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198-204
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-335 KUPARUK RIV U TARN 2N-335 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-335 50-103-20274-00-00 198-204-0 G SPT 4967 1982040 1500 2820 2820 2820 2820 320 380 365 360 4YRTST P Adam Earl 8/1/2022 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2N-335 Inspection Date: Tubing OA Packer Depth 1600 2200 2170 2170IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803195650 BBL Pumped:0.5 BBL Returned:0.5 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:29:11 -08'00' • 335' ConocoPhillips RECEIVED Alaska APR 0 6 2016 P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 g� April 4, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 CANNEL APR 0 8 2016: Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. No cement was pumped. The corrosion inhibitor/sealant was pumped March 25, 2016 &March 28, 2016. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ! 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 4/4/2016 1D-10,2N-302,2N-331,2N-335,2N-243&2X-1 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-10 50029228700000 1980490 11" NA 11" NA 4.00 3/25/2016 2N-302 50103203800000 2011150 10" NA 10" NA 5.90 3/25/2016 2N-331 50103202650000 1981170 20" NA 20" NA 10.00 3/28/2016 2N-335 50103202740000 1982040 23" NA 23" NA 15.50 3/28/2016 2N-343 50103202600000 1980920 26" NA 26" NA 15.50 3/25/2016 2X-01 50029209630000 1830840 25" NA 25" NA 9.00 3/25/2016 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing 17 Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Conductor Extension r) 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-204 3.Address: 6.API Number: Stratigraphic r Service rJ P. O. Box 100360,Anchorage,Alaska 99510 50-103-20274-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375074 KRU Tarn 2N-335 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 12077 feet Plugs(measured) none true vertical 5325 feet Junk(measured) none Effective Depth measured 11891 feet Packer(measured) Seal Assy 11251 true vertical 5250 feet (true vertical) Seal Assy 4963 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108' 108' SURFACE 2421 7.625 2450' 2347' PRODUCTION 11131 5.5 11280' 4977' PROD LINER 774 3.5 12055' 5316' RECEIVED Perforation depth: Measured depth: 11511-11561, 11574-11584, 11614-11634, 11642-11672 MAR 2 9 2016 True Vertical Depth: 5084-5107, 5113-5117, 5131-5139, 5143-5156 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 11268 MD,4963 TVD Packers&SSSV(type,MD,and TVD) Baker-Seal Assy 11251 MD,4963 TVD; SSSV=None 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA 1 2.0%Treatment descriptions including volumes used and final pressure: ,-yCkx 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development r Service F.7 Stratigraphic r- Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG P 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: 316-102 Contact MJ Loveland Email: n1878(C17conocophillips.com Printed Name MJ J LovelandTitle: NSK Well Integrity Supervisor Signature / Phone:659-7043 Date / ./M// X oz S` 44.,t/e_/ t' VT'- 'i/, //6 Form 10-404 Revised 5/2015 /4 (-07-4.6 RBDMS t" MAR 31 2016 Submit Original Only • • . . RECEIVED ConocoPhillips MAR 2 9 201 Alaska P.O. BOX 100360 AOGGC ANCHORAGE,ALASKA 99510-0360 March 25, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well 2N-335, PTD 198-204, Sundry#316-102 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Lov and ConocoPhillips Well Integrity Projects Supervisor • • 2N-335 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/11/16 Prep and weld 23" long extension on conductor made with 16" .375 wall pipe. x ' . . „....2. ., 4 , .A iiiit , n ::::,7),..„.....i::,',.;.!.:4',''': ' -- A „,,,,_:,.: .,..,, , ,. . ,,,...,.....,,,,,;,.,„.„,..„, ,. . .... ,, . . r'.."V'''' 7 . ... , _, , , ‘,. ,,,.. rn. «4 a s” ,. g '_ f a „ ;4,';''',.,..; d fix. 0 , ;of,ill , tsn tilit'' - ' t, : Ir. ,, f ;,',..'',! .,,,-,i'P'..;.,:ii.20';',4','":-,',%0:,,''', .,-,,-:r-.'.' ",T'at,‘0.,i',..os'Irrt,.4,..„,•':'' ''''','''.'''..''''''' . . � , t , 1 r 2N-335 PTD 198-204 "Copyright 2016 All rights reserved . This photograph is provided '�to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibitedwithout the express consent of t_ ConocoPhillips Alaska , Inc.” , ,, .' '# +c�''.!w �*i �ae Il" m= t T «. x�t[P d� ,tf R l A n� :lx i'� 4. ` o a I a fi � �; a .� sj�' Y� 63 } *p ,� Et . ,': �s' a � kTN: vu s•, t ag' �a x 11i':, ,.,•:,,;,;::::,,B"' ^ s p iIIPJ!L! '� ., 4/.,:')„,,,.„:.',,''.', :''.,4..,i.l,.',,.',...,..:,.:,,;4...:.,,-.,',.,:',i,'f:..,,,...„' b. ° ," " i# ` mo„. des., s 5 ` ii, . '' e a vg �,of 71 • • ocsc-2,4f . g\��\ 1/ , s, THE STATE Alaska Oil and Gas 41 �, of Conservation Commission _;,T,.€_ ALAS <:A S f# �� 333 West Seventh Avenue "11.71 c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �_�ti p�, ;-- � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. SCANNED UP ,,_+ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU Tarn 2N-335 Permit to Drill Number: 198-204 Sundry Number: 316-102 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Si / ,4 „ Cathy :. Foerster Chair DATED this/( day of February, 2016. RBDMS c k- TEO 1 E 1 1 2016 • • RECEIVED • STATE OF ALASKA 20 516 FEB 016 ALASKA OIL AND GAS CONSERVATION COMMISSION ZF APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ,%r 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate " Repair Well Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing P • Other: Conductor Extension W. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 198-204 3.Address: 6.API Number: Stratigraphic r Service r , P.O. Box 100360,Anchorage,Alaska 99510 50-103-20274-00 . 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No p 1 KRU Tarn 2N-335 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375074 • Kuparuk River Field/Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12077 5325 11891' 5250' 3400' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108' 108' SURFACE 2421 7.625 2450' 2347' PRODUCTION 11131 5.5 11280' 4977' PROD LINER 774 3.5 12055' 5316' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11511-11561, 11574-11584, 11614- 11634, 11642-11672 , 5084-5107,5113-5117,5131-5139, 5143-5156 3.5 L-80 11268 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=Nipple ' MD=508' TVD=508' Packer-None-Baker-Seal Assy , MD=11251 TVD=4963' 12.Attachments: Proposal Summary r WellBore Schematic p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17• 14.Estimated Date for 15. Well Status after proposed work: 02/25/16 OIL r WINJ r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r, GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: n1878(ir)conocophillips.com ////// Title: NSK Well Integrity Supervisor Signature Date: 3//6-72 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\ - — \ 02 Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: h e to el 0 C Vivi T h f I'v`1 5 i d z -i c r CI�G1 r--e jQ 1` P c Post Initial Injection MIT Req'd? Yes r No l''57; Spacing Exception Required? Yes r No Subsequent Form Required: l0 —4-b APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2-/O_ /6 v'r /q J. O �{ -PA-PA /C Submit Form and Form 10-403 Revised 11/2015 HdPplr e p li a o is va id for 12 months from the date of approval. RBDM,Schments Seligati ni6 • • REFECB 0E512 V ConocoPh i l h ps Alaska AOGcc P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 3, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-335, PTD 198-204 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, /7/7/7; MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2N-335 (PTD 198-204) SUNDRY NOTICE 10-403 APPROVAL REQUEST 02-03-16 This application for Sundry approval for Kuparuk well 2N-335 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 23". / With approval,the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage if it is exposed. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP INJ • 2N-335 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) ,-,...tips`:_:` 501032027400 TARN PARTICIPATING AREA INJ 77.63 4278.84 12,077.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-335.7/22/20158.16:46 PM SSSV:NIPPLE Last WO: 35.611 10/19/1998 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 11,667.0 7/5/2015 Rev Reason:SET PATCH lehallf 7/22/2015 HANGER:257 Casing Strings a -F a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 29.0 108.0 108.0 62.58 H-40 WELDED L J, - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread `L ± SURFACE 7 5/8 6.875 29.0 2,450.4 2,347.2 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 5 1/2 4.950 28.0 12,054.5 5,315.8 15.50 L-80 LTC-MOD • @ 11280' alar. Tubing Strings I Tubing Description I String Ma...I ID(in) I Top(ftKB) I Set Depth(ft..f Set Depth(NA)(...I WI(I Mt) 'Grade I Top Connection ,/.N CONDUCTOR;29.9-108.0p..4q,M/. TUBING 31/2 2.992 257 11,268.51 4,971.1 9.30 L-80 EUE8RDMOD Completion Details ow NIPPLE;508.5 ims Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(`) Item Des Com (in) 25.7 25.7 0.00 HANGER FMC GEN V 5M TUBING HANGER 3.500 508.5 508.5 1.47 NIPPLE CAMCO DS NIPPLE 2.875 '.. 11,141.5 4,908.6 60.12 SLEEVE-C BAKER CMU SLIDING SLEEVE;CLOSED 3/3/2015 2.813 11,244.0 4,9592 60.87 NIPPLE CAMCO D NIPPLE 2.750 11,251.1 4,962.7 60.95 LOCATOR 'BAKER LOCATOR 2.985 11,251.9 4,963.1 60.96 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 Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 11,135.0 4,905.4 60.16 PATCH WET PATCH(OAL 23') 7/19/2015 1.750 Perforations&Slots SURFACE;29.0-2,450.4 Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,511.0 11,561.0 5,084.0 5,106.8 S-5,S-3,2N- 6/23/1999 6.0 APERF 2.5"HC;alternating GAS LIFT;6,361.7 335 BH/DP 11,574.0- 11,584.0' 5,112.6 5,117.1 S-3,2N-335 6/23/1999 6.0 APERF 2.5"HC;alternating BH/DP 11,614.0 11,634.0 5,130.5 5,139.4 S-3,2N-335 6/22/1999 6.0 APERF 2.5"HC;alternating BH/DP 11,642.0 11,652.0' 5,142.9 5,147.3 S-3,2N-335 10/31/1998 4.0 IPERF 2.5"HC;90 deg ph SLEEVE-C;11,141.5 PATCH;11.135.0 11,652.0 11,672.0 5,147.3 5,156.1 S-3,2N-335 10/31/1998 4.0 IPERF 2.5"HC;90 deg ph Stimulations&Treatments Min Top Mao Btm Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn GAS LIFT;11,191.6 I 11,642.0 11,672.0 5,142.9 5,156.1 FRAC 11/2/1998 'PUMP FRAC AS DESIGNED WITH 508 DELAYED XL GEL AND 2 PPG TO 8 PPG AT 15 BPM AND AVG.PRESSURE OF 3643#SCREENED OUT AT 6603#PUMPED 7#TO PERFS TOTAL OF 187,147 LBS WITH 164,428 LBS TO PERFS LEFT 22719LBS IN PIPE NIPPLE;11,244.0 Mandrel Inserts St ati NTop(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 6,361.7' 3,496.7'CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 10/19/1998 8:00 LOCATOR;11,251.1 9 S 2' 11,191.6' 4,933.5 CAMCO KBG-2- ' 1'GAS LIFT DMY BTM 0.000 0.0 1/30/2002 430 SEAL ASSY;11,251.9 9 Notes:General&Safety IR End Date Annotation gi 1/30/2002 NOTE:CONVERTED TO INJECTOR 11/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;11.511.0-11.561.0 APERF;11,574.0-11,594.0 APERF;11.614.0-11,634.0 IPERF;11,642.0-11.652.0 FRAC;11,642.0 IPERF;11,652.0.11,672.0 PRODUCTION 5.5"93.5"5 11280%28.0-12,054.5 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,August 26,2015 TO: Jim Regg '7. c i1 P.I.Supervisor lei ` 1S" SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 2N-335 FROM: Johnnie Hill KUPARUK RIV U TARN 2N-335 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T6g— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-335 API Well Number 50-103-20274-00-00 Inspector Name: Johnnie Hill Permit Number: 198-204-0 Inspection Date: 8/4/2015 Insp Num: mitJWH150809134809 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-335 1Type Inj w TVD 4967 .1Tubing 925 - 925 925 925 1982040 SPT 1500 1600 2295 • 2250 2250 t PTD ' Type Test Test psi IA Interval OTHER P/F P ✓ OA 347 413 400 400 Notes: MITIA post patch per Sundry#315-386 scANNEI ; Wednesday,August 26,2015 Page 1 of 1 STATE OF ALASKA ' AL __,(A OIL AND GAS CONSERVATION COMiviiSSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed. Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Install Tubing Patch 1?' 2.Operator Name: 4 Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Development r Exploratory r 198-204 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20274-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 375074 KRU 2N-335 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s): NONE Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 12077 feet Plugs(measured) none true vertical 5325 feet Junk(measured) none Effective Depth measured 11891 feet Packer(measured) none true vertical 5250 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108 SURFACE 2421 7.625 2450 2347 PRODUCTION 12027 5.5 12055 5316 Perforation depth: Measured depth: 11511-11561, 11574-11584, 11614-11634, 11642-11672 True Vertical Depth: 5084-5107, 5113-5117, 5131-5139, 5143-5156 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 11269 MD,4963 ND Packers&SSSV(type,MD,and TVD) no PACKER NIPPLE-CAMCO DS NIPPLE @ 509 MD and 508 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 shut-in , Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p' Exploratory r Development r Service Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG 17 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 0 Exempt 315-386 Contact Tyson Wiese @ 263-4250 Email Tvson.M.Wieseconocophillips.com Printed Name Tyson Wi e Title Sr. Wells Engineer Signature 2c Phone:263-4250 Date CW 1,)1 t, 5 VTL el/z//5 RBDMSJ\ AUG 1 4 2015 A 4A,c , Form 10-404 Revised 5/2015 Submit Original Only KUP INJ 2N-335 ConocoPhillips m Well Attributes I Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CantoCorioccrIttilEpx 501032027400 TARN PARTICIPATING AREA INJ 77.63 4,278.84 12,077.0 " .". Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 29-335,7/22/20158.16.48 PM SSSV:NIPPLE Last WO: 35.61 10/19/1998 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 11,667.0 7/5/2015 Rev Reason:SET PATCH lehallf 7/22/2015 HANGER:25.7 VFr Casing Strings I .-all ! Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len 0...Grade Top Thread CONDUCTOR 16 15.062 29.0 108.0 108.0 62.58 H-40 WELDED a 41-1. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(L..Grade Top Thread SURFACE 75/8 6.875 29.0 2,450.4 2,347.2 29.70 L-80 BTC-MOD .1 L8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 51/2 4.950 28.0 12,054.5 5,315.8 15.50 L-80 LTC-MOD @11280' IIII (I I'U I Tubing Strings Tubing Description String Ma...ID(in) Top(111(13) Set Depth(ft..Set Depth(ND)(. Wt(Ib/ft) Grade Top Connection CONDUCTOR:290-108.0 - TUBING 31/2 2.992 257 11,268.5 4,971.1 9.30 L-80 EUE8RDMOD Il Completion Details NIPPLE;508.5 s I Nominal ID Alf i Top(ftKB) Top(TVD)(kKB) Top Ind f°) Item Des Com (in) 25.7 25.7 0.00 HANGER FMC GEN V 5M TUBING HANGER 3.500 508.5 508.5 1.47 NIPPLE CAMCO DS NIPPLE 2.875 11,141.5 4,908.6 60.12 SLEEVE-C BAKER CMU SLIDING SLEEVE;CLOSED 3/3/2015 2.813 11,244.0 4,959.2 60.87'NIPPLE CAMCO D NIPPLE 2.750 11,251.1 4,962.7 60.95 LOCATOR BAKER LOCATOR 2.985 11,251 9 4,963.1 60.96 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Incl Top(ftKB) (18KB) r) Des Com Run Date ID(in) I 11.135.0 4,905.4 60.16 PATCH WFT PATCH(OAL 23') 7/1912015 1.750 SURFACE;29.0.2,4504-J Perforations&Slots Shot Dens Top(ND) Btm(ND) (shot. Top(kKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,511.0 11,561.0 5,084.0 5,106.8 S-5,S-3,2N- 6/23/1999 ' 6.0 APERF 2.5"HC;alternating GAS LIFT;6.361.7 335 BH/DP 11,574.0 11,584.0 5,112.6 5,117.1 S-3,2N-335 6/23/1999 6.0 APERF 2.5"HC;alternating BH/DP 11,614.0 11,634.0 5,130.5 5,139.4 S-3,2N-335 6/22/1999 6.0 APERF 2.5"HC;alternating Ex BH/DP 11,642.0 11,6520 5,142.9 5,147.3 S-3,2N-335 10/31/1998 4.0 IPERF 2.5"HC;90 deg ph SLEEVE-C;11,141.5 - PATCH; PATCH;11,135.0 !0 . 11,652.0 11,672.0 5,147.3 5,156.1 S-3,2N-335 10/31/1998 4.0 IPERF 2.5"HC;90 deg ph Stimulations&Treatments l Mm Top Max Btm Depth Depth Top(TVD) Bim(TVD) (ftKB) (kKB) (ftKB) (kKB) Type Date Com GAS LIFT.11,191.6 I: 11,642.0 11,672.0 5,142.9 5,156.1 FRAC 11/2/1998 PUMP FRAC AS DESIGNED WITH 50#DELAYED XL GEL AND 2 PPG TO 8 PPG AT 15 BPM AND AVG.PRESSURE OF 3643 8 SCREENED OUT AT 6603#PUMPED 7#TO PERFS TOTAL OF 187,147 LBS WITH 164,428 LBS TO PERFS LEFT 22719LBS IN PIPE NIPPLE;11,24.4.0 1"Y, Mandrel Inserts St n' N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (MB)6,361.7 Model OD(in) Sery Type Type (in) (psi) Run Date Com 6,361.7 3,496.7 CAMCO KBG-2- 1 GAS LIFT 'DMY INT 0.000 0.0 10/19/1998 8:00 LOCATOR:11,251.1 9 =1 2 11,191.6 4,933.5 CAMCO KBG-2- 1 GAS LIFT 'DMY BTM 0.000 0.0 1/30/2002 4:30 SEAL ASSY;11.251.99 Notes:General&Safety End Date Annotation 1/30/2002 NOTE:CONVERTED TO INJECTOR 11/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;11,511.0-11,561.0 APERF;11,574.011.584.0 _ APERF;11,614.011.634.0 IPERF;11,642.0-11,652.0 FRAC;11,642.0 IPERF;11,652,0-11,672.0 PRODUCTION 5.0"03.5' 11260',28.0.12.0545 2N-335 WELL WORK SUMMARY DATE SUMMARY 7/4/2015 PULLED EQ PRONG &ATTEMPT TO PULL CA-2 PLUG BODY @ 11,244' RKB. IN PROGRESS. 7/5/2015 PULLED CA-2 PLUG BODY © 11244' RKB, TAG TD © 11667' SLM (EST 6' OF RAT HOLE); MEASURE SBHP @ 11592' RKB; BRUSH n' FLUSH PATCH INTERVAL FROM 11100-11200' RKB; DRIFT W/ DMY PATCH DOWN TO 11210' SLM. IN PROGRESS. (READY FOR DSL PATCH) 7/18/2015 B&F TBG DOWN TO GLM @ 11,191' RKB, SET WFT 3-1/2" LOWER PACKER @ 11,158' RKB, LRS PERFORMED PASSING CMIT-TxIA TO 2500#W/TEST TOOL IN LOWER PACKER JOB IN PROGRESS. 7/19/2015 SET 3-1/2" WFT LE PATCH (OAL = 23') @ 11,135' - 11,158' RKB*****SEE WSR FOR DETAILS***** MIT-T TO 3000#W/ LRS &TEST TOOL IN UPPER PATCH, MIT-IA TO 3000#....JOB DONE. 7y (<0F).' ��7:.sv THE STATE Alaska Oil and Gas ; 7A ofA L A ; Conservation Commission .„.."...„ _. =--110ilit_ u x__,_w_. 333 West Seventh Avenue ��*h„ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oFALAS* Fax 907 276 7542 www aogcc.alaska.gov Tyson Wiese SCA Sr. Wells Engineer . ab Lt- ConocoPhillips Alaska, Inc. ‘ ‘>,..I1 P.O. Box 100360 1 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-335 Sundry Number: 315-386 Dear Mr. Wiese: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely,ACathy . Foerster Chair DATED this 25 day of June, 2015 Encl. STATE OF ALASKA �-�� ' r _SKA OIL AND GAS CONSERVATION COP. ;SION r _, `� APPLICATION FOR SUNDRY APPROVALS `tel' �;1� 20 AAC 25.280 1.Type of Request. Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well rRe-enter Susp Well r Other: Install a�tVchbi , Fi 2.Operator Name: 4.Current Well Class: 5.Permit to Dril umber: ConocoPhillips Alaska, Inc. • Exploratory r Development r 198-204 • 3.Address: 6.API Number. Stratigraphic r Service r. P.O. Box 100360,Anchorage,Alaska 99510 50-103-20274-00 ' 7.If perforating, 8.Well Name and Numt> g `Fes. i'1 'E What Regulation or Conservation Order governs well spacing in this pool? 1 �+ ' Will planned perforations require spacing exception'? Yes r No TV KRU 2N-335 ' II I Nn 1 9 cud 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 375074 . Kuparuk River Field/Tarn Oil Pool - -1,#k-)01:1-' ,A* r",= - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft)• Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured)' 12077 - 5325 - 11244' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108' 108' SURFACE 2421 7.625 2450' 2347' PRODUCTION 12027 5.5 12055' 5316' Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft). 11511-11561,11574-11584,11614-11634,11642-11672 5084-5107,5113-5117,5131-5139,5143-5156 3.5 L-80 11269 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) no packer NIPPLE-CAMCO DS NIPPLE MD=509 TVD=508 • 12.Attachments: Description Summary of Proposal p' 13. Well Class after proposed work. Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 17' 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work. 6/26/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval. Date: GAS r WAG p• GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 Email. Tyson.M.Wiese@conocophillips corn Printed Name Tyson Wiese Title: Sr. Wells Engineer Signature V Phone.263-4250 Date 6—I- -1. \5 Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 315 . 3 (0 Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r - Other: �� V/l�G�d �F. Cr . of 1i.5L� 1�7�<< �' ` Spacing Exception Required? Yes ❑ No Subsequent Form Required: j -4o4- APPROVED BY // Approved by:� COMMlscinnicn - - -- Date: l0 L5--i VTC (0�2 �/�p^ pr°ved appl cation Is valid I. Submit Form and Form 10-403 Revised 5/2015 a 10 f L* O R I G I N A�.. Attachments in Duplicate u 1 2N-335 Tubing Patch Installation Permit to Drill #: 198-204 6/18/2015 2N-335 was drilled and completed in October 1998, as a Tarn Producer. In 2002, the well was converted to an MWAG injector. This well is supporting off-set producers 2N- 333 and 2N-350A. On 4/30/2015, a leak detect log identified a leak at approx. 11,149' KB (top of the Baker CMU). The objective of this procedure is to install a patch across the known leak @ 11,149' KB, isolating the leak as well as the sliding sleeve below. The estimated off-set NOB associated with a successful patch job is approx. 175 BOPD. Procedure: Digital Slickline: (Install and Test Retrievable Patch Assembly) 1. Drift the tubing to the 2.75" D-nipple @ 11,244' KB. 2. Pull the existing 2.75" CA-2 plug @ 11,244' KB. 3. Obtain an accurate fill tag depth, to ensure the injection perfs are clear of fill. 4. If fill level is covering injection perfs, a Coil FCO may be performed. 5. Brush and Flush the tubing from 11,100' — 11,200' KB. 6. Perform dummy drift of the 23' retrievable patch assembly to approx. 11,200' KB. 7. RIH and set lower patch packer @ approx. 11,158' KB. 8. Set test tool in packer and perform C-MIT to 2,500 psi. Record Results. 9. Pull test tool, RIH and set upper patch assembly @ approx. 11,133' KB. 10. Set test tool in upper patch packer and perform MIT-T to 3,000 psi. Perform MIT- IA to 2,500 psi to confirm snap latch integrity. Record Results. 11. Pull test tool. Turn well over to Operations. RDMO. • KUP INJ 2N-335 ConocoPhil li ps ='& Well Attributes Max Angle&MD TO Alaska,Inc. Wellbore API/UWI Field Name Wellbore Statuslino!(") MD(ftKB) Act Btm(ftKB) ,,,,,,I,p, 501032027400 TARN PARTICIPATING AREA INJ 77.63 4,278.84 12,077.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2N-335,6/11/201512;58:33 PM SSSV:NIPPLE Last WO: 35.61 10/19/1998 vertical schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 11,627.0 8/4/2014 Rev Reason:MANDREL ORIENTATION hipshkf 6/11/2015 HANGER:257 . '- Geeing Strings ir Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 29.0 108.0 108.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 all at. SURFACE 75/8 6.875 29.0 2,450.4 2,347.2 29.70 L-80 ETC-MOD I Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len0...Grade Top Thread PRODUCTION 5.5"x3.5" 5 1/2 4.950 28.0 12,054.5 5,315.8 15.50 L-80 LTC-MOD @ 11280' II 'W'Tubing!Strin a Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection .n.'./CONDUCTOR;29.0-108.0 ,; ,I CompletionTUBING Details Nominal 2.9921 25.71 11,268.51 4,971.11 9.301 L-80 I EUE8RDMOD Nominal ID NIPPLE;508.5 1 al I Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 25.7 25.7 0.00 HANGER FMC GEN V 5M TUBING HANGER 3.500 508.5 508.5 1.47 NIPPLE CAMCO DS NIPPLE 2.875 11,141.5 4,908.6 60.12 SLEEVE-C BAKER CMU SLIDING SLEEVE;CLOSED 3/3/2015 2.813 11,244.0 4,9592 60.87 NIPPLE CAMCO D NIPPLE 2.750 11,251.1 4,962.7 60.95 LOCATOR BAKER LOCATOR 2.985 11,251.9 4,963.1 60.96 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) , Top(TVD) Top Incl Top(ftKB) I (ftKB) (°) I Des I Com I Run Date I ID(in) 11,244.0 4,9592 60.87 PLUG 2.75"CA-2 PLUG 8/11/2014 0.000 Perforations&Slots SURFACE;29.0-2,450.4 . Shot Dens Top(NS) Btm(ND) (shotsM Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 11,511.0 11,561.0 5,084.0 5,106.8 S-5,S-3,2N- 623/1999 6.0 APERF 2.5"HC;alternating :11 335 BH/DP GAS LIFT,6.361.7 11,574.0 11,584.0 5,112.6 5,117.1 S-3,2N-335 6/23/1999 6.0 APERF 2.5"HC;alternating Leak ^ ill 11,614B 11,6340 2.5"HC;alternating BH/DP 111 BHDP SLEEVE-C;11.1415 'I I 11,642.0 11,6520 5,142.9 5,147.3 S-3,2N 335 10/31/1998 4.0 PERFF 2.5"HC;90 deg ph 111 11,6520 11,672.0 5,147.3 5,156.1 S-3,2N-335 10/31/1998 4.0 (PERF 2.5"HC;90 deg ph I Stimulations&Treatments GAS LIFT,11.191.6 MM Top Max Btm Depth Depth Top(ND) Btm(TVD) I (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 11,642.0 11,672.0 5,142.9 5,156.1 FRAC 11/2/1998 PUMP FRAC AS DESIGNED WITH 50#DELAYED XL GEL AND2 PPG TO8 PPG AT 15 BPM AND AVG.PRESSURE OF 3643#SCREENED OUT AT PLUG:11.244.0, I/// 6603#PUMPED 7#TO PERFS TOTAL OF 187,147 NIPPLE;11,za4.o /�/I NSP WITH 164,428 LBS TO PERFS LEFT 22719LBS I Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) _ (ftKB) _ Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn LOCATOR,11.251.1 1 6,361.7 3,496.7 CAMCO KBG-2- 1 GAS LIFT DMV INT 0.000 0.0 10/19/1998 8:00 I 2 11,191.69 SEAL ASSY,11 251 9 4,933.5 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 1/30/2002 4:30 9 •Y Notes:General&Safety End Date Annotation 1/30/2002 NOTE:CONVERTED TO INJECTOR 11/23/2010 NOTE:View Schematic wl Alaska Schematic9.0 Lecjk CCV 'So,4 J i:00,1c cMv 51A - - -4414411-4: , ', ,,1k \ak IL cMo APERF.14511 0 APERF;11,574.011,584.0 APERF,11,614.011,634.0 -(PERF;146420-11,652 0 `I FRAC,11642.0 (PERF;11,652 0-11,672.0 PRODUCTION 55'(3.5" 112801,28.0-12.054.5 t 9 t-2Q<{ 251 1 WELL LOG TRANSMITTAL DATA LOGGED Igno15 K BENDER To: Alaska Oil and Gas Conservation Comm. June 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECLIVED JUN 19 2U1'..; RE: Multi Finger Caliper(MFC): 2N-335 Run Date: 6/17/2015 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-335 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20274-00 SCANNED j L 1 b z(i 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: 15...eoteeft • • Page 1 of 1 Regg, James B (DOA) From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM ~ a ~~zE~~f To: Regg, James B (DOA) ~( Subject: RE: State MITIA test results for 2N pad on 8/24/10 ~^ l Follow Up Flag: Follow up ,' I'~, Flag Status: Red ~t,~ ~~ "' ~~5 Attachments: MIT KRU 2N Pad DRAFT.xIs Jim, apologize for the mix up I am filling in for Brent this week and by mistake I did not double check the form before sending it off. Therefore I did not notice that it was showing 12 water injectors SI. I have attached the correct copy and again I am sorry about this mistake on my part. If you have any more questions please feel free to contact me. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 25, 2010 2:36 PM To: Phillips, Jim (ASRC Energy Services) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Why were all the wells SI except the gas injector? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 8:57 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: State MITIA test results for 2N pad on 8/24/10 All, Attached is the MITIA tests for 2N pad that were waived by Chuck Shieve on 08/24/10. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 8/26/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks~alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Ina C ~~Z~I/ G FIELD /UNIT /PAD: Kuparuk /KRU / 2N 1"`l/ DATE: 08/24/10 OPERATOR REP: Ives/Mouser AES AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2011150 T etest P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W ND 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T etest P Test si 1500 Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 WeII 2N-307 T e In'. W ND 5,141' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1990170 T etest P Test si 1500 Casin 810 2,180 2,150 2,150 P/F P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W ND 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 1990210 T etest P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In'. W ND 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,300 2,250 2,250 P/F P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W ND 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W ND 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T e test P Test si 1500 Casin 1,150 2,760 2,720 2,710 P/F P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W ND 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T e test P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T e In'. 1N ND 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 .T.D. 1982040 T etest IP Test si 1500' Casin 560 X2,800 X2,600 .2,590 P/F P Notes: OA 200 430 430 430 Well 2N-343 T e In'. G ND 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W ND 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Well 2N-349A T e In'. G ND 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 2,320 2,250 2,250 P/F P Notes: Well 2N-325 T e In'. P.T.D. 1981630 T e test Notes: TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water MIT Report Form BFL 11/27/07 OA 150 250 W ND 5015' Tubin 1,975 1,975 P Test si 1500 Casin 750 2,675 OA 220 250 TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test MIT KRU 2N Pad 08-24-10 Revised1.xls 250 1,975 2,630 240 250 1,975 2,630 240 Interval 4 P/F P INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) C ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 c~~ ~ ~ Dear Mr. Maunder: Enclosed please find a (revised 1013107)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 9/28/07 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, Sea{ant Top-off Report of Sundry Operations (10-404) Kuparuk Fieid Date 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 9116/2007 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 9/27/2007 2N-311 206-179 12" n/a 12" nla 10 9/27!2007 2N-313 198-091 18" n1a 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 • ConocoPhiliips 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: • °~~c^ ocr ,V~Q A/$~ka ~i1~ ~a o 2 ?Opp A~°~0 a~'° C°~issi On 1~~ ac,~ 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, ~~' M.J. vel d ConocoPhillips Well Integrity Projects Supervisor ~`~~ N~~ ~ 7 ~~pU7 • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Tap-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/2812007 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-403 201-239 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 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' 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" nia 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" nla 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-311 208-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 5" n/a 5" n/a 2 9/27!2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 19&190 6" n/a 6" n/a 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" n/a 9.5 9/27/2007 MEMORANDUM . TO: Jim Regg ·~,1t.t-; c¿l t"ß(iY-o P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RlV U TARN 2N-335 Insp Num: mitCS060808192001 Rei Insp Num Packer [Type Inj. I w I TVD ! I " , ,TypeTest \ SPT i Test psi I 7 Interval 4YRTST PIF P . Well I 2N-335 P.T. ! 1982040 Wednesday, August 09, 2006 State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA fNC 2N-335 KUPARUK RIV U TARN 2N-335 Src: Inspector NON-CONFIDENTIAL API Well Number 50-103-20274-00-00 Permit Number: 198-204-0 Depth 4966 Initial I e¡~-' d-0~ Reviewed By: P.I. Suprv :s:¡;l2- Comm Inspector Name: Chuck Scheve Inspection Date: 8/8/2006 1200 2820 15 Min. 30 Min. 45 Min. 2790 I I -~---r------ .-- Pretest IA i , OA 1500 340 500 , i Tubing) 2000 ] 2000 I Notes Pretest pressures were observed and found stable. WelI demonstrated good mechanical integrity. SCANNED AUG 2 42006 60 Min. 500 2780 500 2000 2000 Page I of I , ( (: \ \%-dOY MECHANICAL INTEGRITY RE:FORT' '--, :;pun DA!E: . \C)I~-~'6' oO- OPER & fIELD C:..V'Þ>í: \L0~,(:jl. -lò..,,",,- :. I G R E L £J.. S:::: . \ Ù / \ S. - " ~ WELL NUMJ3 ER d N - s ~ ç' <:'C"'\..)tL~ð :d tL\-(:):;) \C"'~\.~\~'t (J~)~~\(C\~J \Of \<;.-c.v~" " , ;.,~LL D AI A TD: \d () "'- "\ - MD.. SSd S- TVD; :? BID: \\<6<\ \ rID 5dS <.J TVD CasiTIg: S'I;] Shoe: \ "d-<O\ MD TVD i DV: p~ HD .Tvl) ..~,..~~~:: 3~' ;) Shoe: \ dC>S'-\11Ð TVD; :OP: \ \'d<a\ HD :'iD :owoi::g: P ~~~;: \ \d~ \- HI) TVD i Set ê. t P er£s \ \taL..\ ~ to \\<0'\") ',", ::ole Size (p ~ ,,-\ a.n å t:ECF...Al-rIC;~ INTEGRITY - PART f 1 Annulus Press Test: ~p J~~O; 15 min (}<;'d() ; 30 min ð10o. Comments: --~D~~.')f)~~\~\f\' ~(aS~-Od' \ J / MECBJÜ'lICAL INTEGRITY - PART /2 ~ (o\-,~~\ Cement Volumes :', .Amt. Liner ; Csg ~\U ~'-I.. j DV ~~ C i:ü t -.¡ 0 1 toe ov e!:' per:: s Q ~a:c.a 'I.. ~ \ ~ '\ ~'I. \J-..J ~ ~ 'S.. \j~'c.~ c.. \ <ét'\..Á +c:, CD~\ -\~ I(~.~ f(\'J"o. SÇD U , Theoretical TOC Q. ~(J<o '''k S ~ \aaOa CBL ~valuation, =one a.bove perfs S 'l:::"\ ~~ '.\-., a " "I~ -0 \ ; ~n AOGCC File '{~<:; . t."'Kf.\\<Ld'-....\-" ~~~C' ',,\ d'--.. ~ Cement Bond Log (Yes or No) ~~~ Proàu~tion Log: Typ~ Evaluation CONCLUSIONS: ' ?art n: \--\£ ~c..<:..,. S0<L{'J\..o,,<:,,~~~ r ?art: :2: \J\.s:-\~ \~\~~8 . ' - -oO . - !f¿?fv7;). - -0 S ANNE!) fEB 0 «) 2004 . . .. (5. \. WELL LOG TRANSMITTAL II, ProActive Diagnostic Services, Inc. To; State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ' doey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[SI OR CD-ROM FILM BLUE LINE Open Hole I I 1 2N-335 7-17-03 Res. Eval. CH I 1 1 Mech. CH ' Caliper Survey 1 Rpt or 2 Color Signed' Print Name: Phone:(281) 565-9085 Fax:(281) 565-1369 Date · ,,.. :,,, r,:,,.~, :,:,~, C;" ProAoive"Ditignostic Servi~i~s,' In~., PO Box i 369 Stafford TX 77477 E-mail: pds~memorylog.com Website: www. memorylog.com MEMORANDUM THRU: Tom Maunder P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor [.u- DATE: April 25, 2002 Chair SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 2N 309,326, 335 .FROM: John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 M i~.r-1-¥?'¢ ~-¢' ~'~(;X ~4-'~ ' I P.T.D.I 1990210,TyPetestI M I Testpsil 1261 I CasingI 2250I 2960 I 2950 I 29501 P/F I P Notes: we,,riiiii = l pe, j.I I u ,no I=""o I=, o l'n e ='l ~ P.T.D.l'"'~'~':i':'~'"'"iTypetestI U ITestpsil 1205 ICasingI 2250I 295~I 2~60I 2~s0I ~/F I P Notes: WellI 2N.335 I Type,nj.I 'P I T.V.D. I 4963 J Tubing I 2400 I 2400 I 2400 12400 I,nterva, I I P.T.D.I 1982040 ITypetestl M ITestpsil 1241 I Casingl 1150 I 2940 I 2920 I 2900 I P/F I --P Notes: Well P.T.D. Notes: P.T.D. Notes: IType testl I Test psiI I Casing I I I I I P/F I IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4-- Four Year Cycle V= Required by Variance W= Test during VVorkover O= Other (describe in notes) Test's Details As noted in the above test report form no failures were observed. All wells are operating within the area's injection orders. M.I.T.'s performed: 3 Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. cc: none MIT report form 5/12/00 L.G. mit's KRU 3N 4-25-02 Revised js.xlssCANNED JUL ! 9 200~7/8/2002 (' ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Opar.:lIions performed: Ofl;)ratìon stlllidown . rulilubin! 2. Nnrne ot Operator Phillips Alaska, Inc. 3. Address p - O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 110' FNL, 967' FEL, Sec. 3, T9N, R7E,UM At top of productive interval 2494' FSL, 1110' FWL, Sec. 4, T9N, R7E,UM At effective depth At total depth 2332' FSL, 562' FWL, Sec. 4, T9N, R7E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURFACE PRODUCTION PRODUCTION PRODUCTION Length 1 OS' 2301' 11131 ' 774' Size 16M 7-5/SM 5-1/2M 3-1/28 Perforation depth: Slimu~¡I.' Aller r.asing . 5. Type ot Well: Development - Exploratory - Stratigraphic - Service X 12077 feet 5325 feet Plugs (measured) PII~F.,;n!J Pm1urc11e Rnpair wall , Ollu~r X Prod 10 WAG 6. Datum elevation (DF or KB teet) RKB 149 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-335 9. Permit number I approval number 19S-204/ 301-224 10. API number 50-103-20274 11. Field I Pool Kuparuk River Field I Tam Oil Pool Measured Depth 10S' 2450' 11280' 12054' True vertical Depth 108' 2347' 4977' 5316' 11891 feet 5250 feet Junk (measured) me~!iurF'.d 11511.11561; 11574-11584; 11614-11634,11642.11672 RECEIVED Cemented 9 Cu. Yds. High Early 212 sx AS '" & 244 sx Class G & ( 310 sx Class G (included above) true v4::'rticaI5084-5107; 5113-5117; 5131-5139; 5143-5156 Tubing (size, grade, and measured depth) 3-10'2", !J.:1lt,I.-80 Ibfl Ct 11:'81.1' MD CAMCO [,)S @ ~J16' MD. 13. Stimulation or cement squeeze summary .. .... . . . . . Intervals treated (measured) .. .. :." :":.:--NIA. :..:. ".:" ...: . . . , . .. . : Treatment description including volumes used and tinal pressure .... .. .. ..... .. Recresentative Daily Averaae Production or Iniection Data Gas-Mcf Water-Bbl P:1ckF".n. &. SSSV ,typ~ & m~m;urQc:I (h~pth) ~'MD. 14. Prior to well operation Oil-Bbl 298 528 SubSt-:-quent to opelatlûn 15. Attachments Copies of Logs and Surveys run - Dwly Report or Well Operatioll~ X 011 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Jeff A. Spencer c ~. 11 ~~ /h'A /" ßA' y, rr~. ~rv-- Form 10-404 Rev 06/15/88. 8133 G:jS --- MAR 1 :~i 2002 AlaSka Uii Ót Gas Cons. Commission Anchorage . . .. , .. ." .. . .. .... .. . .".. . .. .".. .... . .. . . . . .., Casln~ Pressure BG4 Tublnq Pressure 266 ~92 645 l SII&pfmded Service ..X WAG Inj,Jctor Questions? Call Jeff Spencer 659-7226 Title Production Engineering Supervisor Datepft¡t/d It.:?f:Oz, Prepared by Robert Cn,;stensen 659-7535 ORIGINAL '/ ~ /14 I) /4;r r R§~~fEpl APR 3 b - SUBMIT IN DUPLICATE (' ( 2N-335 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary .. . . 2I14102~inønc~',WA(fEOR.I~tiQn. :. . I . . 179'- Ie; / /99- /'d- / 77'- c' ó2 00 ~ c-~ I 9f).- 10 /ý$--~ ¿;:;~:"' --6 ¿;¿C;.o --C/l dC&~ - jt. dOO -C>~ d- 00 - CJ7 ,;2 00 -10 -. -' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 9951 G-O360 P. Mazzolinl Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Pu1chorage,AJaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Annular Injection during the third quarter of 2000: h(l) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD 1-45 5036 100 0 5136 365 5501 ~') CD 1-03 33505 100 0 33605 385 33990 [; '7 ID-14 33916 100 0 34016 1487.5 35503.6 ~ ~ CDI-25 24860 100 0 24960 8627. 33587 3 2N-341 13544 100 0 13644 20506 34150 ( f 2N -335 25395 100 0 25495 0 25495 ¡I c;-, .:;> 2N-347 14666 100 0 14766 340 15106 -' ? ID-38 33907 100 0 34007 0 34007 ¡.. V ID-30 30492 100 a 30592 0 30592 - -, 2N-318 220 100 0 320 0 320 -- -[J 2N-316 240 100 0 340 0 340 t:-- CD 1-43 285 100 0 385 0 385 ",~,.¢ STATE OF ALASKA ~ ~v,l__I:~ I.;~ [¢.~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ,,/,,~,///~,/,~_.~ APPLICATION FOR SUNDRY APPROVALS /- 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Prod-> MWAG Inj Change approved program _ Pull tubing _ Vadance _ Perforate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development___X RKB 149 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphicm Anchorage, AK 99510-0360 Service__ Tarn Unit 4. Location of well at surface 8. Well number 107' FNL, 975 FEL, Sec. 3, T9N, R7E, UM (asp's 460626, 5911899) 2N-335 At top of productive interval 9. Permit number / approval number 2494' FSL, 1110'FWL, Sec. 4, T9N, R7E, UM 198-204 At effective depth 10. APl number 2379' FSL, 727' FWL, Sec. 4, T9N, R7E, UM 50-103-20274 At total depth 11. Field / Pool 2942 FNL, 4717 FEL, Sec. 4, T9N, R7E, UM (asp's 451584, 5909116) Tarn Oil Pool 12. Present well condition summary Total depth: measured 12077 feet Plugs (measured) none true vertical 5325 feet Effective depth: measured 11891 feet Junk (measured) none true vertical 5250 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 108' 16" 9 cu yds High Early 108' 108' SURFACE 2301' 7-5/8" 212sxAS III 244sx CG 60SX ASI 2450' 2347' PRODUCTION 11131' 5-1/2" 310 sx Class G 11280' 4977' PRODUCTION 774' 3-1/2" Included Above 12054' 5316' Perforation depth: measured RECEIVED true vertical 5084' - 5 5e' JUL 3 1 2001 Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 Tbg (~ 11280' MD. Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) @'MD. Pkr: Baker CSR @ 11261' MD: None, nipple @ 516' MD 13. Attachments Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: Convert to injection 12/2001 16. If proposal was verbally approved Oil ._X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jason Putnam 265-6970 Signedjason~',~am 265-69zo Title: Tarn Engineer Date Prepared by Kelli Wilrnot 265-630.9 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness,, Plug integrity __ BOP Test __ Location clearance __ . Mechanical Integrity Test ~f~, Subsequent form required 10- Original Signed By Commissioner Date Approved by order of the Commission n ........ n___L_~_' Form 10-403 Rev 06/15/88 · ORIGINAL SUBMIT IN TRIPLICATE " ( ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY 2N-335 'f-, ( KRU 2 N-335 NIP (516-517, OD:3.500) TUBING (0-11280, OD:3.500, ID:2.992) API: 501032027400 SSSV T e: NONE Annular Fluid: DSUSW Ref Log Date: TD: 12077 ftKB Max Hole 78 deg @ 4279 An Ie: Gas Lift Mandrel/Dummy Valve 1 (6369-6370, OD:4.725) To Bottom TVD Wt Grade Thread 0 108 108 62.58 H-40 WELDED 0 2450 2347 29.70 L-80 BTC-MOD 0 11280 4977 15.50 L-80 LTC-MOD 11280 12054 5316 9.30 L-80 LTC-MOD Thread EUE-8RD SLEEVE (11149-11150, OD:3.500) PRODUCTION (0-11280, OD:5.500, Wt:15.50) Zone Status Ft SPF Date T e Com ment 50 6 6/23/99 APERF 2.5" HC; alternating BH/DP 10 6 6/23/99 APERF 2.5" HC; alternating BH/DP 20 6 6/22/99 APERF 2.5" HC; alternating BHIDP 30 4 10/31/98 IPERF 2.5" HC; 90 deg ph 5112-5117 5131 - 5139 5143-5156 Gas Lift MandrelNalve 2 (11199-11200, OD:4.725) VMfr V Type V OD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 INT 0.000 0 10/19/98 OV 1.0 BTM 0.313 0 9/28/00 Descri tion ID 2.875 2.813 2.750 2.750 CAMCO DS NIPPLE BAKER CMU SSD Closed 9/27/00; ulled Jet Pum 9/27/00. CAMCO D NIPPLE BAKER CSA 80-40 SEAL (11259-11260, OD:5.500) 11149" set OV 11149'. NIP (11251-11252, OD:3.500) Perf (11511-11561) -----0- Perf (11574-11584) -----0- Perf (11614-11634) -----0-- Perf (11642-11652) -----0- Perf (11652-11672) ------ .-- ----------"----'----'- ---...- -.._-- -------.....--.-..----.-..----------------.....----......-.-----..-.-..-.------...---- '-"""------"---' ---'--"'---------'-------"--------------- '. t ( ~~ ...." AReO Alaska, Inc. Well Name: 2N-335 Rig Name: DOYON 141 Cementing Details Report Date: 10120198 AFC No.: AK9461 Report Number. 13 Field: Tam Casing Size Hole Diameter. Angle thru KRU: Shoe Depth: LC Depth: % washout 5-112" x 3-112" 6-314 1 2054 11891 Centralizers State ty~ used. inletve/s covered and spacing Comments: Description on casing talley. Mud Weight PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 9.8 23 17 22 17 Gels before: Gels after. Total Volume Circulated: 9111 718 :511S Wash 0 Type: Volume: Weight Comments: ARCO Wash 20 bbls 8.4 Spacer 0 Type: Volume: Weight Comments: ARCO 40 12.0 ppg Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight Yield: Comments: Additives: Tail Cement 0 Type: Mix wtr temp: No. of Sacks: . Weight Yield: Comments: G 65 310 1:5.8 1.2 Additives: 2 hs D6oo, 0.1 gps D135, 0.1 gps 047, 3010 D53, 0.8% OM, 0.12"/0 DBOOg Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt Up: Comments: 3.:5 3.0 155 Reciprocation length: Reciprocation speed: Str. Wt. Down: 30 15 fpm 35 Theoretical Displacement Actual Displacement Str. Wt. in mud: 273.8 bbls 27:5.1 Calculated top of cement: CP: Bumped plug: Floats held: 10779 Date: 1 0119/98 yes yes Time:OM5 Remarks:Condittoned mud and staged up pumps untlll fUll returns ~ 3.0 bpm. Pumped 2:5 bbls of fresh water, 20 bbls of 8.4 ppg preflush, 40 bbls of 12.0 ppg Areo spacer and 54.6 bbls of 15.8 ppg cement Displaced cement with 10 bbls of fresh water and 265.1 bbls of seawater. Bumped plug to 2000 psi., reciprocated pipe untllliast 20 bbls of displacement. Had full returns while cementing. Cement Company: Rig Contractor: Approved By: OS DOYON D.Burley ARCO Alaska, Inc. Tarn Stimulation Summary Well: Date: AFC#: Service Co.: Treater: 2N-335 11/2/98 K85107 Dowell Gallegos TVD Top Perf: MD Tbg Tail: Surf. Line Vol.: 5143 11642 7bbls. Pressure Analysis Comments Volume WHTP 100 6675 5985 4799 2820 2652 2300 1820 1160 2460 1662 12118 0 Ibs. 164,247 Ibs. Prop. in Wellbore Prop. in Surf. Equip. 21,148Ibs. 1,571Ibs. Treatment Notes Rigged up DS. Performed fluids quality control on 50# Gel. Temp.=84 degF, pH=7.3 and 300 sec-s Fann visc=46 cpo 408 psi on wellhead before treatment, wellbore containing diesel. Estimated BHP=2220 psi. PT lines to 7350 psi. " Step 1 H2O BD & Stepdown . _... 2 Scour Stage & Stepdown 3 4 XL Gel DF BracketFrac Fluid Volumes Effective Pad: 500 bbls. Proppant Pumped 20/40 Condo 8,671 Ibs. Total Pumped 187,147Ibs. ( -- - 350 100 350 Effective Slurry: 1,103 bbls. 20/40 14,229 Ibs. Prop. in Formation 164,428 lbs. ARC a Reps: Tumage/Riggs Frac Fluid Gradient: 0.435 ISIP 811 FG (lSIP) 0.54 f' \1\ 21\( - ~~ç - 4-~~ ~ Rate 25.2 22.4 17.5 9.3 - ------ ---------- - 15.2 13.2 10.3 5.1 15.1 830 8 795 Treatment Summary .. - - --- ribution: Stirn. Eng. 850 Pad/Slurry Ratio: 45% Total Job Volume 2,902 bbls. Archey/Sman(email) NSK Well Files A TO Central Files ErìcksonlVersteeg 0.57 XS Fric flSDT 2475 2350 2075 1500 ... -'-...--.-- .-- - 210 670 200 190 140 -.. - -----.--.---- 16/20 Tc 11.7 Pc 515 Eff. (%) 0.56 661 60 19.4 - .' - - Fluid: YF150D 10/14 0 lbs. PPA @ Perfs. 7.0 PPA Performed water breakdown, WHTP=59 I I psi @ 12.3 bpm max.. Stepdown test shows extremely high NWB psi, decided to pump scour stages next. Pumped 3 ea. 2 bbl pulses at 5 bpm, bracketed closure between 600 and 440 psi tubing pressure. Performed scour breakdown, WHTP=3650 psi @ 15 bpm max, significant pressure break noted with both scour stages on the perfs. Stepdown test shows much lower NWB psi. Pumped 4 ea. 2 bbl pulses at 5 bpm, bracketed closure between 700 and 650 psi. The pulse data confirmed the cloure picked from the decline. Pumped DF at 15 BPM. Overdisplaced wl5 bbls water. Confirmed the closure picked from the decline analysis. Pumped one 2 bbl pulse after closure that had an ISIP=667 psi. Reran STIMPLAN DF, determined Ct=0.0035 Matched net pressure except for height growth that could be tubing friction related. Went with 100 bbls pre-pad, 500 bbls pad and a complete design of -200 Mlbs proppant. Pumped bracketfrac. Pad was 25 bbls YF120D followed by 4500 lbs 20/40 sand and 1500 Ibs Dl24 in 215 bbls WF120, flushed with 93 bbls WF120 and 25 bbls YFI20.' Shutdown til WHP = 650 psi. Started pumping frac. BH Prop Con calculation not set up correctly. WHP=2540 psi @ start of pre-pad @ 15 BPM. WHP=5050 @ start of pad. WHP=5270 @ start of 2 ppa flat. WHP=4840 at beginning of ramp. WHP=3480 psi, 15 BPM @ 4.5 ppa in ramp. Samples looked good. WHP=2560 psi, 15 bpm @ 7 ppa. Treating pressure began increasing as the 7 ppa hit the perfs. Nolte-Smith shows increasing pressure at a slope of 5.4 indicating NWB SO during the 7 ppa. Max. pressure was 6190 psi. There was no BHP available on this well due to a failure of the Spartec memory gauge, so any attempt to net pressure history match using the surface pressure is affected by the varying tubing friction. I overlayed the two curves nevertheless. In order to get the magnitudes on the same scale, I had to increase the friction pressure significantly. The trends that the model predicted seemed to be somewhat followed by the actual net pressure. This analysis is extremely qualitative at best, but seems to indicate that the model is somewhat accurate. Without BHP data any further conclusions are not possible. 11/15/98 30000 25000 - -= ,:, E - ~ ~ 20000 15000 10000 5000 Conductivi Profile ,( ~ { At Shut-i o--'.!I At Closur 0---0 O~brt~\ 50 200 100 150 Fracture Penetration (ft) USl~ Q. &-- O.~ 250 ARCO Exploration and Production Technology Friday, October 23, 8:47 AM, Page . ¡ ¡ í î ; ¡ I . ( (~' \ ~~ - d-.O '--\ MECHANI CAL INTEGRITY REPORT' '... =PUD DA!E: to ! Of!e¡ p; :.IG RELE;.S=::. 12!'C¡/C¡¡ OPER & FIELD PAHc r-~.~ w""ELL NUMBER IN 3~5 . I I ,. , ~~~LL DATA TD: /2o77J:ID.. 5 ~2S TVD; ?BTD: 1/ tt'îl MD 5Z$'OTVD ., I J .. Casir.g:'S"l )t~'fl Shoe: ¡'Zt?S"2..HD TVD; DV: MD .T\tu .:....:":1e!:': Shoe: --".D ~ ,¡ I }ill T"TT". 0 ;~up. ....'11.), - . HD .... . , 00 ; ":"'\ C' . _u -.'-' '-' t\ . ") 'It. P acke:!:' II 17' HI) TVD i Set ê. t II L (" I . =:ole Size " 11" (p J let to , .'. ¡/(P77.. " 11 G?'I *t ' . ana Perfs ¡ . f ¡ ¡ i i ! f ¡ t:ECP~1~IC;'.L INTEGRITY - PART 11 Annulus Press Test: ~p 15 min 30 min Comme~ts: No ~'UÎvdlr... ~.Ð~.v\',d ,..- H:ECHÞ_1\fICþ.~ INTEGRITY PART /2 bbl Ç. ; Gs g ~ 3 ~ (, ; D V b~/ c. Cement: Volumes:' þ..mt..Line.r C~t ~ol to covercerfs . 4 'i../ Theoretical Toe q!Lt~ & Cement Bond Log (Yes or No) '1 ; In AOGCC File 1 7/ 'liP/ Lj. L [hdA'Úl/þ 50 pD ¿ J ~"W&(./( . CBL Evaluation, =one above perfs ~ A.a"" ~ý~~¡}¡. . . J . . Proà.uc..tion Log: Typ.e . Evaluation CONCLUSIONS: :>ar- ..tl. - L. t . .. ::>"'r- .rZ. -0. '- T . i 1L.Jts ,"WiAc.^7!¡J ' . . .4~"W¡ \}k..-O\ ~A. f"¿ /1310/ , - . ~ - -- Well Compliance Report File on Left side of folder 198-204-0 KUPARUK RIV U TARN 2N-335 50- 103-20274-00 Roll #1: Start: Stop Roll #2: Start Stop MD 1~2__0_77_.. TVD 05325 Completion Date: 10/19/98 Completed Status: 1-OIL PHILLIPS ALASKA INC Current: Name Interval Sent Received T/C/D D 9128 2-4 SPERRY MPT/GR/EWR4/CNP/SLD OH 4/27/99 4/27/99 L BH PRES-SPIN/TEM FINAL 100-11660 6/24/99 CH 5 7/27/99 8/13/99 L DGR/CNP/SLD-MD FINAL 2487-12077 OH 4/29/99 4/29/99 L DGR/CNP/SLD-TVD FINAL 2364-5324 OH 4/29/99 4/29/99 L DGR/EWR4-MD FINAL 2487-12077 OH 4/29/99 4/29/99 L DGR/EWR4-TVD FINAL 2364-5324 OH 4/29/99 4/29/99 L PRES/TEM/JWL FINAL 75-11652 6/22/99 CH 5 7/27/99 8/13/99 L PROD FINAL 11400-11650 7/5/99 CH 2 8/11/99 8/19/99 R SRVY CALC BHI 108.-12077. OH 11/25/98 11/27/98 Daily Well Ops __ -- __ Are Dry Ditch Samples Required? yes~ And Received? yes IlO Was the well cored? yes no Analysis Description Received? yes (~ Sample Set # Comments: Wednesday, November 08, 2000 Page 1 of 1 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 De~ Ms Mahan: ,'~:~;<~ r-~? ~..~ Please find repoaed below the volumes injected into surface casing'~~aucti~asing annuli during the third queer of 2~0, as well as total volumes injected into annuli for which injection authorization expired during the t~rd queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990- 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 ~oo - I o G, Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD 1-37 32487 100 0 32587 Open, Freeze Protected CD 1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor FROM: John Crisp?//,/u~ C,, SUBJECT: Petroleum Irf'spector 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 Tam 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: Tam, Kuparuk River, 2N 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 GAS or CYCLE 2N-307 1990170 2N-308 1990100 94 70 65 P P OIL 2N-309 1990210 2N-313 1980910 94 70 70 P P OIL 2N-315 19819001 2N-317 1981430 94 70 70 P P OIL1 2N-319 1981970 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730 2N-323 1980710 94 701 70 'P P OIL 2N-325 1981630 2N-329 1980670 94 70 70 P P OIL 2N-331 1981170 ~335': ' 1982040 94 70 70 P ~ OIL 2N-337A 1981220 2N-339 1981000 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% [] 9o 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 Barndt 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, GIN& Number Number PSI PSI Trip Code Code Code G~SorC¥CL~ ~L-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 ~av Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jc'xls 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 of elavation (DF or KB feet): ARCO Alaska, Inc. Development X~. 28' RKB 3. Address: Exploratory_~. 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service ~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 110' FNL, 967' FEL, Sec 3, TgN, RTE, UM 2N-335 At top of productive interval: 9. Permit number/approval number: 2494' FSL, 1110' FWL, Sec 4, T9N, R7E, UM 98-204/399-145 At effective depth: 10. APl number: 2379' FSL, 727' FWL, Sec 4, T9N, RTE, UM 50-029-20274-00 At total depth: ;11. Field/Pool: 2332' FSL, 562' FWL, Sec 4, T9N, R7E, UM Kuparuk River Field / Tarn Oil Pool 12. Present well condition summary Total Depth: measured 12077 feet Plugs (measured) None true vertical 5325 feet Effective Deptt measured 11891 feet Junk (measured) None true vertical 5250 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 108' 108' Surface 2421' 7.625" 212 Sx AS III & 2450' 2347' 244 Sx Class G w/60 Sx AS I top job Production 11233' 5.5" 310 Sx Class G 11261' 4968' Liner 793' 3.5" Included in above 12054' 5316' Perforation Depth measured 11642'-11672' true vertical 5143'-5156' ORI61NAL Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, L-80 EUE @ 11276'NC,,'-'' "~ ~?,~,'~ \! ~ Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 11261'; SSSV: None, nipple @ 516' 13. Stimulation or cement squeeze summary ..... ~ ,¢(:0~'£&0'~cJ'%'~Of'~ Intervals treated (measured) . ~.~.O~'i0i'~? N/A Treatment description including volumes used and final pressure Installed jet pump in production well from 8/20/99 to 10/8/99. 14. Representitive Daily Average Production or Injection Data Oii-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Oil rate varies from 10 to 2500 depending on amount of paraffin in wellbore Prior to well operation 54 247 0 1302 369 Approximate average, water is power fluid used Subsequent to operation 508 358 1340 1374 370 15. Attachments' 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Production Engineering Supervisor Date ~/~/~ \~ Signed SUBMIT IN DUPLICATE Form 10-404 Rev ]6/15/88 ' ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing _ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 110' FNL, 967' FEL, Sec 3, T9N, R7E, UM At top of productive interval: 2494' FSL, 1110' FWL, Sec 4, T9N, RTE, UM At effective depth: 2379' FSL, 727' FWL, Sec 4, T9N, R7E, UM At total depth: 2332' FSL, 562' FWL, Sec 4, T9N, R7E, UM Stimulate Alter casing _ Type of Well: Development X. Exploratory _~. Stratagrapic ___, Service ~ 12. Present well condition summary Plugging _ Perforate _ Repair well _ Other _X 6. Datum of elavafion (DF or KB feet): 28' RKB 7. Unit or Properly: Kuparuk River Unit 8. Well number: 2N-335 9. Permit number/approval number: 98-204/399-145 10. APl number: 50-029-20274-00 11. Field/Pool: Kuparuk River Field / Tarn Oil Pool Total Depth: measured true vertical 12077 feet Plugs(measured) None 5325 feet Effective Dept! measured true vertical 11891 feet Junk(measured) None 5250 feet Casing Length Size Conductor 80' 16" Surface 2421' 7.625" Production 11233' 5.5" Cemented Measured depth True vertical depth 9 cu yds High Early 108' 108' 212 ex AS III & 2450' 2347' 244 Sx Class G w/60 Sx AS I top job 310 Sx Class G 11261' 4968' Liner 793' 3.5" Included in above 12054' 5316' Perforation Depth measured 11642'-11672' true vertical 5143'-5156' Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, L-80 EUE @ 11276' Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 11261'; SSSV: None, nipple @ 516' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A Treatment description including volumes used and final pressure Installed jet pump in production well from 8/20/99 to 10/8/99. 14. Prior to well operation Subsequent to operation Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Oil rate varies from 10 to 2500 depending on amount of paraffin in wellbore 54 247 0 1302 Approximate average, water is power fluid used 508 358 1340 1374 Tubing Pressure 369 370 15. Attachments' Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ 17. I hereb/T;erlify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Production Engineering Supervisor Date Form 1 0-404 Rev ~]6/15/88 SUBMIT IN DUPLICATE 8/11/99 Schlumberger NO. 12742 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Kuparuk,Tabasco Pool Color Well Job # Log Description Date BL Sepia Print 1A-10 i,A.I ~--- INJECTION PROFILE 990719 I 1 1A-11 ~ ! (L.... INJECTION PROFILE 990707 I 1 .!1Y-10 [~! C- MI INJECTION PROFILE 990716 I 1 2A-03 L,t.% ~ INJECTION PROFILE W/PSP 990708 I 1 2M-20 F~RODUCTION PROFILE 990702 I 1 2M-30 ~)~.1 ~ INJECTION PROFILE W/PSP 990722 I 1 2N-321A LA.I ~ INJECTION & STATIC PROF W/PSP 990710 I 1 2N-325 ~ t (:_. INJECTION & STATIC PROF W/PSP 990709 I 1 2N-335 PRODUCTION PROFILE 990705 I 1 2T-28 Lk.I ~ MEMORY INJECTION PROFILE 990715 I 1 2T-202 PRODUCTION PROFILE 990706 I 1 2T-210 STATIC BOTTOM HOLE PRESS SURVEY 990721 I 1 2X-10 PROD PROFILE & GAS LIFT SURVEY 990708 I 1 3H-12 t,~L[ ~ INJECTION PROFILE 990706 I 1 3J-04 I.~1 C~ INJECTION PROFILE W/PSP 990724 I I . . 3J-05 C~.l ~ INJECTION PROFILE W/PSP 990725 I 1 3M-04 STATIC BOTTOM HOLE PRESS LOG 990701 I 1 3M-29 STATIC BOTTOM HOLE PRESS LOG 990701 I I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Scblumberger NO. 12706 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2N-307 LK[~-. MI INJECTION PROFILE 990624 I 1 2N-325 I~t f---- MI INJECTION PROFILE 990625 I 1 2N-335 PR ESS/TEMP/GRAD/JEWELRY 990622 I 1 2N-335 SBHP & SPINNER SURVEY 990624 I 1 2T-28 LJhj, c._ MI INJECTION PROFILE 990626 I 1 2T-209 PROD PROFILE ON CTU 990617 I 1 f-~ ~ ~ ~% it ....... T.,,~' ii. ........ II 'Ii# ,.~,. "U¢:; 1 5 i999 SIGN DATE: ';~"' "~., ~'~ "" ", 'u'~' ;cC'{" Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thart~!'a[~e 7~27~99 STATE OF ALASKA : -ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request.' Abandon Alter casing __ Change approved program __ Suspend __ Repair well __ Pull tubing __ Operation Shutdown__ Reenter suspended well__ Plugging __ Time extension __ Variance X Perforate__ Stimulate __ Other __ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 110' FNL, 967' FEL, Sec 3, T9N, R7E, UM At top of productive interval: 2494' FSL, 1110' FWL, Sec 4, T9N, RTE, UM At effective depth: 2379' FSL, 727' FWL, Sec 4, T9N, R7E, UM At total depth: 2332' FSL, 562' FWL, Sec 4, T9N, R7E, UM 5. Type of Well: Development X.~_. Exploratory ~ Stratagrapic ._~ Service ~ 6. Datum of elavation (DF or KB) 28' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 2N-335 9. Permit number: 98-204 10. APInumber: 50-103-20274-00 11. Field/Pool: Kuparuk River FieldFFarn Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical 12077 feet Plugs (measured) none 5325 feet Effective Depth: measured true vertical 11891 feet Junk(measured) none 5250 feet Casing Length Size Conductor 80' 16" Surface 2421' 7-5/8" Production 11233' 5.5" Cemented Measured depth True vertical depth 9 cu yds High Early 108' 108' 212sx AS III, 244sx CG, 60sx ASI 2450' 2347' 310 Sx Class G 11261' 4968' Liner 793' 3.5" Perforation Depth measured 11642'-11672' true vertical 5143'-5156' Included above 12054' 5316' ORIGINAL Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80, EUE tubing @ 11276' MD. Packers and SSSV (type and measured depth) Pkr: Baker CSR @ 11261' MD; SSSV: None, nipple @ 516' MD. 13. Attachments Description summary of proposal _X Detailed operations program__ BOP sketch_ 14. Estimated date for commencing operation Install jet pump in well - July, 1999 16. If proposal was verbally approved Blair Wondzell Name of approver 15. Status of well classification as: Oil _X Gas __ 07/15/99 Date approved Service Suspended__ 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Signed (~~/~b~ Title: Production Engineering Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness ¢e,,t,4 ~, ¢.,.oOXJ Plug integrety __ BOP test __ Location clearance __ O_4 Mechanical integrety test __ Subsequent form required 10- ~ ],,9~ ORIGINAL SIGNED. 8¥ by order of the Commission RO~JI' N. Christenson Commissioner Form 10-403 Hey 06/15/88 Date I^ppr°va' / Date 6 --~ '""'~q SUBMI I IN I HIPLIC, A I b Attachment 1 Install Jet Pump Tarn Well 2N-335 Well 2N-335 is located in the periphery of drill site 2N. The production history for Well 2N-335 is characteristic of the 2N periphery producers, with intermittent production followed by periods of shut-in time. Well 2N-335 has averaged - 10,550 bbls/month oil production since the well was brought on-line 11/98, which ranks 1 lth among the existing fourteen 2N producers. Paraffin accumulation has been a consistent impediment to production, and has resulted in a complete tubing obstruction. The high deviation of Well 2N-335 is considered a contributing factor to wellbore cooling and consequent paraffin deposition. Testing of Well 2N-335 with gas lift indicates that the proposed jet pump installation will result in sustained production. The water injection test at drill site 2N provides an opportunity to utilize injection water as a power fluid source for a jet pump installation in production Well 2N-335. The jet pump is a reverse circulation pump, and "hard line" with a check valve will tie the injection header to the production annulus. The jet pump will be installed in the production tubing at an open sliding sleeve at 11149', which will result in tubing by annulus communication. A variance for Well 2N-335 is requested for the 90 day period from July 15, 1999 to October 15, 1999 to test the jet pump application. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (- 90 days), and the low annulus injection rate (- 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than - 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Ae: Jet. Pump Approval Request Subject: Re: Jet Pump Approval Request Date: Thu, 15 Jul 1999 15:58:48-0800 From: B lair Wondzell <B lair_Wondzell~admin.state.ak.us> To: Erickson&Versteeg <N 1177@mail.aai.arco.com> CC: Dobson&Sloan <N 1127~mail.aai.arco.com>, Beck&Zuspan <N 1052~mail.aai.arco.com>, Ryan L Stramp <RSTRAMP~mail.aai.arco.com>, Goldmann&Hill <N 1297~mail.aai.arco.com> Hans, Thanks for visiting with me this afternoon on this situation. As I understand that you have only two pipelines to Tarn, one for production and the other for lift gas or injection. Since you will need the line for injection, if the for four subject wells are to be lifted during the test it will have to be with the jet pumps, powered by water. We agree this is a reasonable approach and that your efforts should reduce casing corrision to an acceptable level. Therefore testing jet pumps powered by injection water during the Tarn water injection test is acceptable. Blair Wondzell, 7/15/99 Erickson&Versteeg wrote: Blair, Per our phone conversation 7/12/99, verbal 'approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-335, 2N-337A, and 2N-345 during the ~ 90 day period ending October 15, 1999. --~ Water from the Tarn Mt header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by. annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (~ 90 days), and the iow annulus injection rate (~ 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than ~ 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is ~ 1-2 mils~year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659-7687 1 of 1 7/15/99 4:00 PM Jet Pump Approval Request Subject: Jet Pump Approval Request Date: Tue, 13 Jul 1999 16:27:19-0900 From: "Erickson&Versteeg" <N 1177~rnail.aai.arco.com> To: blair_wondzell@admin.state.ak.us CC: "Dobson&Sloan" <N 1127~mail.aai.arco.com>, "Beck&Zuspan" <N 1052@mail.aai.arco.com>, "Ryan L Stramp" <RSTRAMP~mail.aai.arco.com>, "Goldmann&Hill" <N1297~mail.aai.arco.com> Blair, Per our phone conversation 7/12/99, verbal approval is requested to proceed with the planned jet pump installations at Tarn. Verbal approval is requested since the opportunity to test the jet pumps is limited to the duration of the Tarn water injection test,. Sundry requirements for the jet pump test were not anticipated, and the issues outlined in the sundry request were only recently recognized. Approval is requested to install jet pumps in wells 2N-319, 2N-335, 2N-337A, and 2N-345 during the ~ 90 day period ending October 15, 1999. Water from the Tarn MI header will be injected down the 5-1/2" X 3-1/2" production annulus as power fluid for the "reverse circulation" TRICO jet pump. The jet pump will be installed in the 3-1/2" tubing sliding sleeve, which will allow water entry from the annulus to the tubing. This will result in tubing by annulus communication. A variance is requested for the duration of the test. Due to the existing practice of chemical treating injected water, the short duration of the jet pump test (- 90 days), and the low annulus injection rate (~ 2,000 bwpd), the existing schedule for chemical treating of injection water is expected to be sufficient for the 90 day jet pump test. Produced water used for injection is currently treated with RU 275 at the Kuparuk production wells. In general, pitting and wall loss corrosion in flow lines typically can not be detected by inspection until a coupon indicates a wall loss of greater than - 10 mils/year for at least 2 years. The 1999 coupon data for Kuparuk CPF2 injectors indicates that the average coupon wall loss or pitting corrosion is - 1-2 mils/year. Based on this information, wall loss and pitting in the production annulus is not anticipated for the duration of the 90 day test. Joe Versteeg (907) 659-7687 1 of 1 7/13/99 4:52 PM I-I I=t I I__/I N r~ c;IE FlU I 1-- E S To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 April27,1999 RE: MWD Formation Evaluation Logs 2N-335, AK-MM-80403 1 LDWG formatted Disc with verification listing. API#: 50-103-20274-00 PLEASE ACKNOWLEDGE RECE1PT BY SIGNING AND RETURNING ~ ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: " Signed:. 5631 Silverado Way, Suite g · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMIT~L To: State of Alaska Alaska Oil and Gas C~ationComm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 April 29, 1999 RE: MWD Formation Evaluafion Logs 2N-335, ~(~-MM40403 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-335: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20274-00 2"x 5" TVD Resistivity& Gamma RayLogs: 50-103-20274-00 2" x 5" MD Neutron & Density Logs: 50-103-20274-00 2" x 5" TVD Neutron & Density Logs: 50-103-20274-00 1 Blueline 1 Folded Sepia 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia / / -':~PR 2_. ,9 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS [-~ SUSPENDED E~ ABANDONED~ SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-204 3 Address 8 APl Number P.O. Box 100360, Anchora~]e, AK 99510-0360 50-103-20274 4 Location of well at surface 9 Unit or Lease Name 110' FNL, 967' FEL, Sec. 3, T9N, R7E, UM ! ;~' ::- ;-':, i.. ~ '~ ';-- ~*~"'"'";"*"-'~' '~ Kuparuk RNer Unit At Top Producing Inte~al j~ , .... . 2494' FSL, 1110' ~L, Sec. 4, T9N, R7E, UM ' , ' ' ~ ' '- " : ~ 2N-335 At Total Depth ~Z ~ ~~~ 11 Field and Pool 2332' FSL, 562' ~L, Sec. 4, T9N, R7E, UM '~~~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 120'~ ADL 375074 ALK 4293 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or ~and. ~ 15 Water Depth, if offshore 16 No. of Completions 09-Oct-98 17-Oct-98 19-Oct-98~ NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 12077' MD & 5325' ~D 11891' MD & 5250' TVD YES ~ NO ~ N/A feet MD 1050 APPROX 22 Type Electric or Other Logs Run G~Res, G~CCL 23 CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD J CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT EECOgD 16" 62.5~ H-40 SURF. 108' 24" 9 cu. Yds High Early 7.625" 29.7~ L-80 SURF. 2450' 9.875" 212 sx ASIII, 244 sx Class G, 60 sx ASI 5.5" x 15.5~ L-80 SURF. 11261' 6.75" 310 sx Class G 3.5" 9.3~ L-80 11261' 12054' 6.75" (included above) 24 Pedorations open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER S~ (MD) 3.5" 11276' 11261' (CSR) 11642'-11672' MD 5143'-5156' ~D 26 ACID, F~CTURE, CEMENT SQUE~E, ~C 4 spf DEPTH iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11642'-11672' refer to aUachment Date First Production Method of Operation (Flowing, gas lift, etc.) ~.: . , 11~/98 Flowing Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 11/16/98 12 TEST PERIOI: ~ 447 00 ~ 959 ~t.~ Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL G~VI~-API (corr) II Press. 332 0 24-HOUR ~TE: 932 894 0 38'6° ~ 28 CORE DATA Brief description of lithology, porosily, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate I~ev. 7-!-80 CONTINUED ON I~EVEI~SE 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. T-3 1 lZ145' 5054' T-2 11783' .5204' Annulus left open - freeze protected with diesel. 31. LIST OF ATrACHMENTS Summary of Daily Drilling Reports, Directional Survey 32, I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed ~.~..~.~, J .-~/¢~, Title ~ ~rj ~' ¢~' DATE iI' "?"-(" ~ ~ 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 10-407 Date: 11/24/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-335 WELL_ID: AK9461 TYPE: AFC: AK9461 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:10/09/98 START COMP: RIG:RIG # 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20274-00 10/08/98 (D1) TD: 108' (108) SUPV:G.R. WHITLOCK 10/09/98 (D2) TD: 1355'(1247) SUPV:G.R. WHITLOCK 10/10/98 (D3) TD: 2465' (1110) SUPV:G.R. WHITLOCK 10/11/98 (D4) TD: 2465' ( 0) SUPV:G.R. WHITLOCK 10/12/98 (D5) TD: 3982' (1517) SUPV:G.R. WHITLOCK 10/13/98 (D6) TD: 7086' (3104) SUPV:D.P.BURLEY 10/14/98 (D7) TD: 9002' (1916) SUPV:D.P.BURLEY 10/15/98 (D8) TD:10254' (1252) MW: 8.3 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 RIGGIN UP Move rig from 2N-319 to 2N-335. MW: 10.0 VISC: 96 PV/YP: 24/32 APIWL: 8.8 DRILLING ~ 1850' ON HIGHLI Accept rig at 0500 hrs. 10/9/98. NU diverter and test. Drill from 108' to 1355' MW: 10.2 VISC: 60 PV/YP: 20/15 APIWL: 8.8 TESTING BOPE ON HIGH Drill from 1355' to 2465'. Run 7-5/8" casing. Pump cement. MW: 9.1 VISC: 43 PV/YP: 14/13 APIWL: 9.5 DRILLING 8 2660' ON Finish cementing 1st stage. Cement 2nd stage. NU BOPE and test to 250/3500. Drill out stage collar. Drill cement to 2325. Drill cement, float equipment and 20' of new hole to 2465' Run FIT to 16.2 ppg EMW. MW: 9.1 VISC: 46 PV/YP: 16/15 APIWL: 8.0 DRILLING ~ 4685' ON Drill from 2485' to 3982' MWD failure. POOH to MWD. Service MWD. RIH. MW: 9.2 VISC: 51 PV/YP: 18/20 APIWL: 7.7 DRILLING 6-3/4" HOLE FROM 7330' ON HIGHLI Drill 6.75" hole from 3982' to 7086' MW: 9.2 VISC: 50 PV/YP: 17/19 APIWL: 5.6 POH FOR MOTOR FAILURE. Drill from 7086' to 9189' MW: 9.2 VISC: 47 PV/YP: 14/15 APIWL: 6.5 DRILLING FROM 10675', RAISING MUD WT. TO 9.8 PPG. 24 HRS SUPV:D.P.BURLEY 10/16/98 (D9) TD:11634' (1380) SUPV:D.P.BURLEY 10/17/98 (D10) TD:12077'(443) SUPV:D.P.BURLEY 10/18/98 (Dll) TD:12077' ( 0) SUPV:D.P.BURLEY 10/19/98 (D12) TD:12077'( 0) SUPV:D.P.BURLEY Drill from 9189' to 9441' Encountered motor failure. Circ hole clean, monitor well, pump dry job. POH, no problems. Change out motor. Troubleshoot mwd, obtain shallow test. RIH to 9441', no problems. Drill from 9441' to 10254' MW: 9.8 VISC: 53 PV/YP: 19/22 CONTROL DRILL FROM 12010' APIWL: 5.4 24 HRS HIGHLI Drill from 10254' to 11634' MW: 9.8 VISC: 54 PV/YP: 21/23 LAYING DOWN BHA. APIWL: 4.6 Control drill from 11634' to 12077' (TD vis sweeps and circ hole clean. MW: 9.8 VISC: 47 PV/YP: 17/17 R/D CEMENT HEAD, REMOVE LANDING JOINT. Pumped low/high APIWL: 5.0 RIG OFF HIGH Run 3.5" x 5.5" casing to 7345', encountered partial returns. MW: 0.0 VISC: 0 PV/YP: 0/ 0 MOVING RIG TO 2L-329, ALL MODULES ON L PAD. APIWL: 0.0 Pump cement. Run 3.5" completion. ND BOPE. Release rig @ midnight. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~, K1(2N-335(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-335 FRAC, FRAC SUPPORT 1028981741.3 DATE DAILY WORK UNIT NUMBER 11/02/98 FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES DS-GALLEGOS RIGGS FIELD AFC# CC# Signed ESTI MATE K85107 180 KN U2TN InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 408 PSI 665 PSI 523 PSI 500 PSII 10 PSI 0 PSI DAILY SUMMARY PUMP FRAC AS DESIGNED WITH 50# DELAYED XL GEL AND 2 PPG TO 8 PPG AT 15 BPM AND AVG. PRESSURE OF 3643 # SCREENED OUT AT 6603 # PUMPED 7 # TO PERFS TOTAL OF 187,147 LBS WITH 164,428 LBS TO PERFS LEFT 22719LBS IN PIPE EXPECT TAG @ 7557' MAX PRESSURE ON JOB 6603 PSl.[Frac-Refrac] TIME LOG ENTRY 09:00 MIRU DS TGSM MUSTER AREA 14 PEOPLE ON LOCATION. PT LINES TO 7500 PSI 09:40 PUMP BREAK DOWN STAGE 100 BBL WATER 30 BPM SHUT DOWN 769 ISIP. PULSE TESTS. 10:20 PUMP THE SCOUR STAGE 50 # DELAYED XL GEL 100 BBL @ 15 BPM. 75 BBL 1 PPG 50 # DELAYED XL GEL. 50 BBL 2 PPG 50 DELAYED XL GEL @ 15 BPM. 50 BBL PROP FLUSH 50# DELAYED XL GEL 158 BBL FLUSH W/ WATER. SHUT DOWN ISIP 806 PSI AFTER STEP DOWN. PULSE TESTS. 11:45 PUMP DATA FRAC 100 BBL 50 # DELAYED XL GEL @ 5 BBL. 113 BBL S/WATER FLUSH. SHUT DOWN ISIP 806 PSI PULSE TEST. 13:35 PUMPBRAKETFRAC25BBLYF120D×L@ 15BPM. 72 BBL WF 20, .25 PPG @ 15BPM, 36 BBL WF 20, .50 PPG @ 8 BPM, 72 BBL WF 20.75 PPG @ 8 BPM, 25 BBLYF 120D @ 8 BPM 68 BBLWF 120 @ 8 BPM, AND 25 BBLWF 120 @ 8 BPM. 15:00 PUMP MAIN FRAC W/500 BBL PAD AND PER PROCESURE. 50 # DELAYED XL GEL. 100 BBL 2 PPG, 800 BBL 4.5 PPG, 200 BBL 7 PPG, 15 BBL 8 PPG, 60 BBL 10 PPG AND 98 BBL FLUSH ALL AT 15 BPM AND AN AVG. PRESSURE OF 3646 PSI. 16:50 SCREENED OUT 3 BBL INTO THE 8 LB. RAMP. PUMPED 187147 POUNDS OF PROPPANT WITH 164428 LBS OF 7 LB IN PERFS. LEFT 22719 LBS IN PIPE. EXPECT TAG AT 7537' 17:45 RDMO DS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ~ Kl(2N-335(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-335 PERFORATE, PERF SUPPORT 1021981654.6 DATE DAILY WORK UNIT NUMBER 10/31/98 INITIAL PERFS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 YESI YES SWS-JOHNSON JOHNS FIELD AFC# CC# Signed ESTIMATE K85107 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 50 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED 11,642 TO 11672' WITH 4SPF .[Peri, Frac-Refrac] I TIME LOG ENTRY 07:30 MIRU E-LINE 08:45 09:15 HELD TGSM RIH WITH CCL , 20' - 2.5" HALLOW CARRIER PERF GUN 4 SPF 90 DEG. CCW & 90 DEG. CW AND ROLLERS . TIE IN WITH CCL LOG DATED 10-30-98. SHOT PERFS FROM 11652 TO 11672. POOH. ( PUMPED GUNS DOWN HOLE WITH 2 BPM , USING 250 BBLS DIESEL.) 03:15 RIH WITH 10' PERF GUN ( SAME AS ABOVE) PUMPED GUNS DOWN HOLE WITH 250 BBLS DIESEL. SHOT PERFS FROM 11,642 TO 11,652. POOH. 19:00 RDM0 iii i ii i i ii ii i i i ' , , ~,. ' , . .SURVEY CALCULATION AND FIELD WORKSHEET. Job -, 6 i " Company ARCO ALASKA. INC. Rig Contractor & No. DOYON - 141 , Fie~ld TARN DEVELOPMENT FIELD Well Name & ND.TARN DRILLSITE 2N/335 Survey Section Name P- 1 BHI Rep. ' ' ' WELL DATA Target TVD (VI') Target Coord. N/S Slot Coord. N/S -109.24 Grid Correction 0.000 Depths Measured From:RKl~ MSL~ SS Target Description Target Coord. E/W Slot Coord. E/W -967.49 Magn. Declination 26.820 Calculation McthodMINIMUM CURVATI Target Direction (DD) Build\Walk\DL pd~00ft~ 30m[~ ]0m['-] Vert. See:~ Azim. 2.52.65 Magn. to Map Corr. 26.820 Map North to:OTHER SURVEY DATA ,, , Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date TypeTO°l--.D(el~~ Angle(DD) Direction(DD) L~i~ ~ . TVD(FT) Sect ion N('~S(-,_ -- E(+01~W(-'__ (PerDL100 .v~pBUild (+,(.) RightLeft (-, (+) Comment MWD 108.00 0.00 0.00 108.00 0.00 0.00 0.00 TIE IN POINT , , -- ( tCT-9~ MWD 204.50 0.93 141.98 96.50 204.50 -0.28 -0.62 0.48 0.96 0.96 9 7/8" HOLE 09-OCT-9~ MWD 280.57 1.17 147.00 76.07 280.55 -0.70 - 1.75 1.29 0.34 0.32 09-OCT-9[ MWD 368.08 1.22 154.56 87.51 368.04 -1.08 -3.35 2.17 0.19 0.06 .. 09-OCT-9~ MWD 459.83 1.41 153.24 91.75 459.77 -1.40 -5.24 3.10 0.21 0.21 09- OCT-gE MWD 556.35 1.52 144.85 96.52 556.26 -1.98 -7.34 4.37 0.25 0.11 09-OCT-95 MWD 645.88 1.37 147.00 89.53 645.76 -2.64 -9.21 5.64 0.18 -0.17 09-OCT-9~ MWD 738.37 1.23 150.12 92.49 738.23 -3.15 - 11.00 6.74 0.17 -0.15 09-OCT-9~ MWD 830.51 1.49 144.84 92.14 830.34 -3.73 -12.84 7.92 0.31 0.28 09- OCT- 9~ MWD 918.44 1.49 143.34 87.93 918.24 -4.46 -14.69 9.26 0.04 0.00 09-OCT-9~ MWD 1013.28 1.29 146.39 94.84 1013.05 -5.16 -16.57 10.59 0.22 -0.21 09-OCT-9~ MWD 1099.28 1.50 152.69 86.00 1099.03 -5.63 -18.37 11.64 0.30 0.24 09-OCT-9~ MWD 1188.01 3.14 174.67 88.73 1187.68 -5.32 -21.82 12.40 2.07 1.85 45'-- 190M .,. 0~' !'T- 9~ MWD 1281.19 4.37 181.26 93.18 1280.66 -3.66 -27.91 12.56 1.40 1.32 45'-- 190M 09-0CT-9~ MWD 1376.38 6.24 189.60 95.19 1375.44 -0.16 -36.64 11.61 2.12 1.96 8.76 45'--190M .. 10-OCT-9I MWD 1470.10 8.31 190.52 93.72 1468.40 5.32 -48.32 9.53 2.21 2.21 0.98 45'--HS 10-OCT-91 MWD 1565.51 10.77 192.54 95.41 1562.48 12.98 -63.81 6.33 2.60 2.58 2.12 60'--10R 10-OCT-9! MWD 1657.33 12.60 203.84 91.82 1652.41 23.86 -.81.35 0.42 3.18 1.99 12.31 92'--$0R 10-OCT-gl MWD 1753.15 14.94 214.68 95.82 1745.48 40.48 -101.07 -10.84 :3.63 2.44 11.31 96'--50R 10-OCT-9~ MWD 1850.52 18.17 225.23 97.37 1838.83 63.86 -122.09 -28.76 4.52 3.32 10.83 97'--40R __ 10-OCT-9~ MWD 1942.76 21.66 232.22 92.24 1925.55 92.60 -142.66 -52.44 4.57 3.78 7.58 92'--30R 10-OCT-9~ MWD 2039.06 26.05 236.99 96.30 2013.61 129.63 -165.08 -84.24 4.98 4.56 4.95 97'--30R' 10-OCT-gl MWD 2132.34 30.37 239.66 93.28 2095.79 172.35 -188.16 -121.78 4.82 4.63 2.86 9Y--30R · 10-OCT-9~ MWD 2226.00 34.16 242.94 93.66 2174.98 221.36 -212.09 -165.65 4.46 4.05 3.50 94'--20R tr SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-01 Sidetrack No. 'age Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD ..' Well Name & No.TARN DRILLSITE 2N/335 Survey Section Name P-1 BHI Rep. WELL DATA · .' Target TVD (FT) Target Coord. N/S Slot Coord. N/S -109.24 Grid Correction 0.000 Depths Measnr~l From:RKi~ M$1.~ Target Description Target Coord. E/W Slot Coord. E/W -967.49 Magn. Declination 26.820 Calculation Method MINIMUM CURVATU! Target Direction (DD) Buiid\Walk\DL pdl~0ft[~ 30m~ 10m~] Vert. Sec. Azi.m. 252.65 Magn. to Map Corr. 26.820 Map North to:OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool ---Dfl~ Angle Directior L~,i~~ TVD Section~,S +)~/~,W DL Build(+) Right(+) Comment Type 10-OCT-9~ MWD 2317.91 38.74 246.14 91.91 2248.90 275.40 -235.48 -214.96 5.39 4.98 3.48 92'--20R 1(~ ~T-9~ MWD 2411.99 43.78 249.62 94.08 2319.61 337.20 -258.74 -272.44 5.88 5.36 3.70 94'--20R 12-OCT-9~ MWD 2487.90 45.56 249.04 75.91 2373.59 390.47 -277.58 -322.37 2.41 2.34 -0.76 45'--10R 12-OCT-9~ MWD 2588.50 49.66 253.80 100.60 2441.42 464.70 -301.14 -392.77 5.37 4.08 4.73 60'--25R 12-OCT-9~ MWD 2679.83 55.68 255.84 91.33 2496.78 537.23 -320.10 -462.83 6.83 6.59 2.23 60'--20R 12-OCT-9~ MWD 2774.77 60.20 255.03 94.94 2547.16 617.58 -340.34 -540.68 4.82 4.76 -0.85 60'--HS 12-OCT-91 MWD 2870.11 64.87 255.78 95.34 2591.12 702.05 -361.64 -622.53 4.95 4.90 0.79 60'--HS 12-OCT-9~ MWD 2963.07 70.56 256.80 92.96 2626.36 787.85 -382.00 -706.06 6.20 6.12 1.10 60'--HS 12-OCT-9~ MWD 3056.37 73.58 257.40 93.30 2655.08 876.34 -401.81 -792.58 3.29 3.24 0.64 12-OCT~9~ MWD 3153.46 73.60 257.79 97.09 2682.51 969.13 -421.82 -883.54 0.39 0.02 0.40 12-OCT-9~ MWD' 3247.65 75.21 254.84 94.19 2707.84 1059.65 -443.29 -971.67 3.47 1.71 -3.13 30'--60L 12-OCT-91 MWD 3339.72 75.77 256.10 92.07 2730.91 1148.68 -465.65 -1057.95 1.46 0.61 1.37 12- OCT- 9~ MWD 3434.39 75.13 255.78 94.67 2754.69 1240.16 -487.91 - 1146.84 0.75 -0.68 -0.34 12- v-9~ MWD 3527.97 75.75 254.86 93.58 2778.22 1330.63 -510.86 -1234.46 1.16 0.66 -0.98 20'--80L · 12-OCT-9~ MWD 3621.73 75.82 252.63 93.76 2801.24 1421.50 -536.30 -1321.71 2.31 0.07 -2.38 12- OCT-9~ MWD 3714.38 75.35 253.16 92.65 2824.31 1511.23 -562.70 -1407.47 0.75 -0.51 0.57 13-OCT-9~ MWD 3904.95 74.64 254.39 190.57 2873.65 1695.26 -614.13 -1584.21 0.73 -0.37 0.65 13-OCT-9t MWD 3998.59 75.91 252.53 93.64 2897.45 1785.81 -639.91 -1671.02 2.35 1.36 -1.99 20'--HS 13-OCT-9~ MWD 4094.69 77.14 253.26 96.10 2919.84 1879.26 -667.40 -1760.33 1.48 1.28 0.76 13-OCT-91 MWD 4190.51 77.17 253.74 95.82 2941.15 1972.68 -693.93 -1849.91 0.49 0.03 0.50 13-OCT-9~ MWD 4278.83 77.63 253.53 88.32 2960.41 2058.86 -718.22 -1932.61 0.57 0.52 -0.24 13-OCT-9~ MWD 4374.17 . 75.87 250.52 95.34 2982.27 2151.64 -746.84 .-2020.87 3.58 -1.85 -3.16 15'--LS · 13-OCT-9~ MWD 4467.35 76.06 253.57 93.18 3004.87 2242.02 -774.71 -2106.85 3.18 0.20 3.27 13-OCT-91~ MWD 4564.14 75.90 253.57 96.79 3028.32 2335.91 -801.27 -2196.93 0.17 -0.17 0.00 '1 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-016 Sidetrack o.--3" or 6 Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT:.FIELD . "Well Name & No.TARN DRILI.SITE 2N/335 Survey Section Name P-1 BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -109.24 Grid Correction 0.000 Depths Me. asure, d From:RKl~ MSL~ Target Description Target Coord. E/W Slot Coord. E/W -967.49 Magn. Declination 26.820 Calculation Met hod MINIMuM CURVATU! Target Direction (DD) Build\Walk\DL [xl~0ft~ 30m[-] 10m0 Vert. Sec. Azi.m. 252.65 Magn. to Map Corr. 26.820 Map North to:OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Build (+) Right (+) Comment (DD) (DD) (FT) _ 13- OCT-9~ MW'D 4653.21 76.20 254.27 89.07 3049.79 2422.33 -825.21 -2279.99 0.83 0.34 0.79 13 !T-9~ MV/D 4751.36 73.95 253.78 98.15 3075.07 2517.14 -851.31 -2371.16 2.34 -2.29 -0.50 15'--LS 13-OCT-9~ MgrD 4846.63 74.06 253.22 95.27 3101.32 2608.71 -877.32 -2458.97 0.58 0.12 -0.59 .3-OCT-9~ MWD 4943.70 74.08 252.15 97.07 3127.96 2702.05 -905.10 -2548.08 1.06 0.02 -1.10 , _ 13-OCT-91 MW'D 5036.51 74.44 251.77 92.81 3153.14 2791.37 -932.76 -2633.02 0.55 0.39 -0.41 13-OCT-91 MWD 5129.84 74.40 253.11 93.33 3178.21 2881.27 -959.89 -2718.73 1.38 -0.04 1.44 .,. 13-OCT-9~ MWD 5224.85 74.19 252.21 95.01 3203.93 2972.73 -987.14 -2806.03 0.94 -0.22 -0.95 - 13-OCT-9~ MWD, 5317.84 74.15 251.83 92.99 3229.29 3062.19 -1014.76 -2891.13 0.40 -0.04 -0.41 ,._ 13-OCT-9~ MWD 5409.47 73.94 252.54 91.63 3254.48 3150.29 -1041.71 -2975.00 0.78 -0.23 0.77 --. ._ 3-OCT-9~ MWD 5508.56 75.22 251.76 99.09 3280.83 3245.80 -1071.00 -3065.92 1.50 1.29 -0.79 15'--HS 3-OCT-9~ MWD 5601.74 74.36 250.60 93.18 3305.28 3335.69 - 1100.00 -3151.03 1.51 -0.92 -1.24 13-OCT-91 MWD 5694.08 74.01 251.26 92.34 3330.44 3424.49 -1129.03 -3235.00 0.79 -0.38 0.71 13-OCT-91 MWD 5787.29 75.25 252.86 93.21 3355.15 3514.36 -1156.71 -3320.50 2.12 1.33 1.72 20'--20R 13- "~'- 9~ MWD 5883.10 75.04 252.54 95.81 3379.71 3606.97 -1184.25 -3408.92 0.39 -0.22 -0.33 13~OCT-9~ MWD 5974.17 74.67 251.28 91.07 3403.51 3694.86 -1211.54 -3492.48 1.40 -0.41 -1.38 20'--20R 13-OCT-9~ MWD 6067.04 76.14 253.52 92.87 3426.91 3784.73 -1238.71 -3578.14 2.82 1.58 2.41 13-OCT-9~ MWD 6159.32 76.58 252.88 92.28 3448.67 3874.40 -1264.63 -3663.99 0.83 0.48 -0.69 13-OCT-9~ MWD 6255.29 76.49 253.11 95.97. 3471.02 3967.73 -1291.92 -3753.24 0.25 -0.09 0.24 · 13-OCT-9~ MWD 6349.46 75.68 255.56 94.17 3493.67 4059.09 -1316.60 -3841.24 2.67 -0.86 2.60 13-OCT-91 MWD 6441.75 75.13 254.69 92.29 3516.92 4148.32 -1339.53 -3927.56 1.09 -0.60 -0.94 13-OCT-9~ MWD 6536.62 74.61 254.14 94.87 3541.69 4239.85 -1364.13 -4015.77 0.78 -0.55 -0.58 13-OCT-9~ MWD 6631.61 75.54 255.01 94.99 3566.15 4331.58 -1388.55 -4104.25 1.32 0.98 0.92 20'--20R' 13-OCT-9~ MWD 6724.96 75.43 253.36 93.35 3589.55 4421.92 -1413.17 -4191.19 1.72 -0.12 -1.77 .- 13-OCT-9~ MWD 6819.69 74.62 255.08 94.73 3614.03 4513.39 -1438.06 -4279.25 1.95 -0.86 1.82 i i 'I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0 50-016 Sidetrack No. ~mpany ARCO ALASKA, INC. Rig ~ntractor & No. DOYON - 141 Field TARN DEVELOPME~ Well Name & No.TARN DRIL~E 2N/335 Survey ~tion Name P-1 BHI Rep. WELL DATA. Target TVD {~) Target C~rd. N/S Slot ~rd. N/S -109.24 Grid Correction 0.000 ~pth~ Me~u~d From:RK~ MS~ Target Description Target ~rd. E/W Slot ~rd. E/W -967.49 Magn. Declination 26.820 Calculation Meth~MI~ C~VATU Target Direction (DD) BuiidXWalk~DL p~0ft~ 30m~ 10m~ Vert. Sec. ~zim. 252.65 Magn. to Map Corr. 26.820 Map North to:OT~R I SURVEY DATA Survey Survey Incl. Hole Course Vertical To~al C~rdinatc Build Rate W~lk Rate D;~ ~ ~? +~ Build(+) Right(+) Comment Date TypeT~l Angle(DD) Direction(DD) TVD(~) Section N( (-) E( (- (PerDL100 ~rop (-) ~ft (-) 13-OCT-9~ MWD' 6912.91 73.87 254.66 93.22 3639.34 4603.04 -1461.48 -4365.86 0.91 -0.80 -0.45 13-OCT-91 MWD 7006.33 75.20 255.17 93.42 3664.25 4693.01 -1484.91 -4452.79 1.52 1.42 0.55 30'--20R 1 ~[~T-9~ MWD 7~0~.4a 76.09 254.56 95.13 3687.83 4785.10 -1508.97 -4541.76 1.12 0.94 -0.64 14-OCT-9~ MWD 7197.41 76.44 254.31 95.95 3710.62 4878.26 - 1533.98 -4631.54 0.44 0.36 -0.26 14-OCT-9[ MWD 7290.80 77.16 255.35 93.39 3731.94 4969.11 - 1557.77 -4719.30 1.33 0.77 1.11 ~4-OCT-9~ MWD 7385.24 75.45 257.86 94:44 3754.30 5060.64 -1579.03 -4808.54 3.15 - 1.81 2.66 20'--~ 14-OCT-9~ MWD 7478.48 75.14 258.11 93.24 3777.97 5150.43 - 1597.81 -4896.75 0.42 -0.33 0.27 14-OCT-9~ MWD 7572.68 75.08 255.44 94.20 3802.18 5241.23 -1618.63 -4985.37 2.74 -0.06 -2.83 14-OCT-9~ MWD 7667.98 75.21 256.65 95.30 3826.62 5333.18 - 1640.85 -5074.76 1.23 0.14 1.27 14-OCT-9~ MWD 7760.17 74.33 253.10 92.19 3850.84 5422.04 -1664.05 -5160.62 3.84 -0.95 -3.85 20'--120L 14-OCT-9~ MWD 7855.45 74.05 255.02 95.28 3876.80 5513.69 - 1689.22 -5248.76 1.96 -0.29 2.02 14-OCT-9~ MWD 7950.16 73.93 255.17 94.71 3902.92 5604.64 -1712.64 -5336.74 0.20 -0.13 0.16 14-OCT-91 MWD 8044.52 74.00 254.48 94.36 3928.99 5695.26 -1736.38 -5424.26 0.71 0.07 -0.73 15' 90L . . 14-OCT-9~ MWD 8139.37 74.43 253.55 94.85 3954.79 5786.51 -1761.51 -5512.00 1.05 0.45 -0.98 14. -~T-9~ MWD 8233.06 74.74 254.39 93.69 3979.69 5876.80 -1786.45 -5598.81 0.93 0.33 0.90 [4- ~T-9~ MWD 8323.62 75.51 255.09 '90.56 4002.94 59~.27 - 1809.49 -5683.25 1.13 0.85 0.77 14-O~-9~ MWD ~21.40 73.80 254.28 97.78 4028.82 6058.50 -18~.39 -5774.19 1.92 -1.75 -0.83 31' 140L 14-O~-9~ MWD ~15.06 73.30 254.46 93.66 4055.~ 6148.29 -1858.59 -5860.69 0.56 -033 0.19 14-O~-95 MWD ~10.49 73.82 ~3.44 95.43 4082.35 6239.79 - 1883.90 -5948.65 1.16 034 -'1.07 14-O~-91 MWD 8705.89 73.86 ~3.26 95.40 4108.~ 6331.41 -1910.15 -6036.44 0.19 0.~ -0.19 14-O~-91 MWD 8799.29 73.93 ~1.45 93.40 41~.81 6421.14 -1937.35 -6121.95 1.86 0.07 -1.94 14-O~-91 MWD ~95.35 73.68 ~1.92 96.06 4161.60 6513.38 -1966.M -6209.52 0.54 -0.26 0.49 14-O~-9~ MWD 8985.83 73.86 251.19 90.48 4186.89 6600.23 -1993.83 -6291.94 0.80 0.20 -0.81 .. 15-OCT-9~ MWD ~81.43 74.74 252.52 95.60 4212.76 6692.25 -2022.48 -6379.39 1.63 0.92 1.39 n ;HEET ":' · ~ , ounv i:: · b/'M.LtUL/'t I lull ~/4111U FIr' 'J ~vnn~onr--,:-, Job No. 0450-01664 Sidetrack No. ~rage :~ of 6 . Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD Well Name & No.TARN DRILL.SITE 2N/335 Survey Section Name P-1 BI-II Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -109.24 Grid Correction 0.000 Depths M~surea From: RKI~ MSL[] SS~ii Target Description Target Coord. E/W Slot Coord. E/W -967.49 Magn. Declination 26.820 Calculation M¢thodMINIMUM CUR¥^TU! [Target Direction (DD) Build\Waik\DL pdt]0£t~ 30m~ 10m[-] Vert. Sec. ^zim. 252.65 Magn. to Map Corr. 26.820 Map North to:OTHER I I I III SURVEY DATA Survey Survey Incl. 1toic Total Coordinate Build Rate Walk Rate Course Vertical - Build (+) Right (+) Comment Date Tool D~i~ ~! An~;le Direction I~l[ ~1 TVD Section N(+~?(-) E(+0F/T ?(- DL Type (DD) (DD) (FT) (Per 100. F~l/rop (-) Left (-) .... 15-OCT-9~ MWD 9175.66 73.14 251.34 94.23 4238.83 6782.80 -2050.57 -6465.47 2.08 -1.70 -1.25 31'180 -. 15-OCT-9~ MWD 9268.95 73.13 251.26 93.29 4265.90 6872.05 -2079.19 -6550.04 0.08 -0.01 -0.09 ........ 15, "' 7-98 MWD 9362.44 74.52 251.92 93.49 4291.94 6961.82 -2107.55 -6635.23 1.63 1.49 0.71 15-uCT-9[ MWDi 9458.62 73.54 250.76 96.18 4318.40 7054.26 -2137.13 -6722.84 1.54 -1.02 -1.21 31' 180 15-OCT-9~ MWD 9551.67 73.62 252.46 93.05 4344.71 7143.50 -2165.28 -6807.53 1.75 0.09 1.83 15-OCT- 9[ MW'D 9644.67 74.36 250.44 93.00 4370.36 7232.86 -2193.72 -6892.27 2.23 0.80 -2.17 15-OCT-91~ MWD 9739.20 73.28 249.45 94.53 4396.70 7323.55 -2224.85 -6977.55 1.52 -1.14 - 1.05 31' 150R 15-OCT-91~ MWD 9833.90 73.53 251.08 94.70 4423.75 7414.22 -2255.50 -7062.97 1,67 0.26 1.72 -- 15-OCT-98 MWD 9926.71 73.27 251.70 92.81 4450.26 7503.14 -2283.88 -7147.26 0.70 -0.28 0.67 25' 130R ,, 15-OCT-98 MWD 10020.95 72.70 254.49 94.24 4477.84 7593.24 -2310.09 -7233.47 2.89 -0.60 2.96 31' 120R 15-OCT-98 MWD 10116.11 72.62 255.42 95.16 4506.21 7684.00 -2333.66 -7321.19 0.94 -0.08 0.98 16-OCT-98 MWD 10210.19 73.56 253.03 94.08 4533.58 7773.97 -2358.14 -7407.81 2.63 1.00 -2.54 16-OCT-91~ MWD; 10304.41 73.56 253.56 94.22 4560.24 7864.33 -2384.11 -7494.36 0.54 0.00 0.56 3i' 160R ,, 16-OCT-91 MWD 10398.74 71.43 254.44 94.33 4588.61 7954.27 -2408.91 -7580.83 2.43 -2.26 0.93 31' 160R ~6-Ot"T-9~ MWD 10493.31 69.00 255.63 94.57 4620.62 8043.17 -2431.89 -7666.79 2.83 -2.57 1.26 31' 160R 16-1o_i'-98 MWD 10587.07 66.86 253.42 93.76 4655.85 8130.00 -2455.06 -7750.52 3.16 -2.28 -2.36 26' 160R 16-OCT-9[ MWD 10680.82 65.48 252.44 93.75 4693.73 8215.75 -2480.23 -7832.50 1.76 -1.47 -1.05 20' 180R 16-OCT-9~ MWD 10775.10 64.45 254.36 94.28 4733.63 8301.16 -2504.64 -7914.35 2.14 -1.09 2.04 20' 150R 16-OCT-98 MWD 10870.27 62.45 255.70 95.17 4776.17 8386.21 -2526.64 -7996.59 2.45 -2.10 1.41 31' 160R 16-OCT-9[ MWD 10962.17 60.27 254.54 91.90 4820.22 8466.79 -2547.34 -8074.53 2.62 -2.37 -1.26 26' 180 i6-OCT-9[ MWD 11057292 60.71 253.32 95.75 4867.38 8550.09 -2570.41 -8154.60 1.20 0.46 -1.27 16-OCT-9t~ MWD 11152.62 60.04 253.86 94.70 4914.19 8632.40 -2593.66 -8233.57 0.86 -0.71 0.57 14' 160R. 16-OCT-9~ MWD 11246.92 60.90 253.18 94.30 4960.67 8714.44 -2616.94 -8312.25 1.11 0.91 -0.72 . 16-OCT-9~ MWD 11314.14 61.68 253.52 67.22 4992.96 8773.39 -2633.83 -8368.73 1.24 1.16 0.51 II i_=[l[t~_,l:a~.~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPMENT FIELD II · '" Well Name & No.TARN DRILLSITE 2N/335 Survey S~ction Name P-1 BHI Rep. .. WELL DATA Target TYD {FT) Target Coord. N/S S~ot Coord. N/S -109.24 Grid Correction 0.000 I~pths Me$,snred From:RKl~ MSI.~ SS[- Target Description Target Coord. E/W Slot Coord. E/W -967.49 Magn. I~clination 26.820 Calculation Mcth~IMINIMUM CURYATUI Target Direction {DD) Build\Waik\DL pd~fl0ft~ 30m0 10m[-] Vcrt. S~c. Azim. 252.65 Magn. to Map Corr. 26.820 Map North to:OTHER · SURVEY DATA Survey Survey Incl. Hole Cour~ Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth P~ngl¢ Direction IQ~_gl~.~ TVD Section N{-~,~S{-)_ -- E(+01~W(-'~__ DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT') {Per 100 Fll~op (-) I~t't (-) 16-OCT-9~ MWD 11431.10 62.77 252.81 116.96 5047.47 8876.87 -2663.81 -8467.78 1.08 0.93 -0.61 1~--'?~1'-9[ MWD 11525.02 62.81 249.08 93.92 5090.42 8960.34 -2691.07 -8546.71 3.53 0.04 -3.97 · 17-OCT-91 MWD 11616.00 63.66 254.86 90.98 5131.42 9041.51 -2716.18 -8623.91 5.75 0.93 6.35 17-OCT-9! MWD 11710.57 64.13 253.80 94.57 5173.03 9126.40 -2739.12 -8705.67 1.12 0.50 -1.12 17-OCT-gl MWD 11806.26 64.61 255.05 95.69 5214.43 9212.63 -2762.28 -8788.78 1.28 0.50 1.31 17-OCT-9~ MWD 11900.77 65.42 253.08 94.51 5254.35 9298.26 -2785.81 -8871.1~1 2.07 0.86 -2.08 17-OCT-9~ MWD 12003.48 66.92 254.68 102.71 5295.85 9392.19 -2811.88 -8961.40 2.04 1.46 1.56 17-OCT-9~ MWD, 12077.00 66.92 254.68 73.52 5324.67 9459.78 -2829.75 -9026.63 0.00 0.00 0.00 .- _. -- , .. · : ., · 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 __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate _ Pull tubing__ Variance_ Perforate_ Other X Annular Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X_ Exploratory __ Stratigraphic __ Service -- 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 1 10' FNL, 967' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 191 1' FSL, 317' FEL, Sec. 3, T9N, R5E, UM At effective depth At total depth 1741' FSL, 862' FEL, Sec.3, T9N, R5E, UM 2N-335 9. Permit number 98-204 10. APl number 50-103-20274 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 12. Present well condition summary Total Depth: measured 12077' feet (approx) true vertical 5325' feet Effective depth: measured 11891' feet (approx) true vertical 5250' feet Casing Length Size Structural Conductor 80' 16" Surface 2412' 7.625" Intermediate Production 11233' 5.5"x Liner 793' 3.5" Plugs (measured) Junk (measured) None Cemented Measured depth 9 Cu High Early 108' 212 sx ASIII & 2450' 244 sx Class G & 60 sx ASI True vertical depth 108' 2347' 310 sx Class G 11281' 4977' 12054' 5316' Perforation depth: measured 11642'-11672' true vertical 5143'-5156' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 11276' Packers and SSSV (type and measured depth) Baker CSR @ 11261', No SSSV RECEIVED & ( as Cons, Commission Anchorage 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 November 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ig n e d ~'~,~, ~'~~,~ Title Tarn Drilling Team Leader FOR COMMISSION USE ONLY 15. Status of well classification as: Gas __ Suspended__ Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance Mechanical Integrity Test_ Subsequent-form require 10---~.~_0~-~-~ Approved by the order of the Commission ¢, OO~j Commissioner ,,. =orm 10-403 Rev 06/15/88 IAppr°val N°L.~ ~--~'~1"~ I , Date SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Cementing Details Well Name: 2N-335 Report Date: 1011t198 Report Number. Rig Name: DOYON 44¶ AFC No.: AK946'1 Field: Casin,g Size Hole Diameter. An@la thru KRU: Shoe Depth: I LC Depth: I % washout: 7.625 $.875 39 2450.43I 2322.89 I Centralizers State type used, intervals covered and spacing Comments: 28 bowsprings: On stop collars on Ns ~ ,2,62,63 and on collars of#s 3-13, 16,18, 22,25,28,31,34,40,43,46,49,55 Mud Weight: PV(prior cond): PV(affer cond): I YP(prior cond): YP(affer cond): Comments: 10.2 28 20I 22 15 Gels before: Gels after. Total Volume Circulated: Bit 8 4/7 8001300 Wash 0 Type: Volume: Weight: Comments: Water 515 8.33 Spacer 0 Type: Volume: Weight: Comments: ARCO 33/33 10.8 Lead Cement 0 Type: Mix wtr tamp: No. of Sacks: I Weight: Yield: Comments: ASIII 75 201192I 10.$ 4.42 Additives: ASIII wi 50% D124,.2% 1346, 30"/, D53,1.5%S1,1.5% D79 Tail Cement 0 Type: I Mixwtr tamp: I No. of Sacks: Weight: Yield: Comments: GI 75I 244/60 15.8/15.7 1.15/.93 Additives: G wi 1 °/,S'I, .2%D46, .3°/0D651 AS¶ Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Sa'. Wt. Up: Comments: 5 5 75 Reciprocation length: Reciprocation speed: Str. Wt. Down: 20 10 70 Theoretical Displacement: Actual Displacement: Str. WL in mud: 106.6165.6 106.7/66.4 Calculated top of cement: I CP: Bumped plug: Floats held: SurfaceI Date: 10111198 yes yes Time:03:15 Remarks: Cement Company: i Rig Contractor: IApproved By: DS I DOYON I G.R. Whitlock ~ Casing Detail 7.5/8" Surface Casing WELL: TARN 2N-335 ARCO Alaska, Inc. DATE: 10110/98 Subsidiary of Atlantic Richfield Company 'l OF 1 PAGES # I'I'EMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to LR = 29.00 7 5/8" Landing Joint 34' OA. 29.00 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.21 29.00 its. 2.4-55 7 5/8", 2_9.7#, L-80 BTC-MOD 1360.40 31.21 Jt ~66 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 43.34 1391.61 Gemeco 7 5/8" Stage Collar (BAKERLOK) 2..80 1434.95 Jt. #-65 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 40.68 1437.75 its. 3-23 7 5/8";2.9.7#, L-80 BTC-MOD (shutoff baffle on top of jt #3, BAKERLOi 885.64 1478.43 Gemeco Float Collar 1.32 2364.07 its 1-2. 7 5/8", 2_9.7#, L-80 BTC-MOD 83.59 2365.39 Gemeco Float Shoe 1.45 2448.98 2450.43 Insert baffle (~ 2405.63' T.D @ 2465' leaving 11.24' of rathole 28 Gemeco Bow Spring CEN'I'RALIZERS Run centralizers over stop collars on Jts. 1, 2, 62, & 63. Run centralizers over collars on Jts 3-13, 16, 19, 22, 25, 28, 31, 34, 37, 40, 43, 46, 49, 55 Remarks: String Weights with Blocks: 75K# Up,70K# Dn,12k# Blocks. Ran 57 joints 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: G.R. Whitlock CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-335 Supervisor: G.R. Whitlock Date: 10/11/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 2,340' TVD 880 psi LOT = (0.052 x 2,360') Fluid Pumped = 7 518", 29.7 ppf, L-80, BTC 2,485' TM D 2,360' TVD EMW = Leak-off Press. + MW 0.052 x 'I-VD + 9.1 ppg EMW = 16.3 ppg Pump output = 0.1000 bps TIME LINE 2,400 psi ~r- ~ ONE MINUTE TICKS I 2.2oo,s, ..... i.~i~ -i'i'i-i'i"'i' 'i';'i-i ................... 2,000 psi ~,90D psi ] 1 ,B00 psi 1.700 psi 1,600 psi ~ 1,500 psi 1,400 psi 1,300 psi t ,200 psi 1,100 psi 1,ooop~ ~ : LE~K~OFF TEST 900 psi ~1 ~CASING TEST e00 psi ~' ~ --'-- LOT SHUT IN TIME 7OOps~ f~ [ --*--CASING TEST SHUT IN TIME 600500 pslPSl~ ' I j I ' TIME LINE 200pd ~111 I ~OOp~,, ~1 I I I I 0 psi ........ 0 2 4 6 8 10 ~2 14 ~8 18 20 22 24 26 28 30 32 ~ 36 38 40 42 44 48 48 50 52 ~ 56 58 60 62 ~ 68 8~ 70 72 74 76 78 80 STROKES 400 psi. LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE i I stks { 70 psi I 2 stks i 230 psi ................... i .... '~'~;ii~' .... 1 .... Z~'~ .... ................... [ .... ~.~?_ .... i .... ~_9_~l .... 1 , ., .................. ~ .................. ~ .................. ................... .................. i .................. ................... [ .................. 1 .................. ................... [ .................. 4 .................. ................... ~ .................. ~ .................. SHUT IN TIME! SHUT IN PRESSURE .... ~'F~i~ .... ," .................. ',' .... §§6"~'i' .... 1.0min ~ ~ 360 psi 3.0 min ~ ~ 340 psi .... -~:~-~-i~ .... ~ .................. ! .... ~-o-~a .... ............ -. ...... f .................. t ................... 5.0mm ~ = 340 psi , .... '~';~'~ .... f .................. i .... ~;~'~"~a .... .... -.~:~-~ .... ~ .................. .~ .... :~-~-~f .... . 8.0min i i 330 psi . 9.0rain ~ : 330 psi CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE f ......................................................... .................. J .................................... J.. I [ ........................ .O._s_!k_~ .......... _°._R?J ....... 1 stks 20 psi i ........................ ~--~-~ .......... ~b--~-a ...... ~ ........................ .~_.s..t&s. ......... ?_.o_?.s_.., ...... 4 stks 60 psi · .................. ~ .................. .~. .................. 5 stks 110 psi ~ ........................ ~,"A-t'~ ........ '~ gb"l~'~i .... [ , 7 stks ~. 490 ps~ ....................... ~"~f~i~ ....... ¥X6"~'~i .... 10 stks 1,130 psi [ , 11stks i 1,300 psi ; 12 stks 1,500 psi [ ....................... ! .4. ?. .tk. ?. ...... !,...91o_.p..s.L.i [ ....................... ]__S_.s__t.k_.s. ...... .2.;~..2..O..R.SL..i SHUT IN TIME SHUT IN PRESSURE F .... ~.'6"~ri'"'i ..................... '~'i'~'O-~i .... I. ...... L ..... .. ..... .I ........................ -' ...... ~-- ..... 1,0 mm 2,090 psi ................ '1 .................. "- .............. '----I ~.Omm ~ 2,080 psm .... ~.'O'-~[r~""i ...................................... 2,070 psi [iiiiEE, !Eii]iiiiiiiiiiiiiiiiiiiii L i Ef,:8)iii' .... _%.g...m.,_%..: ..................... ~,..o.6..o__p..~!._, 6.0min : 2,060 psi [ .... F.'O"r~i'~ .... ~ ..................... ~;(i~i~-~i .... .... ~:O"~F,'"'I ..................... ~;6'~'~a'" ............ ,' ..... ~ .................. + .................. I 9.Omen i i 2,050psi i F"¥b';o"~r~'''~ .................. L_?..o...o....m.,.n.....,, .................. ., ._.2.,_.o.4..o..R .s J___i 25.0min ! : 2,030psi j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-335 Date: 10119/98 Supervisor: D.P.BURLEY Casing Size and Description: 7 5/8", 29.7 ppf, L-80, BTC Casing Setting Depth: 2,450' TMD 2,350' TVD Mud Weight: Hole Depth: 9.1 ppg 5,324' TVD EMW = Leak-off Press. + MW 0.052 x TVD 840 psi + 9.1 ppg EMW LOT = (0.052 x 2,350') = 12.1 ppg Fluid Pumped = 5.9 bbl Pump output = 0.1000 bps 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi. 1,500 psi. 1,400 psi. 1,300 psi 1,200 psi. 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 2 4 6 0 10 12 14 10 10 20 22:24 26 28 30 32 34 30 30 40 42 44 40 40 50 52 54 56 50 60 02 04 66 68 70 72 74 70 7O 00 02 04 06 80 90 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k STROKES LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE ......................... .O.~_t_k..~. ......... J_ _7. _s_ £ _~j_ .... 2 stks 300 psi 4 stks 375 psi ........................ -~,-~i[~- ......... ~Q-~-i;~-[ .... 8 stks 475 psi 10 stks 550 psi 12 stks 600 psi ....................... !..~.~_t~..~_ ........ _~__s_o___,__~j_ .... ........................ !~_~.t~_~_ ........ .~.?.o_..e.~_[ .... ........................ !_s__~_t~..~_ ........ 7__~_o__~_s_[ .... ........................ .2_°..~Lk.?. ........ ?._9_°___e_~_[ .... 22 stks 820 psi ................... ,: .... .~.~.t~?. ........ _s._~_o._p__~.[ .... 29 stks 840 psi 34 stks 840 psi ~ ....................... ~-~-;iia'"'~ .... i~'~'~'i;a .... r ....................... ~'aia' ........ i~':~'~'~'i' .... , ...................... .fZ~.~_~. ........ .?..P..~.[ .... , : 54 stks 830 psi ," .................. f .............. t ............. ----t : : ~§s{Es : JJ2Ops, ,,' ..................................... i .................. i ~ ..................................... i .................. i ,," ..................................... i .................. ! CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks 0 psi ~ .................. ~ .................. ~ ................... 1 stks 20 psi ......................... ~--~f~- .......... ~-0--~;i ..... 3 stks 40 psi 4 stks 60 psi 5 stks 110 psi , , 6 stks 190 psi , ......................... ES.~E ......... ........................ _?.~.~E ......... ~f.o._P_~L..; ........................ .!.o.~_t~?. ....... ']..,J.~_o...pE.j 11 stks 1,300 psi , ........................ T~'~iia' ....... i',~i~b"F~i'"~ ........................ ~';i[~' ....... ~;'~'~"Fa"i ........................ ~'~i[~' ....... ~','~'~a"~i-",. i . SHUT I, T,~E' S~iUT ~N P~ESSU~E 0.0 min 2,120 psi , 1.0 min 2,090 psi [ .... 2-.-o'~rr~ ........................... ~-,~o--f,-~i--"' SHUT IN TIME ..... o:'0'~-a ............................ ~-o-'~'r'"i ,' .... ~-.~-~-r~ ............................ ~'~'~'iia'"i ...........................................2.0 min Ji'~"~'iJ~-i---'J .................... .I. .................. 4 .................. ,-I 3.0 min : : 510 psi : .... __~_._o_.~j_._ .... [ .................. j .... .C~_~.~.[...j ~ 7.0min [ j 425 psi ] 9.0min : : 415 psi j SHUT IN PRESSURE 3.0 min 2,070 psi : .... ~-.'6-~'i'~ ........................... ~,','~i~6"~'~i--' : .... ~-.'O'~-i-ri ........................... ~-,-~i~i~--~-~i--' r ............ .- .....,I. .................. -I ............... :--,-I ~ .... .7...o__.m_.,:n. .... i .................. ;----~.-'-?---P~L--' 8.0 m~n : : 2,050 ps~ : ~ ..................................... d [ .... _~_._O_.m__i.n. .... 1 .................. j____2_,_O..5__O___p.s_!__j .... J..°:.°_..mj.n....i .................. J_._.~:~!?. .... J..~:.°__.m_j.'L_.,' .................. .... 2_o. :.o. . .mj.n. . . _i .................. j..._~:_o..4._o...p~!_.j 25.0min : : 2,030 psi : NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY 4~ ARCO Alaska, Inc. Atoll: 2N-:~$' 2465/2340 ~Fmv o~h C~tra~or: ~OYON ]Da,y Co~t ~ ~S0904 JC~ Cos~ ~emdon At ~00: Testing BOPE On highllae 24 Daily Drilling Report RIO Ral~;a - Pro,'Jreee: 1110 Esl Cos{ To Date $ 270000 ~.~"~'A~ ' '0~0'~ing Operntians: Tent DOPE drill out run LOT/FIT MUD DATA I':/U D TYPE SPUD VV~IGHT lO,2pp~ V18C0511Y $Oeqc pv/YP 2o/15 GELS 4171 HTH? WL r~V30 rain 'SOLIDS lO~ I tOLE VOLUME 14bbl ~IBT PiT VOL DAILY MUD 'OTAL MUD ;26702 COMPANY BAROID ..... 'riME i END ..... 12:00 AM 02;30 AM DRILLING DATA DEPTH ROT VVT 75 ~'U' ~Vl' 'SO WT ?0 AVE D~" ' MAX DRAG TRQ BTM 2000 'RQ OFF ~[J-~ P PRFS ~30ol I I PUMP NO LINER SZ .16It SPM 1 .018011 GPM 2 III ~PI= I MUD WT lO111 alt NO 51/b MAKE HTC TYPE MX1 SERIAL NO V09YD 0'EPTH OUT OEPSH IN 1118 FOOTAGE 2357 AOTIAST 9.618.0 45- RPM 1 80- I F'A BIT CO81 8100 GRAD E ol~l.-lu BIT DATA BIT NO. SIZE 'l~t, pE ~ERIAL ~C~' ' DEPTH OUT IEPTH IN FOOTAGE AD'~AST / EHBS TFA JETS INCIDENT N EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG INJEO'~ION INJECTION WELL ,2N.313 SOURCE WELL 2N-31, RATE (bpm) PRESStJRE (pm') ~JEC'[ IO~ Water B~ 793 F m~h liT COST DULL III Ck~E III 15 0 TOTAL VOl. (bbl) TOT FOR WELL 10845 DRI LLEdBO P DATA TsTLAST BOP/OIVER r IAST BOP/DRILL10/Oe/~5 LAST~om5msH2S DRILL i~sTFm~E DRIL~0mf~8 '~ AG ~dNFINED I~aT SPILL DRILL FUEL & WATER FUEL U ~{'~:'D 1600 , DRILL WATER USED - 15:~1 !nnLs i POTAELE WATER 130 USED - BBLS WEATHER & pER~NNELDATA lb~P"~ 24 WIND SPEED 1o WIND DIHECTION 180' ' CI41LL FACTOR "r ARCO PERSONNEL ..... ~ CONTRACTOR 25 PERSONNEL MISC PERSONNEL 8 SERVICE 11 PEHSONNFL IOTAL 44 HOURS J i OP$ dOOle' I HOLE SECT a. Go DRIL SURF J_l~ _HA~E OP~ 5king Halo OPERATIONS FROM OeO0 - ooco Ddll from 1355' 10 1702' 03;30 AM 03:00 AM 0.50 ClRC SURF 03:00 AM 04;;30 AM 1.80 WlPERTRP 04:30 AM 19'30 PM g,oO DRIL SURF 12:3o PM 01:30 PM 1,00 GIRC SURF 01:30 PM OZ:30 PM 1.00 WIPERTRP SURF 02:30 PM 03:30 PM 1,Q0 CIRC SURF 03:30 PM 05;00 PM 1.50 TRIP..OUT SURF 05:00 PM 05~00 P~ 1.oo aHA SURF ~6:00 P~ 07:~0 P~ 1.~ CASS SURF ~7:00 PM 10:00 PM ~.~0 CASG t0;00 PM 11:30 PM 1,50 CIRC S~F tl :30 PM 12:~ AM 0.50 CEMENT SURF Risking Hole Making Hale Making Hain Mek~9 Hole Makk~g Hale Making Hole M=k~g Hale C~elng end O~ln~ and O~lng and ~nllng C~ln9 ce~nUng Clrc high.vln ~lloYt trip to 3¢0~ Drill from 1702" [O 2.465' ~1~o~ ~p to 1~4Y Cl~ hole cle~ POOH ~ ~ Download and LD M~ ~U ~e ~n ¢~Ing. Hold se~ meeli~ Run 87jt~ ~ 7-~8" easing C{~ al I.E bpm P~,lmp :30 bbl spacer and 16 bbi lead elurry 24.0~ RECEIVED Alaska 0il & Gas Cons. Commission Anchorage Dally Drilling Report: 2N-335 10/10/98 $upervJ~v: G,R, WHITLQCK Page 1 Dally Drilling Report ARCO Alaska, Inc. AFC N~.' Dale Rpl No [R~ Acee~'- hfs Days 51n~ Ac~-.eptfE~l. 2.8 / ~,.:~' ' R~ Rel~e - bra: ,,. 'Well. 2N-335' ~' Dnplh (MD~V~) 24~ P~ Ds~h MD: '~ Progress; 0 C~'vacto~ D~YON ' ' ~ntly Cost S 13~76 " Cum Cu~ $ 402~ ~t Cost To Data $ BSO0~' ,, R,g'N~?=. DOYQN 141 .... Le~t C~g~ 4,~" ~ ~0~ .... Next C~0' ?-~' ~ ~3~ ~. SE~ Test: ' " ~ere~on At C6~: Drilling 660' Da higltflflo 6 hm ' U~Rg Opnratiu~s: MUD ~TA D~LLI~ OAT~ [ .... ~1~ ~ATA EH~ '" DRILl/BOP ~TA MU~' ~PE 0EPTH BiT NO, BiT NO. tNC~E'~'F LA~T~~T ~'} BOP/DRI[ I. ~I~H1 .... ROT ~ ~IZE ~IZE ' ' ~MPLO~R '" ~ST H2S DRILl." -- LAST FIRE D~ ~.lp~ 60 6.75 ~0~5~8 VISCOSITY P U ~ .... MAKE M~KE ~JLL I AST CONFINED ~ST ~PILL DRILL ~qc ~ HTC Y SPACE 1~1103 PV~P SO ~ ~PE .... TYPF ~E "' ~EL' ~4113 60 G4f4GS diesel ~LS AVG DRA~ SERIAL NO ~E~L NO VOLU~[' FbE[-USED '" AFI~' M~G DEPTH '~UT DEPTH ~U [' ~T SAFE't Y ~T~' DRILL WA~EH U~ED - 1~ g.s ~8s ~m~s ~BLS HTHP ~ ' ' TRQ BTM " DEPTH IN DEP~I IN '- POTABLE WAT~ mV3O m~n 15~ 2465 INJE~ON USED · SQLID~ TRQ OFF '~ FOOTAGE ...... FOOTAGE ~JEC~'ON ~LL ' ~ATHER · 3.6% 20 2N-3t3 P~ON~L DATA HOLE VOLUME PUMP PRES 'ADT/AST AD[lAST SOURCE ~I,L TEMP "~ ............ 23 1O3b~ 1~01 I J t I / 2,-315 MBT "' PUMP NO WOB 2 "' ~B 2 '- ~T~ (bpm) ~ ~ND SPEED 4 7.S t ~ 2J J 10- 10 3,6 ~ LINER SZ RPM 1 HPM t PRESSURE (psi} WINO DIRECTION 9D 8.5 ~ I~l I_ .. - 57S LG~ '-' ~PM 1 ' ' TFA ...... TFA INJECTION fLUIDS '-- GHIl..t, FACTOR"F 23.00 1391 PI I'VOL GPM' ~'- JETS .I~TS ~ Fm~ W~, ARCO P~RSONNEL ' ' 1 s~o 133411 ~zl~21~21~zl I I I I II DAILY MUD SPS 1 .... ~IT COST ' BIT COST CONT~CTOR 26 31=~4 III ~ 0 ,_ FE~SONNEL ~ i° TOTAL MUD 8PP ~ I bOLL DU~ TOTAL VOL (b~l) ' MISC ~ER~NNEL 6 ~305,6 I I I o l ~ I ~1~ I I I 164; COMPANY ' ' ' MUD~ ' GRADE C~OE TOTFOH~LL (bbl) SER~CE TOTAL 42 ¥iuE"'I ENd HOURS ] OPSCODE -I 'H0[,ESECT J~A~E~8I ~ 'OPERATION~RoM000U-U~0 ~2:00 AM ~1=00 ~M 1.00 G~ENT SURF' ~sing and " nlsh c~t~ ~8L Co.filing ol ~o0 AM 02:00 AM ~.00 ~RC SUR~ Casing and O~ el~e to~l wi ~0 ~sI-C~ ll~e Cementi~g 02:00 AM 03:3~ AM 1.50 CEMENT ~RF Caging and Cement 2n~ siege w/t~1 bbls load an~ 10 ~11, Counting 03:30 AM ~:nO AM 3.50 NU_ND SURF Cas~g and Clos~ ~aga tool ~ c~nte~. ~ I~dlng Cementing dlve~er oY:0O AM oa:0D AM t,~ NU ND PROD Casing and N~ spe~ho~d and {est ~ 1~0 p~l Cnmantlrtg ~0~:~ AM ~2:0~ PM 6,00 BOPE PROD C~olnfl and NIB BOPE Md test all Eomponen~ Ceme~ting wea~flg. 02;~0 PM 02:30 PM O.~0 BHA ~OD Ma~ng Hain M/U blt and cl~an~t ~a 03:30 PM 03:30 PM ~,0a RIG~ ~OD Making Holn Cut dfllllng tine ~nd ~Just br~k~ 03:30 PM 0&=00 PM 0.50 ~IP_IN ~OD Making Hole EIH ~ 04:00 PM 05100 PM 1,DO CIRC ~OO Making Hole GI~ ~t con--inured mud ~:0o PM 08:~ PM t,O0 TEST ~OO Making Hole At~t to test ~slng able siege corer wlo succ~$. casing Te ~ psi for ~ mln. 06:00 PM 08:30 PM 0,So CLN OUT PROD M~ing Hole Drill out atago ¢011~ ~:30 PM 07:00 PM 0.50 TRI~I~ P~OO M~lng Hole RIH ~ 22964ep ~ cement 07:00 PM 08:~ PM t.00 QL~OUT PROD M~lng Hole O~ll ~ment to 2~& ~d ~[~ hole 08~00 PM 0a:oo PM t,00 ~ST PROD Ma~lng Hole Te~[ easing Io 2000 ~! ~r 30 m~. 09:00 PM 1O;uu PM 1.~ CLN_OUT PROD Making Hole bHII ~me~ 10:~ PM 10:30 PM 0.50 ~IRO PROD Ma~lng H~e Dlepiaea mud wl LSND ~d 10;~Q PM 11:00 PM 0,S0 ~ST PROD ~aklflg H~u Run FITtO ~6,2 p~ EMW 11 lO0 PM lZ:00 AM 1,00 ?RIP_OUT PRO~ Making H~e P~p d~ job a~d POOH. Daily Drilling Report: 2N-335 10/11/98 Page 1 ARCO Alaska, Inc. Cementing Details Well Name'. 2N-335 Report Date: 10/1119B R=p0rt NumbeF~ Ri@.N, ame: DOYQN '141 AFC No.: .~K94B1 Field:. C~meme: C~mema', 10,2 28, ~ ~ __ 8118 ~ Wash ~ Ty~; Volume'. Weight: .. , Spacer 0 Ty~: Volume: Weigh: C~ment~: ~ 3313~ 10.~ Load Ce*I~/II O Type: Mix ~r tamp: ~. of ~a~: wh~ht; C~menta: . ASll 75 2011 ~ t0,B 4,42 · ......... .... i Tall Cement O Ty~: Mix ~r t~p: ~. of 8e~,: W. ighe C~i~ rn~a: G 7fl 2441~ lS.811 ~.7 1.1 ................... . Plsplacenwlit O Ratc~b~i)rc eli ~t ~hoo): Rate(lail moune s~e); ~lr. ~. ............. , ................ ROcipro~tlO~ le~t~: Rec~mc~fion spg~d: S~. ~. D~; 20 lfl . ~. - ..... T~eoreti~l Uisple~ment: A~I ~[=pigcement: ~. ~. ~ Calcula[ud t~ ~ ~monl; CP: Bumped ~1~: r~ 5 u da~ Dat~: 10/111~9 yes Time:03 =15 .... . ..... ~..,, .. . ......... ~.~ ........ . _ ,~ .... . ...... Cement Company: I Rig Contractor: lApperS'ed By: DS [DOYON [G.R. WhiYock TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS October 8.1~ONSERVATION COMMISSION Paul Mazzolini Drilling Team Leader ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kuparuk River Unit 2N-335 ARCO Alaska. Inc. Permit No: 98-204 Sur Loc: 109'FNL, 967'FEL Sec. 03, T9N. R7E, UM Btmholc Loc. 2403'FSL 707'FWL Sec. 04, T9N, R7E. UM Dear Mr. Mazzolini: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes xvill not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records. FIT data, and anv CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 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 waste in a volume greater than 35.000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one ,,'car. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given inspector on the North Slope pager at 659-3607. DavidW. JoqYffst~-'---~ Xx ~--..._-- ~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosttres Depart]nent or' Fish & Game, Habitat Section w/o encl. Department of Enviromnental Conservation v,-/o encl. STATE OF ALASKA ALASI~Tt' OIL AND GAS CONSERVATION COMMI~'-~ION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill I-- lb TypeofWell Exploratory E StratigraphicTest E Development Oil X Re-Entry ~-' Deepen [~ Service [~ Development Gas E~ single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 120' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 375074, ALK 4293 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 109' FNL, 967' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2522' FSL, 1115' FWL, Sec. 4, T9N, R7E, UM 2N-335 #U-630610 At total depth 9. Approximate spud date Amount 2403' FSL, 707' FWL, Sec. 4, T9N, R7E, UM 10/9/98 $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-337A 11855' MD 707' @ TD feet 29.2' @ 300' feet 2560 5291' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1200' feet Maximum hole angle 73.85° Maximum surface 1357 psig At total depth (TVD) 2300 psig ,, 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC 2395' 28' 28' 2423' 2300' 1) 20 Sx Arcticset III L & MOD 240 Sx Class G u-'"~. 2) 240 sx ASIII L & 60 sx AS I 5.5",,. v,i,8.75", 15.5# L-80 LTC-M 10967' 28' 28' 10995' 4861' 270 sx Class G 3.5." ~ ~6.75" 9.3# L-80 8rd EUE 860' 10995" 4861' 11855' 5291' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ConductorStructural Length Size Cemented RE6 EMia~e~.,d~h True Vertical depth Surface Intermediate ~'rn°edrUCti°n 0 R I GiN A L Perforation depth: measured true vertical ~ 0il & Gas Cons. An~.hnraOe 20. Attachments Filing fee X Property plat ~ BOP Sketch X Diverter'~[<'e-t~t'~ ~ Ddlling program X Drilling fluid program X Time vs depth plot ~' Refraction analysis I~ Seabed report I'~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~~_. ~ '~ Title Tarn Drilling Team Leader. Date Commission Use Only Permit,.J~cp_ber~.~ ~,~ (*'~ ~ IAP' nur ber50- .., '7' I Appr°va' date - ~'"~ Isee c°ver 'etterf°rother requirements Conditions of approval Samples required ~ Yes J~ No Mud Icg required B Yes ~.' No Hydrogen sulfidemeasures r-~ Yes .~ No Directional surveyrequired '~ Yes F~ No Required working pressure for mOPE E~ 2M ~aM B 5M E 10M [~ 15M Other: jrlginal Signed By by order of Date/~) ...~).._..~ Approved by ",vid W. Johnston Commissioner the commission ..... Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc .... Post Office Box 100360 Anchorage, Alaska 99510-0360 October 2, 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-335 Surface Location: 109' FNI. 967" FEI_ Sec 3 TgN FI?E, UM Target Location: 2522' FSL, 1115' FWI_ Sec. 4, TgN, FI?E, UM Bottom Hole Location: 2403' FSL, 707' FWI_ Sec. 4, TgN, R?E, UIVi Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-335, 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. 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 for temporary storage and eventual processing for injection down an approved disposal well. 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 Formation. Therefore, ARCO has not included an H2S contingency plan 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-335 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-335 Well File ', ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 335 1. Move in and rig up Doyon 141. 2. Install diverter system. . 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 formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 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. 11. 12. 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. ND BOPE and install production tree. Secure well. Rig down and move out. t cEIVED OCT O 0il & G~s Cons. Anchorage .... ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 335 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' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 __.10% 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: RECEIVED OCT 02 1998 Alsska 0ii & Gas Cons, Commission-, Anchorage Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor 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/ft. 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-335 is 2N-337A. The wells are 29.2' from each other at a depth of 300'. Drillinq Area Risks: The primary risk in the 2N 335 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) 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 Pumpin_ci 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 iniected 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-335 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. We request that 2N 335 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 RECEIVED OCT 02 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 psi 8,951 psi 10,160 psi 8,636 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). RECEIVED OCT 6 Ajaska Oil & Gas Cons, Anchomc,.qe C,eoted by finch For: BRASSFIELD Oote plotted : 30-Sep-fl8 Plot Reference is 3.35 Vets;on #5. Coord~not ..... in feet rat ....... lot ~335. I Structure: Tarn Drill Site 2N Welt : 335 Field : Tarn Development Field Location : North Slope, Alaska ARCO Alaska, ][nc. <- West (feet) go00 8400 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 1800 1200 600 0 600 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 I I I I ~ I 600 0 - 500 - 1000- 1500 2000 2500 3000 3500 I 4000 4500 50O0 5500 RKB ELEVATION: 148' B/ PERMAFROST 'fVO=1198 TMD=1198 DEP=O K3% TVD=I2OO TMD=I2OO DEP=O · T/ W SAK SNDS TVD=1242 TMD=1242 DEP=O 9.00 BEGIN TURN TO TARGET TVD= 1532 TMD= 153.3 OEP= 1 `3 TD LOCATION: 2403' FSL, 707' FWL SEC. 4, T9N, R7E TARGET LOCATION: 2522' FSL, 1115' FWL SEC. 4, T9N, R7E TARGET TVD=5046 TMD= 11365 DEP=8882 SOUTH 2648 WEST 8478 Base Permofrostrgh~ Base West Sak 7 5/8 Casin~ EocCSO v I 109' FNL, 967' FEL SEC. 3, TgN, RTE f./) 600 0 1200 / 1800 I v 2400 335'33 DLS: 5.00 deg per 100 ft 4.06 .47 B/ W SAK SNDS TVD=1999 TMD=2031 DEP=158 .%,.'x~43,13 7 5/8" CSG PY TVD-2300 TMD-2423 DEP-404 252 65 AZIMUTH % 52.90 .... ~ EOC'VD=2538 TMD=2926 DEP=842 ~IU lf-kl~rJ~l} ***Plane of Proposal*** MAXIMUM ANGLE ~ '73,8,5 DEG ~ RECEIVED C40 TVD:3909 1'MD:'7853 DEP:5574 OCT O 2 1998 BEGIN ANGLE DROP WD--4590- TMD--10302- DEP-7926.- '~OJ' l&GasCons. 6om~issi¢~'~ ~'~%.~e Anchorage ~r~ ~ r~ ~, TARGET ANGLE 60 DEG 3000 0 500 1000 1500 2000 2500 3000 3500 4000 4.500 .'5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Vertical Section (feet) -> Azimuth 252.65 with reference 0.00 N, 0.00 E from slot ,//.335 Created by finch For: BRASSFIELD Dote plotted : 30-Sep-98 / PLot Reference is Coardinotee are in feet reference slat 1~335. / True Vertical Depths ore~ RKB (Doyen ~141). IStructure : Torn Drill Site 2N Well : Field : Tarn Development Field Location : North Slope, Alaska .ak 8O 2O (D 40 q-- O 80 I V 100 120 140 16O 180 2OO <- West (feet) 560 540 520 300 280 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 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 I I I I I I I I I I I I I I I I I I 80 ......... 192o ~ ~ ~ ............... 1200 11 O0 1000 900 800 700~,..~005 R CEIVED ....... OCT O 2 19~8 ~: ~oo /,oo / ....... ¢ I I I I F" I -~T T I '~ ~--'1 f .... I I I--W----F-3--'T'---T--1 .... ~-- I ~--'T I I ----I 360 340 320 300 280 260 240 220 200 180 160 140 120 1 O0 80 <-w~t (f~o+) ¢ 5OO 7O0 BO0 // ,,,'~ 800 / 9OO IOO0 500 6~0 [ -----] ' 40 2'0 ~ 600 15oo i ' 700 '1600 , , 800 /'1700 · 9OO 1000 1100 1200 0 20 40 2o 40 60 80 I V 120 140 160 180 200 10o ~ finch For: BP,.ASSFIELD Dote plotted : 30-Sep-98 Plot Reference is ,355 Version ~5. Coordlnotes are in feat reference slat ~355. IARCO Alaska, Inc. Structure : Tarn Drill Site 2N Well : 335 Field : Torn Development Field Location : North Slope, Alaska 96 40 120 160 200 240 --I--, Q) 280 -~-- 320 0 I V 40O 440 480 520 560 <- West (feet) 920 880 840 800 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 160 120 80 I I I I I I t t I I I I I I I I I I I I I I I r i t t I i I I I I I i i 1100 3O0 1700~ ~ , 1800 f ~ ~500 1400 ~200 ~15oo .... "2400 1300 RECEIVED OCT O 2 199B ~aska Oil & Gas Cons. C~m¢¢C~, fach0rage 1900 2000 1 600 1 1600 800 1500 1400 400 1800 1900 600 96, 920 880 840 800 760 720 680 640 600 560 <- West (feet) 2100 1100 520 480 440 4.00 360 320 280 240 200 160 120 120 160 2OO 240 O 280 520 360 400 440 48O 520 560 600 Created by finch For: BRASSFIELD Date p~otted : 30-Scp-98 Pict Reference is 335 Version 1~5. Coord~nat ..... ;n feet ret ....... lot ~335, [ A] CO Alaska, Inc. Structure: Tarn Drill Site 2N Well : 335 Field : Tarn Developmeni Field Location : North Slope, Alaska 100 200 300 400 500 600 700 800 I v 9oo lOOO 11oo <- West (feet) 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 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 i i i i i i i i i i i t i i i i l .............. 1900 2000 ...... 2100 .................................. 2200 ............... 2300 .............................. 220O 2600 3200 3100 3000 2900 2500 2100 2800 2OOO 2300 25OO 2600 2700 ~ 2300 2200 2400 ~ 1900 2000 2100 ~'- 1700 2200 18oo 1900 1900 .~ ..... 2000 2100 2200 2100 2000 190~ 17oo~%_.----~6oo r~¢ ~800~-.-~-'~~~1800 1600 ~ 1700 1800 27O0 2600 25O0 2400 28OO 3000 29O0 RECEIVED lOO 200 300 400 500 ,oo 0 c' 7o0 800 ._~ I 9o0 V ,' lOO0 11oo 1200 1500 1400 5200 3100 OCT oz 1998 3300 ~as~ 0ii & Gas Cons. Commit¢i¢;, 1:oo Anchorago '~;'rL~'' ~-'/°° ¢¢~' ~oo i ii 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1.500 1400 1300 1200 1100 1000 900 800 700 600 <- West (feet) ~y fi~ca For: BRASSFIELD D~te plotted: 30-Sep-98 Plot Reference is 335 Version ~5. Coardlnotes ore ~n feat reference slat Structure : Tarn Drill Site 2N Well : Field : Tarn Development Field Location : North Slope, Alaska 200 400 6OO 80O 1000 ~ 1200 1400 ,-.t-- 0 16o0 I v 18oo 2000 2200 2400 26OO 2800 <- West (feet) 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 I I I I I I I I I I I I 1 I I I I I I I I I I I f I I I I I I t I I I t I I I I I I I / 2_~p_ ................. -Ci~F| 2o0 2700 ......... 3--s-°-'°- ............................ 3~oo ~ F 2900 4500 41 O0 3900 3700 3500 3300 --~ 400 ,.: 3100 ~ 2100_~ ............. ° ~L/-te-] 2300 3300 ?_500 35? ....... 2700 __ ~- ~ 2soo 600 '"~--~-"--' -" 2900 '------' ~700 ~ 3100 -------- ~ 2900 3300 '~ ~'---'~1 O0 _.~ 800 1000 ~%'" 4500 ............ /.../~0 0 -'sE;;'" o - ...... / 3500 1400 ~- ................. ~ 3,00 ~ 1600 00 '"'""' 4100 330/~0j ..... 2000 .~ 5300 2200 2400 oCT CZ 3500 , . ' ~.t, ~: ~s ,-~,a Oil & A~cliomge ~as~ Commissic'.'~:. 0 ' '2~002600 i ------I I---T--T-- I I F I l----'T- I I'--T'---F--I' I "T----[ i ' I--- I I I I r i --i i i [ i i i i i i i i i i i 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 44.00 4200 4.000 3800 3600 3400 3200 3000 2800 2600 2400 2200 <-- West (feet) I 1800 V " by n~ch For: BRASSFIELD Dote plotted : 30-Sep-98 Plot Reference is 555 Version ~/5. Coordinotee ore in feet reference alot ARCO Alaska, Inc. S4rucfure: Tarn Drill SUe 2N Well : 335 Field : Torn Developmen4 Field Location : North Slope, Alaska <- West (feet) 9600 9400 9200 9000 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 1000 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 I I I I I I I I I I I I 1000 430~ 4100 1200 ~ 1200 5300 ~ 1400 ~ 1400 1600 1800 2OOO ,-.I-- ~ 2200 ~ 2400 0 2600 I V 28OO 5000 3200 3400 RECEIVED 1600 OCT O ~ 199B ....................... 1800 Anchorage ......... ;~E'~ .............................. ~oo ........ .......... '~;oo ....... 2800 3000 4500 4700 /~ 3200 4900 . 3400 3600 3600 }800 ~ , I I I I" , I .... i--'-r i i i ] i , i i i i --f i i -'--i i --f , i i , i ; i i i i t i ) i '1-- i F-- 3800 9600 9400 9200 go00 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 5200 <- West (feet) 2000 0 2200 '-4- 2400 --i- 2600 I V RCO Alaska, !nc. Sfrucfure : Tarn Drill Sfte 2N Well: ~5 Field: Tarn Developmenf Field Locaffon : Norfh Slope, Alaska WELL PROFILE DATA RECEIVED ...... OCT 02:19 8 Turn ta far]et 1'~3~.'%~ ' - inc o~, l~O N~th EDitV. $1~t ol~j/lOC o.o~ 1~.~ 12~.~o.aa o.oo o.~ o.~ 1o.~ lgo.oo 1351.~ -28.37-5.04 13.33 ~d of ~'ld~um2~25.gl 73.~5235.6~ 23~.10 -3~.70-7~.~ ~2.1~ ~ of H~d 10~2.20 73.&~233.62 4=S0~--2~70.75 --73~.e9 7~25.24 0.~ ~ ~ ~ep~um 10994.52~.~ 253.62 4881~-2557.95 -817Q.~7 8581.52 2.~ Tatar 2N-5~7 flee T~ 11364.52 ~.~ 253.82 ~48.~-2648.32 -~.Sg 8881.~ 0.~ ]~ ~ H~ 11654.52~.00 255.B2 51~1.~ -2719.15 -8718.84 glad.al 0.~ T. 0 & ~d ~ H~11854.52~.~ 255.~2 52a1.~ --27~.a~ -~.02 9~6.m 0.~ 340 350 ~OJl&GasCons,~~ Anchorage TRUE NORTH 0 10 · ' I0 29O c,,at,d ~x ,~inc. For: BP, ASSFIELD Date protted : 30-Sep-q. 8 Plot Reference is ~5 V~ion ~5. ] Coordinates ~re in feet telerate ~ot ~5. [ I 1300 7O 280 8O 270 260 700 , + ',5c 700 0 1~0 150 1 go lO0 250 110 240 120 230 150 1~00 22 lOO 21 140 200 Normal Plane Travelling Cylinder - Feet 150 160 190 180 170 All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2N 335 slot #335 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE by Bakek Hughes INTEQ REPORT Your ref = 335 Version #5 Our ref = prop3155 License = Date printed : 30-Sep-98 Date created : 27-Sep-98 Last revised : 30-Sep-98 Field is centred on n?0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 12.880,w150 19 0.800 Slot Grid coordinates are N 5911899.004, E 460625.384 Slot local coordinates are 109.24 S 967.49 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-8500'>, PMSS <0-9134'>, PMSS <0-9553'>, PMSS <0-9690'>, PMSS <0-11225'>, PMSS <0-10655'>, PMSS <7090-10245'> ,317,Tarn Drill Site 2N ,313,Tarn Drill Site 2N ,323,Tarn Drill Site 2N ,329,Tarn Drill Site 2N ,331,Taru Drill Site 2N ,337,Tarn Drill Site 2N ,,337A,Tarn Drill Site 2N PMSS <0-11526'>,,321,Tarn Drill Site 2N PMSS <5286-10028'>,,32IA, Tarn Drill Site 2N PMSS <0-8182 ~,,325,Taru Drill Site 2N PMSS <0-7431 >,,345,Tarn Drill Site 2N PMSS <0-11197 >,,315,Taru Drill Site 2N PMSS <0-8239 >,,339,Tarn Drill Site 2N PMSS <0-12339 >,,341,Tarn Drill Site 2N PMSS <0-9631 >,,343,Tarn Drill Site 2N PMSS < 0 - 6150'>,,TARN#4,TARN #4 PMSS < 2250 - 7162'>,,3A, TARN #3 PMSS < 0 - 7650>,,Tarn#2,TARN #2 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 14-Aug-98 258.0 1198.0 1198.0 4-Aug-98 308.0 800.0 800.0 23-Jul-98 139.9 800.0 800.0 28-May-98 53.5 900.0 900.0 15-Sep-98 38.3 700.0 700.0 18-Jun-98 29.2 300.0 300.0 29-Jul-98 29.2 300.0 9340.0 25-Aug-98 180.7 800.0 800.0 31-Aug-98 180.7 800.0 800.0 22-Sep-98 115.7 1221.0 1221.0 21-Jul-98 149.7 100.0 4000.0 28-Sep-98 251.8 1000.0 1000.0 30-Sep-98 57.5 300.0 4520.0 30-Sep-98 90.2 100.0 3940.0 30-Sep-98 119.1 300.0 5760.0 12-Aug-97 6812.1 1500.0 1500.0 13-Jul-98 4278.3 1271.0 1271.0 14-Aug-97 12999.4 1221.0 1221.0 RECEIVED OCT 0?_ 1991] Oil & Gas Cons. knr.,horage ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline 21¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21 ¼" 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) RECEIVED OCT G2 Oil & Gas Cons. Anchorage ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L J 1 F I I 3" 5,000 psi WP OCT r---j MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP -"'~L 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple x 11" 3,000 psi WP DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom k 1 3" 5,000 psi WP Shaffer GATE VALVE _] ~raulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL LI'~'~ w/two 3" 5M psi WP outlets I SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams RECEIVED oCT 6 2 199B Oil & Gas Cons. commiSSiet; Anchorage o WELL PERMIT CHECKLIST COMPANY ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4 Well located in a defined pool .................. 5. Well Iocaled proper distance from drilling unit boundaly .... 6. Well located proper distance from other wells .......... 7. Sufficienl acreage available in drilling unil ............ 8. If deviated, is we,bore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ . .:,~..AP_PR__. ,~._ ~DA]'E 12. Permit can be issued without administrative approval ...... ~ ~:~/,..>"/~;j~' 13. CaP permit be approved before 15-day wait ........... GEOL AREA ~"N f N f N f N Conductor string provided ................... 15. St, face casing protects all known USDWs ........... 16. CMl- vol adequate to circulate on conductor & sud csg ..... 17. CM I- vol adequate to tie-in long string to surf csg ........ 18. CM I- 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 diveder required, does il meet regulations .......... 24. Drilling fluid program schematic & equip Iisi adequate ..... 25. BOPEs, do lhey meet regulation ................ 26. BOPE press rating appropriate; test to "~'~ psig. ENGINEERING .... "'~i"~ i UNIT# , //,/2/'~ ___ ON/OFFSHORE GEOLOGY A,~R DAiT E, ,_. ANNULAR DISPOSAL 35. APPR E)ATE N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y ~ /,/ 30. ~~/~e~s.-~...'~ Y N,,,~_.__ .................................................................................. 31. Data presented on potential overpressure zones ....... 32. Seis,nic analysis of shallow gas zones ' ..... ........ 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone_for weekly progress reporls ....... // Y N [exploratory only] ~ .......................................................................................... Wilt} proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (~ N (R) will not contaminate freshwater; or cause drilling waste... {~)N .............................................................................................. 1o surface; (C) wiii ii0t impair mechanical integrity of the well used for disposal; ~ N (F)) will not damage producing forrnation or impair recovery from a ~ N ..................................................................... pool; and (~ (,E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: wr,,, JDH ~ RNC ...... ~:: ..... Comments/Instructions: M chel~hsl ~f~'~v 05129/9~1 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 Drilling Services LIS Scan Utility Mon Apr 26 12:52:50 1999 Reel Header Service name ............. LISTPE Date ..................... 99/04/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/04/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, T~LRN 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: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM-80403 G. GRIFFIN G. WHITLOCK RECEIVED APR 27 1999 2N-335 501032027400 " ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 26-APR-99 MWD RUN 3 MWD RUN 4 AK-MM-80403 AK-MM-80403 G. GRIFFIN G. GRIFFIN WHITLOCK/BUR BURLEY 3 09N 07E 109 967 148.80 147.30 120.90 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 2450.0 6.750 12077.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2,3,& 4 A_RE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD) . 4. NO FORMATION EXPOSURE TIME CURVE (SFXE) AVAILABLE FOR MWD RUN 4 DUE TO SOFTWARE MALFUNCTION. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 30 NOVEMBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2N-335. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12077'MD, 5324'TV]D. SROP = SMOOTHED RATE OF PENETP~ATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTILA 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. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SCO2 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: FIXED HOLE SIZE = MUD WEIGHT = MUD SALINITY = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = 6.75" 9.2 - 10.0 PPG. 600 PPM CL- 19149 PPM CL- X.00 G/CC 2.65 G/CC SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NI/MBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2400 0 RPD 2445 0 RPM 2445 0 RPS 2445 0 RPX 2445 0 PEF 2450 0 DRHO 2450 RHOB 2450 FCNT 2464 NCNT 2464 NPHI 2464 FET 2476 ROP 2487 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 11983 5 11990 5 11990 5 11990 5 11990 5 11970 5 11970 5 11970 5 11954 5 11954 5 11954 5 9358 5 12076 5 EQUIVAf~ENT UNSHIFTED DEPTH -- BIT RUN NO MERGE TOP MERGE BASE 2 2487.0 3982.0 3 3982.0 9445.0 4 9445.0 12077.0 MERGED MAIN PASS. $ 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD OHMM 4 1 68 28 8 NPHI MWD P.U. 4 1 68 32 9 NCNT MWD CNTS 4 1 68 36 10 FCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CC 4 1 68 44 12 DRHO MWD G/CC 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF Min 2400 0.01 5.27 1 1.1 0 O8 0 14 0 27 10 16 2 23 150 67 0 12 -1 11 0 First Max Mean Nsam Reading 12076.5 7238.25 19354 2400 8560.55 313.093 19180 2487 243.65 121.957 19168 2400 27.03 4.96708 19092 2445 1266.84 5.25897 19092 2445 2000 5.90895 19092 2445 2000 6.50521 19092 2445 46.21 1.32304 13766 2476 177.02 37.9291 18982 2464 36585.3 20744.5 18982 2464 19298.7 237.288 18982 2464 5.16 2.3453 19042 2450 2.75 0.0982541 19042 2450 3983 2.52821 19042 2450 Last Reading 12076 5 12076 5 11983 5 11990 5 11990 5 11990 5 11990 5 9358 5 11954 5 11954 5 11954 5 11970 5 11970 5 11970 5 First Reading For Entire File .......... 2400 Last Reading For Entire File ........... 12076.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/26 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 ....... 99/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW 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 RPD RPM RPS RPX PEF DRHO RHOB FCNT NCNT NPHI FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 2400 0 2445 0 2445 0 2445 0 2445 0 2450 0 2450 0 2450 0 2464 0 2464 0 2464 0 2476 0 2487 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR EWR4 CNP SLD $ 3875 3859 3859 3859 3895 3982 DUAL GAMMA P~AY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN STOP DEPTH 3888 0 3895 0 3895 0 3895 0 3895 0 3875 5 3875 5 5 5 5 5 0 0 12-0CT-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.83 MEMORY 3982.0 2487.0 3982.0 45.6 75.8 TOOL NUMBER P1099GRM4 P1099GRM4 P1099GRM4 P1099GRM4 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 TEMPEP_ATURE (MT): MUD AT MAX CIRCULATING TERMPER31TURE: 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 6.750 6.8 LSND 9.10 46.0 9.0 5O0 8.0 2.300 1.078 7.000 2.600 .6 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 HOI/R 4 1 68 28 8 NPHI MWD 2 P.U. 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/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 21.2 Name Min Max Mean DEPT 2400 3982 3191 ROP 0.98 1334.09 453.142 GR 42.15 173.76 109.764 RPX 1 27.03 4.87304 RPS 1.1 1266.84 5.81889 RPM 0.08 2000 9.79267 RPD 0.14 2000 12.6739 FET 0.27 1.36 0.653762 NPHI 16.08 64.97 42.9965 FCNT 150.67 621.68 181.273 NCNT 15535.8 29231.3 18502.1 RHOB 1.23 2.85 2.21365 DRHO -1.11 0.79 0.10439 PEF 0.31 13.07 2.5277 Nsam 3165 2991 2977 2901 2901 2901 2901 2839 2792 2792 2792 2852 2852 2852 First Reading 2400 2487 2400 2445 2445 2445 2445 2476 2464 2464 2464 2450 2450 2450 Last Reading 3982 3982 3888 3895 3895 3895 3895 3895 3859 5 3859 5 3859 5 3875 5 3875 5 3875 5 First Reading For Entire File .......... 2400 Last Reading For Entire File ........... 3982 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/26 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 ....... 99/04/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW 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 NPHI 3860.0 FCNT 3860.5 STOP DEPTH 9323.0 9323.0 NCNT 3861 5 PEF 3876 0 DRHO 3876 0 RHOB 3876 0 GR 3889 0 FET 3896 0 RPD 3896 0 RPM 3896 0 RPS 3896 0 RPX 3896 0 ROP 3982 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 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: 9323 0 9338 5 9338 5 9338 5 9351 5 9358 5 9358 5 9358.5 9358.5 9358.5 9445.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY 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 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): 15-OCT-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.83 MEMORY 9445 . 0 3982.0 9445.0 73.1 77.6 TOOL NUMBER P1099GRM4 P1099GRM4 P1099GRM4 P1099GRM4 6.750 6.8 LSND 9.20 53.0 9.0 600 5.5 2.200 1.263 7.050 2.500 38.9 TOOL STAlqDOFF (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 .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 OHMM 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 P.U. 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/CC 4 1 68 44 12 DRHO MWD 3 G/CC 4 1 68 48 13 PEF MWD 3 BARN 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Min 3860 0 55 5 27 1 87 2 01 2 24 2 39 0 29 16 16 150 67 2 23 0 12 -0 05 0 Max 9445 2337 29 230 89 17 47 16 06 14 46 13 92 46 21 177 02 19298.7 31314.2 2.96 2.42 3983 First Last Mean Nsam Reading Reading 6652.5 11171 3860 9445 356.18 10926 3982.5 9445 122.951 10926 3889 9351.5 4.66414 10926 3896 9358.5 4.83724 10926 3896 9358.5 4.93646 10926 3896 9358.5 5.11994 10926 3896 9358.5 1.49492 10926 3896 9358.5 38.9504 10927 3860 9323 224.177 10926 3860.5 9323 20400.1 10924 3861.5 9323 2.33356 10926 3876 9338.5 0.106562 10926 3876 9338.5 2.61571 10926 3876 9338.5 First Reading For Entire File .......... 3860 Last Reading For Entire File ........... 9445 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/26 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 ....... 99/04/26 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 PEF DRHO RHOB GR 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 9323 5 9323 5 9323 5 9339 0 9339 0 9339 0 9352 0 9359 0 9359 0 9359 0 9359 0 9445 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : STOP DEPTH 11954 5 11954 5 11954 5 11970 5 11970 5 11970 5 11983 5 11990 5 11990 5 11990 5 11990 5 12076 5 17-0CT-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.83 MEMORY 12077.0 9445.0 12077.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY 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 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 60.0 73.6 TOOL NUMBER P1099GRM4 P1099GRM4 P1099GRM4 P1099GRM4 6.750 6.8 LSND 9.80 53.0 9.5 6O0 5.4 1.900 1.265 3.500 3.500 46.7 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 RPX MWD 4 OHMM 4 1 68 12 4 RPS MWD 4 RPM MWD 4 RPD MWD 4 NPHI MWD 4 FCNT MWD 4 NCNT MWD 4 RHOB MWD 4 DRHO MWD 4 PEF MWD 4 OHMM OHMM OHMM P.U. CNTS CNTS o/cc o/cc BARN 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 16 2O 24 28 32 36 4O 44 48 5 6 7 8 9 10 11 12 13 Name DEPT ROP GR RPX RPS RPM RPD NPHI FCNT NCNT RHOB DRHO PEF Min 9323.5 0 01 56 94 1 66 1 59 1 65 1 67 10 16 159 55 17679.3 2.07 -0.05 0.55 Max 12076.5 8560 55 243 65 20 07 19 27 17 52 16 59 55 34 1151 93 36585.3 5.16 2.75 6.85 Mean Nsam 10700 5507 144.052 5263 126.791 5264 5.64774 5264 5.8258 5264 5.78736 5264 5.98118 5264 33.1204 5263 294.234 5263 22649.9 5263 2.44099 5264 0.0776862 5264 2.34686 5264 First Reading 9323.5 9445.5 9352 9359 9359 9359 9359 9323.5 9323.5 9323.5 9339 9339 9339 Last Reading 12076 5 12076 5 11983 5 11990 5 11990 5 11990 5 11990 5 11954 5 11954 5 11954 5 11970 5 11970 5 11970 5 First Reading For Entire File .......... 9323.5 Last Reading For Entire File ........... 12076.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/04/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/04/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Scientific Technical Services Date ..................... 99/04/26 Origin ................... STS Reel Name ................ UNK/~OWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
