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Home My WebLink About198-092MEMORANDUM 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-343 KUPARUK RIV U TARN 2N-343 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-343 50-103-20260-00-00 198-092-0 W SPT 4938 1980920 1500 1450 1450 1400 1400 250 250 250 250 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-343 Inspection Date: Tubing OA Packer Depth 440 2190 2110 2100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803202930 BBL Pumped:2.5 BBL Returned:2.4 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. 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BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 April 4, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Cathy Foerster: APR 0 $ ?_O1 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, //RJ/71./7--1—C-4/2.--Y MJ Loveland ConocoPhillips Well Integrity Projects Supervisor . . • 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 r7 Change Approved Program r Rug for Redrill r- Perforate New Pool r Repair Well r Re-enter Susp Well r Conductor extension P9 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r- 198-092 3.Address: 6.API Number: Stratigraphic r Service r7 P. O. Box 100360,Anchorage, Alaska 99510 50-103-20260-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375074 KRU Tarn 2N-343 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 9631 feet Plugs(measured) 9390 true vertical 5495 feet Junk(measured) none Effective Depth measured 9390 feet Packer(measured) 8859 true vertical 5323 feet (true vertical) 4938 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108 108' SURFACE 3310 12 3340 2328' PRODUCTION 9585 10 8859 4938' EC E D PROD Liner 753 4 1/2 9612 5481' MAR 2 9 2016 AOGCC Perforation depth: Measured depth: 9116-9126, 9132-9152, 9160-9176, 9184-9224, 9236-9244, 9252-9262, 9270-9290, 9298-9322 True Vertical Depth: 5124-5131, 5135-5150, 5155-5167, 5173-5201, 5210-5216, 5222-5229, 5235-5249, 5254-5272 scow APR X [Gib Tubing(size,grade,MD,and TVD) 4.5, L-80, 8858 MD,4937 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DB NIPPLE @ 560 MD and 559 TVD SEAL ASSY-BAKER 80-47 CASING SEAL ASSEMBLY @ 8859 MD and 4938 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA 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 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 F7 Exploratory r Development r Service ri 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 VVINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-104 Contact MJ Loveland Email: n1878conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature Phone:659-7043 Date ., f, /7-0,'d1.-- 4-t- ,:=7 4)-4/41/C i L V'TL 4//,/27//G Form 10-404 Revised 5/2015 / 41A RBDMS LA- MAR 31 2016 Submit Original Only • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 MAR 2 9 2016 AOGCC 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-343, PTD 198-092, Sundry#316-104 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, g41"PrILY MJ oveland ConocoPhillips Well Integrity Projects Supervisor • • 2N-343 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/10/16 Prep and weld 26" long extension on conductor made with 16" .375 wall pipe. A r,,,,ffrgt �. r „,,,.'4,4,,,e'...1. airy' tie” .,, )01k*, , ,, 1 ry ,v - „e, , - -0.40007.** _,,,,,,.,;., 2. ,,, „ . , , . . '4*- -' f , ak \ \ ` F 6 \ ....,,„,--„, „ ,c - R3 OO Q. ee ,,,, ., 1/".”, , _c c r ,. - ,s, f * � ,: U U O � = � Q.cn U a 424, Cl) �►- 46111 m Ci) Cl) .44 Q Cl) " a.k O ..'.j:::-' x 1,,,!•.,-1 r a� 0 4- > (,) 9 �R 4� i ... -.t.:.:,..-..,,:.....yCO o r X f 5 JLLe 1, A O L O c '+,a _a 0 Li s c Nva a� o •� ¢ - ., � $ m „,, ,irvs.:-:',.,,-,,, ' ',i:!..,, .,), ' *it' a • • (n4 (n 4— U U co N • � > Q (r9 to 0 L U Q) ,< a'''''''',,,;*,t3 L e N. .�` ? §� + �3�' a �.`'S L ..c � � b 4 O s= — 'C' C g'-'. a) cl— ' , ` ' ' ' '''''''' 4, ‘.' .....,,,,,,„-,..„,"..i'..1.'::':::,!,:i'.,:,.,,..4„.',4'P:91,z,fil'''' ,':--L`*1--- fo' ...:D.— '''' ' s f x�L 'Q�E O O , aw , ,)8 a+ a,r d � 4, 4 fr �1 �'` °� IE. p', gM a. 4,4'4 a' • • .. • lir - "or:A; ' ° . ' t�� '4 ..„,,,6;1::::,,:,...,;:.' ,y .. ' r i iiia` � .. t § L "°`� 'Yi ;VIF r'S`' s�¢ . «sem.., ._ .. . #, L • �9�'- 09 2 OF TFJ 4',&A THE STATE Alaska Oil and Gas �h OfA T e 1 TA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 PR Main: 907.279.1433 A ,gSI� Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 SCOW FEB 2 2 2016 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU Tarn 2N-343 Permit to Drill Number: 198-092 Sundry Number: 316-104 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, Cathy P oerster Chair DATED this/v day of February, 2016. RBDMS LL F€13 1 1 2016 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 5 2016 APPLICATION FOR SUNDRY APPROVALS z iii/LC 20 AAC 25.280 AOU 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r 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 Conductor extension FF' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r 198-092 3.Address: 6.API Number: Stratigraphic r Service �. P.O. Box 100360,Anchorage,Alaska 99510 50-103-20260-00 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 r✓ KRU Tarn 2N-343 ' 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): 9631 • 5495 • 9390' • 5323' 3400' 9390' _ None Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 108' 108' SURFACE 3310 9 5/8 3340' 2328' PRODUCTION 9585 7 8859' 4938' PROD Liner 753 4 1/2 9612' 5481' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9116-9126,9132-9152,9160-9176,9184-5124-5131,5135-5150,5155-5167,5173- 9224, 9236-9244,9252-9262,9270- 5201,5210-5216, 5222-5229,5235-5249, 9290, 9298-9322 • 5254-5272 4.5 L-80 8858 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-CAMCO DB NIPPLE ' MD=560 TVD=559 SEAL ASSY-BAKER 80-47 CASING SEAL ASSEMBLY • MD=8859 TVD=4938 12.Attachments: Proposal Summary Fr. WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service Fir. 14.Estimated Date for 15. Well Status after proposed work: 02/25/16 OIL r W1NJ r WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG 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(a conocophillips.com Title: NSK Well Integrity Project Supervisor Signature !��%J/ //7- �„�.�/.%/, Date: „..2/3//:C Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 \ (.Q — \3Li Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: klb fo � doQtzrtvzf' 0.L. b51 `a1zvicc GtnCi r-c-pIna >r Post Initial Injection MIT Req'd? Yes r No ri Spacing Exception Required? Yes r No ? Subsequent Form Required: /0 — 4 o4 APPROVED BY Approved by: P r ,` COMMISSIONER K- THE COMMISSION Date:2 /O— / , v � 2/e1//4,GRI,G4N,AL. 45/,rSubmit Form and Form 10-403 Revised 11/2015 12 months from the date of approval. Attachments in Duplicate RBDMS F E' ' 1 1 2016 • • )✓ RECEIVED ConocoPhillips Alaska FEB 0 5 2016 P.O. BOX 100360 AOGCC 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-343, PTD 198-092 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, //71/ lam. MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2N-343 (PTD 198-092) SUNDRY NOTICE 10-403 APPROVAL REQUEST 02-03-16 This application for Sundry approval for Kuparuk well 2N-343 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 26". v 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 ' ` b • KUP INJ • 2N-343 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status11-.19) MD(ftKB) Act Btm(ftKB)cnm,<nff,mip, 501032026000 TARN PARTICIPATING AREA INJ 64.98 6,450.00 9,631.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-343,9/8/2015 2:49:30 PM SSSV:NIPPLE Last WO: 35.91 5/18/1998 Vertical schematic/actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,183.0 8/5/2014 Rev Reason:Mandrel Orientations lehallf 9/8/2015 HANGER;25.9 Casing Strings .11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND) Wt/Len(I. Grade Top Thread it'. - 4.. CONDUCTOR 16 15.062 29.9 108.0 108.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...'WtlLen(I...Grade Top Thread SURFACE 95/8 8.835 29.9 3339.6 2,328.0 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) 'Set Depth(ND)...'Wt/Len II.. Grade Top Thread !� 10 PRODUCTION 7"x4.5"@ 7 6.276 27.0 9,612.0 26.00 L-80 BTC-MOD 8850' I ini Aim Tubing Strings Tubing String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection .A.A.."CONDUCTOR;29.9-10e.0 TUBING 41/2 3.958 25.9 8,864.1 4,941.7 12.60 L-80 NSCT Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 91 Item Des Corn (in) NIPPLE;559.9 s 25.9 25.9 0.07 HANGER FMC GEN V 5M TUBING HANGER 4.500 " 559.9 559.0 8.98 NIPPLE CAMCO DB NIPPLE 3.875 8,764.0 4,869.4 44.74 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO DB 3.812 PROFILE;SLEEVE SHIFTED CLOSED 9/25/98 8,848.8 4,930.6 43.62 NIPPLE CAMCO D NIPPLE NO GO 3.750 8,858.1 4,937.3 43.59 LOCATOR BAKER LOCATOR SUB 3.875 II 8,859.1 4,938.1 43.59 SEAL ASSY BAKER 8O-47 CASING SEAL ASSEMBLY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1 i, Top(ND) Top Incl Top OMB) (ftKB) V) Des Com Run Date ID(in) 9,390.0 5,321.3 43.97 PLUG BRIDGE PLUG 10/21/1998 0.000 1 C Perforations&Slots Shot I Dens SURFACE;29.9-3,339.6-1 w Top(TVD) Btm(ND) (shots/f t) Type Com Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 9,116.0 9,126.0 5,123.6 5,130.8 S-5,2N-343 10/23/1998 6.0 IPERF 33/8"HCDP,60 deg ph, 0 deg orient SLEEVE-C;8764.0 9,132.0' 9,152.0 5,135.2 5,149.6 S-5,2N-343 '10/23/1998 6.0 IPERF 33/8"HCDP,60 deg ph, 0 deg orient 9,160.0 9,176.0 5,155.3 5,166.9 S-5,2N-343 3/29/1999 2.0 APERF 2"HSD,UJ changes, 180 deg phasing,0 deg 11 , , orient GAS LIFT;8,805.3 9,184.0 9,224.0 5,172.6 5,201.5 S-5,2N-343 10/23/1998 6.0 IPERF 3 3/8"HCDP,60 deg ph, al0 deg orient 1111 9,236.0 9,244.0 5,210.1 5,215.9 S-3,2N-343 3/28/1999 2.0 APERF 2"HSD,UJ changes, 180 deg phasing,0 deg NIPPLE;8,848.8 �t I orient 9,252.0 9,262.0 5,221.7 5,228.9 S-3,2N-343 10/23/1998 6.0 IPERF 33/8"HCDP,60 deg ph, 0 deg orient 9,270.0• 9,290.0 5,234.7 5,249.1 S-3,2N-343 10/23/1998 6.0 IPERF 3 3/8"HCDP,60 deg ph, 0 deg orient LOCATOR;8,858.1 9,298.0' 9,322.0 5,254.9 5,272.2 S-3,2N-343 3/28/1999 2.0 APERF 2"HSD,UJ changes, SEAL ASSY;8,859.1 180 deg phasing,0 deg 10 orient Mandrel Inserts St ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (RKB) Make Madel OD(in) Sery Type Type (in) (psi) Run Date Com 8,805.3 4,899.1 CAMCO KBG2- ' 1 GAS LIFT 'DMY INT 0.000 0.0 5/17/1998 2:00 LS Notes:General&Safety IPERF;9,116.69,126.0 End Date Annotation 11/23/2010 NOTE:View Schematic w/Alaska Schematic-9.0 IPERF;9,132.0-9,152.0 APERF;9,160.0-9.176.0 IPERF;9.184.0.9,224.0 APERF;9,236.0-9,244.0 IPERF;9,252.09,262,0 IPERF;9,270.0-9,290.0 APERF;9,298.0-9.322.0 PLUG;9,390.0 PRODUCTION 8x4.5"e 8850'; 27.0-9,6120 • • 2-G WELL LOG TRANSMITTAL DATA LOGGED /Z.2J201$ K BENDER To: Alaska Oil and Gas Conservation Comm. September 14, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper/Static Bottom Hole Presure Survey: 2N-343 Run Date: 8/14/2015 A' The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-343 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20260-00 Static Bottom Hole Survey Log 1 Color Log 50-103-20260-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 SCA048) Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: i/) ,,(12-,2-oze<4.) `��; • 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 To: Regg, James B (DOA) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Follow Up Flag: Follow up ~ l ~ ~ ~ ~~~ Flag Status: Red Attachments: MIT KRU 2N Pad DRAFT.xIs ~l 2~ ~~ ~ Jim, I 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 ~, ri ~~:v ,~,1~ ~~'~O~~s ti.... 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 Email to:jim.regg@alaska.gov; phoebe.brooks~alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~w ,~ ~,~~'/C2 FIELD /UNIT /PAD: Kuparuk /KRU / 2N ( 1 DATE: 08/24/10 OPERATOR REP: Ives/Mouser AES AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test • Packer De th Pretest Initial 15 Min. 30 Min. Welf 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 e test 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 e test P Test si 1500 Casin 1,245 2,820 2,760 2,760 PIF P Notes: OA 375 550 520 520 Well 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 TVD 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 WeII 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 etest 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'. W TVD 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 P.T.D. 1982040 T e test P Test si 1500 Casin 560 2,800 2,600 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 X1500 Casin 850 X2,780 -2,630 - 2,620 PIF 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: OA 150 250 250 250 Well 2N-325 T eln. W TVD 5015' Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T e test P Test si 1500 Casin 750 2,675 2,630 2,630 P/F P Notes: OA 220 250 240 240 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover 0 =Other (describe in notes) MIT Report Form BFL 11/27107 MIT KRU 2N Pad 08-24-10 Revisedl.xls ~~., m ~ „~ ~~rr , . _ __ , Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~~~ ~~~ ~ ~ Zfld7 • _~~ti~ - Well Job # Log Description N0.4445 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/15/07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE ` = C - 08/08/07 1 1 B-14 11837493 PRODUCTION PROFILE 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE Q- 08/30107 1 1Y-18 11837499 PRODUCTION PROFILE G' 08/30/07 1 1G-14 11839652 INJECTION PROFILE ~~, 3- 08131/07 1 1A-01 N/A USIT - 08131/07 1 1Y-04 11839653 INJECTION PROFILE f~ 09101107 1 1Y-32 11839655 PRODUCTION PROFILE ~ - 09/02/07 1 2T-TAB-01 11839656 INJECTION PROFILE C - ~ 09103!07 1 2K-25 11846439 INJECTION PROFILE U = j - 09/06/07 1 2K-18 11846440 INJECTION PROFILE l -~ 09/07/07 1 16-18 11846441 PRODUCTION PROFILE ~ - 09/08/07 1 2T-20 11846442 PRODUCTION PROFILE ~ - 09109107 1 2N-310 11850433 SONIC SCANNER 7L'"~-(7 T> 09!16107 1 2N-310 11850433 SONIC SCANNER-FMI ~ ~- C~`~ O 09116107 1 1J-176 11846443 USIT "~ -Q 09/17107 1 1E-29 NIA UCI j - j 09/19/07 1 3F-21 11837503 RST/ WFL 09120107 1 2B-10 11839661 INJECTION PROFILE ~ - 09122107 1 1G-05 11837506 INJECTION PROFILE `J T C - 09/23/07 1 2H-13 11839662 INJECTION PROFIL L - 09/23107 1 1 B-05 11837508 INJECTION PROFILE l,L~ , 09/24107 1 3H-08 11839663 PRODUCTION PROFILE - b 09124107 1 1Y-31 11839664 PRODUCTION PROFILE J ~ - 09125107 1 1G-O6 11839665 INJECTION PROFILE 09126/07 1 2Z-01A 11837512 USIT - (~ 09127/07 1 2V-08A 11837511 ISOLATION SCANNER '~~(- 09/28/07 1 1G-11 11837513 PRODUCTION PROFILE - 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE (~ 09130/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • . . Conocó'Phillips Alaska REC!\\JED SEP 1 2 2007 . sion A\aska on & Gas Cons. CaromlS Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 SCANNED SEP 12 Z007 q'?J; o'1'd"" \ ~4'~ ~~/ v Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). 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 corrosion inhibitor/sealant was pumped on September 5,2007. The attached spreadsheet 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, \~/~ ~ ~end ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 91712007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement DumDed cement date inhibitor sealant date ft bbls ft gal 2N-320 199-001 4" n/a 4" n/a 2 9/5/2007 2N-321 198-173 6" n/a 6" n/a 2 9/5/2007 2N-323 198-071 1" n/a 1" n/a 1 9/5/2007 2N-325 198-163 10" n/a 10" n/a 2 9/5/2007 2N-326 200-155 9" n/a 9" n/a 3.5 9/5/2007 2N-337 206-163 6" n/a 6" n/a 1 9/5/2007 2N-339 198-100 8" n/a 8" n/a 2.5 9/5/2007 2N-341 198-103 3" n/a 3" n/a 1 9/5/2007 2N-342 207-068 18" n/a 18" n/a 4.5 9/5/2007 2N-343 198-092 4" n/a 4" n/a 2 9/5/2007 2N-345 204-034 9" n/a 9" n/a 3.5 9/5/2007 Schlumbepuep û, NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ '7 ZOO7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r¡ nt 17IYL;{ ""¡;'D j),UG 3 . 5~\'f¡;Jo Field: Kuparuk Well Job# Log Description Date BL 1 R-27 11850425 FPIT ,q I - 10;) 08/18/07 1 31-08 11839638 LDL )"'lr(", - f"'IIl\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE I '"r" ,Q I -~-:l 07/29/07 1 3G-26 11813071 LDL )o¡q -rtJK 07/30/07 1 1R-18 11837482 SBHP/DDL )q/-'^f5~ 07/31/07 1 1Y-01 11813072 INJECTION PROFILe U':r:"~ - J-sr3--6""\6 07/31/07 1 2C-08 11813073 INJECTION PROFILE' I )T(\ )1r"Z. -r"'A.""'" 08/01/07 1 3H-32 11837483 LDL :J¡y") - Ñ, f 08/01/07 1 1Y-10 11837485 INJECTION PROFILE ·U~ J~"2., -as- ) 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' ,,,,/) - () '-'fr 08/04/07 1 1A-06 11837486 INJECTION PROFILE i J"r.C' .:,r-/Il.. 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . ,qN~ - /{,. ~ 08/06/07 1 2U-08 11813076 LDL WI7t ~-~I 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE Ifi3. - ~~ 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE ()7"(' Iq~- N1.::2 08/08/07 1 2N-327 11837491 SONIC SCANNER Bù --:t -oco ~ 08/08/07 2N-327 11837491 SONIC SCANNER-FMI ............... -'/'1 08/08/07 3K-01 11632749 PRODUCTION PROFILE . J7ffo ~ 101 08/12/07 1 2X-04 11846430 INJECTION PROFILE (J:U' I-$¡3 -II*, 08/13/07 1 2Z-29 11850419 SBHP SURVEY 11f~ ":")::JCJ 08/13/07 1 2X-19 11850420 SBHP SURVEY ¡ '1 ö - J"J;<,- 08/13/07 1 1A-20 11850421 SBHP SURVEY J O¡f) - IC:} 08/14/07 1 1 F-13 11850422 SBHP SURVEY U 'L "\ 1s.3 -li./I.J 08/14/07 1 1H-10 11846432 SBHP SURVEY Jq,:<-~ 08/14/07 1 1 Q-1 0 11846431 SBHP SURVEY I~¿ - Jq'$r 08/14/07 1 2U-05 11846433 INJECTION PROFILE I 'ï:1" J!Ir.-Ç" -1ìI< 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE I ~I./ - ti?4 08/16/07 1 2H-06 11846435 LDL J~.< -IIß~. 08/17/07 1 Color CD 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ';)7J" 08/22/07 . . 07/23/07 Schlumberger NO. 4336 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth L. 2 5 Z007 Cons. Gomrniss6CANNED JUL 2 7 Z007 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: fìJaS!íi:;'t Oii ¡?, ULC- l '7 ~ -Cf19. Field: Kuparuk Well Log Description Color CD Date BL Job# ('!J 2M-20 11629044 PRODUCTION PROFilE 07/11/07 1 3M-20 11665456 INJECTION PROFilE 07/13/07 1 2M-27 11665457 INJECTION PROFILE 07/14/07 1 1 R-20 11632727 LDL 07/12/07 1 2M-17 11632731 INJECTION PROFILE 07/14/07 1 3M-27 11632732 LDl 07/15/07 1 1R-15 11632734 INJECTION PROFILE 07/17/07 1 2L-327 11665460 TEMPERATURE SURVEY 07/17/07 1 2V ·08A 11665459 UslT 07/16/07 1 2Z-16 11665458 sCMT 07/15/07 1 2N-343 11665463 INJECTION PROFILE 07/20/07 1 1L·07 11632735 INJECTION PROFILE 07/20/07 1 1A-09 11632736 INJECTION PROFILE 07/21/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: J ¡m Regg P.I. Supervisor ----::> G ¡:v Jei hefL( J Î . u! 'P DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-343 KUPARUK RIV U TARN 2N-343 \, q IQ "VC( g... FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~'TfF- Comm NON-CONFIDENTIAL Permit Number: 198-092-0 Inspector Name: Chuck Scheve Inspection Date: 8/8/2006 Well Name: KUPARUK RIV U TARN 2N-343 Insp Nurn: mitCS060808192232 Rei Insp N urn API Well Number 50-103-20260-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 'I 2580 ' 2510 I 2470 i 2470 I-~ I . I 250 I25Ü-¡- 250----¡-~~ I ' 1750 I 1750 I 1750 'I 1750 +---¡750I--~ - 1 ~~" 1 I Well demonstrated good mechanical integrity. 1 IA ! I lOA I Tubing I 500 -^. l------r Well ! 2N-343 ¡Type Inj. I W ! TVD ! 4938 -, T' P.T. , 1980920 ¡TypeTest 1 SPT I Test psi I 1500 .l!!krval 4YRTST P/F P /' Notes Pretest pressures were observed and found stable, 150 SCANNED AUG 24 2D06 Wednesday, August 09, 2006 Page I of I lJ:ï,rE i- " f· . ,; L6 e / í A"~SIiA OILAlWD GAS / CONSERVATION COJDIISSION , March 30,2006 e f'ITIU' ì U~ lÃ\ rL' I~\ ~ f1<,' Æ\ lJb! frIJ U::ï L~ ® U~ lflJ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Dubuisson Manager, North Slope Operations ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 r t.: Subject: Defeated SVS at KRU We1l2N-343 Dear Mr. Dubuisson: ConocoPhillips Alaska, Inc. ("CP AI") responded on March 20, 2006 to the Commission's letter advising of the defeated safety valve system ("SVS") at Kuparuk River Unit Well 2N-343 (PTD 198-092). Included in CP AI's response were the event description and status of remedial actions undertaken to prevent the occurrence of defeated SVS components in the future. The detail of CPA!' s response is appreciated. The Commi~sio!l has reviewed the information provided and concludes no further action regarding this defeated SVS is necess~ ~ /ÍSinc r{ cc: AOGCC Inspectors (via email) Problem Well Supervisor - NSK 69 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 e e ConoC6Phillips Alaska, Inc. E. Paul Dubuisson Manager North Slope Operations Post Office Box 100360 Anchorage. Alaska 99510 ATO-1120 phone 907.263.4822 dubuiep@conoCOPhìllips.com March 20, 2006 1~ _"I~:~ 1" \\ !J'b [! '%1 ~= MAR 2 8 2006 Mr. John K. Norman Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~, " ';ß '" if",", f'·, ""'ffi" ¡",~i,"'~ iŒJ<¡.~h" f'lpg N tJIJ13 \A~iíUi;>, 'yij'J"g";:¡..,,..,ij, ifßlJt,;I~!i't!.~ ~~L _ Ar~t!1¡¡f©~'8 Dear Mr. Norman: In the AOGCC letter dated 21 FEB06 regarding a defeated surface safety valve (SSV) at KRU Well 2N-343, ConocoPhillips Alaska Inc. (CPAI) was requested to provide the Commission with an explanation, including what steps are taking place to prevent future occurrences. Below is a description of the events leading up to the discovery, followed by a table of remedial action items that CPAI's Incident Investigation team recommended. Most of the remedial actìon items have been completed. The surface valve safety system (SVS) training program is still under revision with an expected completion date of mid year. Event Description 1. During AOGCC witnessed SVS testing at DS-2N on January 19th, 2006 the AOGCC inspector found the solenoid valve isolated on the SVS panel for 2N- 343. 2. The SVS Operation Guideline, issued 7/27/03, states that DSO/DSM personnel are required to "visually confirm that the SVS is not defeated at the panel" during their daily wellhouse checks. 3. This DSO position is responsible for three drillsites (2L, 2N, 2P) which require 64 wellhouse checks. 4. The SVS on 2N-343 was previously state tested on December 28, 2005. Three CPAI and one AES qualified DSM operator had operated the pad between December 28, 2005 and January 19, 2006. 5. The operators completed daily visual checks to confirm the 2N-343 panel was in service through the date of the incident. There were no flagged or tagged valves, the hydraulic pressure was correct, and the panel isolation valve was not noted to be in the defeated position. e Mr. John K. Norman 3/20/2006 Page 2 e 6. Multiple personnel came in contact with the 2N-343 safety valve system (SVS) prior to the incident. The specific time and personnel responsible for defeating the panel are unknown. 7. There are a number of people who accessed the pad prior to the event whose work scope may have required them to defeat the panel. A review of records identified several works scopes where the panel may have been defeated including: · December 28, 2005 valve crew serviced 2N-343. · December 31, 2005 the MI header was shut down. · Automation indicates an event on 1-1-06 when the panel was potentially defeated. It is not possible to determine if the panel has been defeated from wellhead automation. 8. The SVS panel is a first generation Baker panel design. 9. The % turn valve isolating and defeating the panel is located on the bottom of the panel obscured from normal view. 10. The % turn valve, which was not in proper position, was not flagged and tagged per the ASH handbook requirements for the Flagging and Tagging Standard. 11.After the discovery, the valve on the panel was returned to the normal operating position without incident. .""" " '''1I'f,__~J)'o-~~\-1,(>::,<' -2 "--- ~,i>~i'j; 1:,' , ' ,·r, " , . .......i. ,,' , r/ ,.' , ,{ .. " /1"" ..I.,,~,~: . "" .,.., ~~: ;.;- ,'- J' ',,;,,,.," i " ........... '~, ~ ,.' "C',~ <;!!"~'", \c, ~"";"~;:',";' .~ Panel isolation valve ~i,~>j' in, the defeated (down) / / ~~ Position //,~' l\~'S photo is copyright by "___'~_'''''' Co ocoPhllllps Alaska Inc" ~__':.Li-_''':''.ê-'.-,~.:::...._,'_, '> and an r . I ..-'. - - .'!! "---'.----'----publishec .. express c ConocoP ,.iI 2N 343 Hydraulic Panel Picture Mr. John K. Norman 3/20/2006 Page 3 e e Remedial Action 1. The Production Superintendents immediately reinforced expectations for performing detailed daily wellhead safety surface system checks. - Completed 2. The Production Superintendents immediately reinforced expectations that any work on wells involving the safety systems requires the Drill Site Operator (DSO) to field verify that safety systems are in the normal operating position within 12 hours after the work has been completed. - Completed 3. All Production Superintendents and Team Leads (CPAI and AES) immediately emphasized that the Flagging & Tagging requirements in the ASH Handbook and SVS Operation Guideline are to be followed without exception. - Com leted 4. All Production Superintendents and Team Leads (CPAI and AES) immediately emphasized that the Defeated Safety Devices Standard in the ASH handbook is to be followed without exce tion. - Com leted 5. CPF2 OS L T wrote up a moredetaHed procedure for the electronic SOL which is specific to roles and responsibilities and created a change log to document trainin on this rocedure. - Trainin has been completed 6. As a result of previous safety valve system incident investigations, the SVS training program has been reviewed and training is being revised. The updated training program is nearing completion and will be rolled out to all personnel that works with SVS panels. - In Pro ress 7. The Production Superintendents emphasized the need to document safety devices found defëaterl without a flag and tag in the Audit Near Miss S stem to allow trendin and notification. - Com leted 8. Wellhead SVS audits are recommended on a semi annual basis. These audits require the participation of the Drill Site Lead Operator, Production Superintendent, DSO, Safe Specialist, and a Well Su ervisor. - On oin CPAI takes regulatory compliance very seriously and has systems and personnel in place dedicated for that purpose. The company will continue to look for ways to ensure compliance and prevent future occurrences. Sincerely, C-.Ù .... Paul Dubuisson Manager, North Slope Operations FocL cc: Jim Regg (via email) /Van Lineberger (via emaH) RE: KRU 2N-343 e · (>Ii).:tl 11ß-<Yl '2- Subject: RE: KRLJ 2N-343 From: NSK Problem Wcll Supv<n1617@conocophillips.com> ])ute: Tue, 14 Mar 2006 12: 12: 13 -0900 1.J;1.{ To: James Rcgg <jiI1lJcgg@admin.statc.ak.us>"jl Jim, I will check on it. We (Problem Wells) did not receive the letter - even though the electronic copy is clearly marked with our address. You will have an answer soon. MJ Loveland -----Original Message----- From: James Regg [maìlto:jim regg@admin.state.ak.us] Sent: Tuesday, March 14, 2006 9:27 AM To: NSK Problem Well Supv Subject: KRU 2N-343 6C.Á\NNEC ¡Wn C 4 The SSV on KRU 2N-343 was found defeated at the control panel on 1/19/06. We sent a letter to Mr. Dubuisson on 2/21; received by them 2/23; you were also copied on the letter - see attached. Letter requested an explanation and description of corrective actions within 14 days of receipt. We have not yet received your response. Jim Regg AOGCC 5fòQ u1 MJ' Lòve'ltt.~) eM l;Jlêl ~f?~ ~Ùl\f1 'ft-e"{ ctdl Nf· eM- N" Sicp1L :3¡I41oG' $~ .J ftr ~ , (S rec£"CK CðP(¡~' l~.r- - 8~"k,A. e~/ffüh)~ repLL'l l"J ~t¿~a 3/?ÆJIO ~ ::Ii< è'i1 3/14fðþ 1 of 1 3/14/2006 12:55 PM e e ~'=',';;;¡jF:;"'\i6,. .~ '1, '. '=' ., 'Î ii' ',,'" ) r: ~' ,. " ", '"" Þ " ',. 'I;'" "', " ' . '\;\ J) ¡:LH ji i: :F'ì Hi' j j""'"j'\ ,,; j il ,~, ';J J,J UU ~ r·~ ,r,:::¡ P"jJ "I ;,q ':51 ~UdJH : : r '! I.}' , , " I U I' n' ,.,.~ n r; '/;\' r' ¡" ',' ((Lj' 1/' ¡ð '\ ì ¡ /8 \.~~ i r(, ,¡',å ,-' ¡ ¡ ¡ n \ ,..,u duf\ ',\ ¡ n ;, ;.J ü~u u\.......>I!,'uLi U j j I / FRANK H. MURKOWSKJ, GOVERNOR .{ ./ A"IA~IiA OIL AND GAS CONSERVATION COJDIISSION / I ;' i ¡ 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 February 21,2006 CERTIFIED MAIL - RETURN RECEIPT REQUESTED 7004 11600001 3621 2417 Paul Dubuisson Manager, North Slope Operations ConocoPhillips Alaska, Inc. p.o. Box 100360 Anchorage, AK 99510-0360 Subject: Defeated SVS at KRU Well2N-343 Dear Mr. Dubuisson: On January 19, 2006 an Alaska Oil and G<lS Conservation Commission ("Commission") Inspector accompanied by a ConocoPhíllips Alaskét, Inc. ("CP AI") representative performed safety valve system ("SVS") inspections at Kuparuk River Unit 2N-pad. The surface safety valve ("SSV") on We1l2N-343 (PTD 198-092) had been defem.d at tb.e panel some time prior to the inspection, preventing the SSV from operating with a low-pressu[~ pilot trip or emergency shutdown of the SVS. A copy of the inspection report is attached. The facts reporteù by our inspector appear to indicate a failure to maintain an operable SVS, which would be a violation of State regulations. . Within 14 days of receipt of this letter, you are requested to provide the Commission with an explanation of how this event happened and what will be done in the future to prevent its occurrence in CPAI-operated fields. Yau are reminded that Conservation Order 430A (Kuparuk River Field, Tarn Oil Pool), Rule 6 modifies the requirements of20 AAC 25.265 ("Automatic Shut-in Equipment") as follows: a) All producing wells will be equipped with a fail-safe automatic surjace safety valve b) Water injection wells will be equipped with a double check valve arrangement or a single check valve plus a fail-safe automatic surface safety valve. c) Gas or MI injection wells will be equip pet! with afail-safe automatic surface safety valve and a single check valve. d) Gas or MI injection wells must be equipped with a landing nipple at a depth which is suitable for the future installation of a down hole flow control device to control subsurface flow. e e I"- : .-'I' .:T ru .-'I ru ..a T U.S:'PostaIServiceTM CERTIF1ED MAIL" RECEIPT (Domestié Máil Only; No Insurance Coverage Provided) Postage $ 0.39 2.40 1.85 UNI:r<íÐEi35?: /.<:;.::~/,... ~<~c~:~- :(~,~~!:~!/ \.':~:'-'- !,',;~/ Postma~r\:ò \'~,')\ , ~ ; FI~ . L\)\J ) :s:' !,¡.. \ c.co. ,,,,W'(; , ,J (I,', ' " 1 ~íJ .; ,-"-, (¡!èfk: BSOORO j::;", \,~¿;~~ .~.-;:- ,;./ 0" ì?;¡¡Ñ.~-l";'r:-<) '~),/ '-I ''''-,>'l~., o' _.::~~~,-",/~-" .-'I I:J I:J Return Reciept Fee I:J (Endorsement Required) I:J Restricted Delivery Fee ..a (Endorsement Required) ,..: ,..: Total Postage & Fees $ Certified Fee 4.64 ~ Sent To I:J I"- :§;;Ðëf,AP£Ñõ.;--··-··---·····------······-··-··-··-···-·-·-·---··---...-.--..-....-.. or PO Box No. ëilj;;-šiiiïë;:z;P+4-·--·-··---·-·----------·--··-----··---···-..--.-....-.-.-.-....-...- - ~ -.. - . Affix. Pas Tata 1 Cost: 0 39 Base Raê~~VIÇES . cetÕÓ1~~~o~ßö1362124d17) Rtn Recpt (Green Car subtotal Tota 1 2.40 , .85 0.00 0.00 Number of Items Sold: 1 . h t the postal store appreGlate \I!~oue~; ~ur .Sustomer and wi~~\I/~~a~ u.__...u" I¡.,~I/and ª Safe UNITED STATES POSTAL SERVICE III/II First-Class Postage & ~ail USPS ees Paid Permit No G . ·10 · Sender: Please print your name, address, and ZIP+4 in this box. AoGJ CG 333 w. 1~ ~Y-é: J o~ too ~/~~~k 111....(,.... 0:1 0 f\ " ". . . II UIWlIII~'\~ wit y \..tâ~ \JOn~. f'\ i !; i ¡ ¡ ! ¡ ¡ ¡ ¡ ¡ ¡ ¡ I ¡ if ¡ ¡ ¡ ¡ ¡ ¡ i ¡ ¡ ¡ i ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ ¡ i ¡ ¡ ¡ ¡ ¡ ¡ ¡ i II; i ¡ ¡ ¡! I ¡ ¡ ¡ ¡ ¡Anchorag~~ e e Mr. Paul Dubuisson February 21, 2006 Page 2 of2 e) Surface safety valve systems must be maintained in good working order at all times and must be tested at six-month intervals or on a schedule prescribed by the Commission. The Commission reserves the right to pursue enforcement action in connection with this apparent violation as provided by 20 AAC 25.535. Should you have any questions regarding this correspondence, please contact Mr. James Regg at (907) 793-1236. Attachment cc: AOGCC Inspectors (via email) Problem Well Supervisor - NSK 69 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Reviewed By: P.I. Suprv Comm Safety Valve & Well Pressures Test Report .1 Pil(t.~, ,.' J!i~\~~ 1.~·~;svJW~~!.!n ij!.in~ ~~~1-1!~e, Welll;.'.~~sur!~_·-· .I ~~sLvt.!· ~~iv~~L:. ' Separ Set LIP Test Test Test Date SI Oil,WAG,GlNJ, Inner Cuter Tubing PSI PSI Trip Code Code Code GAS,CYCLE. SI PSI PSI PSI YeslNo YeslNo un:: - _:r ~ä_~ ., ~-~; _~--, ,,~~~Fu J~~:C~_._1{-~{-T u~~~u___-~i~l_--_~~;__= --~~-~--_.--:~~~~---"---~_~ 2150 200 250 Yes No .---- ---. -~-- ~---- -'-'---"'--- 125'J 490 265 Yes No -~~_. --- --- -----..---- 300 250 Yes No u,__ ____n____ 360 260 Yes No -"-- ,'-- .-------- --,- -~..~-_._---_._-,-------_.__._--,.__._"-- 1250 210 250 Yes No -------. ------" --'---. --~--_.._..._------ ------. -_.'_.----.----- _.__...-_.---~- 2000 50 265 Yes No -----. -.------.-- ----~_.._-- -"--"-- ---- .--.--. -- ---'.---..-,.-.. ------- 2050 400 260 Yes No --"--- --~-...- 1180 600 240 Yes ._._,~ -.---.-- -....---. --------- 1930 400 290 Yes No ----,.~ --._~-- ---_._.~ -'. -.- 2000 700 250 Yes No _._---~...- _.~.~ ..----- .'-.-.-----.'--- _.._-----~.._-_.-_._..-----~~._.._._._~ 1100 200 250 Yes No .-.~------- '-- --....--.- -,--.---,--. .- ..._--_._--~-~._-----~---------~~ 1400 300 270 Yes No -.---------- -----.-- -------.---. ._--_.~~-_._--_._._-------_._~--- 850 50 3325 No 2N- 34 3 svs was defeated at the panel. Operator was called and had no explanation. When panel was normaled up all svs components te~~~s exp~t~.and p~sse~,---___~ _ ~~o~ · ··~~!i-l:~~-:lI~-~; _ ~~ - -::~:.=~ - - --~:r--- -. 7\~-- -~~õ- - 3;:o~_- --~:s -~ - -- ----- -_. _u_ ---- -- ----- ~_.- ----------- -- ----------- Pad: KRU_2N InspDt: 1/19/2006 Inspected by John Spaulding Interval Field Name KUP ARUK RIVER Operator CONOCOPHlLLIPS ALASKA INC Well Data ... . ..-... ... Well Number Permit Number --_.~--~. --- 2N-303 2001690 .---------- .-.-----. 2N-304 2011300 ~"--'-~-- ----_._-_._-~. 2N-305 2001350 --'-- ---.--- 2N-313 1980910 88 --- -------- 2N-315 1981900 88 ---------_.~_._-_._--_. 2N-316 2000900 88 ~-~..._-_._-_.. --------..-.-. 2N-317 1981430 88 .__._----------~---_.. 2N-318 2001000 88 ----. ----- 2N-319 1981970 88 -..---- --- ,2N-323 1980710 88 ------- 2N-329 1980670 88 --..----.- 2N-332 2000790 88 -.------. -'---'- 2N·339 1981000 88 ---.--.-.--. -------- 2N-341 1981030 88 -~------- ---- 2N-343 1980920 3800 --.- .---!-..----.- 85 80 P P I-OIL __~-_=__.8.? -~-p---p ~-=-=-l'-~-ì-O!~~~ 85 80 P P I-OIL --~-š5- --P- -I'. I-OIL 8s---------s5 -~p -- --P- ---- -¡--I-OIL- '---~'---"- - --.'-' ~----~-- .-----------.- 85 80 P P I-OIL -'-'--'..--'--'-'- ,-.--- --.--- --.-"---.--.. 85 80 P P I-OIL -_.-'-'-~--- .-_._--------~-_._------- 85 80 P P I-OIL ---- _.-- ------ ._---~.._- ------~--_.. ..----'''' -..-.. 85 80 P P I-on. ---.--"------- -.--.-. -. ----.---. ---~ 85 85 P P I-CIL .~--------- --_._~ -- ..------ _._~_._- 85 80 P P J -OIL ~-----_.._~ .-- ----.---. 2000 45 P W AGIN -..-----..----- -..------.-. ------..._- ._---_._~ ---- ---.----.-.-- ..~.. -----~ ------I-r [~~;l~~·tt-i¥-:~:~(- ~¡r 1-~_~ InspNo svsJS060207103522 Op'~rator Rep Related Insp: Reason Src: Inspector , Comnient.~ . -- ... .. ,. .~ -----..---.-.-,-------. ---.----..------- e -~-"----- ------. '-'-~--~----'-~ 9':0 ._,,_~______________.. ·_~_____.._n__~_ ",00 ._.._--------~_....- -. ---- -- --------------- No -~---_._----- _.---.._.----"---~--. - ----------_._..._----~---..~..---- no --....-.- --_._-.~_... e Comments 2N-343 svs was defeated at the paneL Operator was called and had no explanation. When panel was normaled up all svs components tested as expected and passed, Tuesday, February 07, 2006 Performance [-~_. .-. --.--..- ---.-.---.-.-.--..-..-....---..] Wells Components Failures Failure Rate :-~J~=:::.~..:::-:-l_8-==----.:..-:-=-:::-=l===-_~,§)~~:-=:-__.. \ . " \ ( \<1 <;--0 S~ MECHANICAL INTEGRITY REPORT' '... :?UD DA:::: : 5/~_~'~ -' _ _ G ., t" - -.' ,;. - 5j¡( e-.." - c.. C/ :.. ~ t\ ... ~ ~ r".':::' ~: - 0 '\ 0 OPER & FIELD t.\7/\ \L.0\O.\0\C- WELL N1lliBER d-\()~'~~ ~ \a.s- ~ :~~LL DATA TD: Sb~ \ .HD.. 5'--\~~ TVD¡ ?BTD: C\~);~ KI? 5~%~ TVD Ca.siTIg: l Shoe:~~~QHD TVD¡ DV:' \-JÞ\ HD ·Tvu '-~~~ ~\ I:;) Shoe: <i ~ \d MD TVD; :OP: ~'ì:¡Ù HD :'TD ,~~R ,..,- : iJ 0 i!: g: Í1: \ r;) P 2. eke ~ c¿{6~ HI) c,.. \ / ""'. ~ole Size D ~ anå TVTI¡ Set ê.t P er£ 3 ~\lG 5\ \ (p to "if'S ¿)." Sà'~\ ~C?_Al~IC:--L INTEGRITY - PART ¡ 1 Annulus Press Test: ~p ; 15 min 3 0 min Co=en t s : ~) C:X\ ",,6.. \~ ì. \d /.... - ~~ ~ ~\. ~ c..\~ P fs J",:> - ad ,,- . ~ j i i i i ¡ ! 1 ¡ tŒCRANICÞ.~ INTEGRITY PART 42 Cement: Volumes :'. Þ-.mt. Liner ; Csg ~'"SS-S'f. j DV \J .!\.. . C ül t -.¡ 01 toe over per £ s e:.' 3D 10 "S '-...J ~_.\'"':-\ C-.\ co",,'\--' <:'Ç(. ~Q ~~ \lJac, ~ð~~\-o'Ç\~CCè CŒ: ð'^-º:"'-'\- "'-J1è. ,\ <J..h9-JQ -\~ C-S '<- ï:'heoret:ical Toe \..j ~ \ G It"d- 'i 8,_,. Cement Bond Log (Yes or No) 'i~~<> ;:r~ AOGCC File '''',,-t.) ? '0"'::>- ~ " \:.) \ x c; ..;"'~ \ \.. <:....~~ ~,~ \ CBL ~val't'tion...!... ::one above perfs, R; )+<").\0 s-<>- ~ <::(),:)(?>,n~' \~ "'-"", ~Ððd~ \)'\Ù ~.\-'- \<::)~_.~. \'0 \.J.p-Ç 'ò~ ~+~' ,~ P roduc.tion La g : Typ ~ ¡Evaluation ? ax t if 1 : ? a.rt: f. 2 : -'- J!7J;?/) /J ;) /JJ- ,V( ((. ·-oti SC/~NNED FES (} 9 200~· Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2860 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3s-23 ~.~.~-©LL~ PERF & S..P WI JEWELRY 'O~ 04129103 2N'343 ~ ~ ~'~ ~ INJECTION PROFILE 05102/03 2N-348 ~ ~' ~ [-t& iNJECTION PROFILE 05/0~103 2P'429 ~ ~ ' ~C~ MEM PSP INJECTION PROFILE 05~06~03 05/28/03 DATE: RECEIVED MAY 50 2005 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Alaska 0~i & Gas Cons. C0mm~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (,~0~ DATE: August 3, 2002 Chair "5; SUBJECT: Mechanical Integrity Tests Phillips Alaska THRU: Tom Maunder P.I. Supervisor 2N Pad FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. we,} 2N-307 IType,nj.I G IT'v'D' I 5141 I Tubingl 3150I 3150I 3150i 3200 Imte~va~l 4 P.T.D.I 1990170 1Type test] P, , I Tes{ psiI' 1500" I Casing I 2275 i' 2900 I 2900 I 29100I ' PiE I.-P. Notes: we,,! 2N-321A I Ty~el.j."I S ! 4915 IYu ,n, I' 1700 I 700 I 700 I 1~oo I Interva, I 4 P.T.D.I 1981730 ITypetesii P ITesipsil'1500 1,casingI 100 I~lgoI 2150I 215oI P/F I E Notes: Well Notes: 'wa, P.T.D.' Notes: P.T.D. Notes: 2N-325 ITyPeinj:l G !T'v'D' I 5015 I Tub~ngl 2850I 2650! 2850 I 2550 I,nte~,a,I '4' 1981630 ITypetestl P ITestpsil 1,500 I,Casingl ~075 I 1950 I 1940 1,1940 I' P/F I -P' 2N-331 ITyPe~nj.I S I T.V.D. 14770 I'Tubingl 1675 '1 575 I 1575 I 1575 Imte~vaq 4 1981170 ITypetestl ,P ITestpsil 1,~00 I Casingl 600 1'2025 I 20251 2025 I' P/F I ~P, I 2N-343 ITypelnj. J G J'T.V.'D.14938 Jf~bingJ 2550 J 2550 J 2650 I' 2550 J,nte~va, J 4 J 1980920 JTyp'etestJ P JTestpsiJ 1500 jcasi'ngJ 2000 I 2925 J '2925 I 2~25J PIE J P I I 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 Workover O= Other (describe in notes) Test's Details I traveled to pAI's Kuparuk River Field to witness 4 year MIT's on 2N Pad. No failures witnessed. M.I.T.'s performed: _5 Attachments: Number of Failures: 0_ Total Time during tests: 4 ,,hm, cc~: SCANNED AUG 1 g 200~ MIT report form 5/12/00 L.G. 020803-MIT KRU 2N JC.xls 8/5/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perlorate_ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 28 feet 3. Address Exploratory _ 7. Unit or.Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk River Unit 4. Location of well at surface 8. Well number 137' FNL, 1084' FEL, Sec. 3, T9N, R7E, UM (asp's 460508, 5911872) 2N-343 At top of productive interval 9. Permit number / approval number 1468' FNL, 2583' FEL, Sec. 4, T9N, R7E, UM 198-092 / At effective depth 10. APl number 50-103-20260 At total depth 11. Field / Pool 1527' FNL, 2250' FWL, Sec. 4, T9N, R7E, UM (asp's 453295, 5910466) Kuparuk River Field / Tarn Pool 12. Present well condition summary Total depth: measured 9631 feet Plugs (measured) true vertical 5494 feet Effective depth: measured 9392 feet Junk (measured) true vertical 5323 feet I Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 108' 16" 9 cu yds High Early 108' 108' SURF CASING 3312' 9-5/8" 386 sx ASm LW, 350 sx C~ass G,, 3340' 2328' PROD CASING 8831' 7" 435 sx Class G 8859' 4938' PROD CASING 753' 4-1/2" (included above) 9612' 5481' PROD CASING Perforation depth: measured 9116'-9126', 9132'-9152', 9160'-9176', 9184'-9224', 9236'-9244', 9252'-9262', 9270'-9290,, 9298'-9322' true vertical 5124'-5131', 5135'-5150, 5155'-5167', 5173'-5201', 5210'-5216', 5222'-5229', Tubing (size, grade, and measured depth) 4-1/2",12.6#,L-80Tbg@8859'MD. NOV I ~ ~001 Packers & SSSV (type & measured depth) Baker Casing Seal Receptacle @ 8859' ~ CAMCO 'DB' @ 560' MD. Alaska 0il & Gas Cons. Commission Anchcr3~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - Subsequent to operation - 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil_ Gas__ Suspended __ Service _Water Injector .W~l~ 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call PeterNezaticky 659.7224 Signed Title Wells Supervisor Date 11/12/01 Peter Nezaticky ~/ ~ Prepared by Sharon A/Isup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N(W4-6)) WELL JOB SCOPE JOB NUMBEI~ " 2N ANN-COMM 1107011721.4 DATE DAILY WORK UNIT NUMBER 11/08/01 OOA CEMENT TOP JOB 2N-303, 317, 343, 349 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES APC-AREND NEZATICKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE K85329 35TN2N1 NG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI DALLY SUMMARY CEMENT TOP JOBS ON THE SURF X COND (OOA). 2N-303, 317, 343, 349.[WH MaintenanceI TIME LOG ENTRY 11:00 ON LOC. MIRU 12:00 PRE-JOB SAFETY MEETING. START MIXING CEMENT. 12:30 12:45 CEMENT MIXED, 6 BBL OF 15.7 PPG ARTIC SET. START PUMPING CEMENT DOWN 2N-303 SURF X CONDUCTOR ANNULUS (OOA) THROUGH 1" HOSE TAKING RETURNS TO VAC TRUCK, PUMPED 5 BBL. START MIXING 4 BBL OF CEMENT. 13:00 CEMENT MIXED MOVED TO 2N-343. PUMPED 2 BBL INTO A 6 F'I' VOID. 13:25 MOVED TO WELL 2N-349. PUMPED I BBL INTO A 7.5 FT VOID. 14:00 DUMPED 5 GAL OF CEMENT INTO 2N-317. SMALL 8 INCH VOID, BUT PREVIOUSLY REPORTED SOFT MATERIAL WHEN TAGGED. 14:30 RDMO RECEIVED NOV i Alaska Oil & Gas Coi~s. Commission Ancho~'age SUNDRY NOTICE 10-404 Phillips Kuparuk Well 2N-343 Annular Cement "Top-Job" November 08, 2001 Phillips Alaska, Inc., Kupamk well 2N-343 top of cement between the surface pipe conductor (9 5/8" x 16") was measured at 6 feet below grade. Arctic Set I cement (15.7 ppg) was pumped into the annular void (2 bbls) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor casing. The State Inspector was notified of the cement job and waived attendance, but will inspect the wellhead post cementing. The field Well Service Report is attached. RECEIVED NOV ]. ~ ?r!!:~ Alaska Oil & Gas Cons. Commission Anchorage 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 January 23, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission' 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report below with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not counted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. Annular Disposal during the fourth quarter of 2000: i h(1) h(2) h(3) 'Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547. 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 / q,~ ~v 70- / /t?-J/? 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 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. · AnnUlar Disposal during the~ourth quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100 0 12681 0 12681 Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000. Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD 1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files Well Compliance Report File on Left side of folder 198-092-0 KUPAR~K RIV U TARN 2N-343 50- 103-20260-00 ARCO MD 09631 '" TVD 05486 '~ letion Date: qf/~/98 Completed Status: lWlNJ Current: WAGIN T Name Interval Sent Received T/C/D D 8452 ~ SPERRY MPT/GR/EWR4/CNP/SLD OH 7/1/98 7/1/98 L DGR/CNP/SLD-MD L DGR/CNP/SLD-TVD L DGR/CNP/SL~-TVD L CMRT-PEX t,2~4AL 8890-9390 ..~AL 119-9632 _,~L 108-5486 ,~I~AL 108-5486 L DGR/EWR4-MD ~4~AL 119-9632 L DSI/GR/CAL b,fflNAL 2375-9586 L FMS /f,~AL 8800-9639 L MI INJP ~I~AL 8750-9220 OH 5 6/22/98 6/24/98 OH 7/8/98 7/8/98 OH 9/2/98 9/2/98 OH 7/8/98 7/8/98 OH 9/2/98 9/2/98 OH 7/8/98 7/8/98 OH 7/8/98 7/8/98 OH 6/22/98 6/24/98 OH 5 6/22/98 6/24/98 CH 2 2/10/99 2/18/99 L PEX-CN tA~INAL 8270-9448 OH 6/22/98 6/24/98 L PEX-CN/LDT ~'/~AL 8274-9462 OH 6/22/98 6/24/98 L PEX-MCFL ~F~AL 8270-9466 OH 6/22/98 6/24/98 L RSTWFL ~AL 3000-9335 9/23/99 CH 5 10/6/99 10/13/99 L RST-WTRFLOW~ '~4NAL 8850-9372 8/27/99 CH 5 9/17/99 9/22/99 L TEM-SPIN/TEM/ /~qAL PRES 3000-9370 9/9/99 CH 5 9/17/99 9/22/99 L USIT L~INAL BL(C) 8786-9407 CH 5 10/8/98 10/15/98 L USIT LJ//~ BL(C) 8786-9407 CH 5 1/4/99 1/4/99 R GYRO CONT.MULTI ff__.~5~RODATA TBNG 0-9410 CH 12/4/98 12/4/98 S RVY CALC. ,.~4I 108-9631. OH 11/20/98 11/24/98 T 8558 ~ SCHLUM PEX-DSI/FMS/CMR OH 6/22/98 6/24/98 Daily Well Ops. ~~ Are Dry Ditch Samples Required? yes ~ And Receive *d?-4za-~m~ Was the well cored? yes ~"- Analysis Description ~eh'~4-?~yes~a~ Sample S¢f3 ..... Comments: Monday, May 01, 2000 Page 1 of 1 10~6~99 - fi'fl, o"~ ~ Schlumberger NO. 12843 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 CD 2L-307 FBHP/TEMP SURVEY 990919 I 1 2N-321A lvt.~ ~L_ RST WATER FLOW LOG 990925 I 1 2N-325 ~.~ r.... RST WATER FLOW LOG 990924 I 1 2N-343 Ct. I c__ RST WATER FLOW LOG 990923 I 1 3G-26 .~)L{ ~ 99346 AIT/GPIT 990816 1 3G-26 99346 AIT/GR/CCL 990816 1 1 3G-26 99346 CONTINUOUS SURVEY W/GPIT 990816 I I 1999 0 Alaska 0tl & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, TJI~~ 9/17/99 Scilmberger NO. 12800 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 lC-26 99339 SCMT 990820 1 2A-02 ~&,t (_. INJECTION PROFILE 990822 I 1 2A-09 LEAK DETECTION LOG 990826 I 1 2A-10 PRODUCTION PROFILE 990830 I 1 2L-315 TEMPERATURE SURVEY 990910 I 1 2M-01 PRODUCTION PROFILE 990830 I 1 2N-325 [,~ t ¢.. RST WATER Fi'ow LOG 990829 I I ,, , 2N-325 -~.-" WARM BACK TEMP LOG 990908 I 1 2N-343 ~,~ ~:_ RST WATER FLOW LOG 990827 I 1 2N-343 ,v WARM BACK TEMP LOG 990909 I 1 2V-08A ~.~ ~._ INJECTION PROFILE 990821 1 1 3G-17 PRODUCTION PROFILE 990826 I 1 3M-02 L~i ~. INJECTION PROFILE 990825 I 1 3M-10 IA, t ~-- INJECTION PROFILE 990906 I I SIGNE DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) L. J- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the second quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the second quarter of 1999. Annular bgection dudng the second quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-15 34380 100 0 32195 16795 48990 2L-313 3779 100 0 3879 8654 12533 CDI-19 33933 100 0 34033 0 34033 1C-25 34216 100 0 34316 0 34316 CD1-40 12071 100 0 12171 0 12171 1C-23 9505 100 0 9605 0 9605 Total Volumes into Annuli for which Injection Authorization Expired during the quarter i Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume ~ Injected Status of Annulus ! 35573 Open, Freeze Protected 1D-10 35473 100 0 2N-323 32696 100 0 I 32796 Open, Freeze Protected I 2N-343 17895 100 0 i 17995 Open, Freeze Protected 2N-329 9 100 0 [ 109 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Ms. Wendy Mahan AOGCC Second Quarter 1999 Annular Injection Report Page Two CC: Mike Zanghi Paul Mazzolini Randy Thomas Kupamk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files Re: Tam Water Injection Subject: Re: Tarn Water Injection Date: Fri, 2 Jul 1999 16:20:37-0900 From: "Erickson&Versteeg" <N1177~mail.aai.arco.com> To: Blair Wonchell <Blair Wondzell@admin.state.ak.us> Thank you for the quick turnaround on the verbal approval. We'll be following up next week to address final approval issues. Hans Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 07/02/99 03:00:55 PM To: Erickson&Versteeg/AAI/ARCO cc: Subject: Re: Tarn Water Injection Hans, I hereby give you verbal approval to step-rate test these wells during the week of July 5 to July 11. This approval does not include the water injection progarm recently requested by letter. Blair Wondzell Erickson&Versteeg wrote: > > The wells which will be injected into initially are 2N-321A, 2N-325 and 2N-343. ~ ~'--~ans > > Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 07/02/99 02:28:30 PM > To: Eri ckson&Vers teeg/AAI/ARCO > cc: > Subject: Re: Tarn Water Injection > Hans, > I need the well names of those you plan to test. > Blair > Erickson&Versteeg wrote: > > > > Blair, > > > > Per our phone conversation, ARCO Alaska Inc is requesting verbal approval to > > initiate water injection at Tarn while review of an Application for Sundry > > Approval is in progress. > > > · Water injection capability at Tarn is expected as early as 7/5/99. ARCO · Alaska · · Inc proposes to initially conduct facility start-up activities and conduct · step > · rate tests on specific wells. After approximately 4 days of injection, the > · wells will be shut-in for surface pressure falloff tests. Ail injection will · be · · ceased at this time. Verbal approval is requested to conduct these initial · · activities. Injection will not be resumed until final approval is obtained > from > > The Commission. Data will be available to The Commission upon request. > > · > Please contact me if you have additional questions. · · 1 of 2 7/15/99 11:30 32 ' ::- 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 ~ 28' RKB, Pad 121' 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service X. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 137' FNL, 1084' FEL, Sec 3, T9N, R7E, UM 2N-343 At top of productive interval: 9. Permit number/approval number: 1468' FNL, 2583' FEL, Sec 4, T9N, R7E, UM 98-92/398-262 At effective depth: 10. APl number: 1474' FNL, 2343' FEU Sec 4, T9N, R7E, UM 50-103-20260-00 At total depth: 11. Field/Pool: 1488' FNL, 2243' FEL, Sec 4, T9N, R7E, UM Kuparuk River Field / Tarn Oil Pool 12. Present well condition summary Total Depth: measured 9631 feet Plugs (measured) None true vertical 5486 feet Effective Deptt measured 9487 feet Junk(measured) None true vertical 5383 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 108' 108' Surface 3311' 9-5/8" 386 Sx AS III LW & 3340' 2228' 350 Sx Class G w/60 Sx AS I top job Production 8831' 7" 435 Sx Class G 8858' 4937' Liner 753' 4" Included w/7" csg 9611' 5480' Perforation Depth measured 9116'-9126'; 9132'-9152'; 9184'-9224', 9252'-9262', 9270'-9290' true vertical 5116'-5122'; 5127'-5141 '; 5165'-5193', 5214'-5221 ', 5227'-5241' Tubing (size, grade, and measured depth) 4-1/2", 12.6 Ib/ft, L-80 @ 8859' Packers and SSSV (type and measured depth) Baker Casing Seal Assmbly @ 8859'; SSSV: None, nipple @ 560' 13. Stimulation or cement squeeze summary N/A ,~,.ia$'~ 0'~ :~ ~ ~ · IntervalsN/A treated ,measured) Treatment description including volumes used and final pressure Set mechanical bridge plug to repair suspected failed casing shoe cement, MIT well, fp = 500 psi, 14. Representitive Daily Average Production or Injection Data ©iI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 375 500 Subsequent to operation 0 6500 0 500 2865 15. Attachments MIT form 16. Status of well classification as: ~j Copies of Logs and Surveys run _ Daily Report of Well Operations ~X Oil _ Gas _ Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ Title: Production Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATF~ ARCO, Alaska, Inc. KUPARUK RIVER UNIT '-- SERVICE REPORT '~' K1(N-343(W4-6)) WELL JOB SCOPE . JOB NUMBER 2N-343 PERFORATE, PERF SUPPORT 0813981522.2 DATE DAILY WORK UNIT NUMBER 10/22/98 PRESSURE TEST BRIDGE PLUG DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 10 (~ Yes () NoI (~ Yes (~ No LIGENZA · ~ ESTI MATE K85111 180KN U2TN $330 $110,163 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final O~ 500 PSI 500 PSI 500 PS! 500 PSII 1400 PSI 400 PSI DALLY SUMMARY PRESSURE TEST BRIDGE PLUG. 2500 PSI FOR 30 MINUTES. 10 PSi DROP IN 30 MINUTES. [PT Tbg-Csg] ! TIME LOG ENTRY 09:00 MIRU HOT OIL PUMP TRUCK. TGSM ( DISCUSS JOB PLAN). RIG UP TO SWS LUBRICATOR PUMP IN SUB AND PRESSURE UP WELL BORE TO 2500 PSI. 10:15 PRESSURE UP TO 2,500 PSI. HOLD FOR 30 MINUTES.ACTUAL PRESSURE BLOCKED IN AT 2,440 PSI. 10:45 PRESSURE DROPPED FROM2,440 PSI TO 2,430 PSI. GOOD TEST. 10:50 BLEED WELL HEAD PRESSURE DOWN TO 500 PSI. _. 11:00 RDMO HOT OIL. ~ SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $40.00 APC $0.00 $10,600.00 ARCO $0.00 $2,300.00 DIESEL $0.00 $8.40 DOWELL $0.00 $8,800.00 GYRO DATA $0.00 $3,000.00 HALLIBURTON $0.00 $11,772.90 LITTLE RED $330.00 $8,315.00 RADIUS $0.00 $5,475.00 SCHLUMBERGER $19,986.00 $59,852.50 TOTAL FIELD ESTIMATE $20,316.00 $110,163.80 ARCO Alaska, Inc. KUPARUK RIVER UNIT SERVICE REPORT '~' K1(N-343(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-343 PERFORATE, PERF SUPPORT 0813981522.2 DATE DAILY WORK UNIT NUMBER 10/21/98 SET BRIDGE PLUG & PRESSURE TEST 8305 DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR 9 O Yes (~ NoI ~ Yes ~ No SWS-ELMORE LIGENZA ESTI MATE K85111 180KNU2TN $8,775 $89,847 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outei' Ann ' rFij~er Ann 0 PSI 500 PSI 375 PSI 520 PSII ~ '"'50PSI 50 PSI DAILY SUMMARY SET BRIDGE PLUG AT 9390. PRESSURE TEST TO 2500 PSI. GOOD TEST. TIME LOG ENTRY 14:00 MIRU SWS. TGSM (SIMULTANIOUS OPERATIONS, W/HES &-HOT OIL. RADIO SILENCE ON PAD. ALL PERSONNEL CONTACTED.) 15:45 PT LUBE / BOPS TO 3,000 PSI. RIH W/3.66 BRIDGE PLUG, BST-10, NT, RLLR, WT, CCL, SWVL, HD. TOTAL LENGTH = 26.4'. LENGTH FROM CCL TO PLUG = 22.4'. 16:50 TIE IN W/USIT LOG DATED 9/12/98. 17:10 DROP DOWN TO 9400'. LOG UP ' . '~_ ~ ' 17:20 LOCATE PLUG AT 3390'. CCL AT 3369: 21' FROM COL.TO TOP OF PLUG.. ~ . 17:30 SET OFF PLUG. GOOD INDICATION THAT PLUG SET. LOG UP TO VERIFY LOCATION.DROP DOWN AND TAG PLUG. POH. 18:30 SET ON SURFACE. PRESSURE UP TO 2500 PSI. HOLD FOR FIFTEEN MINUTES.~PRESSURE DROPPED APPROXIMATELY 10 PSI. 19:00 RDMO SWS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $40.00 APO $0.00 $10,600.00 ARCO $0.00 $2,300.00 DIESEL $0.00 $8.40 DOWELL $0.00 $8,800.00 GYRO DATA $0.00 $3,000.00 HALLIBURTON $2,443.90 $11,772.90 LITTLE RED $1,320.00 $7,985.00 RADIUS $0.00 $5,475.00 SCHLUMBERGER $5,011.50 $39,866.50 TOTAL FIELD ESTIMATE $8,775.40 $89,847.80 OPERATOR' 2N-343 COMMENTS: 2N-325 COMMENTS: COMMENTS: COMMENTS: COMMENTS: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ARCO Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / Misc. DATE: 12/7/98 4,930 5.5"/15.50#/L-80 8,859 1232.5 3, 100 810 3,200 30MIN 3, 100 3, 100 3, 100 1,800 1,750 1,750 Annulus bled 500 psi for test. 5,015 I 5.5"/15.50#/L-80 I 7,395 I 3'5 I 1253.751 2,200 3,200 [ 3,200 1,800 1,840 3,200 1,840 11ol II II II I I I I II TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 0.00 0.00 0.00 WELL TEST: Initial X 4 - Year Workover Other Distribution: orig - Well File c- Operator c- Database c - Trip Rpt File c- Inspector OPERATOR REP SIGNATURE: Eric Zuspen 2N 12-7-98.xls , AOGCC REP SIGNATURE: Lou Grimaldi (Rev 9/17/96) 2/5/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12314 Company Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool & Kuparuk Well Job # Log Description Date Blueline Sepia 2B-07 L~ ~-- MI INJECTION PROFILE 990127 1 1 2N-343~ MI INJECTION PROFILE 990128 1 1 3F-3~ MI INJECTION PROFILE 990126 1 1 SIG .. ...- Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: [ ::'~B 1 8 19~)'') ARCO Alaska, Inc. Post Office B ~,.~00360 Anchorage, Alaska 99510-0360 January 4, 1999 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Cement Bond Log for Tam 2N 343 Blair, as you requested, please find enclosed two copies of the Schlumberger USIT Log which was run in the Tarn 2N 343 well. Any questions, please call me at 265-6377. Staff Drilling Edgineer ARCO Alaska, Inc. is a Subsidiary of AtlanficRichfieldCompany ARCO Alaska, Inc. ~7 Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 18, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-343 (Permit No. 98-92) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tarn 2N-343. If there are any questions, please call 263-4603. Sincerely, RECEIVED P. Mazzolini Tarn Drilling Team Leader & Gas Cons. Commission Anchorage PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-92 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20260 4 Location of well at surface ;.~ .: ...... : 9 Unit or Lease Name AtTop Producing Interval. ~ . , ~.j.:,,;. .~- 10 Well Number 1468' FNL, 2583' FEL, Sec. 4, T9N, R7E, UM :' ~./i~;i~.h.:.. 2N-343 At Total Depth i ,~,~'_'i 11 Field and Pool 1527' FNL, 2250' FWL, Sec. 4, T9N, R7E, UM '" ' ..... 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 121' ADL 375074 ALK 4293 12 Date07. May.98Spudded 13 1Date4-May-98T'D' Reached 14 Date18-May-98C°mp', Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9631' MD & 5486' TVD 9487' MD & 5383' TVD YES M NO U NA feet MD 1050 APPROX 22 Type Electric or Other Logs Run FMS/DSI/GR/SP, Platform/Density/Neutron/CMR/GR, GR/CCL 23 CASING, LINER AND CEMENTING RECORD SE'I-FING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 108' 24" 9 cu.yds High Early 9.625" 40# L-80 SURF. 3340' 12.24" 386 sx ASIII LW, 350 sx Class G, 60 sx AS I 7" x 26# L-80 SURF. 8858' 8.5" 435 sx Class G 4.5" 12.6# L-80 8858' 9611' 8.5" (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9116'-9126' MD 5116'-5122' TVD 4.5" 8864' 8858' (CSR) 9132'-9152' MD 5127'-5141'TVD 9184'-9224' MD 5165'-5193' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 9252'-9262' MD 5214'-5221' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9270'-9290' MD 5227'-5241' TVD N/A 6 spt Uu LS NAL 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) njector Date of Test Hours Tested PRODUCTION FOIOIL-BBL GAS-MCF WATER-BBl. CHOKE SIZE I GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29, 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Reservoir (T3) 8982' 5019' Base Reservoir (T2) 9323' 5192' Annulus left open - freeze protected with diesel. Total pump volumes for this event: Category 1. 17895 Category 2. 100 Category 3, 0 Total: 17995 Total to Date: 17995 31. LIST OF AI~ACHMENTS 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 Title Drilling Team Leader i/, 3-4612 Prepared by Name/Number Sharon AIIsup-Drake/ 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: 8/27/98 ARCO ALASKA INC. WELL SI/MYLARY REPORT Page: 1 WELL:2N-343 WELL_ID: AK9381 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:05/07/98 START COMP: RIG:RIG # 141 WI: 0% SECURITY:0 API NUMBER: 50-103-20260-00 BLOCK: FINAL:05/19/98 05/06/98 (D1) TD: 108' (108) SUPV:RLM 05/07/98 (D2) TD: 1248' (1140) SUPV:RLM 05/08/98 (D3) TD: 3350' (2102) SUPV:RLM 05/09/98 (D4) TD: 3350'( SUPV:RLM 0) 05/10/98 (D5) TD: 3350'( SUPV:DB 0) 05/11/98 (D6) TD: 5425' (2075) SUPV:DB MW: 10.0 VISC: ACCEPTED RIG 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig from 2N-329 to 2N-343. Rig up, nippling up diverter. ~ MW: 10.2 VISC: 92 PV/YP ' 21/39 APIWL: 8.8 DRILLING SURFACE HOLE Continue to rig up. Function test diverter. Rig accepted at 0300 hrs. Directional drill from 108' to 1248' MW: 10.5 VISC: 68 PV/YP: 25/37 WIPER TRIP FROM CASING POINT APIWL: 4.6 Directional drill from 1248' to 2267'. Gas encountered ~ 1340' Drill from 2267' to 2298' Cut mud weight to 9.6 ppg. Drill from 2298' to 3350'. Max gas encountered @ 2370' MW: 10.6 VISC: 48 PV/YP: 16/18 ND DIVERTER APIWL: 4.2 Pump lo/hi vis sweeps and circulated hole clean. Wiped hole to 1168'. CBU to check gas. Run 9-5/8" casing. Pump 1st stage cement job. MW: 8.9 VISC: 44 PV/YP: 10/14 PERFORM LOT @ 3370' APIWL: 8.0 Pump 2nd stage cement job. ND diverter system. NU BOPE and test to 300/3500 psi. Clean out cement to stage collar @ 1488' Drill out stage collar. MW: 9.2 VISC: 49 PV/YP: 13/21 Drilling 8.5" hole from 5725' APIWL: 6.2 Wash through cement contaminated mud to 3060' Clean out cement from 3060' to 3200', test casing to 2000 psi. Clean out cement and float equipment to 3350', drilled 20' of new hole to 3370'. Perform FIT test. Drilled 8.5" hole from 3370' to 5425' Date: 8~27~98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/12/98 (D7) TD: 7685' (2260) SUPV:DB 05/13/98 (D8) TD: 9171' (1486) SUPV:DB 05/14/98 (D9) TD: 9631' (460) SUPV:DB 05/15/98 (D10) TD: 9631'( 0) SUPV:DB 05/16/98 (Dll) TD: 9631'( 0) SUPV:RWS 05/17/98 (D12) TD: 9631' ( 0) SUPV:RWS 05/18/98 (D13) TD: 9631'( 0) SUPV:RWS 05/19/98 (D14) TD: 9631'( 0) SUPV:RWS MW: 9.3 VISC: 48 PV/YP: 15/22 Drilling 8.5" hole from 7830' APIWL: 6.0 Drill from 5425' to 5456' Pumped lo/hi vis sweeps around and circ clean. Drill from 5456' to 7685' MW: 10.0 VISC: 47 PV/YP: 17/14 Drilled to TD @ 9631' APIWL: 4.6 Drill 8.5" hole from 7685' to 7746'. Perform LT, EMW = 14.5 ppg. Drill from 7746' to 9171' MW: 10.1 VISC: 49 PV/YP: 18/22 Logging up from 8600' APIWL: 3.8 Drill 8.5" hole from 9171' to 9631' TD. Logging MW: 10.2 VISC: 55 PV/YP: 19/23 APIWL: 3.4 Log FMS/DSI/GR/SP from 9631' to 3340', first attempt stopped @ 3800'. Attempted to run Platform/Density/Neutron/CMR/GR logs, unable to pass 3450' MW: 10.1 VISC: 55 PV/YP: 17/22 POH, L/D DP APIWL: 3.6 Log from 8255' to 9452'. LD logging tools. MW: 8.5 VISC: 0 PV/YP: 0/ 0 PREPARING TO P/U COMPLETION APIWL: 0.0 Repair hydraulic hose on iron roughneck. PJSM. Test lines, cement w/90 bbl cmt. Displace w/sea H20. Bump plugs w/.6 bbl over calc displacement. O. MW: 8.5 VISC: moving rig to 2N-339 0 PV/YP: 0/ 0 APIWL: 0.0 Install 9.5/8"x 7" packoff and test to 5000 psi. Run 4.5" completion. Freeze protect annulus. N/U tree. MW: 0.0 VISC: 0 PV/YP: 0/ 0 rig released @ 0200 hrs. 5/20/98 APIWL: 0.0 Release rig @ 0200 hrs. 5/20/98 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(2N-343(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-343 PERFORATE, PERF SUPPORT 0813981522.2 DATE DAILY WORK UNIT NUMBER 10/22/98 PERFORATE 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 10 NOI YES SWS-ELMORE LIGENZA FIELD AFC# CC# Signed ESTIMATE K85111 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSI 220 PSI 500 PSI 220 PSII 400 PSII 400 PSI DAILY SUMMARY PERFORATE ZONES FROM 9270'. TO 9290'. 9252' TO 9262'. 9202' TO 9224'.[Perf] TIME LOG ENTRY 09:00 MIRU SWS. TGSM ( DISCUSS JOB PLAN. LATE HOURS LAST NIGHT. SLIPPERY SURFACES). PT LUBE/BOPS TO 2500 PSI. 10:00 RIH W/ROLLER, 20' X 3 3/8" HC/DP 6 SPF SAFE GUN, CCL, HEAD. TOTAL LENGTH = 28' 3". CCL TO TOP SHOT = 4'. 10:15 STOP AT 200' WHILE PRESSURE TESTING BRIDGE PLUG. 11:00 RESUME RIH. 12:00 CONSULT W/DS ENGINEER ABOUT DISCREPANCY BETWEEN USIT LOG AND MWD GR LOG. 12:45 TIE IN W/USIT LOG DATED 9/12/98. 12:55 LOCATE AT 9266'. TOP SHOT IS 4' BELOW CCL. PLACING SHOTS FROM 9270' TO 9290'. INDICATION SHOTS FIRED. POH. 13:45 ON SURFACE, ALL SHOTS FIRED. 14:00 RIH W/10' GUN & SAME TOOL STRING. 15:00 TIE IN AND LOCATE AT 9248' PLACING TOP SHOT AT 9252'. INDICATION SHOTS FIRED. LOG UP TO 9000'. POH. 15:50 ON SURFAC. ALL SHOTS FIRED. 16:00 RIH W / 20' GUN & SAME TOOL STRING. 17:10 TIE IN AND LOCATE AT 9200' PLACING TOP SHOT AT 9204'. INDICATION SHOTS FIRED. LOG UP TO 9000'. POH. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ~, K1(2N-343(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-343 PERFORATE, PERF SUPPORT 1020981808.3 DATE DAILY WORK UNIT NUMBER 10/23/98 PERFORATE '8305 DAy OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES SWS-ELMORE LIGENZA FIELD AFC# CC# Signed ESTIMATE KAWWRK 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 320 PSI 330 PSI 320 PSI 330 PSI 400 PSI 400 PSI DAILY SUMMARY PERFORATED ZONES FROM 9202' TO 9184'. 9152' TO 9132'. AND 9126' TO 9116. I TIME LOG ENTRY 09:00 11:00 MIRU SWS. TGSM ( DETERIORATING WEATHER CONDITIONS EXPECTED TODAY. COLD WEATHER PREPARATIONS). PT LUBE / BOPS TO 2,500 PSI. RIH W/RLLR, 20' X 3 3/8" HC / DP GUN, 6 SSPF, CCL, HEAD. CCL 4' FROM TOP SHOT. TOTAL LENGTH = 28' 3". LOCATE AT 8800' LOG AND TIE INTO USlT LOG DATED 9/12/98. 12:15 LOCATE AT 9180' TO PLACE TOP SHOT AT 9184. INDICATION SHOTS FIRED. LOG UP TO 8800'. POH. 13:05 ON SURFACE. ALL SHOTS FIRED. 13:20 RIH W / SAME TOOL STRING, 20' GUN. 14:15 LOCATE AT 9128' TO PLACE TOP SHOT AT 9132'. INDICATION SHOTS FIRED. LOG UP. POH. 15:05 ON SURFACE, ALL SHOTS FIRED. 15:15 RIH W/SAME TOOL STRING. 10' GUN. 16:25 LOCATE AT 9112' TO PLACE TOP SHOT AT 9116'. INDICATION SHOTS FIRED. LOG UP. POH. 17:30 ON SURFACE. ALL SHOTS FIRED. 18:00 RDMO SWS. ARCO Alaska, Inc Date: Subject: From/Location: Telephone: To/Location: Internal Correspondence September 13, 1998 File Code: 2N-343: Set Bridge Plug & Pressure Test H. T. Erickson NSK-14 x7687, pgr 921 Central Wells Group NSK 69 (3 copies) Well 2N-343 WELL: PROPERTY CODE/ACTIVITY CODE: BUDGET CATEGORY JOB SCOPE PRIMARY OBJECTIVE: ESTIMATED COST: 2N-343/Injector 180KN U2TN/K85111 Perforate/Stimulate Perf/Perf Support Set Bridge Plug $25,000 E-Line X Set bridge plug -X- Pressure test tubing and casing to 2500 psi (sliding sleeve is open) COMMENTS: A bridge plug is recommended to be set in 2N-343. It is suspected that the casing shoe is leaking. The tubing was initially successfully pressure tested on 8/'17/98, however, contaminated cement was found across the perforation interval. The well was cleaned out to PBTD on 8/21/98 and several hard streaks were encountered. Subsequently, the tubing would not pressure test. It is likely that the CTU work drilled up cement that was providing the initial isolation. The bridge plug setting will satisfy AOGCC pressure integrity criteria. A dummy bridge plug drift was performed on 8/31/98 to 9402' WLM (approx 9417' RKB). It is recommended to set the bridge plug as deep as possible and ensure that the sealing element is not set across a collar. The lowest possible perf is 9330' RKB. Petroleum Engineer cc: P. Archey/W. Dobson CPF-2 DS Lead Tech NSK-14 NSK-14 ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A V 1.0 9/15/94 ARCO Alaska, Inc. KRU 2N-343 NIP (560-561, OD:4.500) TUBING (0-8859, 0D:4.500, ID:3.958) PRODUCTION (0-8859, OD:7.000, Wt:26.00) SURFACE OD:9.625, Wi:40.00) SLEEVE (8764-8765, OD:4.500) Gas Lift andrel/Dummy Valve 1 (8805-8806, OD:5.800) NIP (8849-8850, OD:4.500) SEAL (8859-8860, 0D:6.750) PRODUCTION (8859-9612, OD:4.500, Wt:12.60) 1[ AP1:1501032026000 Well Type: PROD PBTD:I9631 ftKB SSSV Type: NONE Origl I TD:19631 ftKB Completion:l ~ I Annular Fluid: DSL/SW7.1/8.5ppg LastW/O:I . UaxHolej65deg @ 4009 J I I .: I Angle:I LastTag: 9414 I a : 8/26/98 I Angle @ TS:ldeg @ Rev Reason: 3 a : 9/10/98 i Angle @ TD:I44 de,q @ 9631 Size ToP 16.ooo o 9.625 0 7.000 0 4.500 8859 Bottom TVD 108 108 3340 2325 8859 4930 9612 5473 Size Top I Bottom I TVD 4.500 0 8859 4930 G~::EiffMa ndr~l~/V~lve~!i%;~~ ~:?i..: -'?!:~:S::.:~ :.i :.-.i:i;.'.'.:-.:~-~:';' ....... Thread WELDED BTC BTC-MOD NSTC Thread NSCT Type NIP Date Run KBG DMY 5/17/98 Description CAMCO 'DB' NIPPLE BAKER CMU W/CAMCO 'DB' PROFILE. 9/8/98 - SLEEVE SHIFTED OPEN. I CAMCO NOGO 'DB' NIPPLE IBAKER CASING SEAL ASSY 80-47 SLEEVE NIP SEAL SHOE Date ..... i Note Drift tubing w/3,67' OD to 9402'. 9/8/98 Well SITP 2N-343 KRU WELL INFORMATION 0 psi WELL HISTORY HANDOVER FORM To Production To Drilling Number AK9381 DOWNHOLE INFORMATION Drillers TD 9631 7" CSG PRES. 0 psi PBTD/Top of fi!! or Ju,-,k: 9487' Date Tagged 5/17/98 9-5/8" or 10-3/4" Csg Pres 0 psi BPV Installed: x Yes No BHP psi/depth Date Instrument Packer fluid DSL/SEAH20 Weight 7.1/8.5 ppg Tubing fluid DSUSEAH20 Weight 7.1/8.5 ppg DIRECTIONAL INFORMATION RKB 28' KOP 350 Avg Hole Angle 62 Max angle of 65 @ 3707'16327' Hole Angle @ TD 44 deg Downhole Plugs: Yes X No sssv Status No SSSV-'DB' Landin.q Nipple Cond. Surf. Prod. Tubing: Tubing: Size 16" 9 -5/8" 7X4-112" 26/12.6~ 4-1/2" 12.6# CASING/TUBING DATA Wt. Grade Conn. Depth WELDED 108' 40~ L-80 BTC 3340' L-80 BTC MOD/NSTC 885119612 L-80 NSCT 8864 Well Head FMC PBU GEN V, 5M (Type/Pres. Rating) Tree Cap Conn Tbg Hgr Corm 4-1/2" NSTC Type Guns NEW, ADD OR RE-PERFED INTERVALS SPF From To Rig released subseqUent to full well completion as required on State Drilling permit: ~Yes XX No If no, specify remaining operations: Perforating & Frac COMPLETION INFORMATION Mfgr/Type/Size/dummy or Orifice/Latch NIPPLE 3.875" CAMCO DB nipple SLIDING SLEEVE Baker CMU Size 3.81" w/3.812" cam DB profile OLM 4-1/2"X1" KGB-2-LS W/DK-1 Bottom Latch DV, NIPPLE 3.75" NOGO, CAMCO DB nipple CSA Baker 7" Casing Seal Assy size 80-47 4.75" OD X 3.875" ID FLOAT CLR 4-1/2" FLT CLR (PBTD) Tops (MD) 560' 8764' 8805' 8849' 8859' 9487' ENVIRONMENTAL SITE INSPECTION Location clean/cellar clean. Minor hydrate gas bubbling in 16" x 9.625" annulas when well is warm. * GENERAL INFORMATION FREEZE PROTECTED TBG, TBG ANNULUS & 7"X 9-5/8" ANNULUS TO 1900' M.D. (-1645' T.V.D.) W/DIESEL SINGLE MASTER VALVE ON TOP OF TBG SPOOL COMPLETE TREE TO BE INSTALLED WHEN AVAILABI Attached tubing detail Ddlling Dept. Rep. Production/Oper Dept. Rep. D.BURLEY Title Drilling Supervisor Date Title 'D ,~-, ~,~ Date · 7/6/98 4-1/2" Production TUbing WELL: TARN 2N-343 ARCO Alaska, Inc. DATE: 5/17/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES -'~ ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RKB to Tubing Hanger LDS = 25.80' 25.80 .7 FMC Gen V 5m, 4.5" Hanger w/4.5" pup, NSCT & CIW "H" BPVG 2.53 25.87 Space out pups. 4.5", 12.6#, L-80 (Pups required on Space Out ) 9.56 28.40 jts276-292 4.5", 12.6#, L-80, NSCT tubing 516.54 37.96 XO 4.5" NSCT box X 4.5" EUE 8rd pin 5.44 554.50 Nipple 4.5" Camco "DB" for SCSSSV, 5.570 OD, 3.875 ID. 4.5" EUE 8RD PxB 1.35 559.94 XO 4.5" EUE 8rd box X 4.5" NSCT pin 1.91 561.29 Jts. 3-275 4.5", 12.6#, L-80, NSCT tubing 8200.75 563.20 Sleeve Baker CMU Sliding Sleeve, 5.625"OD, 3.81", w/Camco 3.812", "DB" profile 4.67 8763.95 Jt. 2 4.5", 12.6#, L-80, NSCT tubing 30.55 8768.62 XO .4.5" NSCT box X 4.5" BTC pin 6.09 8799.17 GLM Camco 4.5"X 1", KBG-2-LS,w/DV, BTC box X pin, 5.985 OD 7.53 8805.26 XO 4.5" BTC box X 4.5" NSCT pin 6.07 8812.79 Jt. 1 4.5", 12.6#, L-80, NSCT tubing 29.93 8818.86 Nipple Camco "DB" nipple, 5" OD X 3.75" ID NOGO 1.51 8848.79 Pup joint, 4.5", 12.6#, L-80, NSCT 7.75 8850.30 Baker 4.875" Locator sub 1.05 8858.05 Baker 7", 80-47 Casing Seal Assembly, 4.750" OD X 3.875" ID. 16.63 8859.10 TUBING TAIL AT >>>>> 8864.10 Note: Tubing spaced out with Iocator sub 1' above CSR. Remarks: String Weights with Blocks: 100K# Up,551~ Dn,10k~ Blocks. Ran 292 its of 4-t/2" tubing Drifted casing with plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Ddlling Supervisor:R. W. SPRINGER Casing Detail 7"X 4-1/2" Production Casing WELL: TARN 2N-343 ARCO Alaska, Inc. DATE: 5116198 Subsidiary of Atlantic Richfield Company 1 OF I PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 27.05' TOPS 7", LANDING JT. 34.0' OVERALL LENGTH 27.05 7" FMC fluted mandrel hanger w/7", 29# pup joint 2.20 27.05 Jts. 1-214 7", 26~, L-80, BTC-MOD (214 joints) 8821.48 29.25 PUP 7", 26~, L-80, BTC-MOD 8.37 8850.73 Baker Csg Seal Receptacle (CSR), SIZE 80-47,4.75" ID, w/XO to 4.5" 20.93 8859.10 PUP ' 4-1/2" 12.6~ L-80 NSCT CSG 6.30 8880.03 jts.21-24 4-1/2" 12.6~ L-80 NSCT CSG (4 Joints) 117.83 8886.33 MARKER 4-1/2" 12.6/f L-80 NSCT CSG (PUP JOINT) 3.74 9004.16 Jts. 5-20 4-1/2" 12.6~ L-80 NSCT CSG (16 Joia, ts) 479.36 9007.90 Weatherford Gemoco Float Collar 1.36 9487.26 Jts. 1-4 4-1/2" 12.6~ L-80 NSCT CSG (4 joints) 121.58 9488.62 Weatherford Gemoco Float Shoe 1.80 9610.20 9612.00 ,, 24 - 4.5" X 8 118" ROTCO Centralizers Run ROTCO solid spiral bladed centralizers on 4.5" jts. 1 - 24. ,., 10 - 7" x 8 1/2" Gemoco Bow Spring centralizers Run Gemoco 7" x 8 t/2" Bow Spring centralizers on Jts 1- 10 22 - 7" X 8 3/8" solid straight bladed centering guides Run on joints 209, 204,199, 196, 193,190, 187, 184, 181,178, 175, 172, 169, 166, 163, 160, 157, 154, 151,148, 145, 142 NOTE: 4.5"JOINTS #25-30 STAY IN PIPE SHED (6 JOINTS) NOTE: 7" JOINT #215-225 STAY IN SHED Remarks: String Weights with Blocks: 235K # Up, 75K~ Dn, 20K~ Blocks. Ran 214 Joints 7" and 24 Joints 4.5" casing. ~~ic rabbit. Used Arctic Grade APl Modified No Lead compound on thread all Drifted 7" & 4.5" cas!rl~ connections. Casir~'~~ate'd. QO ' ,~4-~~:?'''~' Drilling Superuisor:-R: Vt/. SPRINGER ~..~ ~'.' , ',~..~. -' ,-,,-.. I Dow'ell Cementing Service Report ~ Customer I ARCO ALASKA INC ....... J 20058219. Well ¢c~mty R.~ Name 2N 343 TARN US Location (legal] ; Porrnatlon Name/Type I AK I I r.'.'.'.'.'.'.'.':~.:!.Led For I W~l C~ i '~New j DeveJopme~ j Max. ~ J ' 10.1 Ib/gal~ 0 Bemonite Cementing J Cern Prod Casing Max. Allowed Tubing PresmureJ~ Max. Allowed Ann. Pressure j WellHead Connectio~ Service Inmtruction~ Arch Field Est. $ 44, 856.86 0212-8873 ca,~rru~e s~ed ~ Hole Volum~ CircuLated ~ to Cemenfirm . ,., Lilt Pre, sm1: psi Pipe Reciprocated No. Centralizers: Cemerd Head Typ~. 34 i Top P~Ug,: 1 ! Bottom Plugs: 1 Double Job Scheduled For: 5/17198 15:00 , Time J Fluid Type J24hr I Z1:45 j21:49 ; 21:51 ~ 21:52 ! 21:57 i 22:07 !22:!8 ,[ Fluid Density ! 0 I 8.32 Nzo I 0 I H2o I 8.32 Pre Flush I 8.32 Sp~r ', 11.5 Arrived on Location: 5/17~98 15:00 ! 0 Cement J !5.8 22:40I H20 22:48 J Brine l 23:13 i Brine 23:15 j Bhne - 23:20 j Bnne 23:29I Brine 23:35 j 8.32 8.5 8.5 8.5 8.5 Rates CO2tN2 Fluid bpm ! 0 0 0 ' 4 0 0 0 0 0 8 0 8 0 8 0 8 8.5 0 3 0 0 Leave Location: 5/18~98 1:00 Volumes Incr. I Cum. ! bbl ! bb~ i O 0 10 ' 0 0 0 U 20 10 40 ~n 0 70 90 70 O 160 3,48.8 160 0 361 0 381 0 421 0 0 O 0 iJ DoweH Location j Job Start J Prudhoe Bay, AK 5/17/98 DeviaUon 0 0 psi Bit ~lze Well MD Well T'V"D 0in i 9,611 ff 0 ff Pore rr~r.~ Grader 0 Depth, it. s[z~m J Weight,~ ,J Orade 8858 J 7 I 26. i Ne0 o ! o I o ! i Per[m"atio~Open Hole 0 ; 0 ~ 0 I 0 0 ff 0 bbl Casing 348.7 bbl · Tc~.~.",g VM. · ~ V~!, A,,-mutar Vol. 0 bbJj 350.7 bblJ 0 bbJ Casing Tools I Shoe Type: Float Squeeze Type Sh~ Dq~: 9611 ff Stage Tool Type: J Tool Depth: 0 ft Sta~e Tool Def:~: 0 ft J Tail Pipe Size: 0 h'l co;'-r Type: Float j Tau I~pe oepth: 0 ff 9486ff i S~To~Va: Obbl Squeeze Job Tool Type: Message psi J p~i 0 ~ 0 I 30O ; O t 0 j 0 jPressure test 3500 4--, 300 j 0 :mesume pumping 0 ISwitch to Pre Rush - 14% flow O ]Swftc~ to spacer - 1 530 1 580 I 750 Icheck floats - holding I_ ;~t~rt Job ' 0 500 700 700 900 800 0 0 JShutdovm-drop plug 0 !S .wff.'.ch to cement- 13% flow 0 jShutdown-wash lines 0 !Rig to displace-69% flow 0 iPre Rush @ shoe -63% flow , 0 iSpacer (~ shoe - 60% flow 0 iCement ~ shoe - 58% flow 0 iSlow rate -16% flow 0 jShutdown-didnot bump Page 1 of 2 i Cu~w TARN Service Date / ARCO ALASKA INC l"~': 20058219,.-~ .... Volumes I Pressures '""' I "~"' I c'""' ! Post Job Summary Average Pump Rates, bpm i/i Slurry N2 Mud Treating Pressure Summary, psi Maximum Fifia! Average _~ P!.ug to_ -¢q'. eakch3~m Maximum Rate 8 i ~oo i ~ooo I o i o Av~. N2 Pe~ceflt I D~ski_ned Slurry Volume Displacemem Cu~lomer or Autt~odzed Rel~ese~tafive Ray Spdnger 0 bbl 348.8 bbl Dowell Supervisor Total Slurry 90 Volume of Fluid Injected, bbl Mud Spacer N2 Breakdown Fluid V~u.me Oens.'.m/ , Cement Circulated to Surface? Veaume 0 bbl I Washed Thru Perfs To 0 ft J Gray Page 2 of 2 Tarn Development, 2N-343 Sa, race Cementing Loads, 45% Excess Below Frost, 400% Above 9-5/8" Surface Casing, 12-1/4" OH, Run to 3286 ' MD, 2 Stage, Tool at 1450' MD Tool 200' (TVD) below Frost. Stage Tool is In the West Sak. Stage'l: Est. Circ. W/5 bbl FW. 'Pump~ bbls 10.5 ppg ARCO Spacer, Cement from MD of 3322' to stage tool at 1500' (1822') with Class G + Adds (~ 15.8 ppg, 1.15 ft3/sk. And Arctic Set 3 Lite, 10.5 ppg, 4.42 ft3/sk ' Lead Slurry: (1822'-800') x 0.3132 ft3/ft x 1.45 (45% exce~s) = 464. i ft3 ~ ~l~'cJ ~r 464.1 ft3/4.42 ft3/sk = I10 sacks (rounded up from 105) ctic Set 3 Lite (~ 10.5 ppg, Class G with 50% D124, 3.5% D44, 0.4% D46, 30% D53, i.5% q ,'7,~11~/,' S/.,f, jl']~ i and 1.5% D79, 4.42 ft3/sk Tail Slurry: 800' x 0.3132 ft3/ft x 1.45 (45% Excess) = 363.3 ft3 57 ',5',1 ~- I"] ~,,~"~ 80' shoe x 0.4257 ft3/ft = 34.1 ft3 397.4 ft3/l. 15 ft3/sk = 350 sacks cement (rounded q..). ,~ l~l~/.,'" up from 346) ~O , System; Class G with 1% S i, 0.2% D46 and 0..~ Vo D65, I 15 ft3/sk. ! 5.8 ppg S. tage 2: Est. Circ. W/5 bbl FW. Pump 30 bbls 10.5 ppg ARCO Spacer, Cement from 1500' (Tool) to Frost at 1254' (246'), and from Tool to surf, with AS 3 Lite and 60 sacks ASI. 400% Excess above 1254', 45% Excess below 1254' 246' x 0.31~2 ~3/~ x 1.45 (45% Excess) = I 1 !.7 ft3 _,~ ,~ ~ 1254' x0.3132 a3/ft x 5 (400% Excess) 1963.7 ft3 2075.4 Total Volume Tail Slur~ 60 sacks Arctic Set I, 0.93 ft3/sk = 55.8 ft3 2075.4-55.8 fl3 = 2019.6 ft3, 2019.6 ft3/4.42 ft3/sk = 457 sacks. Round up to 465 Sacks Lead Arctic Set 3 Lite ~, 10.5 ppg, Class G with 50% DI24, 3.5% D44, 0.4% D46, 30% D53, i.5% SI and !.5% D79, 4.42 ft3/sk Summary: Stage !: 5 BBL water, 30 bbis 10.5 ppg spacer, ! 10 sacks Arctic Set Lite, 350 sacks G Stage 2: 5bblwater, 30bbis 10.5 ppg spacer, 465 sacks lead, 60 sacks Arctic Set I IBKD 5/4/98 1500 hrs 7o 79- " SURVEY CALCULATION AND FIELD WORKSHEET J ~~' I Job .o. O450-97559 Sidetrack .o. ~ Page I of.,, 5 _ I I Company ARCO ALASKA, INC. Rig Contractor & 'No. DOYON - 141 Field TARN DEVELOPEMENT FIELD Well Name & No. TARN DRILLSITE 2N/TARN 2N-343 Survey Section Name SPERRY SUN BHI Rep. '~ ~ ~ ~'~'~: WELL DATA - -- Target 'I'VD (FT) Target Coord. N/S Slot Coord. N/S -136.47 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -1084.30 Magn. Declination 27.100 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m0 10mO Vert. Sec. Azim. 259.24 Magn. to Map Corr. 27.100 Map North to: OTHER _ SURVEY DATA ; .... Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'I') (IT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) ..... MWD 108.00 0.00 0.00 108.00 0.00 0.00 0.00 TIE IN POINT .-- ..... 07-MAY-98 MWD 161.30 0.27 77.84 53.30 161.30 -0.13 0.03 0.12 0.51 0.51 9 1/2" MlC SET @ 1.5 07- MAY-98 MWD 252.40 0.36 64.64 91.10 252.40 -0.62 0.19 0.59 0.13 0.10 -- ._ 07-MAY-98 MWD 349.98 0.32 148.93 97.58 349.98 -1.01 0.09 1.01 0.47 -0.04 77' SLIDE 210 AZ TF 07-MAY-98 MWD 436.40 4.16 220.20 86.42 436.32 1.34 -2.51 -0.89 4.71 4.44 77' SLIDE 210 AZ TF. ..... '07-MAY-98 MWD 528.28 7.82 210.00 91.88 527.68 8.02 -10.47 -6.17 4.13 3.98 -11.10 77" IOLTF. ___ 07-MAY-98 MWD 619.25 12.10 210.94 90.97 617.26 18.40 -24.02 -14,17 4.71 4.70 1.03 83' ' IORTF '-'1 07-MAY-98 MWD 710.10 17.20 218.10 90.85 705.14 34.87 -42.77 -27.36 5.95 5.61 7.88 77" IORTF 07-MAY-98 MWD 801.51 22.77 223.49 91.41 791.02 59.42 -66,26 -47.89 6.41 6.09 5.90 62' ' 20R TF -- 07-MAY-98 MWD 892.07 24.35 227,64 90.56 874.03 89.55 -91.55 -73.75 2.53 1.74 4.58 42' 20R TF -- -- 07-MAY-98 MWD 984.10 26.21 234.01 92.03 957.26 124.10 -116.29 -104.23 3.58 2.02 6.92 77' ' 40R TF -. 07-MAY-98 MWD 1073.17 30.18 240.79 89.07 1035.76 163.16 -138.79 -139.71 5,72 4.46 7.61 61' ' 45R TF 07-MAY-98 MWD 1164.37 32.50 246.68 91,20 1113.67 208.84 -159.68 -182.23 4.21 2.54 6.46 62' ' 40R TF _.. : 07.MAY.98 MWD 1259.65 34.82 250.63 95.28 1192.98 260.73 -178.84 -231.41 3.35 2.43 4.15 31' , 45R TF ,?' 08-MAY-98 MWD 1354.49 37.03 254.27 94.84 1269.79 315.97 -195.57 -284.46 3.24 2.33 3.84 61' ' 45R TF. 08-MAY-98 MWD 1447.33 38.70 256.33 92.84 1343.08 372.81 -210.01 -339.57 2.26 1.80 2.22 31' "30R TF 08-MAY-98 MWD 1540.23 43.33 256.23 92.90 1413.16 433.68 -224.46 -398.78 4.98 4.98 -0.11 62' ' 0 TF 08-MAY-98 MWD 1632.10 45.30 256.25 91.87 1478.89 497.77 -239.73 -461.12 2.14 2.14 0.02 31" 0 TF 08-MAY-98 MWD 1725.25 50.30 256.68 93.15 1541.44 566.67 -255.86 -528.19 5.38 5.37 0.46 62' · 0 TF 08-MAY-98 MWD 1817.34 54.66 258.45 92.09 1597.51 639.68 -271.55 -599.50 4.97 4.73 1.92 45' ' 10R TF 08-MAY-98 MWD 1909.59 59.16 258.47 92.25 1647.87 716.92 -287.01 -675.21 4.88 4.88 0.02 45' ' 0 TF 08-MAY-98 MWD 2002.09 60.57 260.45 92.50 1694.31 796.91 -301.63 -753.85 2.40 1.52 2.14 15' 0 TF 08-MAY-98 MWD 2096.83 60.78 260.67 ' 94.74 1740.71 879.49 -315.18 -835.33 0.30 0.22 0.23 08-MAY-98 MWD 2188.63 60.80 259.63 91.80 1785.51 " 959.60 -328.89 -914.27 0.99 0.02 -1.13 SURVEY CALCULATIONAND FIELDWORKSHEETJob No. 0450-97559 Sidetrack .o. Page 2 of 5~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPEMENT FIELD Well Name & No. TARN DRILLSITE 2N/TARN 2N-343 Survey Section Name SPERRY SUN BHI Rep. WELL DATA ' Target 'I'VD (~-r) Target Coord. N/S Slot Coord. N/S -136.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -1084.30 Magn. Declination 27.100 Calculati<Sn Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m[-] 10m[~ Vert. Sec. Azim. 259.24 Magn. to Map Corr. 27.100 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL ' Build (+) Right (+) Comment Type (~-r) (DD) (DD) (F-T) (F'F) (F'I-) (IT) (Per ~00 FT) Drop (-) Left (-) 08-MAY-98 MWD 2283.00 61.08 261.25 94.37 1831.35 1042.07 -342.59 -995.61 1.53 0.30 1.72 --, 08-MAY-98 MWD 2375.90 61.18 262.46 92.90 1876.20 1123.34 -354.11 -1076.15 1.15 0.11 1.30 Ii"' 08-MAY-98 MWD 2471.01 61.40 263.66 95.11 1921.89 1206.57 -364.19 -1158.95 1.13 0.23 1.26 ,__ --_ 08- MAY-98 MWD 2562,23 61.72 263.48 91.22 1965.33 1286.55 -373.17 -1238.66 0.39 0.35 -0.20 08-MAY-98 MWD 2655.07 61.95 260.60 92.84 2009.16 1368.28 -384.51 -1319.70 2.75 0.25 -3.10 31' SLIDE 9OL TF. ---- __ _.. 08- MAY-98 MWD 2744.15 61.87 260.59 89.08 2051.11 1446.85 -397.35 -1397.23 0.09 -0.09 -0.01 08-MAY-98 MWD 2841.99 61.27 260.83 97.84 2097.69 1532.86 -411.24 -1482.14 0.65 -0.61 0.25 08-MAY-98 MWD 2934.48 62.97 261.15 92.49 2140.94 1614.57 -424.04 -1562.89 1.86 1.84 0.35 20' SLIDE 30L TF 08- MAY-98 MWD 3026.86 63.26 261.39 92.38 2182.71 1696.92 -436.55 -1644.33 0.39 0.31 0.26 08- MAY-98 MWD 3118.04 62.59 261.17 91.18 2224.21 1778.05 -448.85 -1724.58 0.77 -0.73 -0.24 08-MAY-98 MWD 3212.16 63.04 261.51 94.12 :::>267.21 1861.72 -461.46 -1807.34 0.58 0.48 0.36 08- MAY-98 MWD 3300.87 63.17 262.42 88.71 2307.34 1940.74 -472.52 -1885.68 0.93 0.15 1.03 11 -MAY-98 MWD 3356.30 63.70 260.41 55.43 2332.13 1990.28 -479.92 -1934.70 3.38 0.96 -3.63 6 3/4" MlXL SET @ 1.2 11 - MAY-98 MWD 3445.63 63.96 260.17 89.33 2371.53 2070.44 -493.44 -2013.72 0.38 0.29 -0.27 ., , 11 - MAY-98 MWD 3541.58 64.14 259.62 95.95 2413.52 2156.71 -508.58 -2098.66 0.55 0.19 -0.57 11 - MAY-98 MWD 3635.81 64.17 257.42 94.23 2454.60 2241.50 -525.46 -2181.76 2.10 0.03 -2.33 11-MAY-98 MWD 3729.42 64.23 259.54 93.61 2495.34 2325.77 -542.29 -2264.34 2.04 0.06 2.26 11- MAY-98 MWD 3821.78 64.22 260.89 92.36 2535.51 2408.92 -556.42 -2346.30 1.32 -0.01 1.46 11 -MAY-98 MWD 3916.33 64.49 260.32 94.55 2576.43 2494.14 -570.34 -2430.39 0.61 0.29 -0.60 , 11 -MAY-98 MWD 4008.57 64.97 260.59 92.24 2615.80 2577.53 -584.17 -2512.65 0.58 0.52 0.29 11 -MAY-98 MWD 4101.82 63.39 261.09 93.25 2656.4::) 2661.43 -597.53 -2595.51 1.76 -1.69 0.54 31' SLIDE 180 TF 11 - MAY-98 MWD 4194.87 62.08 260.88 93.05 2699.04 2744.11' -610.49 -2677.20 1.42 -1.41 -0.23 1 1-MAY-98 MWD 4287.38 61.90 260.62 92.51 2742.49 .2825.75 -623.62 -2757.81 0.32 -0.19 -0.28 1 1 -MAY-98 MWD 4381.11 61.60 261.44 93.73 2786.85 2908.28 -636.49 -2839.37 0.83 -0.32 0.87 I SURVEY CALCULATIONAND FIELD WORKSHEET Job No. 0450-97559 Sidetrack No. Page 3 of 5 . Company ARCO ALASKA, INC. Rig Contractor & No.~ DOYON - 141 Field TARN DEVELOPEMENT FIELD Well Name & No. TARN DRILLSITE 2N/TARN 2N-343 Survey Section Name SPERRY SUN BH! Rep. .. ~. -,.,,~1~ WELL DATA ., -- Target TVD (F33 Target Ooord. N/S Slot Ooord. N/S -136.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSL [} SS~] Target Description Target Coord. E/W Slot Ooord. E/W -1084.30 Magn. Declination 27.1 O0 Calculatibn Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: lOOft~ 30mF] lOm~ Vert. Sec. Azim. 259.24 Magn. to Map Corr. 27.100 Map North to: OTHER SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment Date Tool Depth Angle Direction Length 'I-VD Section N(+) / S(-) E(+) / W(-) DL Type (F-r) (DD) (DD) (FT) (F-T) (F'T) (F-I-) (Per lO0 F'r) Drop (-) Left (-) 11 -MAY-98 MWD 4473.81 61.37 261.73 92.70 2831.11 2989.66 -648.41 -2919.95 0.37 -0.25 0.31 11-MAY-98 MWD 4562.69 61.95 260.93 88.88 2873.30 3067.84 -660.21 -2997.28 1.03 0.65 -0.90 20' SLIDE 40L TF 11 - MAY-98 MWD 4660.99 62.65 260.80 98.30 2918.99 3154.84 -674.03 -3083.21 0.72 0.71 -0.13 11 -MAY-98 MW.D 4751.60 62.81 260.97 90.61 2960.51 3235.34 -686.78 -3162.73 0.24 O. 18 O. 19 11 -MAY-98 MWD 4844.42 62.88 260.56 92.82 3002.87 3317.90 -700.04 -3244.25 0.40 0.08 -0.44 11 -MAY-98 MWD 4937.23 62.80 261.03 92.81 3045.24 3400.45 -713.25 -3325.76 0.46 -0.09 0.51 11 -MAY-98 MWD 5029.12 62.74 260.50 91.89 3087.28 3482.12 -726.36 -3406.41 0.52 -0.07 -0.58 11 -MAY-98 MWD 5122.75 62.47 260.83 93.63 3130.37 3565.23 -739.85 -3488.44 0.43 -0.29 0.35 11 -MAY-98 MWD 5215.12 62.55 261.10 92.37 3173.00 3647.13 -752.71 -3569.36 0.27 0.09 0.29 11 -MAY-98 MWD 5306.96 62.75 260.62 91.84 3215.20 3728.67 -765.67 -3649.90 0.51 0.22 -0.52 11 - MAY-98 MWD 5396.97 62.83 260.21 90.01 3256.35 3808.70 -779.00 -3728.83 0.41 0.09 -0.46 12-MAY-98 MWD 5490.50 63.33 258.11 93.53 3298.70 3892.09 -794.69 -3810.73 2.07 0.53 -2.25 12-MAY-98 MWD 5582.41 63.51 257.76 91.91 3339.83 3974.27 -811.87 -3891.11 0.39 0.20 -0.38 12-MAY-98 MWD 5676.29 63.51 258.90 93.88 3381.70 4058.28 -828.86 -3973.39 1.09 0.00 1.21 ,, 12- MAY-98 MWD 5768.21 63.57 259.07 91.92 3422.66 4140.57 -844.59 -4054.17 O. 18 0.07 O. 18 12- MAY-98 MWD 5862.05 63.56 259.00 93.84 3464.44 4224.59 -860.57 -4136.66 0.07 -0.01 -0.07 12-MAY-98 MWD 5953.93 63.80 258.94 91.88 3505.18 4306.95 -876.33 -4217.50 0.27 0.26 -0.07 -- 12-MAY-98 MWD 6047.19 64.17 258.74 93.26 3546.08 4390.76 -892.55 -4299.72 0.44 0.40 -0.21 12-MAY-98 MWD 6140.29 64.44 258.07 93.10 3586.45 4474.64 -909.41 -4381.90 0.71 0.29 -0.72 12-MAY-98 MWD 6233.03 64.41 259.51 92.74 3626.48 4558.29 -925.67 -4463.96 1.40 -0.03 1.55 20' SLIDE 150R TF 12-MAY-98 MWD 6326.64 64.10 260.46 93.61 3667.14 4642.60 -940.34 -4546.99 0.97 -0.33 1.01 12-MAY-98 MWD 6419.95 64.93 260.91 93.31 3707.29 4726.80 -953.97 -4630.11 0.99 0.89 0.48 12-MAY-98 MWD 6514.83 63.82 261.24 94.88 3748.33 .4812.30 -967.24 -4714.62 1.21 -1.17 0.35 31' SLIDE 180 TF 12-MAY-98 MWD 6608.53 62.56 260.21 93.70 3790.59 4895.90 -980.72 -4797.15 1.66 -1.34 -1.10 Illll -- I ............ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-97559 Sidetrack No. ~ Page "4 of 5 Company ARCO ALASKA,, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPEMENT FIELD Well Name & No. TARN DRILLSITE 2N/TARN 2N-343 Survey Section Name SPERRY SUN BHI Rep. WELL DATA · / , Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -136.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE~ SS~ Target Description Target Coord. E/W Slot Coord. E/W -1084.30 Magn. Declination 27.100 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\DL per: 100ft~ 30m~ 10m[~ Vert. Sec. Azim. 259.24 Magn. to Map Corr. 27.100 Map North to: OTHER SURVEY DATA --_ Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I-VD Section N~-+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (~-q (DD) (DD) (F-r) (IT) (FT) (FT) (Per 400 FT) Drop (-) Left (-) ........ 12-MAY-98 MWD 6700.49 62.36 260.68 91.96 3833.11 4977.42 -994.25 -4877.56 0.50 -0.22 0.51 12-MAY-98 MWD 6794.59 62.13 260.65 94.10 3876.93 5060.67 -1007.76 -4959.73 0.25 -0.24 -0.03 12- MAY-98 MWD 6887.39 61.90 260.96 92.80 3920.48 5142.59 -1020.85 -5040.62 0.39 -0.25 0.33 -- 12-MAY-98 MWD 6978.74 61.91 260.77 91.35 3963.50 5223.14 -1033.65 -5120.19 0.18 0.01 -0.21 12-MAY-98 MWD 7073.42 61.90 261.21 94.68 4008.08 5306.63 -1046.73 -5202.68 0.41 -0.01 0.46 12-MAY-98 MWD 7165.40 62.06 261.72 91.98 4051.29 5387.76 -1058.78 -5282.98 0.52 0.17 0.55 12-MAY-98 MWD 7259.84 61.98 260.67 94.44 4095.60 5471,11 -1071.54 -5365.40 0,99 -0,08 -1.11 12- MAY-98 MWD 7353,06 62.06 261.20 93.22 4139.34 5553.40 -1084.52 -5446.69 0.51 0.09 0.57 12-MAY-98 MWD 7445.95 62.14 261.66 92.89 4182.80 5635.43 -1096.75 -5527.87 0.45 0.09 0.50 12- MAY-98 MWD 7538.22 62.69 261.74 92.27 4225,53 5717.14 -1108.55 -5608.79 0,60 0.60 0,09 13-MAY-98 MWD 7626.66 63.04 262.07 88.44 4265.87 5795.76 -1119.64 -5686.71 0.52 0.40 0.37 · 13- MAY-98 MWD 7719.71 63.61 261.04 93.05 4307.64 5878.84 -1131.85 -5768.96 1.16 0.61 -1.11 13-MAY-98 MWD 7814.05 62.85 260.08 94.34 4350.13 5963.04 -1145.66 -5852.04 1.21 -0.81 -1.02 20' SLIDE 180 TF 13- MAY-98 MwD 7906.22 62.53 260.08 92.17 4392.42 6044.93 -1159.77 -5932.72 0.35 -0.35 0.00 13-MAY-98 MWD 7997.25 63.06 260.35 91.03 4434.04 6125.88 -1173.53 -6012.50 0.64 0.58 0.30 13- MAY-98 MWD 8091.39 63.39 259.29 94,14 4476.45 6209.92 -1188.38 -6095.22 1.06 0.35 -1.13 13-MAY-98 MWD 8185.24 63.11 259.75 93.85 4518.69 6293.72 -1203.63 -6177.63 0.53 -0.30 0.49 13-MAY-98 MWD 8278.56 60.46 260.28 93.32 4562.81 6375.94 -1217.89 -6258.60 2.88 -2.84 0.57 45' SLIDE 180 TF 13-MAY-98 MWD 8373.51 57.12 261.81 94.95 4612.00 6457.09 -1230.55 -6338.80 3.78 -3,52 1.61 45' SLIDE 160R TF 13-MAY-98 MWD 8466.20 53.74 261.36 92.69 4664.59 6533.34 -1241.71 -6414.30 3.67 -3.65 -0.49 45' SLIDE 180 TF , 13-MAY-98 MWD 8556.98 50.34 261.97 90.78 4720,42 6604.84 -1252.09 -6485.10 3.78 -3.75 0.67 45' SLIDE 180 TF 13-MAY-98 MWD 8651.77 46.81 261.76 94.79 4783.13 6675.83 -1262.14 -6555.45 3.73 -3.72 -0.22 45' SLIDE 180 TF __ 13-MAY-98 MWD 8742.39 44.98 262.94 90.62 4846.19 ,6740.80 -1270.82 -6619.94 2.23 -2.02 1.30 31' SLIDE 180 TF 13-MAY-98 MWD 8836.02 43.45 262.60 93.63 4913.30 " 6805.97 -1279.03 -6684.71 1.65 -1.63 -0.36 31' SLIDE 180 TF SURVEY CALCULATION AND FIELD WORKSHEET i ~ Job No. 0450-97559 Sidetrack No. __ Page 5 of 5 ' ~I~BI~L/~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYON - 141 Field TARN DEVELOPEMENT FIELD Well Name & No. TARN DRILLSITE 2N/TARN 2N-343 Survey Section Name SPERRY SUN BHI Rep. Jr~irJP~~ WELL DATA · .. Target 'I'VD (FT) Target Coord. N/S Slot Coord. N/S -136.47 Grid Correction 0.000 Depths Measured From: RKB ~ MSLJ-] SS~ Target Description Target Coord. E/W Slot Coord. EJW -1084.30 Magn. Declination 27.100 Calculatibn Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30m~ 10m~ Vert. Sec. Azim. 259.24 Magn. to Map Corr. 27.100 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(q-) /S(-) E(+)/--V~(~i-- DL Build (+) Right (+) Comment Type p--r) (DD) (DD) (F-'T) (FT) (IT) (F-T) (Per tOO FT) Drop (-) Left (-) 13-MAY-98 MWD 8930.01 43.62 262.57 93.99 4981.44 6870.60 -1287.39 -6748.91 0.18 0.18 -0.03 13-MAY-98 MWD 9022.43 43.95 262.81 92.42 5048.16 6934.43 -1295.52 -6812.34 0.40 0.36 0.26 ~11~ 14-MAY-98 MWD 9111.79 43.93 263.16 89.36 5112.51 6996.31 -1303.09 -6873.88 0.27 -0.02 0.39 14- MAY-98 MWD 9206.07 43.83 262.96 94.28 5180.46 7061.51 -1310.99 -6938.75 0.18 -0.11 -0.21 14-MAY-98 MWD 9296.92 43.68 263.55 90.85 5246.08 7124.19 -1318.37 -7001.15 0.48 -0.17 0.65 14-MAY-98 MWD 9391.68 43.95 263.15 94.76 5314.46 7189.62 -1325.97 -7066.31 0.41 0.28 -0.42 ... 14-MAY-98 MWD 9483.65 44.22 262.30 91.97 5380.52 7253.49 -1334.07 -7129.78 0.71 0.29 -0.92 -- 14-MAY-98 MWD 9543.92 44.17 262.36 60.27 5423.74 7295.44 -1339.68 -7171.42 0.11 -0.08 0.10 14-MAY-98 MWD 9631.00 44.17 262.36 87.08 5486.20 7356.03 -1347.75 -7231.56 0.00 0.00 0.00 EXTRAPOLATE TO TD (NO SURVEY) -- · __ __ i ARCO ALASKA INC. DRILLSITE 2N, WELL NO. 2N-343 TARN POOL, ALASKA Gyro Continuous Multishot Survey Inside 4.5" TUBING Survey date: 03 -OCTOBER, 1998 Job number' AK1098GCE497 ORI61NAL CONTENTS JOB NUMBER · AK1098GCE497 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER: AK1098GCE497 Tool 783 was run in WELL# 2N-343 on SCHLUMBERGER 15/32" wireline inside 4.5" TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER: AK1098GCE497 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK1098GCE497 CLIENT: ARCO ALASKA INC. RIG: SCHLUMBERGER LOCATION: DRILLSITE 2N WELL: 2N-343 LATITUDE: 70.25 N LONGITUDE: 150.0 W SURVEY DATE: SURVEY TYPE : 03 -OCTOBER, 1998 GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 147.3 MAX. SURVEY DEPTH: 9410' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 0-9410' APl NUMBER: TARGET DIRECTION: 050-102-22026-00 259.24 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyro da t a D i r e c t i ona i Survey for ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, KRU(TARN) , ALASKA /ob Number: AK1098GCE497 Run Date: 3-Oct-98 11:15:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.250000 deg. N Sub-sea Correction from Vertical Reference: 147.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 2~9.240 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyr oda t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, Job Number: AK1098GCE497 KRU (TARN), ALASKA Page MEASURED I DEPTH feet N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 100.0 200.0 300.0 400.0 0.00 0.00 .26 56.84 .24 119.85 .13 136.27 2.46 216.10 0.00 0.0 -147.3 0.0 0.0 0.0 .26 100.0 -47.3 -.2 .2 56.8 .26 200.0 52.7 -.6 .6 75.8 .12 300.0 152.7 -.8 .8 93.0 2.44 400.0 252.7 .7 1.9 191.6 0.0 N 0.0 E .1 N .2 E .1 N .6 E .0 S .8 E 1.9 S .4 W 5O 60 70 75 8O 0.0 0.0 0.0 0.0 0.0 6.52 212.89 10.63 209.53 16.58 216.69 19.05 219.66 22.22 223.56 4.06 499.6 352.3 6.2 9.6 209.5 4.14 598.5 451.2 16.1 24.5 210.3 6.18 695.7 548.4 32.6 48.0 212.0 5.27 743.3 596.0 44.1 63.2 213.6 6.90 790.0 642.7 58.1 80.7 215.3 8.4 S 4.7 W 21.2 S 12.4 W 40.6 S 25.4 W 52.7 S 34.9 W 65.8 S 46.7 W 850.0 23.27 225.58 900.0 24.01 227.05 950.0 25.26 230.53 1000.0 26.67 234.28 1050.0 28.55 238.35 2.61 836.2 688.9 74.0 99.8 217.1 1.89 882.0 734.7 90.8 119.6 218.7 3.82 927.4 780.1 108.8 140.2 220.2 4.34 972.4 825.1 128.3 161.6 221.8 5.32 1016.7 869.4 149.7 184.1 223.6 79.6 S 60.2 W 93.4 S 74.7 W 107.1 S 90.4 W 120.4 S 107.7 W 133.3 '~'S 127.0 W 1100.0 30.44 241.55 1150.0 31.76 244.63 1200.0 33.23 247.44 1250.0 34.69 249.99 1300.0 35.33 251.44 4.93 1060.2 912.9 172.9 207.8 225.5 4.~3 1103.0 955.7 197.7 232.6 227.5 4.21 1145.2 997.9 223.9 258.2 229.4 4.08 1186.7 1039.4 .251.3 284.7 231.2 2.11 1227.6 1080.3 279.7 311.9 233.0 145.6 S 148.3 W 157.2 S 171.4 W 168.1 S 195.9 W 178.3 S 221.9 W 187.7 S 249.0 W 135 140 145 150 155 0.0 0.0 0.0 0.0 0.0 36.22 253.02 37.85 254.71 38.95 255.56 40.19 256.04 43.16 256.34 2 . 56 1268 . 2 1120 . 9 308 . 7 339 . 6 234 . 6 3.83 1308.1 1160.8 338.7 368.2 236.2 2 . 45 1347 . 3 1200 . 0 369 . 7 397 . 7 237 . 6 2 . 55 1385 . 8 1238 . 5 401 . 5 428 . 0 238 . 9 5 . 96 1423 . 2 1275 . 9 434 . 7 459 . 9 240 . 2 196.7 S 276.9 W 205.0 S 305.8 W 213.0 S 335.8 W 220.8 S 366.7 W 228.7 S 399.0 W A Gyro d a t a D i r e c t i o na i Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, Job Number: AK1098GCE497 KRU ( TARN ) , ALASKA' Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL DEPTH feet SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 2850.0 61.64 258.67 .30 2900.0 62.53 258.58 1.78 2950.0 63.13 258.40 1.23 3000.0 63.34 258.51 .48 3050.0 63.13 258.65 .48 2105.7 2129.1 2152.0 2174.5 2197.0 1958.4 1533.4 1541.2 253.4 1981.8 1577.5 1585.3 253.6 2004.7 1622.0 1629.6 253.7 2027.2 1666.7 1674.1 253.8 2049.7 1711.3 1718.6 254.0 439.2 S 1477.3 W 447.9 S 1520.7 W 456.8 S 1564.2 W 465.7 S 1608.0 W 474.5 S 1651'.8 W 3100.0 62.82 258.82 .71 3150.0 62.91 258.98 .33 3200.0 63.09 259.19 .52 3250.0 63.18 259.44 .48 3300.0 63.43 259.54 .53 2219.7 2242.5 2265.2 2287.8 2310.3 2072.4 1755.8 1763.0 254.1 2095.2 1800.3 1807.3 254.2 2117.9 1844.9 1851.7 254.3 2140.5 1889.5 1896.1 254.4 2163.0 1934.2 1940.6 254.6 483.2 S 1695.4 W 491.8 S 1739.1 W 500.2 S 1782.8 W 508.5 S 1826.7 W 516.7 S 1870.6 W 3350.0 63.41 259.74 .37 3400.0 63.53 259.81 .28 3450.0 63.91 259.76 .77 3500.0 64.08 259.71 .35 3550.0 63.98 259.64 .24 2332.7 2355.0 2377.1 2399.0 2420.9 2185.4 1978.9 1985.2 254.7 2207.7 2023.6 2029.7 254.8 2229.8 2068.4 2074.4 254.9 2251.7 2113.4 2119.2 255.0 2273.6 2158.3 2164.0 255.1 524.7 S 1914.6 W 532.6 S 1958.6 W 540.6 S 2002.7 W 548.6 S 2046.9 W 556.7~S 2091.2 W 3600.0 64.20 259.72 .46 3650.0 64.19 259.77 .09 3700.0 64.04 259.85 .34 3750.0 64.14 '260.01 .35 3800.0 64.14 260.12 .21 2442.8 2464.6 2486.4 2508.2 2530.0 2295.5 2203.3 2208.8 255.2 2317.3 2248.3 2253.7 255.3 2339.1 2293.3 2298.5 255.4 2360.9 2338.3 2343.4 255.5 2382.7 2383.2 2388.2 255.5 564.7 S 2135.4 W 572.7 S 2179.7 W 580.7 S 2224.0 W 588.5 S 2268.3 W 596.3 S 2312.6 W 3850.0 64.19 260.20 .17 3900.0 64.40 260.27 .44 3950.0 64.65 260.26 .50 4000.0 64.77 260.23 .25 4050.0 64.86 260.07 .34 2551.8 2573.5 2595.0 2616.4 2637.7 2404.5 2428.2 2433.1 255.6 2426.2 2473.3 2478.0 255.7 2447.7 2518.4 2523.0 255.8 2469.1 2563.6 2568.1 255.9 2490.4 2608.9 2613.2 255.9 604.0 S 2356.9 W 611.6 S 2401.3 W 619.3 S 2445.8 W 626.9 S 2490.4 W 634.7 S 2534.9 W A Gyro da t a D i re c t i o na i Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, Job Number: AK1098GCE497 KRU (TARN) , ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. .deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 4100.0 64.18 260.11 4150.0 62.13 260.08 4200.0 62.03 260.18 4250.0 62.05 260.10 4300.0 61.71 260.10 .36 2659.2 2511.9 2654.0 2658.2 256.0 · 10 2681.8 2534.5 2698.6 2702.7 256.1 · 27 2705.2 2557.9 2742.8 2746.8 256.1 .15 2728.6 2581.3 2786.9 2790.8 256.2 · 68 2752.2 2604.9 2831.0 2834.8 256.3 642.4 S 2579.4 W 650.1 S 2623.3 W 657.7 S 2666.9 W 665.2 S 2710.4 W 672.8 S 2753.8 W 4350.0 61.58 260.08 4400.0 61.55 260.15 4450.0 61.40 260.10 4500.0 61.23 260.05 4550.0 61.45 259.72 .27 2775.9 2628.6 2875.0 2878.7 256.3 .13 2799.7 2652.4 2919.0 2922.6 256.4 .33 2823.6 2676.3 2962.9 2966.4 256.4 .35 2847.6 2700.3 3006.8 3010.2 256.5 .74 2871.6 2724.3 3050.6 3054.0 256.5 680.4 S 2797.2 W 687.9 S 2840.5 W 695.5 S 2883.8 W 703.0 S 2927.0 W 710.7 S 2970.2 W 4600.0 62.37 258.52 4650 . 0 62 . 57 258 . 43 4700.0 62.74 258.41 4750.0 62.63 258.46 4800.0 62 . 66 258.47 .79 2895.1 2747.8 3094.7 3098.1 256.6 .43 2918.2 2770.9 3139.1 3142.4 256.6 .35 2941.2 2793.9 3183.5 3186.8 256.6 .24 2964.2 2816.9 3227.9 3231.2 256.7 .07 2987.1 2839.8 3272.3 3275.6 256.7 719.1 S 3013.5 W 727.9 S 3056.9 W 736.8 S 3100.4 W 745.8 S 3144.0 W 754.6~S 3187.5 W 4850.0 62.86 258.52 4900.0 62.77 258.55 4950.0 62.68 258.67 5000.0 62.75 258.73 5050.0 62.66 258.81 .41 3010.0 2862.7 3316.8 3320.0 256.7 .~9 3032.9 2885.6 3361.2 3364.5 256.7 .29 3055.8 2908.5 3405.7 3408.9 256.8 .18 3078.7 2931.4 3450.1 3453.3 256.8 .24 3101.6 2954.3 3494.5 3497.7 256.8 763.5 S 3231.0 W 7'72.3 S 3274.6 W 781.1 S 3318.2 W 789.8 S 3361.8 W 798.5 S 3405.3 W 5100.0 62.53 258.93 5150.0 62.49 258.99 5200.0 62.51 259.06 5250.0 62.45 259.11 5300.0 62.76 259.04 .34 3124.6 2977.3 3538.9 3542.1 256.8 .14 3147.7 3000.4 3583.3 3586.4 256.9 .12 3170.8 3023.5 3627.6 3630.7 256.9 .14 3193.9 3046.6 3672.0 3675.0 256.9 .63 3216.9 3069.6 3716.4 3719.4 256.9 807.0 S 3448.9 W 815.5 S 3492.4 W 824.0 S 3536.0 W 832.4 S 3579.5 W 840.8 S 3623.1 W A Gyro da t a D i r e c t i on a I Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, Job Number: AK1098GCE497 KRU (TARN), ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 5350.0 62·64 259.08 5400.0 62.74 259.04 5450.0 62.90 259.03 5500.0 63.11 258.84 5550.0 63.48 258.57 .25 .22 .32 .53 .90 3239.9 3092.6 3262.8 3115.5 3285.6 3138.3 3308.3 3161.0 3330.8 3183.5 3760.8 3763.8 257.0 3805.2 3808.2 257.0 3849.7 3852.6 257.0 3894.2 3897.1 257.0 3938.9 3941.8 257.0 849.2 S 857.7 S 866.1 S 874.7 S 883.4 S 3666.7 W 3710.3 W 3754.0 W 3797.7 W 3841.5 W 5600.0 63.40 258.47 5650.0 63.39 258.45 5700.0 63.47 258.52 5750.0 63.42 258.69 5800.0 63.42 258.88 .23 .05 .22 .32 .35 3353.2 3205.9 3375.6 3228.3 3397.9 3250.6 3420.3 3273.0 3442.6 3295.3 3983.6 4028.3 4073.0 4117.8 4162.5 3986.5 257.1 4031.2 257.1 4075.9 257.1 4120.6 257.1 4165.3 257.1 892.3 901.3 910.2 919.0 927.7 3885.4 W 3929.2 W 3973.0 W 4016.8 W 4060.7 W 5850.0 63.48 258.90 5900.0 63.59 258.97 5950.0 63.52 259.02 6000.0 64.01 259.10 6050.0 64.05 259.00 .14 .25 .17 .99 .20 3465.0 3317.7 3487.3 3340.0 3509.5 3362.2 3531.6 3384.3 3553.5 3406.2 4207.2 4252.0 4296.7 4341.6 4386.5 4210.0 257.1 4254.8 257.2 4299·5 257.2 4344.3 257.2 4389.3 257.2 936.3 S 944.9 S 953 . 5 S 962 . 0 S 970 . 5~ S 4104· 6 W 4148.5 W 4192.4 W 4236.5 W 4280.6 W 6100.0 64·18 258·87 6150.0 64.49 258.66 6200.0 64.56 258.63 6250.0 64.02 259.38 6300.0 63.83 259.68 34 14 72 67 3575.4 3428.1 3597.0 3449.7 3618.5 3471.2 3640.2 '3492.9 3662.2 3514.9 4431.5 4434.2 257.2 4476.6 4479.3 257.3 4521.7 4524.4 257.3 4566.8 4569.4 257.3 4611.7 4614.3 257.3 979.1 987.9 996.8 1005.4 1013.6 4324.8 W ,. 4369.0 W ~ 4413.2 W 4457.4 W 4501.6 W 6350.0 64.05 259.67 6400.0 64.52 259.81 6450.0 64.98 259.87 6500.0 64.83 259.98 6550.0 62.45 259.81 45 97 92 37 75 3684.2 3536.9 3705.9 3558.6 3727.2 3579.9 3748.4 3601.1 3770.6 3623.3 4656.6 4659.2 257.3 4701·6 4704.2 257.4 4746.9 4749.4 257.4 4792.1 4794.6 257.4 4836.9 4839.4 257.4 1021.6 1029.6 1037.6 1045.5 1053 .4 4545.8 W 4590.1 W 4634.6 W 4679.2 W 4723.3 W A Gyro da t a D i r e c t i ona i S u rve y ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, Job Number: AK1098GCE497 MEASURED DEPTH feet I N C L AZIMUTH deg. deg. 660 665 670 675 68O 685 690 695 700 705 710 715 720 725 730 735 740 745 750 755 760 765 770 775 780 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 62.44 259.89 62.33 259.91 62.29 259.92 62.13 260.06 61.88 260.14 62.02 260.11 61.70 260.21 61.64 260.34 61.78 260.37 61.98 260.46 61.64 260.68 61.77 260.77 62.05 260.77 61.82 260.79 61.77 260.85 62.06 260.86 61.97 260.94 61.81 260.90 62.26 260.79 62.57 260.71 62.69 260.67 63.22 260.66 63.12 260.58 63.48 260.49 63.92 260.33 KRU (TARN) , ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. .13 .23 .08 .40 .52 .28 .66 .26 .28 .44 .78 .30 .56 .45 .15 .57 .34 .93 .63 .26 1.07 .25 .74 .92 3793.7 3816.9 3840.1 3863.5 3886.9 3910.4 3934.0 3957.8 3981.5 4005.0 4028.6 4052.3 4075.9 4099.4 4123.0 4146.6 4170.0 4193.6 4217.0 4240.2 4263.2 4285.9 4308.5 4331.0 4353.1 Page 6 CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 3646.4 4881.3 3669.6 4925.6 3692.8 4969.8 3716.2 5014.1 3739.6 5058.2 3763.1 5102.3 3786.7 5146.4 3810.5 5190.4 3834.2 5234.4 3857.7 5278.5 3881.3 5322.6 3905.0 5366.6 3928.6 5410.7 3952.1 5454.8 3975.7 5498.8 3999.3 5542.9 4022.7 5587.1 4046.3 5631.1 4069.7 5675.3 4092.9 5719.6 4115.9 5764.0 4138.6 5808.5 4161.2 5853.1 4183.7 5897.8 4205.8 5942.6 4883.6 257.4 4927.9 257.5 4972.1 257.5 5016.3 257.5 5060.4 257.5 5104.5 257.6 5148.6 257.6 5192.5 257.6 5236.5 257.6 5280.5 257.7 5324.6 257.7 5368.5 257.7 5412.6 257.7 5456.6 257.8 5500.6 257.8 5544.7 257.8 5588.8 257.8 5632.8 257.8 5676.9 257.9 5721.2 257.9 5765.5 257.9 5810.0 257.9 5854.6 258.0 5899.2 258.0 5944.0 258.0 1061.2 S 1069.0 S 1076.7 S 1084.4 S 1092.0 S 1099.6 S 1107.1 S 1114.5 S 1121.9 S 1129.3 S 1136.5 S 1143.6 S 1150.7 S 1157.7 S 1164.7~1S 1171.8 S 1178.7 S 1185.7 S 1192.7 S 1199.8 S 1207.0 S 1214.3 S 1221.5 S 1228.9 S 1236.3 S 4766.9 W 4810.6 W 4854 2 W 4897.7 W '~ 4941.2 W 4984.7 W 5028.1 W 5071.5 W 5114.9 W 5158.4 W 5201.9 W 5245.3 W 5288.8 W 5332.4 W 5375.9 W 5419.4 W 5506.6 W 5550.2 W 5593.9 W 5637.7 W 5681.7 W 5725.7 ,W 5769.8 W 5814.0 W A Gy r o da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, Job Number: AK1098GCE497 KRU (TARN), ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 7850.0 62.19 260.21 7900.0 62.14 260.12 7950.0 62.65 260.11 8000.0 62.89 259.98 8050.0 62.91 259.83 3.46 4375.8 4228.5 5987.1 .19 4399.1 4251.8 6031.3 1.02 4422.3 4275.0 6075.6 .53 4445.2 4297.9 6120.1 .27 4467.9 4320.6 6164.6 5988.5 258.0 6032.7 258.0 6077.0 258.0 6121.4 258.1 6165.9 258.1 1243.9 S 5857.9 1251.4 S 5901.5 1259.0 S 5945.1 1266.7 S 5988.9 1274.5 S 6032.7 8100.0 63.30 259.66 8150.0 63.57 259.60 8200.0 63.05 259.46 8250.0 61.57 259.28 8300.0 60.06 260.12 .84 4490.6 4343.3 6209.2 .56 4512.9 4365.6 6253.9 1.08 4535.4 4388.1 6298.6 2.98 4558.6 4411.3 6342.9 3.35 4583.0 4435.7 6386.5 6210.5 258.1 6255.2 258.1 6299.8 258.1 6344.1 258.1 6387.7 258.1 1282.5 S 6076.6 W 1290.5 S 6120.6 W 1298.6 S 6164.5 W 1306.8 S 6208.0 W 1314.6 S 6251.0 W 8350.0 58.18 260.82 8400.0 56.52 260.90 8450.0 54.73 260.80 8500.0 52.21 261.24 8550.0 51.06 261.61 3.96 4608.6 4461.3 6429.4 3.32 4635.6 4488.3 6471.5 3.59 4663.8 4516.5 6512.7 5.08 4693.6 4546.3 6552.9 2.38 4724.6 4577.3 6592.1 6430.6 258.1 6472.7 258.2 6513.9 258.2 6554.0 258.2 6593.1 258.2 1321.7 S 6293.3 W 1328.4 S 6334.9 W 1334.9 S 6375.6 W 1341.2 S 6415.3 W 1347.1~ S 6454.1 W 8600.0 48.66 261.88 8650.0 47.24 261.91 8700.0 '46.26 262.06 8750.0 45.22 262.38 8800.0 43.51 262.55 4.81 4756.9 4609.6 6630.3 2.'85 4790.4 4643.1 6667.3 1~97 4824.6 4677.3 6703.7 2.13 4859~5 4712.2 6739.5 3.42 4895.3 4748.0 6774.4 6631.3 258.2 6668.3 258.3 6704.7 258.3 6740.4 258.3 6775.3 258.3 1352.6 S 6491.9 W 1357.8 S 6528.6 W 1362.9 S 6564.7 W 1367.7 S 6600.2 W 1372.3 S 6634.8 W 8850.0 43.62 262.76 8900.0 43.46 262.55 8950.0 43.70 262.58 9000.0 43.82 262.71 9050.0 43.93 262.86 .36 4931.5 4784.2 6'808.8 .43 4967.7 4820.4 6843.2 .48 5004.0 4856.7 6877.6 .31 5040.1 4892.8 6912.1 .30 5076.1 4928.8 6946.7 6809.6 258.3 6844.0 258.4 6878.3 258.4 6912.8 258.4 6947.4 258.4 1376.7 S 6669.0 W 1381.1 S 6703.2 W 1385.6 S 6737.3 W 1390.0 S 6771.6 W 1394.4 S 6806.0 W A Gyro da t a D i r e c t i ona I Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, Job Number: AK1098GCE497 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. 9100.0 43.96 263.10 9150.0 43.92 263.34 9200.0 43.84 263.27 9250.0 43.79 263.31 9300.0 43.81 263.42 9350.0 43.63 263.39 9400.0 44.05 263.28 9410.0 43.81 263.12 Final Station Closure: KRU (TARN) , ALASKA Page 8 DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 35 5112.1 34 5148.1 20 5184.2 11 5220.2 16 5256.3 CLOSURE DIST. AZIMUTH feet deg. .36 5292.5 .84 5328.5 2.68 5335.7 4964.8 6981.3 6982.0 258.4 5000.8 7015.9 7016.5 258.5 5036.9 7050.5 7051.1 258.5 5072.9 7085.0 7085.6 258.5 5109.0 7119.5 7120.1 258.5 5145.2 7154.0 5181.2 7188.5 5188.4 7195.5 Distance: 7195.92 ft 7154.5 258.6 7189.0 258.6 7195.9 258.6 Az: 258.59 deg. HORIZONTAL COORDINATES feet 1398.6 S 1402.7 S 1406.7 S 1410.8 S 1414.8 S 1418.8 S 1422 . 8 S 1423.6 S 6840.5 N 6874.9 N 6909.3 W ...~ 6943.7 W ! 6978.1 W 7012.4 W 7046.8 W 7053.7 W A Gy r o da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, KRU(TARN), Job Number: AK1098GCE497SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet -147.3 0.00 0.00 0.00 0.0 .25 86.65 .26 100.0 .18 127.62 .19 200.0 1.23 174.04 1.22 300.0 4.39 214.58 3.21 0.0 147.3 247.3 347.3 447.3 0.0 0.0 0.0 .6 65.8 .8 83.9 1.9 139.7 9.6 200.1 0.0 N 0.0 E .iN .4 E .1 S .7 E .9 S .6 W 4.9 S 2.4 W 400.0 8.50 211.27 4.10 500.0 13.62 213.12 5.16 600.0 19.33 220.00 5.41 700.0 23.45 225.94 2.44 800.0 25.88 232.19 4.05 547.3 647.3 747.3 847.3 947.3 11.0 24.4 45.3 78.1 117.5 24.5 209.9 48.0 211.2 80~.7 213 .7 119.6 217.5 161.6 220.9 14.5 S 8.4 W 30.9 S 18.9 W 53.8 S 35.9 W 82.9 S 63.7 W 113.0 S 98.1 W 900.0 29.88 240.60 5.04 1000.0 33.30 247.57 4.20 1100.0 35.77 252.21 2.33 1200.0 38.95 255.56 2.45 1300.0 44.33 256.23 4.31 1047.3 1147.3 1247.3 1347.3 1447.3 166.0 225.3 293.8 369.7 458.0 207.8 225.0 284.7 229.5 339.6 233.8 428.0 237.6 493.4 240;9 141.9 S 142.0 W 168.7 S 197.3 W 192.1 S 262.5 W 213.0 S 335.8 W 234.3 S'~ 421.6 W 1400.0 49.56 256.49 4.86 1500.0 57.94 258.27 5.43 1600.0 60.90 259.21 .71 1700.0 61.27 260.20 .59 1800.0 61.77 261.06 .59 1547.3 1647.3 1747.3 1847.3 1947.3 563 .3 699.1 872.9 1053.0 1236.6 600.3 243.7 719.2 246.3 889.3 248.7 1104.7 250.5 1278.2 252.0 259 288 322 355 384 .3 S 524.1 W .8 S 656.7 W .8 S 827.2 W .1 S 1004.4 W .7 S 1185.6 W 1900.0 62.15 258.63 .45 2000.0 63.00 258.44 1.35 2100.0 62.95 259.02 .37 2200.0 63.49 259.79 .31 2300.0 64.20 259.73 .38 2047.3 2147.3 2247.3 2347.3 2447.3 1424.5 1612.9 1809.7 2008.2 2212.6 1453.6 253.0 1629.6 253.7 1851.7 254.2 2029.7 254.7 2253.7 255.2 417 454 493 529 566 .8 S 1370.6 W .9 S 1555.3 W .6 S 1748.3 W .9 S 1943.4 W .4 S 2144.6 W A Gyro d a t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, KRU(TARN), Job Number: AK1098GCE497SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 2400.0 64.18 260.19 .18 2500.0 64.56 260.09 .80 2600.0 61.78 260.10 .57 2700.0 61.23 260.05 .35 2800.0 62.71 258.42 .32 2547.3 2647.3 2747.3 2847.3 2947.3 2418.9 2629.1 2821.9 3006.2 3195.3 2433.1 255.6 2658.2 256.0 2834.8 256.3 3010.2 256.5 3231.2 256.6 602.4 S 2347.7 W 638.2 S 2554.9 W 671.3 S 2744.8 W 702.9 S 2926.4 W 739.2 S 3112.0 W 2900.0 62.71 258.63 .25 3000.0 62.49 258.99 .14 3100.0 62.67 259.07 .24 3200.0 63.42 258.50 .41 3300.0 63.43 258.89 .31 3047.3 3147.3 3247.3 3347.3 3447.3 3389 3582 3775 3971 4171 .2 .5 .2 .9 .8 3408.9 256.7 3586.4 256.9 3808.2 257.0 3986.5 257.1 4210.0 257.1 777.9 S 3302.1 W 815.4 S 3491.6 W 852.0 S 3680.9 W 890.0 S 3873.9 W 929.5 S 4069.8 W 3400.0 64.04 259.03 .42 3500.0 63.96 259.48 1.38 3600.0 64.83 259.97 .39 3700.0 62.24 259.97 .18 3800.0 61.67 260.28 .43 3547.3 3647.3 3747.3 3847.3 3947.3 4373 4581 4789 4983 5171 .7 .2 .8 .4 .0 4389.3 257.2 4614.3 257.3 4794.6 257.4 5016.3 257.5 5192.5 257.6 968.1 S 4268.0 W 1008.0 S 4471.7 W 1045.1 S 4676.9 W 1079.1 S 4867.5 W 1111.3 S~ 5052.4 W 3900.0 61.74 260.75 .40 4000.0 62.05 260.86 .56 4100.0 62.60 260.70 .51 4200.0 63.80 260.37 .87 4300.0 62.89 259.96 .51 4047.3 4147.3 4247.3 4347.3 4447.3 5357 5544 5733 5930 6124 .2 .3 .3 .8 .3 5368.5 257.7 5588.8 257.8 5765.5 257.9 5944.0 258.0 6165.9 258.1 1142.1 S 5236.1 W 1172.0 S 5420.8 W 1202.1 S 5607.5 W 1234.4 S 5802.4 W 1267.5 S 5993.0 W 4400.0 62.29 259.37 2.05 4500.0 55.78 260.86 3.43 4600.0 49.37 261.80 4.09 4700.0 45.58 262.27 2.07 4800.0 43.55 262.66 .39 4547.3 4647.3 4747.3 4847.3 4947.3 6321.3 6488.6 6618.9 6726.9 6823.8 6344.1 258.1 6513.9 258.2 6631.3 258.2 6740.4 258.3 6844.0 258.3 1302.8 S 6186.9 W 1331.1 S 6351.7 W 1350.9 S 6480.6 W 1366.0 S 6587.7 W 1378.6 S 6683.9 W A Gyro d a t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 3-43, 4.5" Location: DRILLSITE 2N, KRU(TARN), Job Number: AK1098GCE497SS ALASKA SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL DEPTH SEVERITY DEPTH SECTION feet deg. deg. deg./ feet feet 100 ft. 4900.0 43.85 262.74 .31 5000.0 43.92 263.34 .34 5100.0 43.81 263.39 .15 5188.4 43.81 263.12 2.68 5047.3 5147.3 5247.3 5335.7 Final Station Closure: Distance: 7195.92 6919.0 7015.1 7110.9 7195.5 ft Az: CLOSURE DIST. AZIMUTH feet deg. 6947.4 258.4 7016.5 258.5 7120.1 258.5 7195.9 258.6 258.59 deg. Page HORIZONTAL COORDINATES feet 1390.9 S 6778.5 W 1402.6 S 6874.1 W 1413.8 S 6969.5 W 1423.6 S 7053.7 W 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK1098GCE497 TOOL NUMBER: 783 MAXIMUM GYRO TEMPERATURE: 79.21 C MAXIMUM AMBIENT TEMPERATURE: 58.54 C MAXIMUM INCLINATION: 64.98 AVERAGE AZIMUTH: 258.59 WIRELINE REZERO VALUE: O~ REZERO ERROR/K: N/A CALIBRATION USED FOR FIELD SURVEY: 2548 CALIBRATION USED FOR FINAL SURVEY: 2548 PRE JOB MASS BALANCE OFFSET CHECK: .16 POST JOB MASS BALANCE OFFSET CHECK~: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES .24 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS: OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 9391 43.95 263.15 FINAL SURVEY 9400 44.05 263.28 5314.0 -1325.0 5328.5 -1422.8 -7066.O -7046.8 FUNCTION TEST JOB NUMBER · AKI098GCE497 5 Survey stations were colleCted at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 700 16.580 16.580 16.580 16.580 16.580 AZIMUTH M.D. ft 1 2 3 4 5 700 216.69 216.65 216.74 216.84 216.81 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK1098GCE497 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 783 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 790 GYRO SECTION DATA SECTION POWER SECTION A0200 C0111 C0083 A0162 C0089 C0086 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY' PRINTER INTERFACE A0467 A0085 A0079 A0143 A0433 A0107 A0029 A0055 WIRELINE COMPANY: CABLE SIZE: 15/32" SCHLUMBERGER RUNNING GEAR 2.25" HOUSING w ECCENTRIC BAR TOTAL LENGTH OF TOOL: 25' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 220 POUNDS CHRONOLOGICAL REPORT JOB NUMBER' AK1098GCE497 SATURDAY, 10~03/98 10:30 11:45 12:00 14:30 16:15 17:15 18:45 22:45 09:00 TO LOCATION MU TOOL, RU SCHLUMBERGER PICK UP GYRO RIH SURVEY TO 9410' CONTINUOUS. SURVEY OUT LD TOOL, RD SCHLUMBERGER. TO ATLAS PROCESS SURVEY, CHECK TOOLS. DRILLSITE 18 TOMORROW A.M.. 1 O/8/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 11550 Company: ' Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Well Job # Log Description Date Color Print 2N-343,~'(~J?.-'~ 98511 USlT 980912 ,, 1 ,, ,, , ,,, ,,, ,, .... SIGNED: Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. RECEIVED OCT 1 $ 1998 DATE: AlasKa Oil & Gas Cons. Commissio~ Anchorage 25.13" (638.3 mm) 3.66" max tool OD (93.0 mm) 0,87" ID (22.1 mm) 3,66" max tool OD (93.0 mm) .iL ;3 ' UO ; ll.q. LL l DUE l L/t'N - ,q, LR,..3Pd-I.~ A_r-,.3/t1F_.,I..,L,O/L,t"i~ 1 / FF,.Vd, ~ d/ O 802.339 4 A" FF DRILL" SV Squeeze Packer 4" Line pipe 4 ~" g,50 - "13.50 Ibffl. 4 ~' 16.00 lb/fl 5' 20.30 - 24,20 Ib/tt 5 ½" 36,40 Ib/fl 302,31397 Tensk3n slta~ve 30,000 tb (std) - (13,605 kg) 20,000 lb - 802.3 (9072 kg) i C 7!-'-'-- -'~! Bridging pt~g 802.3093~ , 1396 Squeeze Packers 3-27 Packaged shipping we{ghl - 39 lb ' (17.7 kg) EZ DRIU_~ SP ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 September 30, 1998 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval following Tarn well. 'Form 10-403) on the Well 2N-343 Action Change Approved Program If you have any questions, please call me at 263-4603. Sincerely, Paul Mazzolini Drilling Team Leader Attachments ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company .. ~, STATE OF ALASKA '~- Cj ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Alter casing __ Change approved program X Abandon ~ Suspend __ Operation Shutdown __ Reenter suspended well__ Repair well __ Plugging __ Time extension m Stimulate __ Pull tubing m Vadance __ Perforate __ Other__ 2. Name of Operator: 3. Address: ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 137' FNL, 1084' FEL, Sec 3, T9N, R7E, UM At top of productive interval: At effective depth: At total depth: 1488' FNL, 2243' FVVL, Sec 4, T9N, R7E, UM 12. Present well condition summary 5. Type of Well: Development Exploratory ._= Stratagrapic _.= Service 6. Datum of elavation (DF or KB feet): 149' RKB 7. Unit or Property: Kuparuk River Unit 8. Well number: 2N-343 9. Permit number: 98-92 10. APl number: 50-0103-20260 11. Field/Pool: Kuparuk River Field/Tarn Oil Pool Total Depth: measured true vertical 9612' feet Plugs (measured) 5473 feet Effective Depth: measured true vertical 9414 feet Junk (measured) 5330 feet Casing Length Size Conductor 108' 16" Surface 3340' 9-5/8" Production 9612' 7" X 4-1/2" Liner Cemented 9 cu. Yds High Early 386 sx ASIII, 350 sx Class G, 60 sx ASI 725 sx Class G & Measured depth 108' 3340' 9612' True verticaldepth 108' 2325' 5473' Perforation Depth None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Tubing @ 8859' MD. Packers and SSSV (type and measured depth) Baker Casing Seal Assby @ 8859' MD ORIGINAL 13. Attachments Description summary of proposal _X Detailed operations program __ 14. Estimated date for commencing operation Week of 10/5 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. BOP sketch_ il5. Status of well classification as: Oil _ Gas __ Service: MI Injector Suspended__ FOR COMMISSION USE ONLY Date Conditions of approval: Notify Comission so representitive may witness Plug integrety ~ BOP test __ Location clearance Mechanical integrety test )(, Subsequent form required 10- ~'¢~--~ Approved by order of the Commissioner Porto 1u-403 I~ev u~5/1 b/~8 ,jdginal Signed By O.~.vid W. Johnston Date ~SUBMI I IN I I~IPLI(.;A I b Attachment 1 Description of Proposal Tarn Well 2N-343 As per AOGCC 20ACC25.030 ARCO Alaska is hereby requesting Commission approval for corrective measures to repair production casing integrity on Miscible Gas Injection Well 2N-343. ARCO Alaska proposes to repair suspected failed production casing shoe cement by means of a mechanical bridge plug rated to 10,000 psi differential pressure. As outlined in the well history below, the production casing on Well 2N-343 was initially successfully pressure tested in accordance to AOGCC 20ACC25.030. Pressure tests after the CTUcleanout noted below have not been successful.. Well History 5/17/98: -Production casing cement job performed: full returns, bumped plug, floats held. 5/18/98: -Production casing successfully pressure tested to 3500 psi for 30 min. 8/17/98: -Production casing successfully pressure tested to 2000 psi for 15 min. -Heavy fluids encountered at 9258'. -Recovered sample of contaminated cement at 9391'. -Dummy perf gun reached a depth of 9298'. Engineering decided to conduct a CTU cleanout to the PBTD float collar depth of 9487'. The well perforation interval was estimated at 9100'-9330'. It was suspected that asmall amount of cement had bypassed the wiper plug and was contaminated by the seawater displacement fluid. Contaminated fluid was suspected across the perforation interval. Additionally, the lowest perforation could not be reached with the dummy perforation gun. 8/21/98: -CTU milled soft cement with hard streaks f/9235' - 9480'. -Pressure production casing to 3475 psi. Lost 370 psi in 20 min. 8/26/98 -Pressure production casing to 2500 psi. Lost 200 psi in 15 min. -Dummy perf gun reached a depth of 9394'. 9/12/98 -Completed USIT Cement Evaluation Log f/9404'-8880' Cement Evaluation Results: Adequate bond above and below perforation interval -64' aggregate of 3000 psi compressive strength cement out of 74' possible from log TD @ 9404 to lowest perf @ 9330'. -84' of cement from log TD @ 9404' to float shoe @ 9487' not evaluated. -130' aggregate of 3000 psi compressive strength cement out of 172' possible from highest perf @ 9110' to the top of cement @ 8938' -Possible channel f/9020'-9046' Bridge Plug Recommendation Justification: 1) Bridge plug setting allows accurate depth control whereby giving approximately 60' of rathole from the bridge plug to the lowest perforation. 2) 10,000 psi bridge plug pressure rating exceeds casing pressure rating. 3) Low pressure leakoff indicates squeeze success marginal. 4) Production casing capacity of 0.0152 BBL/ft allows approximately 1 BBL of cement volume from PBTD to the lowest perforation. 5) Excess cement could possibly prevent perforating portions of the productive interval, thus reducing ultimate recovery. WELL LOG TRANSMITTAL To: State of Alaska September 2, 1998 Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor ?~, r'~ 3001 Porcupine Dr. ~,)~ OL-~ ~ Anchorage, Alaska 99501 ' MWD Formation Evaluation Logs 2N-343 (R), AK-MM-80223 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-343 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20260-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20260-00 2"x 5" MD Neutron & Density Logs: 50-103-20260-00 ~ x 5" TVD Neutron & Density Logs: 50-103-20260-00 Note: ( R ) represents replacment data for well 2N-343. N/A ~1 Blue~e Folded Sepia Blueline 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSMYFYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 2, 1998 MWD Formation Evaluation Logs 2N-343 (R), AK-MM-80223 1 LDWG formatted Disc with verification listing. API#: 50-103-20260-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANI) RETURNING THE ATYACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 . Date: Note: The ( R ) represents replacement data for well 2N-343. Previously distributed data (B.C. 1004006094 on July 1, 1998). SBD2 and SCO2 data is reprocessed due to calibration fault. ~'~, ~ ,c _.W..~X~ ~ ~ '7/,//9 ~ . 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWl) Formation Evaluation Logs July 8, 1998 2N-343, AK-MM-80223 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-343: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20260-00 2"x 5" TVD Resistivity, & Gamma Ray Logs: 50-103-20260-00 Q~I! 5t! ~ x MD Neutron & Density Logs: 50-103-20260-00 TVD Neutron & Density Logs: 50-103-20260-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. WELL LOG TRANSIMITTAL To: State of Alaska July 1, 1998 Alaska Oil and Gas Conservation Comm. .Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs ~N-o43, AK-~LM-80SS3 1 LDWG formatted Disc with verification listing. APl#: 50-103-20260-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF ~ TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: $1gne.,d:~] ~ 5631 Silverado Way, Suite G · Anchorage, 'AlasKa 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11273 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 6/22/98 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape KRU 2N-343 '~:~. ~'~'~ 9 82 43 =DSI/FMS/CMR/PEX 98051 5 1 -- KRU 2N-343 98243 PEX-MCFL 98051 6 I 1 KRU 2N-343 98243 PEX-CNL 98051 6 I 1 KRU 2N-343 98243 PEX-CNL/TLD LITHODENSITY 98051 6 I 1 KRU 2N-343 98243 PEX-CMR 98051 6 I 1 ...... KRU 2N-343 98243 DSI 98051 5 I 1 KRU 2N-343 98243 FMS 98051 5 I 1 ,, , ................................................................... DATE Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. TONY KNOWLE$, GOVEF~NOF~ ALASI~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 14, 1998 Mr. Mike Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Tarn wells 2N-323, 2N-329, 2N:343 annular disposal requests Dear Mr. Zanghi: Pursuant to reviewing the additional geologic information, leak-offtest data and cementing information presented today, the Commission is satisfied that sufficient data has been submitted to determine that the waste will be contained in a suitable receiving zone and the disposal will not contaminate freshwater, cause drilling waste to surface, impair the mechanical integrity of the well used for disposal, damage a producing or potentially producing formation or impair the recovery of oil or gas from a pool. Therefore, your request for annular injection into ~vells 2N-323, 2N-329 and 2N-343 is approved. David W. John~~ Chairman ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0350 Telephone 907 276 1215 May 12, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-343 Dear Mr. Commissioner: Enclosed please find a LOT plot, cementing detail and the casing detail sheets for Kuparuk Well 2N-343. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. If there are any questions, please call 265-1492. Sincerely, F. C. Johnson Drilling Engineer Kupamk Drill Site Development FCJ/skad cc' Blair Wondzell DNFID£NTIAL ARCO Alaska, Inc. Cementing Details Well Name: 2N-343 Report Date: 05/10/98 Report Number:. 3 Rig Name: DOYON 141 AFC No.: AK9381 Field: Tarn i Centralizers State t~pe used, intervals covered and spacing Comments: 12 114" x 9 5/8" Gemeco Bow Spring (40) placement on Casing Detail. Mud Weight: PV(pdor cond): PV(affer cond): YP(prior cond): YP(affer cond): Comments: 10.5 26 16 33 18 - Gels before: Gels after. Total Volume Circulated: 13/17 7110 1020 bbls/1250 Wash' . 0 .'. Type: Volume: Weight: Comments: . Spacer ' · 0" . Type: Volume: Weight: comments: . ARCO 30130 10.5 Stage..!lStage 2-. - . . £ead cement .0'- - Type: J Mixwtrtemp: No. of Sacks:I Weight: Yield: comments:: ' ASlII 70 110/276 10.5110.5 4.42/4.42 . :Stage.:!~stage .2. ' ' Additives: Used AS3 Lite'.. . TailC~ant !) ...: :' Type: Mix wtr temp: I No. of Sacks: Weight: Yield: CommentS::- . ' · 70I 350/60 15.8/15.7 1.15/0.93 St~ge.l~sta,, 2 -' . .--- 'stage I=G cmt/Stage ' Additives: '-2='-~$1cmL': - ' - ' "." Stage I=G w/1%Sl, 0.2% D46, 0.3% 1365 Stage2=ASl standard blend . . . '. . DiSPia~ement' 0 - .: . . Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: common!s:': : - 10 10 135 · Stage !/stage 2 . .' ' · · · Reciprocation length: Reciprocation speed: Str. Wt. Down: '..' -: '. ': .: ' 10 15fpm 75 ·. Theoretical Displacement: Actual Displacement: Str. Wt. in mud: · ::; :"'. ..'. '~ '.t244.4/113 246.3/113.8 113 Calculated top of cement: CP: Bumped plug: Floats held: Surface through stage collar ~ 1488'. Date:Stage1 5/9/98 yes/yes yes/yes /Stage2 5/10/98 Time:Stage1 23:35/ Stage2/04:36 Remarks:Stage 1, mixed and pumped 86.5 bbls AS3 lite at 10.5 ppg Followed by 71.7 bbls of G+adds at 15.8 ppg. proceeded cement with 5 biffs of water and 30 bbls of Arco spacer at 10.5 ppg. Displaced with 10 bbls G cmt + 20 bbls wash water + 216.34 bbls of 10.5 ppg mud. Reciprocated casing untill last 65 bbls of displacement. Had full returns while circulating and cementing. Opened stage tool with 3100 psi, circulated out spacer and 20 bbls of cement to surface. Stage 2, Mixed and pumped 217 bbls of AS3 lite at 10.5 ppb followed by 9.9 bbls of AS1 at 15.7 ppg. Proceeded cement with 5 biffs of water and 30 bbls of Arco spacer at 10.5 ppg. Displaced cement with 20 biffs wash water and 93.8 bbls of 10.5 ppg mud. Had full returns during job, 121 bbls of 10.5 ppg cement returns at surface. , ICement Company: I Rig Contractor: IApproved By: DS IDOYON ID.BURLEY Casing Detail 9. 625" Surface Casing WELL: TARN 2N-343 ARCO Alaska, Inc. DATE: 5/9/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LR = 29.91' TOPS Above RKB 9 5/8" Landing Joint 29.91 FMC GEN V- Prudhoe 9 5/8" Csg Hgr 1.73 29.91 jts. 48-84 9 5/8", 40#, L-80 BTC 1419.17 31.64 jt. 89 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 37.64 1450.81 Gemeco 9 5/8" Stage Collar (BAKERLOK) 2.82 1488.45 jt. 88 9 5/8", 40#, L-80 BTC (Thread Locked Collar) 40.37 1491.27 jts. 4-47 9 5/8", 40#, L-80 BTC 1691.53 1531.64 jt. 3 9 5/8", 40#, L-80 BTC (shutoff baffle on top of jt #3, BAKERLOK) 37.19 3223.17 Gemeco Float Collar 1.47 3260.36 its 1-2 9 5/8", 40#, L-80 BTC 76.06 3261.83 Gemeco Float Shoe 1.70 3337.89 3339.59 40 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, 88, 89 over stop collars and over casing collars on Jts. 3-14 and over collars ofjts. 17,20,23,26,29,32,35,38,41,44,47,50,53,56,59,62,65,68,71,74,77,80, 83 and 84 Joints 85-87 (3 joints) will remain in the pipe shed. Remarks: String Weights with Blocks: 110K# Up,70K~ Dn,20k# Blocks. Ran 86 joints of casing. Drifted casing with 8.679 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Ddlling Supervisor:Robert L. Morrison Jr. CASING TEST and FORMATION INTEGRITY TEST Well Name: TARN 2N-343 Date: 5111/98 Supervisor: David Burley Casing Size and Description: Casing Setting Depth: Mud Weight: 8.9 ppg Hole Depth: 2,339' TVD 9 518", 40 ppf, L-80, BTC 3,340' TMD 2,325' TVD EMW = Leak-off Press. + MW 0.052 x TVD 860 psi + 8.9 ppg LOT = (0.052 x 2,339') = 16.0 ppg Fluid Pumped: 3.4 bbl Bled back 1.5 bbls at end of FIT test. Pump output = 0.1010 bps UJ 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 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 0 stks 2 stks 4 stks 6 stks 8 stks I I I I I ~ LEAK-OFF TEST '--a'=CASING TEST ~,,~ SHUT DOWN PUMP .~ , ~-- SHUT IN PRESSURE 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 stks stks stks stks stks stks stks stks stks stks stks stks stks stks stks stks STROKES CASING TEST and FORMATION INTEGRITY TEST Well Name: TARN 2N-343 Date: 5/13/98 Supervisor: D. Burley Casing Size and Description' 9 5~8", 40 ppf, L-80, BTC Casing Setting Depth: 3,34O' TMD 2,325' TVD Mud Weight: Hole Depth: 9.3 ppg 7746' MD 4,320' TVD EMW = Leak-off Press. + MW 0.052 x TVD 1,120 psi + 9.3 ppg LOT = (0.052 x 4,320') = 14.3 ppg Fluid Pumped = 6.9 bbl Pump output = 0.1010 bps Shut Down pump after 48 strokes, total bled back at completion of test 3.5 bbls. U.I 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,1o0 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,5o0 psi 1,40o psi 1,300 psi 1,200 psi 1,1o0 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi o psi I I -- ~CASING TEST _ SHUT DOWN PUMP POINT ~ MONITOR SHUT IN 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk s s s s s s s s s s s s s s s s s s s s s s s s s s s s s s s s s s s s STROKES MEMORANDUM TO: THRU: State of Alaska, Alaska Oil and Gas Conservation Commission Blair Wondzeii, P. !. Supervisor DATE: May 10, 1998 FILE NO: abwkejfe.doc FROM: Chuck Scheve, ~- ~ SUBJECT: Petroleum Inspector BOPE Test Doyon 141 Tarn 2N-343 PTD # 98-0092 ., _ Sunday May 10~ 1998: I traveled to Arco's 2N-343 well being drilled by Doyon Rig 141 and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows, the test lasted 3 hours with one failure. The indicator light on the lower pipe rams remained in the open position when rams were closed. The rig electrician was repairing this problem when I departed location. The testing went well with good test procedures being employed by the Doyon crews. The rig was clean and all related equipment appeared to be in good working order. The location was well organized allowing good access to all areas of the rig. Summary:' 2N-343 well. Doyon 141, Attachment: I witnessed the initial BOPE test on Doyon Rig 141 Drilling Arco's Tam 5110198, test time 3 hours one failure abwkejfe.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8 Test: Initial X Workover: Doyon ARCO 2N-343 Set @ Weekly Rig No. 141 PTD# Rep.: Rig Rep.: 3,310 Location: Sec. Other DATE: 5/10/98 98-92 Rig Ph.# 659-7165 Bobby Mordson Bobby Ingram 3 T. 9N R. 7E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign Yes DH. Rig OK Hazard Sec. Yes Test Quan. Pressure P/F 1 250/3,500 P f 250/3,500 P , I 250/3,500 P P 1 250/3,500 FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N/A MUD SYSTEM: V'~sual Tdp Tank OK Pit Level Indicators OK Flow Indicator OK Meth Gas Detector OK H2S Gas Detector OK Test Press. P/F 250/3,000 P 250/3,000 P , 1 250/3,000 P 1 250/3,000 P I 250/3,000 P 2 250/3,000 P CHOKE MANIFOLD: No. Valves .14 No. Flanges 2~f~ Manual Chokes Hydraulic Chokes Test Pressure P/F 250/3,000 P 250/3,000 P Fun~'oned Functioned P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure Alarm 200 psi Attained After Closure minutes 25 sec. OK System Pressure Attained 2 minutes 55 sec. OK Blind Switch Covers: Master: OK Remote: OK OK Nitgn. Btl's: 5 (~ 2100 OK Psig. OK 3000 1700 Number of Failures: 't ,Test Time: 3.0 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I I REMARKS: Indicator light on lower pipe rams remained in open posidon when rams were in closed pos~on. Distribution: orig-Well File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: abwkejfe Chuck Scheve TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 6, 1998 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 2N-343 ARCO Alaska, Inc. Permit No: 98-92 Sur. Loc.: 137'FNL, 1084'FEL, Sec. 03, T9N, R7E, UM Btmholc Loc: 1496'FNL. 2273'FWL. Sec. 4, T9N, R7E. UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill docs 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. Annular disposal of drilling wastes will not be approved until sufficient data is submitted to ensure the requirements of 20 AAC 25.080 are met. The Commission will require additional geologic information as specified by Bob Crandall during a meeting with Doug Hastings and Fred Johnson of vour staff on May 4. 1998. In addition, a Formation Integrity Test (FIT) must confirm the adequately of cement behind surface casing. Cementing records, FIT data, and anv CQLs must be submitted to the Commission with an Application for Sundry Approvals (Form 10-403) prior to initiating disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of thc Commission max, witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlffenclosures cc: l)cpartment or' Fish & Game. Habitat Section w/o encl. Depamnent of F,m'ironmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill F~I lb. TypeofWell Exploratory E StratigraphicTest ~-- Development Oil [~ Re-Entry E Deepen EI Service X Development Gas [~ SingleZone X Multiple Zone [~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Unit 3. Address 6. Property Designation Tarn Pool P. O. Box 100360, Anchorage, AK 99510-0360 ALK 4293 ADL 375074 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 137' FNL 1,084' FEL Sec 3 TDN R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1,444' FNL 2,683' FEL Sec 4 TDN R7E, UM 2N 343 #U-630610 At total depth 9. Approximate spud date Amount 1,496' FNL 2,273' FWL Sec 4 TDN R7E, UM 514198 $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 ARCO 2N 329 MD 9,885' 1,444' @ target feet -3,000' feet 2,560 TVD 5,385' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 71 o Maximum surface 1,958 psig At total depth (TVD) 2,550 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~lht Grade Couplincj Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 108' 108' 230 ax_+ Permafrost Cement 12¼" 9-5/8" 40 ppf L-80 BTC 2,868' 28' 28' 2,868' 2,500' 1. 60 sx AS3L, 350 sx CIG 2. 360 sx AS3L, 270 sx AS 1 8Y2" 7" 26 ppf L-80 BTC-Mod 9,074' 28' 28' 9,074' 4,775' 450 sx G 8~" 4Y2" 12.6 ppf L-80 NSCT 811' 9,074' 4,775' 9,885' 5,385' (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 Length Size Cemented Measured depth True Vertical depth : Conductor ~'"~~' ~ L ~ ~ i~ ~' surface Intermediate 8R'I ¢! N~iALL Production ' i ~;i©.;' , ,. 2/'"~" 19®Z!,~ Liner ..... Perforation depth: measured ,jum,BlSS,0r-'- true vortical Alaska 0ii & 6as Cons. ~'-', '-' } ' Anch0ra,qe 20. Attachments Filing fee X Property plat I~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fJ. uid program X Time vs depth plot I~ Refraction analysis [~ Seabed report E 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed "~_~_,jL¢) /~~_._;.~, ,1¢~/¢,.. ~tK, .~1.~/,~ Title Drill Site Development Supv. Date ~,/2!?//~ /Jif - commission use Only Perm .mber i AP, nu ,ber. I Approve' date ~... ~ .,, ~), ~::} L~ther requirements Y'~-'~2_ so-/c:>,.q'" ~o' 2.. ~"0 I see cover ~et~er for Conditions of approval Samples required [~ Yes ,,~ No Mud log required [% Yes.~ No Hydrogen sulfidemeasures [--~Yes ~ No Directional survey required j~ Yes [~ No Required working pressure for BOPE [~ 2M E~ 3M .[~ 5M [-- 1OM [~ 15M Other: byorderof D~,.,.,~ .- ~;i~ Approved by 0ri_inalg Signs0 u~, Commissioner the commission Date I"'~. _ _ __' J 'till I [ .... t .......... Form 10-401 Rev. 7-24-89 David W. Juhns[un Submit in triplicate 2N 343 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB permaffost~::::::: 1,255' MD .... :i:i:!:! .....-.. .-.-.-.- .-.-.-.. .....-.- ...-.-.- ........ ...o.o.. ...%... :!:i:i:i :i:i:i:i .... Stage Collar 1,500' MD Top of West Sak 1,258' MD Base of West Sak 2,O37' MD 9-5/8" Surface Casing at 2,868' MD Top of Cement at 8,500' MD 7,! Production Casing at 9,O74' MD 4-1/2" Production Casing at 9,885' MD ;.:.:. ;:;;::. ;:;:::. :.; ;, .:.:.: :.:.'.: ;-;-;. .:.: '.; ;.;.; -. :::::::: Hole :.:.:.:. 8~" Hole Conductor Casing Size ! Hole Size Depth: 135' MD Top of Cement Surface Excess Calculated: 100% RKB 16" in 20" hole Volume Calculations: (135 If) (0.7854 cf/10 (2.00) = 212 cf (212 cf) /(0.93 cf/sx) = 230 sx Slurry Volume: 212 cf or Arctic Set I 230 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 cf/sx Surface Casing excess 9-5/8" in 12-1/4" hole Stage 1: Volume (568 If) (0.3132 cf/If) (1.45) = 258 cf Lead (258 cf) /(4.42 cf/sx) = 58 sx Tail (800 If) (0.3132 cf/10 (1.45) = 363 cf shoe joint vol 30 sx + (363 cf) /(1.15 cf/sx) = 346 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (CIG cmt+ 1% SI(CaCI2) + 0.3% D65 (disp.) + 0.2% D46 (defeam.) Lead Slurry Volume: 258 cf or 60 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 363 cf or 350 sx Slurry Weight 15.8 ppg C/ass G Slurry Yield 1.15 cf/sx Thickening Time 3.5 - 4.5 hours Surface Casing excess Stage 2: Vol. Lead (1,255 If) (0.3132 cf/10 (4.00) = 1,572 cf (1,572 cf) /(4.42 cf/sx) = 360 sx Tail (105 If) (0.3132 cf/10 (4.00) = 132 cf (245 If) (0.3132 cf/10 (1.45) = 111 cf (243 cf) /(0.93 cf/sx) = 261 sx System: Lead (Amtic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% S1 (CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoam.) Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,572 cf or 360 sx Slurry Weight 10.5 ppg Arctic Set 3 Lite Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 243 cf or 270 sx Slurry Weight 15.7 ppg Arctic Set I Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Depth: Top of 4-1/2" casing Top of Cement Excess Calculated: BHT (Static): BHT ( Circ): Volume around 7 " (574 If) Volume around 4-1/2" (811 If) shoe joint vol 6 sx + (530 cf) System: (Class G cement + 2 gps D600 (latex) + + 0.1 D47 (defoamer) + 3% D53 (Gyp) + 0.7% Slurry Volume: 530 cf Slurry Weight 15.8 ppg Slurry Yield 1.20 cf/sx Thickening Time Size / Hole Size 9,885' 9,074' 8,500' 75% 160° F 130° F (0.1268 cf/10 (0.2836 cf/10 /(1.20 cf/sx) 7" and 4-1/2" in 8-1/2" hole (1.75) = 127 cf (1.75) = 403 cf 530 cf 447 sx 0.1 gps D135 (stabilizer) D65 (disp) + 0.15% D800 (retarder) or 450 sx Class G 3.5 - 4.5 hours 4/25/98 ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 343 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 12~'' hole to 9-5/8" surface casing point (2,868'_+ MD 2,500' TVD) according to directional plan. 4. Run and cement 9-5/8" 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. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (2,500' TVD) * (0.25 psi/fi) = 625 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (5,750 psi) = 4,025 psi 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 8Y2" hole to TD (9,074' MD 5,385' TVD) 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). 8. Run and cement 7" L-80 BTC Csg X 4Y2" L-80 NSCT tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (5.385' TVD) * (0.25 psi/fi) = 1,346 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (7,240 psi) = 5, 070 psi Maximum Test: 70% of Min. Yield Strength = (0. 70) * (8, 440 psi) = 5, 910 psi 10. Since this well is a dedicated injection welt, run cased hole cement evaluation logs to verify formation isolation. 11. Run 4½" L-80 NSCT completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 12. ND BOPE and install production tree. 2N 343 mlp, 04/27/98 --?' ARCO Alaska, Inc. '-~ 13. Shut in and secure welJ. 14. Clean location, RD and move to next well on 2N pad. Well will be left ready for perforating. AOGCC Casing Testing Regulation 20 AAC 25.030. (g) Pressure Testing of Casing and Casing Surveys. (1) with the exception of structural and conductor casing, before drilling out the casing or liner after cementing, all casing, liners, and liner laps must be tested to a surface pressure of 1500 psig, or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater; however, surface pressure must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent in 30 minutes, or if there are indications of improper cementing, such as lost returns, cement channeling, or mechanical failure of equipment, corrective measures must be taken. (2) when, in the commission's discretion, casing is subjected to prolonged actual drilling operations the casing must be pressure tested, calipered or otherwise evaluated by a method approved by the commission. (3) for injection wells, a cement bond log must be obtained following the primary cementing of all casing that is 9-5/8 inches or less in diameter, and sufficient notice of pressure tests required by (1) of this subsection must be given, so that a representative of the commission may witness the test. 2N 343 mlp, 04/27/98 ARCO Alaska, Inc. - .... DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 343 Drillincl Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.5-1 O.2 ppg 15-35 25-50 130-150* 10-25 15-40 5-7 9.5-10 _+10% Drill out to TD 9.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System- Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit 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 8½" production hole is calculated using a surface casing leak-off of 13,5 ppg EMW (0,70 psi/ft) and a gas gradient of 0,11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,475 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,500 ft)(0.70 - 0.11) = 1,475 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 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 10.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4,970'. 2N 343 mlp, 04/25/98 ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 343 is 2N 329 about 3,000' to the north. Drillinq Area Risks: The primary risk in the 2N 343 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 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 Pumpinq Ol~erations' Incidental fluids developed from drilling operations will be either injected into a nearby annulus 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 343 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 343 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) * (2,500') + 1,500 psi Max Pressure = 3,060 psi 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 2N 343 mlp, 04/25/98 . , ~' ?~ ARCO Alaska, Inc. 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 9.-5/8" 40 L-80 3 BTC 3,090 psi 2,627 psi 5,750 psi 4,888 psi 7" 26 L-80 3 BTC-M 5,410 psi 4,599 psi 7,240 psi 6,154 psi 4Y2" 12.6 L-80 3 NSCT 7,500 psi 6,375 psi 8,440 psi 7,174 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). 2N 343 mlp, 04/25/98 ARCO KRU 2N-343 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS L J 1 I- 3" 5,000 psi WP OCT ~--J MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE 1 w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP -"~k x 11" 3,000 psi WP I I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom CHOKE LINE 13-5/8" 5,000 psi WP DRILLING SPOOL h~ W/tWO 3" 5,000 psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe Diverter Schematic Doyon 141 Flowline 21 ¼" 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) 35O 350 7OO 1050 1400 1750 2100 2450 2800 3150 3500 385O 4200 4550 4900 5250 5600 RrB Elevation: 149' ................. Structure : Tarn Drill Site 2N Well : /Field : Tarn Development Field Location : North Slope, Alaska/ KOP TVD=300 TMD=300 DEP:O 3.00 6.00 DLS: 3.00 deg per 100 ft. 9.00 <- West (,teet) END INITIAL BUILD TVD=697 TMD=700 OEP=36 7650 7200 6750 6300 5850 5400 4950 4500 4050 3600 3150 2700 2250 1800 1350 900 450 0 450 Target Location: 1444' FNL, 2683' FEL Sec. 4, TgN, R7E Cont. Build / Begin Turn to Tgi...,/ Estimated Surface Location: 137' FNL, 1084' FEL Sec. 3, TgN, R?E CONT. BUILD / BEGIN TURN TO TARGET 14.59 TVD=1186 TMD=1200 DEP=127 17.31 20.11 22.96 25.84 28.74 DLS: 3.00 dog per 100 ft 31.66 34.59 37.53 40.48 43.44 49.36 55.30 9 5/8" CSG PT 61.24 TVD=2500 67.1 9 TMD=2868 DEP=1063 MAXIMUM ANGLE ? 1.23 DEG TD Location: 1496' FNL, 2273' FWL I I Sec. 4, TgN, RTE I ~~ EOC TV0=2651 TMD=3236 BEP=1398 v'"9'° 259.24 AzimuLh 7002' (TO TARGET) ***Plane of Proposal*** 450 1800 Creoted by jonee For: M PRESTRIDGE Date plotted : 2fl--Mar-g8 Plot Reference is 343 Version ~12. Coordinates are in feet reference slot ~343. J True Vertical Depths~ RK8 (Ooyon $41). 350 0 350 700 1050 1400 1750 21 O0 2450 2800 3150 3500 3850 4200 4550 4900 5250 5600 5950 6300 6650 7000 7350 7700 Vertical Section (feet) -> Azimuth 259.24 with reference 0.00 N, 0.00 E from slot #343 TARGET ANGLE 40 DEG 69.48 65.48 61.48 57.48 53.48 DLS: 2.00 dog per 100 ft 49.48 45.48 41.48 TARGET TVD=4994 TMD=9374 DEP=7002 TD / 7" CASING PT TVD=5385 TMD=9885 DEP=7330 BEGIN ANGLE DROP TVD=4123 TMD=7813 DEP=S730 450 900 1350 ARCO Alaska, Inc. Tarn Drill Site 2N 343 slot #343 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 343 Version Our ref : prop2865 License : Date printed : 25-Mar-98 Date created : 27-Feb-98 Last revised : 25-Mar-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 12.610,w150 19 4.180 Slot Grid coordinates are N 5911872.163, E 460508.582 Slot local coordinates are 136.68 S 1084.16 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N,343 Tarn Development Field, North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 343 Version #2 Last revised : 25-Mar-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 100.00 0.00 230.00 100.00 0.00 N 0.00 E 0.00 200.00 0.00 230.00 200.00 0.00 N 0.00 E 0.00 300.00 0.00 230.00 300.00 0.00 N 0.00 E 0.00 400.00 3.00 230.00 399.95 1.68 S 2.01 W 3.00 0.00 0.00 0.00 0.00 KOP 2.28 500.00 6.00 230.00 499.63 6.73 S 8.01 W 3.00 600.00 9.00 230.00 598.77 15.11 S 18.01 W 3.00 700.00 12.00 230.00 697.08 26.83 S 31.97 W 3.00 1000.00 12.00 230.00 990.53 66.92 S 79.75 W 0.00 1200.00 12.00 230.00 1186.16 93.65 S 111.61 W 0.00 9.13 20.52 36.42 End Initial Build 90.84 127.13 Cont. Build / Begin Turn to Tgt 1300.00 14.59 236.62 1283.47 107.26 S 130.09 W 3.00 1400.00 17.31 241.23 1379.62 121.36 S 153.65 W 3.00 1500.00 20.11 244.61 1474.33 135.89 S 182.23 W 3.00 1600.00 22.96 247.19 1567.34 150.83 S 215.75 W 3.00 1700.00 25.84 249.23 1658.40 166.12 S 254.11 W 3.00 147.83 173.61 204.40 240.11 280.65 1800.00 28.74 250.88 1747.26 181.73 S 297.21 W 3.00 1900.00 31.66 252.25 1833.68 197.61 S 344.93 W 3.00 2000.00 34.59 253.41 1917.42 213.72 S 397.14 W 3.00 2100.00 37.53 254.41 1998.25 230.02 S 453.70 W 3.00 2200.00 40.48 255.28 2075.95 246.46 S 514.45 W 3.00 325 375 430 488 551 .91 .76 .06 .66 .42 2300.00 43.44 256.05 2150.30 263.00 S 579.22 W 3.00 2400.00 46.40 256.75 2221.10 279.59 S 647.85 W 3.00 2500.00 49.36 257.38 2288.16 296.18 S 720.13 W 3.00 2600.00 52.33 257.95 2351.30 312.74 S 795.88 W 3.00 2700.00 55.30 258.48 2410.33 329.21 S 874.88 W 3.00 618.14 688.66 762.77 840.28 920.96 2800.00 58.27 258.98 2465.11 345.55 S 956.92 W 3.00 2868.32 60.30 259.30 2500.00 356.62 S 1014.60 W 3.00 2900.00 61.24 259.44 2515.47 361.72 S 1041.78 W 3.00 3000.00 64.22 259.88 2561.28 377.66 S 1129.21 W 3.00 3100.00 67.19 260.30 2602.42 393.34 S 1218.98 W 3.00 1004. 1063. 1090. 1179. 1270. 61 34 9 5/8" Casing Pt 99 86 99 3200.00 70.17 260.70 2638.78 408.72 S 1310.85 W 3.00 3235.62 71.23 260.83 2650.55 414.12 S 1344.04 W 3.00 3500.00 71.23 260.83 2735.61 453.99 S 1591.16 W 0.00 4000.00 71.23 260.83 2896.50 529.41 S 2058.52 W 0.00 4500.00 71.23 260.83 3057.38 604.82 S 2525.89 W 0.00 1364. 1397. 1647. 2121. 2594. 11 72 EOC 94 17 39 5000.00 71.23 260.83 3218.26 680.23 S 2993.25 W 0.00 5500.00 71.23 260.83 3379.14 755.65 S 3460.62 W 0.00 6000.00 71.23 260.83 3540.02 831.06 S 3927.98 W 0.00 6500.00 71.23 260.83 3700.90 906.48 S 4395.35 W 0.00 7000.00 71.23 260.83 3861.78 981.89 S 4862.71 W 0.00 3067.62 3540.85 4014.08 4487.30 4960.53 7500.00 71.23 260.83 4022.66 1057.31 S 5330.08 W 0.00 7812.50 71.23 260.83 4123.21 1104.44 S 5622.19 W 0.00 7900.00 69.48 260.83 4152.62 1117.57 S 5703.53 W 2.00 8000.00 67.48 260.83 4189.30 1132.39 S 5795.37 W 2.00 8100.00 65.48 260.83 4229.20 1146.99 S 5885.89 W 2.00 5433.76 5729.53 Begin Angle Drop 5811.90 5904.89 5996.54 8200.00 63.48 260.83 4272.28 1161.37 S 5974.97 W 2.00 6086.74 8300.00 61.48 260.83 4318.49 1175.50 S 6062.52 W 2.00 6175.39 8400.00 59.48 260.83 4367.76 1189.36 S 6148.43 W 2.00 6262.37 8500.00 57.48 260.83 4420.03 1202.94 S 6232.58 W 2.00 6347.58 8600.00 55.48 260.83 4475.25 1216.22 S 6314.88 W 2.00 6430.91 All data is in feet unless otherwise stated. Coordinates from slot #343 a~d TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7329.94 on azimuth 259.31 degrees from wellhead. Total Dogleg for wellpath is 104.30 degrees. Vertical section is from wellhead on azimuth 2-59.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 343 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 343 Version #2 Last revised : 25-Mar-98 Dogleg Vert Deg/100ft Sect 8700.00 53.48 260.83 4533.35 1229.18 S 6395.23 W 2.00 6512.27 8800.00 51.48 260.83 4594.25 1241.82 S 6473.53 W 2.00 6591.55 8900.00 49.48 260.83 4657.88 1254.11 S 6549.68 W 2.00 6668.66 9000.00 47.48 260.83 4724.16 1266.04 S 6623.59 W 2.00 6743.50 9100.00 45.48 260.83 4793.02 1277.59 S 6695.18 W 2.00 6815.98 9200.00 43.48 260.83 4864.36 1288.75 S 6764.34 W 2.00 6886.02 9300.00 41.48 260.83 4938.11 1299.51 S 6831.01 W 2.00 6953.52 9374.02 40.00 260.83 4994.19 1307.21 S 6878.70 W 2.00 7001.81 TARGET 9374.03 40.00 260.83 4994.20 1307.21 S 6878.71 W 2.00 7001.82 343 Rvsd 24-Mar-98 9500.00 40.00 260.83 5090.70 1320.11 S 6958.65 W 0.00 7082.76 9684.69 40.00 260.83 5232.18 1339.03 S 7075.85 W 0.00 7201.43 9884.69 40.00 260.83 5385.39 1359.51 S 7202.76 W 0.00 7329.93 TD · All data is in feet unless otherwise stated. Coordinates from slot #343 and TVD from RF~B (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7329.94 on azimuth 259.31 degrees from wellhead. Total Dogleg for wellpath is 104.30 degrees. Vertical section is from wellhead on azimuth 259.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,343 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 343 Version #2 Last revised : 25-Mar-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 700.00 697.08 26.83 S 1200.00 1186.16 93.65 S 2868.32 2500.00 356.62 S 3235.62 2650.55 414.12 S 7812.50 4123.21 1104.44 S 9374.02 4994.19 1307.21 S 9374.03 4994.20 1307.21 S 9884.69 5385.39 1359.51 S 0.00 E KOP 31.97 W End Initial Build 111.61 W Cont. Build / Begin Turn to Tgt 1014.60 W 9 5/8" Casing Pt 1344.04 W EOC 5622.19 W Begin Angle Drop 6878.70 W TARGET 6878.71 W 343 Rvsd 24-Mar-98 7202.76 W TD Casing positions in string 'A' · Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2868.32 2500.00 356.62S 1014.60W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9884.69 5385.39 1359.51S 7202.76W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 343 Rvsd 24-Mar-98 453624.000,5910600.000,0.0000 4994.20 1307.21S 6878.71W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,343 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 343 Version #2 hast revised : 25-Mar-98 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 136.68 S 1084.16 W 0.00 100.00 0.00 230.00 100.00 136.68 S 1084.16 W 0.00 200.00 0.00 230.00 200.00 136.68 S 1084.16 W 0.00 300.00 0.00 230.00 300.00 136.68 S 1084.16 W 0.00 400.00 3.00 230.00 399.95 138.36 S 1086.17 W 3.00 0.00 0.00 0.00 0.00 KOP 2.28 500.00 6.00 230.00 499.63 143.40 S 1092.18 W 3.00 600.00 9.00 230.00 598.77 151.79 S 1102.17 W 3.00 700.00 12.00 230.00 697.08 163.50 S 1116.13 W 3.00 1000.00 12.00 230.00 990.53 203.60 S 1163.91 W 0.00 1200.00 12.00 230.00 1186.16 230.33 S 1195.77 W 0.00 9.13 20.52 36.42 End Initial Build 90.84 127.13 Cont. Build / Begin Turn to Tgt 1300.00 14.59 236.62 1283.47 243.94 S 1214.25 W 3.00 1400.00 17.31 241.23 1379.62 258.04 S 1237.82 W 3.00 1500.00 20.11 244.61 1474.33 272.57 S 1266.39 W 3.00 1600.00 22.96 247.19 1567.34 287.50 S 1299.91 W 3.00 1700.00 25.84 249.23 1658.40 302.79 S 1338.27 W 3.00 147.83 173.61 204.40 240.11 280.65 1800.00 28.74 250.88 1747.26 318.40 S 1381.37 W 3.00 1900.00 31.66 252.25 1833.68 334.29 S 1429.09 W 3.00 2000.00 34.59 253.41 1917.42 350.40 S 1481.30 W 3.00 2100.00 37.53 254.41 1998.25 366.70 S 1537.86 W 3.00 2200.00 40.48 255.28 2075.95 383.14 S 1598.61 W 3.00 325.91 '375.76 430.06 488.66 551.42 2300.00 43.44 256.05 2150.30 399.68 S 1663.39 W 3.00 2400.00 46.40 256.75 2221.10 416.27 S 1732.01 W 3.00 2500.00 49.36 257.38 2288.16 432.86 S 1804.30 W 3.00 2600.00 52.33 257.95 2351.30 449.42 S 1880.04 W 3.00 2700.00 55.30 258.48 2410.33 465.89 S 1959.04 W 3.00 618.14 688.66 762.77 840.28 920.96 2800.00 58.27 258.98 2465.11 482.23 S 2041.08 W 3.00 2868.32 60.30 259.30 2500.00 493.29 S 2098.76 W 3.00 2900.00 61.24 259.44 2515.47 498.39 S 2125.94 W 3.00 3000.00 64.22 259.88 2561.28 514.34 S 2213.37 W 3.00 3i00.00 67.19 260.30 2602.42 530.02 S 2303.14 W 3.00 1004.61 1063.34 9 5/8" Casing Pt 1090.99 1179.86 1270.99 3200.00 70.17 260.70 2638.78 545.40 S 2395.01 W 3.00 3235.62 71.23 260.83 2650.55 550.79 S 2428.20 W 3.00 3500.00 71.23 260.83 2735.61 590.67 S 2675.32 W 0.00 4000.00 71.23 260.83 2896.50 666.08 S 3142.68 W 0.00 4500.00 71.23 260.83 3057.38 741.50 S 3610.05 W 0.00 1364.11 1397.72 EOC 1647.94 2121.17 2594.39 5000.00 71.23 260.83 3218.26 816.91 S 4077.41 W 0.00 5500.00 71.23 260.83 3379.14 892.33 S 4544.78 W 0.00 6000.00 71.23 260.83 3540.02 967.74 S 5012.14 W 0.00 6500.00 71.23 260.83 3700.90 1043.16 S 5479.51 W 0.00 7000.00 71.23 260.83 3861.78 1118.57 S 5946.87 W 0.00 3067.62 3540.85 4014.08 4487.30 4960.53 7500.00 71.23 260.83 4022.66 1193.98 S 6414.24 W 0.00 7812.50 71.23 260.83 4123.21 1241.12 S 6706.35 W 0.00 7900.00 69.48 260.83 4152.62 1254.25 S 6787.69 W 2.00 8000.00 67.48 260.83 4189.30 1269.06 S 6879.53 W 2.00 8100.00 65.48 260.83 4229.20 1283.67 S 6970.05 W 2.00 5433.76 5729.53 Begin Angle Drop 5811.90 5904.89 5996.54 8200.00 63.48 260.83 4272.28 1298.05 S 7059.14 W 2.00 6086.74 8300.00 61.48 260.83 4318.49 1312.17 S 7146.68 W 2.00 6175.39 8400.00 59.48 260.83 4367.76 1326.04 S 7232.59 W 2.00 6262.37 8500.00 57.48 260.83 4420.03 1339.62 S 7316.74 W 2.00 6347.58 8600.00 55.48 260.83 4475.25 1352.90 S 7399.04 W 2.00 6430.91 All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7329.94 on azimuth 259.31 degrees from wellhead. Total Dogleg for wellpath is 104.30 degrees. Vertical section is from wellhead on azimuth 259.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,343 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 343 Version #2 Last revised : 25-Mar-98 Dogleg Vert Deg/100ft Sect 8700.00 53.48 260.83 4533.35 1365.86 S 7479.39 W 2.00 6512.27 8800.00 51.48 260.83 4594.25 1378.50 S 7557.69 W 2.00 6591.55 8900.00 49.48 260.83 4657.88 1390.79 S 7633.84 W 2.00 6668.66 9000.00 47.48 260.83 4724.16 1402.72 S 7707.75 W 2.00 6743.50 9100.00 45.48 260.83 4793.02 1414.27 S 7779.34 W 2.00 6815.98 9200.00 43.48 260.83 4864.36 1425.43 S 7848.51 W 2.00 6886.02 9300.00 41.48 260.83 4938.11 1436.19 S 7915.17 W 2.00 6953.52 9374.02 40.00 260.83 4994.19 1443.89 S 7962.86 W 2.00 7001.81 TARGET . 9374.03 40.00 260.83 4994.20 1443.89 S 7962.87 W 2.00 7001.82 343 Rvsd 24-Mar-98 9500.00 40.00 260.83 5090.70 1456.79 S 8042.81 W 0.00 7082.76 9684.69 40.00 260.83 5232.18 1475.70 S 8160.01 W 0.00 7201.43 9884.69 40.00 260.83 5385.39 1496.19 S 8286.92 W 0.00 7329.93 TD All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7329.94 on azimuth 239.31 degrees from wellhead. Total Dogleg for wellpath is 104.30 degrees. Vertical section is from wellhead on azimuth 259.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,343 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref = 343 Version #2 Last revised ~ 25-Mar-98 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300.00 136.68 S 1084.16 W KOP 700.00 697.08 163.50 S 1116.13 W End Initial Build 1200.00 1186.16 230.33 S 1195.77 W Cont. Build / Begin Turn to Tgt 2868.32 2500.00 493.29 S 2098.76 W 9 5/8" Casing Pt 3235.62 2650.55 550.79 S 2428.20 W EOC 7812.50 4123.21 1241.12 S 6706.35 W Begin Angle Drop 9374.02 4994.19 1443.89 S 7962.86 W TARGET 9374.03 4994.20 1443.89 S 7962.87 W 343 Rvsd 24-Mar-98 9884.69 5385.39 1496.19 S 8286.92 W TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 136.68S 1084.16W 2868.32 2500.00 493.29S 2098.76W 9 5/8" Casing 0.00 0.00 136.68S 1084.16W 9884.69 5385.39 1496.19S 8286.92W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 343 Rvsd 24-Mar-98 453624.000,5910600.000,0.0000 4994.20 1443.89S 7962.87W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 343 Tarn Development Field,North Slope, Alaska PROPOSA~L LISTING Page 1 Your ref : 343 Version #2 Last revised : 25-Mar-98 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 230.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 230.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 230.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 3.00 230.00 399.95 1.68 S 2.01 W 2.28 1.06 1.05 0.60 50.00 500.00 6.00 230.00 499.63 6.73 S 8.01 W 9.13 1.42 1.32 0.75 50.00 600.00 9.00 230.00 598.77 15.11 S 18.01 W 20.52 1.93 1.60 0.90 50.00 700.00 12.00 230.00 697.08 26.83 S 31.97 W 36.42 2.64 1.90 1.06 50.00 1000.00 12.00 230.00 990.53 66.92 S 79.75 W 90.84 4.98 2.86 1.54 50.00 1200.00 12.00 230.00 1186.16 93.65 S 111.61 W 127.13 6.59 3.51 1.87 50.00 1300.00 14.59 236.62 1283.47 107.26 S 130.09 W 147.83 7.58 3.85 2.03 50.96 1400.00 17.31 241.23 1379.62 121.36 S 153.65 W 173.61 8.78 4.22 2.21 52.54 1500.00 20.11 244.61 1474.33 135.89 S 182.23 W 204.40 10.21 4.61 2.40 54.46 1600.00 22.96 247.19 1567.34 150.83 S 215.75 W 240.11 11.91 5.03 2.60 56.52 1700.00 25.84 249.23 1658.40 166.12 S 254.11 W 280.65 13.93 5.48 2.83 58.60 1800.00 28.74 250.88 1747.26 181.73 S 297.21 W 325.91 16.28 5.94 3.09 60.61 1900.00 31.66 252.25 1833.68 197.61 S 344.93 W 375.76 19.02 6.44 3.38 62.49 2000.00 34.59 253.41 1917.42 213.72 S 397.14 W 430.06 22.15 6.95 3.70 64.22 2100.00 37.53 254.41 1998.25 230.02 S 453.70 W 488.66 25.71 7.48 4.08 65.79 2200.00 40.48 255.28 2075.95 246.46 S 514.45 W 551.42 29.71 8.02 4.50 67.21 2300.00 43.44 256.05 2150.30 263.00 S 579.22 W 618.14 34.16 8.57 4.97 68.49 2400.00 46.40 256.75 2221.10 279.59 S 647.85 W 688.66 39.07 9.12 5.50 69.63 2500.00 49.36 257.38 2288.16 296.18 S 720.13 W 762.77 44.44 9.67 6.08 70.65 2600.00 52.33 257.95 2351.30 312.74 S 795.88 W 840.28 50.26 10.21 6.72 71.57 2700.00 55.30 258.48 2410.33 329.21 S 874.88 W 920.96 56.52 10.74 7.41 72.40 2800.00 58.27 258.98 2465.11 345.55 S 956.92 W 1004.61 63.20 11.25 8.16 73.15 2868.32 60.30 259.30 2500.00 356.62 S 1014.60 W 1063.34 68.05 11.58 8.71 73.61 2900.00 61.24 259.44 2515.47 361.72 S 1041.78 W 1090.99 70.29 11.74 8.96 73.83 3000.00 64.22 259.88 2561.28 377.66 S 1129.21 W 1179.86 77.77 12.20 9.81 74.44 3100.00 67.19 260.30 2602.42 393.34 S 1218.98 W 1270.99 85.59 12.63 10.70 75.01 3200.00 70.17 260.70 2638.78 408.72 S 1310.85 W 1364.11 93.74 13.04 11.64 75.53 3235.62 71.23 260.83 2650.55 414.12 S 1344.04 W 1397.72 96.68 13.17 11.97 75.70 3500.00 71.23 260.83 2735.61 453.99 S 1591.16 W 1647.94 118.60 14.18 14.50 76.69 4000.00 71.23 260.83 2896.50 529.41 S 2058.52 W 2121.17 160.28 16.04 19.31 77.81 4500.00 71.23 260.83 3057.38 604.82 S 2525.89 W 2594.39 202.10 17.88 24.14 78.45 5000.00 71.23 260.83 3218.26 680.23 S 2993.25 W 3067.62 244.00 19.70 28.98 78.87 5500.00 71.23 260.83 3379.14 755.65 S 3460.62 W 3540.85 285.93 21.51 33.83 79.16 6000.00 71.23 260.83 3540.02 831.06 S 3927.98 W 4014.08 327.88 23.31 38.67 79.38 6500.00 71.23 260.83 3700.90 906.48 S 4395.35 W 4487.30 369.85 25.12 43.52 79.55 7000.00 71.23 260.83 3861.78 981.89 S 4862.71 W 4960.53 411.83 26.92 48.38 79.68 7500.00 71.23 260.83 4022.66 1057.31 S 5330.08 W 5433.76 453.82 28.72 53.23 79.79 7812.50 71.23 260.83 4123.21 1104.44 S 5622.19 W 5729.53 480.07 29.85 56.26 79.85 7900.00 69.48 260.83 4152.62 1117.57 S 5703.53 W 5811.90 487.27 30.18 57.10 79.86 8000.00 67.48 260.83 4189.30 1132.39 S 5795.37 W 5904.89 495.30 30.58 58.02 79.88 8100.00 65.48 260.83 4229.20 1146.99 S 5885.89 W 5996.54 503.11 31.01 58.92 79.89 8200.00 63.48 260.83 4272.28 1161.37 S 5974.97 W 6086.74 510.68 31.45 59.80 79.91 8300.00 61.48 260.83 4318.49 1175.50 S 6062.52 W 6175.39 518.01 31.92 60.64 79.92 8400.00 59.48 260.83 4367.76 1189.36 S 6148.43 W 6262.37 525.08 32.40 61.45 79.93 8500.00 57.48 260.83 4420.03 1202.94 S 6232.58 W 6347.58 531.88 32.90 62.23 79.94 8600.00 55.48 260.83 4475.25 1216.22 S 6314.88 W 6430.91 538.40 33.41 62.98 79.95 All data is in feet unless otherwise stated. Coordinates from slot #343 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7329.94 on azimuth 259.31 degrees from wellhead. Vertical section is from wellhead on azimuth 259.24 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,343 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 343 Version #2 Last revised : 25-Mar-98 Comments in wellpath :m MD TVD Rectangular Coords. Comment 300.00 300.00 0.00 N 0.00 E KOP 700.00 697.08 26.83 S 31.97 W End Initial Build 1200.00 1186.16 93.65 S 111.61 W Cont. Build / Begin Turn to Tgt 2868.32 2500.00 356.62 S 1014.60 W 9 5/8" Casing Pt 3235.62 2650.55 414.12 S 1344.04 W EOC 7812.50 4123.21 1104.44 S 5622.19 W Begin Angle Drop 9374.02 4994.19 1307.21 S 6878.70 W TARGET 9374.03 4994.20 1307.21 S 6878.71 W 343 Rvsd 24-Mar-98 9884.69 5385.39 1359.51 S' 7202.76 W TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2868.32 2500.00 356.62S 1014.60W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9884.69 5385.39 1359.51S 7202.76W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 343 Rvsd 24-Mar-98 453624.000,5910600.000,0.0000 4994.20 1307.21S 6878.71W 6-Aug-97 A~CO Alaska, Inc. Tarn Drill Site 2N,343 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 343 Version #2 Last revised : 25-Mar-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 460508.58 5911872.16 100.00 0.00 230.00 100.00 0.00N 0.00E 0.00 0.00 460508.58 5911872.16 200.00 0.00 230.00 200.00 0.00N 0.00E 0.00 0.00 460508.58 5911872.16 300.00 0.00 230.00 300.00 0.00N 0.00E 0.00 0.00 460508.58 5911872.16 400.00 3.00 230.00 399.95 1.68S 2.01W 3.00 2.28 460506.57 5911870.49 500.00 6.00 230.00 499.63 6.73S 8.01W 3.00 9.13 460500.53 5911865.48 600.00 9.00 230.00 598.77 15.11S 18.01W 3.00 20.52 460490.49 5911857.14 700.00 12.00 230.00 697.08 26.83S 31.97W 3.00 36.42 460476.48 5911845.50 1000.00 12.00 230.00 990.53 66.92S 79.75W 0.00 90.84 460428.50 5911805.66 1200.00 12.00 230.00 1186.16 93.65S 111.61W 0.00 127.13 460396.51 5911779.09 1300.00 14.59 236.62 1283.47 107.26S 130.09W 3.00 147.83 460377.96 5911765.57 1400.00 17.31 241.23 1379.62 121.36S 153.65W 3.00 173.61 460354.33 5911751.60 1500.00 20.11 244.61 1474.33 135.89S 182.23W 3.00 204.40 460325.68 5911737.21 1600.00 22.96 247.19 1567.34 150.83S 215.75W 3.00 240.11 460292.09 5911722.45 1700.00 25.84 249.23 1658.40 166.12S 254.11W 3.00 280.65 460253.66 5911707.35 1800.00 28.74 250.88 1747.26 181.73S 297.21W 3.00 325.91 460210.49 5911691.97 1900.00 31.66 252.25 1833.68 197.61S 344.93W 3.00 375.76 460162.69 5911676.33 2000.00 34.59 253.41 1917.42 213.72S 397.14W 3.00 430.06 460110.40 5911660.48 2100.00 37.53 254.41 1998.25 230.02S 453.70W 3.00 488.66 460053.77 5911644.47 2200.00 40.48 255.28 2075.95 246.46S 514.45W 3.00 551.42 459992.94 5911628.34 2300.00 43.44 256.05 2150.30 263.00S 579.22W 3.00 618.14 459928.09 5911612.13 2400.00 46.40 256.75 2221.10 279.59S 647.85W 3.00 688.66 459859.39 5911595.89 2500.00 49.36 257.38 2288.16 296.18S 720.13W 3.00 762.77 459787.02 5911579.67 2600.00 52.33 257.95 2351.30 312.74S 795.88W 3.00 840.28 459711.20 5911563.50 2700.00 55.30 258.48 2410.33 329.21S 874.88W 3.00 920.96 459632.13 5911547.43 2800.00 58.27 258.98 2465.11 345.55S 956.92W 3.00 1004.61 459550.01 5911531.51 2868.32 60.30 259.30 2500.00 356.62S 1014.60W 3.00 1063.34 459492.28 5911520.74 2900.00 61.24 259.44 2515.47 361.72S 1041.78W 3.00 1090.99 459465.09 5911515.77 3000.00 64.22 259.88 2561.28 377.66S 1129.21W 3.00 1179.86 459377.58 5911500.27 3100.00 67.19 260.30 2602.42 393.34S 1218.98W 3.00 1270.99 459287.74 5911485.05 3200.00 70.17 260.70 2638.78 408.72S 1310.85W 3.00 1364.11 459195.80 5911470.14 3235.62 71.23 260.83 2650.55 414.12S 1344.04W 3.00 1397.72 459162.59 5911464.91 3500.00 71.23 260.83 2735.61 453.99S 1591.16W 0.00 1647.94 458915.30 5911426.30 4000.00 71.23 260.83 2896.50 529.41S 2058.52W 0.00 2121.17 458447.60 5911353.26 4500.00 71.23 260.83 3057.38 604.82S 2525.89W 0.00 2594.39 457979.91 5911280.23 5000.00 71.23 260.83 3218.26 680.23S 2993.25W 0.00 3067.62 457512.21 5911207.19 5500.00 71.23 260.83 3379.14 755.65S 3460.62W 0.00 3540.85 457044.51 5911134.16 6000.00 71.23 260.83 3540.02 831.06S 3927.98W 0.00 4014.08 456576.82 5911061.12 6500.00 71.23 260.83 3700.90 906.48S 4395.35W 0.00 4487.30 456109.12 5910988.09 7000.00 71.23 260.83 3861.78 981.89S 4862.71W 0.00 4960.53 455641.43 5910915.06 7500.00 71.23 260.83 4022.66 1057.31S 5330.08W 0.00 5433.76 455173.73 5910842.02 7812.50 71.23 260.83 4123.21 1104.44S 5622.19W 0.00 5729.53 454881.42 5910796.37 7900.00 69.48 260.83 4152.62 1117.57S 5703.53W 2.00 5811.90 454800.01 5910783.66 8000.00 67.48 260.83 4189.30 1132.39S 5795.37W 2.00 5904.89 454708.11 5910769.31 8100.00 65.48 260.83 4229.20 1146.99S 5885.89W 2.00 5996.54 454617.53 5910755.17 8200.00 63.48 260.83 4272.28 1161.37S 5974.97W 2.00 6086.74 454528.38 5910741.24 8300.00 61.48 260.83 4318.49 1175.50S 6062.52W 2.00 6175.39 454440.77 5910727.56 8400.00 59.48 260.83 4367.76 1189.36S 6148.43W 2.00 6262.37 454354.80 5910714.14 8500.00 57.48 260.83 4420.03 1202.94S 6232.58W 2.00 6347.58 454270.59 5910700.99 8600.00 55.48 260.83 4475.25 1216.22S 6314.88W 2.00 6430.91 454188.23 5910688.12 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #343 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7329.94 on azimuth 259.31 degrees from wellhead. Total Dogleg for wellpath is 104.30 degrees. Vertical section is from wellhead on azimuth 259.24 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 27, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 Re: Application for Permit to Drill KRU 2N 343 Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N 343, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. Because of an early thaw this year on the North Slope, the drilling order of the wells is in a state of flux. We are trying to optimize rig moves on the pad while balancing the Geology Department requests with our overall directional development plan. Moving back and forth on the pad is challenging under the present circumstances. This well required a spacing exception. That exception was filed April 14, 1998. The well can be accessed via a new gravel road from 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) and 20 AAC 25.061. 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, or will be hauled to a permitted Class II disposal well in the KRU. 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, which is similar in depth to the Kuparuk 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. R ECE!VED ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company ~., i-. ~7 1998 ~aska 0il & 6as 00ns. C0mrnissi0:n Anch0ra.cle David W. Johnst°n .... Application for Permit to Drill Page 2 KRU 2N-343 The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) 2) Geologic Data / Logs (20 AAC 25.071) Fred Johnson, Drilling Engineer 265-1492 Doug Hastings, Geologist 265-6967 If you have questions or require additional information, please contact Fred Johnson at the number above or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments KRU 2N-343 Well File CC: Alaska Oii& ~as 00r_.,s. O01ii~JSSJO~ Anohoraoo ADMINISTRATION_ APPR DA1 [: WELL PERMIT CHECKLIST COMPANY..~_~_(..,.O I 2 3 4 5 6 7 8 9 10 11 12 1:~ I easE, I~Llllll'~ef aplhropllate Urfique well name and numbe~ Well located in a defined pool ......... Well located ploper distance from drilling unit boundary. Well located proper distance from other wells Sufficient acreage available in drilling unit If dewaled, is wellbore plat included Operalor orfly affected pady. ()peralor has appropriate bond ir~ force Pern~il can be issued wilhout conse~alion order ~'ermit can be issued wilhout administrative approval (:;~ ~.~d be approved before 15-day wait WEtI_ NAME . '..~.~? ~..~' PROGRAM: exp [] dev E1 redrll [] serv l"] wellbore segl ann d,sposal para .,//__ _..%,,~,,/ _ GEOL AREA T'~ [.INI'I'# _F_~_~..Y/, _,,~- ./~'"~"'~ _.__ ~ ON/OFF StlORE .... ~,.,~/.. y~~j).,~_' ~ ....... ,.,~ .... _.~-~._~~ ./~'~:,'~ZEMA-/RKS ~/~ ~ ENGINEERING 14 15 16 17, 18. 19 (~i:(.)['lr. jl. JCtOf string provided . . S~rface casing protects all known USDWs. . crd]' vol adequale Io circulate on conductor & surf csg. crv1 I' vol adeqL,ate lo tie-in long string to surf csg N(~) .................................................................................................................................................... crvll will cover' all known productive horizons... Casing designs adequate for C, -I'~ B & permafrost Adequate tankage or reserve pit ........... If a ~e..drill. has a 10-403 for abandonment been approved. e .................... 20 21 22 Ach:;cluate wellbole separation proposed, . . 23 If diveder reqLdred, does it meel regulations . 24 [)tilling fluid program ,~;chemalic 8, eq~lip list adequale 25 ['J( )[ '[:: r,. do II~ey meet regulatio~l 2(i B('.)[)[-- pless raling appropriate: lesl lo 27 C'hoke manifold complies w/APl RP-53 (May 84) 28 Work will occur withoul operalion shutdown. 2fl I,'; i~reseime of t l:.S gas probable. _.psi!.] GEOLOGY .................................................................................. / ..................................................................................................................................... ' ~ 30 Permit ?,a~n be issued w/o hydrogen sulfide measures Y~'J~N 31.) Data pr6senled on potential overpressu,'e ZO,leS 3L Selsmic analysis ol shallow gas zones, ~ Y N 33 Seabed condition stn~ey (if ~ff-shore) .... ~ . Y N A~I&R D¢"I[¢ ~ 3,1 (':o,da(:t ~]a,~e/phone for we~klyprogress re[)qrts / Y N . · .:, .: : : ::... ,. ,, r,:..:: :.:,~: ' :' : '.:.'::-.:' -:: :':-::.. =:::;.~:~-¢ ............... ,.~..~:.:~.%.~_~-:.%..%::-~ , . :. GEO[ C)GY RP~. ENGINEERING COMMISSION B E W~~/':~ DWJ Comments/Instructions: 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 Wed Aug 26 15:51:38 1998 Reel Header Service name ............. LISTPE Date ..................... 98/08/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/08/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT / TARN POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-80223 M. GABEL B. MORRISSON 2N-343 501032026000 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 26-AUG- 98 MWD RUN 2 AK-MM-80223 M. GABEL D. BURLEY 3 09N 07E 137 1084 148.80 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 147.30 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 3338.0 8.500 9631.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. THIS DATA REPLACES PREVIOUSLY DISTRIBUTED ONE (BC#:1004006094 AND DISTRIBUTED ON J-OLY 1, 1998) . SBD2 AND SC02 DATA IS REPROCESSED FOR A CALIBRATION PROBLEM. 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZIED LITHO DENSITY (SLD) . 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9631'MD, 5486'TVD. SROP = SMOOTHED ttATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT tlATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: FIXED HOLE SIZE: MUD WEIGHT: MUD FILTRATE SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ 8.8 - 10.1 PPG. 800 - 1000 CL- PPM. 19149 Ch- PPM. 1. o 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 ....... 98/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP DRHO RHOB PEF FCNT NCNT NPHI FET RPD RPM RPS RPX $ Comment Record FILE HEADER FILE N-UMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH 84 0 118 0 3344 0 3344 0 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 84.0 2386 5 2401 2425 2427 2441 2454 2633 2637 2647 2657 2734 2773 2775 2784 2786 2788 2962 2998 3036 GR 85 0 2387 5 2401 5 2428 0 2428 5 2444 5 2453 5 2631 5 2635 5 2648 5 2658 5 2735 5 2776 5 2777 5 2786 5 2787 5 2790 0 2955 0 2992 0 3036 0 STOP DEPTH 9602 0 9642 5 9590 5 9590 5 9591 0 9582 0 9582 0 9582 0 9575 0 9575 0 9575 0 9575 0 9575 0 EQUIVALENT UNSHIFTED DEPTH -- 3063 3074 3090 3114 3130 3201 3205 3327 3341 3349 3380 3387 3391 3563 3569 3592 3594 3595 3599 3605 3607 3613 3618 3652 3662 3671 3683 3685 3686 3689 3693 3699 3702 3712 3720 3722 3724 3726 3757 3761 3764 3766 3773 3776 3780 3783 3788 3791 3793 3796 3798 3801 3805 3808 3835 3861 3869 3O58 3068 3084 3108 3125 3200 3204 3323 3336 3349 3378 3384 3387 3560 3566 3591 3593 3594 3595 3605 3607 3612 3617 3651 3662 3670 3677 3678 3684 3686 3690 3695 3698 3711 3716 3719 3720 3722 3756 3758 3759 3761 3766 3773 3777 3780 3785 3788 3791 3792 3794 3797 3801 3804 3830 3855 3863 3871 3875 3883 3889 3894 3898 3901 3954 3956 3958 3960 3970 3974 3978 3989 3997 4011 4015 4018 4036 4039 4043 4056 4063 4066 4440 4442 4444 4446 4452 4637 4640 4644 4648 4673 4677 4680 4710 4711 4743 4746 4747 4749 4767 4769 4783 4790 4792 4809 4817 5019 5023 5025 5027 5205 5209 5211 3867 0 3872 0 3879 0 3884 0 3890 5 3895 0 3898 5 3950 0 3951 5 3954 5 3956 0 3963 0 3969 0 3974 0 3987 0 3992 5 4005 5 4012 0 4014 0 4031 0 4035 0 4038.0 4051 5 4061 0 4063 0 4434 0 4438 0 4440 0 4441 5 4449 5 4632 5 4634 0 4636 5 4640 0 4667 0 4671 0 4673 0 4704 5 4705 0 4737 0 4740 5 4742 5 4744 0 4761 0 4763 5 4775 0 4784 0 4784 5 4802 5 4812 0 5013 5 5017 0 5018 5 5021 0 5200 5 5202 5 5205 0 5213 5333 5710 5712 5728 5731 5750 5778 5807 5810 5813 5820 6275 6315 6323 6326 6367 6421 6423 6425 6446 6459 6463 6471 6474 6482 6506 6518 6521 6523 6526 6528 6530 6535 6545 6568 6571 6576 6586 6589 6594 6641 6646 6650 6664 6678 6680 6683 6716 6727 6730 6732 6788 6806 6809 6812 6826 5207 5330 5704 5706 5721 5724 5746 5770 5800 5802 5805 5815 6264 6306 6316 6317 6361 6415 6418 6421 6439 6451 6455 6464 6469 6477 6497 6512 6514 6516 6519 6521 6523 6528 6536 6560 6564 6570 6580 6582 6586 6632 6638 6643 6658 6671 6673 6675 6710 6721 6724 6727 6780 6799 6802 6803 6818 6843 5 6892 0 6898 5 6901 5 7078 0 7082 0 7083 5 7672 0 7677 5 7680 5 7959 5 7962 0 8011 5 8017 0 8020 0 8328 0 8330 5 8332 0 8388 0 8397 5 8410 5 8414 5 8430 5 8433 0 8437 0 8439 5 8447 5 8455 5 8469 0 8472 0 8474 0 8563 0 8566 0 8573 0 8576 0 8584 5 8589 0 8641 5 8651 0 8668 0 8670 5 8673 0 8780 5 8786 0 8790 5 8795 0 8834 0 8837 5 8880 5 8887 5 8890 5 8893 0 8897 0 8908 0 8910 5 8913 5 8959 0 6837 6885 6891 6893 7071 7073 7076 7663 7668 7671 7948 7949 8001 8006 8010 8318 8320 8322 8378 8388 8401 8404 8422 8424 8429 8432 8439 8447 8463 8465 8466 8555 8557 8565 8569 8576 8579 8634 8642 8660 8662 8665 8776 8782 8786 8792 8826 8829 8872 8878 8880 8882 8888 8899 8901 8903 8950 8960 8962 9039 9041 9045 9047 9053 9057 9058 9063 9110 9114 9116 9127 9130 9133 9134 9145 9148 9153 9156 9251 9254 9257 9266 9269 9341 9342 9348 9351 9356 9365 9367 9372 9377 9385 9391 9392 9399 9402 9403 9508 9642 $ 0 5 0 5 0 0 5 0 5 0 0 0 0 0 5 5 5 5 5 5 5 5 0 0 0 0 0 5 0 0 0 0 5 5 5 0 5 5 5 0 5 0 5 MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 8951.5 8954.0 9029.0 9032.0 9034.5 9037 0 9042 5 9046 0 9049 0 9053 0 9100 5 9102 5 9104 5 9117 0 9118 0 9121 5 9123 0 9133 5 9135 5 9140 5 9142 0 9240 0 9243 5 9246 0 9254 5 9257 0 9331 5 9333 0 9336 5 9344 0 9350 0 9355 0 9358 0 9362 0 9369 0 9376 5 9381 0 9382 5 9389 5 9392 0 9393 5 9497 5 9632 0 BIT RUN NO MERGE TOP MERGE BASE 1 119.0 3350.0 2 3350.0 9632.0 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 DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 PEF MWD BARi~ 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 84 9642.5 ROP 9.883 2416.76 GR 7.5941 252.69 RPX 1.0687 46.2055 RPS 1.0907 40.6364 RPM 1.11 67.5938 RPD 1.0852 94.1898 FET 0.3174 55.374 NPHI 16.958 63.3312 NCNT 2218.12 3773.71 FCNT 453 1034.21 PEF 0.7087 4.4882 RHOB 1.839 3.088 DRHO -0.172 0.689 Mean Nsam 4863.25 19118 216.428 19050 107.657 19037 4.66558 12450 4.86393 12450 4.96762 12450 5.14549 12450 0.781123 12450 40.8476 12464 2750.8 12464 599.702 12464 1.52338 12482 2.37118 12494 0.0754927 12494 First Reading 84 118 84 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 3350 5 3344 3344 Last Reading 9642.5 9642.5 9602 9575 9575 9575 9575 9575 9582 9582 9582 9591 9590.5 9590.5 First Reading For Entire File .......... 84 Last Reading For Entire File ........... 9642.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/26 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 ....... 98/08/26 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 85.0 ROP 119.0 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ 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) : STOP DEPTH 3317.5 3350.5 09-MAY-98 ISC 5.07 CIM 5.46 MEMORY 3350.0 119.0 3350.0 .3 63.3 TOOL NUMBER P1014CG8 12.250 12.3 LSND 10.30 68.0 9.0 80O FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3ITURE (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 4.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 34.5 First Name Min Max Mean Nsam Reading DEPT 85 3350.5 1717.75 6532 85 GR 7.5941 160.337 81.2542 6466 85 ROP 9.883 1844.06 194.883 6464 119 Last Reading 3350.5 3317.5 3350.5 First Reading For Entire File .......... 85 Last Reading For Entire File ........... 3350.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/26 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 ....... 98/08/26 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR DRHO RHOB ROP PEF FCNT 3315 0 3341 0 3341 0 3345 0 3350 0 3350 0 NCNT 3350 0 NPHI 3350 0 FET 3350 0 RPD 3350.0 RPM 3350.0 RPS 3350.0 RPX 3350.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON STOP DEPTH 9591 5 9580 0 9580 0 9632 0 9580 5 9571 5 9571 5 9571 5 9564 5 9564 5 9564 5 9564 5 9564 5 14 -MAY- 98 ISC 5.07 CIM 5.46 MEMORY 9632.0 3350.0 9632.0 43.5 65.0 TOOL NTJMBER P0972CRNLG6 P0972CP~NLG6 P0972CRNLG6 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 TERMPEP~ATURE: 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 P0972CRNLG6 8.500 8.5 LSND 10.00 89.0 8.5 1000 4.6 4.000 2 . 611 2.700 3.000 53.9 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 FCNT MWD 2 CNTS 4 1 68 32 9 NCNT MWD 2 CNTS 4 1 68 36 10 PEF MWD 2 BARN 4 1 68 40 11 NPHI MWD 2 P.U. 4 1 68 44 12 RHOB MWD 2 G/CC 4 1 68 48 13 DRHO MWD 2 G/CC 4 1 68 52 14 Name Min Max DEPT 3315 9632 GR 40.7404 252.69 RPX 1.0687 46.2055 RPS 1.0907 40.6364 RPM 1.11 67.5938 RPD 1.0852 94.1898 ROP 22.058 2416.76 FET 0.3174 55.374 FCNT 453 1034.21 NCNT 2218.12 3773.71 PEF 0.7087 4.4882 NPHI 16.958 63.3312 RHOB 1.839 3.088 DRHO -0.172 0.689 Mean Nsam 6473.5 12635 121.389 12554 4.66618 12430 4.86408 12430 4.96303 12430 5.13807 12430 227.899 12575 0.780033 12430 599.653 12444 2750.26 12444 1.52194 12462 40.8655 12444 2.37049 12479 0.0755905 12479 First Reading 3315 3315 3350 3350 3350 3350 3345 3350 3350 3350 3350 3350 3341 3341 Last Reading 9632 9591.5 9564.5 9564.5 9564.5 9564.5 9632 9564.5 9571.5 9571.5 9580.5 9571.5 9580 9580 First Reading For Entire File .......... 3315 Last Reading For Entire File ........... 9632 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/08/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/08/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Physical EOF Physical EOF End Of LIS File COMPANY NAi~E : ARCO, ALASKA INC. WELL NAM~ : KRU 2N-343 FIELD NAlViE : TARN POOL BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 50-103-20260-00 REFERENCE NO : 98243 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUN-1998 09:12 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/12 ORIGIN : FLIC REEL NAME : 98243 CONTINUATION # : PREVIOUS REEL : COAE4ENT : ARCO ALASKA INC, KRU 2N-343, TARN POOL, API #50-103-20260-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/06/12 ORIGIN : FLIC TAPE NAME : 98243 CONTINUATION # : 1 PREVIOUS TAPE '. CO~MENT : ARCO ALASKA INC, KRU 2N-343, TARN POOL, API #50-103-20260-00 TAPE HEADER TARN POOL OPEN HOLE WIRELINE 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 O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD iST STRING 2ND STRING KRU 2N-343 501032026000 ARCO, Alaska inc. SCHLU~iBERGER WELL SERVICES 12-JUN-98 RUN 1 98243 DANIEL PALME DAVE BURLEY RUN 2 RUN 3 .......... 3 9N 7E 89 88O 148.80 147.30 120.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 3338.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUN-1998 09:12 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE MODIFIED LDWG FORMATTED OPENHOLE EDIT ON ARCO ALASKA'S KRU 2N-343 WELL. TOOLS RUN INCLUDE DIPOLE SONIC, FORMATION MICROSCANNER , CO~IBINABLE MAGNETIC RESONANCE TOOL, AND PLATFORM EXPRESS. THE DIPOLE SONIC GA~ff4A RAY IS THE PRIMARY DEPTH CONTROL LOG. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SU~4~zARY LDWG TOOL CODE START DEPTH DAS 9640.0 FMS 9641.0 SDN 9461.0 CNT 9452.0 ~ 9404.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 9434.0 9416.0 9404.0 9392.0 9390.0 9378.5 9371.5 9368.5 9366.5 9356.0 STOP DEPTH 2344.0 3340.0 8274.0 8274.0 8893.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... SDN/CNT .............. 88887.5 88899.0 9433.5 9416.0 9404.0 9391.5 9388.5 9378.0 9371.5 9367.5 9377.5 9367.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUN-19~09:12 PAGE: 9348 5 9344 0 9332 0 9324 5 9309 0 9308 5 9305 5 9303 0 9300 0 9299 0 9285 0 9282 0 9275.5 9267.5 9265.0 9258.5 9256.5 9251.0 9245.5 9230.0 9225.0 9222.0 9219.5 9213.0 9204.0 9191.5 9184.0 9172.5 9169.0 9168.0 9165.5 9156.5 9151.5 9150.0 9149.0 9142.5 9129.5 9129.0 9127.0 9123.0 9113.0 9092.0 9091.5 9085.0 9083.0 9074.0 9071.0 9059.5 9056.5 9048.5 9046.5 9045.0 9031.0 9027.5 9024.5 9350.0 9343.5 9331.5 9309.0 9305.0 9302.0 9298.0 9285.0 9281.0 9276.0 9266.0 9257.5 9252.0 9246.0 9230. 5 922 6.0 9223.5 9213.0 9206.0 9174.0 9169.0 9165.5 9157.5 9153.0 9148.5 9143.0 9130.0 9127.5 9124.0 9113.5 9092.0 9083.0 9074.5 9072.0 9056.5 9047.0 9045.0 9026.5 9336.0 9319.5 9309.0 9276.0 9266.5 9226.5 9197.5 9189.5 9172.5 9151.5 9130.5 9113.5 9091.0 9084.5 9057.0 9054.5 9044.5 9028.0 9021.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16_JUN_19 '~-8~0 9 :12 PAGE: 9021.0 9010.0 8990.0 8963.0 8961.0 8960.5 8951.5 8948.5 8944.5 8936.5 8931.5 8918.0 8916.5 8914.0 8911.5 8908.0 8896.0 8884.5 8879.5 8866.0 8853.0 8841.5 8838.0 8816.5 8809.5 8802.0 8795.0 8792 0 8790 0 8783 0 8774 0 8768 5 8760 0 8758 5 8741 0 8733 5 8730 5 8707 0 8694 0 8680 0 8670 0 8651 0 8647 5 8642 0 8633 5 8617 5 8607 0 8580 5 8573 0 8571 0 8566.5 8556.5 8552.0 8541.5 8515.5 9020.0 9009.5 8989.5 8960.0 8951.5 8944.0 8930.5 8917.5 8915.0 891 O. 0 8883.0 8878.5 8867.0 8852.0 8840.5 8837.0 8817.0 8809.0 8801.5 8795.0 8792.5 8789.5 8783.0 8773.5 8768.0 8761.0 8758.5 8740.0 8733.0 8730.0 8706.0 8692.5 8680.5 8670.5 8651.5 8648.5 8642.0 8633.5 8618.0 8607.5 8581.5 8573.5 8571.0 8566.0 8557.0 8553.0 8541.5 8517.0 8960.0 8958.5 8945.0 8934.0 891 O. 5 8904.5 8894.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUN-1998 09:12 PAGE: 8501.0 8502.0 8478.0 8479.0 8470.5 8472.0 8454.0 8456.0 8451.0 8451.5 8442.0 8442.5 8438.5 8440.0 8419.0 8420.0 8415.5 8416.5 8412.5 8414.0 8410.5 8410.5 8396.5 8397.0 8392.5 8393.0 8385.5 8385.5 8358.5 8359.0 8339.5 8340.5 8318.0 8318.5 8303.5 8304.5 8295.5 8297.0 8289.5 8290.5 8284.5 8284.0 100.0 99.5 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 98.0 RUN NO. PASS NO. ............... M~RGE TOP FiERGE BASE THIS FILE CONTAINS THE MODIFIED LDWG FORMATTED OPENHOLE DATA. THE DIPOLE SONIC GAM~A RAY WAS USED AS THE PRIMARY DEPTH CONTROL LOG. THE DIPOLE SONIC AND FORMATION MICROSCANNER WERE LOGGED IN COM~INATION. THE PLATFORM EXPRESS AND COMBINABLE MAGNETIC RESONANCE TOOL WERE LOGGED IN COMBINATION. THE PLATFORM EXPRESS AND C?4R HAVE BEEN DEPTH CORRECTED TO THE DIPOLE SONIC GAMMA RAY. ALL CURVES HAVE BEEN CLIPPED OF INVALID DATA BEFORE FIRST READING AND AFTER LAST READING. THIS DATA HAS NOT BEEN CLIPPED TO ISOLATE OPENHOLE LOGS FROM CASED HOLE LOGS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUN-1998 09:12 PAGE TYPE REPR CODE VALUE 73 66 66 73 65 172 1 0.5 FT 5 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 GR DAS GAPI 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 SP DAS MV 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 FIRES DAS 0H~1116994 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 MTE~DAS DEGF 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 C13 FMS IN 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 C24 FMS IN 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 DEV FMS DEG 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 AZ FMS DEG 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 FMS DEG 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 GR PEX GAPI 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1116994 O0 000 O0 0 1 1 i 4 68 0000000000 FCNT CNT CPS 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 DEV SDN DEG 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 1116994 O0 000 O0 0 I 1 1 4 68 0000000000 CALl SDN IN 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN 0P~4~1116994 O0 000 O0 0 1 1 1 4 68 0000000000 FiNOR SDN 0H~941116994 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUN-1998 09:12 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD N73F~ SAMP ELEM CODE (HEX) MSFL SDN 0H~41116994 O0 000 O0 0 1 1 1 4 68 0000000000 TC~R C~R 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 BFV C~R 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CFF3 ~ 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CFF4 CFIR 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CFF5 ~ 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CFF6 C~R 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 CMFF C~R 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 C~RP C~R 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 KDSR C~R ~iD 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 KTIMCFiR f~D 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 T2LMC~R 1116994 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9641.000 GR.DAS -999.250 SP.DAS -999.250 FIRES.DAS TEND.DAS -999.250 MTE~.DAS -999.250 TENS.DAS -999.250 DT.DAS DTSH.DAS -999.250 SCRA.DAS -999.250 Cl3.FMS 9.436 C24.FMS DEV. FMS 45.190 AZ.FMS 271.230 RB1.FMS 323.225 GR.PEX CNTC. CNT -999.250 CFTC. CNT -999.250 CRAT. CNT -999.250 NRAT. CNT FCNT. CNT -999.250 NCNT. CNT -999.250 DEV. SDN -999.250 NPHI.CNT CPHI.CNT -999.250 CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN RHOB.SDN -999.250 MINV. SDN -999.250 FiNOR.SDN -999.250 MSFL.SDN TC~R.~ -999.250 BFV. Cl~R -999.250 CFF3.CFiR -999.250 CFF4.C~2~ CFFS.CFiR -999.250 CFF6. C~iR -999.250 CMFF. C~IR -999.250 C~RP.~ KDSR.C~R -999.250 KTIM. C~IR -999.250 T2LM. C~R -999.250 DEPT. 2344.000 GR.DAS 46.504 SP.DAS -999.250 f4RES.DAS TEND.DAS -999.250 MT~.DAS -999.250 TENS.DAS 2294.000 DT.DAS DTSH.DAS -999.250 SCRA.DAS -999.250 Cl3.FMS -999.250 C24.FMS DEV. FMS -999.250 AZ.FMS -999.250 RB1.FMS -999.250 GR.PEX CNTC. CNT -999.250 CFTC. CNT -999.250 CRAT. CNT -999.250 NRAT. CNT FCNT. CNT -999.250 NCNT. CNT -999.250 DEV. SDN -999.250 NPHI.CNT CPHI.CNT -999.250 CAL1.SDN -999.250 DRHO. SDN -999.250 PEF. SDN RHOB.SDN -999.250 MINV. SDN -999.250 A~VOR.SDN -999.250 MSFL.SDN TCMR.~ -999.250 BFV. CMR -999.250 CFF3.C~R -999.250 CFF4.C~R CFFS.CFiR -999.250 CFF6.C~4R -999.250 CMFF. C~IR -999.250 C~i~P.~ KDSR.C~R -999.250 KTIM. ClVlR -999.250 T2LM. C~IR -999.250 -999.250 -999.250 9.218 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-JUN-1998 09:12 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 98/06/12 ORIGIN .. FLIC TAPE NAME : 98243 CONTINUATION # : 1 PREVIOUS TAPE : CO~k4ENT : ARCO ALASKA INC, KRU 2N-343, TARN POOL, API #50-103-20260-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/06/12 ORIGIN : FLIC REEL NAME : 98243 CONTINUATION # PREVIOUS REEL : COGENT : ARCO ALASKA INC, KRU 2N-343, TARN POOL, API #50-103-20260-00