obtain pressure survey. 2) Dummy off upper GLM. 3) Punch circulation holes in tubing above ESP 4) Set BPV. Rig Operations: 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11) 12) 13) MIRU. Pull BPV. Circulate well. Set TWC ND tree NU and test BOP. Pull existing completion. Run Bond log. Make GR/JB run to below packer setting depth. Run 3-1/2" premium tubing and permanent packer completion. Set TWC,ND BOP ,NU and test tree, Pull TWC. Freeze protect well and set packer. Test packer. Packer test to be witnessed by AOGCC. Bullhead tubing freeze protection and set TWC. Rig down and move off. TREE: 2-9/16" / 5000 psi / (SSV ACTUATOR) WELLHEAD: 7-1/16" / 5000 psi FMC ADAPTOR, J-11 Current KB Elevation =65.2FT GL Elevation = 35 FT 11" WKM THRU-BORE IO,D CONOCO S~YLEI CONDUCTOR Camco 2 7/8'x 1' 9-5/8% 40#/ft, L-80, Btrs ~ J ~. sidepocket KBUG GLM Csg 2-7/8", 6.5#, L-80, EUE 8 rd tubing. Capacity bbls/ft: 0.00579 Tubing drift: 2.441" Max devation: 53" KOP: 500' Centrilift GC 1200 ESP, 9164' i series 513, GPMTARC, 6787' tvd · Mid-perf = 7010' tvd 9410' MD 9213' PERFORATING SUMMARY: Ref. Log: AWL GR-CCL OF 09-30-94 CO SIZE SPF INTERVAL STATU~ Atlas 3-3/8 6 9330-9360 Open Atlas 3-3/8 6 9420-9490 Open -- -- 7332' TVD ---- PDTD 19759'1 ::::::::::::::::::::::::::::::: · :-:-:,:-:-:.:-:-:-:-:-: :-: :-: :.:-:.:-: .-:.:..:.:: :-.-: Date By Comments MILNE POINT WELL: J-11 11/03/94 RRW .COIL ESP COMPLETION 09/06/96 M. LinderESP Replacement B.P. EXPLORATION (ALASKA)INC. TREE: 3-1/8" 5000psi KB Elevation = 65.2 FT WELLHEAD: 7-1/16' / 5000 psi FMC ADAPTOR J-11 Proposed sLE,evat,o. =35~ [OLD CONOCO STYLE] 13 3/8" I 116' I ~' 3.5", 9.3 ppf, L-80 EUE Mod. tubing ',~! ~i I I Mid-perf = 7010' tvd 9410' MD WLEG I Bottom at -9225 PERFORATING SUMMARY: NOTE: Allow 75' between Ref. Log: AWL GR-CCL OF 09-30-94 WLEG and top perf CO SIZE SPF NTERVAL STATUS Atlas 3-3/8 6 9330-9360 Open Atlas 3-3/8 6 9420-9490 Open .,, 7332' TVD PBTD ~ 9759' ~ 7", 26#/ft, L-80 NSCC ~ 9849' ~ Date By Comments MIl. NE POINT WELl..: J-11 11/03/94 RRW SOIL ESP COMPLETION 09/06/96 M. Linder ESP Replacement COMPLETION DIAGRAM 8/26/99 TC Proposed Conversion B,P, EXPLORATION (ALASKA) INC. " ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other ESP Completion/Retrieve LLC valve & pkr screen assembly 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2630' NSL, 1914' EWL, Sec. 28, T13N, R10E, UM At top of productive interval 2935' NSL, 1541' EWL, Sec. 21, T13N, R10E, UM At effective depth 2926' NSL, 1512' EWL, Sec. 21, T13N, R10E, UM At total depth 3157' NSL, 1506' EWL, Sec. 21, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE: 65' 7. Unit or Property Name Milne Point Unit 8. Well Number MPJ-11 9. Permit Number / Approval No. 94-114 10. APl Number 50- 029-22502 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 9849' feet true vertical 7427' feet Effective depth: measured 9764' feet true vertical 7335' feet Casing Structural Conductor Surface Intermediate Production Liner Length Size 80' 13 3/8" 2571' 9 5/8" 12824' 7" Plugs(measured) Junk(measured) Cemented MD TVD 250 sx Arcticset (approx) 112' 112' 551 sx PF 'E'/250 sx 'G' 2782' 2476' 470 sx Class 'G' 9849' 7427' Perforation depth: measured 9330'-9360', 9420'-9490' (open) true vertical 6935'-6962',7017'-7082'(open) Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9213' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. . 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~ ~/~ ~ Title Engineering Supervisor Date Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplicat.~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ARCO Well Name: MPJ-11 Rig Name: N-4ES AFE# 339007 Accept Date: 08/30/96 Spud Date: . Release Date: 09/04/96 AUGUST 31, 1996 RIG ACCEPTED @ 0700 HRS ON 8/30/96. CHECK CASING NO PRESSURE, PULL 11" FALSE BOWL & 6" BPV, SET TEST PLUG NU DSA & 13 5/8" 5000# BOP STACK. TEST BOPE: TEST ALL RAMS, LINES & VALVES TO 250 & 5000 PSI TEST HYDRILL TO 250 & 3000 PSI TEST KELLY UPPER & LOWER KELLY VALVE, TIW, IBOP TO 250 & 5000 PSI OK PULL TEST PLUG INSTALL WEAR BUSHING. MAKE BHA #1 TIH PICKING UP 3 ½" 15.5 DRILL PIPE SLIP & CUT DRILL LINE. CONTINUE TIH PICKING UP DRILL PIPE TAG LLC @ 9202' DPM LATCH LLCV ROTATE FREE. CIRCULATE OUT GAS ON OPEN CHOKE W/8.4 PPG SOURCE WATER. SEPTEMBER 01, 1996 CONTINUE CIRCULATE THU OPEN CHOKE - NO FLUID LOSS, MONITOR WELL. POOH W/LLCV LD VALVE & CAMCO RETRIEVING TOOL MU BHA #2 6 1/8 x 5 3A x 4 9/16" BURNING SHOE SERVICE RIG. TIH W/BURING SHOE ON BHA #2 TO 9194' REPAIR MUD PUMP - CHANGE #2 SWAB & LINER TAG PACKER @ 9206' BURN OVER PACKER 9206 TO 9209' PUSH DOWN TO 9225' CIRCULATE BU MONITOR WELL OK NO FLUID LOSS PUSH PACKER TO 9347' POOH LD BURINING SHOE PICK UP OVER SHOT W/4 5/8" GRAPPLE TIH W/BHA #3 TAG PACKER @ 9347' WASH OVER & LATCH FISH WORK FREE W/50K OVER PREPARE TO POOH @ 0600 HRS. ADDED ONE DRUM OF LUB-TEX TO FLUID AS LUBRICANT WHILE MILLING PACKER - DROP TORQUE 20K FT/#TO 10K FT/# P/U WT DROP 200 TO 140K, SO WT INCREASED 75K TO 90K. SEPTEMBER 02, 1996 SERVICE RIG POOH W/PACKER ASSEMBLY NO RECOVERY. KNOCK ICE OUT OF DERRICK MU BHA #4, SPEAR W/4" GRAPPLE TIH. SLIP 42' DRILL LINE. FINISH TIH W/SPEAR TAG FISH @ 9347' SPEAR & JAR FREE 60K OVER. POOH W/PACKER ASSEMBLY LD PACKER & 1 JT SCREEN ASSEMBLY AND WLEG MU BHA #5 BIT W/7" CASING SCRAPER SPACED OUT TO 9250' TIH TAG FILL 9359' WASH & REAM 9359' TO PBTD @ 9759' DPM CIRCULATE HI VIS SWEEP AROUND EVERY 100' CARBOLITE RETURNS W/SWEEPS, FLUID LOSS TO FORMATION 60 BBLS/HR @ TOP OF PERF SLOWED TO 6 BBLS/HR @ PBTD AT PBTD @ 0600 HRS. SEPTEMBER 03, 1996 CIRCULATE @ PBTD OF 9759' CARBOLITE FRAC SAND IN RETURNS CIRC UNTIL NO SAND IN RETURNS CIRCULATION SYSTEM VISCOLSIFY W/XANVIS FLUID LOSS 6 BBLS/HR. PUMP 20 BBL SAPCE FOLLOWED BY CLEAN SOURCE WATER, MONITOR WELL FLUID LOSS 33 BPH POOH LD DRILL PIPE TO 9300' - 30' ABOVE PERFORATIONS MIX & SPOT 20 BBLS XANVIS PILL FOR FLUID LOSS - MONITOR Page 1 of 2 SUMMARY OF DALLY OPERATIONS WELL FLUID LOSS 10 BBLS/HR POOH LD DRILL PIPE & BHA. FLUSH OUT BOP STACK PULL WEAR BRUSHING RIG UP TO RUN COMPLETION - MAKE UP & SERVICE ESP RUN 2 7/8" 6.5# L-80 EUE 8RD TUBING W/ESP CABLE 131 JTS IN HOLE @ 0600 HRS FLUID LOSS 40 BBLS/HR OF SOURCE WATER. SEPTEMBER 04, 1996 SERVICE RIG CONTINUE RIH W/ESP COMPLETION ON 2 7/8" TUBING CHANGE ESP CABLE SPOOLS - SPLICE ESP CABLE. CONTINUE RIH W/ESP COMPLETION RAN OUT OF ESP CABLE ON SPOOL #2 - SPOOL 500' SHORT- WAIT ON SPOOL #3 & SPLICE LINE FINISH RUNNING ESP - 289 JTS 2 7/8" 6.5# L-80 EUE TUBING & ONE GLM MU WKM 11x2 7/8" TUBING HANGER MAKE SPLICE @ HANGER LAND TUBING -SET TWC CHECK VALVE ND 13 5/8" BOP STACK FlU 11x2 9/16 5000# WKM TREE TEST TUBING HANGER & TREE TO 5000 PSI OK PULL TWC INSTALL BPV FREEZE PROTECT W/60 BBLS DIESEL DOWN ANNULUS BULLHEAD @ Y2 BBL/MIN 0 PSI 12 BBLS DIESEL DOWN TUBING 0 PSI. BLOW DOWN LINES SECURE WELL- RIG RELEASED @ 0400 HRS ON 09/04/96. Page 2 of 2 Lh ~. .~-~ Ar'e we i'i We i i ~ s C 0 H kl E i"! T S ---- AOGCC Ge'; DATA 6307 6322 DWOP SIIc'VE .~ f ,,~l! C D bi/.. CDN/DC TVD CE.; R / DC CDR/DC TVD r~. /C L. F'FC~/*GR/CCL /,'qR 'OOL. P F C/ .... /', F'FC/'GR/CCL C~.. 6000---9800 r.~?~ 500 '-- 7440 2800-" 9800 ~. 2420-"7440 9000 9762 ~-'rl/~ 9350 9600 9090 "' 929a- ~'L-'~, 9230-9500 D,3. k..e' i i/'05/96 R I..I N i.X:,/:', f !? .. R E: C V D d'¥'rch samp'ies we i i cor'ed'/ r' e ci LI '¥ r"e d ? y e s .4 .. ,.~ r' e <.-.; e ')' ',/e ,J v ~ .... ::, yes ~ys'¥s & descr,-;i'p'tz~'on J'"ece'i've,ci'i:' il(' ",/e S / "t e s-iz s 'i' in cs orr, p r'equi' r'-ed'?~!I~: i 'i' a n c e I n'~ -i' a ! ['"I 0 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 December 19, 1994 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN TVD for well MPJ-11 , Job # 9438~ was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 3 Bluelines 1 Film st .... 1 A~iska Oil & Gas Conservation Comm. 1 RFolded Se~ Att~.: Larry Grant '"'",,,-- 300~ine Drive Anchorage, Alaska -9_9501 OXY USA, lnc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 Blueline 1 RFolded Sepia Sent Certified Mail P 676 541 382 PLEASE A~ BP EXPLORATION (ALASKA) INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: ' AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA_PLUS Page: 1 Date' 11/28/94 RUN DATE_RECVD 94-114 6322 T 2728-9877 OH/CDN/CDR 94-114 6307 T 9000-9762 CH/GR/CCL 94-114 SURVEY R 112-9870 ANADRILL 94-114 DWOP R 09/07-10/31/94 94-114 407 R COMP DATE: 10/31/94 94-114 PFC/GR/CCL L 9090-9294 94-114 PFC/GR/CCL L 9230-9500 94-114 PFC/GR/CCL L 9350-9600 94-114 GR/CL/ L 9000-9762 94-114 CDR/DC L 2800-9800 94-114 CDN/DC L 6000-9800 Are dry ditch samples requiro~d~s Are well tests requir Well is in compliance ~ ~' Ini~cial COMMENTS I 11/10/94 1 10/31/94 11/16/94 11/16/94 11/16/94 1 11/03/94 1 11/03/94 1 10/12/94 1 10/12/94 COMP 11/10/94 COMP 11/10/94 no And received? Analysis & description received? no Received? yes no yes no yes no STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska)/nc. 94-114 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 ~. _ 5o- 029-22502 4. Location of well at surface ~ _.;~; .. ,.. ' 9. Unit or Lease Name 2630' NSL, 3366' WEL, SEC. 28, T13N, RIOE ~.~ ~~C'~,I MIIne Point Unit At Top Producing Interval 10. Well Number -' ~ . i ' ~ "':' 11. MPJ-11 Field and Pool At Total Depth ......... :'-;- -~ .*._.~.~.__~_~.~+~; Mi/ne Point Unit - Kuparuk Sands 3167' NSL, 3734' WEL, SEC. 21, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 65' I ADL 315848 'i2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Compleiions I 9/6/94 9/13/94 10731/94 N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD] 19. Directional Survey 120. Depth where SSSV set 12.1. Thickness of Permafrost 9870' MD/7433' TVD 9764' MD/7335' TVD YES [] N:) [] ! LLC ~ 9203' feet MD ! 1800' (Approx.,) 22. Type Electric or Other Logs Run GR/CDR/CDN 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WI'. PER k-r. GRADE. TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# i(-55 32' 112' 24" 250 SX Arcticset (Approx.). 9-5/8" 36# K-55 31' 2782' 12-1/4" 551 sx PF "E"/'250 sx "G" 7" 26~ L-80 29' 9849' 8-1/2" 4'/'0 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD/ Gun Diameter 3-3/8" 6 spf 2-1/8", HS-7OCM 9050' 9208' MD TVD 9330'-9360' 6935'-6962' w~ ESP 9420'-9490' 7017'-7081' 26. ACID, FRACTURE, CEMENT,SQUFF'"/F~ ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,,, 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 11/10/94 .... - - I ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL ,~AS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE - 128. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ol oil, gas or water. Submit core chips. p, ECE VED Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLCX~ 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. Subsea Kuparuk C Sand 9267' 6812' Top A Sand 9418' 6950' Base A Sand 9545' 7067' - 31, LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~'~~ TitleDri//inaErl_oineerSu_~ervisor Date.. ////I~/ 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 O~peration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 MP J-11 09/07/94 1,370' MOVE RIG FROM J-10 TO J-11. SPOT COMPLEXES. R/U WATER, AIR AND ELECTRIC BERM AROUND SUB AND CUTTINGS TANK. SPOT DIESEL TANK. NU 20" DIVERTER AND MIX SPUD MUD. PU AND STRAP BHA. FUNCTION TEST DIVERTER/ SPUD @105' AND DRILL TO 1370'. ACCEPTED RIG @1400 HR'S ON 09/06/94. 09/08/94 2,797' DRLG 12 1/4" HOLE AND MWD SURVEY F/1369-2033'. CBU. 14 STD SHORT TRIP. NO PROBLEMS. DRLG 12 1/4" HOLE AND MWD SURVEY F/ 2033-2763'. CIRCULATE SWEEPS. PUMP PILL. SHORT TRIP TO DC'S. SLM. NO CORRECTION. NO HOLE PROBLEMS. DRLG 12 1/4" HOLE F/ 2763-2797'. ClRC AND CONDITION MUD FOR CSG. PUMP PILL. DROP EMS. POH. LD BHA. RETRIEVE EMS SURVEYS WITHIN SPECS. RU TO RUN CSG. RIH W/9 5/8" CSG. MU LJ WASH 17' TO BOTTOM. LAND CASING @2781'. CIRCi1 1/2 ANNULAR VOLUMES AT 12 BPM W/NO FLUID LOSS. CEMENT 9 5/8" CSG. 09/09/94 3,851' LD CEMENT HEAD AND LJ. ND 20" DIVERTER SYSTEM. RU AND PERFORM 125 SK TOP JOB. RD CSG EQUIPMENT CHANGE BAILS. MU WKM SPEED HEAD W/BAKER LOK. TORQUE TO 13000 LBS. INSTALL DSA. NU BOP. TEST BOPE. INSTALL LONG WEAR BUSHING. BLOW DOWN LINES. SERVICE TOP DRIVE. VISUALLY INSPECT DERRICK LINES, PINS, SHEAVES AND WELDS. MU BIT AND BHA. PU 54 JTS 'E' DP. TAG UP AT 2694'. TEST 9 5/8" CSG. DRILL OUT CEMENT AND FLOAT EQUIPMENT AND 10' NEW HOLE TO 2807'. DRILL 8 1/2" HOLE AND MWD SURVEY F/ 2805-3851'. CIRC SWEEP. SHORT TRIP TO SHOE. NO PROBLEMS. 09/10/94 5,843' SHORT TRIP TO SHOE. TIGHT AT 3345'. REAM 90' TO BOTTOM. DRLG 8 1/2" HOLE AND MWD SURVEY F/3851-4889'. PUMP SWEEP AROUND. 16 STD SHORT TRIP. TIGHT AT 3911'. DRLG 8 1/2" HOLE AND MWD SURVEY F/4889-5843'. PUMP SWEEP AROUND. DROP EMS. POH, NO PROBLEMS. CHANGE BHA. SERVICE WEAR RING. ORIENT BHA. LOAD SOURCE INTO CDR COLLAR. RIH TO SHOE. TEST MWD. (SLM). SLIP AND CUT DRLG LINE. 09/11/94 6,732' SERVICE TOP DRIVE. HOSE IN DRAW WORKS LEAKING. REMOVE AND REPLACE. RIH. CHECK BENCH MARK. TIGHT @5120'. REAM LAST STAND TO BOTTOM. DRLG 8 1/2" HOLE AND MWD SURVEY F/5843-6510'. RES TOOL INTERMITTENT. PUMP SWEEPS. POH, NO PROBLEMS. DOWN LOAD CDN. CHANGE OUT CDR. CHANGE BEARING SECTION ON TURBINE. SERVICE WEAR RING. ORIENT BHA. LOAD SOURCE. RIH. SURFACE TEST MWD. CHECK BENCHMARK. RELOG F/6220-6510'. DRLG 8 1/2" HOLE AND MWD SURVEY F/6510-6732'. 09/12/94 8,600' DRLG 8 1/2" HOLE AND MWD SURVEY F1 6732-7581'. SHORT TRIP TO 6400'. NO PROBLEMS. DRLG 8 1/2" HOLE AND MWD SURVEY F/7581- 7974', NOTICED BAD SPOT IN DRLG LINE. CIRC SWEEP. POH TO SHOE. SLIP AND CUT 675' DRLG LINE. RIH. DRLG 8 1/2" HOLE AND MWD SURVEY F/7974-8600', . 09/13/94 9,800' DRLG 8 1/2"'HOLE AND MWD SURVEY F18600-9004'. SHORT TRIP TO 7900'. NO PROBLEMS. DRLG 8 1/2" HOLE AND MWD SURVEY F/9004- 9323'. CONTROL DRLG AT 60'/HR F/9323-9690'. DRLG F/9690-9800'. 09/14/94 9,870' DRLG F19800-9870'. CIRC LO-HI VIS SWEEP. POH TO HWDP. SLM. NO CORRECTION. NO HOLE PROBLEMS. SERVICE TOP DRIVE. RIH. NO PROBLEMS NO FILL. CIRC AND COND MUD FOR CSG. SPOT CONDITIONED PILL. PUMP PILL. POH W/50 STDS DP. POH LD DP. CHANGE RAMS TO 7". LD BHA. DOWN LOAD MWD TOOLS. CLEAR FLOOR. PULL WEAR BUSHING. INSTALL TEST PLUG AND TEST DOORS. CHANGE BAILS. RU CSG EQUIPMENT. RIH W/7" CSG. 09/15/94 9,870' RIH W/7" CSG SHOE. CBU AT 2 1/2 BPM. FINISH RIH W/CSG. NO HOLE PROBLEMS. MU HANGER AND LAND CSG. BREAK CIRC SLOW. CIRC AND CONDITION MUD. NO MUD LOSS. PUMP 20 BBL'S H20, 70 BBL'S SPACER, 222 S× CEMENT. DISPLACED W/RIG PUMPS. OPEN ES CEMENTER. CIRC AND CONDITION MUD. PUMP 75 BBL'S H20, 70 BBL'S SPACER, 250 SX CEMENT. DISPLACED W/RIG PUMPS. CLOSE ES CEMENTER. CHECK FLOATS, OK. MONITOR WELL LD LJ. CHANGE BAILS. CLEAR FLOOR. INSTALL PACK OFF AND TEST. CHANGE TOP DRIVE TO 3 1/2". CHANGE RAMS TO 3 1/2". TEST. INSTALL WEAR BUSHING. MU BHA. 09/1 6/94 9,870' FINISH RIH W/3 1/2" DP. TAG CEMENT AT 5705'. TESi' CSG. 'I~CEMENT AND ES CEMENTER AT 5739'. PU AND RIH W/3 1/2" DP TO LANDING COLLAR AT 9760'. BREAK CIRC. TEST CSG. REVERSE CIRC OUT MUD WI FILTERED SOURCE WATER. CONTINUE TO CIRC AND FILTER SOURCE WATER. BLOW DOWN LINES. POH LD DP TO 2000'. DISPLACE TOP 2000' HOLE W/DIESEL. POH. LD DP. LD BHA. CLEAR FLOOR. PULL WEAR BUSHING. PREP TO INSTALL FALSE BOWL. 09/17/94 9,870' CHANGE PIPE RAMS TO 5". ATTEMPT TO INSTALL FMC FALSE BOWL IN WKM HEAD. BOWL WILL NOT SEAT DEEP ENOUGH IN HEAD FOR LOCK DOWNS TO ENGAGE BOWL. CHECK SPECS ON BOWL- OK. SEND BOWL TO MACHINE SHOP. REMOVE .25" FROM JUNK RING. CHANGE TOP DRIVE TO 5". WAIT ON BOWL. FREEZE PROTECT ANNULUS. INSTALL BOWL W/ BPV AND ENGAGE LOCK DOWNS. ND BOP. INSTALL ADAPTER FLANGE AND 7" DRY HOLE TREE. TEST HANGER. PULL BPV. TEST 7" VALVE. INSTALL BPV AND TREE CAP. RELEASE RIG @1800 HR'S ON 09/16/94. TO: PHILLIPS FROM: MELVAN/HINKEL WELL: MPJ-11 MAIN CATAGORY: DRILLING SUB CATAGORY: FILL CLEAN OUT LOCATION' ANCHORAGE DATE' 10/19/94 OPERATION: POST FRAC CARBOLITE CLEAN OUT. Ii initial Well ! SIWHP I lAP I 0AP I GLP Status (psi) (psi) (psi-) (psi) NA I 0 NA NA I NA TIME I OPERATION 02:45 MIRU Nowcam unit 4905. Spot tanks and lay lines and hook up reverse manifold.. Thaw out inj head sump. 05.30 Make up 3.5" reverse nozzle. 05.45 Pressure test BOP, wellhead connection, and line to 4000 psi. Good test. 05.50 Wait on clean vac truck to arrive on location. (Peak drivers at a safety meeting/. 08.30 Peak truck arrives. Fill same from frac tank. , 09.45 Retrieve Meoh , 10.37 RIH. , ,, 1100 2184 0 0 0 30/85 Tag up already. Displace hole to sea wtr. 11.50 " 1.25 0 85 Begin reversing out bridge. 13.23 2541 " 1400 200 Looks like a gap now. Pick up speed. 14.43 3100 " 0 294 Lost pump. Air line to tractor tank plugged. Run line from power skid tank. Resume pumping. 15.41 3450 1.27 0 1850 357 In and out of bridges. 16.42 3800 1.28 In heavy sand. Decide to clean coil and fix air system 17.10 " 0 470 Shut dwn- fix air. 17.45 " 1.27 0 1450 Resume cleanout 20.10 5025 1.3 1150 682 Weight check, 7000 lbs. 21.01 5470 1300 752 Sand bridges.. 22.21 6000 865 SD to switch tanks. 23.56 6675 972 Sand bridges. 10/20/94 00.33 7025 1015 Weight check, 9000 lbs. 01:00 7060 1.2 1700 1035 Heavy cart) returns. 10.0 lb/gal. 06:00 8540 1.3 1425 9.2 lb/gal. 08.36 9185 1.28 09.41 9422 1.31 1250 1713 In perfs. Loosing 20% of returns. Slow pen. rate. 09.57 9454 1.32 1150 1731 Perfs uncovered. 21% Losses to perfs. 10.21 9500 1.32 " 1770 Stop digging. Short trip 100 ft 10.30 " 1.75 1000 Inc rate and continue reversing. 11.53 0 Returns clean. Shut in well to check pressure.Z- 12.17 440 WHP stabilized. Prep to Pooh. 12.26 " 1.75 POH reversing. ~ ¢~r~Ft~~ 13.19 4540 1.5 1973/0 Sw. to Meoh dwn, po',~. ~. m 1000 ft w/MEOH. 14.12 0 "/0 700 56 At surf. RD/~e~e~., .: r-'~ ",/~'J i.,... SENT VIA MAC MAIL PAGE -1- Final Well Status DATE WHP lAP 0AP GLP ! FLT (psi) (psi) (psi) (psi) I (o F) 10/20/94!440 I "^ ! 4oo ! "~ I , N^ . SUMMARY Retrieved Meoh and ran in w/rev nzl. Tagged solid carbolite bridge @ 2184 ft. Reversed out a servies of bridges down to 3800 ft where carbolite became more consistant. Cleaned out sand down to 9500 ft with reverse circulation. Short tripped 100 ft and reversed another 100 bbl. Shut dwn. Wellhead pressure dropped to 440 psi static. Pulled out while continuing to reverse. Frz protected top lO00 ft w/ Meoh. FLUIDS PUMPED B B L S. DESCRIPTION 2003 SEAWATER, FILTERED TO 3 MICRONS 30 MEOH 2033 TOTAL BOTTOM-HOLE ASSEMBLY #1 Tool String Descriptions I O.D. I i.D. ! Len~lth ! Comments FN 2.75 12" DUAL CHECKS 2.45 11" JET NZL 2.5 2" TOTAL 25" SENT VIA MAC MAIL PAGE -2- TO: PHILLIPS FROM: HINKEL/MELVAN WELL: MPJ-11 MAIN CATAGORY: DRILLING __ SUB CATAGORY: FILL CLEAN OUT LOCATION: ANCHORAGE DATE: 10/21/94 OPERATION: POST REFRAC CARBOLITE CLEAN OUT Initial Well Status SIWHP lAP 0AP GLP FLP FLT II 650 I NA I 175 ! .A I NA I NA ITM ! OPERATION I 21:45 MIRU Mowcam coil tubing uni~ 4905. (C'IV 33 bbls). Hook up lines and reverse manifold. Wait on Peak to move in tanks. (Wench truck got tied up on a rig project). 10/22/94 01.30 Spot tanks. 01.35 Pressure test BOP and wellhead connection to 4000 psi. Good test. 01.43 Recover m~thanol. 02.00 Open swab. 02.00 Surf 0 650 650 Start RIH with 3.4" nzl. 02.05 150 1.35 1150 500 1 Bring pump on line. Crack choke and maint WHP. 03.46 3000 1250 132 Continue circ out frac gel. 04.51 5050 220 Weight check, 8000 lbs. Cont in hole. 06.51 8600 385 SD pump. Weight check, 17,000 lbs. Continue in hole looking for TOS. 07.06 8725 Tag TOS. PUll up hole. 07.07 8660 1.28 0 800 387 Switch to reverse. Run back to TOS. 11.08 9432 1.5 0 1230 692 Loosing 20% returns. 11.1 6 9450 1.5 0 1060 706 Loosing 28% returns. 11.34 9490 " 0 990 731 Loosing 41% returns. 11.49 9525 " 0 1010 754 43% Losses. 12.55 9692 " 0 820 857 18% losses 13.09 9740 " 0 850 877 Call this TD. Circ coil clean. Prep to pump hi-vis pill. 13.13 " 885 Choke plugcjed. Work same. Pick up. Plugged again 13.30 9666 Plugged again. Lots of metal & trash. 13.41 " Give up reversing- Plugging surf. manifold. Switch to pump dwn coil. 13.57 " 1 560 935 La), metal back on btm. 14.45 9500 1.25/2 0 720 980/0 Switch to Xanvis sweep. Loosing 35% returns. 14.57 " 2.5 0 910 22/0 Inc rate for sweep. 15.41 9677 2.5 o 990 11 o Stop and wait for pill. 17.30 " " 1080 400 Start pullin~l out. 18.15 5000 2 3300 700 18.50 3000 2 3430 620 580/0 Swap to Meoh. 19.42 0 750 57 At surface. RD/Secure well. 21.00 0 Leave location. SENT VIA MAC MAIL PAGE -1- Final Well DATE WHP I lAP 0AP GLP J FLT Status (psi) I (psi) (psi) (psi) I (° F) I1 I 7so ! N^ I sso i N^ ! SUMMARY Run in hole with 3.4" reverse nozzle. Reverse sand from 8725 to 9740, loosing 43% of returns to the formation once the perfs were uncovered. Ran into drlg mud and metal pieces (per'[ debris) at about 9680 ft which plugged the surface eqpt. Reversed out some of the material then had to clear the coil back below 9680. Finished cleaning up the well down to 9690 with reverse circualation including a 22 bbl Xanvis pill with breaker. Did not see any additional sand or trash with the high vis sweep. Reversed back up to 5000 ft while pulling out, then circulated down the coil to frz protect coil and well, continuing to hold back pressure on the well. Well frz protected dwn to 1000 ft. FLUIDS PUMPED I' I B BLS. DESCRIPTION 1570 SEAWATER, FILTERED TO 3 MICRONS 22 XANVIS 57 Meoh 1 649 TOTAL BOTTOM-HOLE ASSEMBLY #1 Tool String] Descriptions ! O.D. I I.D. J Length I Comments FN 2.75 12" DUAL CHECKS 2.45 11" JET NZL 2.5 2" TOTAL 25" SENT VIA MAC MAIL PAGE -2- TO: FROM: WELL # PHILLIPS/HUTCHINS DAVE HILDRETH MPJ-11 LOCATION: DATE: OPERATIONS' ANCHORAGE, AK i_'.il~'., ~ ~ i i OCT 28, 1994 SETTING OF LLC-2 VALVE AND FLUID PACK WELLBORE. Initial Well Status FLWHP I lAP 0AP I GLP I FLP I FLT (psi) (psi) (psi) (psi) . (psi) (o F) ! soo I o I I i TIMEI OPERATION I 12:00 M! AND RU NOWCAM 4905. 14:00 INSTALLED CTC, DCV, DAILEY JARS AND HDC. 15:21 PRESSURE TESTED TO 3000 PSIG, OK 15:46 INSTALL 6" LUBRICATOR BELOW THE BOP'S, PU XO, 2-CENTRALIZER SUBS, LLC-2 VALVE 16:40 INSTALL'LUBRICATOR ON THE TREE 16:50 RU HARDLINE TO THE FRAC TANK. 17:21 PRESSURE TEST CT AND LUBRICATOR TO 4000 PSIG. OK BLEED PRESSURE DOWN TO 500 PSIG. 17:35 OPEN WELL SlWHP = 500 PSIG ( 29 TURNS) 18:50 WT CHECK AT 5000 FEET, 8500~i TIH 19:40 TIH O/VT DOWN 6500#) WT CHECK AT 9100' (16,500#) 19:41 TIH TO TAG 19:43 TAGGED PAOKRER TOP AT 9189' CTM SET 5000~ DOWN. 19:45 WORKING TO LATCH LLC-2 19:52 LATCHED IN TO PACKER, SET BACK DOWN AND COCKED JARS, JARRING AT 27000# TO RELEASE LLC- 2. TOOK3HIT TO SHEAR OUT. PUHTO9100' THE TOP OF THELLC-21SAT 9203 FEET 20:06 CONDUCT INFLOW TEST TO TANK. Pi = 500 psig AND IN 3 MIN THE WHP = 0 PSIG. CONDUCT INFLOW TEST. ""1 I pM I CTP IW VOL, I ~ REMARKS 20:52 9094 1.06 1270 0 START DISPLACING WELL BORE WITH 10.1 PPG NaCI COMPLETION FLUID. 21:01 9094 2.04 3600 90 16 PUMPING 10.1 PPG NACL 21:09 9094 2.20 3700 90 33 CT VOLUME DISPLACED. 21:36 9094 2.00 3080 80 90 POOH WHILE DISPLACING WELLBORE WITH NaCI PRODUCTION FLUID. 22:18 6994 2.01 3320 60 173 POOH DISPLACING SW. 23:41 3000 2.01 3670 60 325 POOH DISPLACING SW. 00:01 1669 2.00 3600 50 365 SWITCH TO MEOH WI-:IILE POOH 0:08 1000 1.00 1080 50 15 STOPPED AT 1000' TO FILL THE CT. 0:26 1000 1.00 1050 10 18 POOH STRING OUT MEOH AT 30 % 0:40 100 1.00 2000 10 5 STOPPED AT 100' AND FP THE TOP 1130 'AND TREE 0:054 100 0 0 0 10 CIRCULATED CLEAM MEOH TO SURFACE. POOH 0:057 SURF 0 0 0 CCH AND CHECK INFLOW 01:02 SURF. 0 0 0 RD CTU AND SECURE WELL. Final Well DATE W H P I A P 0 A P G L P F LT Status (psi) (psi) (psi) (psi) (o F) WSl 0 0 0 N/A N/A SENT VIA MAC MAIL PAGE -1- SUMMARY MI AND RU NOWCAM 4905 AND RU TO INSTAL A LLC-2 CAMCO VALVE IN THE PACKER AT 92O8 FEET. MAKE UP TOOLS AND CAMCO'S LLC-2 VALVE WITH 15' OF CENTRALIZER PUPS. TIH AND TAGGED THE TOP OF THE BAKER MODEL "F" PACKER WITH SEAL BORE PROTECTOR AT 9208. STUNG INTO PACKER AND JARRED 3 TIMES AND TOOL SHEARED. PUH TO 9094' AND CONDUCTED INFLOW TEST FOR 30 MINUTES. NO FLOW. POOH DISPLACING THE WELL BORE WITH 10.1 PPG NaCI / NaBr. PUMPED 365 BBL OF NACL AND SWITCHED TO MEOH DISPLACED THE TOP 1000' WITH 30 % MEOH AND FP THE TOP 100' OF 7" WITH 10 BBL OF MEOH. CLOSED SV AND MONITOR FLOW. NO INFLOW, RD CTU AND SECURE WELL TOP OF LLC-2 AT 9203 FEET. FLUIDS PUMPED B BLS. DESCRIPTION 365 63 NaCI/Na Br COMPLETION FLUID (10.1 PPG AT 75 ° F) MEOH BOTTOM-HOLE ASSEMBLY #1 I I DESCRIPTION I OD I ! LEN ! REMARKS COIL TUBING CONNECTOR 3.125 1 0.93 DOUBLE CHECK VALVE 3.125 1 1.57 BAILEY HYDRAULIC JARS 3.125 1.25 8.85 HYDRAULIC DISCONNECT 3.375 0.812 1.52 (7/8" BALL) 2 3/8" APl * 3 1/2" EUE 8RD XO 3.17 1 0.82 2-CENTRALIZER SUBS 3.668 2.34 15.00 1-5 3/4" CENTRALIZERS PER SUB, LLC-2 CAMCO VALVE 5.70 4.54 SAEL ASSMEBLY 2.82 TOTAL 36 .O5 SENT VIA MAC MAIL PAGE -2- To: ROSSBERG From: C. Parker Location' ANCHORAGE Date' 11/5/94 Well' MPJ-12 Operation- Set LLCV and Displace w/Kill Weight Brine ! Main Category: 330068 Drilling ! Sub Category: Completion I Well Status: Shut in ! WHP (psi): _+500 ! lAP (psi): - ! GLP (psi) -- I OAP (psi): -- I WHT (°F).: 0 i'nME I .... OPER.~TION ......... ' 14:00 Rig up Nowcam 4905. Run line from casing valve to Frac Tank to take returns. Pick up 21' Flanged Lubricator, Pump-in Sub, CT BOP, 12' Nowcam Lubricator. 19:00 Pick up Camco and Baker tools. _21:38 Pressure test to 4000 psi. 22:08 Start in hole. I TIME IDEPTH IPUMPRATE IPREss.COIL I WELL IBBLS. I PRESS. REMARKS 23:09 5000 Weight check 9800# upl 3500 # down 23:32 7000 Weight check 13,200# up~ 5500# down 23:42 7650 Weight check 14,500# up, 6500# down 23:49 7710 Tag up. Apply weight to push seal assembly into packer. 23:58 7710 Stroke jars and shear off running tool with I jar lick. 11/6/94 0:01 7700 Open wellhead valve and bleed pressure down. Monitor for flow. -- 0:48 7700 Bled back 4 gal. in 45 minutes. LCC appears to be holding. 1:00 7700 2.00 . 3650 Begin displacing hole w/10.1 ppg Brine 1:55 7700 2.00 3650 100 Shut down, check for flow. Resume pumping. 2:42 7700 2.14 3620 200 POOH while pumping 3:45 50 2.00 3700 320/0 Begin pumping MeOH to freeze protect coil tubing. 4:05 0 OOH. Monitor well--no flow. RDMO. OPERATIONS SUMMARY Rig up Nowcam 4905 w/flanged riser below CT BOP. Run in w/LLC-2 (Liquid Level Control Valve) with Baker seal assembly on bottom. Sting into Baker Model FB-1 packer at 7738' ELMD. Latch into packer and shear off running tool with 1 jar lick. Bleed off well pressure and monitor for inflow. Displace hole with 10.1 ppg Brine. FLUIDS PUMPED J 320 Bbl. J 10.1 ppg NaCI/NaBr Brine 35 Bbl. J Methanol to freeze proctect coil. BOTTOM HOLE ASSEMBLY O.D. I.D. LENGTH LENGTH ITEM (Inches) (Inches/l (Feet/ (FeetI Baker Coil Tubing Connector 3.125 1.000 0.94 Baker Dual Check Valves 3.125 1.000 1.55 , Daile~/Jars 3.125 1.250 , 9.44 Open Baker Hi Impact Hydraulic Dis-Connect 3.375 0.813 1.53 7/8" Ball X-over (2 3/8" Re,q. Box X 2 7/8"8 rd Pin) 3.125 1.000 0.83 , 2 7/8" Flow Couplings (4 ea.) w/Centralizers 2.875 2.350 15.05 (2 ea./ Centralizers - OD 5.750" 3.5" LLC-2 (Liquid Level Control Valve) 5.710 6.47 Includes Running Tool (4.59') Baker Seal Assembly w/Latch 4.000 3.000 2.83 TOTAL BHA LENGTH To: ROSSBERG From: Melvan / Crawford / Whitlow Location: ANCHORAGE Date: 10/31/94 Well: MP J-11 Operation: 2 7/8" COILED TUBING ESP COMPLETION I Main CategorT: DRLG - AFE330068 I Sub Category: CT COMPLETION I Well Status: Shut In I WHP (psi/: 0 I lAP (psi): .o I GLP(psi/ HA J CAP (psi): o I WHT(°F) amb [ vT~,, '~.'L~.L',-',-~. ""''~" "' ! "''" %~'! ' -- I .... ~1----'1 ' I 'il r I ~,~ .~ 4, , , i-nME i OPERATION 10/31 Move CTU 4907 from J-10 to J-11. R/U WELLHOUSE, 7" BOPS, WORK WINDOW, 4 - DEADMEN AND GUY WIRES, DSR 07.00 SKID, OPEN TOP TANK & ESP CABLE SPOOLING UNIT. USING 90 TON SPURT BOOM CRANE. 18.00 Test BOPE. Test Pipe Rams, Blind/Shear Rams, Blind Rams to 400 psi and 3000 psi. Test Hydril to 1500 psi. spot ESP reel house and pump shack. Load pump cable spool. Offload second reel. 20.45 Prep pump. Check pump oil. 21.15 Pick up P-gauge/mtr/intake. Fill motor and perform all motor Q/A on floor. PU pump section & bolt on same. Prep to stab coil. 11/01 01.00 Attach cable and band 55' of flat to pump with nine (9/ flat ~luards held by 49 flat bands. Fill motor seals. 02.00 PU GLM assembly with pump head and check valve. 03.31 PU injector head. Check out inserts. Stab lower coil connector & PT 2000 psi. OK. 09.47 RIH w/first coil spool, [ REEL NO. 2142 [ 600 FT OF CT]]. (14-1/2 wraps of coil on the reel at start) Zeroed counter w/ first coil at the work window floor for reference. Band electrical cable every 20'. 10.19 Finish with first reel of coil. Begin to change out reels, un-sling crane from work window. Sling to mt reel. Un-bridle mt reel and set aside. PU reel 2164 with 8800' of 2-7/8" coil and sling into bridle. MU splicing cable. Get hot work permit, cut retaining an~]le straps. 15.30 Begin TIH banding every 20'. RIH 91.4 FT TO SPLICING CABLE, Set slips AND SAFETY CLAMP. CUT OUT CABLE SPLICE, MU CTC AND HOSE TO HARDLINE. 17.23 Flush full coil spool w/75 bbl MEOH AT 2.5 BPM AND 1100 PSI. [20 BBL EXCESS TO PURGE CT] Bleed down coil. 19.00 M/U27/8"CTSPLICE[2CAMCOCTC'SAND8&2FT, 27/8"PUPJTS. [TOTAL SPLICE =12.75 FTJ. PULL TEST W/ 38 K, ENERGIZE PACKING AND PRESS TEST ENTIRE CT STRING AND CTC'S W/2000 PSI FOR 15 MIN. P/T OK. 20.14 SET MANUAL COUNTER AT 604.2 FT, [BTM OF SPLICE AT FLOOR OF WORK WlINDOW]. TOTAL STRING BELOW SPLICE = BHA OF 82.55 FT + 604.20 FT CT = 686.75 FT. 21.00 RIH WITH CT BANDING ESP CABLE EVERY 20 FT. CTMD = 604 FT. COILED TUBING REEL NO. 2164 [ 8800 FT CT] 21.52 CTMD = 1340 FT. 22.05 CTMD = 1605 FT, TEST ESP POWER CABLE OK. CONT RIH. AVE ROP LAST 1 HR = 15 FPM. 23.18 CTMD = 2250 FF. RIH SLOWLY FOR 1000 FT WHILE CORRECT LOOSE WRAPS ON ESP POWER CABLE SPOOL. 23.44 CTMD = 2614 FT, TEST ESP POWER CABLE OK. AVE ROP = 16 FPM, CONT RIIH. BAND EVERY 20 FT. 11/02 00.38 CTMD=3614FT, TEST ESP POWER CABLE, OK. AVEROP=18FPM, CONTRIH. WORK WlNDOW FLOOR TO GROUND LEVEL = 21.83 FT. TBG HGR L.D. SCREWS = 2.75 FT AGL. RKB = 30.0 FT AGL. FLOOR = 8.17 FT BKB. 02.24 CTMD = 5135 FT. CONT RIH. 02.49 CTMD = 5694 FT, TEST ESP CABLE - OK. 03.46 CTMD = 6694 FI-, TEST ESP CABLE - OK. CONT. RIH BANDING EVERY 20 FT. AVE ROP = 17 FPM. 05.16 CTMD = 7850 FT, UP WT = 48 K. CALC. B©UY. WT = 50K. 06.24 STOP AT 8970 FT CTMD, DID NOT TAG BTM, PICK BACK UP TO 8934.4 FT CUT POINT, 60 K UP WT [1500 PSI M.P.] NO PROBLEM POOH TO CUT POINT. MARK CT AT CUT POINT AT 8934.4 FT CT. WHEN LANDED BTM OF PUMP ASSEMBLY WILL BE AT 9050 FT BKB, BASED ON CT MEAS. NOTE: BTM OF PUMP ASSEMBLY WILL BE AT 9110 FT BKB BASED ON WRAPS OF CT LEFT ON REEL [ 11.5 WRAPS = 402 FT LEFT ON REEL]. 60 FT ERROR BETWEEN WRAPS AND CT MEASURING WHEEL IN 8360 FT = 0.7% MEASURING ERROR. [CAUSED BY STOPS EVERY 20 FT'I' 06.29 SET HAND SLIPS, M/U SAFETY CLAMP, BLEED OFF CT PRESS TO MEOH TANK. 08.30 CUT ESP POWER CABLE AND LAY OUT 54" SHEAVE. R/D CABLE SPOOLING UNIT. 11.00 LOAD CT BY 7" ANN. WITH MEOH WATER. LET FLUIDS EQUALIZE, PUT VAC. ON CT. DRILL HOLE IN CT. 13.20 CUT CT, DRESS OFF END, MAJ CTC, 4 FT PUP AND TBG HANGER. 1,4.14 M/U TBG HGR LANDING JOINT AND CTC. 15.23 BEGIN SPLICING CENTRILIFT ESP CABLE. INSPECT SPLICE. OK. 17.00 BAND ESP CABLE AND SLOWLY LOWER 7 1/16" TBG HAGER DOWN THRU 7 1/16" BOPS AND WORKING VALVE. 17.29 LANDED COILED TBG HANGER. VISUALLY CHECK AND SET LOCK-DOWN SCREWS. RU HOT OIL TO PT HANGER. 17.43 CLOSE ANNULAR BOP ON CT. 17.52 PT TUBING HANGER SEALS TO 2000 PSI. HOLD FOR 15 MINUTES. 18.07 GOOD TEST. BLEED DOWN ANNULUS. PUT VAC ON COIL. 18.30 CUT COIL. BACKED OUT LANDING JOINT. LIFTED OUT LANDING ASSEMBLY OUT OF STACK. 19.37 SET 2-WAY CHECK VALVE. CLOSED MASTER VALVE. CLOSED BOTH BLINDS ON BOP STACK. WELL IS SECURE. LEAVE 90 T CRANE RIGGED UP. WINDS ABOVE 30 MPH. UNABLE TO RIG DOWN.W/CRANE. CLEAN UP WELLSITE. 22.00 SDFN. WAIT ON WEATHER TO RIG DOWN. MPU J-11, ESP 2 7/8" CT COMPLETION PAGE 1 I'nME ! OPERATION ! 11/03 '~7.00 WINDS AT 30- 40MPH. WOW TO RIG DOWN. DO MAINT. ON POWER SKID. LIFT LINES AND HOSES ABOVE DRIFTS. 11/04 08.00 STORM DROPPING, WINDS AT 20 - 30 MPH, CLEAR OUT BIG DRIFTS AROUND EQUIP. ,~, 20.00 LAY DOWN INJECTOR HEAD. LAY DOWN WORK WINDOW. 22.00 PULL FLOAT FREE FROM ICE AND SNOW. PULL OPS CAB FREE. PULL CABOVER TRACTOR AND TRAILER FREE. 24.00 SECURE WELL. SDFN 11/05 '~)@.00 OPEN MASTER VALVE AND CHECK WHP. 0 PSIG. OPEN BLINDS. DEPRESSURE BOP CONTROL LINES. PULL BOP STACK FROM WELL. PULL OFF WELL HOUSE. ...1_3.00INSTALL FMC PENETRATOR ADAPTOR TO TUBING HANGER. NIPPLE UP 2-9/16" TREE. 15.00 PRESSURE TEST HANGER SEALS TO 5000 PSIG FOR 30 MINUTES. OK. PT PENETRATOR FLANGES AND TREE TO 5000 PSIG FOR 30 MINUTES. OK. 16.00 CLOSE MASTER, SWAB AND WING VALVE. WELL SECURE. RETURN WELL TO MP OPS. 16.15 BEGIN PREPING NOWCAM 4907 TO COMPLETE WELL J-12, CHANGE OUT EMPTY REEL FOR FULL REEL OF 2 7/8". 20.30 LEAVE LOCATION. OPERATIONS SUMMARY Ran Centrilift type 146 GC-1200 Series 513, MODEL GPMT pump w/tandem seals and Model KME1, Series 562,100 h.p. motor section, and' CentriLift Check Valve. Ran Camco tyPe KBMG Gas Lift Mandrel w/l" pocket, and DCK gas lift valve with DCK latch in place. Mandrel run 20 ft above Check Valve. Ran 8920 ft 2 7/8" 5.464¢ HS-70 Coil Tubing (2.495" I.D.) Hung string off in FMC 7 1/16" X 2 7/8" Tubing Hanger. BOTTOM OF PUMP ASSEMBLY AT 9050' BKB. [BASED ON CTMD]. CTMD HAS BEEN SHALLOW ON ESP JOBS DUE TO NUMEROUS STOPS FOR CABLE BANDING [EVERY 20 F-'I-J. Ran 9 flat cable guards including 49 flat guard bands. Ran 458 preformed bands to fasten cable to coiled tubing. Inner annulus and tubing filled with 50-50 MEOH from 0-800 ft and 10.1 ppg brine FROM 800 FT TO TD. KBMG mandrel run w/DCK valve and BK5 latch set for 3500 psi tbg to casing shear. Tree nippled up with 2 way check in hanger. 2.5" H BPV profile. 2 7/8" FMC tubing hanger with 2 7/8" ACME LEFT HAND threads on top and 8 rd on bottom. MPU J-11, ESP 2 7/8" CT COMPLETION PAGE 2 CENTRILIFT ESP BOTTOM HOLE ASSEMBLY MAX O.D, I.D. LENGTH ITEM (InchesI (Inches// (Feet) P- Gauge 4.50 NA 1.98 Motor 5.62 NA 11.00 Seal Section & Gas Separator 5.13 NA 15.82 Pump and Discharge head. 5.13 NA 18.94 2 7/8" 6.5# L-80 EUE 8 RD. Tubing Pup 3.67 2.441 2.23 Centrilift Check Valve 3.7 NA 0.40 Pup 2:7/8" 6,54~ L-80 8 Rd. Tubing 3.67 2.441 10.19 XO Pu.p 2 7/8" 6.,5~ L-80 8 Rd. Tubing 3.67 2.441 9.94 GLM 4.7 2.441 6.45 XO Pup 2 7/8" 6.54f L-80 8 Rd. Tubing 3.67 2.441 3.70 Coiled Tbcj Conn. 4.25 " 1.90 TOTAL LENGTH OF CENTRILIFT ESP BHA = 82.55 FT 2-7/8" Coiled tbg. [ REEL NO. 2142 ]. 2.875 2.495 604.20 Splice (w/two coiled tubing connectors) _ 4.25 2.441 12.75 2-7/8" Coiled tbg. [REEL NO. 2164 ]. 2.875 2,495 8316.42 Coiled TI~ Conn. 4.25 2.495 1.92 Pup 2 7/8" 6.5~ L-80 8 Rd. Tubing 3.67 2.441 4.25 Hanger (to lock dwn screws) 6.95 2.44'1 0.66 RKB to hanger lock dwn screws [ RKB = 30.00 FT ABOVE GL7 65 FT AMSL] 27.25 TOTAL MEASURED DEPTH BELOW ORIGINAL RKB 9050.00 MPU J-11 JOB NOTES 1. GODZILLA INJECTOR HEAD REPAIRS SEEMED TO HAVE SOLVED PROBLEMS. INJ HEAD WORKED WELL AND DID NOT MARK CT AS BEFORE. WT CELL IS WORKING BE'I-I'ER, BUT IS STILL OFF BY 10-20K. IT DOES TRACK WT NOW SO A W-I' LOSS WOULD BE SEEN. NOWCAM ELEC TECH. HAS WORKED 2 WKS ON PROBLEM 2. USING THE PORTABLE WELLHOUSE WORKS WELL. KEEPS BOPS WARM AND PROVIDES SHELTER FOR MEN AND TOOLS. LEGS AND FRONT PORCH FOR WORK WINDOW WORKED VERY WELL. PORCH PROVIDES NEEDE STORAGE/WORK SPACE FOR TOOLS AND BANDS. 3. DEPTH CONTROL SHOULD BE CHECKED WITH WRAPS OF CT LEFT ON REEL. STOPPING EVERY 20 FT INCREASES THE MEASURING WHEEL SLIPPAGE SO THE CT IS DEEPER THAN MEASURED. [ABOUT 60 FT FOR THIS WELL]. 4. A 3 MAN CREW IS NOT ENOUGH FOR THE CT COMPLETIONS. WE NEED ANOTHER MAN TO EFFICIENTLY RUN THE CTU. WE HAVE A LOT OF EQUIP. AND ADDITIONAL HOURLY COSTS THAT WAIT FOR WORK TO BE DONE WITH ONLY A 3 MAN CREW. THERE IS ALSO A SAFETY CONCERN DUE TO PERSONELL FATIGUE, THESE CT COMPLETIONS ARE MUCH MORE LABOR INTENSIVE THAN NORMAL CTU OPERATIONS. 5. WE HAVE SOME COMM. PROBLEMS AT MILNE POINT. THE PBU TRUNK WILL NOT ALWAYS WORK. REPEATER IS SCHED. TO BE IN IN MARCH 1995. 3 WATT MPU RADIOS WILL NOT REACH FROM J PAD TO CAMP. WE ALSO NEED A PHONE IN PE ROOM SO HE CAN BE REACHED IF NEEDED. DELAYS EASILY OCCUR ON THE JOB WHEN WE CAN'T CONTACT SERVICE PEOPLE OR BPX ENGINEERING. 6. NEED WRITTEN SPECS FROM CAMCO ON LLCV DESIGN OPENING PRESS. AND GAS LIFT DCK SHEAR VALVE SHEAR PRESSURE. MPU J-11, ESP 2 7/8" CT COMPLETION PAGE 3 P~ NO, ***--**************************************** ~,~** ~~: ***~***~ W~LL H~AD LOCATION: AZII~LtTH FRO~ ROT~Y TABLE TO T~RGET IS TIE IN POINT(TIP) : ME~EI) I)EFq'H 112,00 TRUE VE~,q' ])El'TH 112,00 I~LINATION AZ.I~rI'H 0,00 ~TI'I'UI)E (N/-S) O, O0 DEPA~tRE(E/-W) BEP(E/-W) w************ ~ILL SL~.~Y CALOJLATIONS w**w~.~,w*** CIRCULAR ARC M£ASL~LEI) I~¥AL VI~KTICAL DEPTH ft ft ft 112,04~ 0,0 112,~ 17B,~ ~,9 17B,92 265,49 ~,6 265,49 3~,19 94.7 451,55 91,4 451 TARGET ~ATI~ AZIlt_ITH ~TITUDE SECTIDN I~LN, ft de~ deg it 0,00 0,00 0,00 0.09 0,22 311,97 0.09 -0,08 0,52 217,99 -0,11 -0,75 0,50 210,53 -0 -1,45 0,73 ~6,20 -1,55 DEPARIIJ~.~ DISPLACE~MT at AZI~Jltt £/-W ft ft d~a 0,00 0,00 -0,10 0.13 311,97 -0,47 0,46 -0,94 1,24 229,40 -1,56 2,20 225,23 DLS de.Q; 1,50it 0.00 0.~ 0.~ 0,31 543.60 726,87 815.96 914,86 92,1 92,7 90,6 726,01 89.1 815,73 98,9 914,16 -2.~ 0.73 220,67 -2,40 -2,37 3,~ 224,61 0.07 -2,19 0,59 358.07 -2.37 -2,77 3,65 229,40 1,32 0,24 2,59 12,~ 0.09 -2,36 2,~ 272,24 2,24 5,21 4,61 28,74 5,~) -0,21 5,21 3'57,64 2,53 13,36. 6,41 26.09 13,65 4,13 14,26 16,82 1,&4 1008,69 1101,56 1196.03 I291,34 1~4,79 94.0 1007,~ 92,7 94,4 I1~,97 95.3 1282,96 93,4 1371,~ 24.92 ~,76 7,73 25,46 7,42 26,52 16,26 40,~ 11,10 14,56 41,09 10,64 4~,45 14,52 2,60. 59,67 13,29.' 5,73 60,69 14,01 62,29 13,00. 3,05 84,34 17,0~ 4,~ 85,56 16,~ 87,06_ 10,73 3.98 114,40 20.63 3.72 115.82 1B,~ 117,27 9,02 4,02 1478,~ 1575.,17 1668,22 1765,72 1859~60 .92,8 1456_,72 96,6 1547.98 73,1 1672,63 97.5 1719.91 73,9 1602,46 148,08 21.67 4,24 149,72 l~,B2 23.22 0.60 1~,64 ~I:~3,~ 25,75 3,97 725,22 2.~.,,30 27,16 3,53 268_,57 310.72 2"¢,73 2,23 313.23 20,74 151,15 7,89 22,26 167,96 ~,~ 226,49 6,05 26,69 269,89 28,92 314~ 5,26 2,23 3,02 2,81 1953,55.. 204B,63 2143.62 22"_J5,42 94,0 1682,92 95,1 1961,66 ~,0 ~37,~ 91,8 2106,26 94.4 21.77,51 356.95 ~,42 2.25 411,76 ~,74 4,99 414,83 4615,20 38,15 5°09 471,69 526.~ 41,15 1,13 530,15 590,2B 44,47 0,51 594,28 30,82 ~2,%' 4,67 34,2~ 416.24 4,72 3-7,25 473,3'2 4,76 42,36 531,64 4,57 43,27 595,86. 4,16 2,~7 3.64 2,54 4,27 3,55 24~,76 2517,74 2613,41 2684,74 2721 73,9 2242,69 94,0 7305,19 95,7 ~67,97 71,3 2414.~ 26,3 2437,44 657,76 47,~ ~9, ./-6. ~1,91 727,84 ~,98 359.25., 732.09 800,01 49,03 354,51 804,16 854,19 49,~ 25-5,09 858,13 68.2,12 51,05_ 351,90 685,92 43,~ 6.A2,~ 3,75 42.68 733,~ 3,~ 38,75 B05,09 2,76 ~,04 856,8(, 2,26 30,66 8~,45 1,9B 3,44 1,4~ 3,73 1,32 7,52 2820,16 2913,41 300~.B7 3103,53 3176,07 99',1 24~,'~ 93,3 2558,94 95.5 2620.04 94,7 2679,92 94,5 2737.62 959.01 S0.65 354.98 962.40 1031,18 S0.58 355,65 1034,~ 1104,52 49.62 356,07 1107.49 1177,82 51,68 357,09 11~,66 1252,55 52,76 3~.'.,11 1255,26 21,67 962,64 1,~ 15,97 1034,46. 0,66 10,65 1107,54 0,55 6,72 1180,~ 0,31 1,87 1255,26 0,09 2.42 0,63 0,86 2.13 1.41 3293,46 3366.,47 3462,40 2577,25" 3672,72 95,4 27~,24 73,0 2B51,04 95,9 _7-/06,51 ~,0 2965,13 95,3 3022,22 1328,72 53,22 355,24 1231,22 -3.87 1331,22 359,83 0,87 1403,13 53,05 356.42 1405,43 -9,29 1405,46 ~9,62 1,03 I479,93 53,35 255,10 1482,02 -14,97 1.4t32,10 359,42 1,14 15S6.,17 53.49 353.74 1557,94 -22,28 1556,10 359,18 1,16 1632,47 52,95 355,09 16~,73 -29.B2 1634,20 258,95 1,26 RECEIVE[O lq~.~;E~ IHi~:VAL U~F.~IC. AL- DI~TH D~F'fH ft ft ft 3766,04 93.3 3078.86 38~.00 94.0 31~ 3954,21 94,2 31~,73 4047,28 93,1 3251,19 4141,89 94,6 3311,24 ?A~I;E:T STATION AZI~IUTH LATITUDE S£~IDN INCLN, ~'-S ft deQ deq. ft 1706,61 52,30 35%14 1707,81 17~%,~ 52,30 354.69 1781 1855,~ 52,61 355,37 18~.27 1928.79 51,14 354,42 2001.81 50,07 352,49 2001,83 D~'fiF:.TLIR£ DI~'LACI~D.FI' at F,/-W ft ft -36,13 17~,19 -42,72 178~,37 -49,19 -55,70 1930,00 -64,02 2O02,85 GZII~JTH de9 358.79 35.B,63 358,17 DLS deq/ lO0. ft 0,69 0,38 0,66 1,77 1,94 4~.79 4330.83 4426,26 4522.30 ~16.53 93,9 3371,37 95,0 95,4 3494,37 96,0 3556.,72 94,2 36.17,09 20-73,74 50,25' 351,73 2073.27 2146,40 49,83 352,27 2145,42 2218.74 49.16 351.57 2217.26 2291.67 49,89 354,51 22~,9,77 Z3&3,97 50,43 353,82 2"~..1.75 -73,92 2074,59 357,96 -84,07 2147.07 357.,76 -94,26 2219,27 357,57 -103,10 2292.09. 357,42 -110,46 Z364,33 357,32 0,.~. 0,65 0,90 2,45 0,80 4709,15 4798,21 4898.50 4%3,46. 5086,84 92,6 3675,95 89,1 3731,79 100,3 3794,51 95,0 3854,51 93,4 3913,65 24.35.45 50,66 0"5'5,94 2432,96 2504.80 51 ./:.9 3%,94 2_~2,2L7 2582,98 50,90 359,16 25~,52 26%.46 50.,71 359,92 26.~.11 2728,61 50.70 ~9,07 2.726,37 -116,84 2435,77 ~57.,t~ -119,93 2505,14 357,26 -121,22 2583~37 357.31 -121,82 2656,90 357,37 -122,45 2729~12 357,43 1,78 2,87 0,81 0,65 0,70 5181,77 5276.02 537!,93 5471,42 5566,94 94.9 3974,14 94,2 4034,79 95.9 4096, ./-4,. 99,5 4160.75 95.5 4222,37 2801,73 50,14 357,22 2799., 49 2673.87 49.76 L"~. ,07 2871,51 2947.I6 49,% 356.88 .3023,26 49,89 .355,74 30D,6O 3096,25 49.77. 356.94 30?3,44 -124,82 2802,27 357,45 -129,04 2874,41 357.43 -133,~ 2947,69 357,40 -138,44 3023.77 357,3~ -143,10 3096,75_, 357,35. 1,61 1,02 O,.k6 0,~ 0,97 5663.03 5756,~ 5851,00 5868 5965,13 96,1 4284,4~ ~,4 4344,~ 94.6 4406.54 17,1 4417,66. 97,0 44~.85 3169.56' 49,69 356,76 3166.,65 3240.65 49.50 356.32 3237,61 3312.51 49.34 355,89 3325.47 49,38 L~US.~ 3322,23 33'99,12 49,37 355,79 3~95,69 -147,13 3170,07 357,34 -151,42 3241,15 357.32 -1%,30 3312.99 357,30 -157,22 ~5,95_ 357,29 -162,49 33"~,56 .357.26 0,16 0,41 0,~ 0,54 0,16 6060,17 6154.99 6249,31 6344,46 6439.15 95.0 4542,75 94,8 46O4.~4 94.3 4~,7,15 95,1 4730.60 94.7 4795,/,.1 3471,22 49.37 354,11 3467,54 3542,82 48.81 ~3.81 3538.80 ~13.44 48,50 350,80 36O8.96 3683,98 47,87 350,03 36.78,88 3~2,26 45,41 346,08 3746.46 -168,84 3471,65 357,21 -176,~ 3543,19 357.15 -185,85 36.13,74 b-57,05 -197,65 3664,18 356,92 -210,70 3.'/52.38 356,7g 1,34 0,63 2,42 0,% 2,99 6533.46 6626,79 6722,38 _/-.815,19 6909,28 94.3 48.62,58 93,3 4929,% 95.6 4998.,09 92,8 5O64,28 94,1 5130,38 3618,16 44,11 350,57 ~11,71 3842,87 44.17 351.31 3875,89 3~49,3Q 44,~ 353,06 3941,91 4014,~ 44,80 3%,61 4061,30 45,93 c."58,41 4073,58 -223,02 3818,22 356,65 -23fd,25 3882,90 -242,31 ~49,~ 356.,48 -249,,16 4014,38 356,46 -251,06 4061,31 356,47 2,32 0,56 1.28 2,75 1,81 7003,81 7097,91 7193,66 7288,34 7383,29 94,5 5195,26 94,1 5257.85 95,7 5319,43 94,7 5377,6O 95,0 5433,29 4150,00 47,35' 358.45 4142,3{ 4220,12 4%23 1,19 4212,56 4293,03 50,72 3.44 4285,81 436.7,32 53,47 1,~ 436O,44 4443,8~ 54,71 2,34 4437.31 -252,94 4150,02 ~6,51 -253,13 4220,16 -250,15 425CJ,I0 356,.~ -247,24 4367.45 356,75 -244,94 4444,06 356,84 RECEIVED 1,54 2,92 2.38 3,50 1,69 lqOV 1 6 i994 Gas Cons. Commission ~chor;. SU~¥E¥ CALCULATIONS CIRCLE.AR ARC {'P..THOI)*~*~ MBs, D.~:~ INT~t~AL U~RICAL D~FTH I)1~PTH ft ft ft 7473,81 ~+5 ~5.~ 7~2,60 ~,0 ~2,61 7672,37 ~',6 ~01,41 ~72,~ ~,7 5~.28 7~.,70 94,6 5724,~ TARGE~ STATION AZIMUTH ~ATITLCiE SE~'TION INC~N. ft d~ d~ ft 4517,~. ~,72 2,28 4511+13 4597,~ ~,92 1,~ 45~,01 ~78,06 52,~ ~?,54 4756,16 ~,61 ~8.~ 47~,53 DEPARTLII;.LE DISPLAC. B~N~ at £/-W ft ft -241,9.~. 4517,62 -239,59 4598,26 -23~,14 ~.76,47 -240,25 4756,60 -242,B8 482.~,81 ded 356.93 357,01 357,07 357610 357,12 deo/ lOOft 0,06 1,01 2,9 2,15 2,35 7948,36 8041,78 8136,34 822?,78 8325,42 81,7 5779,02 ?3,4 5(N3,71 ?4,6 5911 ~,4 5981,40 ?5,./, 6055,06. 4B69,05 47,12 355,61 4863,27 4956,42 45.22 354,61 4~50.42 5022,07 42,87 352,37 5015,73 50,_q4,11 40,61 351,84 5077,34 5144.~ 38,65 350,~ 5137,63 -246,81 4889,51 357,11 -252,55 4956,86 357,08 -~9.96 5022,46 357,03 -268,51 5064.44 356,97 -277,77 5145,13 3%,91 2,51 2,I0, 2,98 2,45 2,20 8421,07 8516,14 B607,SB 8703,15 8~01,85 95,6 6131.02 95.1 6206.66. 91,4 6285,89 95,6 6366,51 96.7 6455,61 5202,63 36,19 349,48 5194,87 5256.,8~ 33,66 350,53 5248.62 5L'"QS,?l 31,31 351,_% 525'7,27 5353,81 ~,03 352,75 5344,B4 5400,15 27,06 352,95 -267,76 5202,84 356.,~3 -~7,25 5257,03 356,76 -304°92 5306,03 356,71 -311,49 5353.91 -317,27 5400.23 356.63 2,67 2,52 2.~ 2,46 8897,15 89~7,11 90?5,73 9191.57 9289,01 95.3 6541,23 100,0 6631,75 98,6 6721,09 95,8 660B,18 ?7,4 6897,13 544!,96 25,02 356.~5 5432,54 5484,35 25,16 356.',21 5474,83 5526,12 24,95_ 355,65 5516,49 5566,10 24,39 354,.A4 5556,35 5605,_A8 23,82 354,02 5595,95 -~1,32 5442,04 3~,62 2,60 -324.18 5464,42 356,61 0,16 -327,14 5526,19 356.61 0,32 -330,52 5%6._,17 3%,60 0,73 -334,46 5605,94 356.,58 0,63 9475,~ 9570,04 9.,.665,62 9761, lc/ 9870.00 92,6 6981,89 94,3 7066,41 94.2 7155,13 95,6 7243,47 95,6 7332,12 F~k~ TO TD 108,8 7433.24 5642,~ ~,57 351,14 5632,83 56B0,34 23,25 352,95 566..9.92 b'716,~ 22,70 350,93 5706,32 5.753,31 22,18 350,59 5742,33 5788.81 21,68 350,0,5. 57-/7,52 5828,76 21,68 .350,06 5817,11 -~..,-5',25 5643,03 356,55 -344,44 56BQ,37 356,52 -349,5? 5717,02 356,4? -~5,45 5753,32 356.46 -361,45 57~,B2 ~,42 1,2~ 0,83 1,02 0,56. 0,57 -~,~ 5828,76 356.36 0,00 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 November 10, 1994 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN for well was sent to: IVIPJ-11 , Job # 94320 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 _,4 ~' //'1OH LIS Tape ,- "" 1 Depth Shift Monitor (/ '~'/ 3 Bluelines Plot ~ 1 Film Returning~_..N, CDR & CDN- TVD Field Film ~ State~~ 1 OH LIS Tape .Ata~ka Oil & Gas Conservation Comm. 1 Blueline ~ Attn: Larry Grant 1 RFolde__cLSepi~ //3001 Porcupine Drive (k.~ Ancllorage, Alaska 99501 OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline 1 RFolded Sepia Sent Certified Mail P 676 541 364 PLEASE ACKNOWLEDGE RECEIPT ~'Y ~1~1;~ AND RETURNING ONE COPY EACH ;2~¢ BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 2 November 1994 Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PACKER FINAL BL 1 PFC/PERF FINAL BL 1 PFC/PACKER RF SEPIA 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PACKER FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PACKER RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 Run # 1 Run # 1 ECC No. 6279.01 6288.01 5600 B Street Suite 201 .~~,~ Anchorage, AK 99518 . Attn. Rodney D. ' ~O~O~~~~ Received by:/~~/~4~ /~//~' Date: ~ /~0~ -- % LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 October 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL /~ # DESCRIPTION .k/~J-11 (08-1i-i3) i PDK/GR LDWG TAPE+LeT .../(~ F-28 (32-2-11-13) I,~3/1 cN/SR LDWS ~A~Z+~ZS~ r~ I GR/CCL LDWG TAPE+LST ~%~ MPJ-12 ; ~ ~ ~ 1 GR/CCL LDWG TAPE+LeT ECC No. Run # 1 954.04 Run # 1 3043.04 Run # 1 6279.00 Run # 1 6280.01 Run # 1 6285.00 Run # 1 6286.00 Run # 1 6288.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ' Attn. Rodney D. Paulson Or F.AX o (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 4 October 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION MPJ-13 ~/~ 1 PFC/PERF FINAL BL 1 GR/COLLAR FINAL BL 1 PFC/PERF RF SEPIA 1 GR/COLLAR RF SEPIA 1 FMT/GR FINAL BL 1 FMT/GR FINL.RF SEPIA Run # 1 Run # 1 Run # 1 Run ~ 1 ECC No. 6279.00 Run # 1 6280.00 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 j Att~ Re, J .dney D. Paulson Received ALASKA OIL AND GAS CONSERVATION COMMISSION l~ ~W. ALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (g07) 2767542 September 2, 1994 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-11 BP Exploration (Alaska), Inc. Permit No: 94-114 Sur. Loc. 2630'NSL, 3366'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 3163'NSL, 3652'WEL, Sec. 21, T13N, R10E, UM Dear Mr. Jordan: 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficien~ notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field at 659-3607. David W.~ohnston \ ~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~J~L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill CIIlb. Type of well. Exploratory r-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65' feet Milne Point Unit-Kuparuk 3. Address 6. Property Designation Sands P. O. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 315848 4. Location of well at surface 7. Unit or property Name 11. Type Bond(r~e 20 ^^c 25.025) 2630' NSL, 3366' WEL, SEC. 28, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2990' NSL, 3640' WEL, SEC. 21, T13N, RIOE MPJ- 11 2S 100302630-277 At total depth 9. Approximate spud date Amount 3163' NSL, 3652' WEL, SEC. 21, T13N, RIOE 9/5/94 $200,000.00 112. Distance to nearest '13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa,dTVD) property line ADL 25906-3163' feet No close approach feet 2560 9921' MD/7327' TVD feet :i'6. To be completed for deviated wells 17. Anticipated pressure (s,,~ 2o ,v,c 25.035 Kickoff depth 600 feet Maximum hole angle 52 o Maximum eu~face 3330 psig At total depth (TVD) ~800'/4~0 psi~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing -weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 13-3/8" 54.5# K-55 Weld 80' 32' 32' 112' -112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 36#" K-55 B TRC 2785' 31' 31' 2816' 2502' ! 575 sx PF "E"/250 sx "G"/250 sx "C" 8-1/2" 7" 26# L-80 BTRC 9891' 30' 30' 9921' 7327' 320 sx Class "G" 119. To be completed for Redrill, Re-entry, and Deepen Operations. 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 ~ Surface I nte rmed i at e Production i:;r'.;:'~ -'2 '"~':~:" Liner .. dept ' "-' u~i & ~:~;.~s (;0ri,. Perforation h: measured true vertical ' ~,'~,,.: ..... 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program~ Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify thaLt, he foreg¢,ing is true and correct to the best of my knowledge Signed A,_ Title Drillin~ Engineer Supervisor Date ' Commission Use Only Permit Number IAPI ~umber JApprov,,al date JSee cover letter cji_/l~ 150-0 ;Lc/- ;;;;L~,~-O;L ] ~,,.~.~? Ifor other requirements Conditions of approval Samples required [] Yes I~No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes 1~ No Directional survey required I;~Yes [] No Required working pressure for BOPE []2M; 1-13M; I~hM; l-I10M; ['-'!15M; Other: by order of Approved by Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in tr~iplicate I Well Name: [ MPJ- 11 Well Plan Summary [ Type of Well (producer or injector): [ Kuparuk Producer I Surface Location: Target Location: Bottom Hole Location: [AFE Number: I 330068 [ Estimated Start Date: [ 9/5194 [MD: 19921' I [ Well Design (conventional, slimhole, etc.): 2630 NSL 3366 WEL Sec 28 T13N R10E UM., AK. 2990 NSL 3640 WEL Sec 21 T13N R10E UM., AK. 3163 NSL 3652 WEL Sec 21 T13N R10E UM., AK. I [ TVD: [ Rig: ]Nabors 22-E I'Operating days to complete: [11 17327' bkbI ~'KBE: I Milne Point Ultra Slimhole 7LS ! 65' Formation Markers: Formation Tops MD TYD (bkb) base permafrost 1877 1815 MA 4640 3625 Ugnu Sands NA 5046 3875 Top of Schrader Bluff (West Sak) Sands OA 5331 4050 Seabee Shale 5583 4205 Base of the Schrader Bluff (West Sak) Sands HRZ 9190 6665 High Resistivity Streak Top Kup 9389 6845 Kuparuk Cap Rock Top C Sand 9510 6955 Target 9692 7120 Kuparuk A Sand Total Depth 9921 7327 Casing/Tubing Program: Hole Size Csg/ WUFt Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 13 3/8" 54.5# K-55 Weld 80 32/32 112/112 12 1/4" 9 5/8" 36# K-55 btrc 2785 31/31 2816/2502 [ 8 1/2" 7" 26# L-80 btrc 9891 30/30 9921/7325 Intemal yield pressure of the 7" 26~ casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7100 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional Only Intermediate N/A Final 1. Insert Bit to Seabee Base w/MWD Dir. 2. PDC Bit f/Seabee to TD w/~ Dir/GR/CDR/CDN. ' Cased Hole Logs: GR/CCL will be mn in 7" casing to coincide with Wireline Perforating Operations without a Rig on the well. CBL run only if necessary. A GR/CCL Log will be obtained in the 7" casing in conjunction with WL Perforating. Mud Logging is not required. Mud Program: Special design considerations None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (P P G) Viscosity Point gel gel. Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A Isec Density Marsh Yield 10 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to t° to 10.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1600 i~Maximum Hole Angle: Close Approach Well: 52.0 degrees (No Shut Ins) Disposal: Cuttings Handling' CC2A Fluid Handling: All drilling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Annular Injection: The MPJ-11 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBL$ IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED I INJECTED VOL (BBLS) (BBLS) Milne Point MPJ-11 0 35,000 5/3/94 thru Milne Point MPJ-08 0 35,000 5/3/94 thru Milne Point MPJ-10 0 35,000 5/3/94 thru FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. RECEIVED MPJ-11 Proposed Summary of Operations I . 2. 3. 4. 5. . . . 10. 11, 12. 13. 14. 15. Drill and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for dg move. MIRU Nabors 22E ddlling dg. NU and test 20" Diverter system. Build Spud Mud. Ddll a 12-1/4" sudace hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD required). ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD/GR/RES. Test 9-5/8" casing to 2800 psig, Drill out float equipment and 10 feet of new formation, Pedorm a LOT. Drill ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale and POOH. LD the Insert Bit and Motor. Send Schrader Bluff GR/RES Log Data to town ASAP (Attn: John Dillon/Tim Cook @ Fax: 564-4440). MU a Hycalog HX65H PDC bit (Rerun from MPJ-09) on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD tools to the Dir/GR/Res. RIH. Drill 8.5" hole to TD and Run and Cement 7" casing. This hole section will be logged LWD with Tdple Combo (GR/Res/Neu/Dens). RIH while PU 3-1/2" ddll pipe with 7" 26~ bit and scraper. Drill out ES Cementer, RIH to PBTD, displace the drilling mud out of the hole with source water, while pedorming a casing wash, filter source water to 2 micron absolute. POOH L/D 3-1/2" drill pipe. Freeze protect the well. ND BOPE, NU and Test the Frac Tree. Set BPV in 7" x 11" tubing hanger. RDMO Nabors 22E ddlling dg to drill MPJ-12. Well will be completed with Coil Tubing deployed ESP. EC ,iVED MPJ-11 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX #SACKS: 575 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg gal/sk APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost C ADDITIVES: Retarder WEIGHT: 15.6 ppg gal/sk APPROX NO SACKS: 250 YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 CENTRALIZER PLACEMENT: 1. I Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly--batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'rnd 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. MPJ-11 7" PRODUCTION CEMENT PROGRAM- CASING HALLIBURTON STAGE I CEMENT INTERVAL: CIRC. TEMP: 140° F 7040' TVDSS. ,,lOB ACROSS THE KUPARUK BHST 170 deg F at SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk gal/sk APPROX # SACKS: 210 140° F FLUID LOSS: < 50cc/30 min @ 140° F angle. MIX WATER: 5.0 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ FREE WATER: 0cc @ 45 degree .STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: 60° F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.8ppg gal/sk YIELD: 1.15 cu ft/sk MIX WATER: 5.0 APPROX # SACKS: 1 10 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 18 joints of 7" Casing (36total). This will cover 300' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 5600' - 4700' to cover the Schrader Bluffs Sands (23 Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 60, OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage I cement volume is calculated to cover 1000' md above the LK1 with 30% excess. 2. Stage 2 cement volume is calculated to cover from the OG base to the to 500' above the NA 30% excess. Tol PRUDHOE BAY DRILLING GROUP MPd- t (P t3) VERTICAL SECTION VIEW Section at: 355.82 TVD Sca]e.' ~ ~nch = ~000 feet Scale · ~ ~nch = 1000 feet o. A i '~ I wn ..... : 08/~8/94 Ii ~ I Narker Identification ND BKB SECTN iNCLN ~1 ~OP ~Ik¢ 2.5/~00 riO0 ~00 0 0.00 ~ __ ~ .......... , C) START 2.5/100 CURYE ~000 998 32 ~0.00 ~__ -~ ....... r,~¢~F-R~3 B) END OF 2.5/~00 CURVE 272~ 2444 887 52.0~ j E) 9-5/8" CASING POINI 28~6 2502 962 52.0~ / ~ ............................ ~A~E~r-F8F5 F) STARI 2/~00 DROP 7760 5546 4858 52.0~ )__ I G) END OF 2/~00 DROP 91~0 6593 5691 25.00 H) --- TARGET --- 95~0 6955 5860 25.00 - ~ I) TD 992~ 7327 6033 25.00 ~ ,~-~~ I ~---t .................. , _ -~"~- ~--- ~ .......... I ...................... ~ ...... l ~r.~s-'~r - - - ~ .......... ~-[ -- t- 'S[~[EF ~ 5 -4~o3 i j ............ ~ ~ ~, ~ ,~-. , , ..... , ..... ! ....... i .......... -~¢,ac ] ........... ~ .................. ! .......... L ..... -~ __ - _~ ..... I ~ ,, i I I I I i o 5oo ~ooo 50o 2000 25o0 30oo 3500 40m 4500 5000 55oo 6o00 65oo Section Departure ,, (Anadr~]] (6)93 NPd~iP~3 B~.52 5:24 PH :1} PRUDF~'OE BAY DRT'LLTN6 6ROUP 14arker IdentJf Jcation 140 N/S E/W A) KB 0 0 ~ A B) KOP BUILD 2.5/100 600 0 MPJ-1 ] (P~t3) PLAN VTEN CLOSURE ..... : 6034 feet at Azimuth 356.57 DECLINATION.: 30.000 E SCALE ....... : ~ inch = ~000 feet DRAWN ....... : 08/~8/94 Anadrj ]] $£hYumberger 3500 3000 2501 2000 500 lO00 500 0 500 10~* 1500 2000 2500 3000 3500 <- wEST' EAST -> (~nadrill (c)93 NPJt~P'I3 B~.52 5:25 PN 1) WELL PERMIT CHECKLIST IN= CLASS b' 1-- O;I WELL NAME GEOL AREA I,,t PJ -.. lt PROGRAM: exp [] il 3 dev ~ redrll [] serv [] ON/OFF S~O~ OtIU ADMINISTRATION APPR DATE ENGINEERING 1. Permit fee attached .................. ~ N 2. Lease number appropriate ................ ~; N 3. Unique well name and number ............... ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary.. ~ N 6. Well located proper distance from other wells ...... ~ N ' 7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ........ '6 N 9. Operator only affected party .............. Q~ N 10. Operator has appropriate bond in force ......... .~-~ N 11. Permit can be issued without conservation order ..... ~ N 12. Permit can be issued without administrative approval.. ~ N 13. Can permit be approved before 15-day wait ........ O N 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... . Y~ N 23. If diverter required, is it adequate .......... ~ N . 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate .................... N 26. BOPE press rating adequate; test to ~~ psig.~ N 29. Is presence of ff~S gas probable ............. Y GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures .... Y / 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis 9f shallow gas zones .......... 7 N 33. Seabed condition survey (if off-shore) ........ ~ N 34. Contact name/phone for weekly progress reports .... ~ Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ-~~ Co~ments/Instructions: HOW/jo - A:~FORMS-~heklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. MILNE POINT MICROFILMED Run 1' 30 - September - 1994 GR/CCL Cased Hole M/ESTE~ ATLAS ~000 }762 Atlas Wireline Services Tape Subfile 2. is %ype: S TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPJ - 11 500292250200 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 21-OCT-94 6279.00 R. ECK D. ROBERTSON 28 liN 10E 2630 3366 65.20 65.20 35.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 13.375 110.0 3RD STRING 9.625 2781.0 PRODUCTION STRING 7.000 9849.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: ATLAS WIRELINE SERVICES BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH REMARKS: GR/CCL Cased Hole. 72.00 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG TIED TO MAGNETIC MARKS. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 8998.0 9762.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH .... PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ- 11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 21 990 60 6 4 4 10 579 41 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 20 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 9787.000000 8987.000000 0.500000 Tape File Depth Uni = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4804 datums Tape Subfile: 2 110 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 9526.0 9762.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 9540.0 9540.5 9579.5 9579.0 9606.5 9606.5 9651.0 9651.5 9675.5 9676.0 9682.0 9682.5 9696.5 9696.5 9719.0 9719.0 9737.5 9737.5 9743.0 9743.5 9748.0 9749.5 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS). TENS WAS SHIFTED WITH GRCH. CN WN FN COUN STAT / ??MATCH1. OUT $ : BP EXPLORATION (ALASKA) : MPJ- 11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR ~ 68 1 GAPI 4 2 TENS GR 68 1 LB 4 * DATA RECORD (TYPE# Total Data Records: 0) 1014 BYTES * 66 264 66 264 36 36 Tape File Start Depth = 9777.000000 Tape File End Depth = 9513.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1588 datums Tape Subfile: 3 50 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8998.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9784.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CASING COLLAR LOC. GR GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 30-SEP-94 FSYS REV. J001 VER. 1.1 1146 30-SEP-94 9760.0 9763.0 9000.0 9762.0 1800.0 YES TOOL NUMBER 2323XA 1311XA .0OO 9849.0 .0 WATER/DIESEL 8.34 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 .0 .0 BLUELINE COUNT RA~ SCALES SET BY FIELD ENGIN~ ~ FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ- 11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 1 GAPI 4 2 TTEN GR 68 1 LB 4 3 TEN GR 68 1 LB 4 4 SPD GR 68 1 F/MN 4 5 CCL GR 68 1 4 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 4 76 115 41 1 4 26 165 19 6 2O * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 77 Tape File Start Depth = 9787.000000 Tape File End Depth = 8987.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24011 datums Tape Subfile: 4 149 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9526.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9774.0 30-SEP-94 FSYS REV. J001 VER. 1.1 1125 30-SEP-94 9760.0 9763.0 9000.0 9762.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CASING COLLAR LOC. GR GAMMA RAY $ TOOL NUMBER 2323XA 1311XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .O00 9849.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BP_M): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): WATER/DIESEL 8.34 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RAT~~ ~CALES SET BY FIELD ENGIN5 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS. · PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ - 11 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 TTEN GR 68 3 TEN GR 68 4 SPD GR 68 5 CCL GR 68 1 GAPI 4 1 LB 4 1 LB 4 1 F/MN 4 1 4 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 4 76 115 41 1 4 26 165 19 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 26 Tape File start Depth = 9777.000000 Tape File End Depth = 9513.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7931 datums Tape Subfile: 5 98 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes , , ****************************** ****************************** ~i~[,,~ NA~E ~ ~IL~E POIMT ~O~O[!G~ ~ ~ORTH SbOPE STAT~ ~ ~bASKA RECEIVED ~VOV 70 1994 · aska DJl & Gas Cons. Cemrnission AnChorage R-MOV-t. 994 15:02 AGE ,' 500292250200 ~P EXPLOPATION SCHLUMBERGER WEbL SERVICES 8-NOV-94 15~ S!PI?:G . 4320 q4320 94320 ST..AaO!tR ~ICOL8 NICOb$ [7) bHT~IC~ P LUTRICK D bUTRICK 2a 65.20 65,20 35.o0 .............. ;:::: .... :~ ....... ~.~on :. ~0.0 IS ma~e Ver(,f~,catlon 5~stino :bll.,lrl~berqer AlasKa ComPut.~,p~ Center 15:02 ~et~th sb~te~ and Cl.~p~ed curves} al! bit rubs meroed. DFPTh I~!CqE~E[~T: o.5000 S U Y}';i . ~ ~;, . ,;.. ; ............... [;-: ...... D ~ 5 q 3 ~. 0 B~S~b!i'~ CdPVF rO~ S~.~IF'mS: GRCH CI~bvE SwIF~T 0,~1;'~ (,vi~A~;U~ED ~ St:r, I 966¢.5 9675.5 9540,5 9q47,5 9425.q 9432.q 91~o.c 91~6.5 9047,5 905~.e ~WPCED DhTA $o(JPCE ~,bwg TOOb SToP DEPTH 9g08,o DEPTH ~895.0 9675.5 9547.5 q~32,5 9P57.5 9186.5 9054.0 ~0~,~ 272g.o 5o4.5,0 ?'.'~EIRGE BASE 6515,0 Tape vet!fi, cation [~isti. no ~hlumberqer AlasKa Com..,.~t~p~P Center 15:02 3 5945,0 9~08.0 2 fi~3~,o 6515.0 ~ 6515,a 9745.0 8998-g762 FT. F'RO~ 8998 TO 2728, A 8I~OCK S~IFT OF $ ** SET ~!~YEE - 6~,E~ ** 1 66 2 66 3 73 64 4 66 1 6 73 7 65 8 ~8 0.5 9 65 11 66 13 ~6 14 65 15 66 68 1~ 66 (; 66 0 ** SET TYPE - CNAM ** ~i~r ...... !C~ ~ ~I P API FI!,E UMB NUmB P OCES$ !9 O~DL~ # LOG 3'YPF CLASS ~OD NLI~B SA~P ~LEM CODE {HEX) '~'~;~. ........ 7:'''~~, _ ................. ~ ,)n, . Ooc.. C,O '''~ .......... 1 I ' ..... ~ ''''; ..... '''''';;~68 ....... 000000 GP ~,,,D G~PI ~3n2~ O0 060 O0 0 1 J t 4 68 0000000000 6~ 68 68 68 68 68, 68 68 0000000000 0000000000 O000OO0000 0000000000 O000OO0000 0000OOO0O0 0000000000 0000000000 nooooooooo :hlU~t~e~,.:,~er i.'~..1,,.a~a Cor~,gutin~ Center l-~!OV-19o4 !15:02 PMF M ~;,; ~ ~'~ t F 630298 OO 000 O0 0 1 ~ ~. $ 68 0000000000 C.~ L ~ :~,~ i~:' r'~ I~'-~ 630~5~ O0 000 O0 0 I ! 1 4 6fl 0000000000 NP}~I ~'~'r') PU-S 63o25~ OO 009 O0 O i 1 1 4 6fi 0000000000 NCN~ ,'?~n CPS 630258 O0 o00 O0 C i 1 t 4 6S o000000000 FC~!~ :','~ :~ ~ CPS a3n25a O0 000 oo 0 i ~ 1 4 6B 0000000000 66.422 WET.~i~D -g99.250 -99g 250 PEF.~D -.999~50 FCNT.~WD .-999'250 PEF.~WD ~99.250 FCNT.MWD -g99. -g99~ -999 -999 -99 250 250 250 250 25O 250 250 250 FTL? l,~A'!g : FOIl .002 MaX aEC STZ.~ : 1uP4 L~S~ ~ I. t,t? files. :S Ta~e vert. f~.cation P-MOV-1994 15:02 PAGE: BIT RU~ aU~EP: DFPTH I~CPE~E~: 0.5000 F~L~ SUMMARY LDWG TOOL CODE ST~R~ DEPT~ CD~ LOG ~EADER DATA DATE LOGGED: SURFACE SOFT~ARE VERSION:. DOWNHOLE $OFTWAPE ~ERSIDN: DATA TYPE (~E!~DRY or REAL-TI~E~: TD DRILLER TUP LOG INTERVAL POmTO~ LOG INTERVAL PIT ROTATING SPEFD POLE INC!,INATION (DEG) STOP UEPTN 5034.5 14-SEP-94 Lo,Os 20.4 FAST 2.5 ~E~ORY 9870.0 2728.0 0.~ ~1.7 54.9 TOOl, STPING (TOP TO BOTTO~) V~i~Dt]t~ TOOL CODF TOOL TYPE TOOL ............ . C ,:.~:.,~ ...... , .... ,:. A~Pt, iTUDE RES RGS02 8,500 2780.0 ~0.20 !45.0 2.470 1,BSO 0,000 SANDSTONE ~.65 8,500 PO~E~qOI.,E At,;O C~S!!>~ DATA OPE?~ HOI',E ~,IT SIZE DRILl, EPS CAOI~G DEDT~q 3.~UO TYPE: FLUID bOSS (C3): ~,~XT~lLir~ R~CnRDED TE~PERAT~R~ (DEGF)t ~TS~lVi,ry (p~N,~:) ~.T T~Y~ERA~URE ~':'UP AT '>~Ei~SUDEO TE~P~RATI. IRF "[:D ~T ~'~ ~X CIRCULATING 'fE~,IPERATUFE : riATPlX ~OL~ ~DP6'EC~Im,'' (TN]: T~3CL 5~'~,I.3f~'~' fi~): 1,000 86.0 71.0 0.0 IS Ta~,e '~er~flcatlon Listfns :hlumber~er ,alaska COmP'dtit':~~ <~eDter ~-~OV-I 994 15:02 R~.:5 '!o f~!T:ai~,87 F'f GR ?~ ~IT:59,P9 FT ~tL,~.,,~F,b I ~VAL ~707 TO 5935 FT ......... ri' ,'" . CO~'~ RF~Df')~T POR~ ~0 BIT:130,30 FT DE~-~ TfD ~t~':1,31'63 FT NE[IT TO 8IT:!..38.59 FT [?nIt, t,~D INTERVAL 5935 TO 6510 ************ P0~:~ 3 CDR RE,~9OUT PORT T(J BIT:7~.39 FT R~'5 TO ~i~;69.29 ~"~t' G~ ~0 ~IT~79.64 FT Cr~< ~FAOOUT PORT TO SlT~I30.19 CT D~:? TO ~IT1'!31.50 PT NEIIT TC BIT:138.48 FT [)~ILL~fO I~ER, VaL 6510 TO 9~70 ¥~$N~0~,~' PESlST~V!TY DATA 6170 TO 6510 TU ~,~;LL ~ 7:!8 13-SE~T-i994 ', ~ .... · · ~ ~ M~X I~,:~C!,:INA~:[~.~. 54 9~ lEG ~T 757~ ~ FT INCLI~,]'ATION ~m mD12!.6~ ES Ta~e Veriftc~tio.~ List:ino ..'hlumberc~er Alaska Comput!no .... e.'t~r 15:02 DKPT F~' 630258 00 000 00 0 ~ 1 I 4 68 0000000000 UR [.,~I G~P! 630258 0i) 000 O0 o 2 I I 4 68 0000000000 ROP~ 1,~1 F/HR 630~58 !lO 000 O0 0 2 ! I 4 68 0000000000 T~B L~! ti~ 630258 O0 0~(> 00 0 2 1 I 4 68 0000000000 PS~ !,~:1 O~i~ ~302$~ O0 000 O0 0 2 I 1 4 68 0000000000 DER LWI ONa~ 630258 00 000 O0 0 ~ I 1 4 68 0000000000 DEP'!'. 5934.50G GR.bW! -999 2:50 ~OPE:. I~Wl 204.544 TAB.L~I .. 3r~.LW1 -999.2S~.; PSR.LW1 9991250 OER.B~I -999.250 DFP* 27?1,. 5f~U, Ga. LWl 20.795 ROPE.L~I -~99.250 TAB.L~I ~T[,*r,t,;~l. '909, . .2~r~. ..,: pS}~'I,,N1 -099,250. DER.,LWl '999.~50 '999,250 '999'250 I~'TL? NA>~E ..' ~DIT ,002 8~RV!CE : FblC D~TF F~bW TyPE LAS~ FIt, E F I 1.~_ ? yr !J, r.4 ~,~ k 3 Curves an~ 1Oq4 n~der" 4ata for each hit run I.D separate iS ~at, e VerifY. cat,.on list~tnc] :blumber~er AlasKa Co~,putin~ Center PAGE~ LOG H~ADE~ DATh ~A~A TYPF (:.4E~4ORV or TD D~I[~bFR (FT): ~OP LOG YNTEPVaL (,FT): nOTTOM L~G I~,'T~RVAL (FT)~ ~IT POTATI?~;G SPEFD (RP~.~): *'~OLE I~C~,I~,]ATION (PEG) STOP D~PTH 65 ._, 14-$EP-94 sOcos o.4 FAST 2,5 ~EMORY 9870.0 2728.0 0,O 60 21.7 54.9 VF~'.~)[]P TC~L COD~ TOOb TYPE TOOb NUMBER CDR PHASE AND AMPLITUDE RES PGS022 CDb: cnb. P DE~JS AMD NUET POPO NDS0~2 ~()Pf:;~Ot.~E A~"~L) C~T~<~G DATA c:r,F,~ ROLE ~jTT STZR (!~)l 8 500 ~0.20 145.0 2.470 1.850 0,000 SANDSTON~ 8,500 ~45~P!X nE~:$TTY; TOOL 6~;~.:DOFF (i~): 86.0 71.0 0.0 ~-~OV-~994 15102 ~E$ ~'O ~iT148.87 FT GP TO BIT:ES.29 FT DD!~,L~D !~TMRVA~, 9797 TO 5935 FT CDR Q~L¥ LOGGING TOO.b THIS RUN. CDR READOUT POR· TO BIT:72,45 FT RES TO ~IT169,28 FT GR TO biT:TS.70 FT CD~ R~A~OUT PORT TO B~'T:130,30 FT D~!<~ :fO ~IT'113~.63 F~ NE!~T TO BIT:138.59 FT DPt~,L~D I,'.,~TERVAL 5935 TO 65~.0 · *********** ~b~ 3 ************* CD~ ~{MADO[!T PORT TO BIT:72.39 MT RES TO ~lT:6g,22 WT GR TO BIT:79.64 FT CDN ~A!)OI!T PORT TO BIT:130,19 FT DF~ TO BI~:1~31~.50 FT ~EUT ~O BIT:!.38.48 FT DPlLLED t~TFRVAL 6510 TO 9570 W~SHDO~i PESISTIVITY DATA 6170 TO 6510 TD !~!,,L AT 7118 ~3-SEPT-1994 ~X I~,!CLI~ATIO}~: 54.92 DEG AT 757~,8 FT I~C5I~!~TION AT TD12].68 $ 5!8 FORMAT DATA PAGE: ** SET ~YP~ - 6~,E~ ** TYPE REP~ CODE V~LUE 1 66 O IS Tane Verificatl. gn BJ, stlnO ;hlum~:~er,?er Alaska Comput!nc! ('enter PA ~,E: I0 3~25~ O0 000 O0 0 3 I 1 4 68 0000000000 30258 O0 000 O0 0 3 1 I 4 68 0000000000 3025~ O0 O00 O0 0 3 1 1 4 68 0000000000 630258 O0 000 O0 0 3 I 1 4 6~ 0000000000 63025~ O0 000 O0 0 3 1 I 4 68 0000000000 6302~6 O0 009 O0 0 3 1 1 4 68 0000000000 630258 O0 O00 O0 0 3 1 i 4 68 0000000000 630256 O0 000 O0 0 3 1 1 4 68 0000000000 630258 O0 000 O0 0 3 I I 4 68 0000000000 630258 O0 000 O0 0 ~ 1 1 4 68 0000000000 63025~ nO 000 O0 0 3 1. I 4 68 0000000000 yp~ - CHA~ ** ~:,:VrC~.: apl ,~P! APl ~PI Fib NLJ~8 U~B SIZE R ESS RDE~ ~ LOg TYPE CLASS ~(JD NUmB SAMP ELE~ CODE ....... :- .... .... .....,..,..................-..,,...--. 302$~ 0 000 0 3 I 4 68 0000 0000 30258 O0 On() O0 0 3 1. 1 4 68 0000000000 30258 O0 OeO O0 0 3 1 1 4 68 0000000000 DATA D~p~P. 65o9.5o0 GR.BW2 -09o.250 ~ OPE .:bt,-': 2 199" ,156 TAB.LW2 .~'T~. l,v/2 '909.2.50 pSR LW2 -99~,250 DER,BW2 -999'250 DP !~n, h w ~ -9¢9'259 'PEF" bw2, -O99 ,250 DCA b' LW2 - 999,250 P I., ¢5 '2 -999,250 PgR.LW2 -999:250 DKR.Lw2 -999:250 RHOB: t.,W2 DPHn !,v~2~ ~ -9o9,259 P~:F.LW2 -999,250 DCAG.LW2 -999.250 TNPN.LW2 -999,2So ~999.o250 999.250 -99 250 -99 250 **** FTb~' Ttx [ I LE:P F!L~ ~'.~A~I~j :FOll .0~3 SFCVIC~% : WLTC VFRSIO% : 00! COl FTIjr ?ypjy : PAGE: I! ~urves anc~ lo0 heoder ~ata for e~ch bit run in separate BIT RU?~ ~,~U~,~aE~: 3 t~DWG TOOL CODE; STAR~~ DEPTH LOG HFADE~ DATA ~OFTW A~'t;:: S[~R?,ACE SOFT'~'~RE ~E~SION: f)OW?~HOLE SOFTWAPE VERSION: ;'-~ ! ~'~ T ~ Il [';~ At?Gl, E: 9S70,0 14'$EP'94 FAST 2,5 9~70.0 2728.0 0.0 60 21.7 54.9 ................... .--;~ ...... ; .... . CD~; PHASE .D h~PLITL~DE ~{~S ~GS05 S .... ~. TT,~ f I"~): 8.500 ~KTI~I..E~S C~S~G DE~T~ fF~): 2780.0 ,;,:r, TYOF' :~ ~Ji,~u~w+'glTY:, -. ([ ,.a/G): 10.2o f i ! e s. ~hlUm~,erger AlasKa Co~F, utIn~ Center ~-NOV-~994 15102 HOL~ CORRECTI[]~'~ (IN~ I 145.0 2.470 1,850 0,000 SAS~DSTONE 2.65 8.500 TOOL 8T~iDOFF (i~:~): 1,000 ************ PtJ~ CDR RFAnO~T PORT TO 8~T152,04 FT RES TO 8iTI4B.87 FT G~ TO BITISg.~9 FT O~ILDFO INTERVAL 2797 TO 59~5 FT CDR O~LY LOGGIN~ TOOL THIS RUN. ************ RU~ 2 ************* CDR RF~DOUT PORT TO ~IT~7~,45 FT RES TO BI~:~9.2~ F,£ GR TO 8IT179.70 FT CD~,~ R~Df]IIT PORT D~:~i TO ~IT:~3~.63 F~ NEUT DPI!,L~O INTFRVAU 5935 TO 65~0 ************ P{,}~ 3 ************* CDR READOUT PORT q~O BIT~72 39 FT RFS T~ ~IT169.2~ PT GR TO ~I'T~79.64 FT CDi,~ F~,.,~.Ob PO · ~0 B!T:I~O.i~ FT O~l,. TO Slm:~3~'50 FT ~E!tT TO BITI138.4B FT DPI[,LFD I~TERVAL 65~0 TO 9870 ~4ASNDO~ RESISTIVITY DATA 6170 TO 6510 TD Wgl..b AT 71!8 13-SEPT-!994 MaX I~CLI~AwIO~: 54.9~ DE~ A~ 757~.a FT $ I, TS FORMAT r)ATA 86.0 71.0 0'0 1¸2 ** ~ATA FnP,~A'~ SPECIF!CSTTOb~ PECOPD ** ** SET wyo~ . o4En ** TYPE R~P~ CODE V~kllg i 6~ 0 ~ 66 O 3 73 69 [$ Tar, e Versification Listlno :bl.mber<~er Alaska Cov~puttpo center 15: 2 PAGE: 5 66 7 65 ~ 68 0.5 ~ ~ ~" 1! 66 IP 68 13 66 0 14 65 F~~ 1~ 66 68 16 66 0 66 ** Sg~ TYPE - N~N~ SE~w U~I? SEPV!CE API ~PI AP1 %5 OKD£R DEBT FT 630258 O0 000 O0 GR I,~3 GAP! 630258 00 000 00 ROP~ 1.,!~;3 Fi~P 6302~8 00 000 O0 T~B !,~;3 h~ 630258 O0 000 O0 T~BP !,,¢3 HP 630258 00 000 00 Ama r,w3 O~i~ 630258 00 OO0 O0 PSP 1,~3 0~ 6302~F 00 OmO n0 DVR [,;'¢3 0~ ~3¢~58 O0 000 O0 RHO~ I.,~3 G/C~ ~30258 O0 000 O0 D~HT !,~3 PU 63025~ 00 000 00 P~F L%~3 ~;/~ 630258 O0 O00 O0 DCAI, 1.,~,3 !P 63~258 00 000 O0 TNp,4 !.~ P~! 6302~8 O0 000 O0 MF~ Lw3 CPS 630258 ~O 000 O0 ~FF~ ~:43 CB5 6302~8 PI FILE NUmB NUMB SIZE REPR PROCESS OD NUmB SA~P ~L~M CODE (~EX) 4 1 1 4 68 0000000000 4 t 1 4 68 0000000000 4 ! 1 4 68 0000000000 4: 1 1 4 68 0000000000 4 I I 4 68 0000000000 4 1 I 4 68 0000000000 4 1 i 4 68 0000000000 4 I I 4 68 0000000000 4 I i 4 68 0000000000 4 1 1 4 68 0000000000 4 I I 4 68 0000000000 4 1 1 4 68 0000000000 a 1 I 4 68 0000000000 4 1 1 4 68 OOOO000000 4 1 I 4 68 0000000000 4 1 1 4 68 0000000000 DFp'r. c~87 (..;. oO L:, GR. LW3 T,aB''', . f., ~'; 3 -90?. 2r--, .'.: A'rR. L !-'-' 3 RHOc, 'r~.,:'~ -909 2~,~ noHIoLW~ DCAI,. I.,,~' 3 -9°9.25o T~-~PH. bW3 DFP''r . ~,0 g 5.50,3 G g,,,'. T I':, b F:. 1,, ,,, ~ -90.9.2r-, 9 ~Tk',. I:K 3 -999.250 ~OPE.LW3 66.422 TAB -999.~50 PSR.hW3 -999..250 -999.250 DR~O.LW3 -999.~50 -999.250 HENA.LW3 -999.250 HFF~.t, W3 -099.~50 ~ODE.LW3 -999.950 TAB.Lk3 -999.250 PSR.LW3 -999.250 DER.LW3 -999.~50 ORHO.LW3 -999.250 PEw.!,W3 -999.75~ HEW~.LW3 -999.~50 MEFA.I,~3 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6.088 IS ~a~e Verification I,istinc~ ;blumterqer .~.]asKa Co+~putir~.,q. CeDter 15:02 D~T~ N~X RFC 5!ZF FTLF TYPE: POINT, ~iPd-11., AP1 50-029-22502-00
