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198-143
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-06_21071_KRU_2N-317_CaliperSurvey_CaliperLogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21071 KRU 2N-317 50-103-20266-00 Caliper Survey w/ Caliper Log Data 06-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:198-143 T36602 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.12 10:42:06 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-05-06_21070_KRU_2N-317_LeakDetectionSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21070 KRU 2N-317 50-103-20266-00 Leak Detection Survey 06-May-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:198-143 T36601 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.12 08:45:48 -08'00' Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: rr ti AOGCC s ATTN: Natural Resources Technician If Alaska Oil & Gas Conservation Commision \! 333 W. 7th Ave, Suite 100 �•�� Anchorage, AK 99501 8143 107 8 TRANSMITTALDATE TRANSMITTAL 8 . • , NAME API # ORDERSERVICE it FIELDWELL NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA DATE LOGGED Prints CD's 1H-114 1H.111 1H-105 1H-113 1H-116 3M-19 3G -07A 50-029-23584-00 50-029-23581.00 50-029.20727.01 50-029-23588-00 50.029.23594-00 50-029-21737.00 50-103.20127-01 EOSH-00071 EAI8-00022 E118.00075 El 18.00076 E118-00077 E118.00078 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL IPROF ]PROF-WFL ]PROF-WFL IPROF-WFL [PROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17 -Jul -19 19 -Jul -19 20-Ju1-19 21Ju1-19 22 -Jul -19 23 -Jul -19 1 1 1 1 1 1 1 3G-11 50-103-20133-00 El 18-00081 KUPARUK RIVER WL IPROF FINAL FIELD 25 -Jul -19 1 3M-13 1 B•16AL1 1A-17 1C-121 3N -14A 3G-08 50-029-21720.00 50-029.22457-60 50.029-22102-00 50-029.23015-00 50.029-21589-01 50.103-20128-00 E118-00084 EDEA -00009 E118.00085 E118-00086 EOSH-00074 COSH -00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL IPROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28 -Jul -19 28 -Jul -19 29 -Jul -19 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 1 1 1 2N-317 50-103.20266-00 E0SH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 15 return via courier or sign/scan and email a copy to and CPAI. SCANNED AUG 0 7 2019 Schlumberger -Private ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. F77,0 199 — M3 Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, July 13, 2019 3:05 PM To: Loepp, Victoria T (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 2N-317 Sustained casing pressure of the IA Attachments: 2N-317.pdf; 21N-317 90 Day TIO plot.PNG Follow Up Flag: Follow up Flag Status: Flagged Victoria- Kuparuk Tarn producer 2N-317 (PTD# 198-143) was reported by operations with 2020 psi on the inner annulus. The well was shut in on the 91" of July for gas handling purposes and will remain shut in until the diagnostics and/or repair have been completed. The production casing is 5.5 inch, 15.5 Ib, L-80 which has a burst pressure of 7000 psi. 45 percent of the burst rating is 3150 psi. CPAI intends to conduct a series of diagnostics to identify the pressure source and develop a plan for repair. If repairs options are not immediately available, the well will be secured. Pending the outcome of the diagnostics the appropriate notifications will be submitted. Please let me know if you disagree with the plan. Attached are copies of the well bore schematic and 90 -day TIO plot. Dusty Freeborn/Jan Byrne Wells Integrity Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Coin� ComcoPhillips Alaska, Inc. run, Twmla tat6m AM Lest Tag veiml aereec laenwp lmdetlen possibilities Em Wb YIeIMae Lat MPn By Lav Tag:SUa40. U 15 1 INmM - Last Ran, Reason XAtlOER: as rRXlMtlm EMOnk WtlBpn Rev Reason: GLV IO In Pa1Hi ) Wtsew9 i] zembaej Casing String, .awn, lbenpuan Op(b) CONDUCTOR 18 ID as 1606 TWIXKB) 29.1 aelpag me) 109.0 4et pepb (IVB)... VNIyn 11... 1(b'S 62.58 G- TOP TAS H-00 WELDED calm Bucnptiun pp PN SURFACE )5l8 IB MI 6d] TopIM®I 29.1 am Sep to -h 2,694.3 sot pyn ltVpl,.. WpT.n ll., 2,314.0 29.]0 pine rap Tnraa 1,80 BTC$100 Geelm praWpBPn r1w, PRODUCTION 5.SKi5' 512 @ ]640' -IMI 4.95 Tm I11K9) 25.] 6etpnplX lnK01 8,483) Btl BepN (IYp)... pIMAn 0._ptle 5,581.3 1650 Taprnlw] L-80 LTC -MOD Tubing Strings coxBecTan: le t_Mo, roam Bescrlpfpn sMm Me... mlMl Tap lnxa) ytpwtn ryL Sm pepm RVB11... Vrt lmery G,aee TOPeonnee o. TUBING 3112 2.99 215 >,63).) 4992.3 9.30 L-80 EUE8RDM0D Completion Detsiis xlPpl@am.2 Tn"OVB) Tm ImJ NwnMm Tro (Me) Imcal rl have Ban can IB MI 23.5 23.5 0.00 HANGER FMC GEN N 5M TUBING HANGER 3.600 2 505.1 .98 NIPPLE CAMCO DS IPPLE 2875 ), 1 .4 4,906.0 48.85 SLEEVE BAKER CMU LIDING EVEw/CAMCO B R FI ;Sleeve 263 imPrapm)y assembled M Baker. Can be shifted As is open M offer rnwk.On 9117M ), 13.0 4,13115. 46.41 NIPPLE MCO DNI N p Sg 7,620.1 4,9 .0 48.25 LOCAT R BAIB=RL TOR 2985 7,621. 4, SEAL BY BAKER CA LNG SEAL FMB) 3,ppp Ogler In Hole irel Ile retrievable plugs, valves, PUMPS, ll,h, ate.) PATG1:3,414p TnP YIW /.0 TnPE f"(s) 21 9.4 Tcp Bcl (-) .21 PA Be[ CH Gm SH AIR T H- TRAD IE PATCH 1 KB PACKER, SPACER PIPE, 312' KB PACKER; On, Run pb 1 of") 1.W - 2.M. OAL-23.34') 2414' RKB (MIDDLE OF TOP ELEMENT) 7,W.0 1.8 4&94 PAT H DEEP AT U E ASS7,506' R (Mid Ela Ef KB PACKER, SPACER PIPE. IN SRU 202018 1. GLM (wIV.114 un« REPLACED ON ]22019» » a suRFAca: at.'4M4d- REPLACED AGAIN &WWII). SPACER PIPE, SNAP LATCH. OD -218', 10.1' OAL40.38) AS 4,94 .1 17.39 PATCH PACKER DEEP PATRASSY@ , id Elememl(SNAPLATCHRECEPTACLE,SPACER 16 1. PIPE 312' KS PACKER; OD- ,78, ID-1SB.OAL. sZEvE T.mo4 35.E PATCH >,6q.p ; CONDUCTOR SUBSIDENCE: Wage, 17X IV Cw olu" mansion 1nf a enal Of 109', man, ¢011dadp( top 58Gk 10 wignelRKB 913c012 Perforations a Slob BAaL ;T,aM,f sna PATCH P.1aER, 7, rz. TwlbeO) BXn LXxel Top") IXKB I B.RVp)Dena n mne Bala IMOM1IN 1 ryce can 0 5,248.> 11101 5,. 317 1 91111 B 4.0 I RF 1.5 BH, HC, 8 tlep ph Frac Summary EIeXcowas Ptggad BoynN pn) I'toµxntln Fampbnllry W11996 Bbe Nmemm Top DePX 1me01 BXn (X1(0) unFm Flue Byamm vd eben l6Xp Vaw,y llwp 1 9011998 IL 0 8,042.0 Mandrel Inserts M xPPLE: Tetao aft LIXATOR; >,6A1 son N T°Plahae ], 0. "ell) 4.9 MW qM AM MobtlLabel KBG2- 9 GAS 8uv LIFT tWta V IMM Me BTM Po - Ibl TAURun IPO D. qun OaM 16 can E%T FEW a DMY Notes: Generel a Safety aMA93Y:7.ai12 g'... Endorsee, Annoessn 111 2010 NOTE: View ScnemMiC wl Alaska SdoAnalic9. &12201 N TE SITU GLM IN NCORPORATED M PATC ASSEM Y ),521' R FMG9.W3A 11 )PERF: Camy B: T.aW.a9.4p0 PROPICTKK15.sYJ.YO STATE OF ALASKA • A SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r', Plug Perforations E Fracture Stimulate 1 Pull Tubin Performed: 9 Operations Shutdown Suspend 1 Perforate E Other Stimulate 1 Alter Casing E Change Approved Program i Plug for Redrill E Perforate New Pool E Repair Well E Re-enter Susp Well E Other:Tubing Patch R- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development P Exploratory 198-143 3.Address: _ Stratigraphic 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Service 50-103-20266-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380054 KRU TARN 2N-317 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 8500 feet Plugs(measured) None true vertical 5593 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) None true vertical 0 feet (true vertical) None Casing Length Size MD Burst Collapse CONDUCTOR 80 16 109 109 SURFACE 2665 7 5/8 2694 2314 PRODUCTION 8458 51/2 8484 5581 SCANNED r, I ' ui Perforation depth: Measured depth: 8002-8042 :TikC.: r True Vertical Depth: 5250-5277 NAR 0 1 2016 r OGCC Tubing(size,grade,MD,and TVD) 3 1/2, L-80, 7638,4992 Packers&SSSV(type,MD,and ND) PACKER: None SSSV: None 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation — — — 2200 1800 Subsequent to operation 109 634 996 1798 275 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development 17 Service E Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil P"' E WDSPL r Printed and Electronic Fracture Stimulation Data I— GSTOR WINJ IWAG E GINJ r SUSP E SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Tyson Wiese Ca.263-4250 Email Tyson.M.Wieseanconocophillips.corn Printed Name T son W.= e Title Sr. Wells Engineer Signature Phone:263-4250 / Date �'l Form 10-404 Revised 5/2015 ,‘/W4 3/////L RBDMS LI- MAR 0 1 2016 Submit Original Only t- p $€ $ , KUP OD • 2N-317 ConocoPhiQips ' Well Attrinir Max Angle&MD TD • Ala )),0 Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) lgips 501032026600 TARN PARTICIPATING AREA PROD 60.09 6,849.80 8,500.0 -'- Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 25-317,2/25/20162.30.02 PM SSSV:NIPPLE 75 11/2/2014 Last WO: 35.32 8/13/1998 Vernal schematic(actual) - ,,.. „ Annotation Depth(ftKB) End Date Annotation Last Mod By frI End Date Last Tag.SLM 18,240.0 14/25/2015 Rev Reason:PULL PATCH ASSY,AVA pproven 2/10/2016 CATCHER,CA-2 PLUG SET DEEP PATCH HASGER,23s ' l Casing Strings -,--. .. "..�""'.-"'.""'... "...""...". Casing Description 00(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR (6 15.062 291 109.0 109.0 62.58 H-40 WELDED •I SURFACE - Casing Description OD(in) ID(i n) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 75/8 6.875 29.1 2,694.3 2,314.0 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread PRODUCTION 5.5"x35" 5 1/2 4.950 25.7 8,483.7 5,581.3 15.50 L-80 LTC-MOD et@ 7640' Tubing Strings ii Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING """'""m""`"'""'"""....,,,, 31/2 2.992 23.5 7.637.7 4,992.3 9.30 L-80 EUE8RDMOD . .w CONDUCTOR.29.11090 _ Nominal ID ,��-Completion Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 23.5 23.5 0.00 HANGER FMC GEN IV 5M TUBING HANGER 3.500 NIPPLE;508.2 ; nt_, .F 506.2 506.1 0.98 NIPPLE CAMCO DS NIPPLE 2875 I 7,510.4 4,906.0 48.85 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO DB 2,813 PROFILE;Sleeve improperly assembled by Baker,can be shifted but is open in either position 9/17/98 s 7,613.0 4,975.1 46.41 NIPPLE CAMCO D NIPPLE NO GO;275"CA-2 PLUG 4 26 15 2750 7,620.1 4,980.0 46.25 LOCATOR BAKER LOCATOR y 2.985 7,621.2 4,980.8 46.22 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 • a Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) / , Top(ND) Top Incl I Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) PATCH;2,402.3 2,402.3 2,152.6 53.93 PATCH SHALLOW PATCH-STRADDLE PATCH(3 1/2"KB 2/8/2016 1.830 PACKER,SPACER PIPE,3 1/2"KB PACKER;OD- 2.78",ID-1.83",OAL-23.34')2414'RKB(MIDDLE s• t OF TOP ELEMENT) i.. ;. 7,483.8 4,888.6 49.23 PATCH DEEP PATCH UPPER ASSY @ 7,504'RKB(Mid 2/7/2016 1.000 • •/ Element)(3 1/2"KB PACKER,SPACER PIPE,IN • _ SITU GLM,SPACER PIPE,SNAP LATCH,OD- 2.78",ID-1"OAL-00.38') 7,554.5 4,935.3 47.81 PATCH DEEP PATCH LOWER ASSY @7,572'RKB(Mid 2/6/2016 1.560 SURFACE'29.1-2,6943- Element)(SNAP LATCH RECEPTACLE,SPACER PIPE,3 1/2"KB PACKER;OD=2.78,ID-1.56.DAL- ': 35.08) PATCH,7,483.13 �) CONDUCTOR SUBSIDENCE:Welded 12"X 16" 9/3/2012 I conductor extension fora total of 109',raising SLEEVE;7,5104 - conductor top back to orignal RKB Perforations&Slots Shot Top(TVD) EMI(TVD) Dens (s Top(ftKB) Btm IRKS) (RKB) (ftKB) Zone Date It) It) Type Com 8,002.0 8,042.0 5,249.7 5,277.5 S-5,S-3,2N- 9/4/1998 4.0 IPERF 2.5"BH,HC,180 deg ph 317 Stimulations&Treatments GAS L,rT i 560 1 I,ri Min Top Max Btm L Depth Depth Top(ND) Btm(TVD) I (RKB) (ftKB) (ftKB) (ftKB) Type Date Com 8,002.0 8,042.0 5,249.7 5,277.5 FRAC 9/7/1998 Placed 167 Mlbs of proppant in the formation. Mandrel Inserts - at oN TopTop(ND) Valve Latch Port Size TRO Run R _r (RKB) (ftKB) Make Model OD(in) Sets Type Type (in) (psi) Run Date Com NIPPLE;7,6130 1 1 7,560.2 4,939.1 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.250 0.0 2/9/2016 EXT M1'MI C I� 9 PGK, 12:00 Notes:General&Safety LOCATOR;7.6201 _1', End Date Annotation If11/22/2010 NOTE View Schematic w/Alaska Schematic9 0 SEAL ASSY;7,821.2 I I PATCH;7,554.5 1 1 FRAC;8,002.00-i IIPERF 80020-8 042 _ Casing 3,7,650 0-8,480.0 PRODUCTION 5.5"x3.5" 7640',25.7-8,483.7 • 2N-317 S DTTMS.JOBTYP SUMMARYOPS 2/4/16 WEATHER MOVED EQUIPMENT TO LOCATION. WIND SPEED TOO HIGH TO RIG UP CRANE. JOB TO START WHEN WEATHER IMPROVES. *JOB IN PROGRESS 2/5/16 WEATHER STANDBY DUE TO PHASE CONDITIONS. JOB TO BEGIN WHEN WEATHER IMPROVES. *JOB IN PROGRESS 2/6/16 TUBING / PERFORMED DRIFT W/ BARBELLED 2.78" GAUGE RING &TAGGED D NIPPLE @ 7613' - CASING RKB. RAN 2.78" DUMMY PATCH DRIFT (OAL 25') TO 2500' SLM; DID NOT SEE ANY PATCH OBSTRUCTIONS. SET 35 KB LOWER STRADDLE PACKER @ 7572' RKB (MID ELEMENT) 2/7/16 TUBING/ SET TEST TOOL IN DEEP PATCH LOWER ASSEMBLY @ 7510' SLM. LRS PERFORMED CASING PASSING CMIT TxIA TO 2000#. PULLED TEST TOOL. SET DEEP PATCH UPPER PATCH ASSEMBLY @ 7504' RKB (MID ELEMENT). *JOB IN PROGRESS 2/8/16 TUBING/ SET TEST TOOL IN DEEP PATCH UPPER ASSEMBLY © 7504' RKB (MID ELEMENT). LRS CASING PERFORMED PASSING CMIT TxIA TO 2000#. PULLED TEST TOOL. SET SINGLE TRIP PATCH PATCH @ 2414' RKB (MIDDLE OF TOP ELEMENT). SET TEST TOOL IN TOP OF SINGLE TRIP PATCH. LRS PERFORM PASSING MIT-T TO 2000#. PULLED TEST TOOL. LRS PERFORM PASSING MIT-IA TO 2000#. *JOB IN PROGRESS 2/9/16 TUBING/ PULLED 1" DMY VLV FROM IN SITU GLM @ 7484" SLM. SET 1" OV(BTM INT LATCH, 1/4" CASING PORTS) IN SAME. JOB COMPLETE. PATCH WELL READY TO POP. 2/21/16 ANNCOMM (AC EVAL) TIFL- PASSED 2.4352. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 8, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 vot21/2015M.K.BENDER Anchorage, Alaska 99501 RECEIVED OCT 14 Z015 RE: Multi Finger Caliper(MFC): 2N-317 AOGCC Run Date: 8/12/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-317 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20266-00 sokoiel :; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' AD / ' :/ Y1-13 k4s-v-t3 2 WELL LOG TRANSMITTAL DATA LOGGED q/3/2015 K. BENDER To: Alaska Oil and Gas Conservation Comm. August 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ise12.,:e RE: Multi Finger Caliper(MFC) : 2N-317 X00 "; Run Date: 8/12/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-317 Digital Data(LAS), Digital tal Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20266-00 t,1(,J cAs 352., 10114It5— iv c71n,14l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 SCANNED MAR 1 4 X418 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ✓aLt'ftw Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~:)~ '/~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Beverly Mildred Damtha ;~..owell Date: [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is/ f STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other Conductor Extension Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-143• 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20266-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380054 ' 2N-317 . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Tarn Oil Pool • 11.Present Well Condition Summary: Total Depth measured 8500 feet Plugs(measured) None true vertical 5593 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 7621 true vertical 0 feet (true vertical) 4981 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108 1640 630 SURFACE 2665 7.625 2694 2314 6890 4790 PRODUCTION 8458 5.5 8484 5581 7000 4990 pNNED N{UV : La RECEIVED Perforation depth: Measured depth: 8002-8042 True Vertical Depth: 5250-5278 SE P 1 6 2013 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7620 MD,4980 ND AOGCC Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER 80-40 CASING SEAL ASSEMBLY @ 7621 MD and 4981 ND 12.Stimulation or cement squeeze summary:N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r ` Service r Stratigraphic r 16.Well Status after work: Oil r , Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-306 Contact Martin Walters/MJ Loveland Email N1878( cop.com Printed Name Martin Walters Title Well Integrity Projects Supervisor Signature J'' / �'� f ' Phone:659-7043 Date 9/11/13 ��/' �, Y F (4 i> RBDMS OCT 11 7 13 Form 10-404 Revised 10/2012 Submit Original Only . • RECEIVED Conoco Phillips S E P 16 2013 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 11, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well 2N-317, PTD 198-143, Sundry# 313-306 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • • • ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 NSK Well Integrity Projects Supervisor • • 2N-317 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/03/13 Welder fitted and welded 12"X 16" conductor extension for a total of 109'. • S 2N-317 DESCRIPTION OF WORK COMPLETED SUMMARY LJ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 140 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a (revised 10/3/07)spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9128107 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, ` -= on Arend • ~, ConocoPhillips Well Integrity Field Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9!2712007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" nla 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27!2007 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: _ .~ 1.`~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIn. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, '~ f ~~ :•' M.J. vel d ConocoPhillips Well Integrity Projects Supervisor ~~C~ oar /V~~ A/$ske DiJ& ©2 2pp~ An as ~°ns e e~°ra~~ Sisson ~~ • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404 Date Kuparuk Fieid 9/28/2~~7 WeN Name PTD # Initial top of cement Vol. of cement um ed Finai top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-103 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9!16!2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/912007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' $" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9!27/2007 2N-304 201-130 10" Na 10" n/a 4.5 9127!2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n!a 14" n/a 4.5 9!27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27!2007 2N-311 206-179 12" n/a 12" n/a 10 9127!2007 2N-313 198-091 5" nia 5" n/a 2 9/27!2007 2N-314 200-183 26" n/a 26" n/a 7 9/27/2007 2N-315 19&190 6" n/a 6" Na 3 9/27/2007 2N-317 198-143 5" Na 5" n/a 1 9!27/2007 2N-318 200-100 10" n/a 10" n!a 1 9/27/2007 2N-319 198-197 5" n/a 5" nia 9.5 9/27/2007 . .._......."......... SchlumblPglr I Cj1r -/Lf3 sCANNED JUN· ~ 1 2007 06/14/07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4300 ;~ 0 zom Company: Alaska Oil & Gas Cons C()mm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 fi <!\~ Field: Kuparuk Well Color CD Job# Log Description Date BL 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumbergel' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well ../ ,2N-305Jð O· ì )5- J 2N-308 {C1l\ - ÛÎt. ./2N-317 I (1 S~ N 1 v2G-06 13 ~( - ~ ~ ).. ../ 1 Y -04 ¡ ~} - f¡ ~ l J3J-10 i ri -J.\.ç J 2U-10 1(1) - t )\~ ""1C-178~) - (:-if SIGNED: Job# 11047348 11047344 11047345 11022913 11047351 11058227 11047352 11022908 I . '1 / '! .'/ í~; ) I / ; J 3 : _ J I /\j-rt ...... SCAf~~'~E[ ~ 6' P' n f:: Z- no'- ~"" -~ tJ L t} U J f J Log Description SBHP SURVEY SBHP SURVEY SBHP SURVEY FLOWING BHP INJECTION PROFILE \) 'I L MULTI-FINGER CALIPER LOG PRODUCTION PROFILE WIDEFT PRODUCTION PROFILE WIDEFT ~ I ('! 1, I . ; J / l! / /tt'{,1,--I " v NO. 3443 08/03/05 I q~- ;t.f3 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL 07/25/05 1 07/24/05 1 07/24105 1 07/20/05 1 07/27/05 1 07/18/05 1 07/28/05 1 07/14/05 1 Kuparuk Color ....."" \ J ~. DATE: 7:"'~~- V Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. CD _/ - Ák~ 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 _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 28 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 47' FNL, 705' FEL, Sec. 3, T9N, R7E, UM (asp's 460889, 5911960) 2N-317 At top of productive interval 9. Permit number / approval number 1762' FNL, 703' FWL, Sec. 34, T10N, R7E, UM 198-143/ At effective depth 10. APl number 50-103-20266 At total depth 11. Field / Pool 1417' FNL, 4965' FEL, Sec. 34, T10N, R7E, UM (asp's456640, 5915891) Kuparuk River Field/Tarn Pool 12. Present well condition summary Total depth: measured 8500 feet Plugs (measured) true vertical 5593 feet Effective depth: measured 8028 feet Junk (measured) true vertical 5268 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 108' 16" 9 cu yds High Early 108' 108' SURF CASING 2666' 7-5/8" 290 sx AS IIILW, 240 sx Class G,, 2694' 2314' PROD CASING 7622' 5-1/2" 262 sx C~ass G 7650' 5001' PROD CASING 830' 3-1/2" (included above) 8480' 5579' PROD CASING Perforation depth: measured 8002' - 8042' true vertical 5250' - 5277' 7 ",.; .~--.-, ~.-~.--,-'~ ..... ~ ~': ;-.?. '-~;'~ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-8O Tbg @ 7650' MD. Packers & SSSV (type & measured depth) No packer .,~.1~ 0ii & Gr,¥; C,,.~r,s. Commissi0r~ CAMCO 'DS'@ 506' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mc! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Peter Nezaticky 659-7224 Peter Nezaticky ~,,'~// ~ Prepared by Sharon Al/sup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N(W4-6)), WELL JOB SCOPE JOB NUMBER' " 2N ANN-COM M 1107011721.4 DATE DAILY WORK UNIT NUMBER 11/08/01 OOA CEMENT TOP JOB 2N-303, 317, 343, 349 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES APC-AREND NEZATICKY FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTIMATE K85329 35TN2N1 NG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSIJ 0 PSII 0 PSI DAILY SUMMARY CEMENT TOP JOBS ON THE SURF X COND (OOA). 2N-303, 317, 343, 349.[WH Maintenance] TIME LOG ENTRY 11:00 ON LOC. MIRU 12:00 PRE-JOB SAFETY MEETING. START MIXING CEMENT. 12:30 12:45 CEMENT MIXED, 6 BBL OF 15.7 PPG ARTIC SET. START PUMPING CEMENT DOWN 2N-303 SURF X CONDUCTOR ANNULUS (OOA) THROUGH 1" HOSE TAKING RETURNS TO VAC TRUCK, PUMPED 5 BBL. START MIXING 4 BBL OF CEMENT. 13:00 CEMENT MIXED MOVED TO 2N-343. PUMPED 2 BBL INTO A 6 FT VOID. 13:25 MOVED TO WELL 2N-349. PUMPED 1 BBL INTO A 7.5 FT VOID. 14:00 DUMPED 5 GAL OF CEMENT INTO 2N-317. SMALL 8 INCH VOID, BUT PREVIOUSLY REPORTED SOFT MATERIAL WHEN TAGGED. 14:30 RDMO SUNDRY NOTICE 10-404 Phillips Kuparuk Well 2N-317 Annular Cement "Top-Job" November 08, 2001 Phillips Alaska, Inc., Kupamk well 2N-317 surface casing has "grown" several inches to the point where the casing hanger was no longer contacting the conductor pipe. The cement top between the surface casing and conductor pipe (7 5/8" x 16") was measured at 1 feet below grade. Arctic Set I cement (15.7 ppg) was dumped into the annular void (5 gal). The cement top was brought to the surface of the conductor pipe. The State Inspector was notified of the cement job and waived attendance, but will inspect the wellhead post cementing. The field Well Service Report is attached. Well compliance Report File on Left side of folder 198-143-0 KUPARUK RIV U TARN 2N-317 50- 103-20266-00 PHILLIPS ALASKA1NC MD 08500~'~'TVD 05592 ~'"Completion Date: /~13/98 Completed Status: 1-OIL Current: Microfilm Roll / Roll 2 / -- Name Interval Sent Received T/C/D D 8738 SPERRY GR/EWR4/CNP/SLD OH 11/18/98 11/18/98 L DGRJCNP/SLD-MD L, FI:NAL 2720-8500 '~,~t¥o/~- '~/]~/~'76 OH 11/25/98 11/25/98 L DGR/CNP/SLD-TVD ~IAL 2328-5593 ~ OH 11/25/98 11/25/98 L DGR/EWR4-MD //I~NAL 2720-8500 ~X~ OH 11/25/98 11/25/98 L DGR/EWR4-TVD ~NAL 2328-5593 OH 11/25/98 11/25/98 Daily Well Ops ~_/~q~9_ _ c~/~ Are Dry Ditch Samples Required? yes ~).~And Received? yes Analysis Description ~ Was the well cored? yes .~___._. Comments: Tuesday, August 01, 2000 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, ¢.~/z~/~ Commissioner Blair Wondzell, ~ P. I. Supervisor ~'o'~ FROM: John Crisp? ff,~u~ c,, SUBJECT: Petroleum IrCspector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc CC;, NON-CONFIDENTIAL SVS Tarn KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tarn, Kuparuk River, 2N Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE i 2N-307 1990170 2N-~08 1990100 94 70 65! P P OIL 2N-309 1990210 2N-313 1980910 94 70 70 P P OIL 2N-315 1981900 ~~!i~;i"t981430 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730 ,, 2N-323 1980710 94 70 70 P P 0IL 2N-325 1981630 .... 2N-329 1980670 94 70 70 P P OIL 2N-331 1981170 2N-335 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000i 2N-341 1981030 94 70 65 P P OIL 2N-343 1980920 2N-345 1981130 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% [] 90 Day Remarks: 7/9.7/00 Page 1 of 1 SVS Tam KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Bamdt AOGCC Rep' John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GASorC¥¢LE 2L-305 1982400 94 70 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090: 94 70 65 P P OIL 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% W190 Day Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc'xls 0 I:t I I--I-- I I~ G S ~::: !:t L~ I r' E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 25, 1998 RE: MWD Formation Evaluation Logs 2N-317, AK-MM-80320 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-317: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20266-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20266-00 2"x 5"MD Neutron & Density Logs: 50-103-20266-00 2"x 5" TVD Neutron & Density Logs: 50-103-20266-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 25, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-317 (Permit No. 98-143) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tarn 2N-317. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad RECEIVED SEP 2 8 1998 Naska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well o,, [] OAS I~ SUSPENDED I~ ABANDONE© SERWCE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-143 '3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~. ..................... 50-103-20266 ~;di~'L~':l d_,'n~ ~.~~ 9 Unit or Lease Name 4 Location of well at sudace ~ ~'~ "~'"'" "~'q 47' FNL, 705' FEL, Sec. 3, TgN, R7E, UM ~ ,/., ;'¢:~, :.,_ -~. ' ~ Kuparuk River Unit At Top Producing Inte~al Vcz~-:~:j.j-~{ 10 Well Number 1762' FNL, 703' ~L, Sec. 34, T10N, R7E, UM':-~ 2N-317 At Total Depth ~. - . - : _ ..~_: -. 11 Field and Pool 1419' FNL, 314' ~L, Sec. 34, T10N, R7E, UM Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease Designation and Sedal No. Tam Oil Pool RKB 28', Pad 121'~ ADL 380054 ALK 4602 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~15 Water Depth, if offshore 16 No. of Completions 04-Aug-98 11-Aug-98 13-Aug-98~ NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickn~s of permafrost 8500' MD & 5592' ~D 8387' MD & 5515' ~D YES ~ NO ~ NA feet MD 1050 APPROX 22 Type Electric or Other Logs Run G~Res, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58~ H-40 SURF. 108' 24" 9 cu. yds High Eady 7.625" 29.7~ L-80 SURF. 2694' 9.875" 290 sx ASIIILW, 240 sx Cla~ G, 60 sx ASl 5.5" x 15.5~ L-80 SURF. 7621' 6.75" 262 sx Class G 3.5" 9.3~ L-80 7621' 8484' 6.75" (included above) 24 Perforations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER S~ (MD) 3.5" 7638' 7621' (CSR) 8002'-8042' MD 5250'-5277' ~D 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8002'-8042' MD refer to a~achment 27 PRODUCTION TEST Date First Production ~Method of Operation (Flowing, gas lift, etc.) 9/11/98~ FIo~ng Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE ~ GAS-OIL RATIO 9/2N9~ 4.00 TEST PERIOI: 535 328 0 176~ 613 Flow Tubing Casing Pressure CALOU~TED OIL-BBL GAS-MOF WATER-BB[ OIL GRAVIS-APl (corr) Press. 383 0 ~4-HOUR RATE: 32'10 1968 0 39° 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and pr~ence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate D~.v. 7-1-R0 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Reservoir (T3) 7779' 5093' Base Reservoir (T2) 8054' 5286' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~- ! - ~ ~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 O-407 RECEIVED SE? 2 8 1998 Anchorage Date: 9/8/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-317 WELL_ID: AK9325 TYPE: AFC: AK9325 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:08/04/98 START COMP: RIG:RIG 9 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20266-00 08/03/98 (D1) TD: 108'(108) SUPV:D.BURLEY 08/04/98 (D2) TD: 1700' (1592) SUPV:M.C. HEIM 08/05/98 (D3) TD: 2700'(1000) SUPV:M.C. HEIM 08/06/98 (D4) TD: 2700' ( 0) SUPV:M.C. HEIM 08/07/98 (D5) TD: 2720' ( 20) SUPV:M.C. HEIM 08/08/98 (D6) TD: 3977' (1257) SUPV:M.C. HEIM 08/09/98 (D7) TD: 5548' (1571) SUPV:M.C. HEIM MW: 10.0 VISC: 190 PV/YP: 42/36 DRILL 9-7/8" HOLE FROM 600' APIWL: 10.2 Move rig over hole, RU diverter system. Accept rig 8 1400 hrs. 8/3/98. Test diverter. Clean out conductor from 59' to 108' MW: 10.2 VISC: 72 PV/YP: 27/35 DRLG. @ 2208. APIWL: 7.2 Drilling & surveys from 108' to 1697'. Replace conveyor sprocket and repair chain. MW: 10.2 VISC: 58 PV/YP: 18/19 APIWL: 4.0 RUN CSG. (NOTE) MAX GAS DURING SURFACE HOLE (1450 UNITS) MI Drilling and surveys from 1697' to 2700'. Wiper t~ip to bit, hole tight @ 900' thru 400' Clean bit and RIH, bridge @ 509' and 570' MW: 10.1 VISC: 47 PV/YP: 14/11 TESTING BOPE. APIWL: 4.8 Run 7-5/8" casing. Pump 1st and 2nd stage cement. N/D diverter. N/U BOPE. MW: 9.4 VISC: 44 PV/YP: 11/10 DRLG. & SURVEYS 83180.00 APIWL: 6.0 N/U BOPE and test to 250/3500~. Drill cement, closing plug & stage tool. Drilling insert baffle. Drill formation from 2700' to 2720'. Perform LOT, EMW @ 15.03~ MW: 9.3 VISC: 47 PV/YP: 13/13 DRLG. & SURVEYS @ 4350' APIWL: 5.6 Drilling and surveys from 2720' to 3977' Set rtts packer 2636' Release packer and pump pill. MW: 9.5 VISC: 46 PV/YP: 12/10 DRLG. & SURVEYS @ 5750. APIWL: 5.8 Drilling and surveys from 3977' to 5548' 08/10/98 (D8) TD: 7242'(1694) SUPV:M.C. HEIM MW: 9.5 VISC: 51 PV/YP: 13/21 DRLG. & SURVEYS @ 7500. Drilling and surveys from 5548' to 7242' AP IWL: 4.4 08/11/98 (D9) TD: 8500' (1258) SUPV:M.C. HEIM MW: 10.0 VISC: 49 PV/YP: 13/20 APIWL: 4.2 LAYING DOWN 4" DP. (24 HRS. RIG POWER) Drilling and surveys from 7242' to 8500' 08/12/98 (D10) TD: 8500' ( 0) SUPV:M.C. HEIM MW: 10.0 VISC: 48 PV/YP: 16/14 CIRC. F/ CEMENTING CSG. Run 3.5" x 5.5" casing. APIWL: 4.5 08/13/98 (Dll) TD: 8500' ( 0) SUPV:M.C. HEIM MW: 8.3 VISC: 0 PV/YP: 0/ 0 POH LOOKING FOR LEAK IN TBG. OR JEWELRY. APIWL: 0.0 (24 HRS. RIG PO Running 5.5" x 3.5" completion. Pump cement. Run 3.5" tubing. Freeze protect well. 08/14/98 (D12) TD: 8500' ( 0) SUPV:M.C. HEIM MW: 0.0 VISC: NEXT REPORT 0 PV/YP: 0/ 0 .APIWL: 0.0 Pull hanger. PU landing joint, sting in seal assembly, pressure to 3500~, no hold, check surface equipment, assume failure in seals, GLM or sliding sleeve. RIH with new seal assembly. ND BOPE, NU master valve and test. Release rig @ 2100 hrs. 8/14/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, K1(2N-317(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-317 FRAC, FRAC SUPPORT 0903980509.2 DATE DAILY WORK UNIT NUMBER 09/04/98 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 NOI NO SWS-STEPHENSON KRALICK FIELD AFC# CC# Signed ESTIMATE K85118 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 250 PSi 320 PSI 0 PSI 0 PSI 0 PSII 0 PSI DAILY SUMMARY PERFORATE 8002'-8042' USING 2.5" HC BH 4 JSPF 180 DEGREE PHASING [Per[] TIME LOG ENTRY 07:30 MIRU SWS 08:30 PFF BOP AND LUB TO 4000 PSI 08:45 RIH W/CCL GAMMA AND 20' GUN - 2 1/2" HC BH 4 SPF 180 PHASED 2 JSPF 90 CCW HIGH SIDE 2JSPF 90 CW HIGH SIDE 09:30 TAG BOTTOM 8223' ELM 10:10 LOG TIE IN PASS FROM BOTTOM TO 7800' 10:30 SHOOT 100 PSI OVERBALANCED @ 8022'-8042' ELM - ALL SHOTS FIRED - WELLHEAD PRESS DROPPED TO 40 PSI 12:00 RIH W/20' GUN GAMMA - SAT DOWN @ 4600', 4930', - UNABLE TO GET DOWNHOLE 13:00 MIRU HOT OIL- PUMP @ 1 BPM DIESEL 1650 PSI - ABLE TO MOVE DOWNHOLE AGAIN- REDUCE PUMP RATE TO .5 BPM - STOPPED AGAIN @ 6124' - UP HOT OIL TO BPM - MOVING AGAIN - SHUT DOWN HOT OIL 14:00 TIE IN PASS 14:15 SHOOT 8022' - 8002' ELM WITH SAME GUN CONFIGURATION - POOH W/ALL SHOTS FIRED 16:30 RDMO SWS RECEIVEB SFP 2 8 ARCO Alaska. Inc. KUPARUK RIVER UNIT ,~. WELL SERVICE REPORT ,~ K1(2N-317(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-317 FRAC, FRAC SUPPORT 0903980509.2 DATE DAILY WORK UNIT NUMBER 09/07/98 FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES DS-YOKUM RIGGS FIELD AFC# CC# Signed ESTIMATE K85118 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 563 PSI 1100 PSI 465 PSI 500 PSII 310 PSI 300 PSI DAILY SUMMARY [Frac-Refrac] PUMPED FRAC PER PROCEDURE W 50# DELAYED XL GEL. PUMPED 12/18 PROPANT AT AVG PSI OF 3500 LBS AND 15 BPM. SCREENED OUT IN THE 7 LBS HOLD STAGE W/184,711 LBS PROP PUMPED AND 166,789 LBS OF 6.7 PPG TO PERFS. LEFT 18,078 LBS GEL IN 3.5" PIPE 3463' FILL IN PIPE. BHP AROUND 2300 PSI TIME LOG ENTRY 08:10 MIRU TGSM 8 PEOPLE ON LOCATION. PT LINES TO 9500 08:30 PUMP BREAKDOWN STAGE @ 30 BPM GOT BREAKDOWN @ 6271 PSI TO 3650 PSI. DO PULSES @ 75 LBS. ISIP OF 1027 PSI. 08:55 PUMP DATA FRAC W 50 # DELAYED XL GEL @ 15 BPM AND 4216 PSI. SHUT DOWN GOT ISIP OF 1158 PSI 10:00 PUMPED SCOUR STAGE W/50# DELAYED XL GEL AT 30 BPM AND 4080 PSI 75 BBL OF 1 PPG AND 70 BBL 2PPG PROPANT. PREFORM STEP DOWN, GOT ISIP OF 855 PSI. 10:35 PUMP MAIN FRAC W/450 BBL 20# LINEAR GEL PREPAD AND 200 BBL 50# XL GEL PAD. PUMPED REST OF FRAC W/12/18 PROPANT 2 PPG TO 9 PPG W/50# XL GEL AND J 478 FLUID LOSS AGENT @ 15 BPM AND 3500 PSI. 12:45 SCREENED OUT 187 BBL INTO THE 7 LB HOLD STAGE. PUMPED 184,167 LBS OF 12/18 PROPANT W/166,789 LBS OF 6.7 PPG TO PERFS. LEFT 18,087 # IN 3.5" PIPE 3463' FILL IN HOLE BHP 2300 PSI. · ', SURVEY CALCULATION AND FIELD WORKSHEET - i ~ Job No. 0450-99764 Sidetrack No. __ P~ge 1 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/317 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~llrr~i~ WELL DATA Target'1'VD (F-r) Target Coord. N/S Slot Coord. N/S -46.74 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. EJW Slot Coord. E/W -704.62 Magn. Declination 26.860 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: lOOffr~ 30mE~ 10m~ Vert. Sec. Azim. 312.75 Magn. to Map Corr. 26.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'T) (F~ (FT) (FI') (Per lOO F'r)Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT , 04-AUG-98 MWD 108.00 0.00 0.00 108,00 108.00 0.00 0.00 0,00 0.00 0.00 8" M1 C 1.4 DEG AKO .., 04-AUG-98 MWD 134.40 0.62 150.03 26.40 134.40 -0.14 -0.12 0.07 2.35 2.35 ..... 04-AUG-98 MWD 221.46 0.74 184.24 87.06 221.45 -0.94 -1.09 0.27 0.48 0.14 04-AUG-98 MWD 311.92 0.70 176.10 90.46 311.91 -1.70 -2.23 0.26 0.12 -0.O4 04-AUG-98.... MWD 401.06 0.72 166.56 89.14 401.04 -2.56 -3.31 0.43 0.13 0.02 ~'~ r~ I ~ I I~1 ~ o. 8 o.o U 11.31 I I/' L ,.~ 04-AUG-98 MWD 582.79 2.01 336.74 91.88 582.75 -2.67 -3.54 0.37 3.04 1.34 04-AUG-98 MWD 673.43 4.93 339.55 90.64 673.21 2.26 1.57 -1.62 3.23 3.22 04-AUG-98 MW[3 763.97 6.89 330.08 90.54 763.27 10.92 9.93 -5.69 2.41 2.16 -10.46 04-AUG-98 MWD 852.99 8.65 333.07 89.02 851.47 22.29 20.52 -11.39 2.03 1.98 3.36 04-AUG-98 MWD 943.41 10.95 329.08 90.42 940.56 36.91 33.96 -18.88 2.65 2.54 -4.41 ,._ 04-AUG-98 MWD 1037.70 13.44 328.83 94.29 1032.72 56.04 51.02 -29.15 2.64 2.64 -0.27 ~'; 04-AUG-98 MWD 1117.00 15.53 326.65 79.30 1109.49 75.20 67.77 -39.76 2.72 2.64 -2.75 04-AUG-98 MWD 1208.10 18.26 325.26 91.1 0 1196.65 100.98 89.69 -54.60 3.03 3.00 -1.53 {:~ FT~ 04-AUG-98 MWD 1276.46 19.27 324.61 68.36 1261.38 122.47 107.69 -67.24 1.51 1.48 -0.95 ::3 04-AUG-98 MWD 1397.27 23.35 324.46 120.81 1373.91 165.44 143.44 -92.71 3.38 3.38 -0.12 o~ ~ 04-AUG-98 MWD 1490.81 25.59 323.45 93.54 1459.04 203.45 174.75 -115.52 2.44 2.39 -1.08 ~ ~ 04-AUG-98 MWD 1585.67 28.82 318.19 94.86 1543.41 246.36 208.27 -142.97 4.24 3.41 -5.55 5o 05-AUG-98 MWD 1684.63 31.22 317.47 98.96 1629.09 295.67 244.95 -176.22 2.45 2.43 -0.73 05-AUG-98 MWD 1780.38 33.85 314.78 95.75 1709.81 347.06 282.03 -211.93 3.13 2.75 -2.81 05-AUG-98 MWD 1877.26 38.08 313.93 96.88 1788.20 403.93 321.78 -252.62 4.40 4.37 -0.88 05-AUG-98 MWD 1968.60 41.08 313.85 91.34 1858.59 462.11 362.12 -294.55 3.28 3.28 -0.09 05-AUG-98 MWD 2063.78 43.74 314.58 95.18 1928.86 526.27 406.89 -340.55 2.84 2.79 0.77 · SURVEY CALCULATION AND FIELD WORKSHEET i ~1~=~I JobNo, 0450-99764 Sidetra(~kNo, __ Pacje 2 of 4 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/317 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~ilrr~~ WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord. N/S -46.74 Grid Correction 0.000 Depths Measured From: RKB ~] MSL~ SS~ Target Description Target Coord. E/W Slot Coord. EJW -704.62 Magn. Declination 26.860 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: lOOftr~ 30m[--] lOm~ Vert. Sec. Azim. 312.75 Magn. to Map Corr. 26.860 Map North to: OTHER SURVEY DATA Survey Sun/ey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~) (DD) (DD) (FT) (1=3') (F~ (F'~ (Per ~00 FT) Drop (-) Left (-) 05.AUG.98 MWD 2158.10 46.05 312.16 94.32 1995.68 592.82 452.57 -388.95 3.05 2.45 -2.57 05-AUG-98 MWD 2253.69 48.99 312.21 95.59 2060.23 663.31 499.91 -441.18 3.08 3.08 0.05 ...... 05-AUG-98 MWD 2344.95 52.25 312.10 91.26 2118.12 733.84 547.25 -493.47 3.57 3.57 -0.12 05-AUG-98 MWD 2439.29 55.01 310.85 94.34 2174.06 809.77 597.54 -550.39 3.11 2.93 -1.33 05-AUG-98 MWD 2534.30 57.03 311.68 95.01 2227.16 888.53 649.50 -609.60 2.25 2.13 0.87 05-AUG-98 MWD 2624.29 57.20 311.85 89.99 2276.02 964.08 699.84 -665.97 0.25 0.19 0.19 05-^UG-98 MWD 2650.51 57.10 312.43 26.22 2290.24 986.11 714.62 -682,30 1.90 -O.38 2.21 ..... 08-^UG-98 MWD 2705.94 57.25 311.92 55.43 2320.29 1032.69 745.89 -716.82 0.82 0.27 -0.92 4 3/4' MIXL 1.2 DEG AKO 08-^UG-98 MWD 2798.42 56.92 309.59 92.48 2370.55 1110.27 796.57 -775.62 2.14 -0.36 -2.52 08-AUG-98 MWD 2894.95 56.97 310.03 96.53 2423.20 1191.07 848.37 -837.77 0.39 0.05 0.46 08-^UG-98 MWD 2988.75 57.51 310.04 93.80 2473.95 1269.86 899.11 -898.17 0.58 0.58 0.01 08-^UG-98 MWD 3084.45 57.56 310.29 95.70 2525.32 1350.52 951.1 9 -959.87 0.23 0.05 0.26 08-AUG-98 MWD 3178.32 56.72 312.46 93.87 2576.26 1429.34 1003.29 -1019.04 2.14 -0.89 2.31 08-AUG-98 MWD 3272.04 56.64 314.47 93.72 2627.75 1507.64 1057.16 -1075.87 1.79 -0.09 2.14 , , 08-^UG-98 MWD 3366.90 56.60 313.48 94.86 2679.94 1586.83 1112.16 -1132.88 0.87 -0.04 -1.04 08-AUG-98 MWD 3459.26 56.66 312.68 92.36 2730.74 1663.96 1164.84 -1189.21 0.73 0.06 -0.87 08-AUG-98 MWD 3554.54 56.86 312.22 95.28 2782.97 1743.65 1218.63 -1248.01 0.46 0.21 -0.48 08-AUG-98 MWD 3649.59 57.45 312.17 95.05 2834.52 1823,50 1272.27 -1307.18 0.62 0.62 -0.05 08-AUG-98 MWD 3739.56 58.07 312.57 89.97 2882.52 1899.60 1323.55 -1363.40 0.79 0.69 0.44 08-AUG-98 MWD 3833.90 57.94 312.84 94.34 2932.50 1979.61 1377.81 -1422.19 0,28 -0.14 0,29 09-AUG-98 MWD 3935.05 58.10 313.13 101.15 2986.07 2065.41 1436.31 -1484.96 0.29 0.16 0.29 09-AUG-98 MWD 4026.38 57.88 311.97 91.33 3034.49 2142.85 1488.68 -1542.01 1.10 -0.24 -1.27 09-AUG-98 MWD 4119.53 57.87 313.54 93.15 3084,02 2221.73 1542.23 -1599.93 1.43 -0.01 1.69 - 09-^UG-98 MWD 4212.76 57.04 312.25 93.23 3134.18 2300.32 1595.73 -1657.50 1.47 -0.89 -1.38 i i ii i! i I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-99764 Sidetrack No. Page 3 'of 4 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD ' Well Name & No. TARN DRILLSITE 2N/317 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~'~lllrr~~ WELL DATA .. Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -46.74 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W -704.62 Magn. Declination 26.860 Calculation Method MINIMUM CURVATURE 'Target Direction ([39) Buil~Walk\DL per: 10Oft[~ 30m~ l Om~] Vert. Sec. Azim. 312.75 Magn. to Map Corr. 26.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DB) (FT) (FT) (F'D (F'I~ (Per 10o F-r)Drop (-) Left (-) .. 09-AUG-98 MWD 4307.38 57.14 311.51 94.62 3185.59 2379.74 1648.75 -1716.64 0.67 0.11 -0.78 09-AUG-98 MWD 4402.42 56.78 310.07 95.04 3237.41 2459.37 1700.80 -1776.96 1.33 -0.38 -1.52 09-AUG-98 MWD 4495.58 58.58 311.92 93.16 3287.22 2538.05 1752.45 -1836.36 2.56 1.93 1.99 09-AUG-98 MWD 4591.72 59.31 312.24 96.14 3336.81 2620.40 1807.65 -1897.49 0.81 0.76 0.33 09-AUG-98 MWD 4686.13 60.06 313.03 94.41 3384.47 2701.90 1862.85 -1957.45 1.07 0.79 0.84 09-AUG-98 MWD 4777.82 57.85 312.43 91.69 3431.75 2780.45 1916.15 -2015.14 2.47 -2.41 -0.65 -, 09-AUG-98 MWD 4863.07 58.03 313.11 85.25 3477.00 2852.70 1965.21 -2068.18 0.71 0.21 0.80 09-AUG-98 MWD 4962.39 57.99 313.94 99.32 3529.62 2936,93 2023.22 -2129.26 0.71 -0.04 0.84 .... 09-AUG-98 MWD 5057.73 57.58 313.42 95.34 3580.44 3017.58 2078.93 -2187.59 0.63 -0.43 -0.55 09-AUG-98 MWD 5152.03 57.38 313.10 94.30 3631.14 3097.09 2133.42 -2245.50 0.36 -0.21 -0.34 09-AUG-98 MWD 5248.04 56.47 313.97 96.01 3683.53 3177.53 2188.84 -2303.82 1.21 -0.95 0,91 09-AUG-98 MWD 5343.31 56.83 311.12 95.27 3735.92 3257.10 2242.64 -2362.45 2.53 0.38 -2.99 09-AUG-98 MWD 5437.74 57.53 310.80 94.43 3787.10 3336.42 2294.66 -2422.38 0.79 0.74 -0.34 ~l,f1 ., ._ 09-AUG-98 MWD 5535.14 56.91 309.59 97.40 3839.83 3418.22 2347.51 -2484.92 1.22 -0.64 -1.24 10-AUG-98 MWD 5629.54 56.45 310.04 94.40 3891.69 3497.00 2398.01 -2545.51 0.63 -0.49 0.48 10-AUG-98 MWD 5725.59 58.39 312.09 96.05 3943.41 3577.89 2451.19 -2606.52 2.70 2.02 2.13 ' 10-AUG-98 MWD 5818.38 58.93 312.67 92.79 3991.67 3657.14 2504.61 -2665.06 0.79 0.58 0.63 .... 10-AUG-98 MWD 5913.07 58.98 313.11 94.69 4040.50 3738.27 2559.82 -2724.50 0.40 0.05 0.46 10-AUG-98 MWD 6008.15 58.90 313.34 95.08 4089.56 3819.71 2615.60 -2783.85 0.22 -0.08 0.24 10-AUG-98 MWD 6102.54 59,04 313.51 94.39 4138.22 3900.59 2671.20 -2842.59 0.21 0.15 0.18 10-AUG-98 MWD 6196.77 59.09 313.64 94.23 4186.66 3981.41 2726.91 -2901.14 0.13 0.05 0.14 10-AUG-98 MWD 6287.56 58.78 313.83 90.79 4233.51 4059.16 2780.68 -2957.34 0.39 -0.34 0.21 10-AUG-98 MWD 6382.50 58.85 313.97 94.94 4282.67 4140.37 2837.00 -3015.86 0.15 0.07 0.15 10-AUG-98 MWD 6477.31 59.12 311.17 94.81 4331.53 4221.61 2891.95 -3075.69 2.55 0,28 -2.95 i · i ii iii __ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-99764 Sidetrack No, P~.go ~ -of ~1~'- [![e']; I =~L.1 Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/317 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -46.74 Grid Correction 0.000 Depths Measured From: RKB [~ MSLE~ SS~ Target Description Target Coord. F_.JW Slot Coord. E/W -704.62 Magn. Declination 26.860 Calculation Method M!N!MUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mE~ 10m0 Vert. Sec. Azim. 312.75 Magn. to Map Corr. 26.860 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (F-'~ (FT) (FT) (FT~ (Per 100 F'r)Drop (-) Left (-) 10-AUG-98 MWD 6570.93 59.59 311.97 93,62 4379,25 4302.14 2945.40 -3135.95 0.89 0.50 0.85 10-AU G-98 MWD 6665.31 59.40 311.91 94.38 4427,15 4383.45 2999.75 -3196,44 0.21 -0.20 -0.06 _. 10~AUG-98 MWD 6756.23 59.99 312.26 90.92 4473.03 4461.94 3052.36 -3254.69 0.73 0.65 0.38 .., 10-AUG-98 MWD 6849.79 60.09 311.04 93.56 4519.76 4542.98 3106.22 -3315.26 1.13 0.11 -1.30 10-AUG-98 MWD 6943.35 59.10 310.60 93.56 4567.11 4623.62 3158.97 -3376.32 1.13 -1.06 -0.47 10-AUG-98 MWD 7037.85 56.37 309.24 94.50 4617.55 4703.42 3210.25 -3437.59 3.13 -2.89 -1.44 10-^UG-98 MWD 7130.86 54.15 307.44 93.01 4670.55 4779.62 3257.67 -3497.52 2.87 -2.39 -1.94 11-^UG-98 MWD 7230.35 53.29 309.02 99.49 4729.43 4859.57 3307.30 -3560.52 1.54 -0.86 1.59 11-AUG-98 MWD 7324.27 51.42 309.16 93.92 4786.79 4933.78 3354.18 -3618.24 1.99 -1.99 0.15 ,, 11-AUG-98 MWD 7419.36 50.16 308.70 95.09 4846.90 5007.29 3400.48 -3675.55 1.38 -1,33 -0.48 ,,, 11 -AUG-98 MWD 7511.89 48.83 308.78 92.53 4907.00 5077.47 3444.51 -3730.43 1.44 -1.44 0.09 11 -AUG-98 MWD 7607.81 46.53 309.07 95.92 4971.57 5148.23 3489.06 -3785.60 2.41 -2.40 0.30 11-AUG-98 MWD 7700.15 44.39 309.48 92.34 5036.34 5213.92 3530.72 -3836.55 2.34 -2.32 0.44 11 -AUG-98 MWD 7791.58 44.57 310.40 91.43 5101.57 5277.91 ......... 3571.85 -3885.67 0.73 0.20 1.01 _o. ¢~,, ' 11 -AUG-98 MWD 7885.35 45.29 311.56 93.77 5167.96 5344.10 3615.28 -3935.66 1.16 0.77 1.24 C~° ~-I 11 -AUG-98 MWD 7978.29 45.65 310.65 92.94 5233.14 5410.32 3658.84 -3985.58 0.80 0.39 -0.98 o ~ - {' ~ · ~ o 11 -AUG-98 MWD 8072.57 46.32 311.22 94.28 5298,65 5478.09 3703.26 -4036.80 0.83 0,71 0.60 ~ -, 11 -AUG-98 MWD 8166.11 46.71 312.66 93.54 5363,02 5545,95 3748.62 -4087.28 1.19 0.42 1.54 o 11 -AUG-98 MWD 8256.84 46.70 312.05 90.73 5425,24 5611.98 3793.11 -4136.08 0.49 -0.01 -0,67 ~. 11-AUG-98 MWD 8354.55 46.67 310.81 97.71 5492.27 5683.05 3840.15 -4189,38 0.92 -0.03 -1.27 11-AUG-98 MWD 8416.48 46.33 311.1 7 61.93 5534.90 5727.96 3869.62 -4223.29 0.69 -0.55 0.58 , 11-AUG-98 MWD 8500.00 46.33 311.17 83.52 5592.57 5788.34 3909.39 -4268.77 0.00 0.00 0.00 Projected Data - NO SURVEY i i iai .._ ..... STATE OF ALASKA - .~- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Alter casing _ Repair well _ Change approved program __ Operation Shutdown m Re-enter suspended well _ Plugging __ Time extension _ Stimulate_ Pull tubing_ Variance m Perforate__ Other X Annular Iniection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 48' FNL, 705' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 1762' FNL, 703' FWL, Sec. 34, T10N, R7E, UM At effective depth At total depth 1419' FNL, 314' FWL, Sec. 34, T10N, R7E, UM 5. Type of Well: Development X Exploratory m Stratigraphic m Service 6. Datum elevation (DF or KB) 28' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-317 9. Permit number 98-143 10. APl number 50-103-20266 11. Field/Pool Kuparuk River/Tarn Oil Pool feet 12. Present well condition summary Total Depth: measured (approx) true vertical 8500' 5593' feet feet Plugs (measured) None Effective depth: measured (approx) true vertical 8387' 5515' feet Junk (measured) feet Casing Length Size Structural Conductor 80' 16" Surface 2666' 7.625" Intermediate Production 7593' 5.5" Liner 863' 3.5" Cemented Measured depth 9 cubic yards 108' 290 sx AS III & 2694' 240 sx Class G & 60 sx AS I 262 sx Class G 7621' 8484' True vertical depth 108' 2314' 4981' 5582' Perforation depth: measured 8002'-8042' true vertical 5250'-5277' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 7638' Packers and SSSV (type and measured depth) Baker CSR @ 7621' MD 13. Attachments Description summary of proposal __ Detailed operation program __ BOP sketch __ Contact Paul Mazzolini at 265-4603 with any questions. LOT test, surface cement details and casing detail sheets X 14. Estimated date for commencing operation September 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '--'~~ ,/V~~.,e-.~._.~ Title Kuparuk Team Leader oo ,ss,o Date ~11~, ,)~, Conditions of approval: Notify Commission so representative may witness I~',"~/¢ ~..~~ IAppr°val N°~'~¢~~/I Plug integrity_ BOP Test Location clearance __ I Mechanical Integrity Test_ Subsequent-form require 10- ~G'~ ~>,¢rj- ~ r~ ,~,f..~ drl[jii~.i c,;~ ...... I ~,pproved by the order of the Commission David W, Johr~stor: Commissioner I Form 10-403 Rev 06/15/88 Approved Copy C'1, 1R~t~/~d SUBMi~ i-~ TRI~PI'~-CATE ARCO Alaska, Inc. Cementing Details Well Name: 2N 317 Report Date: 08~06~98 Report Number: 4 Rig Name: DOYON 141 AFC No.: AK9525 Field: Tam Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7-5/8" 9-7/8" nla 2688 2559 Centralizers State type used, intervals covered and spacing Comments: 42 Gemeco Bow string centralizers, placement on casing detail Mud Weight: PV(prior cond): PV(afler cond): I YP(prior cond): YP(after cond): Comments: 10.1 18 14I 19 11 Gels before: Gels after: Total Volume Circulated: 7/9 4/6 Wash 0 Type: Volume: Weight: Comments: Spacer 0 ]'ype: Volume: Weight: Comments: ARCO 30 bbls/30bbls 10.5/10.6 1st Stagel2nd Stage Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: ASIIII 70 45/245I 10.5 4.42 1st stagel2nd stage Additives: I Standard Blend Tail Cement O Type: I Mixwtrtemp: I No. of Sacks: Weight: I Yield: Comments: G 70 240/60 15.8/15.7 1.15/0.93 1st stage/2nd stage Additives: 1st stage tail is CIG wll%S1,0.2%D46,0.3%D65 and 2nd stage is Standard Arctic Set 1 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 5.6 to 8 bpm 5.5 to 8 bpm 1st stage/2nd stage Reciprocation length: Reciprocation speed: Str. Wt. Down: 20 15 fpm Theoretical Displacement: Actual Displacement: Str. Wt. in mud: Calculated top of cement: CP: Bumped plug: Floats held: Surface thru stage collar at 1420' Date:8/6/98 1st stage-no, 2nd Yes Time:1351 hrs stage-yes ~,emarks:lst stage: staged pumps up to 8 bpm & cond mud, pumped 5 bbls water, 30 bls 10.6 ppg spacer, 35 bbls lead plus 50 bbls tail cement. Displaced with 25 bbls. of wash-up water, 25 bbls. of mud, 32 bbls. of spacer and 35.5 bbls. of mud. Did not bump plug. 2nd stage: Dropped bomb and opened stage tool w/850 psi. Conditioned and circulated mud. Pumped 5bbls water, 30 bbls. 10.5 ppg spacer, 194 bbls. of lead, ~lus 10 bbls. tail cement. Displaced with 25 bbls. of wash-up water and 40 bbls. of mud. Full returns through out job, bumped plug with 2000 psi and closed stage tool. ClP at 1351 hrs. 8/6198. Cement Company: Rig Contractor: Approved By: DS DOYON Tom Brassfie d CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-317 Supervisor: M.C. HElM Date: 8/6/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.4 PP9 Hole Depth: 2,328' TVD LOT = 7 5/8", 29.7 ppf, L-80, BTC 2698 TMD EMW = 680 psi + 9.4 ppg EMW (0.052 x 2,328') = 15.0 ppg Fluid Pumped= 4.0bbl 2,317' TVD Leak-off Press. + MW 0.052 x TVD Pump output = 0.1000 bps Z300 p~ 2,200 psi Z000 psi 1,800 p~ 1,700 psi 1,500 psi 1,400 psi 1,300 I:~ ~ psi 700 6O0 500 p~ 4OO psi ~00 psi 20O 100 psi 0 psi J i J J J J J J I J J J J J J J J ] J J J J J L J J J J J J J J J J , J I ,,J J ,J J J J J ' J .... '15 ............................ I I ~' ~ LEAK-OFF TEST J ~CASING TEST J ..... '~'..'.. LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME J ) ~Ti ~F LIH~ J f ~ .......... i / 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 62 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 84 stk stk stl( stk stk stk stk stk stk stk stl( stk stk stk stk stk stk stk stk stk stk stk stk stl( stk stk stk stk stl( stk stk stk sti( stk s/k stk stk sti( sti( stk stk stl( stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .......................... .o...s.!.k..s. ............ ..o2.sJ ...... ........................... ~..s.t..k..s. ........... §.o..p.?j ..... .......................... .4...s.!.k._s. .......... ~.O..p_.s.i ..... ........................... ~..~.!.k.~ .......... ~.0._p.~] .... .......................... ~....!.k.~ .......... §~.o..p_~] ..... ......................... ~_.O...s.!.k.?. ........ ~.o..p_.sj ..... ......................... ~.~.?.!.k..s. ........ .4.~.o..p..sj ..... ........................... .~..4...~.t..k_~ ........ .4.~.o_.p.~! ..... .......................... )..6...~.!.k_.~_ ........ .4.~.o..p.~] ..... ......................... )_.8...s.!.k..s. ......... §.o..o..p..sj ..... ......................... ~_o.._~.t..k.~ ........ §j.o..p.~! ..... .......................... .4..o...~_t..k.~ .......... §.o..o..p.~] ..... I ~HUT IN TIMEt SHUT IN PRESSURE ..... ~i:~'-~-~ .... ~i .................... ~ ..... ~-a-~-~.~.i ..... ..... ~-:~--~,-r~ .... T .................... I .... '~:~ii-i;~;i ..... ...... ~:~'~T~'"'T .................... j .... '~'~'"~i .... ..... .4.:g...m..i.n. ............................... ~.4_.o_.[,..sj .... 5.0 min .............................................. ~.o..~.sj .... ..... .6..g...m. ].n. .............................. .2..2..0..p..s.] .... j 7.0 min ..... .2..2..0..p..s.] ..... ..... .9...o...m.?......L ......................... ~.o..p.~! .... ..... ~..o.-.o...m.L.n_ ............................. ~.o..o..p.~.i .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks 0 psi [ I stks ! 130 p_si 2 stks 340 Esi 4 stks 930 psi l .................... · .................... .~ ......................~ 5 stks 1,140 Esi ........................... .6...s.!.k..s. ......... j,~.o..R.s.L.,j ........................... .7. ._s. !.k_ .s_ ......... .1..,~.o_.p__s.L_! 8 stks 1,770 p_si l ........................... '~i'~;i'~ ......... ..................... ~ ........................................ I SHUT IN TIME SHUT IN PRESSURE ..... i~:~'B'B' .... [ .................... !'"'~,','6:iib'i~F" ..... '~"i~'i~[F,' .... l .................... i'"~;iJ~iii'";i'" ..... .e.:.o...m..i..n. ......................... !...],.O.].o_.RR!_..' 3.0 min i 2,010 Esi ..... :,i:i:r~-r~f .... I .................... 1---~;iiiiii-i:;~;r-' ..... §:iF~B' .... [ .................... '~- ",'"~;i:iiJii'~i'-' ..... i~:~'~iF,' .... [ .................... ..... 7;6'~i'B' .... [ .................... 9.0 min i 1,980 p. si .... -~-~:i~-~-i,:,'"-[ .................... l'":i;~ii'i:;;i'" .... ~i~:~'ii.,-i,~---'l .................... 1-'-~';~i~ii-i;;i--' .... .3..O.:.O_..m..i..n. ........................ j ....1. :.9..6..0.. p..s.L., NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company Casing Detail 7-5/8" Surface Casing WELL: TARN 2N-313 DATE: 8/4/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to LR= 29.10 29.10 7 5/8" Landing Joint 34' OA. 29.10 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.65 29.10 32-63 7 5/8", 29.7#, L-80 BTC-MOD 1346.74 31.75 Jt #31 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 41.15 1378.49 Gemeco 7 5/8" Stage Collar (BAKERLOK) 2.78 1419.64 Jr. #30 7 5/8", 29.7#, L-80 BTC-M©D (Thread Locked Collar) 42.97 1422.42 jts. 3-29 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top of jr #3, BAKE 1141.07 1465.39 Gemeco Float Collar 1.30 2606.46 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 85.05 2607.76 Gemeco Float Shoe 1.48 2692.81 2694.29 Insert baffle @ 2559.22 42 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, over stop collars every collar thru Jt. # 15=every 3rd collar to surface. 1 above & 1 below stage collar. Remarks: String Weights with Blocks: 80K# Up, 70K# Dn, 12k# Blocks. Ran 63 oints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: M, C. HElM TONY KNOWLES, GOVERNOR ALAS~ OIL AND GAS CONSERVATION COMMISSION Juh' 29. 1998 3001 PORCUPINE DRIVE ,'-NCH©RAGE, ALASKA 99501-3192 .~H©NE: .,'907) 279-1433 1907) 276-7542 Paul Mazzolini Tarn Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage. AK 99510-0360 Re' Kuparuk River Unit 2N-317 ARCO Alaska. Inc. Permit No. 98-143 Sur. Loc. 47'FNL, 705'FEL. Sec. 3, T9N, R7E, UM Btmnhole Loc. 1410'FNL. 331'FWL, Sec. 34. TION, R7E, UM Dcar Mr. Mazzolini: Enclosed is thc approvcd application for permit to drill thc above rcfcrcnccd welt. ,Annular disposal of drilling waste down the well No. 2N-317 is contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrity Tcst (FIT). Please note that any disposal of fluids gcncratcd from this drilling operation which are pumped down the surfacc/production casing annulus ora permittcd cxisting xvcll on Drill Sitc 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling xvastc in a volume greater than 35.000 barrels through thc annular spacc of a single xx'ell or for a period longer than one year. Thc pcrmit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd by law from other governmental agcncics, and docs not authorize conducting drilling operations until all other rcqu~rcd pcrmittlng dctcrminations arc made. Bloxvout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must bc given to alloxv a rcprcscntativc of the Commission to xvitncss a test of BOPE installcd prior to drilling ncw holc. Notmc may be given by contacting the Commission pctrolcum field inspcctor on thc North Slopc pager at 659-3607. Robert N. Christenson, P.E. Commissioner BY ORDER OF THE COMMISSION dlf/Enclosurcs Dcpartmcnt of Fish &Gamc, Habitat Scction xx-/o cncl. Department of Environmental Conservation v~';o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory F~ StratigraphicTest F~ Development Oil X Re-Entry Deepen Service O Development Gas D SingleZone X Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 47' FNL, 705' FEL, Sec. 3, TgN, RTE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1627' FNL, 573' FWL, Sec. 34, T10N, R7E, UM 2N-317 #U-630610 At total depth 9. Approximate spud date Amount 1410' FNL, 331' FWL, Sec. 34, T10N, RTE, UM 7/28/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-329 8493' MD 331' @ TD feet 179' @ 400' feet 2560 5590' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 600' feet Maximum hole angle 58.05° Maximum surface 1357 psig At total depth 2300 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' __.200 CF 9.875" 7.625" 29.7# L-80 BTC MO£ 2638' 28' 28' 2666' 2300' 1.40 sx ASlII, 240 sx Class G 2. 240 sx ASlII, 60 sx AS I 6.75" 5.5" 15.5# L-80 LTC-M 7638' 28' 28' 7666' 5006' 260 sx Class G 6.75" 3.5" 9.3# L-80 8RD EUE 827' 7666' 5006' 8493' 5590' (included above) RECEIVED 19. To be completed for Redrill, Re-entry, and Deepen Operations. "- -- Present well condition summary Total depth: measured feet Plugs (measured) J U L true vertical feet Effective depth: measured feet Junk (measured) '_~¢ 0il & Gas Cons. (;0mm~sst0n true vertical feet ~J'lCh0rage casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Perforati~inn~repth: measured true vertical 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~~.~/'~o.-~.~ Title Tarn Drilling Team Leader Date Commission Use Only Permit Number I APl number J Approva, date ~.~ J See cover letter for ~'~"",,/,~'/..~ 50-,,/oj~ ---- ~ o ~ ~'~. '~/'" f'6 other requirements Conditions of approval Samples required r- Yes J~l No Mud log required [-- Yes ~ No Hydrogen sulfidemeasures ~-~Yes ~No Directional surveyrequired ~,Yes ~ No .equ,re. work,. press..e or.O.. E] [Xl WI Other: by order of ~T'c-'~?" ~Ii2~ ~~¢$; ORIGINAL SJGNl~j3FpT~sioner commission Date Approved by the Form 10-401 Rev. 7-24-89 Robert N. Chdstenson Submit in triplicate 2N WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB permafrost i:i:i:i:i: ':':':':': ..... .......... Stage i:i:i:i:i: ..... ......-... ':':':',': ..... Top of West Sak :::::::: ::i:::: :::: 1,256' MD Base of West Sak 2,162' MD 7-5/8" Surface Casing at 2,666' MD Top of Cement at 7,100' MD 5-1/2" Production Casing at 7,666' MD 3-1/2" Production Casing at 8,493' MD ':'X':.: :.:-:.:.:,: :.:-:-:.: :.:,:.:.:. :::::::;::: .-........ ,:.:.:-:.: ,,,,..-... ,.-.-...-, '.'.:.:.:. ......- ......-... ......-... ::i!::!::i:::::: '-7/8" Hole :::::.':::: ......... 6-3/4" Hole Conductor Casing Size I Hole Size 16' in 20' hole Depth: 135' MDRKB Top of Cement Surface Excess Calculated: 100% ~/olume Calculations: (135 If) (0.7854 cf/If) (2.00) = 212 cf (212 cf) ~(0.93 cf/sx) = 230 sx SlurryVolume:212 cf or Arctic Set I 230 sx Slurry Weight 15.7 ppg rounded Slumj Yield 0.93 cf/sx Surface Casing excess 7-5/8" in 9-718" hole Stage 1: Volume (442 If) (0.2148 cf/If) (1.45) = 138 cf Lead (138 cf) /(4.42 cf/sx) = 31 sx Tail (800 If) (0.2148 cf/If) (1.45) = 249 cf shoe joint vo121 cf+ (249cf) /(1.15cf/sx) = 237sx System: Lead (Amfic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI.,_) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Cl G crnt + 1% SI(CaCI2) + 0.3% 1365 (disp.) + 0.2% D46 (defoam.) Lead Slurry Volume: 138 cf or 40 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 249 cf or 240 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.15 cf/sx Thickening Time 3.5 - 4.5 hours Surface Casing excess Stage 2: Vol. Lead (1,20910 (O.2148cf/lf) (4.00)= 1,039cf (65 If) (0.2148 cf/If) (1.45) = 20 cf (1,059 cf) 1(4.42 cf/sx) = 240 sx Tail (0 If) (0.2148 cf/If) (4.00) = 0 cf (150 If) (0.2148 cf/Io (1.45) = 47 cf (47 ct') ~(0.93 cf/sx) = 50 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,059 cf or 240 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 47 cf or 60 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size I Hole Size 5-112" and 3-112" in 6-314" hole Depth: 8,493' Top of 3-112" casing 7,666' Top of Cement 7,100' Excess Calculated:50% BHT (Static):1600 F 130° F BHT (Circ): excess Volume around 5-1/2" (566 If) (0.0835 cf/If) (1.50) = 71 cf Volume around 3-1/2" (827 If) (0.1817 cf/If) (1.50) = 225 cf 296 cf shoe joint vol 4 cf + (296 cf) /(1.20 cf/sx) = 250 sx System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 gps D47 (defoam.) + 3% D53 (Gyp) + 0.8% D65 (disp) + 0.12% DS00 (ret.) Slurry Volume: 296 cf or260 sx Slurry Weight 15.8 ppg Class G Slurry Yield 1.20 cf/sx Thickening Time 3.5 - 4.5 hours 7/1 7/98 ~ ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 317 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. 4. Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. ~ 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). . Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. '- ~ ARCO Alaska, Inc. L.~ DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 317 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +_10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System' Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: ARCO Alaska, Inc. The nearest well to 2N 317 is 2N 329. The wells are 179' from each other at a depth of 400'. Drillinq Area Risks: The primary risk in the 2N 317 drilling area is_~shallow gas below the permafrost. Therefore the surface hole will need to be drilled With weighted mud (~.8- 10.2 PEg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 317 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. ~_e. request that .2..N 317 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regUlation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline 214,4" 2,000 psi WP DRILLING SPOOL w/16" Outlet I , 21~" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT F--j MANUAL GATE V KILL LINE L 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / / BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE ~~T~~ raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams 400 ~qO 800 1200 1600 -I-- ~ 2000 ¢' -4-- ~ 2400 0 2800 ~. 5200 I-'- 3600 I v 4000 4400 C,eeted ~y f;.,~ For: BRASSFIELD Dote Catted : 16-Jut-Off Plot .Reference ~$ 517 Version ~'~, Coerdinctes 6re ;n feet reference slot ~317. True Ve~ic~l Oeoths~ore relerence RK8 (Ooyon 141). 312.75 AZIMUTH 5451' (TO TARGET) lAP, co aska, in ............ JStructure : Tarn Drill Site 2N Well : 517 JField : Tarn Development Field Location : North Slope, AlaskaJ <- West (feet) 4400 4000 5600 3200 2800 2400 2000 1600 1200 800 400 0 400 I ! I I I I I I I I I I I II I I I ! II ' I Ii ' 4400 TARGET LOCATION: [ 1627' FNL, 573' P¢,'L SEC. 34, TI ON, R7E TARGET TVD=5266 TMD=8034 DEP=5451 k 4000 - 3600 iL 3200 TO LOCATION: 1410' FNL, 331' ~VL SEC. 34, TI ON, R7E RKB ELEVATION: 149' NORTH 3670 WEST 4005 ['yi~l~O - Casing Pt ~%~X C35C35 ~'%/-'",,T2 - Base Bermuda (%,, /TARGET - Mid Bermuda ~..~314- Top Bermuda %%~ Angle 0rap Orop ",,%C40 KOP TVD=600 TMD=600 DEP=0 i S.CO 6.00 9.00 DLS: 3.00 deg per 100 ft ~2~~ ~ ~I~ION TURN TO TARGET TVD=1094 TMD=1100 BEP=62 17.81 B/ PERMAFROST TVB=1199 TMD=1209 DEP=92 20.67 T/ W SAK SNDS '1-VB=1245 TMD=1256 DEP=107 3.57 6.49 9.4-2 DLS: 5.00 deg per 100 ft 2.56 5.32 24 '~7.18 B/ W SAK SNDS TVD=1999 TMD=2162 DEP=58g '~ 3 EOC TVD=2247 TMD=2565 DEP=907 7 5/8" CSG PT TVD=2500 TMD=2666 0EP=992 C80 TVD=2¢90 TM0=3025 0EP=1297 MAXIMUM ANGLE 58.05 DEG C50 TV0=3766 TMD=5456 0EP=3343 C40 TVD=3965 TMD=5813 0EP=3662 2800 , 2400 I 1 2000 L ~16oo 1200 · ~%_~7 5/8 Cosir, g ~- 800 Bose West Sok SondsX~ i ~ 400 Too L~es'~ S_ck Sc~dsX ~- ~, c?ost.',~% i 8eg~n Turf.. to TcrgetA-~o ,L 0 L 400 I SURFACE LOCATION: 4.7' FNL, 705' FEL SEC. 5, TgN, R7E BEGIN ANGLE DROP TVD=4600 TMD=7013 OEP=4681 56.32 52.32 DLS: 2.00 deg per 100 ft 4800 48..32 END ANGLE DROP TVD=5006 TMD=7666 DEP=51 T4 TVO=504.6 TMD=7725 OEP=5231 T3 - T/BERMUDA TVD=5147 TMD=7866 DEP=5332 52oo TARGET - MI9 BERMUDA TVD=5~66 TM9=8034 I)EP=5451 __%___ T2 - B/BERMUDA WO=5585 TMD=820.~r'~r~'~ _~uEP=~570 %,,. c~5 TVO=~44.~ T~D=S29~ OEP=~6;'- ', ~600J TARGET ANGLE 45 DEG 6000 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 .5200 56~0 6000 Vet-riehl Secfion (feet') -> Azimufh ~12.75 with reference 0.00 N, 0.00 E from slof #317 Creo,e~ ~ f~o. For: BRASSFIELD Dote plotted : 16-Jul-98 Plot Reference ;9 31'/ Version t3. Coordinates ere ;n feet reference slot ~317, True Ver[ical Depths ere reference RKB (0oyon 141). tNTE~ ARCO A!askawl inc] Structure : Tarn Drill Site 2N 11 : 317 Field : Tarn Oeveopmenf Fied Location : North Slope, Alaska. 32O 300 28O 260 240 220 200 <- West (feet) 260 240 220 200 180 160 140 120 100 80 60 20 0 40 I I ! I I I t I I I I I I I I I I I I t I I I , "'.. '".~ 2400 "'.. '"~ 1200 ',,,., %,,,700'..,.. "'~ 1200 '",, 1200'.~ "... 2300%.. "... '..... '"'. ""A 1 600 '".. ".. "".. '"'.. '"'.. '".. 1100 '.. '-. 220¢~ '.. 110~'~ '".. '".. ". · ,. 1500 ",, 4O '; 1600 , ', , · , · · 2O 1300 '~ 1500 · · , 100 '.. '.. ".. 12O0 .. '~ 1 400 · 60 j .320 ~- 300 280 [ 260 240 220 200 180 ". 180 "... '"-. .... .. .~ 1000 ... L "'. '"'. 2106"~ '"'. '" " 160 ".. '"" "" ' ' ' !. "". ', ~ 300 i- ~° "... 1300 '... . '... ".~ 1000 .. 140 '",, '".. ',. ",. ', " 2000". '" ',,, '\ goo 120 i'b8 1200 '"... '".. "... '.. ".. ',. 1200, '.. '.,k 900 '. .. J "',, ,,~ 1300 '",, ',, ' ""--,, '"'-,, ~';,.'",, , ~;'~,"'.., '",, ~ ",. "-, ~ '-, ",, ',,',, ", ~ ",,. "-,. ",. ',, ",, ",, ", 8oo ~ ! ~ "-. '% 1:,oo ", ", ", ", ',, I- " ' " 1 ' ' ' 1 -. -.. '.. ., 200 ". ". '.. i ~ ~~ ooo ....,. ", ",, i8ob, ,,,soo ',, F L~.......... '"'""~ 9 O0 ""-. '"-. 80;"", '", '", '", '", -. '. '. .. .. '. '. '~ /uu j --..,...,,... ,oo-,...-,::,,.,.. ',,,,,, ,,,,, 1,o<,",.,,,oo ',,,,,, ~ '"-. 1,300 ~ 800 '"' '"' 70;" "' '", '". '", 600 1 ~.. '-.. ~ ". '% 900 ' "k lOOn ', ', · '--....... '-..... ~ ~;.~..-...,. ',.,, .,, ~ ,~oo',,,, "....~oo ",., "'-.. "'-~ ~- ~ 700 ". ".. 800 60C{'" %, 90 15uu~, ",~ 500 '¢," F ~ .... "'"'"'"... 9 O0 '"'""-.x 1100 ~ 700%'-. "'-. _Tna '". '", 800 1400'~ 50(~.. ~C5'...[ ~uu -.... %._. ,~ '%. 600 '-.. ',~ -,,,. ~'~ ,, ............... ...1000 "'"'"'-...800 '"'"'"-. 1000 "'~500 600~,,,. ,.,%60;uu ,,,~) "~ ~)500_~,. ..... . '-,,.. %,, '-. '% 500 .~' ............ .o.o '%, ~ ........ ~---.~oo" ....... .~oo"--... ~oo e --, ..... _,.~.o.o. ....... ..,. ~oo %5oo_¢. "'e~°°e I i i ? i i i i i i I i i i i i i i i i i I [ i 260 240 220 2(~0 180 1 ~0 140 120 1 O0 8'0 6'0 40 2'0 0 2'0 4~0 60 <- Wesf (feel) 100 - 80 Z 140 0 i 20 ~ ---I- i CO ~ 8O 6O 40 20 0 20 ARco Alaska , Alaska Cocrd,notes are ;n ~eet reference slot ~317. JTrue Vedical Oept~s ~re re~erence RKB {Doy~ ~1). 960 g20 88O 840 <- West (feet) 800 760 720 680 64.0 600 560 520 480 4,4.0 400 560 320 280 240 200 800 760 I I I I I I I I I I t I 700 · ",, "~.'q 700 720 3206'-:?',., 680 i .. . 51 O0 ','... ',. '.~ 2000 "-, "x 2200 30OO"*,'... "-. 6oo '"".. 1 '% "" ..%. 600 %. -.., _C: "::::~i'"~"",, % 560 ~ 0 296'~'k- '". '~, 1700 · · 180 960 ,, . '~ 2300 ,, ,, "',, 2000 g20 " ', 880 ~ 2200 ~- 840 80O ', \ "~, x , ~ 760 '""~ 1600 21 O0 ',, 720 ',, x "5 ~ 640 ,,,, , 2OOO ~ 6C0 ' 1500 , ,~ i 600 ,, Z 520 "'- 1900 "-.~"'-.:"-. "',, ", k 520 I~,.. '"',., ~'a;~-:::-,.. '"" " 480 1 ""-.. 1600 "". 1 50~" '"""'" "" " k 480 .... .... .... -...-... ',,. ,,. ~¢ook I "'-.., '"-., "-. '":~=, 2000 ",, ',., 440 ~ "-.. "-. ~,,oo -%. ", ",-. L ,.~o t "-.... "....1800 '..... '%. -~ 1400 ("~'~ I ' 400 -[,..>.. ""... "'.. "-.. '%,, 2600 "',, h 40o . ~t..~.~. '""-. '"'. 1400'%-1900~'"".'. '"', ~o J~~oo "'"- '""- ~7oo '"', "% '", L ~o '~ '""~- '"-. 1500 %. ,.,. ,.¥. ,,, ~ '-.... ',.., ',., '-,'-.. ~oo ~ ;oo", '"'--....... ""-,,...,, 280 ~ "~-._ '"',C.' - - '-. "- ' ' k.~.._ ' ..... _..2100 ~ "-,, 1400 "-, '" i i f i i i i i i i i i i i i i i i i i i i i i 800 760 720 680 640 600 580 520 480 440 400 360 320 280 240 200 160 <- Wesf (feel) For: HRASSFIELD Dote plotted : 16-Jul-98 Plot Reference ;s .317 Version Cocrdinotes [3re ~n feet reference Slot ~17. True Verticcl Oe~ths ore reference RgB (Doyon 141). 0 Alaska, In IStructure : Tarn Drill Site 2N Well : 517 Field : Tarn Development Field Location : North Slope. Alaska 1320 1280 1240 1200 1000 960 920 <- West (feet) 1160 1120 1080 1040 1000 960 920 880 840 800 760 720 680 640 600 560 I I I ! I I I I I I I I I I I I I I ! f I ~ I I I I I ~ I i 160 J ~, ",,,,,% 2000 1120 ~,, '""-., '"",, 390(}""., "", "'-, 1080 '",. ",,~_~o !040 3800 % ',, ". ""'.. '"".""., 1 900 3700 '%. "'. "', '""., 2200 ~6oo'",,, ,..:$~oo 880 '"'. 3500"% '%,-, ",. ",. '~,~ 1800 840 '"-,, 340~",.-.. ~ 2400 800 J '"-.. ~ ~ o'6'-.,""",',',, 760 72O 680 ,., 8oo · 640 6OO '"',, 2100 ",. ",~'-. "-,,...,... 1%3-::;-.. 320(~'~,",.",. · '" '" 20O0 "'-, 1700 ~ 2000 ! 320 ' I ', F 1280 / 1240 ~ 1200 i 1900 i -108C L · ', i 1040 920 700',% , r 1 ~ 80C ~ 72C F 68o 3 ~ OG-;;. '-. %. '"-, [ x'Nj'",. 2200 ~ 5000~ '"~/ '~[ 600 i i i i i i i I i i i i i I I i I I i i i i i i i i t i i i i 1160 1120 1080 104-0 1000 960 920 880 840 800 760 720 680 64-0 600 560 <- West (feet) [A' RCO Alaska, J rn I Location : North Slope, WELL PROFILE DATA ..... Point ..... MD ~nc Oir TVa Nor~ East V. Sec[ ~e on O.CO O.00 O.O0 O.CO 0.00 O.OO O.CO o.oa ,, ~eg[n Turn TO T~rge[ It00.CO 15.00 350.00109~-.3t55.36 -52.54 62.15 3.00 905.69 3.00 [nd of E]uild/Tum 2555.30 58.'g5311.882246.7666,5.82 -619.28 2.00 Er~d cf Ho!d 7013.41 58.05 3t 1.88 46(~0.41 3185.71 -342§.274680.65 o.aa --.nd Of Orcp/Turn 7666.05 45.00 311.865005.583526.08 -38(~8.B6 51go. 4~- Target 2N-O (I) R'~d ! 8034.35 45.(]0311.865266.805699.93 -~A302.76 5450.83 o.ooj End of Held 8293.15 45.(~0311.885449.CO3822.10 -4139.015633.81 O.OO T.O. &' ~.~d '~f Hc~d 84.g3.1545.00 3l t.aB 5590.4'2 3916.51 --4'244.,'J0 5775.22 O.OO 55O 34O % -. ~soo 320 TRUE NORTH 0 10 2O 5OO 300 2go C,eote,~ b~, ,'i,,chFor: BEASSFIELD Dote platted : ~8-Jul-g8 PIot Reference ;s .]17 Version ~5. Ca~rdin~tes ore in feet reference slot ~317. True Ve~[c~t Deot~s ~re reference RKB (Do,on 141~. 40 ,,'DU / 70 280 270 26O 25O 5O0 80 go iD0 1i0 240 120 230 "~" / ,, / ./2100 ,' 210 2OO 150 500 "-. ~30 Normal Plane Travelling Cylinder- Feet 160 190 180 170 All depths shown ore Measured dept:hs on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2N 317 slot #317 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 317 Version #3 Our ref : prop2841 License : Date printed : 16-Jul-98 Date created : 24-Feb-98 Last revised : 13-Jul-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 13.495,w150 18 53.185 Slot Grid coordinates are N 5911960.166, E 460888.537 Slot local coordinates are 46.74 S 704.62 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-8239'>,,339,Tarn Drill Site 2N PMSS <O-9690'>,,329,TarnDri11 Site 2N PMSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-???>,,337A,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <O-9631'>,,343,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <0 - ???>,,345,TarnDrill Site 2N PMSS < 0 - 7650>,,Tarn#2,TARN #2 PMSS < 2250 - 7162'>,,3A, TARN #3 PMSS < 0 - 6150'>,,TARN#4,TARN #4 Closest approach with 3-D Minimum Distance Last revised Distance M.D. Diverging from M.D. 1-Jun-98 327.7 300.0 300.0 2S-May-98 179.1 400.0 400.0 18-Jun-98 299.4 300.0 300.0 19-Jun-98 299.4 300.0 300.0 28-May-98 90.1 0.0 0.0 28-May-98 389.3 300.0 300.0 15-Jul-98 360.4 100.0 100.0 16-Jul-98 419.9 100.0 100.0 14-Aug-97 11739.0 7533.3 7533.3 13-Jul-98 2323.1 7723.2 8529.3 12-Aug-97 6568.2 625.0 625.0 method ARCO Alaska, Inc. Tarn Drill Site 2N 317 slot #317 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 317 Version #3 Our ref : prop2841 License : Date printed : 16-Jul-98 Date created : 24-Feb-98 Last revised : 16-Jul-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is nT0 10 13.495,w150 18 53.185 Slot Grid coordinates are N 5911960.166, E 460888.537 Slot local coordinates are 46.74 S 704.62 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North A~RCO Alaska, Inc. Tarn Drill Site 2N,317 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 100.00 0.00 330.00 100.00 0.00 N 0.00 200.00 0.00 330.00 200.00 0.00 N 0.00 300.00 0.00 330.00 300.00 0.00 N 0.00 400.00 0.00 330.00 400.00 0.00 N 0.00 500.00 0.00 330.00 500.00 0.00 N 0.00 600.00 0.00 330.00 600.00 0.00 N 0.00 700.00 3.00 330.00 699.95 2.27 N 1.31 800.00 6.00 330.00 799.63 9.06 N 5.23 900.00 9.00 330.00 898.77 20.36 N 11.76 1000.00 12.00 330.00 997.08 36.14 N 20.87 1100.00 15.00 330.00 1094.31 56.36 N 32.54 1200.00 17.81 326.27 1190.23 80.29 N 47.50 1209.22 18.07 325.98 1199.00 82.65 N 49.09 1255.68 19.40 324.65 1243.00 94.92 N 57.58 PROPOSAL LISTING Page 1 Your ref : 317 Version #3 Last revised : 16-Jul-98 Dogleg Vert Deg/100ft Sect E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 E 0.00 0.00 W 3.00 2.50 W 3.00 9.99 W 3.00 22.46 KOP W 3.00 39.86 W 3.00 62.15 Begin Turn to Target W 3.00 89.38 W 3.00 92.15 Base Permafrost W 3.00 106.71 Top West Sak Sands 1300.00 20.67 323.54 1284.64 107.21 N 66.49 W 3.00 121.60 1400.00 23.57 321.45 1377.27 137.05 N 89.45 W 3.00 158.71 1500.00 26.49 319.79 1467.87 169.72 N 116.31 W 3.00 200.61 1600.00 29.42 318.45 1556.19 205.14 N 147.00 W 3.00 247.19 1700.00 32.36 317.32 1642.00 243.20 N 181.44 W 3.00 298.32 1800.00 35.32 316.37 17~5.05 283.81 N 219.53 W 3.00 353.86 1900.00 38.27 315.55 1805.12 326.85 N 261.18 W 3.00 413.65 2000.00 41.24 314.82 1881.99 372.20 N 306.25 W 3.00 477.54 2100.00 44.21 314.18 1955.44 419.75 N 354.64 W 3.00 545.35 2161.73 46.04 313.82 1999.00 450.14 N 386.11 W 3.00 589.08 2200.00 47.18 313.61 2025.29 469.35 N 406.21 W 3.00 616.89 2300.00 50.15 313.08 2091.32 520.88 N 460.82 W 3.00 691.96 2400.00 53.13 312.60 2153.38 574.19 N 518.31 ~ 3.00 770.36 2500.00 56.11 312.16 2211.27 629.13 N 578.53 W 3.00 851.88 2565.30 58.05 311.88 2246.76 665.82 N 619.26 W 3.00 906.69 Base West Sak Sands EOC 2665.92 58.05 311.88 2300.00 722.82 N 682.82 W 0.00 992.06 7 5/8" Casing Pt 3000.00 58.05 311.88 2476.77 912.08 N 893.87 W 0.00 1275.51 3025.00 58.05 311.88 2490.00 926.24 N 909.66 W 0.00 1296.72 C80 3500.00 58.05 311.88 2741.34 1195.34 N 1209.74 W 0.00 1699.73 4000.00 58.05 311.88 3005.91 1478.59 N 1525.60 W 0.00 2123.95 4500.00 58.05 311.88 3270.48 1761.84 N 1841.47 W 0.00 2548.17 5000.00 58.05 311.88 3535.04 2045.10 N 2157.33 W 0.00 2972.39 5436.48 58.05 311.88 3766.00 2292.36 N 2433.07 W 0.00 3342.72 C50 5500.00 58.05 311.88 3799.61 2328.35 N 2473.2~ W 0.00 3396.61 5812.56 58.05 311.88 3965.00 2505.42 N 2670.6~ W 0.00 3661.80 C40 6000.00 58.05 311.88 4064.18 2611.60 N 2789.07 W 0.00 3820.83 6500.00 58.05 311.88 4328.75 2894.86 N 3104.93 W 0.00 4245.05 7000.00 58.05 311.88 4593.32 3178.11 N 3420.80 W 0.00 4669.27 7013.41 58.05 311.88 4600.41 3185.71 N 3429.27 W 0.00 4680.65 7100.00 56.32 311.88 4647.33 3234.29 N 3483.45 W 2.00 4753.41 7200.00 54.32 311.88 4704.23 3289.19 N 3544.67 W 2.00 4835.64 7272.08 52.88 311.88 4747.00 3327.92 N 3587.86 W 2.00 4893.65 7300.00 52.32 311.88 4763.96 3342.73 N 3604.38 W 2.00 4915.82 7400.00 50.32 311.88 4826.45 3394.84 N 3662.50 W 2.00 4993.88 7500.00 48.32 311.88 4891.63 3445.47 N 3718.96 W 2.00 5069.70 Begin Angle Drop Iceberg Intez-val All data is in feet unless otherwise stated. Coordinates from slot #317 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Total Dogleg for wellpath is 72.01 degrees. Vertical section is from wellhead on azimuth 312.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 317 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A Depth Degrees Degrees Depth C O 0 R D I N A T E 7600.00 46.32 311.88 4959.41 3494.55 N 3773 7666.05 45.00 311.88 5005.58 3526.08 N 3808 7723.22 45.00 311.88 5046.00 3553.07 N 3838 7866.06 45.00 311.88 5147.00 3620.49 N 3914 8000.00 45.00 311.88 5241.71 3683.72 N 3984 PROPOSAL LISTING Page 2 Your ref : 317 Version #3 Last revised ~ 16-Jul-98 R Dogleg Vert S Deg/100ft Sect .69 W 2.00 5143.20 .86 W 2.00 5190.44 End Angle Drop .96 W 0.00 5230.86 T4 .16 W 0.00 5331.85 T3 - Top Bermuda .67 W 0.00 5426.55 8034.33 45.00 311.88 5265.99 3699.93 N 4002.75 W 8034.35 45.00 311.88 5266.00 3699.93 N 4002.76 W 8202.64 45.00 311.88 5385.00 3779.38 N 4091.36 W 8293.15 45.00 311.88 5449.00 3822.10 N 4139.01 W 8493.15 45.00 311.88 5590.42 3916.51 N 4244.30 W 0.00 5450.82 TARGET - Mid Bermuda 0.00 5450.83 2N-D (I) Rvsd 12-Jul-98 0.00 5569.82 T2 ~ Base Bermuda 0.00 5633.81 C35 0.00 5775.22 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #317 and TVD from RK~ (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Total Dogleg for wellpath is 72.01 degrees. Vertical section is from wellhead on azimuth 312.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,317 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 317 Version #3 Last revised : 16-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 600.00 600.00 0.00 N 0.00 E KOP 1100.00 1094 1209.22 1199 1255.68 1243 2161.73 1999 2565.30 2246 2665.92 2300 3025.00 2490 5436.48 3766 5812.56 3965 7013.41 4600 7272.08 4747 7666.05 5005 7723.22 5046 7866.06 5147 8034.33 5265 8034.35 5266 8202.64 5385 8293.15 5449 8493.15 5590 .31 56.36 N 32.54 W Begin Turn to Target .00 82.65 N 49.09 W Base Permafrost .00 94.92 N 57.58 W Top West Sak Sands .00 450.14 N 386.11 W Base West Sak Sands .76 665.82 N 619.26 W EOC .00 722.82 N 682.82 W 7 5/8" Casing Pt .00 926.24 N 909.66 W C80 .00 2292.36 N 2433.07 W C50 .00 2505.42 N 2670.66 W C40 .41 3185.71 N 3429.27 W Begin Angle Drop .00 3327.92 N 3587.86 W Iceberg Interval 58 3526.08 N 3808.86 W End Angle Drop 00 3553.07 N 3838.96 W T4 00 3620.49 N 3914.16 W T3 - Top Bermuda 99 3699.93 N 4002.75 W TARGET - Mid Bermuda 00 3699.93 N 4002.76 W 2N-D (I) Rvsd 12-Jul-98 00 3779.38 N 4091.36 W T2 - Base Bermuda 00 3822.10 N 4139.01 W C35 42 3916.51 N 4244.30 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2665.92 2300.00 722.82N 682.82W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 8493.15 5590.42 3916.51N 4244.30W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-D (I) Rvsd 12-Jul 456905.000,5915680.000,0.0000 5266.00 3699.93N 4002.76W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,317 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 317 Version #3 Last revised : 16-Jul-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degre=s Depth C O O R D I N A T E S Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 46.74 S 704.62 W 100.00 0.00 330.00 100.00 46.74 S 704.62 W 200.00 0.00 330.00 200.00 46.74 S 704.62 W 300.00 0.00 330.00 300.00 46.74 S 704.62 W 400.00 0.00 330.00 400.00 46.74 S 704.62 W 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 330.00 500.00 46.74 S 704.62 W 600.00 0.00 330.00 600.00 46.74 S 704.62 W 700.00 3.00 330.00 699.95 44.47 S 705.93 W 800.00 6.00 330.00 799.63 37.68 S 709.85 W 900.00 9.00 330.00 898.77 26.38 S 716.38 W 0~00 0.00 0.00 0.00 KOP 3.00 2.50 3.00 9.99 3.00 22.46 1000.00 12.00 330.00 997.08 10.60 S 725.49 W 1100.00 15.00 330.00 1094.31 9.62 N 737.16 W 1200.00 17.81 326.27 1190.23 33.55 N 752.12 W 1209.22 18.07 325.98 1199.00 35.91 N 753.71 W 1255.68 19.40 324.65 1243.00 48.18 N 762.20 W 3.00 39.86 3.00 62.15 Begin Turn to Target 3.00 89.38 3.00 92.15 Base Permafrost 3.00 106.71 Top West Sak Sands 1300.00 20.67 323.54 1284.64 60.47 N 771.11 W 3.00 121.60 1400.00 23.57 321.45 1377.27 90.31 N 794.07 W 3.00 158.71 1500.00 26.49 319.79 1467.87 122.98 N 820.93 W 3.00 200.61 1600.00 29.42 318.45 1556.19 158.40 N 85i-62 W 3.00 247.19 1700.00 32.36 317.32 1642.00 196.46 N 886 06 W 3.00 298.32 1800.00 35.32 316.37 1725.05 237.07 N 924.15 W 3.00 353.86 1900.00 38.27 315.55 1805.12 280.11 N 965.80 W 3.00 413.65 2000.00 41.24 314.82 1881.99 325.47 N 1010.87 W 3.00 477.54 2100.00 44.21 314.18 1955.44 373.01 N 1059.26 W 3.00 545.35 2161.73 46.04 313.82 1999.00 403.40 N 1090.73 W 3.00 589.08 Base West Sak Sands 2200.00 47.18 313.61 2025.29 422.61 N 1110.83 W 3.00 616.89 2300.00 50.15 313.08 2091.32 474.14 N 1165.44 W 3.00 691.96 2400.00 53.13 312.60 2153.38 527.45 N 1222.93 W 3.00 770.36 2500.00 56.11 312.16 2211.27 582.39 N 1283.15 W 3.00 851.88 2565.30 58.05 311.88 2246.76 619.08 N 1323.88 W 3.00 906.69 EOC 2665.92 58.05 311.88 2300.00 676.08 N 1387.44 W 0.00 992.06 7 5/8" Casing Pt 3000.00 58.05 311.88 2476.77 865.34 N 1598.49 W 0.00 1275.51 3025.00 58.05 311.88 2490.00 879.50 N 1614.28 W 0.00 1296.72 C80 3500.00 58.05 311.88 2741.34 1148.60 N 1914.36 W 0.00 1699.73 4000.00 58.05 311.88 3005.91 1431.85 N 2230.22 W 0.00 2123.95 4500.00 58.05 311.88 3270.48 1715.10 N 2546.09 W 0.00 2548.17 5000.00 58.05 311.88 3535.04 1998.36 N 2861.95 W 0.00 2972.39 5436.48 58.05 311.88 3766.00 2245.63 N 3137.69 W 0.00 3342.72 C50 5500.00 58.05 311.88 3799.61 2281.61 N 3177.82 W 0.00 3396.61 5812.56 58.05 311.88 3965.00 2458.68 N 3375.28 W 0.00 3661.80 C40 6000.00 58.05 311.88 4064.18 2564.86 N 3493.69 W 0.00 3820.83 6500.00 58.05 311.88 4328.75 2848.12 N 3809.55 W 0.00 4245.05 7000.00 58.05 311.88 4593.32 3131.37 N 4125.42 W 0.00 4669.27 7013.41 58.05 311.88 4600.41 3138.97 N 4133.89 W 0.00 4680.65 Begin Angle Drop 7100.00 56.32 311.88 4647.33 3187.55 N 4188.07 W 2.00 4753.41 7200.00 54.32 311.88 4704.23 3242.45 N 4249.29 W 2.00 4835.64 7272.08 52.88 311.88 4747.00 3281.18 N 4292.48 W 2.00 4893.65 Iceberg Interval 7300.00 52.32 311.88 4763.96 3295.99 N 4309.00 W 2.00 4915.82 7400.00 50.32 311.88 4826.45 3348.11 N 4367.12 W 2.00 4993.88 7500.00 48.32 311.88 4891.63 3398.73 N 4423.58 W 2.00 5069.70 All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Total Dogleg for wellpath is 72.01 degrees. Vertical section is from wellhead on azimuth 312.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,317 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 317 Version #3 Last revised : 16-Jul-98 Dogleg Vert Deg/100ft Sect 7600.00 46.32 311.88 4959.41 3447.81 N 4478.31 W 2.00 7666.05 45.00 311.88 5005.58 3479.34 N 4513.48 W 2.00 7723.22 45.00 311.88 5046.00 3506.33 N 4543.58 W 0.00 7866.06 45.00 311.88 5147.00 3573.75 N 4618.78 W 0.00 8000.00 45.00 311.88 5241.71 3636.98 N 4689.29 W 0.00 8034.33 45.00 311.88 5265.99 3653.19 N 4707.37 W 0.00 8034.35 45.00 311.88 5266.00 3653.20 N 4707.38 W 0.00 8202.64 45.00 311.88 5385.00 3732.64 N 4795.98 W 0.00 8293.15 45.00 311.88 5449.00 3775.36 N 4843.63 W 0.00 8493.15 45.00 311.88 5590.42 3869.77 N 4948.92 W 0.00 5143.20 5190.44 End Angle Drop 5230.86 T4 5331.85 T3 - Top Bermuda 5426.55 5450.82 TARGET - Mid Bermuda 5450.83 2N-D (I) Rvsd 12-Jul-98 5569.82 T2 - Base Bermuda 5633.81 C35 5775.22 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft a~ove mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Total Dogleg for wellpath is 72.01 degrees. Vertical section is from wellhead on azimuth 312.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,317 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 317 Version #3 Last revised : 16-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 600.00 600.00 46.74 S 704.62 W KOP 1100.00 1094.31 9.62 N 737.16 W Begin Tur~ to Target 1209.22 1199.00 35.91 N 753.71 W Base Permafrost 1255.68 1243.00 48.18 N 762.20 W Top West Sak Sands 2161.73 1999.00 403.40 N 1090.73 W Base West Sak Sands 2565.30 2246.76 619.08 N 1323.88 W EOC 2665.92 2300.00 676.08 N 1387.44 W 7 5/8" Casing Pt 3025.00 2490.00 879.50 N 1614.28 W C80 5436.48 3766.00 2245.63 N 3137.69 W C50 5812.56 3965.00 2458.68 N 3375.28 W 7013.41 4600.41 3138.97 N 4133.89 W Begin Angle Drop 7272.08 4747.00 3281.18 N 4292.48 W Iceberg Interval 7666.05 5005.58 3479.34 N 4513.48 W End Angle Drop 7723.22 5046.00 3506.33 N 4543.58 W T4 7866.06 5147.00 3573.75 N 4618.78 W T3 - Top Bermuda 8034.33 5265.99 3653.19 N 4707.37 W TARGET - Mid Bermuda 8034.35 5266.00 3653.20 N 4707.38 W 2N-D (i) Rvsd 12-Jul-98 8202.64 5385.00 3732.64 N 4795.98 W T2 - Base Bermuda 8293.15 5449.00 3775.36 N 4843.63 W C35 8493.15 5590.42 3869.77 N 4948.92 W TD - Casing Pt Casin$ positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 46.74S 704.62W 2665.92 2300.00 676.08N 1387.44W 7 5/8" Casing 0.00 0.00 46.74S 704.62W 8493.15 5590.42 3869.77N 4948.92W 5 1/2" Casing Targets associated with thls wellpath ................ Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-D (I) Rvsd 12-Jul 456905.000,5915680.000,0.0000 5266.00 3653.20N 4707.38W 6-Aug-97 ARCO Alaska, inc. Tarn Drill Site 2N,317 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 317 Version #3 Last revised : 16-Jul-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 330.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 330.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 330.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 0.00 330.00 400.00 0.00 N 0.00 E 0.00 1.04 1.04 0.60 N/A 500.00 0.00 330.00 500.00 0.00 N 0.00 E 0.00 1.31 1.31 0.75 N/A 600.00 0.00 330.00 600.00 0.00 N 0.00 E 0.00 1.57 1.57 0.90 N/A 700.00 3.00 330.00 699.95 2.27 N 1.31 W 2.50 1.84 1.83 1.05 N/A 800.00 6.00 330.00 799.63 9.06 N 5.23 W 9.99 2.16 2.10 1.20 330.00 900.00 9.00 330.00 898.77 20.36 N 11.76 W 22.46 2.60 2.37 1.35 330.00 1000.00 12.00 330.00 997.08 36.14 N 20.87 W 39.86 3.20 2.66 1.51 330.00 1100.00 15.00 330.00 1094.31 56.36 N 32.54 W 62.15 4.01 2.98 1.67 330.00 1200.00 17.81 326.27 1190.23 80.29 N 47.50 W 89.38 5.04 3.32 1.84 328.91 1209.22 18.07 325.98 1199.00 82.65 N 49.09 W 92.15 5.15 3.35 1.86 328.78 1255.68 19.40 324.65 1243.00 94.92 N 57.58 W 106.71 5.74 3.52 1.95 328.13 1300.00 20.67 323.54 1284.64 107.21 N 66.49 W 121.60 6.30 3.68 2.03 327.51 1400.00 23.57 321.45 1377.27 137.05 N 89.45 W 158.71 7.82 4.08 2.23 326.07 1500.00 26.49 319.79 1467.87 169.72 N 116.31 W 200.61 9.62 4.50 2.46 324.69 1600.00 29.42 318.45 1556.1~ 205.14 N 147.00 W 247.19 11.70 4.95 2.71 323.42 1700.00 32.36 317.32 1642.0~ 243.20 N 181.44 W 298.32 14.10 5.42 3.01 322.25 1800.00 35.32 316.37 1725.05 283.81 N 219.53 W 353.86 16.81 5.91 3.34 321.20 1900.00 38.27 315.55 1805.12 326.85 N 261.18 W 413.65 19.87 6.42 3.73 320.24 2000.00 41.24 314.82 1881.99 372.20 N 306.25 W 477.54 23.27 6.95 4.16 319.37 2100.00 44.21 314.18 1955.44 419.75 N 354.64 W 545.35 27.02 7.48 4.65 318.59 2161.73 46.04 313.82 1999.00 450.14 N 386.11 W 589.08 29.56 7.81 4.99 318.15 2200.00 47.18 313.61 2025.29 469.35 N 406.21 W 616.89 31.14 8.02 5.20 317.88 2300.00 50.15 313.08 2091.32 520.88 N 460.82 W 691.96 35.61 8.55 5.80 317.23 2400.00 53.13 312.60 2153.38 574.19 N 518.31 W 770.36 40.44 9.08 6.46 316.64 2500.00 56.11 312.16 2211.27 629.13 N 578.53 W 851.88 45.62 9.59 7.17 316.09 2565.30 58.05 311.88 2246.76 665.82 N 619.26 W 906.69 49.14 9.92 7.66 315.77 2665.92 58.05 311.88 2300.00 722.82 N 682.82 W 992.06 54.63 10.42 8.43 315.46 3000.00 58.05 311.88 2476.77 912.08 N 893.87 W 1275.51 72.86 12.09 10.99 314.45 3025.00 58.05 311.88 2490.00 926.24 N 909.66 W 1296.72 74.24 12.22 11.19 314.41 3500.00 58.05 311.88 2741.34 1195.34 N 1209.74 W 1699.73 100.36 14.60 14.88 313.72 4000.00 58.05 311.88 3005.91 1478.59 N 1525.60 W 2123.95 127.96 17.11 18.80 313.31 4500.00 58.05 311.88 3270.48 1761.84 N 1841.47 W 2548.17 135.59 19.63 22.72 313.05 5000.00 58.05 311.88 3535.04 2045.10 N 2157.33 W 2972.39 183.25 22.15 26.66 312.87 5436.48 58.05 311.88 3766.00 2292.36 N 2433.07 W 3342.72 207.41 24.35 30.09 312.76 5500.00 58.05 311.88 37~9.61 2328.35 N 2473.20 W 3396.61 210.93 24.67 30.59 312.74 5812.56 58.05 311.88 31~65.00 2505.42 N 2670.66 W 3661.80 228.23 26.25 33.06 312.68 6000.00 58.05 311.88 4064.18 2611.60 N 2789.07 W 3820.83 238.61 27.19 34.53 312.64 6500.00 58.05 311.88 4328.75 2894.86 N 3104.93 W 4245.05 266.30 29.72 38.47 312.56 7000.00 58.05 311.88 4593.32 3178.11 N 3420.80 W 4669.27 293.99 32.24 42.42 312.50 7013.41 58.05 311.88 4600.41 3185.71 N 3429.27 W 4680.65 294.73 32.31 42.52 312.49 7100.00 56.32 311.88 4647.33 3234.29 N 3483.45 W 4753.41 299.38 32.76 43.18 312.48 7200.00 54.32 311.88 4704.23 3289.19 N 3544.67 W 4835.64 304.52 33.29 43.91 312.47 7272.08 52.88 311.88 4747.00 3327.92 N 3587.86 W 4893.65 308.07 33.68 44.41 312.47 7300.00 52.32 311.88 4763.96 3342.73 N 3604.38 W 4915.82 309.45 33.83 44.60 312.46 7400.00 50.32 311.88 4826.45 3394.84 N 3662.50 W 4993.88 314.14 34.38 45.26 312.46 7500.00 48.32 311.88 4891.63 3445.47 N 3718.96 W 5069.70 318.61 34.93 45.89 312.45 All data is in feet unless otherwise stated. Coordinates from slot #317 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Vertical section is from wellhead on azimuth 312.75 degrees. Calculation uses the minimum cuz-vature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 317 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANG'ULAR COORDINATES PROPOSAL LISTING Page 2 Your ref : 317 Version #3 Last revised : 16-Jul-98 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 7600.00 46.32 311.88 4959.41 3494.55 N 3773.69 W 5143.20 7666.05 45.00 311.88 5005.58 3526.08 N 3808.86 W 5190.44 7723.22 45.00 311.88 5046.00 3553.07 N 3838.96 W 5230.86 7866.06 45.00 311.88 5147.00 3620.49 N 3914.16 W 5331.85 8000.00 45.00 311.88 5241.71 3683.72 N 3984.67 W 5426.55 8034.33 45.00 311.88 5265.99 3699.93 N 4002.75 W 5450.82 8034.35 45.00 311.88 5266.00 3699.93 N 4002.76 W 5450.83 8202.64 45.00 311.88 5385.00 3779.38 N 4091.36 W 5~9.82 8293.15 45.00 311.88 5449.00 3822.10 N 4139.01 W 5633.81 8493.15 45.00 311.88 5590.42 3916.51 N 4244.30 W 5775.22 322.85 35.49 46.48 312.44 325.55 35.86 46.85 312.44 327.88 36.18 47.17 312.43 333.71 36.98 47.98 312.42 339.18 37.74 48.74 312.41 340.58 37.93 48.93 312.41 340.58 37.93 48.93 312.41 347.45 38.88 49.88 312.40 351.15 39.39 50.40 312.40 359.31 40.51 51.53 312.38 POSITION UNCERTAINTY SU~R~ARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 8493 ARCO (H.A. Mag) User specified 359.31 40.51 51.53 i Ellipse dimensions are half axis. 2 Casing dimensions are not included. 3 Ellipses are calculated on 2.58 standard deviations. 4 Uncertainty calculations start at drill depth zero. 5 Surface position uncertainty is not included. 6 Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the !NTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #317 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Vertical section is from wellhead on azimuth 312.75 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ]%RCO Alaska, Inc. Tarn Drill Site 2N, 317 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 317 Version #3 Last revised : 16-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 600.00 600.00 0.00 N 0.00 E KOP 1100.00 1209.22 1255.68 2161.73 2565 30 2665 92 3025 00 5436 48 5812 56 7013 41 7272 08 7666 05 7723 22 7866 06 8034 33 8034 35 8202.64 8293.15 8493.15 1094 1199 1243 1999 2246 2300 2490 3766 3965 4600 4747 5005 5046 5147 5265 5266 5385 5449 5590 .31 .00 00 00 76 00 00 00 00 41 00 58 00 00 99 00 00 00 42 56.36 N 82.65 N 94.92 N 450 14 N 665 82 N 722 82 N 926 24 N 2292 36 N 2505 42 N 3185 71 N 3327 92 N 3526.08 N 3553.07 N 3620.49 N 3699.93 N 3699.93 N 3779.38 N 3822.10 N 3916.51 N 32.54 W Begin Turn to Target 49.09 W Base Permafrost 57.58 W Top West Sak Sands 386.11 W Base West Sak Sands 619.26 W EOC 682.82 W 7 5/8" Casing Pt 909.66 W C80 2433.07 W C50 2670.66 W C40 3429.27 W Begin Angle Drop 3587.86 W Iceberg Interval 3808.86 W End Angle Drop 3838.96 W T4 3914.16 W T3 - Top Bermuda 4002.75 W TARGET - Mid Bermuda 4002.76 W 2N-D (I) Rvsd 12-Jul-98 4091.36 W T2 - Base Bermuda 4139.01 W C35 4244.30 ~ TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2665.92 2300.00 722.82N 682.82W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 8493.15 5590.42 3916.51N 4244.30W 5 1/2" Casing Tazgets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-D (I) Rvsd 12-Jul 456905.000,5915680.000,0.0000 5266.00 3699.93N 4002.76W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 317 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 317 Version #3 Last revised : 16-Jul-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 460888.54 5911960.17 100.00 0.00 330.00 100.00 0.00N 0.00E 0.00 0.00 460888.54 5911960.17 200.00 0.00 330.00 200.00 0.00N 0.00E 0.00 0.00 460888.54 5911960.17 300.00 0.00 330.00 300.00 0.00N 0.00E 0.00 0.00 460888.54 5911960.17 400.00 0.00 330.00 400.00 0.00N 0.00E 0.00 0.00 460888.54 5911960.17 500.00 0.00 330.00 500.00 0.00N 0.00E 0.00 0.00 460888.54 5911960.17 600.00 0.00 330.00 600.00 0.00N 0.00E 0.00 0.00 460888.54 5911960.17 700.00 3.00 330.00 699.95 2.27N 1.31W 3.00 2.50 460887.24 5911962.44 800.00 6.00 330.00 799.63 9.06N 5.23W 3.00 9.99 460883.35 5911969.25 900.00 9.00 330.00 898.77 20.36N 11.76W 3.00 22.46 460876.88 5911980.59 1000.00 12.00 330.00 997.08 36.14N 20.87W 3.00 39.86 460867.86 5911996.41 1100.00 15.00 330.00 1094.31 56.36N 32.54W 3.00 62.15 460856.29 5912016.68 1200.00 17.81 326.27 1190.23 80.29N 47.50W 3.00 89.38 460841.45 5912040.69 1209.22 18.07 325.98 1199.00 82.65N 49.09W 3.00 92.15 460839.87 5912043.05 1255.68 19.40 324.65 1243.00 94.92N 57.58W 3.00 106.71 460831.44 5912055.36 1300.00 20.67 323.54 1284.64 107.21N 66.49W 3.00 121.60 460822.60 5912067.70 1400.00 23.57 321.45 1377.27 137.05N 89.45W 3.00 158.71 460799.80 5912097.65 1500.00 26.49 319.79 1467.87 169.72N 116.31W 3.00 200.61 460773.10 5912130.46 1600.00 29.42 3!~.45 1556.19 205.14N 147.00W 3.00 247.19 460742.60 5912166~03 1700.00 32.36 317.32 1642.00 243.20N 181.44W 3.00 298.32 460708.35 5912204.~6 1800.00 35.32 316.37 1725.05 283.81N 219.53W 3.00 353.86 460670.47 5912245.06 1900.00 38.27 315.55 1805.12 326.85N 261.18W 3.00 413.65 460629.05 5912288.31 2000.00 41.24 314.82 1881.99 372.20N 306.25W 3.00 477.54 460584.20 5912333.88 2100.00 44.21 314.18 1955.44 419.75N 354.64W 3.00 545.35 460536.06 5912381.67 2161.73 46.04 313.82 1999.00 450.14N 386.11W 3.00 589.08 460504.75 5912412.21 2200.00 47.18 313.61 2025.29 469.35N 406.21W 3.00 616.89 460484.75 5912431.53 2300.00 50.15 313.08 2091.32 520.88N ~60.82W 3.00 691.96 460430.41 5912483.32 2400.00 53.13 312.60 2153.38 574.19N 518.31W 3.00 770.36 460373.20 5912536.92 2500.00 56.11 312.16 2211.27 629.13N 578.53W 3.00 851.88 460313.26 5912592.16 2565.30 58.05 311.88 2246.76 665.82N 619.26W 3.00 906.69 460272.73 5912629.06 2665.92 58.05 311.88 2300.00 722.82N 682.82W 0.00 992.06 460209.46 5912686.37 3000.00 58.05 311.88 2476.77 912.08N 893.87W 0.00 1275.51 459999.39 5912876.68 3025.00 58.05 311.88 2490.00 926.24N 909.66W 0.00 1296.72 459983.68 5912890.92 3500.00 58.05 311.88 2741.34 1195.34N 1209.74W 0.00 1699.73 459685.00 5913161.51 4000.00 58.05 311.88 3005.91 1478.59N 1525.60W 0.00 2123.95 459370.61 5913446.33 4500.00 58.05 311.88 3270.48 1761.84N 1841.47W 0.00 2548.17 459056.21 5913731.16 5000.00 58.05 311.88 3535.04 2045.10N 2157.33W 0.00 2972.39 458741.82 5914015.98 5436.48 58.05 311.88 3766.00 2292.36N 2433.07W 0.00 3342.72 458467.37 5914264.62 5500.00 58.09 311.88 3799.61 2328.35N 2473.20W 0.00 3396.61 458427.43 591d300.81 5812.56 58.55 311.88 3965.00 2505.42N 2670.66W 0.00 3661.80 458230.89 5914478.86 6000.00 58.05 311.88 4064.18 2611.60N 2789.07W 0.00 3820.83 458113.03 5914585.63 6500.00 58.05 311.88 4328.75 2894.86N 3104.93W 0.00 4245.05 457798.64 5914870.46 7000.00 58.05 311.88 4593.32 3178.11N 3420.80W 0.00 4669.27 457484.25 5915155.28 7013.41 58.05 311.88 4600.41 3185.71N 3429.27W 0.00 4680.65 457475.82 5915162.92 7100.00 56.32 311.88 4647.33 3234.29N 3483.45W 2.00 4753.41 457421.89 5915211.77 7200.00 54.32 311.88 4704.23 3289.19N 3544.67W 2.00 4835.64 457360.95 5915266.98 7272.08 52.88 311.88 4747.00 3327.92N 3587.86W 2.00 4893.65 457317.96 5915305.92 7300.00 52.32 311.88 4763.96 3342.73N 3604.38W 2.00 4915.82 457301.52 5915320.81 7400.00 50.32 311.88 4826.45 3394.84N 3662.50W 2.00 4993.88 457243.68 5915373.22 7500.00 48.32 311.88 4891.63 3445.47N 3718.96W 2.00 5069.70 457187.48 5915424.12 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #317 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Total Dogleg for wellpath is 72.01 degrees. Vertical section is from wellhead on azimuth 312.75 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes I~TEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 317 Tarn Development Field,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 317 Version #3 Last revised : 16-Jul-98 Dogleg Vert G R I D C O O R D S Deg/100ft Sect Easting Northing 7600.00 46.32 311.88 4959.41 3494.55N 3773.69W 2.00 5143.20 457133.00 5915473.47 7666.05 45.00 311.88 5005.58 3526.08N 3808.86W 2.00 5190.44 457097.99 5915505.19 7723.22 45.00 311.88 5046.00 3553.07N 3838.96W 0.00 5230.86 457068.04 5915532.32 7866.06 45.00 311.88 5147.00 3620.49N 3914.16W 0.00 5331.85 456993.19 5915600.12 8000.00 45.00 311.88 5241.71 3683.72N 3984.67W 0.00 5426.55 456923.-00 5915663.70 8034.33 45.00 311.88 5265.99 3699.93N 4002.75W 0.00 5450.82 456905.01 5915679.99 8034.35 45.00 311.88 5266.00 3699.93N 4002.76W 0.00 5450.83 456905.00 5915680.00 8202.64 45.00 311.88 5385.00 3779.38N 4091.36W 0.00 5569.82 456816.81 5915759.88 8293.15 45.00 311.88 5449.00 3822.10N 4139.01W 0.00 5633.81 456769.38 5915802.84 8493.15 45.00 311.88 5590.42 3916.51N 4244.30W 0.00 5775.22 456664.58 5915897.78 All data in feet unless otherwise stated. Calculation uses minimum cuz-vature method. Coordinates from slot #317 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 5775.22 on azimuth 312.70 degrees from wellhead. Total Dogleg for wellpath is 72.01 degrees. Vertical section is from wellhead on azimuth 312.75 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,317 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 317 Version #3 Last revised : 16-Jul-98 Comments in wellpath MD TVD Rectangular Coords. Comment 600.00 600 00 0.00N 0.00E KOP 1100 1209 1255 2161 2565. 2665. 3025. 5436. 5812. 7013. 7272. 7666. 7723. 7866. 8034. 8034. 8202. 8293. 8493. .00 1094 31 .22 1199 00 .68 1243 00 .73 1999 00 30 2246 76 92 2300 00 00 2490 00 48 3766 00 56 3965 00 41 4600 41 08 4747 00 05 5005 58 22 5046 O0 06 5147.00 33 5265.99 35 5266.00 64 5385.00 15 5449.00 15 5590.42 56.36N 32 82.65N 49 94.92N 57 450.14N 386 665.82N 619 722.82N 682 926.24N 909 2292.36N 2433 2505.42N 2670. 3185.71N 3429. 3327.92N 3587. 3526.08N 3808. 3553.07N 3838. 3620.49N 3914. 3699.93N 4002. 3699.93N 4002. 3779.38N 4091. 3822.10N 4139. 3916~51N 4244. 54W Begin Turn to Target 09W Base Pez-mafrost 58W Top West Sak Sands 11W Base West Sak Sands 26W EOC 82W 7 5/8" Casing Pt 66W C80 07W C50 66W C40 27W Begin Angle Drop 86W Iceberg Interval 86W End Angle Drop 96W T4 16W T3 - Top Bermuda 75W TARGET - Mid Bermuda 76W 2N-D (I) Rvsd 12-Jul-98- 36W T2 - Base Bermuda 01W C35 30W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2665.92 2300.00 722.82N 682.82W 7 5/8" Casing 0.00 0.00 0.00N 0.00E 8493.15 5590.42 3916.51N 4244.30W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-D (I) Rvsd 12-Jul 456905.000,5915680.000,0.0000 5266.00 3699.93N 4002.76W 6-Aug-97 ARCO Alaska, Inc .... Post Office Box 100360 Anchorage, Alaska 99510-0360 July 22, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-317 Surface Location: 47' FNL 705' FEL Sec 3 TgN R7E, UM Target Location: 1,627' FNL, 573' FWL Sec. 34, T10N, R7E, UM Bottom Hole Location: 1,410' FNL, 331' FWL Sec. 34, T10N, RTE, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-317, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. This well will require a spacing exception. That exception will be filed under a separate cover. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field ~ L~ C L~ IV ~! for temporary storage and eventual processing for injection down an approved disposal well. JUL 2 5 1998 The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne ~aska 0JJ & Gas ~,s. corm Formation. Therefore, ARCO has not included an H2S contingency plan Anchorage with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johnst~-~,, Application for Permit to Drill Page 2 KRU 2N-317 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-317 Well File STATE O7 LASKA ALASKA OIL AND GAS CO?, ~2RVATION CO_~LXHSSION 3001 Porcupine Drive Anchorage .Maska 99501-3192 Re' THE APPLICATION OF ARCO .S~LASIC-X ) INC. to present testimony fbr classification ) of a nexv pool and the establistunent of rules ) for development of the Tarn oil pool in the ) Kuparuk River Field. ) Conservation Order No. 430 Kuparuk River Field Tarn Oil Pool July '2 i. ! 998 IT APPEARING THAT: By letter dated March 27. 1998. ARCO Alaska. Inc. (".~I") requested a public hearing to present testimony to define the Tam oil pool and establish rules for development and production of the reservoir. Notice of public hearing to be held on April 28. 1998 was published in the ~4mchorage Daily News on March 28. 1998. . A hearing concerning the matter of the applicant's request was convened in confbrmance with 20 AAC 25.540 at the Commission's offices, 3001 Porcupine Drive. ,amchorage. Alaska 99501 at 9:00 am on April 28. 1998. FINDINGS: 1. The Tarn oil pool is located immediately adjacent to the southwest corner of the Kuparuk River Unit ("KRU") on Alaska's North Slope. 2. .MAI is operator of the KRU and operator of state leases overlying the Tarn oil pool area. 3. AAI has petitioned the Alaska Department of Natural Resources to expand the KRU to include the Tarn oil pool. 4. The Tarn oil pool has .,~ot been completely delineated. Large portions of the Tam oil pool have vet to be drilled. 5. The Tarn oil pool CO~Teiates with the stratigraphic interval between 4376 feet to 5990 feet measured depth {MD) in the .~I Bern~uda ~1 (KRU 36 10-7., 1), which appears to contain a typical and representative strati~'aphic section of the pool. 6. The Tarn oil pool is composed of five late Cretaceous aged marine sandstone and interbedded mudstone interYals that are stratigaphically within the Seabee Formation. The name and depth fbr each productive Tarn interval in the AAI Bermuda #1 well is as £ollows' "C30" Intel~-'al 5990'- 5716' MD "Bermuda" Interval 5608'- 5542' MD "Cairn" Interval 5452' - 5316' kid "Arete" Interval 5316' - 5105' _X;ID "Iceberg" Interval 510~' 4076 rid 7. The Tarn inter~,als share a common depositional environment and have similar tithologic characteristics and fluid compositions. The five intervals are located closely adjacent, both stratigraphically and areallv. Conservation Order No 3 .!ulv 21. 1998 Page 2 S. Available xvell data shows that sand distribution within the Tarn oil pool is complex, with variable ~oss sand percentages withit: . ~ch interval. The current areal delineation of the pool relies on recently acquired 3-D seismic data calibrated to weilbore data. 9. Not all of the reservoir inter",,als in the Tarn oil pool have been shown to be hydrocarbon bearing in existing wells. The northern and southern productive limits of the Cairn. iceberg and Arete intervals have not vet been determined. 10. The Tarn oil pool appears to be monoclinal in structure with eastern dip ranoi~ o- from three or four degrees to nearly fiat. Few faults have been tbund. 11. Hvdrocarbon distribution within the Bermuda and Cairn intervals is controlled bv sand distribution, with updip strati~aphic seal along the western marain of the pooi area. 12. Petrophysical in~brmation is derived from conventional cores collected from the :&-XI Tarn ~1 tt~rough Tarn 7.-4 wells and rotary sidewall cores from the .&AI Bermuda ~1 (KRU 36 10- 7 '1 ) well. i 3. The Tarn oil pool is composed of heterogenious sandstone. Fmc to vet3, fine-ffained, with shale laminations and interbeds. Sandstone ~ains are principally quartz, plagiociase. zeolites, and heterolithic rock fragTnents. Clay content is high, ranging between 15 and 25 percent, and occurs primariiy in the heterolithic ~:¥amework of the sandstone. 14. Core porosity ranges from 18 to 27 percent and averages 21 percent. Air permeability ranges from 1 to 45 millidarcies and averages 10 millidarcies. Average water saturation based upon core ana!vsis is about 40 percent. 15. Sandstone porosity is dominantly secondary, with common microporosity. This condition. combined with fine-grain size and high clay content, decreases permeability and increases susceptibility to fine migration. 16. AAI requests well spacing of 10 acres to allow flexibility in locating wells because of rock properties and strati~at~hic constraints. 17. AAI estimates that the iikelv volume of oil in the Bermuda and Cairn intervals is about i 36 million barrels of original oil in place ("OOIP"). AAI did not provide a volume estimate tbr other intervals in the Tarn oil pool. i 8. ..-kAl plans to produce the Bermuda and Cairn interval ~br a short period using primao' depletion methods, then initiate enhanced oil recovew ("EOR') operations. Initial EOR plans call for miscible gas injection using a 20 percent pore volume slug, tbilowed bv lean gas sxveep to move miscible products to the wellbore. AAI rejected waterflood operations because of potential reservoir damage and unfavorable reservoir permeability and poor water mobility characteristics. 19. AAI estimate oil recovery in the Bermuda and Cairn interYais at 10 percent of OOIP using primary, methods. With miscible and lean gas injection. A_a_I estimates an additional recovery of 21 percent OOIP. Total recovery from the two intervals is expected to be about 43 million barrels. 20. Solution gas-oil ratio was estimated at 710 scf/stb from a recombined separator sample. 21. The gas-oil ratio is expected to increase sig-nificantly during production life because of pressure drawdown and miscible gas or lean gas breakthrough during reservoir depletion. 22. AAI calculated original reservoir pressure of 2350 psig in Tarn ~2 on the basis of a pressure build up test immediately following a 1 O-day flow test. The well flowed an average ! 900 BOPD of 37 API ~avity crude oil with a gas-oil ratio of !200 scg'stb at a flowing tubing pressure of 550 psig. Gas-oil ratio was elevated because of reservoir pressure drawdown Conservation Order No. -~ JuN ~ 1. 1998 24. 25. 26. .AA[ ,,','ill measure reservoir pressure in proc !rig wells and injection wells initially and ;vithin portions of the reservoir on a periodi~ oasis to monitor reservoir perlbrmance. Other surveillance such as profile logs may be applied to wells ,`,,;here multiple intervals are open ~br production or rejection. Casing and cement plans ,,,,'ill adhere to 20 AAC 25.030 xvith designs based on pertbrmance factors to v¥'ithstand permafrost and downhole conditions. .kAl proposes to use well annuli in accordance with 20 'AAC 25.080 to dispose of drilling wastes as part of the development operations and is also requesting authorization for an area injection order tbr waste disposal and EOR operations. .-kAl proposes to commingling Tam oil with hydrocarbons from the Kuparuk oil pool for processing in KRU production facilities. Production ,`',,ill be allocated back to Tam oil pool on the basis of monthly well tests. CONCLUSIONS: 1. Pool rules lbr the initial development and delineation of the Tam oil pool are appropriate at this time. Initial pool development will be conducted on leases that are not participating in the KRU. AAI, the operator of the KRU and the leased portion of the Tarn oil pool area, can properly undertake concurrent operations in both the Kuparuk and Tm'n oil pools. Minimum well spacing of 10 acres will allow the operator to deal effectively with difficult rock properties and strati~aphic constraints in locating wells, and should not cause waste. compromise ultimate recovery or jeopardize correlative rights. Early implementation of miscible gas injection to mobilize oil followed by lean gas injection to sweep the reservoir and support pressure will preserve reservoir energs' and enhance ultimate recovery fi'om the pool. Remedial measures may be required in some areas of the reservoir to control placement of injectant, and improve the ability of the injectant to sweep the rock and maintain reservoir pressure. Annular disposal of drilling wastes can occur in an environmental safe manner if conducted in accordance with 20 AAC 25.080. but will require subsequent Commission review on a well-by-well basis to ensure that the provisions of 20 AAC 25.080(C) are met. The area injection order ~br the Tarn oil pool can provide a partial basis for any subsequent Commission determinations concerning annular disposal. Reservoir pressure will be measured in wells using standard industry,, practices on a regular basis to manage production and monitor resel'voir performance. Exception from the gas-oil-ratio limitations of 20 AAC 25.240 is appropriate provided a pressure maintenance project starts within six months of the start of regular production. 10. Commingling Tarn and Kuparuk production streams on the surface is appropriate provided that there is adequate individual well testing to assure production allocation quality. 11. Two well tests per month has been a minimum standard for commingled pools with the advent of commingling pools in surface facilities prior to custody transfer and severance from leases. 12. An allocation factor of 1.0 for the Tarn Pool is acceptable during the first year of production to evaluate multiphase well test equipment and allocation quality. . , . Conservation Order Nc, ~30 '~-_ .... Paae 4 July 21. 1998 NOW, THEREFORE, IT IS ORDERED qAT the rules hereinafter set forth, in addition to statewide requirements under 20 AAC 25. apply to the ibllowing affected area re~'e.,Ted to in this order. Umiat Meridian TllN RTE T11N RSE T10N RTE T 1 ON RSE T9N RTE TSN RiE 25, 26.34.35 30,31 1. _, o, 4.9. 10. 11. 1'~ lo, 14. i5. 16.17.20.21.22.23.24. '~< 26. 27, 28 29. o0.31, o-, _~o, 04. ~, 06 6, 7, 18. 19.30.31 1.2.3.4.5.6.7.8.9, 10. 11. 12. !3. 14.15. 16.17.20.2i.22.23, 24.25.26.27.28.29, 32.33.34.35, 36 1 '~ 3 _t -~ 6.'7 8.9.10.11 '" !" la ,q t6.~7.1S Rule 1 Field and Pool Name The pool is in a geogaphic area knoxvn as the Kuparuk River Field and will be contained within the Kuparuk River Unit. Hydrocarbons underlying the affected area and within the referenced intervals of the Seabee Formation constitute a single oil and gas reservoir called the Tarn oil pool. Rule 2 Pool Definition The Tarn oil pool is defined as the accumulation of hydrocarbons common to and correlating with the intervals between the measured depths of 4376 feet and 5990 feet (MD) interval in the Bermuda #1 well (KRU 36 10-7/1). Rule 3 Spacing Units Nominal spacing units within the pool will be I0 acres. The Dool shall not be ooened in anv well closer than 300 feet to an external boundar~? where ownership changes. Rule 4 Casin~ and Cementin_o Practices a.) Conductor casing must be set at least 75 feet below ~ound level and cemented to surface. b. ) Where required tbr annular disposal, suN'ace casing must be set at least 500 feet below the permafrost and be cemented to surface. Rule 5 Injection Well Completion a./ Injection wells may be completed with tapered casing provided a sealbore assembly, packer, or other isolation device is positioned not over 200 feet above the top o£the iniection or per~brated interval. b. I A sealbore assembly, packer, or other isolation device may be positioned within 200 feet of a seconda~ target interval within the defined pool vchere potential reserves are reasonably expected and will be evaluated or exploited. Conservation Order No. 4_ ,,~ July 2!. 1998 Page 5 Rule 6 Automatic Shut-in Equipment a.) All wells capable of unassisted flow of hydrocarbons will be equipped with a fail-safe automatic surface safety valve. b.) Injection wells will be equipped with a double check valve arrangement. c.) Surface safetv valves will be tested at six-month intervals. Rule 7 Common Production Facilities and Surface Commingling a.) Production from the Tam oil pool may be commingled with production ~t¥om the Kuparuk oil pool in surface facilities prior to custody transfer. b.) The allocation factor for the Tarn oil pool will be 1.00 for the first year of production to evaluate the allocation metho& testing frequency and quality. c.) Each producing ,,veil will be tested a minimum oft~vo times per month during the first ,,.'ear of regular production. d.) The Commission may require more frequent or longer tests if the allocation quality deteriorates. e.) The operator shall submit a monthly file(s) containh~g daily allocation data and daily test data Ibr agency surveillance and evaluation. f.) The operator shall provide the Commission with a well test and allocation review report after six months and after one year of commingled production. Subsequent report frequency and necessity will be determined after the first year of regular production. g.) After one year of regular production, an evaluation of test frequency and allocation quality must be done to support extension of the 1.00 allocation factor or consideration of alternatives. Rule $ Reservoir Pressure Monitoring a. ) Prior to regular production or injection an initial pressure survey shall be taken in each well. .-\ minimum of one bottom-hole pressure survey per producing or injecting governmental section shall be measured annually. Bottom-hole surveys in para~aph (a) may fulfill the minimum requirement. c.) The reservoir pressure datum will be 5200 feet subsea. d.) Pressure surveys may consist of stabilized static pressure measurements at bottom-hole or extrapolated from surface, pressure fall-off, pressure buildup, multi-rate tests, drill stem tests, and open-hole Ibrmation tests. e.) Data and results from pressure surveys shall be reported quarterly on Form 10-412. Reservoir Pressure Report. All data necessary for analysis of each survey need not be submitted with the Form 10-412 but must be available to the Commission upon request. f.) Results and data from special reservoir pressure monitoring tests or surveys shall also be submitted in accordance with part (e) of this rule. Rule 9 Gas-Oil Ratio Exemption Wells producing from the Tarn oil pool are exempt from the gas-oil-ratio limits of Conservation Order July 21. 1998 Pa_de 6 20 AAC 25.240(b) so lon_o_ as the t~rovisions of 20 :-MAC -.~'>'~._, ~,,c'~at~f ) apply. Rule 10 Pressure Maintenance Project A pressure maintenance miscible gas injection project must be initiated within six months after the start of regular production fi-om the Tam oil pool. Rule 11 Reservoir Surveillance Report A SUlWeillance report will be required after one year of regular production and annually thereafter. The report shall include but is not limited to the following: a.) Progress of enhanced recovery project(s) implementation and reservoir management summary including engineering and geotechnical parameters. b.) Voidage balance, by month, of produced fluids and injected fluids. c.) Analysis of reservoir pressure surveys within the pool. d.) Results and where appropriate, analysis of production logs. tracer survevs and observation well surveys. e. ) Results of well allocation and test evaluation for Rule 7(5 and any other speciai monitoring. f.) Future development plans. Rule 12 Production,Anomalies In the event of oil production capacity restrictions at or from the Kuparuk facilities, all commingled reservoirs produced through the Kuparuk facilities will be prorated by an equivalent percentage of oil production, unless this will result in surface or subsurface equipment damage. Rule 13 Administrative Action Upon proper application, the Commission may administratively waive the requirements of any rule stated above or administratively amend this order as long as the change does not promote waste, jeopardize CO~Teiative rigi~ts, and is based on sound engineering principies. DONE at Anchorage. Alaska and dated July 21. 1998. ;~:, :' 5~ ~,,,~,,,' ..... o' ~'-"--~ J'~-- -- · ~NDavid W. Johnston. ,'~.¢.~-~-,.%__ '-...:~..::: .:../:..~.. _.:,.~ ..._-.,,. Chairman ""h ;'"~ ..,:4-.-*;x':.,- I'-*: ;~'"' ..... .'. ;-' :. ' S .'~ - ,.,.: ~,?-,x:'-, :., : ~', - .. ~ ":75.-;.., ~.~. .... ;1 ,ag' '(,%"~*'?- ~"'fi'** 1i/75'5~,';';;' Camilla Oechsii Commissioner .-\S ~ 1 0'1.080 pro~ ides that within 20 days ar'ter recemt of,written notice of the entrw of an order, a person aFr'ected by it may file with the ~_'o'm~ission an at~piication for reheai'in~. A request for rehearing must be recei'ved by 4:30 PM on the 23rd da5' following the date of the order, or next working day ifa holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in ;vhole or in part within 10 days. The Commission can refuse an application by not acting on it within the i0-day pep;od. An affected person has 30 days ~'rom the date the Commission refuses the application or mails (or othem'~se distributes) an order uaon rehearinz. both being the final order of the Commission. to appeal the decision to Superior Court. \Vhere a request for reheanng is denied by nonaction of the Commission. the 30 day period for appeal to Superior Court runs from the date on which the reauest is deemed denied (i.e.. 10th day after the application for rehearing was filed'). FIELD & POOL COMPANY _.,,~/,"c.,,,-.~ WELL PERMIT CHECKLIST GEOL AREA ADMINISTRATION INIT CLASS /~/::~JZ/ /~-",,~.,' 2 ENGINEERING WELL NAME/,~ Z,~u/~-.~,,,/? PROGRAM: exp [] dev~'redrll [] serv [] wellbore segll ann. disposal para req)~ ~;:~'~ (:::3 UNIT# ~.x .~, ON/OFF SHORE Y N Y N Y N Y N Y N Y N Y N N Y N Y N Y N Y N Y N 'N 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and nurnber .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 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 .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ...... ~ ....... 26. BOPE press rating appropriate; test to ¢-)~ psig. 27. Choke manifold complies w/APl RP-53 (M&y~'~4) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY ____.R DATE, 30. Permit can be issued WIG hydrogen sulfide measures ..... ,~,/~'-YY N~ ,,) ,,~ 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .............. 33. Seabed condition survey (if off-shore) ............. 34. Con. tact.nam, e/phone for weekly progress reports Y N ....... Y N lexplora[ory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not darnage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular C O M~M_ I S__S I._O_..N~- BEW WM w~'"~_L.2-~ DWJ_~ ........ RPC ,JDI~ -- ...................... ............. RNC ~ CO M:chel~list rev 05/29/98 dlf: C'\msoffice\wordian\diar~a\r;hecMist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drillin9 Services LIS Scan Utility Tue Nov 17 10:40:22 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/17 Origin ................... STS Reel Name ................ UNK/~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writin~ Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/11/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 2N-317 501032026600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 17-NOV-98 MWD RUN 2 MWD RUN 3 MWD RUN 4 AK-MM- 80320 AK-MM-80320 AK-MM- 80320 R. KRELL R. KRELL R. KRELL D. HEIM D. HEIM D. HEIM 3 9N 7E 47 7O5 148.80 RECEIVED NOV 18 1998 Alaska ~i ~, uas uons. Oommi~ion Anchorage DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2698.0 6.750 8500.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DOUG HASTINGS OF ARCO ALASKA, INC. ON 08/12/98. MWD IS PDC. 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED ON LOG. 4. MWD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE- 4 (EWR4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 5. HOLE SECTION 7880'MD, 5164'TVD TO 8320'MD, 5469'TVD WAS CONTROL DRILLED AT 100 FT/HR FOR NUCLEAR LOG QUALITY. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8500'MD, 5593'TVD. SROP = SMOOTHED RATE OF PENETRATION. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY). TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON SANDSTONE POROSITY. SBD2 = SMOOTHED BULK DENSITY COMPENSATED (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). SLD SLIDE = LOCATION OF SLD SENSOR WHILE SLIDING (NO ROTATION). COMPENSATED THERMAL NEUTRON POROSITY PROCESSING PARAMETERS: FIXED HOLE SIZE: 6.75" MUD WEIGHT: 9.4 TO 10.0 PPG MUD SALINITY: 750 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 1.0 o/cc 2.65 G/CC SANDSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2650.0 FET 2695 5 RPD 2695 5 RPM 2695 5 RPS 2695 5 RPX 2695 5 DRHO 2698 RHOB 2698 PEF 2698 FCNT 2700 NCNT 2700 NPHI 2700 ROP 2720 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 8406.0 8413.0 8413.0 8413.0 8413.0 8413.0 8393.0 8393.0 8393.0 8377.5 8377.5 8377.5 8500.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 2720.0 3977.0 3 3977.0 5548.0 4 5548.0 8500.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD API 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/C3 4 1 68 DRHO MWD G/C3 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 2650 8500 GR 40.77 264.9 RPD 1.1 2000 ROP 0 1443 RPX 1.04 49.77 RPS 1.02 1610.76 RPM 1.03 2000 FET 0.45 13.34 NPHI 14.42 51.49 FCNT 150.7 875.59 NCNT 19545.6 40965.7 RHOB 1.94 3.13 DRHO -0.08 0.83 PEF -0.66 5.77 Mean Nsam 5575 11701 124.214 11513 5.52811 11436 197.098 11560 4.6274 11436 4.92018 11436 5.29303 11436 1.39543 11436 39.5016 11356 224.881 11356 24720 11356 2.34011 11391 0.0579273 11391 2.75912 11391 First Reading 2650 2650 2695.5 2720.5 2695.5 2695.5 2695.5 2695.5 2700 2700 2700 2698 2698 2698 Last Reading 8500 8406 8413 8500 8413 8413 8413 8413 8377.5 8377.5 8377.5 8393 8393 8393 First Reading For Entire File .......... 2650 Last Reading For Entire File ........... 8500 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX 2650 0 2695 5 2695 5 2695 5 2695 5 2695 5 RHOB 2698 0 DRHO 2698 0 PEF 2698 0 FCNT 2700.0 NCNT 2700.0 NPHI 2700.0 ROP 2720.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 10.83 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXI~ ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P_AY EWR4 ELECTROMAG. RESIS. 4 STOP DEPTH 3884 5 3891 5 3891 5 3891 5 3891 5 3891 5 3871.5 3871.5 3871.5 3855.5 3855.5 3855.5 3976.5 08-AUG-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD MEMORY 3977.0 2720.0 3977.0 56.6 58.1 TOOL NUMBER P1068GRM4 P1068GRM4 CNP SLD $ COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AAID CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P1069NL4 P1069NL4 6.750 6.8 LSND 9.40 47.0 9.5 800 5.6 2.700 2.250 3.000 2.800 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 PU-S 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/C3 4 1 68 44 12 35.0 DRHO MWD 2 G/C3 4 1 68 PEF MWD 2 BARN 4 1 68 Name Min Max Mean Nsam DEPT 2650 3976.5 3313.25 2654 ROP 0.12 760.09 236.533 2513 GR 44.01 178.32 110.191 2470 RPX 2.33 47.66 4.7136 2393 RPS 2.11 1610.76 5.7035 2393 RPM 0.82 2000 50.7261 2484 RPD 2.17 2000 8.243 2393 FET 0.5 7.48 0.872231 2393 NPHI 19.78 50.69 44.3753 2312 FCNT 150.7 501.31 172.742 2312 NCNT 19545.6 32899.4 22039 2312 RHOB 1.94 2.69 2.2102 2348 DRHO -0.08 0.24 0.0527087 2348 PEF 1.57 5.04 2.45958 2348 48 13 52 14 First Reading 2650 2720.5 2650 2695.5 2695.5 2650 2695.5 2695.5 2700 2700 2700 2698 2698 2698 Last Reading 3976.5 3976.5 3884.5 3891.5 3891.5 3891.5 3891.5 3891.5 3855.5 3855.5 3855.5 3871.5 3871.5 3871.5 First Reading For Entire File .......... 2650 Last Reading For Entire File ........... 3976.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT NCNT NPHI DRHO RHOB PEF GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3856.0 3856.0 3856.0 3872.0 3872.0 3872.0 3884 5 3892 0 3892 0 3892 0 3892 0 3892 0 3977 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 10.83 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5429.0 5429.0 5429.0 5445.0 5445.0 5445.0 5455.0 5465.0 5465.0 5465.0 5465.0 5465.0 5548.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA R3LY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEILATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 09-AUG-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD MEMORY 5548.0 3977.0 5548.0 56.5 58.6 TOOL NTJMBER P1068GRM4 P1068GRM4 P1069NL4 P1069NL4 6.750 6.8 LSND 9.40 45.0 9.5 750 5.8 3.300 2.600 3.500 3.200 38.4 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMkRKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 RPX MWD 3 OHMM 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 0HMM 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 NPHI MWD 3 PU-S 4 1 68 32 9 FCNT MWD 3 CNTS 4 1 68 36 10 NCNT MWD 3 CNTS 4 1 68 40 11 RHOB MWD 3 G/C3 4 1 68 44 12 DRHO MWD 3 G/C3 4 1 68 48 13 PEF MWD 3 BARN 4 1 68 52 14 First Name Min Max Mean Nsam Reading DEPT 3856 5548 4702 3385 3856 ROP 1.31 878.7 240.174 3143 3977 GR 40.77 219.9 118.676 3142 3884.5 RPX 1.86 12.38 4.11509 3147 3892 RPS 1.94 11.81 4.22088 3147 3892 RPM 2 9.7 4.16499 3147 3892 RPD 2.17 7.43 4.32233 3147 3892 FET 0.45 13.34 1.5487 3147 3892 NPHI 20.01 51.49 40.163 3147 3856 FCNT 150.73 556.54 211.848 3147 3856 NCNT 20820.7 35170.5 24314.5 3147 3856 RHOB 2.1 2.81 2.28581 3147 3872 DRHO -0.04 0.59 0.0603686 3147 3872 PEF 1.65 4.41 2.50141 3147 3872 Last Reading 5548 5548 5455 5465 5465 5465 5465 5465 5429 5429 5429 5445 5445 5445 First Reading For Entire File .......... 3856 Last Reading For Entire File ........... 5548 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI DRHO RHOB PEF GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. 4 .5000 START DEPTH 5429.5 5429.5 5429.5 5445.5 5445.5 5445 5 5455 5 5465 5 5465 5 5465 5 5465 5 5465 5 5548 5 STOP DEPTH 8377.5 8377.5 8377.5 8393.0 8393.0 8393.0 8406.0 8413.0 8413.0 8413.0 8413.0 8413.0 8500.0 11 -AUG - 98 SURFACE SOFTWARE VERSION: INSITE 3.2.12.3 DOWNHOLE SOFTWARE VERSION: CIM 5.46,SP4 5.16,SLD 10.83 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/~GLE: MAXIMUM ANGLE: TOOL STRING VENDOR TOOL CODE DGR EWR4 CNP SLD $ (TOP TO BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... MEMORY 8500.0 5548.0 8500.0 44.3 60.1 TOOL NUMBER P1068GRM4 P1068GRM4 P1069NL4 P1069NL4 6.750 6.8 LSND 10.00 49.0 9.5 700 4.2 3.100 1.750 4.200 3.400 55.0 .0 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 4 FT/H 4 1 GR MWD 4 API 4 1 RPX MWD 4 OHMM 4 1 RPS MWD 4 OHMM 4 1 RPM MWD 4 OHMM 4 1 RPD MWD 4 OHMM 4 1 FET MWD 4 HOUR 4 1 NPHI MWD 4 PU-S 4 1 FCNT MWD 4 CNTS 4 1 NCNT MWD 4 CNTS 4 1 RHOB MWD 4 G/C3 4 1 DRHO MWD 4 G/C3 4 1 PEF MWD 4 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Min Max Mean Nsam DEPT 5429.5 8500 6964.75 6142 ROP 0 1443 157.381 5904 GR 64.81 264.9 133.028 5902 RPX 1.04 49.77 4.86586 5896 RPS 1.02 46.58 4.97551 5896 RPM 1.03 41.32 4.86859 5896 RPD 1.1 36.8 5.06982 5896 FET 0.56 10.41 1.52598 5896 NPHI 14.42 51 37.2379 5897 FCNT 150.82 875.59 252.279 5897 NCNT 20096.2 40965.7 25987.5 5897 RHOB 2.12 3.13 2.42083 5896 DRHO -0.05 0.83 0.0587025 5896 PEF -0.66 5.77 3.01596 5896 First Reading 5429 5 5548 5 5455 5 5465 5 5465 5 5465 5 5465.5 5465.5 5429.5 5429.5 5429.5 5445.5 5445.5 5445.5 Last Reading 8500 8500 8406 8413 8413 8413 8413 8413 8377.5 8377.5 8377.5 8393 8393 8393 First Reading For Entire File .......... 5429.5 Last Reading For Entire File ........... 8500 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ................ ~ ..... 98/11/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
