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Home My WebLink About198-037Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~ ~- ~ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA D Diskettes, No. [] Other, No/Type 'OVERSIZED [::] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha n Lowell Date: ~/~.~ /si ~. TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Isl K • STATE OF ALASKA ALA ,OIL AND GAS CONSERVATION COMI1, iION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other r Resin packer After Casing r Pull Tubing r Stimulate-Frac Waiver r repair r r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: • ConocoPhillips Alaska, Inc. Development r Exploratory r 198-037 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20254-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25569 ' 2T-202 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tabasco Oil Pool . 11.Present Well Condition Summary: Total Depth measured 4427 feet Plugs(measured) 3623', 4250 true vertical 3492 feet Junk(measured) 4167 Effective Depth measured 4266 feet Packer(measured) 3441,3478,3828 true vertical 3335 feet (true vertical) 2546,2579,2910 Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 112 112 SURFACE 3637 10.75 3677 2765 LINER 499 7.625 3940 3018 RECEIVED NOV 12 2013 SCANNED • A i\ .h ;J j f Perforation depth: Measured depth: 3959'-4240' AOGCC True Vertical Depth: 3028'-3310' Tubing(size,grade,MD,and ND) 4.5, L-80,3784 MD,2867 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER ZXP LINER TOP PACKER @ 3441 MD and 2546 ND PACKER-CAMCO SLB-MZ PACKER @ 3478 MD and 2579 ND PACKER-BAKER SC-1 GRAVER PACK PACKER @ 3828 MD and 2910 ND NIPPLE-CAMCO DB NIPPLE @ 507 MD and 507 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze but resin placed in it Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development l7 - Service r Stratigraphic r 16.Well Status after work: Oil r'. Gas r VVDSPL r Daily Report of Well Operations XXX 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: 313-168 Contact Tyson Wiese @ 263-4250 Email Tyson.M.Wiese(a�conocophillips.com Printed Name Tyson Wi se Title Wells Engineer Signature Phone:263-4250 Date `\ 11)1,013 VLF )2-f/ 2-- / i3 RBDMS NOV 19 01.. Form 10-404 Revised 10/2012 � /y Submit Original Only l(( 2T-202 Well Work Summary DATE SUMMARY 6/12/2013 DRIFTED TBG WITH 2.81" DUMMY CA-2 PLUG TO DS NIPPLE @ 3623' RKB, SET 2.81"CA- 2 PLUG @ SAME, SET CATCHER ASSY ON TOP OF PLUG. LRS TO MIT TBG AND PERFORM DDT, MIT IA. Note: MIT-T= Pass, MITIA= Board Operator shut down pumping ops due to OA guage tracking IA/exceeding OA limits; since there is no OA, DHD will come back to attempt MIT-IA. 6/15/2013 (AC EVAL): T DDT(PASSED). IN PROGRESS. 6/19/2013 (AC EVAL) MIT IA(PASSED) 6/20/2013 DDT IA(IN PROGRESS). 6/21/2013 (PRE-CTD)CONTINUED IA DDT(FAILED DUE TO IA PRESSURE INCREASE). 8/1/2013 RIH TO TAG CATCHER AT 3603' CTMD, CORRECT DEPTH TO 3619' RKB, PUMP 5 BBLS GEL, 5 BBLS 20/40 SAND SLURRY, 5 BBLS GEL, LAY IN SAND FROM 3615'TO 3435' RKB, PUH LET SAND SETTLE FOR 2 HRS,TAG TOS @ 3465' RKB, F/P TBG WHILE POOH, READY FOR S/L, JOB IN PROGRESS. 8/2/2013 Attempt to Correlate GLM#1 but S/D on TOS @ 3393' RKB; Bailed f/3393'-3400' RKB (30' Above window); Correlated GLM#1 (29'C/F). In Progress. 8/5/2013 TIE INTO GLM @ 3388' RKB FOR CORRECTION; BAIL SAND FROM 3407' RKB TO 3428' RKB. IN PROGRESS. 8/6/2013 BAILED SAND FROM EST. 3434'TO 3445' RKB. IN PROGRESS. 8/7/2013 BAILED SAND FROM 3441'TO 3446' RKB. DUMP BAILED 1+GAL. CEMENT ON SAND @ EST. 3446 RKB. WOC. IN PROGRESS. 8/10/2013 GAUGED TBG TO 2.78"TO 3436' RKB. SET CATCHER @ SAME. PULLED DV FROM 3389' RKB, SET HFCV. PULLED CATCHER. READY FOR CIRC OUT. 8/12/2013 LOAD WELL WITH 310 BBLS OF DIESEL, PUMPING DOWN TBG @ 1 BPM 700 PSI, TAKING RETURNS UP IA TO PRODUCTION. WELL READY FOR COIL, IN PROGRESS. 9/21/2013 RODE UNIT FROM PBU TO 2T-202. RIG UP COIL UNIT. TEST BOPS. RACK BACK FOR THE NIGHT, IN PROGRESS. 9/22/2013 PUMPED 230 BBLS OF 140 DEGREE DIESEL TO WARM THE TBG, SWAP TO HES PUMP 5BBLS WELLLOCK RESIN TREATMENT INTO IA. JET TBG &GLM @ 3389' RKB WITH MUSOL-A SOLVENT AND CHASE TO SURFACE. FREEZE PROTECT TBG& IA TO 2500' WITH DIESEL. READY FOR SLICKLINE 9/24/2013 CIRCULATED 10 BBLS DSL @ 1 BPM WITH A MAX PSI OF 650 PSI. DRIFTED TBG WITH 2.5" BLR&TAG @ 3384' SLM (RECOVERED SAMPLE); PULLED CV&SET DV @ 3389' RKB; RAN CHECK SET TO CONFIRM DV SET. READY FOR DHD. 9/29/2013 (MISC)MIT-T PASSED TO 1500 PSI. MIT-IA AND IA DDT POSTPONED. 9/30/2013 (MISC)MIT-IA PASSED TO 1500 PSI. T DDT IN-PROGRESS, IA DDT IN-PROGRESS. 10/1/2013 (MISC): T DDT(PASSED), IA DDT(PASSED). 10/21/2013 TAG @ 3386'CTMD W/2.83" BO MILL. MILL @ 1 FPM RATE BROKE OUT IN THE SAND @ 3452' CTMD, STOP @ 3550'CTMD. POOH TO DROP MOTOR& MILL, PU JSN. CLEAN OUT SAND TO PLUG @ 3610 CTMD (PLUG @ 3622' RKB). WELL READY FOR DHD FOR POST MILLING MIT'S, IN PROGRESS. 10/23/2013 (AC EVAL) : MIT-T(PASSED)TO 1500 PSI, MIT-IA(PASSED)TO 1500 PSI, DDT-IA(IN PROGRESS). 10/23/2013 BAIL SAND f/3514'-3519' SLM (EST. 76' OF FILL ON CATCHER) (JOB POSTPONED FOR DHD). IN PROGRESS. 10/24/2013 BAIL SAND (APPEARS SAND FALLING OUT OF 4 1/2 TBG) DOWN TO 3451' SLM (APPROX. 144'OF FILL ONTOP OF CATCHER/PLUG). TAGGED X-OVER W/3.60"GAUGE RING @ 3376' RKB. TURN OVER TO CTU. 10/27/2013 (AC EVAL) : DDT-IA(IN PROGRESS). 10/29/2013 (AC EVAL): IA DDT(PASSED) n.. 1 KUP PROD 2T-202 Conoco Phillips /°- Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) tana4,„- .., 501032025400 TABASCO PROD 61.44 2,022.60 4,427.0 Comment H2S(ppm) 'Date Annotation End Date KB-Grd(R) -Rig Release Date 21-202,11)t1/20138.54:19 AM SSSV:NONE 40 10/28/2011 Last WO: 5/25/2004 45.00 3/27/1998 Vertical schematic(actual) Annotation Depth(RKB) -End Date Annotation Last Mod By End Date Last Tag:SLM 13,384. 0 9/24/2013 Rev Reason:SHOW RESIN haggea 9/26/2013 HANGER;32.9-,'z'( L. J Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 41.0 112.0 112.0 6258 H-40 WELDED II I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread M.SURFACE 103/4 10.050 40.8 3,677.4 2,764.8 40.50 J-55 BTC M7 CONDUCTOR:41.0-112.0• �� I�' Casing Description 'OD(in) ID(in) 'Top(ftKB) -Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade 'Top Thread• LINER 75/8 6.750 3,441.2 3,940.0 3,018.3 29.70 L-80 BTC-MOD Liner Details Nominal ID NIPPLE:507.0 1 1. Top(RKB) Top(ND)(MB) Top net(°1 Item Des Com (in) I 3,441.2 2,546.2 27.59 PACKER BAKER ZXP LINERTOP PACKER ' 7.625 - 3,460.0 2,563.0 26.75 HANGER 'BAKER HMC LINER HANGER ' 7.625 } Casing Description OD pn) ID(In) Top(11KB) Set Depth(RHB) Set Depth(ND)... WULen(I...Grade Top Thread GRAVEL PACK SAND I 6 3/4� 4,248.0 4,427.0 3,491.9 - -,� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) -Set Depth(ND)... WI/Len(I...Grade -Top Thread GRAVEL PACK LINER 41/2 4.000 3,827.0 4,251.0 3,320.3 Liner Details Nominal ID Top(ftKB) Top(ND)((MB) Top Inc'F) Item Des Com (in) xo Reducing,3,376.9 ( 3, 827.0 2,908.9 15.00 SEAL ASSY BAKER 80-40 LOCATOR S-22 SEAL ASSEMBLY 2.867 3,828.0 2,909.9 14.99 PACKER BAKER SC-1 GRAVEL PACK PACKER 4.000 • GAS LIFT'3,388 6 3,833.0 2,914.7 14.97 EXTENSION BAKER 80-40 MODEL'S'GRAVEL PACK 4.000 EXTENSION w/SLIDING SLEEVE,UPPER 8 • LOWER EXTENSION 8950.0 3827.9 14.36 SCREEN 9.6 JTS BARERWELD 140 GRAVEL PACK 4.000 8 v SCREEN;4.5"x30',w26'WRAPPED ON 13.54/FT "Y'-- 4,250.0 3,319.3 13.17 PLUG BULL PLUG 0.000 iI':r v.a Tubing Strings V. Tubing Description I String Ma...1 ID(in) !Top(ftKB) 1 Set Depth(ft../Set Depth(ND)(...1 Wt(Iblft) 1 Grade l Top Connection N Z TUBING 41/2 3.958 32.9 3,7837 2,8671 1260 L-80 IBTM Cement Squeeze;3,417.0 - v Completion Details PACKER;3.478.4 - Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) P32.9 32.9 0.00 HANGER FMC GEN IV ESP HANGER ' 4.500 507.0 506.7 832 NIPPLE CAMCO DB NIPPLE 3.812 3,376.9 2,490.0 30.38 XO Reducing CROSSOVER 4.5 x 3.5 3.500 3,478.4 2,579.4 25.93 PACKER CAMCO SLB-MZ PACKER 2.920 GAS LIFT:3.5666 3,622.6 2,712.5 19.04 NIPPLE CAMCO DS NIPPLE w/RHC PLUG INSTALLED 2.813 3,700.5 2,787.0 15.80 GAUGE WELL LIFT DGU,SIN:10366511 3.958 3,717.2 2,803.0 15.53 Discharge CENTRILIFT 513 SERIES BOLT ON-DISCHARGE 2.995 I HEAD 3,717.7 2,803.5 15.53 PUMP CENTRILIFT,56 STAGE P62-538 PMSXD 066 P75 HO FER 6 CRC PUMP 3,739.7 2,824.7 15.42 INTAKE CENTRILIFT GPXARCINT FER H6 PUMP INTAKE CATCHER;LUG;3. 6226^ 6_A 3,740.7 2,825.7 15.41 SEAL CENTRILIFT TANDEM SEAL SECTION-GSB3DB LT NIPPLE;3,622.6 FER HL H6 AFLAS/HSN-Coated 3,754.5 2,8398 15.35 MOTOR CENTRILIFT 562 MSP 336/2650/78 16R ESP MOTOR- Coated 1 3,779.8 2,863.4 15.22 GAUGE WELL SURFACE;40.8-3.677- l 4 3,781.7 2,865.3 151 Centralizer MOTOR LIFT CENTRALIZER MGU,P/N:PWLE9001/S/N:192-00651 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 1 Top(ND) Top Intl GAUGE;3.700.5 Via►•' Top(ftKB) (RKB) I.) Des Com Run Date ID(in) 3,615.0 2,705.3 19.46 CATCHER 3"BAITSUB,XO,GUTTED 2.5"JD(CATCHER 6/12/2013 0.000 Discharge;3,717.2 ASSY OAL=47") 3,6226 2,712.5 19.04 PLUG 2.81"CA-2 PLUG 6/122013 0.000 PUMP;3,717.7 1111II,IIll 4,167.0' 3,238.5 13.51 FISH PLUG IPB LOST DOWNHOLE DURING 5/24/2004 INTAKE;37397 njiar, WORKOVER 5/24/2004 ' SEAL;3,740.7 ' ' Perforations&Slots MOTOR;3,754.5 91�. Dens °l Top(ND) Ate,IND) (shots/? Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAUGE;3,779.8 I�1 3,950.0 4,240.0 3,027.9 3,309.6 TABASCO, 12/31/1998 50.0 SLOTS OPEN HOLE SCREENS TE_1,2T-202 Ceneal¢er;3,7817 ( ) Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(RKB) (ftKB) (ftKB) Des Start Date Com 3,417.0 3,478.4 2,524.9 2,579.5 Cement Squeeze 9/22/2013 PUMP 5BBLS WELL LOCK RESIN TREATMENT INTO IA JET TBG Mandrel Inserts St ati C on Top(ND) Valve Latch Port Size TRO Run 0 y ig No Top(ftKB) (ftKB) Make Model CD(in) Sery Type Type (In) (psi) Run Date m 1 3,388.6 2,500.2 CAMCO KBMG ' 1 GAS LIFT DMY 'BK 0.000 ' 0.0 9/24/2013 i 2 3,566.6 2,660.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/2/2012 Notes:General&Safety LINER;3,4412-3,940.0-as End Date Annotation 1/5/1999 NOTE:ESP WORKOVER SLOTS;3.950.07,240.0 5/24/2004 NOTE:WORKOVER-ESP PACKERLESS COMPLETION-POOR DETAIL SHEETS FOR ORIGINALNVO FISH;4,187.0 �' 5242004 NOTE:TIE-BACK LINER PULLED 1/1/1999 1/13/2011 NOTE:View Schematic w/Alaska S/1/199 ic9.0 9/22/2013 NOTE:SPOT 5 BBLS OF WELLOCK RESIN IN IA FOR PACKER LEAK GRAVEL PACK LINER;3,,21.0 III 4,251.0 GRAVEL PACK SAND;4.248.0- 4,427.0 a • 0 I %%/'s THE STATE Alaska Oil and Gas t ®fALASK A Conservation Commission u w GOVERNOR SEAN PARNELL 333 West Seventh Avenue � �E* Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Tyson Wiese SCOW) Wells Engineer �"� ConocoPhillips Alaska, Inc. P.O. Box 100360 ■ Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, 2T -202 Sundry Number: 313 -168 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, �T Cathy P. oerster Chair DATED this /U` day of May, 2013. End. II STATE OF ALASKA 'ilk- 0 5//a/L3 OIL AND GAS CONSERVATION COMMON 9/ I0 -1 • APRL.ICATION FOR SUNDRY APPROVALS 20 AAC 25.280 , 1. Type of Request: Abandon I"` Plug for Redrill r Perforate New Pool I"'" Repair w ell Change Approved Program r Suspend r Rug Perforations (°°'° Perforate r Pull Tubing f Time Extension f Operational Shutdown I — Re -enter Susp. Well i°"W Stimulate E Alter casing ( - RTS /r'1 JGi Lkf►'~ -- Other: �i'�tr y � 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 1/LP ConocoPhillips Alaska, Inc. Development (? . Exploratory f- 198 -037' 3//f( 3. Address: Stratigraphic I Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20254 - 00 ' 7. If perforating, halt 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes E No Ir 2T - 202 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569 Kuparuk River Field / Tabasco Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 4427 , . 3492 4266' 3335' • 4250' • 4167' Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 112' 112' SURFACE 3637 10.75 3677' 2765' LINER 499 7.625 3940' 3018' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ' 3950' - 4240' 3028' - 3310' 4.5 x 3.5 L - 80 3377 / 3784 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - CAMCO ZXP LINER TOP PACKER ' MD= 3441 TVD= 2547 PACKER - CAMCO SLB -MZ PACKER ' MD= 3478 TVD= 2579 PACKER - BAKER SC -1 GRAVEL PACK PACKER ' MD= 3828 TVD= 2910 NIPPLE - CAMCO DB NIPPLE • MD =507 TVD =507 12. Attachments: Description Summary of Proposal , W.' 13. Well Class after proposed work: Detailed Operations Program IT BOP Sketch F Exploratory E Stratigraphic Development I� ' Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/14/2013 Oil Imo' Gas I WDSPL r Suspended I 16. Verbal Approval: Date: WINJ r GINJ l — WAG f Abandoned I — Commission Representative: GSTOR r SPLUG fl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Email: Tyson.M.Wiesea( conocophillips.com Printed Name T so Wiese Title: Wells Engineer Signature Phone: 263 -4250 Date y.3 - ;n /3 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3/ 3 Plug Integrity E BOP Test (l Mechanical Integrity Test E Location Clearance I RBDMS MAY 10 201 Other: Spacing Exception Required? Yes ❑ No [VY Sibsequent Form Required: 1 y d04- APPROVED BY Approved by: C ap cation is v alid tOrl . tl the from th 5 da�#2 Oiflapproval. Date: S ' f /3 lwF Submit Form and Attachments in Duplicate t? \ ) ov6e10,A2L 3 / //3 - Y, /( v, ...., KUP • 2T -202 • , ConocoPhtllips i Well Attributes Max Angle & MD TD Alaska IfK: Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) 501032025400 TABASCO PROD 61.44 Z022.60 4,427.0 - ' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NONE 40 10/28/2011 Last WO: 5/25/2004 45.00 3/27/1998 Well Con5g'. -2T -202, 11/13/203 scnemnc- Actual 12 109'37 AM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 3,694.0 11/12/2012 Rev Reason: TAG ninam 11/13/2012 HANGER, 33 ' ., '' -" Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.063 41.0 112.0 112.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd R4 050 24.7 0. J - 191 P Ca Description FACE String 103/ O. . Str 1 O .p0 ID 0 .. Top (4ftKB) .8 Set Depth 3,6774 (1... Set Depth ,76 (N D) ... String Wt 50 . Strng 55 String Top BTC Thrd LINER 75/8 6.750 3,441.2 3,940.0 3,018.3 29.70 L - 80 BTC - MOD CONDUCTOR, '.8., 41 -112 Liner Details Top Depth (TVD) Top Inc! Nomi... NIPPLE, 507_ Top (ftKB) (ftKB) (1 Item Description Comment ID (!n) 3,441.2 2,547.2 27.78 PACKER BAKER ZXP LINERTOP PACKER 7.625 { 3,460.0 2,563.5 26.89 HANGER BAKER HMC LINER HANGER 7.625 Aii, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK 6 3/4 4,248.0 4,427.0 3,491.9 SAND Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK 4 1/2 4.000 3,827.0 4251.0 3,320.2 LINER Liner Details Top Depth XO Reducing, ( (TVD) Top tool Noml... 3,377 l Top (ftKB) (ftKB) ( °) item Description Comment ID (in) 3,827.0 2,909.0 15.00 SEAL ASSY BAKER 80 LOCATOR S SEAL ASSEMBLY 2.867 GAS 3,389 uF7, S.' 3,828.0 2,909.9 14.99 PACKER BAKER SC -1 GRAVEL PACK PACKER 4.000 3,833.0 2,914.8 14.97 EXTENSION BAKER 80-40 MODEL'S' GRAVEL PACK EXTENSION w /SLIDING 4.000 SLEEVE, UPPER & LOWER EXTENSION 3,950.0 3,028.0 14.36 SCREEN 9.6 JTS BAKERWELD 140 GRAVEL PACK SCREEN; 4.5 "x30', w /26' 4.000 WRAPPED ON 13.5#/FT n . 4,250.0 3,319.2 12.75 PLUG BULL PLUG 0.000 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PACKER, 3,47e _ TUBING 41/2 3.958 32.9 3,783.7 2867.1 12.60 L -80 IBTM Completion Details Top Depth Li (TVD) Top Inc) Noml... Top (ftKB) (ftKB) 11 Item Description Comment ID (in) 32.9 32.9 -0.86 HANGER FMC GEN IV ESP HANGER 4.500 507.0 506.7 5.32 NIPPLE CAMCO DB NIPPLE 3.812 GAS LIFT 3,376.9 2,490.4 30.38 XO Reducing CROSSOVER 4.5 x 15 3.500 3,478.4 2,579.7 26.02 PACKER CAMCO SLB-MZ PACKER 2.920 3,622.6 2,712.5 18.05 NIPPLE CAMCO DS NIPPLE w/ RHC PLUG INSTALLED 2.813 3,700.5 2,787.0 15.61 GAUGE WELL LIFT DGU, S/N: 10366511 3.958 3,717.2 2,803.1 15.50 Discharge CENTRILIFT 513 SERIES BOLT ON - DISCHARGE HEAD 2.995 3,717.7 2,803.6 15.50 PUMP CENTRILIFT, 56 STAGE P62 -538 PMSXD 066 P75 H6 FER 6 CRC NIPPLE, 3,623 PUMP 3,739.7 2,824.7 15.40 INTAKE CENTRILIFT GPXARCINT FER H6 PUMP INTAKE 3,740.7 2,825.7 15.40 SEAL CENTRILIFT TANDEM SEAL SECTION- GSB3DB LT FER HL H6 AFLAS/HSN- Coated ' { SUR41 - 3FACE, 3,754.5 2,839.0 15.33 MOTOR CENTRILIFT 562 MSP 3362650/78 16R ESP MOTOR- Coated 677 3,779.8 2,863.4 15.22 GAUGE WELL LIFT MGU, P/N: PWLE9001 / S/N: 192 -00651 ® 3,781.7 2,865.3 15.21 Centralizer MOTOR CENTRALIZER GAUGE, 3,701 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) I I I I Top Depth Dhcharge, (TVD) Top Inc! 3,717 Top (ftKB) (ftKB) (1 Description Comment Run Date ID (in) PUMP, 3,718 2 4,167 3,238.3 12.75 FISH PLUG IPB LOST DOWNHOLE DURING WORKOVER 5/24/2004 5/24/2004 INTAKE, 3,740 SEAL,3.741 Perforations & Slots MOTOR, 3,755 rt Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btrn (ftKB) (ftKB) (ftKB) Zone Date (sh -. Type Comment y �� 3,950 4,240 3,028.0 3,309.5 TABASCO, 12/31/1998 50.0 SLOTS OPEN HOLE SCREENS GAUGE,3,780 CZ) TE_1, 2T - 202 Centralizer, 3,782 382 1 Notes: General & Safety 3,782 1 End Date Annotation 1/5/1999 NOTE: ESP WORKOVER 5/24/2004 NOTE: TIE -BACK LINER PULLED 1/1/1999 5/24/2004 NOTE: WORKOVER - ESP PACKERLESS COMPLETION - POOR DETAIL SHEETS FOR ORIGINAUWO 1/13/2011 NOTE: View Schematic w/ Alaska Schematic9.0 ird Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (!n) Sery Type Type (in) (psi) Run Date Com... 1 3,388.6 2,500.3 29.88 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/12/2012 LINER, ,A ■ 2 3,566.6 2,660.3 21.85 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/2/2012 3,441 -3,940 SLOTS, 3,9504,240 y, _E • FISH, 4,187 `( !) ME GRAVEL PACK LINER, 3,8274,251 GRAVEL PACK SAND, 4,248-4,427 TD,4,427 • • 2T -202 Well Lock Resin Packer Repair Permit to Drill #: 198 -037 The objective of the proposed 2T -202 Resin Packer Repair is to restore packer integrity, by utilizing a resin system that exhibits improved mechanical properties when compared to conventional cement systems. Post RWO (Jan 2012), the well is now failing the IA draw down test, indicating that the cup type packer seals may be compromised. In order to bring this Tabasco ESP producer back online, the IA will need to pass an MIT and IA DDT test post resin job, ensuring that we have restored our packer integrity in this single casing configured well. Proposed Procedure: Slick Line / Little Red: 1. Set CA -2 plug in nipple @ 3,623' KB. Confirm tubing integrity and plug is holding. 2. Permit MIT -IA to 1,500 psi and obtain LLR. RDMO SLB Coil Tubing: 1. RIH and place a 180' sand plug from CA -2 plug to approx.. 50' below GLM. 2. Allow sand to settle and tag TOS to confirm depth is within window. 3. RDMO Slick Line / Little Red: 1. RIH and confirm top of sand is within window. 2. Pull DMY valve from GLM @ 3,389' KB. Pump 300 bbls diesel to load the well. 3. RDMO SLB Coil Tubing / Halliburton Pumping Services / Little Red: (Resin Treatment) 1. Ensure that the 10 -403 Sundry has been approved by the AOGCC. 2. RIH and position nozzle 20' above TOS. Pump hot diesel to warm up the coil tubing. 3. Pump 15 bbls of resin into the IA through the open pocket @ 3,389' KB. 4. Lay in 2 bbls of resin in the tubing from TOS to 3,289' KB. 5. PUH to safety and displace spacer fluid and foam ball from coil string. 6. Freeze protect tubing to surface. RDMO Slick Line / Little Red: 1. Wait 7 days for resin to fully cure and develop compressive strength. 2. Perform MIT -IA and MIT -T to 1,500 psi. Perform IA drawdown test. 3. RIH with bailer and tag top of resin @ approx. 3,289' KB. RDMO. SLB Coil Tubing: 1. RIH and mill resin from 3,289' KB to 4.5 "x3.5" X -over @ 3,377' KB. POOH 2. RIH and mill resin from 3,377' KB to 3,520' KB, partially into sand plug. POOH 3. Perform post milling MIT -IA 1,500 psi, MIT -T to 1,500 psi, and IA DDT. 4. If all tests pass, RIH and FCO down to CA -2 plug @ 3,623' KB. RDMO. Slick Line / Little Red: jic fi 1. Notify AOGCC Inspector of integrity testing via email, 24 hours prior to testing' r 2. MIT -IA and MIT -T to 1,500 psi. Perform IA DDT. Record Results. C Ghu`f" 3. RIH and pull catcher and CA -2 plug @ 3,623' KB. Install SOV. RDMO. 34° y' TW .. • ! TW 4 -3 -2013 2T -202 Resin Packer Repair PTD: 198 -037 Current Completion Pronosed Packer Repair i L 1.) Set pluglcatcher J 16 626 H -40 Conductor (a` 112' KB in nipple KB. 3.623' Y 1 Camco DB Nipple @ 507' KB 2.) Lay in 180' sand plug from 3,623' KB to 3,443' KB. Approx. 190' KB resin product in the IA. Top of Resin @ 3.289' KB 3.) Tag Top of Sand to confirm. Pull DMY from f GLM @ 3,389' KB. ::: "f � \ E.. 'I ! / J /{ 0:4 w vp- / he Tubing and IA with hot 7 5 +'8" Liner Top Packer @ 3,441' KB ..V0 diesel by pumping down CT string. 6.) With nozzle 20' above top of sand, pump the a Leaking SLB MZ Packer a@ 3,478' KB j '" following: 1 IA DDT Failed 6 bbl 8.6# inh. Seawater D1v1Y in Prod Mandrel @ 3,567' KB 17 bbls 11# Resin 5 bbl 8.6# inh. Seawater Release Dart/Ball 5 bbl Musol -A Camco DS Nipple ((_0, 3,623 KB Displace with Diesel 7.) When Resin hits II 10 40.5# J -55 Casing TD @ the nozzle. Lay in 0.5 3.677' KB bbl from TOS to GLM @ 3.389' KB. in 1 Centrilift ESP Pump (a? 3 KB 10 ` 8.) Open IA, Close TxCT, Displace 15 bbls resin into the IA. III— at 9.) Open TxCT. Close IA, Lay in remaining 1.5 bbl Centrilift ESP Seals @ 3,741' KB mini) resin from 3,389' KB to 3.289' KB. 10.) POOH Laying In gm Centrilift ESP Motor @ 3,755' KB iii Diesel to Surface. 11.) At Surface, cleanup ({ i W i ESP Centralizer Ca 3,782 KB [ 1 i I-+ C I residual resin fluids from equipment using Musol -A solvent. 12.) After 7 days. RIH Baker Gravel Pack Packer w Seal A ssembly wt S.L. and tag top of @ 3,828' KB — resin. RIH with CT. I I 1 1 1 1 mill up resin. and 111011 11111 FCO down to plug. 1111111 11 �' li1#IE:i;_. 75/8 "29.7 #L -80 Liner TD @3,940'KB ' :: 11(1:11 1 1 1 81) - ;:: : = "1. i) 13.) Perform MIT -IA, MIT -T. and IA DDT. If i Iifillf; : `''1 tests pass. Install )i1t ::: Oh Screen Slots (Tabasco) gg 3,950' KB to 4,240' KB SOV, pull plug. and 1 turn well over to [ 4.5" Gravel Pack Liner TD @ 4,251' KB :i...'nriar ..I operations. TW Page 1 of 1 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, October 31, 2012 1:33 PM To: 'NSK Well Integrity Proj' Cc: NSK Problem Well Supv; Nenahlo, Thomas L; CPF2 Prod Engrs Subject: RE: 2T -202 (PTD# 198 -037) Short Term Flow Test Walter, You have approval to do a short term flow test (not to exceed 30 days) in order to evaluate the productivity of the well. I believe you indicated that the production casing pressure tested during the recent RWO but increased onsite /inspections at the wellhead would be appropriate during the flow period. Regards, Guy Schwartz SCANNED APR 1 7 2013 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Tuesday, October 30, 2012 2:53 PM To: Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; Nenahlo, Thomas L; CPF2 Prod Engrs Subject: 2T -202 (PTD# 198 -037) Short Term Flow Test Guy, Tabasco single casing ESP producer 2T -202 was worked over in January 2012 to replace the ESP and add a packer above it to provide an additional barrier between the reservoir and surface. Subsequent to the RWO a leak was discovered between the IA and reservoir and was later determined to be in the feed - thru packer above the ESP. CPAI intends to conduct a short term flow test not to exceed 30 cumulative producing days with a known tubing /packer leak to verify the productivity index and watercut of this well. A decision to perform another workover or P&A the well will be based upon the results of the flow test. Please reply with your consent or contact me at your convenience if you have questions or comments. Martin Martin Walters / MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office: 907 -659 -7043 Cell: 907 - 943 -1720 Pager: 907 -659 -7000 #937 10/31/2012 STATE OF ALASKA • ALASKA', AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell Plug Perforations r Stimulate r Other r Alter Casing F.7 Rill Tubing . FFrforate New Pool r Waiver r Time Extension r Change Approved Program ]"" Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fr. Exploratory r 198 -037 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic j Service r 50- 103 - 20254 -00^' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25569 2 9. Field /Pool(s): Kuparuk River Field / Tabasco Oil Pool 10. Present Well Condition Summary: Total Depth measured 4427 feet Plugs (measured) None true vertical 3492 feet Junk (measured) 4167 Effective Depth measured 4266 feet Packer (measured) 3441, 3478 true vertical 3335 feet (true vertucal) 2547, 2580 Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 121 121 SURFACE 3637 10.75 3677 2765 LINER 499 7.625 3940 3018 RECEIVED SLANNED FEB 2 2 2012 FEB 0 7 2012 Perforation depth: Measured depth: 3962' -4246' True Vertical Depth: 3040' -3315' 1 Alaska all & Gas Cons. Commission 1 Anchorage Tubing (size, grade, MD, and TVD) 4.5, L -80, 3784 MD, 2867 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER ZXP LINER TOP PACKER @ 3441 MD and 2547 TVD PACKER - CAMCO SLB -MZ PACKER @ 3478 MD and 2579 TVD NIPPLE - CAMCO DB NIPPLE @ 507 MD and 507 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 346 53 4758 -- 220 Subsequent to operation shut - in 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ Service r Stratigraphic r 15. Well Status after work: Oil J Gas r WDSPL ]-` Daily Report of Well Operations XXX GSTOR r WINJ f` WAG r GINJ r SUSP r SPLUG E 16. 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: 311 -392 Contact Erik Nelson 263 -4693 Printed Name Eri elson Title Wells Engineer Signature /' Phone: 263 -4693 Date D I' s i; ,Fe6zD(7_, Form 10-404 Revised 10/2010 RBDMS FEB 0 74 _ 2.." 7- / 2_ Submit Original Only 9 KUP • 2T -202 ConocoPhillips a Well Attributes Max Angle & MD TD Ail`::h�f. f +: Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Ca1ogK 501032025400 TABASCO PROD 61.44 2,022.60 4,427.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: NONE 40 10/28/2011 Last WO: 5/25/2004 45.00 3/27/1998 Well Confia'. -2T -202 1/27/201212:43:12 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 3,640.0 6/25/2009 Rev Reason: WORKOVER ninam 1/27/2012 HANGER,33 *: Casing Strings Description String 0... String ID ... Top (ftKB) Set Depth 5... Set Depth (TVD) String Wt.. String String Top Thrd 9 P 9 9 P( ) P ( P ( ) �� 9 9 �� 9 P CONDUCTOR 16 15.063 40.8 112.0 112.0 62.58 H WELDED r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 4 SURFACE 103/4 9.794 40.8 3,677.4 2,764.7 40.50 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDU41 - CTO12 R, LINER 75/8 6.750 3,441.2 3,940.0 3,018.3 29.70 L - 80 BTC - MOD 1 Liner Details lir Top Depth (TVD) Top Inc' Nomi... ■ NIPPLE. 507 Top (ftKB) (ftKB) ( °) Item Description Comment ID ('n) w € ,, 3,441.2 2,547.2 27.78 PACKER BAKER ZXP LINERTOP PACKER 7.625 ,,S: 3,460.0 2,563.5 26.89 HANGER BAKER HMC LINER HANGER 7.625 Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK 63/4 4,248.0 4,427.0 3,491.9 SAND Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GRAVEL PACK 5.1 3,946.0 4,248.0 3,317.3 20 GAUGE LINER SCREEN Liner Deta Top Depth (TVD) Top Inc! Nomi... XO Reducing Top (ftKB) (BBB) (°) Item Description Comment ID (in) 3,377 11 3,946.0 3,024.1 14.37 Gravel Pack Illa Screen GAS LIFT. Tubing Strings - -- Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 32.9 3,783.7 2,867.1 12.60 L -80 IBTM Completion Details -- -..4 Top Depth v - (TVD) Top Inc( Nomi... Top (ftKB) (ftKB) Comment Item Description ID (in) • • 32.9 32.9 -0.86 HANGER FMC GEN IV ESP HANGER 4.500 507.0 506.7 5.32 NIPPLE CAMCO DB NIPPLE 3.812 3,376.9 2,490.4 30.38 XO Reducing CROSSOVER 4.5 x 3.5 3.500 PACKER, 3.478 3,478.4 2,579.7[ 26.02 PACKER CAMCO SLB-MZ PACKER 2.920 OA 3,622.6 2,712.5 18.05 NIPPLE CAMCO DS NIPPLE w/ RHC PLUG INSTALLED 2.813 3,700.5 2,787.0 15.61 GAUGE WELL LIFT DGU, S/N: 10366511 3.958 3,717.2 2,803.1 15.50 Discharge CENTRILIFT 513 SERIES BOLT ON - DISCHARGE HEAD 2.995 3,717.7 2,803.6 15.50 PUMP CENTRILIFT, 56 STAGE P62 -538 PMSXD 066 P75 H6 FER 6 CRC I PUMP GAS LIFT 3,739.7 2,824.7 15.40 INTAKE CENTRILIFT GPXARCINT FER H6 PUMP INTAKE 3,507 3,740.7 2,825.7 15.40 SEAL CENTRILIFT TANDEM SEAL SECTION - GSB3DB LT FER HL H6 AFLASMSN- Coated I 3,754.5 2,839.0 15.33 MOTOR CENTRILIFT 562 MSP 336/2650/78 16)4 ESP MOTOR- Coated 3,779.8 2,863.4 15.22 GAUGE WELL LIFT MGU, PM: PWLE9001 / S/N: 192 -00651 3,781.7 2,865.3 15.21 Centralizer MOTOR CENTRALIZER IF Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth NIPPLE, 3,623 F. (TVD) Top Inc! - Top (ftKB) (ftKB) (1 Description Comment Run Date ID (in) 4,167 3,238.3 12.75 FISH PLUG IPB LOST DOWNHOLE DURING WORKOVER 5/242004 5/24/2004 SURFACE, Perforations & Slots 413,677 Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ft86) (ftKB) (ftKB) Zone Date Oh- Type Comment GAUGE, 3,701 = 3,962 4,246 3,039.6 3,315.3 TABASCO, TE1, 2T -202 12/31/1998 50.0 SLOTS I I II Notes: General & Safety Discharge, End Date Annotation 3'717 ( 5/24/2004 NOTE: TIE - BACK LINER PULLED 1/1/1999 - PUMP, 3,718 . [i.... �. - 5/24/2004 NOTE: PACKERLESS COMPLETION - POOR DETAIL SHEETS FOR ORIGINALNJO INTAKE, 3,740 - 1/13/2011 NOTE: View Schematic w/ Alaska Schematic9.0 SEAL,3,741 MOTOR, 3,755 GAUGE, 3,780 "� Centralizer, ` 3,782 1 I Mandrel Details Top Depth Top Port (TVD) Inc( OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Mode( (in) Sery Type Type ON (psi) Run Date Com... 1 3,388.6 2,500.3 29.88 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 1/11/2012 LINER, . Ik 2 3,566.6 2,660.3 21.85 CAMCO KBMG 1 GAS LIFT SOV BK 0.000 0.0 1/11/2012 3.441-3.940 Vf CA i SLOTS, 3,962-4,246 FISH, 4,167 * V GRAVEL PACK € .$ LINER SCREEN, 3 . , GRAVEL VEL PACK SAND, 4,248-4.427 •.....'.::. TD, 4.427 2T -202 Pre Rig Work DATE SUMMARY 12/20/11 DRIFT AND TAG CMU AT 3589' 1, ( -28' CORR), OPEN CMU, MEASURED HP @ 3622' SLM = 1205 psi, & 3516' SLM. LOAD IA WITH 230 DIESEL AND 40 DIESEL DOWN TUBING. READY FOR BPV. 12/21/11 T -POT (PASSED) T -PPOT (PASSED) IC -POT (PASSED) IC -PPOT (PASSED) • • ConoeoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2T - 202 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/4/2012 5:30:00 PM Rig Release: 1/12/2012 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/04/2012 24 hr summary RDMO 2T -220. Swap out Double Gates on BOPE. MIRU on Well 2T -202. Kill Well. 17:30 19:30 2.00 MIRU WELCTL MOB P Release Rig From 2T -220 at 10:00 A.M. Move Rig to middle of location and swap out the Double Gates on the BOPE. MIRU on 2T -202. Spot and level Nordic Rig 3 over Well. Berm up. Move in spot and berm up support equipment. Accepted Rig at 17:30 hours. 19:30 21:00 1.50 COMPZ WELCTL THGR P Bring in and PU lubricator and pull BPV. 21:00 22:30 1.50 COMPZ WELCTL KLWL P Pressure test circ. hoses and hard line 250/3500 psi 22:30 00:00 1.50 COMPZ WELCTL KLWL P Initial Pressure T /I /O = 350/ 75/ 20 psi. Line up and pump 160 degree filtered 8.3 ppg seawater w/ 3% KCL taking returns to tiger tank. Pumping 4 bpm at 250 psi down IA 710 hhLs away. 01/05/2012 Continue Kill Well. ND ESP Tree. Perform initial BOPE test. 00:00 05:00 5.00 COMPZ WELCTL KLWL P Continue pumping 160 degree filtered 8.3 ppg seawater w/ 3% KCL taking returns to tiger tank. Pumping 5 bpm at 250 psi down IA. Pump 340 bbls down IA total. Total returns 261 bbls to tiger tank. still have diesel returns, pump 180 bbls to get seawater returns to surface, monitor well, Tbg dead IA with 10 psi and diesel to surface, total returns 331 bbls to tiger tank, attempt to vac out kill tank, valve froze up, place heater on valve and vac out tiger tank. Open up IA and continue circulating seawater down tubing up IA to tiger tank at 5 bpm at 200 psi. After 232 bbls away, get seawater returns. Total returns to tiger tank 60 bbls. monitor well 30 min, dead. 05:00 05:30 0.50 COMPZ WELCTL THGR P Install CIW 4" TYPE 'H' BPV. 05:30 07:30 2.00 COMPZ WELCTL NUND P ND Stack. Inspected tree and lifting threads in TBG hanger. All check out good. install blanking plug. Crane on Location to swap out ESP spool. Perform Swap. Page 1 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 18:00 10.50 COMPZ WELCTL NUND P PJSM. NU 11" BOP Stack with VBR's in Top Cavity and 3 -1/2" solid in the bottom Cavity. Rig on High Line at 17:00 hrs. 18:00 00:00 6.00 COMPZ WELCTL BOPE P PJSM. Function & Test BOP Ram's and choke manifold to 250/3500 psi ,f�v and the annular to 250/2500 psi. ' Check all Alarms on Rig and perform !r Koomey draw down on HYD system. 01/06/2012 Pull Tubing Hanger. Circ Well. Rig up to handle the ESP completion. POOH with the 41/2" ESP Completion. Clean and Clear floors. Load out Centrilift equipment. 00:00 01:15 1.25 0 0 COMPZ WELCTL BOPE P Continue to Function & Test BOP Ram's and choke manifold to 250/3500 psi and the annular to 250/2500 psi. Check all Alarms on Rig and perform Koomey draw down on HYD system. 01:15 02:00 0.75 0 0 COMPZ WELCTL OWFF P PJSM- Pull Blanking plug and Type H BPV and Monitor for flow to ensure well is still dead. 02:00 02:15 0.25 0 0 COMPZ WELCTL SFTY P PJSM. Discuss Hazard for Pulling ESP Completion. 02:15 03:00 0.75 0 0 COMPZ WELCTL PULL P Insure TBG & IA pressure is still zero. Screw into tubing hanger with landing joint. BOLDS. 03:00 03:30 0.50 0 0 COMPZ WELCTL THGR P Pull Hanger up 3 -ft. Picks free at 85k and drops back to 80k. 03:30 06:30 3.00 0 0 COMPZ WELCTL CIRC P PJSM. Circulate 400 bbls down tubing up IA. get returns of crude at 70 bbls pumped. Shut down and strap returns at 6 bbls. Bull head 200 bbls down IA, 5 bpm at 60 psi ICP, 70 psi FCP. 06:30 07:00 0.50 0 0 COMPZ WELCTL OWFF P Observe well for flow. slight vac. 07:00 07:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard for Pulling and Laying down 4 1/2" x 3 1/2" ESP Completion. 07:15 18:00 10.75 3,782 90 COMPZ RPCOM PULL P Pull Tubing Hanger to floor,and UD same. Continue OOH laying down TBG and spooling up ESP cable and Tec Wire. Up Wt 85k. Made some repairs to the ESP Spooler. Most all the Pin End of TBG and the inside of TBG showed signs of corrosion, box end look OK. 18:00 22:00 4.00 90 0 COMPZ RPCOM PULL P Tear down and inspect ESP, seals and motor. approximately 25 -ft of sand on top of pump. Recovered with completion: 15 ea. SS flat bands 4 ea. protectolizers 54 ea. 4 1/2" Cannon clamps 11 ea. 3 1/2" Cannon clamps ""Only a 7" piece of 1 severely corroded flat guard recovered. Page 2 of 8 • • Time Logs Date From TO Dur S. Death E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 COMPZ RPCOM OTHR P Clean and clear floors. load out Centrilift equipment. 01/07/2012 Prep to run Casing Evaluation. PU Run Clean Out/Test BHA #1 to SC -1 GP. Test 10 -3/4" csg x 7 -5/8" liner to GBH -22 GP seal. TOOH. PU Run 7 -5/8" RBP / 10 -3/4" Test Pkr BHA #2. Set RBP. 00:00 01:45 1.75 0 0 COMPZ RPCOM OTHR P PJSM- Bring in Baker csg evaluation equipment. Change floors over to run DP. Bring in 5 jts 3 1/2 DP, strap and tally. Set wear ring. 01:45 02:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Dicuss hazards of running scrapers 02:00 05:00 3.00 0 2,070 COMPZ RPCOM PULD P PU MU BHA #1, GBH -22 seal /nozle assembly, tandem string magnets, 7 -5/8" csg scraper, bumper sub, oil jar, 6 ea. 4 -3/4" DC's, intensifier, 5 ea. 3 -1/2" DP's, XO, 10 -3/4" csg scraper, XO. RIH on DP to 2,070 -ft, set in slips for slip and cut. 05:00 07:30 2.50 2,070 2,070 COMPZ RPCOM SLPC P Slip and Cut Drill Line. Service Top Drive. 07:30 09:15 1.75 2,070 3,812 COMPZ RPCOM FCO P Continue In Hole with Scraper Assembly to clean and scrape 7 -5/8" & 10 -3/4" casing. Work scraper assembly down to 3,812 -ft with problems. 09:15 12:15 3.00 3,812 3,812 COMPZ RPCOM CIRC P Stop and CBU x2 while pumping 8.3 ppg filter brine down the drill pipe, taking return up the IA and out to the return tank at 8 bpm, 100 psi. Was unable to maintain returns after pumping 120 bbls. B/D Top Drive, Srut bag on annular and bullhead 480 bbls down IA to flush casing out at 8 bpm, 175 psi. 12:15 13:00 0.75 3,812 3,822 COMPZ RPCOM PRTS P Completed Flushing Casing. Continue with Charge pump only. Up Wt 90k and 75K Dn .Located and No -Go out on SC -1 GP packer at 3,822 -ft, end of tool string at 3,831 -ft, with 5k to 10k down wt. Park Drill Pipe and line up to test IA to 1500 psi for 30 mins. Blow down TD. Page 3 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:00 1.00 3,822 3,822 COMPZ RPCOM PRTS P Fluid Pack IA, shut in Annular Bag around 3.5" Drill Pipe. Start pumping down IA thru Flow Cross. On Line with rig pump at 1.0 bpm, 880 psi, 1.5 bpm, 950 psi, 2.0 bpm, 990 psi and held pump rate at 2.5 bpm, 1200 psi, pressure would not build any further. Lower pump down to 2.0 bpm at 990 psi for 3 bbls more, shut and pressure drop from 990 psi to 670 psi in 5 mins and another 10 psi in 5 mins. Attempted another test at 3.0 bpm for 18 bbls more and pressure only built to 990 psi, shut down pump again and psi slowly fell to 660 psi. Contacted Town Engineer for Plan Forward. 14:00 16:30 2.50 3,822 0 COMPZ RPCOM TRIP P Un -stab seal assembly and TOOH S/B Drill Pipe. 16:30 17:30 1.00 0 0 COMPZ RPCOM PULD P Lay down scraper assembly. 17:30 19:30 2.00 0 0 COMPZ RPCOM OTHR P Standby for 10 -3/4" Retrieveamatic and 7 -5/8" RBP from Baker Tool House. Load out BHA #1, Bring in Baker tools, BHA #2 19:30 00:00 4.50 0 3,780 COMPZ RPCOM PULD P PU MU BHA #2- 7 -5/8" Model "G" RBP, 47 Model "L" retrieving tool, XO, 11 stds DP, XO, 10 -3/4" Model "B" Retrievamatic test pkr, XO, 6 -ft x 3 -1/2" DP Pup and RIH on DP, 82k up / 72k down.Set RBP at 3,780 -ft. 01/08/2012 Pressure test IA to RBP. Dump sand. TOOH. Load and tally completion. MIRU E -line. Obtain 7 -5/8" and 10 -3/4" FAST CAST logs. MU 7 -5/8" Caliper tool. 00:00 01:00 1.00 3,780 3,760 COMPZ RPCOM PRTS P RBP set at 3,780 -ft. release and PUH 20 -ft, 10 -3/4" Retrievamatic at 3,398 -ft. Pressure Test IA Surface to _ RBP at 3,780 -ft to 1500 psi, chart good 30 minute test. 01:00 02:15 1.25 3,760 3,760 COMPZ RPCOM CIRC P Circuleate 30 bbls down tubing to clean up, dump 200# of 20/40 mesh, let stand 1 hour. 02:15 02:30 0.25 3,760 3,760 COMPZ RPCOM SFTY P PJSM- discussed hazards with tripping out of hole with test packer. 02:30 05:30 3.00 3,760 0 COMPZ RPCOM TRIP P TOOH standing back DP, Lay down and load out Baker equipment. 05:30 06:00 0.50 0 0 COMPZ RPCOM OWFF P Clean Floor. Monitor Well on Trip Tank. 06:00 10:00 4.00 0 0 COMPZ RPCOM PULD P Load 4 -1/2" IBT Completion TBG, Drifted last 500' of tubing and the Hanger with a 3.843" Lock -set. 10:00 11:00 1.00 0 0 COMPZ RPCOM ELOG P PJSM. R/U HES E -Line Unit and Load tools to rig floor. 11:00 12:00 1.00 0 500 COMPZ RPCOM ELOG P RIH w/ 10 -3/4" Fast -Cast Logging Assembly. 12:00 12:30 0.50 500 0 COMPZ RPCOM ELOG T Had Trouble with Logging Tools. POOH with 10 -3/4" Fast -Cast Logging Assembly. Page 4 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 14:45 2.25 0 0 COMPZ RPCOM ELOG T Re -head E -Line Connection. 14:45 15:30 0.75 0 3,420 COMPZ RPCOM ELOG T RIH w/ 10 -3/4" Fast -Cast Logging Assembly again. 15:30 19:15 3.75 3,420 0 COMPZ RPCOM ELOG P Start Logging the 10 -3/4" from 3,420 to surface at High - definition CSG inspection speed. Logging Speed is 15 FPM. 19:15 20:15 1.00 0 0 COMPZ RPCOM ELOG P OOH with 10 -3/4" Fast -Cast Logging Assembly, MU 7 -5/8" Fast -Cast tool, run checks. 20:15 21:15 1.00 0 3,780 COMPZ RPCOM ELOG P RIH with 7 -5/8" Fast -Cast Logging Assembly. 21:15 23:00 1.75 3,780 0 COMPZ RPCOM ELOG P Start Logging the 7 -5/8" liner from 3,780 -ft to 3,420 -ft at High - definition CSG inspection speed. Logging • Speed is 15 FPM. TOOH after entering 10 -3/4" casing. 23:00 00:00 1.00 0 0 COMPZ RPCOM ELOG P OOH with 7 -5/8" Fast -Cast Logging Assembly, MU Extended Reach Caliper tool, run checks. 01/09/2012 Obtain 7 -5/8" Liner Caliper and GYRO log. Pull RBP. Load out equipment. Pump corrosion inhibitor. Prep for Running completion. 00:00 00:15 0.25 0 0 COMPZ RPCOM ELOG P Running checks on Extended Reach Caliper tool. 00:15 00:45 0.50 0 3,788 COMPZ RPCOM ELOG P RIH with 40 arm extended reach caliper. 00:45 01:45 1.00 3,788 0 COMPZ RPCOM ELOG P Start logging from 3,788 -ft, log 7 -5/8" Liner at 40 fpm to 3,420 -ft, TOOH 01:45 02:45 1.00 0 0 COMPZ RPCOM ELOG P QOH with 40 arm caliper,_MU GYRO and run checks 02:45 07:00 4.25 0 3,750 COMPZ RPCOM ELOG P RIH with GYRO data tool making required stops to aquire tool settings. Log up from 3,750 -ft to surface. 07:00 08:30 1.50 3,750 0 COMPZ RPCOM PULD P Completed Logging Operation. Down load Data from Gryo Data Logging Tools. Un -Load Logging Tools from Rig FLoor. R/D and Release E -Line Unit and Crew. 08:30 08:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Making RBP Retrieval Tool. 08:45 09:45 1.00 0 3,774 COMPZ RPCOM PULD P MU and TIH with Baker RBP„ • Retrieval Assembly. 09:45 11:30 1.75 3,774 3,777 COMPZ RPCOM CIRC P Reverse Circulate Sand from top of RBP set a 3,377 -ft. Up Wt 75k and 70k Dn Wt. Pump Rate 8 bpm, 1180 psi. Pump a 32 bbl High -Vis Sweep. 11:30 12:00 0.50 3,777 3,775 COMPZ RPCOM FISH P Wash Down at 4 bpm, engage RBP at 3,777 -ft. Latch Plug, PUH and Let relax. 12:00 17:00 5.00 3,775 0 COMPZ RPCOM TRIP P PJSM. TOOH with RBP. Single Drill Pipe and maintain proper hole fill. Up Wt 75k. 17:00 21:15 4.25 0 0 COMPZ RPCOM PULD P PJSM- MU DP and DC left in derrick and RIH to 1,438 -ft, TOOH single down DP and DC to shed. Page 5 of 8 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 21:15 22:30 1.25 0 0 COMPZ RPCOM OTHR P PJSM- Pull wear ring. Off load DP and DC from pipe shed. 22:30 23:30 1.00 0 0 COMPZ RPCOM CIRC P Pump 240 bbls corrosion inhibited seawater at 5 pbm, 60 psi down csg. monitor well, on vac. 23:30 00:00 0.50 0 0 COMPZ RPCOM OTHR P Change over floor equipment, prep for running completion. 01/10/2012 Run ESP Completion with Flowthru Packer. 00:00 00:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM- discussed hazards with MU and running ESP completion. 00:15 06:00 5.75 0 90 COMPZ RPCOM PULD P PU MU Service Motor and seals, install accessories and RIH to connect I -wire to DGU. 06:00 08:00 2.00 90 289 COMPZ RPCOM TRIP P RIH as per running order to 289 -ft where the 7 -5/8" x 3 -1/2" SLB -MZ Packer goes. Waiting replacement Packer, the last one had bad seals. Found Bad section on ESP Cable (420 -ft) Made cut on cable to splice below and above SLB -MZ Packer. 08:00 11:00 3.00 289 289 COMPZ RPCOM RCST T Wait on New Packer from SLB Shop. 11:00 11:30 0.50 289 289 COMPZ RPCOM PULD T Load New Packer assembly to rig floor. 11:30 15:45 4.25 289 289 COMPZ RPCOM RCST P PJSM. MU Packer to Completion String. Make Cable splice to bottom and upper section of MZ Packer. 15:45 17:30 1.75 289 1,344 COMPZ RPCOM RCST P Packer Installed and Splice is complete and tested, all good. MU two more joints of 3 -1/2" Tubing above Packer and Change Handling Equipment to 4 -1/2 ". Continue in hole with completion. 17:30 18:00 0.50 1,344 1,344 COMPZ RPCOM OTHR P Stop at 1,343 -ft and test resistivity integrity. Phase to Phase passed but the Phase to Ground Failed. Tried two different test meter with same results. 18:00 20:30 2.50 1,344 299 COMPZ RPCOM TRIP T TOOH standing back Tubing to found problem area on cable. 20:30 22:00 1.50 299 299 COMPZ RPCOM TRIP T Stopped at the SBL MZ Packer. Disconnect the Feed -Thru Connections below the Packer. All three connections were full of fluids. Check Cable both directions. Good. Dry out the Connectors. Add Teflon thread tape to the NPT male connections and tighten extra tight. Make -up the three Feed -Thru Connections. Check cable. Good. 299 1,343 COMPZ RPCOM TRIP T Resume to run back in with the Completion. Check Cable. Good. 01/11/2012 Continue running ESP Completion. Make final splice. Land Tubing Hanger. PT Tubing and IA. RU S -Line. Set Catcher Sub. Pull DV. Set CV. RD S -Line. ND BOP Stack. NU Tree. Test Tree. Test Cable. Page 6 of 8 • • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 1,343 3,742 COMPZ RPCOM TRIP P Continue running the Completion from 1,343 -ft as designed. ESP Cable /Equipment continues to check, GOOD. 05:00 08:30 3.50 3,742 3,742 COMPZ RPCOM OTHR T Set down at the Liner top Packer at 3441 -ft with the SLB-MZ Packer. MU to Top Drive and Rotate 1/4 turn left and right and pump down TBG at 2,4,and 6 bpm, 420 psi and work Packer and completion down inside 7 -5/8" casing. Check the integrity of the ESP Cable, tested good. 08:30 11:00 2.50 3,752 3,752 COMPZ RPCOM THGR P MU Tubing Hanger. Make final splice of ESP cable to penetrator. Check the integrity of the ESP Cable, tested good. 11:00 11:30 0.50 3,752 3,784 COMPZ RPCOM THGR P MU Landing Joint and Land ESP Completion. RILDS. There are (53) 4 -1/2" Cannon Clamps, (9) 3 -1/3" Cannon Clamps, (7) SS Bands, (3) Protectolizers with armor guards, (2) Flat Guards on the ESP Completion. 11:30 12:00 0.50 3,784 3,784 COMPZ RPCOM PULD P PJSM. RU Testing Equipment. 12:00 16:30 4.50 3,784 3,784 COMPZ RPCOM PRTS P PJSM. Test Tubing to 250 psi for 5 minutes, increase psi to 2500 psi and hold for 30 minutes. Bleed down Tubing to zero. Test IA to 250 psi for 5 minutes, increase pressure to 1500 psi and hold for 30 mintues. Start 3 hour Depressurization bleed down schedule. 16:30 16:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss Hazard for Slick -line Operation. 16:45 17:45 1.00 0 0 COMPZ RPCOM SLKL P MIRU Slick -line Unit and Load Equipment to Rig floor. 17:45 20:30 2.75 0 0 COMPZ RPCOM SLKL P PT Slickline lubricator section. Open TIW valve, RIH and set catcher sub above plug. Run in with Kick -Over Tool and pull the Dummy Valve from the GLM at 3,388 -ft. Run with the Circulating Valve (5/16" Orifice) and set in the same GLM. Rig down S -Line equipment. Note: the 23" long AVA Catcher Sub remains in the Well for post RWO S -Line operations). 20:30 23:30 3.00 0 COMPZ WHDBO NUND P PJSM. Install BPV. Install 2 7/8" Solid Pipe Rams in the upper gate. Install 5" x 2 7/8" VBPRS in the lower gate. Nipple down BOP Stack and set back on the Stump. 23:30 00:00 0.50 0 COMPZ WHDBO NUND P Nipple up Tree. Page 7 of 8 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/12/2012 24 hr Summary Finish Freezing Protecting Well with Diesel. Install BPV. Secure Cellar. Release Rig. RDMO. 00:00 02:00 2.00 0 COMPZ WHDBO NUND P Complete nipple up Production Tree. DSO verified Tree alignment. 02:00 04:00 2.00 0 COMPZ WHDBO PRTS P Test Hanger void at 250 psi and 5,000 psi. Good. Perform final ESP Cable electrical checks as follows: 1.8 Ohms Phase to Phase and 3.74 Gig Ohms Phase to Ground. Good. Pull BPV. Install TWCV. Pressure test Tree at 250 psi and at 5,000 psi. Good. Pull the TWCV. 04:00 10:30 6.50 0 COMPZ RPCOM FRZP P PJSM. Rig up cellar hoses. Pressure test hoses at 2,500 psi. Freeze protest Well with 230 bbls down the IA at 1 bpm, ICP =230 psi, FCP =370 psi. Shut down and circulate 60 bbls down Tubing at 1 bpm, ICP =50 psi, FCP =320 psi. Blow Down Treating Iron. 10:30 12:30 2.00 0 COMPZ RPCOM PLUG P Install CIW 4" TYPE 'H' BPV 12:30 15:00 2.50 0 0 COMPZ MOVE DMOB P Wait on Vac Trucks to remove fluid from pits and return tanks so rig can move.RDMO. Release Rig. Page 8 of 8 Lit - a3? z0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 12, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: CASTM-CASE/MIT: 2T-202 Run Date: 01/08/2012 - 01/09/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -202 Data in LAS /DLIS format, Digital Logs, Interpretation Report, 3D Viewer 1 CD Rom 50- 103- 20254 -00 CASE Log (Processed Log) SCANNED MAY 13 2013 1 Color Log 50- 103 - 20254 -00 CAST -M (Field print) 1 Color Log 50- 103 - 20254 -00 µ_ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 1 1„'t 1 t'1 Signed: 84,4 • • STITTEE Cl[F AILASM SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson q R ()S Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, 2T -202 Sundry Number: 311 -392 Dear Mr. Nelson: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, 4 Daniel T. Seamount, Jr. Chair DATED this _23rd_ day of December, 2011. Encl. 1 • • j 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 DEC 2 4 Zp11 19 December 2011 ;p�s,Ott g �� ® RnG�4taA� Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2T -202 (PTD 198 -037). Well 2T -202 was drilled in 1998 and completed as a single completion in the Tabasco formation. ./The well was completed with an open -hole gravel pack and placed on artificial lift with an electrical submersible pump (ESP). Recently, ConocoPhillips Alaska initiated a policy requiring two barriers from any energized fluid ., (i.e. reservoir fluids, power fluids, lift gas, etc.). Consequently, we must retrofit all of our packerless single casing ESP wells at West Sake and Tabasco with a 2 barrier. This can be done by either installing a packer or an inner casing string. The primary objective of this workover is to install a TC -ESP with a feed -thru packer, which, along v with a competent production casing string, will satisfy our barrier requirements. This, in and of itself, does not require Sundry Approval; but, if the production casing is found to be compromised, our backup plan is to bring the existing 7 -5/8" liner to surface then install a TC -ESP with a feed - thru packer, which does require Sundry Approval, hence the reason for this pre - emptive Application for Sundry Approval. If you have any questions or require any further information, please contact me at 263 -4693. Regards >3 6 / .....2„.7 Erik. s 1 / Wells Engineer CPAI Drilling and Well ATE OF ALASKA ALASKA OIL ANWAS CONSERVATION COMMISSION -1 (P " 8 PePIVPD °' ' `" 'izzau , APPLICATION FOR SUNDRY APPROVALS DEC 2 0 2011 . 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well l✓ , 7 +@A4 ion Suspend r Plug Perforations r Perforate r Pull Tubing ► ITAIMESSfis ion E Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1 Exploratory r 198 - 037 - 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20254 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No I✓ 2T - 202 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569 • Kuparuk River Field / Tabasco Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4427 • 3492 • 4266' 3335' 4167' Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 121' 121' SURFACE 3637 10.75 3677' 2765' LINER 499 7.625 3940' 3018' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3962' -4246' 3040' -3315' 4.5 L - 3785 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER ZXP LINER TOP PACKER MD =3441 TVD =2547 NO SSSV 12. Attachments: Description Summary of Proposal J7 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/23/2011 011 Gas r WDSPL r' Suspended r 16. Verbal Approval: Date: WINJ r GINJ f WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson © 263 -4693 Printed Name Erik Nelson Title: Wells Engineer /f/ Signature t �ii - Phone: 263-4693 Date . GI )/ Commission Use Only 2 Sundry Numbe3I i '3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r/ " Mec chni hanical Integrity Test F Location Clearance r Other r 3S00 c 3( '"' P t Subsequent Form Required: /O — C.r o LI/ APPROVED BY Date: ) 4 2j3 // 1 Approved by: "V t COMMISSIONER THE COMMISSION Form 1 HatiMedDECOry goat r L I- UR 1G1NAL / ... _: ., Submit' Duplicate ,•‘‘ • • • 2T -202 Expense Rig Workover PTD #: 198 -037 Current Status Well 2T -202 was shut -in and freeze protected on 06 December 2011 in preparation for the RWO. f F 35 s Scope of Work Pull 4 -' /2' TC -ESP completion. Scrape, inspect, and pressure test 10-%" x 7 -5/8" csg. Option #1 - If the 10 -%" x 7 -5/8" csg passes pressure tests then we'll run a new 3 -W TC -ESP completion with a feed -thru pkr. Option #2 - In the event the 10-%" csg does not pass the pressure test we will tie -in a 7 -5/8" csg string to the top of the 7 -5/8" liner top packer and bring it to surface. Then we'll run a new 3-Y2" TC -ESP completion back in with a feed -thru pkr. General Well info MASP: 1214 psi Reservoir pressure /TVD: 1531 psi / 3171' TVD Using SBHP measured on 25 June 2009 of 1239 psi at 3640' MD (2729' TVD and 1208 psi gradient stop at 3590' MD (2682' TVD) Wellhead type /pressure rating: FMC Gen IV 11" 5M BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: NA due to packerless ESP completion Well Type: Producer Estimated Start Date: 23 December 2011 Production Engineer: Thomas Nenahlo RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 — 7407 E -Mail: Erik.Nelson @conocophillips.com Proposed Procedure from failure of pressure test on 10 -% "x 7 -5/8" csq: ./ 1. MU and TIH w/ Baker RBP and set it —3800' MD. PU —100' MD. PT 7 -5/8" x 10-%" csg 250/2500 psi , I (test fails). 2 -- 2. Set test pkr in 10-%" csg and test void between RBP and test pkr to 250/2500 psi. Upon successful test release test pkr and TOOH racking back 3 -' /z' IF DP leaving RBP in hole as a barrier. 3. Set test plug in 9 -5/8" csg. Install 7 -5/8" rams in btm cavity. PT BOPE body to 250/ psi. 3 ° ° fA' 4. Setup 7 -5/8" csg handling eqpt and TIH w/ Baker 7 -5/8" tie -back assembly on 7 -5/8" csg. 5. TIH to locate SBE in Baker ZXP liner top pkr. Calculate space -out requirements. PU just above SBE and reverse circulate in 9.3# /gal corrosion inhibited brine. Stab back into SBE. 6. ND BOPE w/ tbg head and land 7 -5/8" csg in slips. Cut 7 -5/8" csg w/ Wachs cutter. Install FMC packoffs. 7. NU BOPE w/ tbg head. PT packoffs to 250 /3Qnn psi. Set test plug and install blanking plug. 8. Install VBRs in btm cavity. PT BOPE to 250/6PCksi. Pull test plug upon successful PT. 9. MU and TIH w/ Baker RBP retrieval assembly. Release and retrieve Baker RBP. TOOH sideways. 10. MU and TIH w/ TC -ESP on 3 -1/2" tbg w/ 3 -1/2" x 7 -5/8" feed -thru pkr. 11. MU tbg hgr, make final splice of ESP cable to penetrators. Bullhead gelled diesel or IPF down the IA to 3000' MD. Land hanger. RILDS. 12. RU Slickline: RIH to set WRP below bottom mandrel. Set catcher sub on top. Proposed Procedure continued on next page: • . 13. RD Slickline. Pressure up on tubing to 4000 psi to set the packer. Hold and chart for 30 mins. Bleed tubing down to 1500 psi, PT annulus to 2500 psi. Hold and chart for 30 mins. Bleed IA to zero, bleed tbg to zero, quickly ramp up IA pressure to shear the SOV. Pull landing joint. 14. Install two -way check. ND BOPE. Test ESP cable integrity. 15. NU and test tree to 250/5000 psi. Pull two -way check. Set BPV and RDMO Nordic #3. Post -Riq Work: 1. Pull BPV 2. RU Slickline 3. Pull SOV from upper mandrel & replace w/ DV 4. Pull DV from bottom mandrel and replace w/ SOV 5. Pull catcher sub 6. Pull WRP 7. Handover to Ops • • ConocOPhilh p s Tabasco Well: 2T -202 2011 RWO OPTION #2 COMPLETION API: 50- 103 - 20254 -00 Conductor: PTD: 198 - 037 DS 16 ", 62.5 #, H -40 to 112' RKB Wellhead: FMC Gen IV X -mas Tree: 4- 1/16 ", 5K psi Production Casing: Lift Threads: 5" RH Acme 10 -3/4 ", 40.5 #, J -55 BPV: 4" CIW Type 'H' to 3677' RKB Proposed 3 - 1/2" Completion Production Liner • Tubing = 3 -1/2 ", 9.3 #, L -80, 8rd EUE 7 -5/8 ", 29.7 #, L -80 BTC -Mod • 2.313" DS- nipple at 500' 3427' to 3940' RKB • 3 -1/2" KBG2 -9 GLM GP Screens • Baker 3 -1/2" x 7" feed -thru packer 4 ", 11.6 #, L -80 BTCM -SCC • 3 -1/2" KBG2 -9 GLM 3946' to 4246' RKB • Baker Centrilift TC -ESP >3 x 4— 3 -1/2" x 7 -5/8" feed -thru pkr @ —2750 ft RKB Proposed 7 - 5/8" Csa String • 3 - 1/2 ", 9.3 #, L - 80, 8rd EUE • Casing = 7 -5/8 ", 29.7 #, L -80, BTCM J • Baker WELLLIFT Motor Gauge Unit < 4— New 7 -5/8 ", 29.7 #, L -80, BTC -Mod S w S r Baker ZXP Lnr Top Pkr @ 3441' RKB Baker HMC Lnr Hgr @ 3460' RKB 1 — Existing 7 -5/8 ", 29.7 #, L -80, BTC -Mod B 1 — Baker SC -1 Pkr @ 3824' RKB 4 U 4" Baker Weld GP Screens _ _ Last Updated: 18- Dec -11 Updated by: EQN 1 4.1P • 2T - 202 ConocoPtlillips A. ' a Well Attributes Max Angle & MD TD i Wellbore API /UWI Field Name Well Status In) MD (ftKB) Act Btm (ftKB) Alaska.lnc. Ind p) b 501032025400 TABASCO PROD 61.44 2,022.60 4,427.0 co, =^ Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date ••• Well Canfl9: -2T -202, 414/2011 244.41 PM SSSV: NONE 625 1/11/2009 Last WO: 5/25/2004 45.00 3/27/1998 Schemer - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 3640.0 6/25/2009 Rev Reason: FORMAT UPDATE Imosbor 4/4/2011 - Casing Strings HANGER, 33 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - -- CONDUCTOR 16 15.063 40.8 112.0 112.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 40.8 3,677.4 2,764.7 40.50 J - 55 BTC IN Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 75/8 6.750 3,441.2 3,940.0 3,018.3 29.70 L -80 BTC -MOD Liner Details Top Depth CONDUCTOR, al/o) Top Intl Nomi... I 41 -112 Top (ftKB) (ftKB) PI Item Description Comment ID (in) 3,441.2 2,547.2 27.78 PACKER BAKER ZXP LINERTOP PACKER 7.625 3,460.0 2,563.5 26.89 HANGER BAKER HMC LINER HANGER 7.625 i. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd GRAVEL PACK 63/4 4,248.0 4,427.0 3,491.9 SAND Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd GRAVEL PACK 5.1 3,946.0 4248.0 3,317.3 20 GAUGE LINER SCREEN _ Liner Details Top Depth GAS LIFT. _ (TVD) Top Intl Nomi... 3.00' Top (RKB) (ftKB) (1 Item Description Comment ID (in) I 3,946.0 3,024.1 14.37 Gravel Pack Screen I Tubing Strings Tubing Description TUBING s String 41/2 ( 0... String 3.9 ID 58 ... I Top (R32 I KB) Set 3 Depth I (f... Set Dep2 I th (ND) ... String 12 Wt... I String L - 80 l ... String B TCM Top Thrtl OD .5 Completion Detai Top Depth (ND) Top Intl Nomi... Top (ftKB) (RKB) (1 Item Description Comment ID (in) - .. 32.9 32.9 -0.86 HANGER FMC TUBING HANGER 4.500 3,360.3 2,476.0 31.09X04.5x3.5 3.500 e4 3617.3 2,707.5 18.20 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 3,694.1 2,780.8 15.64 GAUGE 2.992 3,704.1 2,790.4 15.59 DISCHARGE BAKER DISCHARGE w/GAUGES 0 00 3,704.6 2,790.9 15.59 PUMP UPPER BAKER UPPER PUMP 71 GC4 100 LT (3666' SLM) 0.000 3,716.1 2,802.0 15.51 PUMP LOWER BAKER LOWR PUMP 45 GC4 100 MT 0.000 3,733.5 2,818.8 15.43 INTAKE BAKER ESP INTAKE 0.000 3,734.5 2,819.8 15.42 SEAL BAKER GST3 TANDEM SEAL 0.000 In 3,748.3 2,833.0 15.36 MOTOR BAKER 418 HP KMH 2610/98 MOTOR 0.000 SLEEVE 3,x17 3,782.2 2,865.7 15.20 XO NIPPLE 2.000 3,782.4 2,865.9 15.20 Centralizer ESP GUIDE/CENTRALIZER i lk Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) CI Description Comment Run Date ID (in) SURFACE, A : - 4,167.0 3,238.3 12.75 FISH PLUG IPB LOST DOWNHOLE DURING WORKOVER 5/24/2004 41 - 3,677 5/24/2004 Perforations & Slots Shot DISCHARGE, Top (TVD) Btm (TVD) Dens 1111 . 3,704 1� Top (ftKB) Btm (11K13) (ftKB) (ftKB) Zone Date )sh -• Type Comment PUMP UPPER. [;'.� 3,962.0 4,246.0 3,039.6 3,315.3 TABASCO, 12/31/1998 50.0 Screen 3,705 /.ct 1 TE_1, 2T - 202 PUMP LOWER, 3,716 '., I Notes: General & Safety _ End Date Annotation INTAKE, 3734 - _ -- 5/24/2004 NOTE: TIE -BACK LINER PULLED 1/1/1999 SEAL, 3,735 4 - 5/24/2004 NOTE: PACKERLESS COMPLETION - POOR DETAIL SHEETS FOR ORIGINALNVO 1/13/2011 NOTE: View Schematic w/ Alaska Schematic9.0 MOTOR, 3.748 XO NIPPLE, 3,782 centralizer, 3,782 1 Mandrel Details Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run LINER IL Top (RKB) (RKB) (`) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 3.441 -3,240 1 3,000.7 2,193.9 44.74 CAMCO KBG - 2 1 GAS LIFT DMY BK - 5 0.000 0.0 5/24/2004 Screen, �' 3,9624.246 . ' FISH, 4,167 GRAVEL PACK LINER SCREEN, k A 3,94, GRAVEL L PACK SAND, 4,2484,427 TD, 4,127 " • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Rsc4/4 1. Operations Performed: Abandon ❑ Repair well ❑ Rug Perforations ❑ Stimulate ❑ Other [ Conductor Pull Tubing Perforate New Pool Waiver Extension After Casing ❑ 9 ❑ ❑ ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory ❑ •• 198 -037 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic El Service' ❑ . 50- 103 - 20254 -00' Q© 7. Property Designation (Lease Number): 8. Well Name and Number. ADL0025569 • 2T - 202 9 Field /Pool(s): Kuparuk River Field / Tabasco Oil Pool 10. Present Well Condition Summary: Total Depth measured 4427 feet Plugs (measured) None true vertical 3492 feet Junk (measured) None Effective Depth measured 3441 feet Packer (measured) 3734 true vertical 2546 feet (true vertucal) 2819 Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 112 112 0 0 SURFACE 3637 10 3/4 3677 2765 0 0 LINER 499 7 5/8 3940 3018 0 0 GRAVEL PACK L 302 5.1 4248 3317 0 0 1 Perforation depth: Measured depth: 3962 - 4246 rs. f True Vertical Depth: 3040 - 3315 , ' "" :flit i) ll :mi. Tubing (size, grade, MD, and TVD) 3.5, L -80, 3704 MD, 2790 TVD Allot ' .;' G ' & ttgAz si,ifl3lSSlpf, Packers & SSSV (type, MD, and TVD) INTAKE - BAKER ESP INTAKE @ 3734 MD and 2819 ND NONE - Type Not Found (Manual Entry Required) @ 0 MD and 0 ND 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. 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 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development NI . Service ❑ Stratigraphic ❑ X 15. Well Status after work: Oil Mi Gas ❑ VVDSPL ❑ Daily Report of Well Operations GSTOR ❑ VVINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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 311 -166 Contact MJ Loveland / Martin Walters Printed Name MJ Lov= land / Title WI Poroj Supervisor Signature Phone: 659 -7043 Date 8/2/11 R8 bMS AUG Q 8 /69(494 Form 0 -404 Revised 10/2010 Submit Oriainal Only • • 2T -202 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06111/11( Welded 20" long piece of 16" conductor on as extension. 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' • • " ' . -..'-'4r•-Q.:-..2','-.P.f..;',:t '7,1.47i. ,;.",.-...'-',,I,ii:../-;::.7., ..': 7 ';',.,:", 1 "; ' .': ' ' . • _. . , . • , . .. ' '‘'..4 ''.: ......_•:`;.1..i,57,,,A......., ,.• , ,'„ :::,,''' - .'' :.' ,•"`' ; ,. ,'"'r ":',.• • i : ,,,' , -,' ,..,-;' • ' . . , ' ' , ' . , .. • ",..:1,77,4%t",7"'-'•,",..',..:::-.7,"...7.• ,''' '... • :,' • ' ' ,'"' . ...;: '''' - • ' ' ' -- ' ..01 ' ' ';....- i 1 el . . . . . . I t' fil 1 41/f"" 4 iff • - _ 117 9 , ,. A. 4 •4`47 / 7 , „, ',.. ,1; 0•:. f A il .. . . 1 4- • : - 1 v - . - 17 , N . . t.-- _., ,.... , 4 e I',7 4 e 4.,if •,1::: , ,,!.. ..:, ..fr r• q . .. .. 41 '.' ; :fit.; 'qeirip, '''' 1 ....'" ' . l'I . fr r . 7 -•-• ' ..,/ ,Irl • P .. ' '',( ■ . • ; ' ,4 / t J . / fifir .- ......: ‘ i f, •' it .4"-K - • " t• i 1 4 .,,,,,, .,-1. . a , . ''' 1 ,. ,,-• ..,,,.5%.2,::-,--:-.:,,g.:%,, ,.7 I . :_,.,.......... ' .'. ... . ' ' • ' ''' ' • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 30, 2011 *ANitiED JUL 4P L ! ; amp•_ TTitcv � v fJ Commissioner Dan Seamount ' ' Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 t. Anchorage, AK 99501 uf' `" " iaz�A �� . C'diredissiOn Commissioner Dan Seamount: 7 aoc2- Enclosed please fmd 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. The cement was pumped on 5/23, 2011. The corrosion inhibitor /sealant was pumped 6/22, 6/24, 6/25, 6/26, and 6/27, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, MJ Lo land ConocoPhillips Well Integrity Projects Supervisor • • I ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 6130111 2F,2M,2N,2T,2X,2Z,3B,30 PAD 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 2F -19 50029227280000 1962010 8" N/A 23" N/A 13 6/25/2011 2M -09A 50103201770100 1960900 _ SF WA 18" N/A 3.5 6/26/2011 - 2M -14 50103201730000 1920630 SF N/A 19" _ N/A _ 3.5 6/26/2011 2M -17 50103201500000 1910180 SF N/A 19" N/A 3.5 6/26/2011 2M -26 50103201720000 1920550 SF N/A 21" N/A 3.5 6/26/2011 2N -316 50103203420000 2000900 SF N/A 18" N/A 4 6/27/2011 2N -318A 50103203430100 2090220 10" N/A 27" N/A _ 7 6/27/2011 2T-40 50103205280000 2060400 2' N/A 2' N/A - 6 6/26/2011 2T-202 50103202540000 1980370 6" N/A 20" N/A 9 6/26/2011 2X -07 50029209910000 1831130 SF N/A 21" N/A 2 6/25/2011 2X -08 50029209920000 1831140 SF N/A _ 21" N/A _ 2.5 6/25/2011 2Z -02 50029209600000 a 1 830800 18" N/A 18" N/A 2.6 6/24/2011 3B -01 50029213180000 a 1 850560 SF 1.50 17" 5/23/2011 _ 6 6/22/2011 30 -12 50029218040000 1 880410 SF N/A 22" _ N/A 1.7 6/22/2011 N T SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 MJ Loveland Well Integrity Project Supervisor �'; MAY` ConocoPhillips Alaska, Inc. t P.O. Box 100360 S 0 , Anchorage, AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, 2T -202 Sundry Number: 311 -166 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. `/� Chair DATED this /i° day of May, 2011. Encl. • STATE OF ALASKA (Pi 1 ' ALASKA'', AND GAS CONSERVATION COMMISSI� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: Conductor ExtensiorP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r • Exploratory r 198 - 037 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20254 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 2T -202 . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025569 ° Kuparuk River Field / Tabasco Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4427 • 3492 • 3441' 2546' Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 16 112' 112' SURFACE 3637 13 3677' 2765' LINER 499 10.75 3940' 3018' GRAVEL PACK LINER 3317' SCREEN 302 5.1 4248' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3962 - 4246 3040 - 3315 3.5 L - 3704 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) ESP no Packer MD= TVD= no Packer NONE - MD= TVD= no SSSV 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r . Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/15/2011 Oil r - Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland / Perry Klein Printed Name MJ Loveland Title: WI Poroj Supervisor Signature / /C r Phone: 659-7043 Date - Commission Use Only Sundry Number:51 ` ..- Conditions of approval: Notify Commission so that a representative may witness 11 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED Other: 4" 1 le. d4C-C4-" cCS gi ro ( I".( MAY . J 1. ?O11 Alaska fail & fki$ Com Con Consrlisaion Subsequent Form Required: 10 — yo d / , I tnel'age APPROVED BY �/ / / I Approved by .S' / COMMISSIONER THE COMMISSION Date: j� / ORIGIN L 4P Form 10d0�+� �� Su bmit in Duplicate .404r/4 • • ConocoPhillips Alaska, Inc. Kuparuk Well 2T -202 (PTD 198 -037) SUNDRY NOTICE 10 -403 APPROVAL REQUEST May 9,2011 This application for Sundry approval for Tabasco well 2T -202 is to extend the conductor to original height so as to prevent any further corrosion to SC. This well is a Tabasco ESP well and is currently on line. At some point during normal operations the conductor subsided about 14 inches. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor. 2. Examine SC below where landing ring was for any corrosion damage. 3. Install anti - corrosion coating on SC as specified by CPAI Corrosion Engineer. 4. Extend the conductor to braiden head and fill the void with cement and top off with sealant. 5. File 10 -404 with the AOGCC post repair. NSK Problem Well Supervisor 05/07/05 ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Shut-in Bottom Hole Pressure: 2T-202 Run Date: 6/25/2009 • August 28, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-202 Digital Data in LAS format, Digital Log Image file ~~ ~~;~, , 1 CD Rom . •ttj:,;~~ _ ~~'.tl~~.r 50-103-20254-00 ~ ~ ~~~-03~- 1~s~9~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto halli~u c ~ :t ~. ; ~~~ ~f' Date: SEP Q ~ 2009 ~~~ska ~~4 ~ C~as Gaas, l,cs;~~issi~rF Ancho~a~~ Signed: ~ ( ( Mike Mooney Wells Group Team Leader Drilling & Wells y ConocoPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 June 14, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 2T-202 (APD # 198-037 / 304-167) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 2T -202. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ),{ A4~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells RECEIVED MM/skad tJ LJ N'i5 2004 Aiaaka ou &, Gas Cons. Comm_n AnctM.age Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing D Operat. ShutdownD Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 198-037 1 304-167 6. API Number: 50-1 03-20254-00 Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic 0 Exploratory D Service D P. O. Box 100360 7. KB Elevation (ft): RKB 41' B. Property Designation: ADL 25569 1 ALK 2667 9. Well Name and Number: 2T -202 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Tabasco Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION CSG WINDOW Perforation depth: measured 4427' feet true vertical 3492' feet measured 3441' feet true vertical 2546' feet Length Size MD 112' 16" 121' 35551 10-3/4" 3677' 549' 7-5/8" 3940' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 2764' 30181 Measured depth: screen 3946'-4246' RECEIVED true vertical depth: 3024'-3316 tJ U N'j .1 ?OO4 AJøa Oil & Gas Cons. Comm_ffD MOOmge Tubing (size, grade, and measured depth) 4.5" 13.5", L-BO, 3327' 13672' MD. Packers & SSSV (type & measured depth) Baker SC-1 gravel pack pkr @ 3824' no sssv 12. Stimulation or cement squeeze summary: Intervals treated (measured) n/a 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1831 1463 88 2624 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A it C.O. Exempt: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Form 1 0-404 Revised 04/2004 Contact Printed Name Signature n/a Oil-Bbl 720 754 Casinq Pressure Tubinq Pressure 374 259 Abandoned D WDSPLD Jim Ennis @ 265-1544 Jim Ennis ;¡;J J1~ Title Phone [ngil,eer-- r /A~// / L1 Wells Group Date 6/ , 7,/°1,""826$-4612 b Sharon AI/sur;- Prepared v JUM 1,6 100\ Submit Original Only L (' f ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-202 Common Well Name: 2T-202 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code 5/9/2004 00:00 - 02:30 2.50 MOVE RURD DEMOB 02:30 - 09:00 6.50 MOVE RURD DEMOB 09:00 - 10:00 1.00 CMPL TN SFTY DEMOB 10:00 - 15:00 5.00 MOVE DEMOB 15:00 - 1B:00 3.00 MOVE MOVE DEMOB 1B:00 - 00:00 6.00 MOVE RURD DEMOB 5/1 0/2004 00:00 - 04:00 4.00 MOVE RURD RIGUP 04:00 - 06:00 2.00 WELCTL KILL DECOMP 06:00 - OB:OO 2.00 WELCTL KILL DECOMP 08:00 - 09:10 1.17 WELCTL KILL DECOMP 09: 10 - 09:20 0.17 WELCTL KILL DECOMP 09:20 - 11 :00 1.67 WELCTL KILL DECOMP 11 :00 - 12:00 1.00 WELCTL KILL DECOMP 12:00 - 13:00 1.00 WELCTL NUND DECOMP 13:00 - 15:30 2.50 WELCTL NUND DECOMP 15:30 - 1B:00 2.50 WELCTL OTHR DECOMP 18:00 - 00:00 6.00 WELCTL BOPE WRKOVR 5/11/2004 00:00 - 01 :00 01 :00 - 02:00 1.00 WELLSR PULD DECOMP 1.00 WELLSR PULD DECOMP 02:00 - 04:30 2.50 WELLSR PULD DECOMP Page 1 of 6 Start: Rig Release: Rig Number: Spud Date: 3/8/1998 End: Group: 5/8/2004 Description of Operations Break apart BOPE for transport. Prep pipe shed for move. Prep rig to lower derrick. Lower derrick @ 02:30 hrs. Rigging down Handy Berm. RID Sub, pipe shed & motor complex. Prep for move. Held Pre-Workover Mtg for 2T-202 wI the rig crew, tool pusher, co-man, centrilift reps, & fmc rep. Called for Trucks to move rig @ 11 :00 am. Trucks showed up on location @ 13:30. Moved rig off of pad @ 15:00. Rig left 1 D pad at 15:00 hrs moved to 2T -202. Arrived on pad at 1B:00 hrs. ACCEPTED RIG @ 16:00 HRS BECAUSE 2T-202 PREP WORK NOT READY FOR RIG. Adjusted level on pad around well. Spotted BOPE behind well. Set rig mats and spot rig over well, begin setting up and leveling. Spot pit section and pipe shed, connect utilities, mud lines. Raise derrick, scope up and latch down. Set kill tank, berm up and RIU hardline. Set ESP cable spooler & berm up. Set Handy Berm under rig for containment. Called for 2 loads (560 bbls) of seawater and LRS to heat up to 160 deg. . RIU lubricator and pull BPV; Load Pits wI 160 degree seawater and prepare to pump. LRS hot oil truck continued to heat the other vac truck. 700 psi on the inner annulus. Bled gas to tank. Bled down to 50 psi. Begin pumping 160 degree seawater @ 1 BPM then walked up to 3 BPM. Only gas returns at the tanks. 60 bbls pumped and started getting intermittent returns at the tanks (gas & crude). Pumping @ 3 BPM and WHP = 225 psi. 310 BBLS pumped with 210 BBLs in the Tanks. Returns are pretty much 1 for 1 now. Finished circulating hot 160 degree seawater around. Total pumped 520 BBLs and obtained 400 bbls of returns. Both Tubing and Inner Annulus are dead with 0 psi. FMC Rep installed BPV and depressured Voids. Took pictures of Tree for re-alignment post workover. Begin nippling down the Tree. Nippled up BOPE. Contacted the AOGCC (14:45 05/10104), Chuck Sheve waived the witnessing of the BOP test. Continued NU BOPE. Discovered that the Rig was not centered over the hole properly. Attempt to adjust without lowering the derrick. Adjusted wellhead position and NU flownipple. Everything looks straight. Problem was not how the rig was spotted but the wellhead loose would not allow flow niplle to line up. Hook up accumolater lines to BOPE.Test BOP Blinds, Choke Manifold, HSR's, Manual's, Floor Safety valves, 4.5" Pipe Rams, and Accumalator, 250 Low 3500 psi High. Pulled test jt, blanking plug and verified well is dead, pulled BPV. Picked up 4.5" landing jt. screwed into hanger. B.O.L.D.S. Pull tubing hanger to rig floor. Pulled max. 60K. Up wt. 35K dwn wt. Well is dead, standing full. All equipment was intact at surface, heat trace, ESP cable and tubing. All clamps at the top of the string are in good shape. Measured the distance from the hanger to the mark on the landing jt. @ 22' 6". Monitored well to ensure well is dead, took 5 bbls to fill. RU cable spooler, heat trace spooler. RU cable sheave in derrick along Printed: 6/3/2004 10:41 :30 AM , ( ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T -202 Common Well Name: 2T-202 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code 5/11/2004 02:00 - 04:30 2.50 WELLSR PULD DECOMP 04:30 - 11 :00 6.50 WELLSR PULD DECOMP 11 :00 - 13:00 2.00 WELLSR PULD DECOMP 13:00 - 22:00 9.00 WELLSR PULD DECOMP Page 2 of 6 Start: Rig Release: Rig Number: Spud Date: 3/8/1998 End: Group: 5/8/2004 Description of Operations with the elephant trunk for containment. POOH standing back 4.5" tubing in derrick, removing bands and clamps, spooling up ESP cable and heat trace. 2B stands pulled. Interior of tbg beginning to look bad/corroded; ext showing little corrosion. Still recovering all bandslchannel. Begin laying down tbg. LD remainder of 4.5" tubing, 3 jts 3.5" and 3 jts 2.B75" all junk, very corroded. The lower section of the tubing missing bands and flat guards. No way to count how many are missing. With bands broken the flat guards drag on the BOP and fall back down the hole, some hanging up on the ram cavity of BOP. LD all of completion equipment and NORM tested. Last 20 joints of tubing heavily corroded with holes through tubing body. 22:00 - 23:00 1.00 WELLSR OTHR DECOMP Clean up rig floor and all of tools used to POOH. Removed heat trace spool from rig floor. Removed all of bands, clamps and flatguards out to Berm area for NORM testing. 23:00 - 00:00 1.00 WELLSR OTHR WRKOVR Open pipe ram doors. Clean debris (bands, clamps or flat guards) from stack. 5/12/2004 00:00 - 02:00 2.00 FISH OTHR WRKOVR Button up ram doors. Pull flow nipple out to cut off 1 ft. 02:00 - 03:30 1.50 WELCTL BOPE WRKOVR Set test plug, close blinds and press test body to 3500 psi. Confirmed with Chuck Sheve wlState no witness necessary. 03:30 - 04:00 0.50 CASE MIT WRKOVR Pulled test plug. Installed Wear Ring. LD test jt. Closed Blinds and press test casing to 1500 psi for 10 min. Held OK. 04:00 - 04:30 0.50 WELLSR PULD DECOMP Change out elevators and rig up to LD remainer of 4.5" tubing. 04:30 - 15:00 10.50 WELLSR PULD DECOMP UD 4.5" tubing from derrick. NORM test and junk. Swap BOP inserts to 3-1/2", load pipe shed for fishing run. Test BOP to 3500 psi--good. 15:00 - 19:00 4.00 FISH TRIP DECOMP Make up first section of BHA; wear ring ID is egg shaped and won't let mousetrap pass through. Send WEAR RING to machine shop to have id opened up to 6-7/8 min. 19:00 - 00:00 5.00 FISH TRIP DECOMP Install wear ring with 6-7/8" ID. MIU BHA for fishing bands, clamps and flat guards and RIH picking up 3-1/2" PH-6 P-11 0 workstring. 5/13/2004 00:00 - 01 :30 1.50 FISH TRIP WRKOVR Continued to RIH picking up 3-1/2" P-11 0 workstring. Tagged obstruction @ 3391'. 01 :30 - 02:00 0.50 FISH FISH WRKOVR Attempted to work over junk with mouse trap by rotating with tongs. No luck. 02:00 - 07:00 5.00 FISH RURD WRKOVR UD elevators and bails. Pick up and NIU Power Swivel. Attempt to rotate through trash, speed limited by rig hydraulics. 07:00 - 08:30 1.50 FISH FISH WRKOVR Attempted to locate proper Xover to tie kelly hose into swivel. Unable to circulate without hose. Made it approx. 2' further, unable to make it deeper, Mouse Trap plugging off. 08:30 - 15:00 6.50 FISH TRIP WRKOVR Stand back Power Swivel. Trip out of hole. 15:00 - 16:00 1.00 FISH TRIP WRKOVR Clean wash pipe out. Lots of scale, parts of bands. Cleaned rig floor and tools. 16:00 - 19:30 3.50 FISH TRIP WRKOVR PIU BHA #2 (fishing tools) added a pump out sub, Xover and extention. 19:30 - 21 :30 2.00 FISH TRIP WRKOVR RIH WIBHA #2 on 3-1/2" workstring. Tagged up on fish @ 3425'. 21 :30 - 23:30 2.00 FISH TRIP WRKOVR Picked up Power Swivel and RIU Kelly hose. 23:30 - 00:00 0.50 FISH OTHR WRKOVR Established circulation (reversing)@ 3BPM, tagged up on fish at 3415',10' higher, rotating down over junk in hole. Lots of black scale over shakers. Rotating down. Starting press = 300 psi started plugging off, press = 1000 psi. Up wt 45K Dwn wt 35K RTWT 40K 5/14/2004 00:00 - 00:30 0.50 FISH TRIP WRKOVR N/D and Stand back Swivel. 00:30 - 04:30 4.00 FISH TRIP WRKOVR POOH standing back pipe until wet. Dropped ball and press up to Printed: 6/3/2004 10:41 :30 AM '{ ConocoPhillips Alaska Operations Summary Report Page 3 of 6 Legal Well Name: 2T-202 Common Well Name: 2T-202 Spud Date: 3/8/1998 Event Name: WORKOVER/RECOMP Start: 5/8/2004 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 5/14/2004 00:30 - 04:30 4.00 FISH TRIP WRKOVR shear out pump out sub to 2000 psi. Continued to POOH. 04:30 - 06:00 1.50 FISH TRIP WRKOVR Break out mouse trap and clean out one flatguard, and 5 gal bucket of small pieces of bands and scale. 06:00 - 12:00 6.00 FISH TRIP WRKOVR Make up fishing BHA #2 (same as previous, added 1 jt of washover pipe). Begin trip back in hole. 12:00 - 13:30 1.50 FISH FISH WRKOVR Tag top of trash at 3423', rev circulate wI sw over fish. Swept hole wI 15 bbl 2# gel. Circ press increased to 600, rising to 1100 psi as we tried to wash through; unable to clear string string. l' deeper than tag. 13:30 - 14:30 1.00 FISH PULD WRKOVR NID and stand back power swivel. Begin POOH. 14:30 - 18:00 3.50 FISH TRIP WRKOVR Dropped ball and press up to shear pump out sub to 1200 psi. POOH standing back in derrick. 18:00 - 19:00 1.00 FISH TRIP WRKOVR Clean ou mouse trap, more flate guards and bands. UD one jt of wash pipe and changed mill on mouse trap. Clean all debris from fig floor. 19:00 - 22:00 3.00 FISH TRIP WRKOVR Run work string back in hole from derrick. 22:00 - 00:00 2.00 FISH TRIP WRKOVR RIU Power Swivel. Establish circulation and lowered to fish Tagged higher at 3414' 5/15/2004 00:00 - 02:30 2.50 FISH MILL WRKOVR Reverse pumping @ 5BPM, 300 psi. Tagged at 3414' milled back down to 3425'. Max pump press 1270 psi @ 5 BPM. Press up several times a blew loose dropping pressure. Finally plugged off and would not blow loose. 02:30 - 03:30 1.00 FISH TRIP WRKOVR Bled off press. Cleared all lines, NID and stand back Power Swivel. Install Bails & elevators. Open pump out sub. 03:30 - 07:00 3.50 FISH TRIP WRKOVR POOH with BHA to clean out and re-run. 07:00 - 08:00 1.00 FISH PULD WRKOVR Recovered approx. 5 gal bucket of bands, channel. Clean rig floor of all debris. Rig back up, re-run same BHA as previous exc. head was swapped out with same wlo mousetrap and v-groove "fingers". 08:00 - 12:00 4.00 FISH TRIP WRKOVR RIH (drift every stand) tag at 3419'; rig up power swivel. 12:00 - 13:00 1.00 FISH MILL WRKOVR While making up Power Swivel to workstring, swivel torqued through air tugger lines set to stabilize swivel causing cablelhoses to wrap around string/block. The control valve for the Swivel does not have a stop to keep from moving from one position to another. See Near Miss Report. Untangle cables and hoses. 13:00 - 14:30 1.50 FISH TRIP WRKOVR Continued to RIU Power Swivel. 14:30 - 17:00 2.50 FISH MILL WRKOVR Appeared to work thru Bridge @ 3419'. Worked through liner top into 7-5IB" casing. Set back Power Swivel in mouse hole. 17:00 - 18:00 1.00 FISH MILL WRKOVR Continued in hole occasionally hitting obstructions and falling thru pushing junk down to 3759', plugginfg off again. Reverse circulate hole clean and RID Power Swivel and set back in Rat Hole. 1B:00 - 19:30 1.50 FISH CIRC WRKOVR Reverse circulate hole clean, slowed pumps down because pressures reaching 1250 psi. RID Power Swivel and set back into Rat Hole. 19:30 - 23:00 3.50 FISH TRIP WRKOVR POOH w/BHA. Junk basket, jars & washpipe full of parts of bands, clamps or flatguards. 23:00 - 00:00 1.00 FISH TRIP WRKOVR Change out Mouse TraplMill, clean rig floor of all loose debris. 5/16/2004 00:00 - 03:30 3.50 FISH TRIP WRKOVR Put Mouse Trap back in BHA and trip in hole on workstring. Tagged obstruction @3432'. Rotated and worked down, tagged top of liner @ 3441'. Rotated and worked past liner top. Ran on down to same spot from last run @ 3759' 03:30 - 04:30 1.00 FISH TRIP WRKOVR RID elevators & Bails, power tongs.. PU and MU Power Swivel. 04:30 - 06:00 1.50 FISH MILL WRKOVR Established reverse circuating. Start milling on junk 3755' with mill and Mousetrap.Made approx. 4' back down to 3759'. Plugged off, pump press up to 1250 psi. Pumped sweep around. 06:00 - 07:30 1.50 FISH PULD WRKOVR N/D Power Swivel. RIU Bails & elevators and power tongs. 07:30 - 12:00 4.50 FISH PULD WRKOVR Begin POOH racking back pipe. At surface, break down BHA and clean Printed: 6/3/2004 10:41 :30 AM Page 4 of 6 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 2T-202 Common Well Name: 2T-202 Event Name: WORKOVERlRECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code 5/16/2004 07:30 - 12:00 4.50 FISH PULD WRKOVR 12:00 - 13:00 1.00 RIGMNT RSRV WRKOVR 13:00 - 14:00 1.00 FISH TRIP WRKOVR 14:00 - 14:30 0.50 RIGMNT RGRP WRKOVR 14:30 - 16:30 2.00 RIGMNT RGRP WRKOVR 16:30 - 18:00 1.50 FISH WASH WRKOVR 18:00 - 19:00 1.00 WAlTON EQIP WRKOVR 19:00 - 21 :00 2.00 FISH TRIP WRKOVR 21 :00 - 22:00 1.00 FISH TRIP WRKOVR 22:00 - 00:00 2.00 FISH MILL WRKOVR 5/17/2004 00:00 - 01 :00 1.00 FISH MILL WRKOVR 01 :00 - 02:00 1.00 FISH TRIP WRKOVR 02:00 - 06:00 4.00 FISH TRIP WRKOVR 06:00 - 06:30 0.50 FISH PULD WRKOVR 06:30 - 11 :30 5.00 FISH TRIP WRKOVR 11 :30 - 15:00 3.50 FISH MILL WRKOVR 15:00 - 16:00 1.00 FISH PULD WRKOVR 16:00 - 20:00 4.00 FISH TRIP WRKOVR 20:00 - 00:00 4.00 WELCTL BOPE WRKOVR 5/18/2004 00:00 - 01 :30 1.50 WELCTL BOPE WRKOVR 01 :30 - 04:00 2.50 WELCTL BOPE WRKOVR 04:00 - 06:00 2.00 WELCTL BOPE WRKOVR 06:00 - 07:00 1.00 WELCTL BOPE WRKOVR 07:00 - 10:00 3.00 FISH TRIP WRKOVR 10:00 - 12:00 2.00 FISH FISH WRKOVR 12:00 - 13:30 1.50 FISH FISH WRKOVR 13:30 - 15:00 1.50 FISH RURD WRKOVR 15:00 - 16:00 1.00 FISH RURD WRKOVR Start: Rig Release: Rig Number: 5/8/2004 Spud Date: 3/8/1998 End: Group: Description of Operations out mousetrap--recovered 5 gal bucket of "wadded" channel & bands. Lubricate rig. Begin RIH with new BHA. Change out elevators. Baker elevators cracked. Sent back in for repairs. MU rig elevators. Begin working on Power Swivel controls-- install flow control valve due to problems from yesterdays NEAR Miss. Charged as REPAIR TIME. RID Power Swivel, RIU bails elevators and tongs. Start RIH. Rig elevators broken. Wait on delivery of elevators from another rig. Continued in hole tl3742' (worked tight spot @ 3742'). Ran on down tagged @ 3759'. Gave AOGCC 24 hr notice of Weekly BOP test. (John Krisp). RID bails, elevators & power tongs. RIU Power Swivel. Start pumping and rotating, washing (milling) down to 3759' Continued mill on junk @ 3759' very slowly. Pump press 340 psi @ 5 BPM. Milled in same spot for 2 hrs. started milling down to 3760' plugged off again. Pump press 1300 psi. Shut down press bled off to BOO psi. Back flushed thru surf lines, no evidence of plugging on surface. RID Power Swivel, R/U bails, elevators, and power tongs. Begin tripping out of hole. Dropped ball and sheared pump out sub. POOH. Pipe pullled dry up to 1300' started pulliing wet. Trash on ball of pump out sub. At surface; clean out mousetrap. Recovered approx. 3 gals trash--bands, channel. Begin trip back in hole. Tag top of fill at 3756' (lost 4'); Pick up off and begin rev-circ @ 4 bpm, 340 psi. RIH and begin milling on trash, make slow progress to 3765'. Circulating press increse to 1300 psi, not making anymore hole. RID Power Swivel Begin tripping out of hole. Notify State Rep John Crisp of BOP test once out of hole. State waived witnessing test. Clean out BHA. Pull wear bushing, install test plug & test jt. Fill stack & choke manifold. Weekly BOP test to high 3500 psi low 250 psi. Test BOPE & choke tl250 low 3500 high. Annular Preventer would not test. Removed riser & Xover on top of Annular. Pulled mouse hole, R/U tire move Annular cap and replace bag (element). Replace mouse hole and riser and return to testing. Complete testing blinds and choke. Install wear bushing. RID testing equipment Make up same BHA; begin trip back in. Stood up at liner top @3441'. PU power swivel and make up crossovers. Rotate through liner top. Set back power swivel in rat hole slot. Cont RIH to TOF @ 3765'. Make up power swivel. Torque up connections below power swivel. Extreme issues with the way we are dealing with the power swivel. It almost hinges on safety issues making up the tool joints below the power swivel. Very time consuming and indeed improvements must be made. Unable to reinstall mousehole that was removed for bag change-out Printed: 6/3/2004 10:41: 30 AM II; '~ Page 5 of 6 ConocoPhillips Alaska Operations Summary Report 2T-202 2T -202 WORKOVER/RECOMP Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/1BI2004 5/19/2004 5/20/2004 Nabors 3S From - To Hours Code î~dbe Phase 15:00 - 16:00 16:00 - 18:00 1B:00 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 09:00 09:00 - 10:30 10:30 - 11 :45 11 :45 - 12:30 12:30 - 13:50 13:50 - 14:52 14:52 - 16:00 16:00 - 19:00 19:00 - 23:00 23:00 - 00:00 00:00 - 04:00 04:00 - 05:30 1.00 FISH 2.00 FISH 2.00 FISH 0.50 FISH 0.50 FISH 1.00 FISH 2.00 FISH 1.50 FISH 0.50 FISH 7.00 FISH 1.50 FISH 1.25 FISH 0.75 FISH 1.33 FISH 1.03 FISH 1.13 FISH RURD WRKOVR MILL WRKOVR MILL WRKOVR MILL WRKOVR CIRC WRKOVR TRIP WRKOVR TRIP WRKOVR TRIP WRKOVR TRIP WRKOVR TRIP WRKOVR RURD WRKOVR CIRC WRKOVR FISH WRKOVR FISH WRKOVR FISH WRKOVR CIRC WRKOVR 3.00 WELLSR SFTY WRKOVR 4.00 FISH 1.00 FISH 4.00 FISH 1.50 FISH TRIP WRKOVR TRIP WRKOVR TRIP WRKOVR WASH WRKOVR Start: Rig Release: Rig Number: 5/8/2004 Spud Date: 3/8/1998 End: Group: Description of Operations operation. Bring in supersucker to remove sloughed in gravel. Install mousehole. Working wash tools up and down on fill. 350 psi ICP. 50 psi IDPP. Up wt = 55K. Down wt = 48K. One time over pull of 25K. Casing pressure worked up to 600 psi. during washover. Cable wrapped around blocks twice. Able to continue after tighting up tuggers. This area also needs improvement. Finally broke through heavy milling are around 3,788' RKB. able to make hole at will. Appears that circulating 1 1/2 bottoms up prior to making a connection has helped us speed the process a bit. Prep to make up joint #115 for tagging up on crossover. Wash sand with little restriction down to TOL @ 3824'. Firm tag. 200 G PM- 500/650 psi 20 RPM - 3000 ftlbs (1000 psi hyd press) Circ hole clean prior to POOH. Good amount of sand in returns. Rig down and set back power swivel in rathole. Install bails and elevators. POOH to recover junk. Cont POOH with wash pipe assy. Recover 3-41bs steel bands. UD wash pipe assy. MIU IBP retrieving tool & 3 jnts 2 3/8" Hydril 511 - jar and DCs. RIH Backload water from pits and clean pits for taking on filtered seawater. Lots of sand in pits. Finish pits. Stby for sea water. Begin reversing out to top of IBP. Dwn wt = 44K. Begin gel sweep, 220 PSI @ 3 BPM w/GEL. 6BO PSI @ 5 BPM w/SW. Stop at 3,B76' Circulate clean SW to Surface. 10,B20 strokes, 320 BBLS. 620 PSI casing pressure. 35K DWN WT. Pick up joint 116. Unable to see IBP. Washed through what appears to have been a sand bridge or? Up wt = 52K DWN 48K. Begin to PUH. UP wt = 75K Appears that we have settled sand around us. Prep to set back one stand and circulate bottoms up. Attempt 0 reverse out sand. Plug tubing up several times. Swap to Circulate dwn tubing taking returns up the casing. Able to break circulation by jogging pipe with 200 PSI on tubing. Pump 1400 strokes and begin to reverse out. PUH to safety for RIG assesment meeting at the EMOC. Rig Assesment and improvement meeting number 1- with Mike Mooney, Marty Lemon, and both Day and night Crews of Nabors. Day CO rep William Rauchenstein, Night CO rep Arvid Mosnes. . POOH with IBP retrieving tool. Found error in DP tally. 114 jnts run, not 116 as planned. Depth had been 3861', ie 3' above IBP setting depth. Recovered pieces of steel bands in retrieving tool. Prepare additional 2 3/8" flush joint pipe, Hydril 511 to be able to push IBP below gravel pack screen at 4246' if unable to latch. Commence RIH with IBP retrieving tool. Cont RIH with IBP retrtieving tool on 16 jnts 2 3/8" - 2 x boot basket - jars - 4 3/4" DC & 31/2" workstring. MIU circ hose and wash down onto IBP at 3B64'. Made several attempts to engage wlo success. Pumped 20 bbl hi-vis pill while reciprocating tool above IBP. Latch IBP and allow to equalize, but no losses. Pull up and partly release IBP, minor losses. Allow packer to Printed: 6/3/2004 10:41 :30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/20/2004 5/21/2004 5/22/2004 ... ~ ( ConocoPhillips Alaska Operations Summary Report 2T-202 2T-202 WORKOVER/RECOMP Nabors 3S From - To Hours Code 6'ouJe Phase 04:00 - 05:30 05:30 - 07:00 07:00 - 13:45 13:45 - 15:15 15:15 - 00:00 00:00 - 02:00 02:00 - 04:30 04:30 - 05:00 05:00 - 10:00 10:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 06:00 06:00 - 10:30 1.50 FISH WASH WRKOVR 1.50 FISH CIRC WRKOVR 6.75 FISH TRIP WRKOVR 1.50 WELLSR SLlN WRKOVR B.75 WELLSR SLlN WRKOVR 2.00 CMPL TN OTHR WRKOVR 2.50 CMPL TN RUNT WRKOVR 0.50 CMPL TN SFTY WRKOVR 5.00 CMPL TN RUNT WRKOVR 13.00 CMPL TN RUNT WRKOVR 1.00 CMPL TN RUNT WRKOVR 2.00 CMPL TN RUNT WRKOVR 0.50 CMPL TN RUNT WRKOVR 3.50 CMPL TN NUND WRKOVR 4.50 CMPL TN NUND WRKOVR Page 6 of 6 Start: Rig Release: Rig Number: Spud Date: 3/8/1998 End: Group: 5/8/2004 Description of Operations deflate for 10 min, pull up 4' and well went on massive loss. Fluid level out of sight. Fill well with 0.5 bpm while waiting on shooting fluid level. Shut down pump and allow to stabilize for 30 min. Shoot fluid level, found to be @ 540', as expected. PJSM & POOH with IBP laying down workstring. Shot fluid level twice, still 540'. OOH with workover string. IBP not recovered. Found grapple in retrieving tool to be too big 1 1/2" instead of 1 31B", wrong size sent out from BOT. Call out Wireline to locate IBP. Rig up wieline and begin to run LIB. First run tagged Liner top. Second LIB tagged sand and small metal bits @ 4,148' RKB. Begin to run bailers in an attempt to uncover IBP. Bailers coming back full every run. Metal and river sand. Bail to 4155'. Discontinue operation as sufficient gravel pack sreen exposed and to avoid jeopardizing operation by attempting to pulllBP on SL with possibly some junk left in hole to stick IBP. RD slickline. Filled hole with 10-15 bph filtered SW throughout operation. Pull wear bushing and wash BOP & wellhead. Prepare to run completion. Bring in ESP motor and fill same with oil purging all air out of system. PJSM prior to run completion. MU ESP assy. Service and fill with lube. Torque all sections and install ESP cable. Continue to RIH with completion string. Installing clamps every other collar. One band every 10 JTS under the clamps to hold the Gaurdian pressure gauge line slightly taunt. Pumping 5-10 BBLS every hour. Confirmed that Sliding sleeve is closed. Torqed all 3.5" to 3,200# all 4.5" to 3,600#. Average running speed 1 0 jnts/hr. Run 10 x 3.5" & 106 X 4.5" tubing. Check cables every 1,000 ft run. Upwt: 55, Dwwt: 40, Blockwt:10 klbs. No obstruction passing TOL at 3,441'. Guardian gauge: 9BO psi, 54 F. Check ESP cable and I-wire every 1,000'. PU FMC hanger. Cut ESP cable and I-wire, connect and install penetrators. Finish connecting I-wire and ESP cable to penetrators and run through hanger. Run heat trace penetrator. Land completion at 02:00 hrs. '-Wire: EWZ1826-ZP, SN 84689 ESP: C85A5101 ,SN 30067 Heat trace: EM160B-4. sn 82629 LD landing joint. Set TWC. Change to 4.5" rams. ND BOPE. Install tree & PT same to 250115000 psi. Gaurdian Gauge press = 990# @59 deg. Release Rig. Printed: 6/3/2004 10:41 :30 AM ( 2T-202 Well Events Summary Date Summary 02/26/04 BIOCIDE/CORROSIONINHIBITION: PUMP 1 GAL W 40 BBLS SW DOWN IA. PUMP 197 BBLS SW. PUMP 55 GALS CRO-0408F W/ 19 BBLS DIESEL. PUMP 5 BBLS DIESEL.D [Scale Inhibitor] 03/05/04 DRIFT TO 3275' SLM W/ 2.25 CENT. RUN DUAL PANEX GAUGES, OBTAINED SBHP OF 879 PSI W / BHT OF 60 DEG @ 3237' RKB AND MADE A GRADIENT STOP @ 3137' RKB.D [Pressure Data] 03/21/04 POT, PPPOT-T & IC passed. Function test LDS1s.D [ANN COM ISSUES, WH Maintenance] 04/17/04 LLR-OA of 9 gpm @ 750 psi. .0 [ANN COM ISSUES, WH Maintenance] 04/30/04 TAG @ 41781 RKB.DRIFTED TBG W/ 2.125" WT BAR X 231 (W/ 2.25" ON TOP, MIDDLE, & BTM) CLEAR TO 4034' RKB. NOTE: HAD SOME TROUBLE GETTING BY LINER TOP @ 3442' RKB. RUB T APPERED TOOLS TO GET BY.D [Tag] 04/30/04 SET IBP @ 3864' MD IN THE 4.5" BLANK PIPE BELOW THE GRAVEL PACK PACKER. CORRELATED DEPTH WITH PDS MEMORY LOG. PRESSURE TESTED PLUG TO 1000PSI. WILL CONTINUE IN AM WITH SAND PLUG. 05/01/04 PLACED 800# OF 20-40 RIVER SAND, 6.3 PPG, OVER THE IBP. ESTIMATED TOP OF SAND = 38241 CTD. 05/01/04 TAG SAND PLUG @ 38491 RKB.D [Tag] 05/02/04 TAG SAND PLUG @ 3806' SLM (38361 RKB).D [T ag] 05/08/04 LAY IN SAND 1000 # 20/40 RIVER SAND PLUG 1:1 FROM 38361 RKB TO APPROX 3793' RKB. USING 3 BBLS OF GEL PRIOR, 4 BBLS OF SLURRY, FOLLOWED BY 4 BBLS OF GEL. TAGGED SAND PLUG @ 3765' CTM (-3795' RKB). ( ConocoPhillips Alaska, Inc. 2T-202 KRU TUBING (0-3327, 00:4.500. 10:3.958) Surface (0-3677, 00:10.750, Wt:45.50) TUBING (3327-3672, 00:3.500, 10:2.992) PACKER (3441-3442, 00:10.750) Production (3441-3990, 00:7.625, Wt:29.70) Discharge (3670-3671, 00:5.130) PUMP (3671-3683, 00:5.130) PUMP (3683-3700, 00:5.130) SEAL (3702-3715, 00:5.130) ESP (3715-3749, 00:5.130) PACKER (3824-3825, 00:6.580) PUP (3825-3946, 00:4.500) Perf (3946-4246) PLUG (4167-4168, 00:2.250) Gravel Pack Sand (4257-4427, 00:6.750) w.:L.o ,.¡;-~,' .j "1i~1 I! "1 '! I m.I'lii -¡¡ . lL.~=L ~J~ .IIi;¡ "..w r I I' . ;;So .~. r-j ::...; } ---¡;¡:&... I API: 501032025400 SSSV Type: NONE Well Type: PROD Orig 3/27/1998 Completion: Last w/o: 5/25/2004 Angle @ TS: deg @) Angle @ TD: 13 deg @ 4427 Annular Fluid: DSUSW Rev Reason: WORKOVER WELL Last Update: 5/28/2004 J Reference Log: 33' RKB Last Tag: 3441 Last Tag Date: 5/8/2004 Casing String - All Description Conductor Surface Production Gravel Pack Screen Gravel Pack Sand Tubing String - TUBING Size I Top I Bottom 4.500 0 3327 3.500 3327 3672 Perforations Summary Interval I TVD I Zone I Status 1Ft I SPF I Date I Type I 3946 - 4246 3024 - 3316 300 50 12/31/1998ßCREEN Gas Lift MandrelsNalves St I MD I TVD I Man I Man Type I 1 2968 2171 CA~~O KBG-2 Other (plugs, eqUip., etc.) - JEWELRY Depth TVD Type 0 0 COLLAR FMC LANDING COLLAR 1 1 PUP 4.5" TUBING PUP 3327 2447 XO 3584 2676 SLEEVE-O BAKER CMU SLIDING SLEEVE 3661 2749 GAUGE BAKER GUARDIAN GAUGE 3670 2758 Discharge BAKER PUMP DISCHARGE 3671 2759 PUMP BAKER LOWER PUMP 71 GC4 100 L T 3683 2770 PUMP BAKER UPPER PUMP 45 GC4 100 MT 3701 2787 INTAKE BAKER INTAKE 3702 2788 SEAL BAKER TANDEM SEAL 3715 2801 ESP BAKER ESP 418 HP KMH 2610/98 MOTOR 3749 2834 Centralizer BAKER CENTRALIZER Other{plugs,eqllip.,..etc.) ':HORIZONTALGRAVEl PACK Depth TVD Type Description 3441 2546 PACKER BAKER ZXP LlNERTOP PACKER/TIEBACK SLEEVE (TIE-BACK LINER PULLED 1/1/1999 PACKER BAKER SC-1 GRAVEL PACK PACKER PUP BLANK PIPE Ref Log Date: TD: 4427 ftKB Max Hole Angle: 61 deg @ 2023 Size 16.000 10.750 7.625 5.100 6.750 Bottom' 112 3677 3990 4246 4427 Wt 62.58 45.50 29.70 0.00 0.00 Grade Thread H-40 Welded L-80 BTC-MOD L-80 BTC-MOD 20 GAUGE Top 0 0 3441 3946 4257 TVD 112 2764 3067 3316 4427 TVD 2447 2760 I Wt I Grade I 12.60 L-80 9.30 L-80 Thread BTC-MOD ABM/EUE Comment V Mfr I V Type I V OD I Latch I Port I TRO I ~~~ I C~~t DMY 1.0 BK-5 0.000 0 5/24/2004 Description .. 3824 2906 3825 2907 Fish-FISH Depth I 4167 PLUG GenerálNbtes Date I Note 5/24/2004 PACKERLESS COMPLETION I CommeM IPB LOST DOWNHOLE DURING WORKOVER 5/24/2004 Description 2T-202 ID 3.958 3.958 2.992 2.813 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ID 7.625 4.000 4.000 ,-......, ~ Jim Ennis . Wells Group Engineer Drilling & Wells Conoc~iIIi pS P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-265-1544 May 3, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 2T-202 (APD # 198-037) Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Sundry Approval to workover the Kuparuk well 2T -202. 2T -202 has a failed ESP assembly that needs to be replaced. If you have any questions regarding this matter, please contact me at 265-1544. \:;:~ ' J. Enl s . Wells Grou~ :ngineer CPAI Jrillin~ and Wells , JJE/skad RECEIVED MAY 042004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ,.--. RECEIVED .}~(,--\ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ APPLICATION FOR SUNDRY APPROV ALMAY 04 2004 ~ 20 AAC 25.280 .ALAska Oil & Gas Con5 r.nmmission D Suspend D Operation Shutdown D Perforate [J- AWß'ðTågiJ Annular Disp. D D Repair well 0 Plug Perforations D Stimulate D Time Extension D Other D D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 5. Permit to Drill Nul])ber: 198-037 V 6. API Number: / 50-1 03-20254-00 V 9. Well Name and Number: 2T-202 10. FieldlPool(s): Kuparuk River Field 1 Tabasco Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4236' Size ~ 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 41' 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D 8. Property Designation: ADL 255691 ALK 2667 11. Total depth MD (ft): 4427' Casing CONDUCTOR Total Depth TVD (ft): 3492' Length MD TVD 121' 16" 121' 3677' 3012' 3018' 112' 3555' 10-3/4" 7-5/8" 3940' SURFACE PRODUCTION 549' Burst Collapse Perforation Depth TVD (ft): 3018'-3492' Tubing Size: Tubing Grade: 4.5"/3.5" 12.7/8" L-80 Tubing MD (ft): 3129'/3238'/3335' Perforation Depth MD (ft): open hole gravel pack 3940'-4427' Packers and SSSV Type: Baker SC-1 Gravel Pack pkr no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Packers and SSSV MD (ft) pkr @ 3824' no SSSV 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D May 7, 2004 Date: Contact: Title: Phone Conditions of app~é : Notify Commission so that a representative may witness Plug Integrity D 30P Test ~ Mechanical Integrity Test D Location Clearance D Other: ~SùD Ç> S \ \-J\. \ f" '\: '" \,,) -'"'- ~\::) V ~<;. ~ R8DMS Sf l COMMISSIONER BY ORDER OF THE COMMISSION nPlr-,I"f ^, Service D Plugged D WINJ D Abandoned D WDSPL D Jim Ennis @ 265-1544 Wells Group s;a1 E~ineer Date ~ '1>/° ~ ISUndry Number: .3cry'-/¿.? v M- 0-6 100\ Daæ 1~f SUBMIT IN DUPLICATE STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon [~ Alter casing [~] Change approved program [--1 Suspend r-] Operation Shutdown 0 Perforate 0 V adance r'~ Repair well ~] Plug Perforations [~ Stimulate r-] Time Extension [~ Pull Tubing ~] Perforate New Pool [--1 Re-enter Suspended Well [] Annular Disp. [--] Other E] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development_ ~] Exploratory r~ Stratigraphic [~ Service [~] 5. Permit to Drill Number: 198-037 6. APl Number: 50-103-20254-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 122' 2T-202 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): .Plugs (measured): I Junk (measured): 4427' 3492' 4236 3305 Casing Length Size MD TVD Burst Collapse CONDUCTOR 112' 16" 112' 112 PRODUCTION 3555' 10-3/4" 3677' 2764 PRODUCTION 26' 7-5/8" 3467' 2570 PRODUCTION 473' 7-5/8" 3940' 3018 Perforation Depth MD (ft): Open hole gravel pack 3953-4254' MD Packers and SSSV Type: no packer no SSSV Perforation Depth TVD (ft): Open hole gravel pack 2909-3323' TVD 12. Attachments: Description Summary of Proposal [] Detailed Operations Program E~] BOP Sketch 14. Estimated Date for Commencing Operations: November 20, 2003 16. Verbal Approval: Date: Tubing Size: 2-7/8" Tubing Grade: L-80 Packers and SSSV MD (ft) no SSSV 13. Well Class after proposed work: Exploratory [] Development [] 15. Well Status after proposed work: oi, FI Gas I--I WAG E] GINJ E] Plugged [--1 WINJ ~ Tubing MD (ft): 3335' Service r-~ Abandoned C' WDSPL ['-] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ...,Jerry Dethlefs signature ~'~//."~ ~'.. ,~ Commission Use Only Contact: Title: Phone 659-7043 Jerry Dethlefs Problem Well Supervisor Date 11/15/03 Conditions of approval: Notify Commission so that a representative may witness JSundry Number: Plug Integrity [--1 BOP Test [] Mechanical Integrity Test Location Clearance Subsequent Form Required: , ~ BY O~D~8 OF Approved by: ~~ ......... ~"~' QMM SS ONER , THE COMMISSION Date: Form 10-~~~0~0~ DUPLICATE SUBMIT iN DUPLICATE ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 2T-202 (PTD 1980370) November 15, 2003 This application for Sundry approval for well 2T-202 (PTD 1980370) is to document that the AOGCC and ConocoPhillips concur the well may be produced on gaslift due to a failed Electric Submersible Pump (ESP). The ESP failure was reported to the AOGCC on 11/07/03. The well was originally completed in March 1998 and has been on production until it's recent failure. Due to the configuration of the completion, the well does not have an isolation packer between the tubing and annulus. Well 2T-202 does not have the capability to flow to the surface unassisted. A bottom-hole static pressure was measured on 11/10/03 of 842 psi at 3212' MD (2353' TVD). There is not a gaslift mandrel in the tubing string; lift gas will be injected into the tubing/casing annulus (IA) and enter the tubing via the "Y block" assembly on the "I tube." The tubing nipple at 3241' MD is normally plugged, but the plug has been removed for gas entry. Most, if not all, produced fluids will enter the tubing through the inactive pump. The applied gaslift will prevent annular flow of produced liquids. The well is equipped with a wellhead Safety Valve System as per regulations. ConocoPhillips intends to workover this well in the future to replace the ESP motor. A casing MIT and inspection log will be performed at that time to verify casing integrity. Recent well test data shows the following results: 15-NOV-03 14:55 WELL TEST SUMMARY REPORT FORM TOTL LIFT LIFT DS WL LENGTH CHK FTP FTT OIL WAT %WC FLUID GAS GOR GLR HZ PRES 2T 202 5:47 176 327 100 827 951 53 1778 52 63 29 40 580 2T 202 18:25 176 317 99 911 1065 54 1976 68 75 34 42 575 2T 202 12:00 176 318 99 921 107'4 54 1995 67 73 34 42 577 2T 202 13:09 176 315 99 969 1112 53 2081 73 75 35 42 577 2T 2021 20:00 176 359 102 621 954 61 1575 45 72 28 42 610 As per this request, ConocoPhillips intends to produce 2T-202 on gaslift until the ESP is repaired. iC0n°c0PIiiilips:Alaska,i,lnci (0-3129, 0D:4.500, ID:3.958) Annular Fluid: DSI_/SW (3129-3130, Reference 0D:4.500) Last T~ (3237-3238, OD:3.500) (3238-3239, 0D:8.600) ESP (3262-3280, 0D:5.620) Tubing (3228-3335, 0D:2.875, ID:2.441) ESP ~ (328(X3289, 0D:5.620) Production OD:10.750, Wt45.50) (3289-3303, 0D:5.620) KRU 2T-202 APl: 501032025400 SSSV Type: NONE 4236 2/1712000 Well Type:J PROD I Odg J 3/27/1998 J Completion:J ' Last W/O: J 12/31/1998 I Ref Log Date:J TD:J4427 ftKB ' Max Hole Angle:J61 deg (~ 2023 Size Top Conductor 16.000 0 Production 10.750 0 Angle @ TS:I deg ~ Angle @ TD:J 13 deg @ 4427 I Rev Reason: J Tv~AGIJ E'WELRY' BY Last Update:12/20/2006 Size 4.500 3.500 2.875 Production 7.625 3441 Production 7.625 3467 . . Bottom TVD J Wt J Grade I Thread 0 3129 2288 I 12.30 I L-80 J EUE-ORD 3129 3228 2366 I 9.30 J L-S0 I BTCM 3228 3335 2454 I 6.50 I L-80 I HYD511 ..... - JEWELRY ':' IB°tt°m I TVD I Wt Grade I Thread I 112 I 112 162.581,-40 IWe~ded I 3677 I 2764 J 45.50I L-80 I BTC-MOD I 3467 I 2570 J33.70J L-80 J BTC.,-MOD I 3940 I 3018 J29.70 I i'-'80 J. BTO-MOD Description ID 4.5X3.5 CROSSOVER 2.992 BAKER SENTRY GAUGE 2.992 TRICO Y BLOCK ON "1" TUBE 2.347 NIP TRICO ' X' LANDING NIPPLE; 2.31" XX. Plug set 2/17/O0. SWIVEL SUB 2.312 2.875 Oentiliff UT PUMP W/DISCHARGC 0.000 ESP Centilift LT PUMP 0.000 SEAL Centiliff TANDEM SEAL 0.000 MOTOR Centilift 570HP KMH 0.000 MOTOR Centilift 570HP KMH 0.000 Gravel Pack Pocket 0.000 I Note I NEW TUBING RUN IN WELL (shows 3/20/98 date to accommodate schematic picture) Y BLOCK COMPLETION FROM 3238' RKB OPEN HOLE GRAVEL PACK 3953'-4254' threads inside and outside on plug galled; hangar threads ma), be galled~ too. Bottom of "1 tube" 15' shallower than bottom of pump. CTU not able to get past 7 '5/8" liner top @ 3442' (3303,3325, 0D:5.620) (3325-3351, 0D:5.620) Gravel Pack Pocket (3832-3833, 0D:8.600) 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 _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 447' FSL, 556' FWL, Sec. 1, T11N, RSE, UM At top of productive interval 1987' FSL, 892' FEL, Sec. 2, T11N, R8E, UM At effective depth At total depth 2066' FSL, 965' FEL, Sec. 2, T11N, R8E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ 6. Datum elevation (DF or KB feet) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-202 9. Permit number / approval number 198-037 / 10. APl number 50-103-20254-00 11. Field / Pool Kuparuk River Unit Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical 4427 feet Plugs (measured) 3492 feet Effective depth: measured 4236 feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth Conductor 80' 16" 9 cu yds High Eady 80' Surface 3636' 10.75" 535 sx AS III, 600 sx Class G, 60., 3677' Production 499' 7.625" 260 sx Class G 3940' Production 3400' 7.625" tieback to sudace 3441' Production 433' 4.5" open hole 3832' - 4265' True vertical Depth 121' 2764' 3018' Perforation depth: measured open hole gravel pack 3953' - 4254' true vertical Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80 @ 3129', 3.5", 9.3#, L-80 @ 3228', 2.875", 6.5#, L-80 @ 3335':..,.iii.;t!~!~ Packers & SSSV (type & measured depth) No packer, no SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended__ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~--~~//'~~~ Title: Wells Team Leader Peter Nezaticky C// / ~/ Questions? Call Peter Nezaticky 659-7224 Date ~ ::~2,~__/~/___ Prepared b~/ Sharon AIIsup. Drake 263-4612 Form 10-404 Rev 06/15/88 · SCANNED AUG 0 2002: SUBMIT IN DUPLICATE P~{ILT.IPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (2T-202 (W~-6)) WELL JOB SCOPE JOB NUMBER 2T-202 AN N-COM M 0727021646.18 DATE DAILY WORK UNIT NUMBER 07/28/02 CEMENT TOP JOB DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 YES YES DS-CULPEPPER NEZATICKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE WCW.K02.TB9 $4,000.00 $4,100.00 9.2T Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSIII0 PSI 0 PSI DAILY SUMMARY PUMPED 1.5 BBL OF ARTIC SET I CEMENT INTO SURFACE PIPE X CONDUCTOR ANNULUS.[WH Maintenance] TIME 08:00 09:30 09:45 10:30 LOG ENTRY DS ON LOCATION. MIRU START MIXING CEMENT - ARTIC SET I @ 15.8 PPG. PUMPED 1.5 BBL OF CEMENT. WASHED UP. RDMO ARCO Alaska, Inc. (0-3129, OD:4.500, ID:3.958) (3129-3130, 0D:4.500) GAUGE (3237-3238, 0D:3.500) YBLOCK (3238-3239, 0D:8.600) ESP (3262-3280, 0D:5.620) Tubing (3228-3335, 0D:2.875, ID:2.441) ESP (3280-3289, 0D:5,620) Production -- (0-3677, OD:10.750, Wt:45.50) (3289-3303, OD:5.620) MOTOR (3303-3325, 0D:5.620) MOTOR (3325-3351, 0D:5,620) 2T-202 2T-202 APl: 1501032025400 SSSV Type:I NONE Annular Fluid: DSL/SW Reference Log: Last Tag: 4236 Last Tag Date: 12/17/00 I Casing String - ALL Size I Top 16.000 I 0 lO.75o I o 7.625 / 3441 7.625 I 3467 Tubing String - tubing Size Top 4.500 0 3.500 3129 2.875 3228 Other (plugs, equip., et( Well Type: PROD Orig Completion: J 3/27/98 Last W/O: 12/31/98 Ref Log Date: TD: 4427 ftKB Max Ho e Ang e: 61 deg (~ 2023 Angle @ TS: Ideg @ Angle (~ TD: 13 deg. @ 4427 Rev Reason: I TAG/~EWELRY BY Last Update: V2/H20/00 Boffom 112 TVD Wt GradeI Thread 112 62.58 I H-40 ] Welded 45.50 I L-80 I BTC-MOD 33.70 1-80 I 29.70 L-80 3677 2764 3467 2570 BTC-MOD 3940 3018 BTC-MOD Bottom Thread 3129 EUE-8RD 3228 3335 -JEWELRY 'rvD I Wt 2288 I 12.30 I L-80 I 2366 [ 9.30 L-80 2~4_5.4_ ..... L___6_.__5_0 .... .L_-.8__O___L BTCM HYD511 Depth TVD Type Description ID 31291 22881 XO 14.5X3.5 CROSSOVER 2.992 32371 23731 GAUGE IBAKER SENTRY GAUGE 2.992 3238/ 23741 YBLOCK I TRICO Y BLOCK ON "1" TUBE 2.347 3241 / 2376{ NIP I TRICO ' X' LANDING NIPPLE; 2.31" XX-Plug set 2/17/00. 2.312 3242 2377 SWIVEL SWIVEL SUB 2.875 3262 2394 ESP Centilift UT PUMP W/DISCHARGQ 0.000 3280 2409 ESP Centilift LT PUMP 0.000 32891 24161 SEAL Centilift TANDEM SEAL 0.000 33031 2428[ MOTOR Centilift 570HP KMH 0.000 i._.__33_2__51 244_6_[ MOTOR _ Centilift 570HP KMH 0.000 3832 2914/Gravel Pack 0.000 I / Pocket Date I Note 12/31/98 I 1/19/99I 1/19/99I 2/2/99I 3/31/99 NEW TUBING RUN IN WELL (shows 3/20/98 date to accommodate schematic picture) OPEN HOLE GRAVEL PACK 3953'-4254' Y BLOCK COMPLETION FROM 3238' RKB Pulled BPV; threads inside and outside on plug galled; hangar threads may be galled, too. Bottom of"l tube" 15' shallower than bottom of pump. CTU not able to get past 7 '5/8" liner top @ 3442' (see video Icg) SCANNED AUG 0 D 2002. SUNDRY NOTICE 10-404 Phillips Kuparuk Well 2T-202 Annular Cement "Top-Job" July 28, 2002 Phillips Alaska, Inc., Kuparuk well 2T-202 top of cement between the surface pipe and conductor (10 3/4" x 16") was measured at 8 feet below grade. Arctic Set I cement (15.8 ppg) was pumped into the annular void (1.5 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. '-'Well Compliance R Port File on Left side of folder 198-037-0 KuP~i~-Rivu i~S 2T,202 ......... 502"'i03220~54200 ...... ~0 Completion Date: /'4/28/98 Completed Status: 1-OIL Current: MD 04427 ~' TVD 03492- . T Name L CMT VOL L CST Interval Sent Received T/C/D cF41qAL 3677-4393 ~/~l/~ CH 5 5,11,98 5,14,98 ~(~L 3677-4260 OH 5 5,11,98 5,14/98 L DGR/EWR4-MD L DGR/EWR4-TVD L DSSI ..FINAL 121-3959 OH 4/29/98 4/30/98 t.Fq~AL 121-3038 OH 4/29/98 4/30/98 ~F~NAL 100-4000 OH 5/11/98 5/14/98 L MICRO L PEX-AIT ..~rfNAL 100-4410 OH 5/11/98 5/14/98 ~q~L 3677-4413 OH 5/11/98 5/14/98 L PEX-CN wFINAL 3677-4387 L PEX-CN/LDT t~'I~AL 3677-4393 L PEX-DLL/CALIPER ~AL 3940-4260 L PEX-MCFL t~'NAL 3677-4393 L PEX-SSTVD ~FfNAL 3677-4413 OH 5/11/98 5/14/98 OH 5/11/98 5/14/98 OH 5 5/11/98 5/14/98 OH 5 5/11/98 5/14/98 OH 5 5/11/98 5/14/98 CH 5 8/11/99 8/19/99 L PROD-PSP/FSPL ~L DEFT 3880-4255 7/~[6~C~ SIDEWALL SUMM c.F~AL 3967-4235 OH 5 5/11/98 5/14/98 T 8373~ . SCHLUM DAS~MUAIT~L~SDN OH 5/11/98 5/14/98 Daily Well Op~/U/~ - ~/j Yf? Are D~ Ditch Samples Required? yes ~~d Rec~ Was the well cored? ~ no eceived? :~? no Sample Set g Comments: Monday, May 01,2000 Page 1 of 1 Schlumberger NO. 12742 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Kuparuk,Tabasco Pool Color Well Job # Log Description Date BL Sepia Print 1A-10 i,,k.I ~ INJECTION PROFILE 990719 I 1 1A-11 ~t ! ~ INJECTION PROFILE 990707 I 1 1Y-10 ~,~! (~ MI INJECTION PROFILE 990716 I 1 2A-03 L,~.% ~ INJECTION PROFILE WlPSP 990708 I 1 2M-20 PRODUCTION PROFILE 990702 I 1 2M-30 t~.~ ~ INJECTION PROFILE W/PSP 990722 I 1 2N-321A i~.,%l ~ INJECTION & STATIC PROF W/PSP 990710 I 1 2N-325 [vt, ! C..- INJECTION & STATIC PROF W/PSP 990709 I 1 2N-335 PRODUCTION PROFILE 990705 I 1 2T-28 [~1 (:-.. MEMORY INJECTION PROFILE 990715 I 1 2T-202 PRODUCTION PROFILE 990706 I 1 2T-210 STATIC BOTTOM HOLE PRESS SURVEY 990721 I 1 2X-10 PROD PROFILE & GAS LIFT SURVEY 990708 I 1 3H-12 IVLI ~ INJECTION PROFILE 990706 I 1 3J-04 [~1 (.-- INJECTION PROFILE W/PSP 990724 I 1 3J-05 (,A,I C..- INJECTION PROFILE WIPSP 990725 I 1 3M-04 STATIC BOTTOM HOLE PRESS LOG 990701 I 1 3M-29 STATIC BOTTOM HOLE PRESS LOG 990701 I I SIGNED: ~~-'~'~ DATE: [l~ i{:)'1('~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank~~ 8/11/99 STATE OF ALASKA ALASCJ-~--OIL AND GAS CONSERVATION COMMIS-~5(ON REPORT OF SUNDRY WELL OPERATIONS; '1. Operations performed: Operation Shutdown w Stimulate__ Plugging_ Perforate__ Pull tubing __X Alter casing ._X Repair well __ ther __X Install ESP 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development X. RKB 41 3. Address: Exploratory . 7. Unit or Property: P.O. Box 100360 Stratigraphic Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 447' FSL, 556' FVVL, Sec. 1, T11 N, RSE, UM 2%202 At top of productive interval: 9. Permit number/approval number: 1987' FSL, 892' FEL, Sec 2, T11 N, RSE, UM 98-037/398-315 At effective depth: 10. APl number: 50-103-20254 At total depth: '11. Field/Pool: 2066' FSL, 965' FEL, Sec 2, T11 N, R8E, UM Kuparuk River Field i'12. Present well condition summary Total Depth: measured 4427 feet Plugs (measured) true vertical 3492 feet Effective Depth: measured 4260 feet Junk (measured) true vertical 3329 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 9 cu yds High Early 121' 121' Surface 3636' 10.75" 535 sx AS III & 600 sx Class 3677' 3012' 60 sx AS I Production Liner 499' 7.625" 260 sx Class G 3940' 3018' measured Open hole gravel pack 3940'-4427' ... true vertical 3018'-3490' _ Tubing (size, grade, and measured depth) -'-~ .... '-- - 4.5", 12.6#, L-80 @ 3129', 3.5", 9.3~, L-80 from 3129'-3228', 2.875", 6.5#, L-80 from 3228'-3335' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured)0F Ii INAL ~4, Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation '15, Attachments ~6. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil _~X Gas ~ Suspended ~1. I hereby certifl/that the foregoing is true and correct to the best of my knowledge, :Signed Title: Tabasco Drilling Team Leader Date Paul Mazzolini Questions? Call Tom Brockway 263-4 ~ 35 Prepared by Sharon AIIsup-Drake Form 10-404 Rev 06/15/88 SUBMIT IN DUPLIC~, Date: 2/12/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2T-202 WELL ID: 999283 TYPE: -- AFC: 999283 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:12/26/98 START C0MP:12/25/98 RIG:NORDIC % 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20254-00 12/25/98 TD: 0' PB: 0' 12/26/98 TD: 4427' PB: 4260' 12/27/98 TD: 4427' PB: 4260' Cl C2 C3 12/28/98 (C4 TD: 4427' PB: 4260' 12/29/98 (C5 TD: 4427 ' PB: 4260' 12/30/98 (C6 TD: 4427' PB: 4260' 12/31/98 (C7 TD: 4427' PB: 4260' 01/01/99 (C8 TD: 4427' PB: 4260' SUPV: MOVE OVER 2T-202 @ 0300 H Prepare rig to move. MW: 0.0 DOILW SUPV: SET FMC BPV MW: 8.6 SW Move rig to 2T-202. Accept rig @ 1200 hrs. 12/25/98. R/U to pump kill fluid. SUPV: M/U TWO WAY RETRIEVING TO MW:10.0 BRINE Pump brine kill fluid. N/D tree. NU BOPE and test to 300/3000 psi. Well flowing through two way check. RIH W/ BAKER 'CS' PLUG ON MW:10.0 BRINE SUPV:DONALD L. WESTER Pump kill fluid down tubing. Well dead. Pull 3.5" tubing. REPLACE TUBING SPOOL W/ 1 MW:10.0 BRINE SUPV:DONALD L. WESTER Pull 3.5" tubing. RIH w/ 'SB' plug and set @ 3828'. Dump 20/40 sand and displace to end of DP. Set storm packer. N/D BOPE. CIRCULATING TO BALANCE FL MW:10.0 SUPV:M. WINFREE NU BOPE stack and test. Pull storm packer. BRINE MW: 9.7 BRINE SUPV:M. WINFREE Pul 7-5/8" hanger to floor. Shut down check for flow, no flow. Install 7-5/8" pipe rams and test to 1000%, OK. FILTERING BRINE MW: 9.7 BRINE SUPV:M. WINFREE POOH w/7-5/8" casing. RIH and tag liner tie back at 3429' Date: 2/12/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 01/02/99 (C9) TD: 4427' PB: 4260' 01/03/99 {Ci0 TD: 4427' PB: 4260' 01/04/99 (Cll TD: 4427' PB: 4260' 01/05/99 (C12 TD: 4427' PB: 4260' 01/06/99 (C13 TD: 4427' PB: 4260' REV. CIRC SAND OFF PLUG MW: 9.7 BRINE SUPV:M. WINFREE Circ brine. Shut down, back flowing up pipe. Reverse circ. Set packer 30' RKB and test to 1000 psi, OK. MU 11" spool, install packoff and sleeve and test to 5000 psi. LD DP MW:10.0 BRINE SUPV:M. WINFREE Pull storm packer. Pull plug, losing fluid, re-set plug. Pump CalcCarb pill. RUNNING ESP W/ 'Y'-BLOCK SUPV:M. WINFREE RIH w/ 4.5" tubing. MW:10.0 BRINE SPLICE ESP CABLE & 'I' WI SUPV:M. WINFREE Continue to run 4.5" tubing. MW:10.0 BRINE RIG MOVING TO 2C PAD, STO MW:10.0 BRINE SUPV:DONALD L. WESTER Continue to run 4.5" completion w/ESP. ND BOPE. NU master valve and test to 250/5000 psi. Freeze protect well. Release rig at midnight 1/6/99. .... STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing ~ Repair well _ Change approved program _ Operation Shutdown __ Re-enter suspended well _ Plugging __ Time extension _ Stimulate _ Pull tubing~ Variance_ Perforate_ Other X Install ESP 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 447' FSL, 556' FWL, Sec. 1, T11 N, R8E, UM At top of productive interval 1987' FSL, 892' FEL, Sec. 2, T11 N, R8E, UM At effective depth At total depth 2066' FSL, 965' FEL, Sec. 2, T11 N, R8E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 41' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-202 9. Permit number 98-037 10. APl number 50-103-20254 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical 4427' 3490' 4266' 3335' Casing Length Size Structural Conductor 80' 16" Surface 3636' 10.75" Intermediate Production 3899' 7.625" Liner 433' 4.5" feet feet feet feet Plugs (measured) None Junk (measured) Cemented Measured depth True vertical depth 9 cu yds High Early 121' 121' 535 sxAS III & 3677' 3012' 600 sx Class G, 60 sx AS I 260sx Class G 3940' 3018' open hole 3832-4265' 3334' Perforation depth: measured No perfs true vertical N/A Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 3848' Packers and SSSV (type and measured depth) Baker SC-1 Gravel Pack PKR @ 3832', No SSSV 2 4 998 Ala l 0il & 6as,c s. c,0mmiss! ORIGINAL 13. Attachments Description summary of proposal X Contact Tom Brockway at 263-4135 with any questions, Detailed operation program BOP sketch _X 14. Estimated date for commencing operation November 30, 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended _ 7. I hereby ce~_.~_if.i~ that the forejgo~ng is true and correct to the best of mv knowledae. ~ Signed 7 Title Tab~.soo Drilling Team Leader FOR OOMMIS$10N USE ONLY Oonditions of approval: Notily Oommission so repres, e~tative may witness Plug integrity_ BOP Test ~ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- N.O~ Original ,:,~gned By David W. Johnston Approved by the order of the Commission Form 10-403 Rev 06/15/88 Date ]Approval SUBMIT IN TRIPLICATE TABASCO 2T-202 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: RU slickline unit. RIH and pull OV from GLM #3 @ 3749'. Pull GLV from GLM #1 @ 3098' and replace with DV. Leave GLM #2 dummied off. If the OV in GLM #3 can not be pulled with wireline, continue as outlined below: , A. RU Kinley punch on wireline and RIH. B. Shoot perfs in the 3-1/2" tubing just below GLM #3 @ 3749' Set BPV in tubing and install VR plug in annulus valve. Remove flow riser and gas lift riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.1 ppg). Circulate well to brine. Ensure well is dead. Set BPV. ND tree. NU and test BOPE to 3000 psi. Record results. Test casing to 3000 psi. Record results. Pull BPV. Screw in landing joint. POOH w/3-1/2" tubing. Lay down all tubing and jewelry. Make up packer plug and storm packer on 3-1/2" DP and RIH. Set packer plug in gravel pack packer. Spot +/- 200 lb sand plug on top of the packer plug. Set 7-5/8" storm packer and ND BOPE. ND tubing head and packoff. NU and test BOPE to 3000 psi. Record results. Pull 7-5/8" storm packer and verify well is dead. Screw in landing joint. Pull casing hanger. POOH with 7-5/8" tie-back casing string and lay down. Set 10-3/4" storm packer and ND BOPE. NU tubinghead and packoff. Test packoff. NU and test BOPE to 3000 psi. Record results. Pull 10-3/4" storm packer and verify well is dead. PU bit and scraper. RIH cleaning out well to top of liner hanger. Circulate hole clean. Verify well is dead. POOH. RIH with grapple assembly and pull packer plug. Verify well is dead. Circulate hole clean. Pick up Centrilift ESP motor, seal assembly, Y-block, and 2-7/8" tubing I-tube on 4-1/2" 12.6# L-80 BTCM production tubing. Run in well with ESP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. Position ESP at desired depth, set tubing hanger and run electrical penetrators through same. Make surface electrical connections as required. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up horizontal production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. Freeze protect well. Make final conductivity check of ESP cable and instrumentation wire. Set BPV. Release rig and turn well over to production. TAB, 11/23/98, v2 . o 7. 8. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 2T-202 WO Tabasco 2T-202 Workover Proposed Completion 16" Conductor @ 80' J Weatherford Gemoco 10-3/ 4" DV Stage Collar Stnd. Grade BTC Threads (+/- 2807' MD / 2063' TVD) 4-1/2" Nova Clamps (~AII Depths RKB Nordic 3-1/2" Nova Clamps ESP power cable splice above Y-block B. 1 jt, 3-1/2" 9.3# L-80 EUE8RD tubing A. Centrifilt Series 562 ESP assembly w/power cable, 5.62" OD Super-Bands to top of Y-block +/- 3' intervals i FMC Tabasco Producer horizontal wellhead/hanger system w/125 amp penetrators · Heat Trace, Raychem, 3000' L. 4-1/2" 12.6# L-80 BTCM tubing to surface K. XO sub, L-80 4-1/2" BTCM box x 3-1/2" BTCM Special Clearance pin J. 3 jts, 3-1/2" 9.3# L-80 BTCM tubing 3.865" Special Clearance couplings I. Baker 'Sentry' gauge, 3-1/2", w/I-wire, Clamp-on style H. 3-1/2" x 4' Landing pup, 9.3#, L-80, BTCM 3.865" Special Clearance couplings G. 3-1/2" Trico Y-Block w/couplings, 3-1/2" EUE8RD pin on motor leg, 2-7/8" EUE8RD pin on I-tube leg, 3-1/2" BTCM Special Clearance box on uphole end F. 2-7/8" Trico 'X' landing nipple w/2.312" profile, EUE8RD box x Hydrill 511pin E. 3-11/16" x 2' L-80 'Swivel Sub', 2.875" ID Hydrill 511 D. 3 jts, 2-7/8" 6.5# L-80 Hydrill 511 flush jt tubing C. 2-7/8" Wireline Entry Guide, Hydrill 511 10-3/4" Surface Casing 40.5# J-55 BTCM (+/- 3677' MD / 3012' TVD) Liner Hanqer Assembly (3442' MD / 2547' TVD) -- Baker C-2 Tieback Sleeve w/Iocator, 10' tieback extension -- Baker ZXP Linertop Packer, 7-5/8" x 10-3/4" -- Baker HMC Liner Hanger, 7-5/8" x 10-3/4" 7-5/8" Intermediate Casing 29.7# L-80 BTCM (3940' MD / 3018' TVD) Well TD (4427' MD / 3490' TVD) Open Hole Gravel Pack Assembly -- Baker SC-1 Gravel Pack packer, 7-5/8" -- Baker 4-1/2" Gravel Pack screen, Hunting Seal Lock 20 gauge (0.02") screen 12-20 US mesh gravel pack sand -- 3 jts, Baker 4" blank tubing, Hunting Seal Lock threads TAB, 11/19/98, vl 11" 5( psi BOP Stack-- Nc._ ]ic Rig 3 Kuparuk River Unit Tabasco Operations - Producer Wells Kill Line ~ Choke Line ~ 4 I Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 Iow and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 16" Starting Head 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Double Flange Adapter/Spacer Spool 4. 11" 5000 psi Hydril Type V Single Pipe Rams, 3-1/8" 5000 psi Side Outlets w/ manual locks 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines, 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate, 2 Kill valves - each are 3" 5000 psi gate 6. 11" 5000 psi Hydril Double Ram with Pipe Rams on Top and Blind Rams on Bottom, 3-1/8" Side Outlets w/Manual Locks 7. 11" 5000 psi Hydril Annular Preventer TAB, 09/30/98, v. 1 ARCO Alaska, Inc. ' :~" Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 26, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-202 (Permit No. 98-37) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2T-202. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Drilling Engineer Kuparuk Drill Site Development TWM/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 ' ~ r OIL [~ GAS [~] SUSPENDED r~ ABANDONED~ SERVICE E~ 2 Name of Operator ~-~ 7 Pe~it Number ARCO Alaska, Inc 98-037 -~:..~ '~.~ .~ ~-.~ 3Address ~ ~~ 8 APlNumber~ ~ P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20254 4 Location of well at sudace 7%;;' ~ ;~-'~'~';' '. '~~'~'"~;~ 9 Unit or Lease Name 447' FSL, 556' ~L, Sec. 01, T11N, R8E, UM ~ ...... ~'- : Kuparuk River Unit 1987' FSL, 892' FEL, Sec. 02, T11N, R8E, UM ~ ~_;., : 2T-202 At Total Depth ; 11 Field and Pool 2066' FSL, 965' FEL, Sec. 02, T11N, RSE, UM Kuparuk River ~eld 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease D~ignation and Sedal No. Kupamk River Oil Pool RKB 41', Pad 81' ADL 25569 ALK 2667 12 Date08.Mar_98Spudded 13 20-Mar-98Date T.D. Reached ~14 24-Apr-98Date Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Sumey 20 Depth where SSSV set 21 Thic~s of pe~afrost 4427' MD & 3492' TVD 4266' MD & 3335' ~D YES ~ NO U NA feet MD 1380 APPROX 22 Type Electric or Other Logs Run AIT/GR/SP/LDT/CN~CAL, FDI/Microlo~GR, FMI/GR, DL~Cal, DSI 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.58~ H-40 SURF. 121' 24' 9 cu yds High Early Cold Set 10.75" 45.5/40.5~ L-80/J-55 SURF. 3677' 13.5' 535 sx ASIII, 600 sx Class G, 60 sx ASI 7.625" 29.7~ L-80 3441' 3940' 9.875' 260 sx Class G 7.625' 29.7~ L-80 SURF. 3441' 9.875' tieback to sudace, not cemented 4.5" 13.5~ L-80 3832' 4265' 12.25" Open hole - Gravel packed screen 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 3848' 3832' No peals, open hole completion 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Date First Production Method of Operation (Flowing, gas lift, etc.) ~11/98 Gas Lift Date of Test Hours Tested PRODUCTION FO~OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE J GAS-OIL RATIO ~98 12.00 TEST PERIOI: 2~ 126 6 124~ 225 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BB[ OIL GRAVIS-APl (cor0 Press. 325 ] ]~ 24-HOUR RATE: 479 108 12 17° 28 CORE DATA Bdef descdplion of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See A~achment. More core analysis will be sent under separate cover sheet. Form 10-407 Submit in duplicate 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 Tabasco 3963' 3041' Base Tabasco 4236' 3306' Annulus left open - freeze protected with diesel. 31. LIST OF ATrACHMENTS Summary of Daily Drilling Reports, Directional Survey, Core Description 32.1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ' Title ~--/~'/~/-~'~ DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form10-407 Date: 5/5/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2T-202 RIG:PARKER WELL_ID: AK8645 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:03/07/98 START COMP:04/14/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20254-00 03/04/98 (D1) TD: 0'( SUPV:DEB 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PREPARE MOVE CAMP/RIG OFF C1 Prepare rig to skid & skid 38' Raise cellar box. 03/05/98 (D2) TD: 0'( SUPV:DEB 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Moving Rig: Utility Module at CPF-2, Drilling Module 0.3 miles to 2X road. Change out cracked V-Block on #3 Lampson. 03/06/98 (D3) TD: 121'(121) SUPV:DEB MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 R/U-DRIL MOD OVER HOLE @ 0300 Rigging Up - Drilling module over hole ~ 0300, Utility Moidule set down @ 0500 hrs. Hold utility module at 2A and move drilling module to lead. Move rig towards 2T (at 'F' Pit at midnight). 03/07/98 (D4) TD: 121'( SUPV:DEB 0) MW: 8.4 VISC: 187 PV/YP: 14/54 APIWL: 14.0 OOH 8 559' TO INCREASE BEND Increase bend in AKO on Motor. Total move = 17.2 miles. Rig Accepted @ 0600 hrs, 3/7/98. Function test diverter system. Grimaldi, AOGCC ield Inspector. 03/08/98 (D5) Tm: 1530' (1409) SUPV:DEB MW: 9.1 VISC: 72 PV/YP: 20/26 APIWL: 11.2 DRILL AT 2300' Drill from 121' to 1530' POH. Change AKO from 1.3' to 1.5' POH. Increase AKO to 1.8'. POH. LD UBHO sub. Reset AKO to 1.4' 03/09/98 (D6) TD: 3675'(2145) SUPV:DEB MW: 9.6 VISC: 65 PV/YP: 21/20 APIWL: 7.4 13-1/2" TD @ 3695' MD Short tripped out to HWDP @ 0400 hrs. Drill from 1530'-2758' TVD. (16.7 ADT) . 03/10/98 (D7) TD: 3695' ( 20) SUPV:DEB MW: 9.9 VISC: 64 PV/YP: 24/19 APIWL: 6.8 POH TO HWDP - WASHED & REAMED Washed and reamed out across Ugna and base of permafrost. Pulled tight at 2034' Pump out and back ream to 1513' 03/11/98 (D8) TD: 3695'( SUPV:DEB 03/12/98 (D9) TD: 3695'( SUPV:DEB 0) 0) MW: 10.0 VISC: 190 PV/YP: 33/50 APIWL: 6.2 CEMENT 10-3/4" SURFACE CASING POH. Pulled 50-70K over at 2782' Wash and ream through tight area. Pulled tight at 2782' pumped and back reamed to clean out. Hold PJSM on running casing. MW: 9.8 VISC: 82 PV/YP: 22/20 APIWL: 9.4 NU FMC CASING HEAD ON 10-3/4" Circ 1675 Bbls total, 7BPM, 400 psi.N' NU FMC casing head on neck of 10-3/4" hanger. Locking nut/ring would not make up into bottom of head. Take head back off and try ring in threads by hand - no go. Threads in bottom of head look good; but apparently were miss-machined. FMC hand went to Prudhoe to PU a good cassxing head. Clean pits and clean rig while waiting for new casing head. 03/13/98 (D10) TD: 3695'( 0) SUPV:DEB MW: 8.8 VISC: 34 PV/YP: 6/ 8 APIWL: 20.0 TEST CASING @ 3568' Shoe Jts below RTTS Lost 800 psi in 3 minutes. NU FMC Gen 5 casing head, orient & lock down. Drill out cement from 2070' to 2086' RIH. Tag cement at 3441' Test casing to 2200 psi; fell to 1690 psi in 7 min. No surface leaks found. Re-test to 2200 psi; fell to 1575 psi in 10 min. (Suspect leak in bottom joints or shoe.) Alerted weekend duty engineer of problem and plans. POH for RTTS. 03/14/98 (Dll) TD: 3959' (264) SUPV:DEB MW: 10.0 VISC: 98 PV/YP: 46/45 APIWL: 2.6 CIRC AND CONDITION CORING MUD POH. Down load LWD tools. Test above RTTS to 2170 psi for 30 min casing test, lost 25 psi. OK. Casing is good. Leak is out shoe joints (Shoe at 3677'). Held PJSM with Geologist; Sperry-Sun; Baroid; Parker Tool Pusher; Co. Rep; & rig crew. Drill to 3959' MD; 3038' TVD. 03/15/98 (D12) TD: 3972' ( 13) SUPV:DEB MW: 10.2 VISC: 114 PV/YP: 44/42 APIWL: 2.4 POH. CORE BBL #1 @ SURFACE. RIH to bottom at 3959' POH to shoe & monitor well, static. Held PJSM. Core 9-7/8" x 4-3/4" core from 3959' to 3972' MD; 3051' TVD. (1.88 ACT). First 5' cored very slow; broke thru "cap" at approx 3964' and cored very fast to 3972' Stopped coring at 3972' to try to avoid washing away too much of top of Tabasco. 03/16/98 (D13) TD: 3988' ( 16) SUPV:DEB MW: 10.2 VISC: 115 PV/YP: 49/43 APIWL: 2.6 POH AFTER CLEAN OUT RUN POH after Clean Out Run & Drilling 1' to 3989', PU Core Barrel with stabilizers for Core #3. POH tight & swabbing in shale above Tabasco. PJSM on laying down core. Got on "hard" spot or barrel jammed last 1' (3988' MD). 03/17/98 (D14) TD: 4019' ( 31) SUPV:GRW 03/18/98 (D15) TD: 4028'( 9) SUPV:GRW MW: 10.2 VISC: 118 PV/YP: 50/41 APIWL: 2.6 CORING Make 1' new hole to get fresh face. Core from 3989' to 3999' ADT = 1.0. Trip out of hole w/ core barrel. Tite from 3958' to 3709' Ream from 3677' to 3999' Drill from 3999' to 4014' and slow ratty ROP (4-8 fph. Had drilling break from 4014' to 4019' (50+ fph) . MW: 11.0 VISC: 117 PV/YP: 57/44 APIWL: 2.4 POOH W/CORE Pump out of hole to shoe. Pump pill. POOH. Core from 4019' to 4028' Core catcher came off w/ core bit. Recovered .9 ft of core. Drill from 4028' to 4043' ADT = .36. 03/19/98 (D16) TD: 4099'( 71) SUPV:GRW MW: 11.1 VISC: 133 PV/YP: 61/51 APIWL: 2.4 POOH W/CORE Hold safety mtg w/ new crew on handling core barrel. Core from 4043' to 4049' ADT=2 hrs. Drill from 4049' to 4099' Catch 5' samples. ADT = 1.41 hrs 03/20/98 (D17) TD: 4427' (328) SUPV:GRW MW: 10.5 VISC: 69 PV/YP: 35/20 APIWL: 3.5 RIG W/CLEANOUT ASSEMBLY Drop bypass ball and core from 4099' to 4117' Hold safety meeting re laying down core. Drill from 4117' to 4427' ADT=5.96hrs. 03/21/98 (D18) TD: 4427' ( 0) SUPV:GRW MW: 10.6 VISC: 80 PV/YP: 35/29 APIWL: 3.5 LOGGING POOH for logs. Hold safety mtg. Wash & ream from 3441' to 4427' 03/22/98 (D19) TD: 4427' ( 0) SUPV:GRW MW: 10.6 VISC: 76 PV/YP: 36/26 APIWL: 3.8 RIH TO SET SAND PLUG Finish run #2, Run ~3: FMI/GR. Hold safety mtg. Casing & cementing. 03/23/98 (D20) TD: 4427' ( 0) SUPV:GRW MW: 10.5 VISC: 75 PV/YP: 35/29 APIWL: 3.8 POOH RIH with 3.5" tubing. Pump 1st stage sand plug back. Pump 2nd stage sand plug back. Pump 3rd stage sand plug back. 03/24/98 (D21) TD: 4427' ( 0) SUPV:GRW MW: 10.3 VISC: 76 PV/YP: 32/30 APIWL: 3.9 FRERZE PROTECTING Clean out to 3940' Hold Safety mtg. Test liner lap to 2000 psi for 5 min. Test door seals to 300/3000 psi. 03/25/98 (D22) TD: 4427' ( 0) SUPV:GRW MW: 8.3 VISC: 26 PV/YP: 1/ 0 APIWL: 0.0 RUNNING POLISHING MILL Run 7-5/8" tieback. Stab into sealbore extension. Test 03/26/98 (D23) TD: 4427' ( 0) SUPV:GRW seals to 300 psi. Test casing to 1900 psi. Displace well with water, brine and diesel. Space out and attempt to land tieback string. Tagged 13' above TOL. Washed until seals 3' into seal bore. Could go no further. RIH with concave mill bit sub. Wash to 3439' Work thru junk at TOL. MW: 10.2 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CUTTING DRILLING LINE RIH with polishing mill. Pump 2 hi-vis polymer sweeps. Run 7-5/8" casing. Freeze protect with diesel. N/D BOPE. Pressure test annulus to 2000 psi and casing to 3000 psi, OK. 03/27/98 (D24) TD: 4427' ( 0) SUPV:GRW MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish N/U Xmas tree and clean up cellar. Release rig ~ 0600 hrs. 3/27/98. REMEDIAL AND COMPLETION OPERATIONS WELL:2T-202 RIG:NORDIC WELL_ID: AK8645 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:03/07/98 START COMP:04/14/98 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20254-00 04/14/98 (C25) TD: 4427' PB: 0' SUPV:DB REPAIR CHOKE VALVES - LOA MW:10.4 BCMUD Move rig from 1D-01 to 2T-202. Accept rig @ 20:30 hrs. Remove tree, NU BOPE. 04/15/98 (C26) TD: 4427' PB: 0' SUPV:DB CLEANING OUT 7-5/8" CASIN MW:10.2 KCLPLY NU BOPE. Test BOPE 250/5000 psi. RIH with 6.75" clean out assembly. 04/16/98 (C27) TD: 4427' PB: 0' SUPV:DB CLEAN OUT 7-5/8" CASING MW:10.1 KCLPLY Circ down tagged @ 3459', did not encounter restriction at 3444' with mill. Wash and ream from 3459' to 3755'. RIH w/bladed concave mill. Mill on junk and clean out sand and cement from 3755' to 3768' with slight mill cuttings back. 04/17/98 (C28) TD: 4427' PB: 0' SUPV:DB CLEANING OUT SAND @ 3938' MW:10.1 KCLPLY MILL CNT/SAND/JUNK F/3771 T/3806' MU FIVE BLADE CONCAVE JUNK MILL AND RIH TO 3773'. CLEAN OUT CMT AND FLOAT COLAR F/3806 T/3873' 04/18/98 (C29) RU SCHLUMBERGER MW:10.1 KCLPLY TD: 4427 ' PB: 0' SUPV: DB POH, LAID DOWN MILL AND JUNK SUBS. MILL IN GOOD CONDITION, SEVERAL SMALL PIECES OF JUNK RECOVERED FROM SUBS. PULLED ABOVE SHOE TO 3770', ROTATED AND RECIPROCATED PIPE, CIRC HOLE CLEAN. SHUT DOWN PUMPS AND MONITORED WELL. RIH, TAGGED FILL @ 4245' 04/19/98 (C30) TD: 4427' PB: 4257' SUPV:DB UNDERREAM HOLE TO 12-1/4" MW:10.1 KCLPLY RIH T/4259', NO FILL. RU SCHLUMBERGER, RAN DDL/CAL F/4270 T/3000' MADE TWO RUNS W/SIDEWALL CORE GUNS, ATTEMPTED 90 SHOTS, COMPLETED 84. 04/20/98 (C31) TD: 4427' PB: 4257' SUPV:DB FLUSH AND CLEAN SURFACE E MW:10.1 KCLPLY Open hole to 12.25" from 4158' to 4259'. CBU. Pull up to 3929' Open hole from 3953' to 4005', observed rotary torque increase. POOH with underreamer. RBIH and underreamer hole to 12.25" from 4005' to 4091' 04/21/98 (C32) TD: 4427' PB: 4257' SUPV:MC/B RUN AND GRAVEL PACK LINER MW:t0.1 BRINE RIH, tagged 2' of fill @ 4257'. Pump high vis pill and displaced hole to 10.1 ppg filtered NaBr brine. Pump clean up sweep. Displace drill pipe with acid pickle. Spot completion fluid with lithium hypochlorite across open hole section. 04/22/98 (C33) TD: 4427' PB: 4257' SUPV:MC/DB REVERSE CIRCULATE AND CLE MW:10.1 BRINE Attempt to reverse out lithium hypochlorite. Unable to circulate. Mule shoe packed off. Pull into casing @ 3883' Attempt to reverse out lithium hypochlorite. Pipe packed off. Circulate down drill pipe to clear restriction. Pump acetic acid. Reverse out acetic acid to waste tank. RIH with Baker open hole gravel pack assembly to 3859' 04/23/98 (C34) TD: 4427' PB: 4257' SUPV:MC/DB POOH LAYING DOWN 3.5" DRI MW:10.1 SW Pressure test lines to 4500 psi. Set packer. Perform flow test. Perform open hole gravel pack. Flow test gravel pack. Set Baker retrievamatic packer. Attempt to POOH, fluid losses increased when seal assembly cleared top of packer. Spot pill. Pull seals above packer and monitor fluid loss. Spot 2nd pill and monitor losses. Re-position seals in packer. 04/24/98 (C35) TD: 4427' PB: 4258' SUPV:MC/DB TRIP OUT MW:10.0 BRINE PUMPED 40 BBL LCM PILL TO EQUALIZATION AND PULLED SEAL ASSY ABOVE PACKER. MONITORED WELL, LOSSES SLOWED TO 3 BPH AFTER 1 HOUR, 15 BBL FLUID LOSS. 04/25/98 (C36) TD: 4427' PB: 4258' SUPV:MC/DB MOVING RING TO 3G-14. MW:10.1 BRINE RU AND TEST 7-5/8" X 3-1/2" ANNULUS TO 2500 PSI, 15 MIN. RU AND TEST TUBING TO 2500 PSI, 15 MIN. SET TWC IN HANGER, ND BOPE, SERVICED DOUBLE GATE FOR STORAGE. End of WellSummary for Well:AK8645 SURVEY CALCULATION AND FIELD WORKSHEET uo .o. 0450-96337 Sidetrack No. P ...... · Company ARCO ALASKA, iNC. Rig Contractor & No. PARKER245 Field KUPARUK RIVER UNIT ' ~ ~' Well Name & No. PAD 2T/TAB02 Survey Section Name Definitive Survey BHI Re ROBBY BARNARD WELL DATA' ~ '~: '1 ~1 get'l'VD (FT) Target Coord. N/S Slot Coord, N/S 447,00 Grid Correction 0.000 Depths Measured From: RKB [~ MSL[~ SS0 get Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 27.430 Calculation Method MINIMUM CURVATURE 'get Direction (oD) Build\Walk\DL per: 100ft[~ 30m~] 10m~] Vert. Sec. Azim. 316.85 Magn, to Map Corr, 27,430 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 (FI') (DO) (OD) (F'r) (FI') IF'r) (1~ (Per ~0o F'r)Drop (-) Left (-) MWD 0,00 0,00 0,00 0.00 0,00 0,00 0.00 TIE IN POINT · MAR-98 MWD 121.00 0.00 0.00 121.00 121,00 0.00 0,00 0,00 0,00 0.00 9 1/2' M1 C 1.3 DEG AKO , -MAR-98 MWD 172.00 0,50' 112,00 51,00 172.00 -0,20 -0.08 0,21 0,98 0,98 GYRO · MAR-98 MWD 280.22 0,22 270.30 108.22 280,22 -0,49 -0,26 0,44 0,66 -0,26 MWD -MAR-98 MWD 354,00 2,00 322,00 73,78 353,98 0,89 0,76 -0,50 2,54 2,41 GYRO .MAR-98 MWD 464.31 4,24 328,36 110.31 464,12 6,81 5,75 -3.82 2,05 2,03 MWD -MAR-98 MWD 534.00 6.00 328,00 69.69 533,53 12,90 11,03 -7.10 2,53 2.53 -0.52 GYRO -MAR-98 MWD 644.97 7,10 329.81 110.97 643.78 25.28 21.87 -13,63 1.01 0,99 1.63 9 1/2' M1C 1.5 DEG AKO I-MAR-98 MWD 733.15 10.67 315,07 88.18 730.89 38.75 32.37 -22.14 4.77 4.05 -16,72 ,_ ~-MAR-98 MWD 823.19 16,72 317.33 90.04 818.33 60,06 47.81 -36.82 6.74 6,72 2,51 9 1/2' MlC 1.8 DEG AKO , , , ,-MAR-9S MWD 916.08 23,12 319.46 92.89 905.62 91.67 71.52 -57.75 6,93 6,89 2.29 i-MAR-98 MWD 1005.96 28.90 315.46 89,88 986.37 131.05 ,00.43 .84.48 6.72 6.43 -4.45 U t-MAR-98 MWD 1096.26 33.28 313.60 90,30 1063.68 177.62 133.09 -117.74 4.97 4.85 '2.06 , · )-MAR-98 MWD 1188.07 36.85 313.21 91.81 1138,82 230,26 169,32 -156.06 3.90 3.89 -0.42 ' ' I ~-MAR-98 MWD 1283.57 43.17 315.13 95,50 1211,93 291,56 212,13 -200.02 6:74 6.62 2.01 )-MAR-98 MWD 1377.84 49.27 315.55 94,27 1277,12 359.57 260.52 -247.83 6.48 6.47 0.45 )-MAR-98 MWD 1471.82 54.13 315.02 93,98 1335.35 433,27 312.91 -299.72 5.19 5,17 -0.56 9'1/2" MlC 1.4 DEG AKO 3-MAR-98 MWD 1563.30 52,76 316.97 91.48 1389.84 506.74 365.75 -350,77 2.27 -1,50 2.13 3-MAR-98 MWD 1658,52 51,72 316.96 95.22 1448,15 582,02 420,78 -402,14 1.09 -1.09 -0,01 0-MAR-98 MWD 1745,64 52.07 317,04 87.12 1501,91 650,57 470,91 -448,90 0,41 0.40 0,09 0oMAR-98 MWD 1837.35 56.37 317,68 91.71 1555,52 724,95 525.64 -499.28 4.72 4.69 0,70 0~MAR-98 MWD 1928.85 59.47 318.40 91.50 1604.11 802,45 583.29 -551.10 3.45 3.39 0,79 i 0-MAR-98 MWD 2022,61 61.44 317.73 93.76 1650.34 883.99 643,96 -605.61 2.19 2,10 -0,71 O- MAR-98 MWD 2303.32 61,38 318.63 280.71 1784,67 1130.41 827.65 -769.96 0.28 -0.02 0.32 I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-96337 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER 245 Well Name & No. PAD 2T/TAB02 Survey Section Name Definitive Survey WELL DATA Sidetrack No. ~ PaGe.. Field KUPARUK RIVER UNiT BHI Rep. ROBBY BARNARD Target TVD (FO Target Coord. N/S Slot Coord. N/S 447.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ Target Description Target Coord. EAN Slot Coord. E/W 556.00 Magn. Declination 27.430 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[~ 30mE] lomE] Vert. Sec. Azim. 316.85 Magn. to Map Corr. 27.430 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (OD) (DO) (FO (FO (FO (FO (Per 1oo FT)IDrop (-) Left (-) 1 O-MAR-98 MWD 2488.69 58.83 318.17 185.37 1877.06 1291.04 947.82 -876.64 1.39 -1.38 -0.25 9 1/2' M1C 1.4 DEG AKO , · ,, 1 O-MAR-98 MWD 2583.39 55.28 317.92 94.70 1928.55 1370.48 1006.91 -929.76 3.76 -3.75 -0.26 . 1 O-MAR-98 MWD 2676.22 53.19 317.81 92.83 1982.80 1445.79 1062.76 -980.29 2.25 -2.25 -0.12 1 O-MAR-98 MWD 2768.39 51.60 318.40 92.17 2039.04 1518.79 1117.11 -1029.05 1.80 -1.73 0.64 1 o-MAR-98 MWD 2861.89 49.02 317.61 93.50 2098.75 1590.72 1170.59 -1077.18 2.83 -2.76 -0.84 1 O-MAR-98 MWD 2951.75 46.37 317.50 89.86 2159.23 1657.16 1219.62 -1122.03 2.95 -2.95 -0.12 1 O-MAR-98 MWD 3046.58 43.22 316.63 94.83 2226.52 1723.97 1268.54 -1167.52 3.38 -3.32 -0.92 1 O-MAR-98 MWD 3140.65 39.65 316.47 94.07 2297.03 1786.21 1313.73 -1210.33 3.80 -3.80 -0.17 ' 10-MAR-98 MWD 3233.14 36.21 315.88 92,49 2369.97 1843.05 1354.75 -1249.68 3.74 -3.72 -0.64 10-MAR-98 MWD 3327.39 32.50 314.81 94.25 2447.77 1896.21 1392.59 -1287.04 3.99 -3.94 -1.14 10-MAR-98 MWD 3419.86 28.54 313.11 92.47 2527.41 1943.10 1425.21 -1320.80 4.38 -4.28 -1.84 10-MAR-98 MWD 3513.28 24.37 312.21 93.42 2611.03 1984.59 1453.42 -1351.38 4.48 -4.46 -0.96 10-MAR-98 MWD 3603.14 20.12 310.88 89,86 2694.18 2018.46 1476,01 -1376.81 4.76 -4,73 -1.48 i;~ 11 -MAR-98 MWD 3659.71 16.98 310.19 56.57 2747.81 2036,35 1487.71 -1390,48 5.56 -5.55 -1.22 /~, 14-MAR-98 MWD 3708.67 15.57 311.41 48,96 2794.81 2049.99 1496.67 -1400.87 2.96 -2.88 2.49 9 7/8' ROTARY ASSEMBLY 14-MAR-98 MWD 3804.73 15.10 312.02 96.06 2887.45 2075.29 1513.57 -1419.84 0.52 -0.49 0.64 14-MAR-98 MWD 3897.75 14.67 312.19 93.02 2977.34 2099.10 1529.59 -1437.57 0.46 -0.46 0.18 : 14- MAR-98 MWD 3906.11 14.52 310.75 6.36 2985.43 2101,20 1530.99 -1439.14 4.70 -1.79 -17.22 , 19-MAR-98 MSS 4046.00 14.00 317.43 139.89 3121.02 2135,56 1554.90 -1463.88 1.23 -0.37 4.78 MSS 20-MAR-98 MSS 4355.00 12.75 317.43 309.00 3421.64 2207.03 1607.54 -1512.23 0.40 -O.40 0.00 MSS 20-MAR-98 MSS 4427.00 12.75 317.43 72.00 3491.86 2222.92 1619,24 -1522.98 0.00 0.00 0.00 Projected Data - NO SURVEY Monday, March 16, 1998 Well 2T 202 Core Description, Core #1 (CI-I) Core cut fi'om 3959' MD to 3972' MD; Total footage attempted - 13': Total footage recovered - 2.5' Top 6": MUDSTO~q~., dark gray, nonfissile, dull, very firm,, gritty, feel, irregular sharp contact with;.' Unknown thickness: Ttn~ (volcanic), light gray, altered, brittle, waxy luster, irreg~r lensoidal fissility; Unknown thickness: . S~a)STO~, medium gray, medium to coarse grained w/large floating gravel clasts (up to 1" diameter), firm, well cemented, no hydrocafoon staining, overlying;, Bottom 6" (base): S~-4r)¥ P~m,~. Cotqa~.ot~t~m-~T~, medium gray, firm, moderate cement, pin point oil saUumion, bleeding from SS mau-ix, most matrix not oil saturated/med. Appears core loss (- 4' ?) ocam~ by disaggregation of the tuffaceous interior. ORIGINAL Monday, March 16, 1998 Parker Drilling Co., Rig #245 Well 2T-202 Core Description, Core #2 (C2) Core #2 cut from 3972' MD to 3988' MD; total footage attempted (core 2) - 16': total footage recovered (core 2) - 2.6' (16.25% recovery core 2 - total recovery, cores 1 and 2 - 17.6%): two preserved sections, one section (C2-1) marked from 3972 to 3973.1 (unconsol.) and the second section (C2-2) marked from 3973.1 to 3974.6 marked unconsol./con. (Due to varied formation cement) Top - unknown thickness CL,x¥, dark gray, medium soft, non-plastic, thin bedded Unknown thickness SANDSTONE, very dark gray to black (oil stained), medium to coarse grained w/large floating gravel clasts (up to 1.5" diameter), unconsolidated,. 0il saturated, bleeding, overlying; Base - unknown thickness .. SANDY PEBBLE CONGLOMERATFJBRECCIA (wacke), very dark gray to black (oil stained), unconsolidated to moderate/hard cement, pebbles: medium to fine grained; angular to rounded (composed of qtmnz, chert,. and rock fragments), sand: coarse to medium grained; mb-angular to sub-rounded, good to poor porosity., oil saturated, oil bleeding from sand matrix. The poor recovery appears to be caused by the cemented conglomerate not moving up into the core Curtis Goddard Rig Geologist Tuesday, March 17, 1998 Parker Drilling Co., Rig #245 Well 2T-202 Sample Cuttings Description and Core Description, Sample collected from the shakers while coring Core #3 (C3) During the coring, cuttings were collected from the shakers at 3990, 3994, and 3998, MD. The descriptions are the same for all three depths and are as follows: SAND with siltstone and shale, dark gray, lithic, medium to f'me grained, subangular to subrounded, unconsolidated, well sorted, oily. Core #3 was cut from 3989' MD to 3999' MD; total footage attempted (core 3) - 10': total footage recovered (core 3) - 2.5' (25% recovery core 3 - total recovery cores 1 through 3 - 19.5%): one preserved section (C3-1) marked from 3989 to 3991.5 (both unconsolidated and consolidated) SANDY PEBBLE CONGLOMERATE/BRECCIA (wacke), light gray to very dark gray to black (oil stained), unconsolidated to moderate/hard cement, pebbles: medium to f'me grained; angular to rounded (composed of quartz, chert, and rock fragments), sand: lithic, coarse to medium grained; sub-angular to sub-rounded, good to poor porosity, oil saturated, oil bleeding from sand matrix, some asphaltic material. NOTE: the bottom 0.8' of the core was 'caught' outside the core catcher. This core was well cemented and tight. It is oil bearing but not producing. The gravel size was gradational - medium size gravel at the base and f'me gravel at the top. The poor recovery appears to be caused by the cemented conglomerate not moving up into the core bbl. - same problem as before. Curtis Goddard Rig Geologist Wednesday, March 18, 1998 Parker Drilling Co., Rig #245 Well 2T-202 Core Description, Core #4 (C4) . . Core cut fxom 4018' MD to 4029' MD; total footage attempted (core 4) - 11': total footage recovered (core 4) - 0.9' (8.2% recovery core 4 - total recovery cores 1 through 4 - 17% [8.5' recovered/50' attempted): one preserved section (C4-1) marked from 4018 to 4018.9 (unconsolidated) (--- Softball size) S~xtD, very dark gray (oil stained), medium to coarse grained with floating gravel clasts, soft,, not cemented (appeared to be held together by heavy hydrocarbons?), good porosity, bleeding oil; The rest was loose pebbles and sand, all oil stained and the same description as the sandy pebble conglomerate previously observed. The entire core recovered was contained in the core catcher., which was bleeding oil as it sat on the rig floor (the core catcher came off the coring assembly with the bit). It was noted the core catcher was viability. ground down by the formation and therefore, was cutting the formation along with the bit. This would account for the cut core being at too large ora diameter to slide up into the core barrel, and jamming, preventing further core capture. Curtis Goddard Rig Geologist Thursday, March 19, 1998 Parker Drilling Co., Rig #245 Well 2T-202 Core Description, Core #5 (C5) Core cut from 4043' MD to 4049' MD; total footage attempted (core 5) - 6': total footage recovered (core 5) - 3.0' (50% recovery core 5 - total recovery cores 1 through 5 - 20.5% [I 1.5' recovered/56' attempted): one preserved section (C5-1) marked from 4043 to 4046 Cooth unconsolidated and consolidated) Top 0.6' $.42qDV PEBBLE CONGLOMERATE./BRECCIA (wacke), very dark gray to black (oil stained), unconsolidated. pebbles: medium to fine grained; angular to rounded (composed of rock fragments), sand: coarse to medium grained; sub-angular to sub-rounded, good to poor porosity, oil saturated, bleeding, some asphaltic material. Ne, ct 3' S.~qDSTONE wrm PEBBLES, very dark gray to black (oil stained), medium to coarse grained w/floating gravel fine grained clasts, mod sorted,, unconsolidated but appears to be softly 'cemented' by heavy h.vdrocarbons, oil saturated, bleeding, overlying unknown thickness - between top and base SANDY PEBBLE CONGLOIvIERATE/BRE(2CIA (wacke), - same as top 6" base - Y' thick SAaNDY PEBBLE CONGLOMERATE, very. dark gray to black (oil stained), modemteghard cement, pebbles: fine grained; subrounded; sand: coarse to medium grained; sub-angular to sub-rounded, good porosity, oil saturated,, bleeding, heavy oil present. - Note: lithology could not be determined due to the heavy oil stain on the grains/pebbles. Curtis Goddard Rig Geologist Friday, March 20, 1998 Parker Drilling Co.: Rig #245 Well 2T-202 Core Description, Core Core cut from 4099' MD to 4117' MD; total footage attempted (core 6) - 18': total footage recovered (core' 6) - 0.0' (0% recovery core 6 - total recovery cores 1 through 6 - 15.5% [11.5' recoverecV74' attempted). Before cutting Core fi6 the borehole was drilled from 4049' MD to 4099' MD. Cutting samples were collected every five feet over this intervaL These intervals were 4054, 4059, 4064, 4069, 4074, 4079, 4084, 4089, 4094, and 4099' MD. The sample descriptions looked the same for all samples (I don't have a scope for descriptions - only a hand lens) and is as follows: SAND, dark gray, lithic (angular chips throughout the samples indicate pebble conglomerate - larger clasts drilled to chips), sand: medium to coarse grained, subang-lar to subrounded, well sorted, oil saturat6d, bleeding. The plan is to drill to TD and collect samples, off the shakers, every 5'.. Wireline logs, including sidewall cores, are scheduled for this evening or early morning tomorrow. If this hole is too washed out to complete the logging program, a sidetrack is schedule& Curtis Goddard Rig Geologist 5/11/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11157 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 2T-202 --~ ~:~'~'~ 98197 OH EDIT-DAS,FMI,AIT, CNT,DLL,SDN 980321 1 2T-202 981 97 PEX-AIT 9803~-1 I 1 2T-202 98197 :P]~(:~ 980321 1 1 2T-202 98197 :P~X:-~/I.,]7~ 9803~.1 I 1 2T-202 98197 PEX-MCFL 980321 I 1 2T-202 98197 DUAL LATERLOG W/PEX 980419 I 1 2T-202 98197 PEX-SSTVD 980321 I 1 2T-202 98197 MICROLOG 980321 I 1 2T-202 98197 DSI 980321 I 1 2T-202 98197 CEMENT VOLUME LOG 980321 I 1 2T-202 98197 SIDEWALL CORES 980419 I 1 2T-202 98197 SIDEWALL CORE SUMMARY 980322 I I ~ ~ "" DATE: SIGNED: _ =J/-~ ~L..~- -.Z~<~.L_~:- ~-( Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. WELL LOG TRANSMYI'T~ To: State of Alaska April 29, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs TABASCO 2T-202, AK-MM-80154 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 TABASCO 2T-202: 2" x 5" MD Resistivity & C_ramma Ray Logs: 50-103-20254-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20254-00 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 TRANSMITrAL To: State of Alaska April 29, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs TABASCO 2T-202, AK-MM-80154 1 LDWG formatted Disc with verification listing. API#: 50-103-20254-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc, TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 3. 1998 Michael Zanghi Drilling Superintendent ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Rc: Kupamk River Unit 2T-202 ARCO Alaska. Inc. Pcrmit No: 98-37 Stir. Loc.: 447'FSL. 556'FWL. Sec. 1. T1 IN. RSE. UM Btmhole Loc: 2059'FSL. 955'FEL? Sec. 2, T1 iN. RSE. UM Dear Mr. Zanghi' Enclosed is thc approved application for permit to drill thc above referenced well. Thc permit to drill docs not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prcvcntion equipmcnt (BOPE) must be tcstcd in accordance with 20 AAC 25.035. Sufficicnt notice (approxilnatcly 24 hours) of the BOPE test pcrformcd bcforc drilling below the surface casing shoc must bc given so that a rcprescntativc of thc Commission may witncss the test. Notice may be. given by~ the Commission petroleum field inspector on thc North Chairman BY ORDER OF THE COMMISSION dlf/ench~sures l)cpartment of Fish & Game. I[abitat Section w, o encl. I)cpartmcnt of Environmental Consen'ation w:o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.00,5 la. Type of Work Drill X Redrill ~' lb Type of Well Exploratory ~,' Stratigraphic Test E~ Development Oil X Re-Entry E Deepen [--' Service E Development Gas [~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation ' _'. I (-')_4 P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25569, ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) / 447' FSL, 556' FWL, Sec. 1, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1966' FSL, 868' FEL, Sec. 2, T11 N, RSE, UM 2T-202 #U-630610 At total depth 9. Approximate spud date Amount 2059' FSL, 955' FEL, Sec. 2, T11N, RSE, UM 3/4/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-23 4427' MD 2059' @ TD feet 15' @ 100' feet 2560 3522' TVD 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 60.8° Maximum su~a~ 1799 psig At total depth (TVD) 2134 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 13.5" 10.75" 45.5# K-55 BTC 3596' 41' 41' 3637' 2758' 815 Sx Arcticset III & 490 Sx Class G & 60 sx AS I 9.875" 7.625" 29.7# L-80 BTC MOD 3876' 41' 41' 3917' 3028' 117 sx Class G 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured), true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~% ~,~ ~,~.,. ~i~..~ Conductor "'~¢ ;~' ¢~ Surface ~%, i~ ~ E- Intermediate Production ORIGINAL Liner ii: ~7..r'`' ~'~' Perforation depth: measured true vertical t,~.~.ql.-,, ' o 20. Attachments Filing fee X Property plat r~ BOP Sketch X DiverterSketch X ['.iichD~i~ program X Ddlling fluid program X Time vs depth plot [~ Refraction analysis J~ Seabed report ~ 20 AAC 25.050 requirements X 21. I hereby certify that th~ foregoing is true and correct to the best of my knowledge Signedf ~~~j// ,j~,,~j, ~~' ,~/j~/l/~,/~/ Title Drilling Superintendent Date '"" ~X/ Commission Use Only Permit N~'~'er ~7 I A"~'~> I See c°ver'etterf°r 50- ~ <::3 ,~_...,~ ~ IAppr°valdate ' ' · -'" -- other requirements Conditions of approval Samples required r- Yes' j~ No Mud l d E~ Yes J~ No Hydrogen sulfide measures J~ Yes 1~ No Directional survey required ~ Yes J~ No Required working pressure for BOPE [~ 2M J~ 3M E~ 5M ~ 10M E 15M Other: Original Signed By by order of Approved by David W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 J.'~S jbmit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - TABASCO POOL 2T-202 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 13.5" hole to 10-3/4" surface casing point (+/3637' MD) according to directional plan. 4. Run and cement 10-3/4" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and using light weight lead permafrost cement. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to a maximum of 13.5 ppg EMW. 7. Drill 9.875" hole to proposed core point (+/- 3900' MD) according to directional plan. 8. Core Tabasco Sands 9. Ream cored interval and finish drilling 9.875" hole to well total depth (+/- 4427' MD) according to directional plan, running LWD logging equipment as needed. 10. Run open hole wireline logs as needed. 11. RIH to TD. PU and spot a sand plug to cover the Tabasco sands and provide a base for cementing the 7-5/8" liner. 12. Run and cement the 7-5/8" intermediate liner with the liner shoe 10' - 20' above the Tabasco sands. Design liner lap for +/- 150' inside the 10-3/4" surface casing. Set liner top packer and pressure test. 13. Tie the liner back to surface. Displace well with kill weight brine and non-freezing fluids during tieback operation. 14. Pressure test liner and tieback to 3000 psi. Set back pressure valve. 15. ND BOPE. NU production tree. Release drilling rig. 16. Move in and rig up Nordic 2 17. ND production tree. NU BOPE and pressure test to 3000 psi. Pull back pressure valve. Test casing to 3000 psi 18. Drill out plugs and cement and wash out sand to desired depth. POOH and run open hole caliper log to confirm hole volume for gravel packing. 19. RIH with scraper assembly with 2 scrapers and a bit with no jets. RIH to PBTD and check for fill. If fill is present, reverse out to PBTD. 20. Displace the drill-in fluid with completion fluid. POOH 21. Pick up openhole gravel pack assembly and RIH to PBTD 22. Set and test Gravel Pack packer. Gravel pack the well by circulating gravel pack sand until a sand out pressure of 1500 psi is obtained. POOH and lay down gravel pack service tools. 2T-202 TAB,02/20/98, v.3 23. Pick up 3-1/2" tubing with seal assembly, gas lift mandrels, and heat trace, and RIH. Sting into packer seal bore. 24. Land tubing and set tubing hanger. Set BPV 25. ND BOPE. NU tubinghead, master valve and production tree. 26. Secure well and release rig. 2T-202 TAB,02/20/98, v.3 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 2T-202 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 10-3/4" Surface Casin~ 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to Core Point 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Core Point To TD 10.4 10-18 15-25 35-45 4-8 6-10 4-5 7.5-8.5 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. A clean, new Iow solids system will be displaced into well after drilling out and running FIT Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure 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/ft. This shows that formation breakdown would occur at a surface pressure of 1800 psi. The leak off EMW was chosen based on an open hole FIT on 2T-Tab-01 taken to 12.5 ppg at 2025' TVD (0.65 psi/ft). Therefore, Arco Alaska, Inc. will test the BOP equipment to 3000 psi. MASP = (3048 ft)(0.70 - 0.11) = 1800 psi Based on offset well data, reservoir pressures in the Tabasco sands in the vicinity of 2T pad are expected to be +/- 1500 psi (0.49 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.4 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 3048' at the top of the formation. Well Proximity Risks: The nearest existing well to 2T-202 is KRU 2T-23. As designed, the minimum distance between the two wells would be 15' at 100' MD. 2T-202 TAB, 02/20/98,v. 2 Drilling Area Risks: Risks in the 2T-202 drilling area are limited to lost circulation and potential borehole instability in the Tabasco formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous DS 2T drilling results, 10.4 ppg mud should be adequate to control both the West Sak and Tabasco formation pressures without resulting in lost circulation. The 10-3/4" casing shoe will be tested to an equivalent mud weight of 13.5 ppg upon drilling out of the surface casing. ARCO Alaska, Inc. has drilled through the Tabasco formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 ACC 25.033 (e) and 20 ACC 25.601 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of 2T-202. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well on 2T Pad. (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 2T-202 7-5/8" tieback casing annulus will be filled with kill weight brine and diesel after setting the 7-5/8" tieback string and prior to the drilling rig moving off of the well. 2T-202 TAB,02/20/98,v.2 Tabasco 2T-202 PfSducer Well Proposed Well Design FMC Wellhead ARCO Alaska, Inc. 16" 62.5# H-40 @ _+121' Directional KOP = 300' Max Angle = 61 ° @ 2493' MD completion interval = 15° Heat Trace @ _+ 2250' 3-1/2" 6.5# 8rd ABMod Production Tubing 3-1/2" Gas Lift Mandrels w/1-1/2" pockets 7-5/8"x10-3/4" Baker "HMC" Liner Hanger w/"ZXP" Liner Top Packer tied back to surface 10-3/4" 40.5# K-55 @ _+ 3637' MD OO O O OO" O O O O! oo 0 0 0 0 0 0 ! 000 0000~ 0 0 0 0 0I o o o~ 0 0 0 J I O0 0 0 O0 o o oo~ 0 0 Oi 0 0 01 0 0 0 O0 0 0 00! o o oo~ °° ~ 0 0 0 O0 O00CI 000 ! 0 0 O~ 0 0 0 0 00! I 0 0 0 0° 0 0t o ~' Baker SC-1 GP Packer @ _+ 3854' 7-5/8" 29.7# L-80 @ _+3917' MD Top of Tabasco Sand · +90' 4-1/2' Blank Pipe ± 300' 4-1/2" Wire-wrapped Screen Openhole Gravel Pack PBTD @ _+4427' MD LBL, 2/11/98 Far: B ROCICffAY/McKAY:: ARCO Alaska, Structure : Pad 2T Well : Tab02 i I Field : Kuparuk River Unit Location · North Slope, AlaskaJ <- West (feet) 800 16.00 14-00 1200 1000 800 600 2CCC 400 2OC 0 TD LOCAT:ON: ! 2059' FSL, 955' FEL I SEC. 2, T1 IN, RSE 2CC ~ - i : ~800 ~ EST. RKB ELEVATION: 112' ' I ~ T- ~-- - J TARGET ¢ OCATtON' ! I ..... Ld- O 7 fid Casing , .... '. ~ °T q · ~966' F<' 868' FE! (~ 1TARGET - Top Sand t ~a~. z, ,, ,,~, ~u~ }:: 200 ~ k %¢~0 3/4 Csg Pt /EOD TARGET KOP TVD-300 TMD-300 DEP-O ~Base Wes( Sak Sands ~D=3048 - ' - - ' % TMD=3957 4C0 ~ ' ~ OEP=2082 :~r,r - ~LS: ,.gO deg per 100 ,t ~a.oo i~00 ~ ~2.00 ~ N56.00 B/. PERMAFROST,, ~ WO=la02~ TMD=1725, OEP=653 ~fZVT~,fTT~,f AXT~T ~NO.O0 T/ UGNU SNDS WO=15z7 TMD=~813 DEP=728 ~0~ ~ _VI~IiVI~ UT~Vt' .~IN' ~ ~ FOC W0=1550 TMD=i819 OEP=755' ~60.00 BEGIN ANGLE DROP WD=1879 TMD=2495 DEP=i~2~ 6.00 ~2 nO 2cc0 ~ ~8.00 22CC= ~ ~~~DEP=!757 % ~ ~ %oo.uu ~52.00 SURFACE ~ ~ ~ 447' FSL, 2400 - ~zo. Ou N 24.00 z~O i B/ W SAK SNDS ~D=2672 TMD=5547 OEP=t978 20.00 ] 10 3/4" CSG PT/BOO WD=2758 TMD=3637 DEP:2004~L16'00 ' 2800 3CCC 3200 34-00 360C 203 K-lO TVO=2999 TMD=3aa5 DEP=2069 TARGET T/TAB SND TVD=3048 TMD=3937 DEP=2082 TARGET ANGLE 1 5 DEG B/ TAB SND TV0=3293 TMD=4-1go DEP=2148'~ \ TD - CSG PT TVD=3522 TMD=4427 DEP=2209~. ~ i r , , i ; ii i I ii i I i i i i i 0 2CC 400 600 80C 1000 1200 1400 1600 1800 2000 2200 Verficol Section (feet) -> i 2400 Azimuth 31 6.85 with reference 0.00 N, 0.00 E from slo'r #Tab02 ' 'A CO Alaska, Structure : Pad 2T Well : Tab02 Field : Kuparuk River Unit Location : North Slope, Alaskaj 3OC q 280 i 260 240 220 2C0 ~80 1 8O <- West (feet) 240 220 200 180 160"~ 140 120 100 80 60 40 20 0 1400 1600 1700 "'", I ~2¢0. ',. 1200 " !~500 ',, ~200 ",, -.. \ / ", 1~oo \ / %, \ -,, ; i4oo '" \ 11000 ,~ 1100 I ',,. iooo %,. . -.., , ~ ~0o · ; / " 1400 "' / '% . 1300 1 20 ~-C 6C !300 ? 50C L h 280 ~ 260 F j- 240 j-- 220 / / ;200' / / ,, / ZOO ~: 6C !!00 / / k '40 i / / "% 1000 1'~00 / "",.,.,.. 'k~ ~0'G7 '.... u u / - 1 400 '-, 1 300 / -. k "., ~ ~oo //ooc 10 ,k_ . '.. 60o ~ ~ooo ' ~ soo / 80O ~oo i ' / h 2o 1200 60 -J I t I I I I i J I I J I J I I d I ~10 I 2~,0 220 200 180 160 140 120 100 0 <- West (feel) 14oc 4~0 ~ 1900 I , 40 1200 ! 800 1100 / I 60 :'o ~ 2'0 Z o ARCO Alaska, Inc. Structure : Pad 2T Well : Tab02 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 8.60 76C 720 680 640 600 560 520 480 440 400 380 .520 280 24.0 200 150 880 , , 8C0 ", 760 1 "'""',,, t '~ 1700 720 '".... ,, 680 q "., /\1 .560 (_ ¢80 © 2100 2300 '- 1600 2000 500 4C0 520 280 240 2C0 160 2200 1700 F ~- 800 O0 F ~ 760 = 77~ ' ~ 64o L aoc 2100 2100 'k,~~iu"'; : h sst A - 520 Z 0 2000 J 48C 2~,~0 2000 X 440 ~ 400 ~ 80C' ~ ~60 ',. 1 400 1900 ,,... I 4700 1800 i 1700 120 t , , , [ ~ i i , i i i , [ t ~ ,i , , ~ I [ J 800 760 720 680 640 600 560 520 480 440 4 0 560 <- West (feet) 1 60( ! ",, 13CO -, "-. % 280 2 ~ '". L ~ '-~, 1200 ' 2zC 1 600 x.. '-..~_. [- 2ce "'-.2?oo'x. ~ :60 -- ~ 20 1. t t n i i : ; 320 280 240 20 O 160 1 For: BROCKWA¥/McKAY] n(~e,e~ce ;s re~o2 veta;~ frS. 'ARCO Alaska, i 'c. Structure : Pad 2T Well : Tab02 I Field : Kuparuk River Unit Location : North Slope, Aloskcj 2CGC 'gOO 1800 1700 :500 ~ 130o t I 1100 (_ ~C0O O Z gCC 4 8C0 J 7cc ~ <- West (feet) 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 5C0 400 300 200 700 L ~ aC0 '~ 3Q~Q_ X ~700 "% ~00 2~0~ 5800 6cc~ i 5200 2200 ! 5i00 50O H 2 i O0 ! -'"----_3000 -'--4E° N 48o0 20O 2600 2200 ICO I' f '[ ] t ] [ ] f [ [ I ] [ t I [ I d [ I ~ I I t [ ~800 ~700 ~600 ~500 7400 7500 N200 1~00 7000 900 800 700 600 ",~ 2500 "%2400 .. '-., 2300 3000 ",., \ ~ 3~0o % 2200 2500 ' 2900 ',. 2100 :200 280O " '-~ 2000 ~ i oo 24o0 X. \ 2700 2200 -- 2400\ \ 2600 """..,... 900 2500 -.~ 1800 OO i 5700 '"'""'x,. 210 2300 2x00L~ 80c 5600 2400 '... ~,x2EOC 5500 -. ! 700 200( x ',,, -, 70C 53oo ~ 9o( \\ "'.,., 60o ~, cc~',~\ ~cc '. 500 '% 1500 · <- West (feet) 4O0 ', i 400 '.% 1900 -. - 1800 % 1300L 300 .., ~ 200 4400 i 600 i i 5O0 F~,oc I I i I I i 500 400 300 20!3 4500 ARCO Alaska, [fie. Structure : Pad 2T Well : Tab02 Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE DATA <aP ITc?~et TacO2 Rvsd 30-J 39~6.76 15.C0 316.85 3048.00 1519.08 -1423.96 2O82.13 iLO. & E~o :f Held 4~27.48 15.CD 316.85 3522.00 1611.74 -1510.82 2209.14 ¥C "c O? ,'",,'D Nc,m East V. Sect Deg/:CC, 0.¢¢ 0 Ca 5t 6 83 O.CO 0.80 O.CO O.CO ~CC.C0 C CS ~.~ ~cc.co c.co o.co c.co c.cc~ ~8~8.80 60.75 31685 !549.78534.45-500.g8 732.5~ 4.~ 2~2.S6 60 75 316.851879.17963.59-903.26 1320.75 0.~ ~638.76 15.C0 516.852758.221~62.$~ -1370.862C04.48 $.~ 330 340 35O TRUE NORTH 0 10 2O 32O / i I 120 / f J Corciates c,e ;n feet reference s~ot ~To~02. 30 4~ 6O 29O 7O 28O 2/-'0 260 R~ 240 230 i 3-9%~ 220 140 210 2OO 190 180 170 , W -' No~mc! Place Travelling Cylinder - Feet Ail depths shown are Measured depths on Reference ,,~= ARCO Alaska, Inc. Pad 2T Tab02 slot #Tab02 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : Tab02 Version #8 Our ref : prop2407 License : Date printed : 13-Feb-98 Date created : 26-Sep-97 Last revised : 13-Feb-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.172,w150 0 47.034 Slot location is nT0 19 49.568,w150 0 30.801 Slot Grid coordinates are N 5970427.091, E 498945.146 Slot local coordinates are 447.00 N 556.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-6370'>,,9,Pad 2T PGMS <0-6975'>,,7,Pad 2T PGMS <0-8208'>,,6,Pad 2T PGMS <0-7670'>,,5,Pad 2T PGMS <0-8160'>,,4,Pad 2T PGMS <0-8445'>,,17,Pad 2T PGMS <0-7868'>,,13,Pad 2T PGMS <0-6789'>,,Il,Pad 2T PMSS <3115 - 3645'>,,12,Pad 2T PGMS <0-6725'>,,12B,Pad 2T PMSS <4757-6800'>,,12A,Pad 2T PMSS <1287-1725'>,,2,Pad 2T PGMS <0-8890'>,,2A, Pad 2T PMSS <0-10570'>,,29,Pad 2T PMSS <0-9845'>,,19,Pad 2T PMSS <380 - l1400'>,,31,Pad 2T PGMS <0-8250'>,,10,Pad 2T PGMS <0-7650'>,,8,Pad 2T PMSS <5917-7957'>,,16A, Pad 2T PGMS <0-8947'>,,16B,Pad 2T PMSS <1604-3625'>,,16,Pad 2T PGMS <0-7625'>,,15,Pad 2T PGMS <0-8262'>,,14,Pad 2T PMSS <650 - l1080'>,,37,Pad 2T PMSS <918' - 10890'>,,28,Pad 2T Closest approach with 3-D MinimLun Distance method Last revised Distance 23-Jan-98 219.9 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Ja~-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan- 98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan-98 23-Jan- 98 23-Jan-98 23-Jan-98 23-Jan-98 170.0 143.0 119.1 94.5 469.9 370.0 319.9 343.9 343.9 343.9 45.0 45.0 52.0 499.7 106.0 295.0 195.0 445.0 445 0 445 0 420 0 393 8 542 7 52 4 180.0 20 0 325 0 300 0 300 0 160 0 20 0 300 0 325 0 325 0 325 0 20 0 20 0 675 0 300 0 120 0 120 0 20 0 20 0 20 0 20 0 20 0 300 0 350 0 575.0 Diverging from M.D. 180.0 4427.5 325.0 300.0 4040.0 160.0 20 0 300 0 325 0 325 0 325 0 300 0 3800 0 3576 1 3O0 0 120.0 120.0 300.0 20.0 20.0 20.0 300.0 300.0 350.0 575.0 PMSS <921-10235'>,. Sad 2T ... PMSS <0-12821'>,,21,Pad 2T PMSS <893 - 12977'>,,23,Pad 2T PMSS <469-10632'>,,18,Pad 2T PMSS <0 - 9210'>,,26,Pad 2T PMSS <5497-13787'>,,32B,Pad 2T PMSS <0-5924'>,,32,Pad 2T PMSS <4850 - 5918'>,,32A,Pad 2T PMSS <4627 - 10686'>,,30A, Pad 2T PMSS <0-4749'>,,30,Pad 2T PMSS <741-15471'>,,36,Pad 2T PMSS <918 - 10193'>,,22,Pad 2T PMSS <0-4175'>,,TTa,Pad 2T PMSS <12144-13360'>,,38A, Pad 2T PMS$ <0-9298'>,,27,Pad 2T PGMS <0-7897'>,,3,Pad 2T 23-Jan-98 23 -Jan- 98 23 -Jan- 98 23 -Jan- 98 23-Jan-98 23-Jan- 98 23 -Jan- 98 23-Jan- 98 23 -Jan- 98 23-Jan- 98 23-Jan- 98 23-Jan- 98 23-Jan- 98 23-Jan-98 23-Jan-98 23-Jan-98 515 529 15 482 22 82 82 82 85 85 432 30 207 382 33 69 200 0 100 0 325 0 525 0 900 0 900 0 900 0 675 0 675 0 100 0 100 0 100.0 ~00.0 602.2 280.0 100.0 200.0 3436.8 325.0 525.0 3286.8 3286.8 3286.8 675.0 675.0 100.0 100.0 100.0 100.0 602.2 4427.5 KUPARUK RIVEP '.,.,IT '20" DIVERTER SCHEMATIC 6 I4 i 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES· . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. . CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WE[! RORE FLUIDS OR GAS iS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC?.5.035(b) 1. 16'CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20' - 2000 PSi DRILLING SPOOLWITH ONE 16' OUT'LET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVER'i'ER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WINO CONDITIONS. 6. 20" - 2000 PS! ANNULAR PREVENTER. OKJ3 11~.'94 7 6 5 4 I 1. 16' - 2000 PSI STARTING HEAD 2_ 11' - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI VARIABLE PIPE RAMS 5, 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR 13 5/8" 5000-Psi BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH e 29 I I' MILES I · 26 S~ SH~T ~ ~0~ NOTES ~ND ~ o 2T-202 LOCATION IN~O~T/ON ' D~ILL SITE : 2-T ~ 6 e TABASCO { TT )I ~ e I 3 /NO SCALE/ I ~8~ e 14 2 I e ~ 19 ~ 20 ~ 21 LEGEND o ~w co~uc~o~ ~oc~,o~ ~ LOUNSBURY ~ EXI 5 r lNG CO~O~C rO~5 ARCO Alaska, Inc. 2T-202 ~LL CONDUCTOR Subsidiary of Atlantic Richfield Company AS-BUILT LOCA~ON I 2/15/98 OCS 8C.,M Pt. J£R K$8 No, K98014AC$ T II ,. BASIS OF LOCATION AND ELEVATION ARE O,,LLSITE ~'~L" -~: ~ 2-T MONUMENTS PER LHO 8 ASSOCIATES. ~ I~: ~. COORDINATES SHO, ARE ,.S.P. ZONE 4. ,.,.D. 27.,LL DISTANCES ,RE TRUE. ~ ~ /~ '~~" '~ -~ ~ 3. ELEVATIONS SHO~ ARE 8.P.M.S.L. T. II N.. R.8 E.. UMI~T MERIDIAN. ~L~SK~. 5. DATE OF SURVEY: 2/12/98. FIELD BK. L98-8 pg. 40. 6. SEE REFERENCE DRAWING: CEA-D2TX-866. FOR CONDUCTOR 18-23. 26-32. 36-38 8 T~8~SCO LOC~TIONS. ~ 7. DRILL SITE 2-T GRID NORTH IS ROTATED 179' 59' 40' ~ VICINITY ~P ~' · Zm~L~S ~ST FROM ~.S.P. ZONE 4 GRID NORTH. LOCATED IN SECTION I. T II N . R 8 E . U. M. SEC. SEC. ~L L L INS LINE O. G . P~D NO. Y X L~TI TUDE LONGITUDE O/S O/S ELEV. ELEV. F.5.L. F.W.L. 2T-202 5.970.427.60 498.944.83 70'19'49.573' 150'00'30.810' 447' 556' 77.0' 80.2' g' SURVEYOR'S CER T/FICA TE ~ ~.. '-, ~ I HEREBY CERTIFY THaT I ~M PPOPE~LY ~GIS ~:" ~ %~ ~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF i 49~h ~~ ~ ~ ~ ~L~SK~ ~NO TO~T TH~S PL~T REPRESENTS A SURVEY ~, ..................... ~...~ .... ~ ..... ~OONe OY ~e DO UNOeO ~Y O~OECT SU~eOWS~ON ~.%~-...-.- .... ~~ ~' BRIAN G MANGOLD ~ ~ AS OF FEBRUARY 12. 1998. "- ~"""='- ~ LOUNSBURY ~ DRILL Sim 2-T ARCO Alaska,Inc. 2 -2o2 cou uc o Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ON CADD FILE NO. LK6220D9IDRA"NG NO: CEA-D2TX-6220D9 SHEET: 2/15/98 002 OF 2 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Februaw 20,1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill Tabasco 2T-202 Tabasco Core Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well to the prospective Tabasco interval from 2T Pad in the Kuparuk River Unit ("KRU"). The well is designed to core and test the production potential of the Tabasco sands in the vicinity of 2T pad. The well is planned with an open hole gravel pack completion through the pay sands, which is designed to control the sand production expected in these unconsolidated formations. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the Tabasco sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the Tabasco sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at 2T-202, such as shallow gas. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. lO) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is March 4, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Since~r. Thomas A. Brockway ~ Operations Drilling Engineer Attachments: CC: Tabasco 2T-202 Well File Tom McKay ATO-1202 Jack Walker ATO-1266 Steve Kranker ATO-1252 Lewis Ledlow ATO-1282 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ? ? (~:)O_~ ~. INIT CLASS WELL NAME ,' ./~ .2.,~"- ..~-c:3~ PROGRAM: exp [] dev~/redrll [] serv [] wetlbore seg L~ ann. disposal para req ,_'~ /Z..~.~ y GEOL AREA ~ ?<::~ UNIT# / ////'~""~:2 ON/OFF SHORE ~ ~'~,) ADMINISTRATION 3. 4. 5. 6. 7. 8. 9. 10. 11. 'AP, PR DATEj 12. . .,~. /~,/.~_~/~' 13. L REMARKS Permit fee attached ....................... N Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ 1t'1 N ~.,¢',,~ ?_ If deviated, is wellbore plat included ............... I yIN /"~/'/~,-~f~ _,~ '"~/ Operator only affected party ................... Operator has appropriate bond in force ............. I~yyy N ~-' ' - - ' - ,~' Permit can be issued without conservation order ........ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. N If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ (_~ r n o ~ s~ BOPE press ating approp 'ate; test t '~ ¢ p 'g. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. N N N ~N )N GEOLOGY ,,~R D&TE/ 31. Data presented on potential overpressure zones ........ 32. Seismic analysis of shallow gas zones ............ >,, -33. Seabed condition survey (if off-shore) .......... ~ Y N 34. Contact name/phone for we,eklypro~ress reports . . ~... Y N lexpiora'l:ory only] GEOLOGY: ENGINEERING: COMMISSION: ;2 DWJ .~ JDH ~ ' co co ~/~-I~ Com ments/I nstructions: HOWIIjt - A:\FORMS\cheklist rev 09~97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding 'information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Apr 27 11:38:13 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/04/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services c .osq Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT 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: MWD RUN 1 AK-MM-80154 S. BURKHA_RDT D. BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: TABASCO 2T-202 501032025400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 27-APR-98 MWD RUN 2 MWD RUN 5 AK-MM-80154 AK-MM-80154 S. BURKHARDT P. SMITH D. BREEDEN D. BREEDEN 1 liN 008 447 556 .00 121.20 80.20 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 9.625 3677.0 9.880 4426.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MILLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD DATA IN THE INTERVAL 3622'MD, 2712'TVD TO 3678'MD, 2765'TVD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE RUNNING IN THE HOLE WIPING ON MWD RUN 3. THE DATA IS PRESENTED MERGED WITH MWD RUN 2. 4. RUN 6 IS A CORING RUN WITH NO MWD SERVICE. 5. WELL 2T-202 WAS LOGGED TO A CORE POINT DEPTH OF 3959'MD, 3038'TVD. THIS WELL RECHED A TOTAL DEPTH (TD) OF 4426'MD, 3490'TVD. SROP = SMOOTHED RATE 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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 121.0 RPD 121.0 RPM 121.0 RPS 121.0 STOP DEPTH 3930.5 3930.5 3930.5 3930.5 RPX 121.0 GR 121.0 ROP 123.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 122 5 3427 0 3432 5 3433 5 3435 0 3437 5 3446 0 3449 0 3477 5 3481 0 3490 5 3492 0 3494 5 3502 0 3504 5 3506 0 3507 5 3509 5 3511.5 3512.5 3518.5 3540.5 3543 5 3547 0 3549 5 3554 0 3556 5 3560 0 3561 5 3563 0 3566 5 3568 0 3575 0 3578 0 3589 0 3591 0 3593 0 3594 5 3596 0 3597 5 3651 0 3655 0 3661 0 3676 0 3679 0 3682 0 3683 5 3689 0 3697 5 3714 0 3715 5 GR 121 0 3425 5 3431 5 3433 0 3435 5 3439 5 3446 5 3449 0 3477 5 3481 5 3491 5 3492 5 3494 0 3501.0 3503.0 3504.5 3505.5 3508.0 3511.0 3513.5 3521.0 3538.5 3542.0 3547.5 3548.5 3552.5 3555.5 3558.5 3561.0 3564.0 3566.0 3567 5 3573 0 3575 0 3588 5 3589 5 3591 5 3594 5 3598 0 3600 5 3651 0 3654 5 3658 5 3678 0 3679 0 3681 5 3682 5 3686 5 3697 5 3713 0 3714 5 3930.5 3921.0 3960.5 EQUIVALENT UNSHIFTED DEPTH 3716 5 3718 5 3720 5 3730 5 3739 5 3741 5 3743 0 3744 5 3746 0 3747 5 3749 0 3753 5 3755 5 3759 5 3781 5 3784 5 3786.0 3789.0 3790.5 3807.0 3810.0 3811.5 3815.5 3817.5 3819.5 3821.0 3822.0 3824.0 3828.5 3832 0 3833 5 3834 0 3842 0 3843 0 3844 5 3845 5 3846.5 3851.0 3853 0 3868 0 3870 0 3871 5 3874 5 3876 5 3903 0 3905 0 3906 0 3907 5 3909 0 3910 0 3911 0 3912 5 3960 5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD 3715 5 3717 0 3718 5 3732 5 3740 5 3742 5 3744 0 3745 5 3748 0 3750 5 3752 0 3756 0 3757 5 3759 5 3782 0 3784 0 3786 5 3789 0 3791 0 3806 5 3811 0 3812.5 3816.0 3816.5 3817.0 3818.0 3821.0 3823.0 3828.5 3831.5 3832.5 3833 5 3842 0 3843 0 3844 5 3846 0 3847 0 3849 5 3852 0 3867 0 3869 5 3872 5 3875 0 3877.5 3903.0 3904.0 3905.5 3906.5 3908.0 3908.5 3909.0 3911.0 3959.0 BIT RUN NO 1 2 5 MERGE TOP 121.0 1469.0 3695.0 MERGE BASE 1469.0 3695.0 3959.0 $ REMARKS: 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 DEPT FT 4 1 ROP MWD FT/H 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 121 3960.5 2040.75 ROP 4.6928 1157.08 189.72 GR 9.86048 131.108 64.1538 RPX 1.9761 887.142 41.8835 RPS 2.2232 1628.58 63.9642 RPM 2.1412 2000 117.464 RPD 2.3044 2000 258.245 FET 0.186 97.3186 1.69071 First Nsam Reading 7680 121 7675 123.5 7601 121 7620 121 7620 121 7620 121 7620 121 7620 121 Last Reading 3960.5 3960.5 3921 3930.5 3930.5 3930.5 3930.5 3930.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 3960.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/27 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 ....... 98/04/27 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 STOP DEPTH FET 121.0 1396.5 RPD 121.0 1396.5 RPM 121.0 1396.5 RP$ 121.0 1396.5 RPX 121.0 1396.5 GR 121.0 1404.0 ROP 122 . 0 1469.5 $ LOG HEADER DATA DATE LOGGED: 08-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 1469.0 TOP LOG INTERVAL (FT): 121.0 BOTTOM LOG INTERVAL (FT): 1469.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .5 MAXIMUM ANGLE: 49.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0967CRG8 EWR4 ELECTROMAG. RESIS. 4 P0967CRG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13.500 DRILLER'S CASING DEPTH (FT): 13.5 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S) : 72.0 MUD PH: 9.1 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3) : 11.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 9.000 MUD AT MAX CIRCULATING TERMPERATURE: 9.930 17.3 Dat MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION 10.000 .000 (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: a 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 DEPT GR RPX RPS RPM RPD ROP FET Service Order Units Size Nsam Rep FT 4 1 68 MWD 1 API 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 OHMM 4 1 68 MWD 1 FT/H 4 1 68 M-WD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 121 1469.5 795.25 2698 GR 9.86048 131.108 60.2835 2567 RPX 1.9761 356.437 66.2392 2552 RPS 2.2649 1628.58 126.553 2552 RPM 2.1412 2000 271.157 2552 RPD 2.3044 2000 616.614 2552 ROP 65.0684 637.171 186.593 2696 FET 0.311 3.5316 1.036 2552 First Reading 121 121 121 121 121 121 122 121 Last Reading 1469.5 1404 1396.5 1396.5 1396.5 1396.5 1469.5 1396.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 1469.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/27 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 ....... 98/04/27 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 STOP DEPTH FET 1397.0 3677.5 RPX 1397.0 3677.5 RPD 1397.5 3677.5 RPM 1397.5 3677.5 RPS 1397.5 3677.5 GR 1406.0 3685.5 ROP 1471.0 3695.5 $ LOG HEADER DATA DATE LOGGED: 10-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 3695.0 TOP LOG INTERVAL (FT): 1469.0 BOTTOM LOG INTERVAL (FT) : 3695.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.1 MAMIMUM ANGLE: 61.4 TOOL STRING {TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAP~IARAY P0967CRG8 EWR4 ELECTROMAG. RESIS. 4 P0967CRG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13.500 DRILLER'S CASING DEPTH (FT) : 13.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD 9.10 72.0 9.1 500 11.2 9.000 8.056 10.000 .000 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHM}4 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 26.1 Name Min Max Mean DEPT 1397 3695.5 2546.25 GR 13.2484 120.282 63.8047 RPX 3.2274 887.142 32.3477 RPS 3.4144 732.218 35.3736 RPM 3.5743 962.523 42.5986 RPD 3.936 2000 84.4675 ROP 4.6928 1157.08 204.45 FET 0.186 15.984 1.29757 Nsam 4598 4560 4562 4561 4561 4561 4450 4562 First Reading 1397 1406 1397 1397.5 1397.5 1397.5 1471 1397 Last Reading 3695.5 3685.5 3677.5 3677.5 3677.5 3677.5 3695.5 3677.5 First Reading For Entire File .......... 1397 Last Reading For Entire File ........... 3695.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 3678.0 3929.0 RPD 3678.0 3929.0 RPM 3678.0 3929.0 RPS 3678.0 3929.0 RPX 3678.0 3929.0 GR 3686.0 3919.5 ROP 3697.0 3959.0 $ LOG HEADER DATA DATE LOGGED: 14-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 3959.6 TOP LOG INTERVAL (FT) : 3695.0 BOTTOM LOG INTERVAL (FT) : 3959.6 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 14.5 MAXIMUM ANGLE: 15.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR EWR4 $ DUAL GAMMA RAY ELECTRONLAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P0967CRG8 P0967CRG8 9.880 9.9 LSND 10.00 98.0 8.0 1600 2.6 3.600 2.400 3.300 3.400 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 RPX MWD 5 OHMM 4 1 68 8 3 RPS MWD 5 OHM~ 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD MWD 5 OHMM 4 1 68 20 6 ROP MWD 5 FT/H 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 41.1 First Name Min Max Mean Nsam Reading DEPT 3678 3959 3818.5 563 3678 GR 57.8788 112.872 88.7162 468 3686 Last Reading 3959 3919.5 RPX 2.0884 14.1493 4.97749 RPS 2.2232 12.9631 5.26185 RPM 2.2712 13.4529 5.18763 RPD 2.4806 12.3644 5.40911 ROP 15.2758 271.08 78.2573 FET 0.4187 97.3196 7.8265 503 3678 3929 503 3678 3929 503 3678 3929 503 3678 3929 525 3697 3959 503 3678 3929 First Reading For Entire File .......... 3678 Last Reading For Entire File ........... 3959 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/04/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUFIBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-202 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 501032025400 REFERENCE NO : 98197 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/05/ 7 ORIGIN : FLIC REEL NAME · 98197 CONTINUATION # : PREVIOUS REEL : COPR4ENT : ARCO ALASKA INC, 2T-202, KUPARUK RIVER, API #50-103-20254-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/05/ 7 ORIGIN : FLIC TAPE NAME : 98197 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 2T-202, KUPARUK RIVER, API #50-103-20254-00 TAPE HEADER KUPARUK RIVER UNIT 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 1 ST STRING 2ND STRING RUN 1 98197 E. BARTZ C. GODDARD 2T-202 501032025400 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 22-APR-98 RUN 2 RUN 3 .......... 1 liN 8E 447 556 122.00 112.00 71.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ................................ 9.875 10.750 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED OPEN HOLE DATA AQUIRED ON ARCO ALASKA'S 2T-202 WELL. THE AIT GAM~A RAY IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O . 5000 FILE SUMPIARY LDWG TOOL CODE START DEPTH DAS 4374.0 FMI 4386.0 AIT 4404.0 CNT 4376.0 SDN 4392.0 DLL 4244.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH .............. 88888.0 4364.5 4353.5 4350.0 4335.5 4333.5 4316.0 4308.0 4307.0 4297.5 4294.0 4290.0 4288.0 STOP DEPTH .......... 3677 0 3677 0 3684 0 3677 0 3677 0 3940 0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... DAS FMI AIT CNT SDN ................................... 88892.0 88888.5 4354.0 4336.0 4317.5 4307.5 4296.5 4290.5 4365.0 4354.5 4336.0 4307.5 4296.5 4290.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 4279 5 4272 5 4263 0 4257 0 4256 0 4252 5 4248 5 4245 5 4234 0 4233.0 4228.5 4225.5 4225.0 4224.0 4219.0 4216.5 4209.5 4205.5 4197.5 4196.5 4192.5 4187.0 4186.5 4182.5 4177.0 4173.5 4166.5 4166.0 4164.5 4164.0 4161.0 4158.0 4156.0 4149.5 4141.0 4140.5 4134.5 4133.5 4124.0 4114.5 4114.0 4111 5 4104 0 4094 0 4090 5 4081 0 4078 5 4075 5 4074.0 4056.5 4036.5 4029.0 4024.5 4018.0 4017.5 4279.0 4271.5 4256.5 4255.5 4249.0 4235.0 4227.5 4226.0 4218.0 4207.0 4198.5 4194.0 4188.5 4182.5 4179.0 4175.5 4168.0 4165.5 4160.5 4152.0 4141.5 4135.5 4115.5 4090.5 4079.5 4078.0 4074.0 4038.5 4026.0 4018.5 4263.0 4256.5 4249.0 4235.0 4230.5 4224.0 4220.0 4211.5 4198.5 4188.0 4168.0 4165.5 4162.5 4156.0 4141.5 4135.5 4125.5 4115.5 4111.0 4106.0 4094.0 4076.0 4057.5 4030.0 4018.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 4009.0 4011.5 4004.5 4004.0 4000.0 4003.0 3993.5 3995.0 3986.5 3989.0 3985.5 3989.0 3977.0 3980.0 3976.0 3977.5 3972.5 3973.0 3970.0 3971.0 3965.5 3966.0 3964.5 3966.0 3958.5 3959.5 3953.5 3954.0 3952.5 3954.0 3946.5 3947.5 3945.5 3947.5 3937.0 3938.0 3937.5 3926.5 3929.0 3929.0 3920.5 3921.0 3918.5 3921.0 3915.5 3917.5 3907.5 3910.0 3903.0 3903.0 3899.0 3899.5 3897.0 3898.5 3888.5 3889.5 3886.0 3887.0 3885.0 3887.0 3875.0 3875.5 3874.5 3875.0 3862.0 3862.0 3853.0 3853.0 3846.0 3846.5 3842.5 3843.0 3839.5 3843.0 3837.0 3838.0 3827.5 3826.5 3824.0 3824.0 3822.0 3822.0 3820.5 3822.0 3820.0 3820.5 3818.0 3817.5 3813.5 3815.0 3801.5 3802.0 3800.0 3802.0 3795.5 3795.5 3788.5 3790.5 3783.0 3784.0 3779.5 3782.0 3779.0 3773.5 3773.5 3772.0 3773.5 3767.0 3768.0 3766.5 3768.0 3758.5 3759.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 3755.5 3759.0 3749.0 3749.0 3744.0 3742.5 3743.0 3738.5 3738.0 3738.0 3734.0 3734.0 3732.0 3729.5 3728.5 3730.5 3725.5 3726.5 3722.0 3715.0 3708.5 3711.0 3705.5 3703.5 3701.0 3704.5 3 698.5 3696.0 3695.0 3697.5 3691 . 0 3692.5 3687.5 3688.5 3687.0 3681.5 3680.5 3679.0 3680.5 3674.0 3676.0 3667.0 3668.5 3663.5 3665.5 3650.0 3654.0 3635.5 3639.0 3633.5 3636.5 3625.5 3627.0 3606.0 3609.0 3598.5 3600.0 3595.5 3597.5 3591 . 5 3594.5 3575.5 3577.0 3560.0 3561.5 3558.0 3560.0 3552.5 3554.0 3540.5 3543.5 3539.0 3540.5 3535.5 3537.0 3525.0 3528.5 3516.5 3518.5 3513.5 3516.0 3512.0 3513.0 3498.0 3498.5 3491 . 5 3493.0 3485.5 3487.5 3476.0 3478.0 3469.0 3469.5 3463.0 3465.0 3460.0 3462.5 3749.0 3743.0 3738.0 3734.0 3730.5 3722.5 3716.0 3707.0 3705.0 3699.5 3697.5 3688.5 3680.5 3679.0 .. r¸ LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 3452.0 3447.0 3444.5 3435.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ R~S: 3453.0 3449.0 3446.0 3437.0 102.0 98.5 RUN NO. PASS NO. ............... ~ERGE TOP FiERGE BASE THIS FILE CONTAINS THE EDITED OPEN HOLE DATA. THE DATA HAS BEEN CLIPPERD OF INVALID COUNTS AT FIRST READING AND AT CASING. THE FMI AND DAS DATA HAVE BEEN SHIFTED TO THE AIT PDC GAM~iA RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 148 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 6 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~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUf4B SAMP ELEM CODE (HEX) DEPT FT 1022724 O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI 1022724 O0 000 O0 0 1 1 1 4 68 0000000000 SP AIT MV 1022724 O0 000 O0 0 1 1 1 4 68 0000000000 · LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CI..~SS MOD ~ S~,IP ELI~I CODE (HEX) TENS AIT LB 1022724 O0 000 O0 0 1 1 1 4 68 TEND AIT LB 1022724 O0 000 O0 0 1 1 1 4 68 FIRES AIT 0HM~1022724 O0 000 O0 0 1 1 1 4 68 MTEMAIT DEGF 1022724 O0 000 O0 0 1 1 1 4 68 DEV AIT DEG 1022724 O0 000 O0 0 1 1 1 4 68 CNTC CNT CPS 1022724 O0 000 O0 0 1 1 1 4 68 CFTC CNT CPS 1022724 O0 000 O0 0 1 1 1 4 68 FCNT CNT CPS 1022724 O0 000 O0 0 1 1 1 4 68 NCNT CNT CPS 1022724 O0 000 O0 0 1 1 1 4 68 CRAT CNT 1022724 O0 000 O0 0 1 1 1 4 68 NRAT CNT 1022724 O0 000 O0 0 1 1 1 4 68 NPHI CNT PU-S 1022724 O0 000 O0 0 1 1 1 4 68 TNPH CNT PU-S 1022724 O0 000 O0 0 1 1 1 4 68 CALl SDN IN 1022724 O0 000 O0 0 1 1 1 4 68 DRHO SDN G/C3 1022724 O0 000 O0 0 1 1 1 4 68 PEF SDN BN/E 1022724 O0 000 O0 0 1 1 1 4 68 RHOB SDN G/C3 1022724 O0 000 O0 0 1 1 1 4 68 MSFL SDN 0H~41022724 O0 000 O0 0 1 1 1 4 68 MINVSDN OH~k4 1022724 O0 000 O0 0 1 1 1 4 68 F~NOR SDN 0H~4~1022724 O0 000 O0 0 1 1 1 4 68 AFiO AIT 0H~1022724 O0 000 O0 0 1 1 i 4 68 AF20 AIT 0H~1022724 O0 000 O0 0 1 1 1 4 68 AF30 AIT OHMM1022724 O0 000 O0 0 1 1 1 4 68 AF60 AIT 0H~41022724 O0 000 O0 0 1 1 1 4 68 AF90 AIT 0H~1022724 O0 000 O0 0 1 1 1 4 68 DTCO DAS US/F 1022724 O0 000 O0 0 1 1 1 4 68 DTSM DAS US/F 1022724 O0 000 O0 0 1 1 1 4 68 RSHC DAS 1022724 O0 000 O0 0 1 1 1 4 68 C24 FMS IN 1022724 O0 000 O0 0 1 1 1 4 68 C13 FMS IN 1022724 O0 000 O0 0 1 1 1 4 68 RB1 FMS DEG 1022724 O0 000 O0 0 1 1 1 4 68 AZ FMS DEG 1022724 O0 000 O0 0 1 1 1 4 68 LLD DLL OH~4~ 1022724 O0 000 O0 0 1 1 1 4 68 LLM DLL 0H~41022724 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. TEND.AIT CNTC. CNT CRA T. CNT CALl. SDN MSFL. SDN AF20.AIT DTCO.DAS Cl3.FMS LLM. DLL 4404 000 -999 250 -999 250 -999 250 -999 250 -999 250 2 835 -999.250 -999.250 -999.250 GR.AIT -999.250 SP.AIT FIRES.AIT -999.250 MTE~.AIT CFTC. CNT -999.250 FCNT. CNT NRAT. CNT -999.250 NPHI.CNT DRHO.SDN -999.250 PEF. SDN MINV. SDN -999.250 AINOR.SDN AF30.AIT 2.995 AF60.AIT DTSM. DAS -999.250 RSHC.DAS RB1.FMS -999.250 AZ.FMS 0 688 -999 250 -999 250 -999 250 -999 250 -999 250 2 954 -999.250 -999.250 TENS. AIT DEV. AIT NCNT. CNT TNPH. CNT RHOB. SDN AFi O .AIT AF90. AIT C24. FMS - LLD.DLL -999.250 -999.250 -999.250 -999.250 -999.250 2.189 2.845 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: DEPT. 3677. 000 GR. AIT TEND. AIT 794 . 388 MRES.AIT CNTC. CNT 1072.301 CFTC. CNT CRAT. CNT 4. 849 NRAT. CNT CALl . SDN 10. 397 DRHO. SDN MSFL.SDN 0.076 MINV. SDN AF20.AIT -999.250 AF30.AIT DTCO. DAS 113. 662 DTSM. DAS C13. FMS 13. 071 RB1. FMS LLM. DLL - 999. 250 46. 536 SP.AIT O. 434 MTE~.AIT 220. 945 FCNT. CNT 5.473 NPHI. CNT 0 . 695 PEF. SDN O. 104 ~INOR. SDN -999. 250 AF60 .AIT 262. 566 RSHC.DAS 57. 244 AZ. FMS 25. 563 TENS. AIT 68.102 DEV. AIT 229. 076 NCNT. CNT 65. 080 TNPH. CNT 10. 000 RHOB. SDN O. 054 AFl O. AIT -999.250 AF90.AIT 1.997 C24.FMS 310. 659 LLD.DLL 2910.000 18.247 938.265 77.709 3.092 -999.250 -999.250 15.862 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~gLRY LDWG TOOL CODE DAS AIT CNT $ BASELINE CURVE FOR SHIFTS: START DEPTH STOP DEPTH 3677.0 52.0 3677.0 3432.0 3677.0 3432.0 GR LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH 88888.0 4350.0 4333.5 4316.0 4307.0 4294.0 4288.0 4279.5 4272.5 4257.0 4252.5 4245 5 4233 0 4225 5 4225 0 4216 5 4205 5 4197 5 4192.5 4186.5 4182.5 4177.0 4173.5 4166.0 4164.0 4158.0 4149.5 4140.5 4133.5 4114.0 4090.5 4081.0 4078.5 4075.5 4036.5 4024.5 4017.5 4009.0 4OOO. 0 3985.5 3976.0 3964.5 3952.5 3945.5 3937.0 3926.5 3920.5 3915.5 3899.0 3897.0 3885.0 DAS 88892. o 4354.0 4336.0 4317.5 4307.5 4296.5 4290.5 4279.0 4271.5 4256.5 4255.5 4249.0 4235.0 4227.5 4226.0 4218.0 4207.0 4198.5 4194.0 4188.5 4182.5 4179.0 4175.5 4168.0 4165.5 4160 5 4152 0 4141 5 4135 5 4115 5 4090 5 4079 5 4078.0 4074.0 4038.5 4026.0 4018.5 4011.5 4003.0 3989.0 3977.5 3966.0 3954.0 3947.5 3938.0 3929.0 3921.0 3917.5 3899.5 3898.5 3887.0 A I T CNT LIS Tape Verification Listing Schlumberger Alaska Computing Center 3874.5 3862.0 3853.0 3839.5 3837.0 3824.0 3820.5 3813.5 3800.0 3788.5 3779 5 3772 0 3766 5 3755 5 3749 0 3742 5 3738 0 3734 0 3728 5 3725.5 3708.5 3701.0 3695.0 3691.0 3687.5 3679.0 3674.0 3 667.0 3663.5 3650.0 3635.5 3633.5 3625.5 3606.0 3598.5 3595.5 3591.5 3575.5 3560.0 3558 0 3552 5 3540 5 3539 0 3535 5 3525 0 3516 5 3513.5 3512.0 3498.0 3491.5 3485.5 3476.0 3469.0 3463.0 3460.0 3875.0 3862.0 3853.0 3843.0 3838.0 3824 0 3822 0 3815 0 3802 0 3790 5 3782 0 3773 5 3768 0 3759.0 3749.0 3743.0 3738.0 3734.0 3730.5 3726.5 3711.0 3704.5 3697.5 3692.5 3688.5 3680.5 3676.0 3668.5 3665.5 3654.0 3639.0 3636.5 3627 0 3609 0 3600 0 3597 5 3594 5 3577 0 3561 5 3560 0 3554 0 3543.5 3540.5 3537.0 3528.5 3518.5 3516.0 3513.0 3498.5 3493.0 3487.5 3478.0 3469.5 3465.0 3462.5 7-MAY-1998 12:21 PAGE 10 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 11 3452.0 3453.0 3447.0 3449.0 3444.5 3446.0 3435.0 3437.0 100.0 102.0 $ REMARKS: THIS FILE CONTAINS THE EDITED CASED HOLE DATA. THE DATA HAS BEEN CLIPPED OF INVALID COUNTS AT CASING AND AT LAST READING. THE DAS CURVES WERE SHIFTED TO THE AIT PDC GAM~A RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUFiB NUFi~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF~ SAMP ELEM CODE (HEX) DEPT FT 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 TENS AIT LB 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 TEND AIT LB 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 MTE~AIT DEGF 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH AIT GAPI 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT CNT CPS 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger A1 aska Compu ting Center 7-MAY-1998 12:21 PAGE: 12 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RCNT CNT CPS 1022724 O0 000 O0 0 2 1 1 4 NRAT CNT 1022724 O0 000 O0 0 2 1 1 4 RTNR CNT 1022724 O0 000 O0 0 2 1 1 4 NPHI CNT PU-S 1022724 O0 000 O0 0 2 1 1 4 NPOR CNT PU-S 1022724 O0 000 O0 0 2 1 1 4 TNPH CNT PU-S 1022724 O0 000 O0 0 2 1 1 4 DTCO DAS US/F 1022724 O0 000 O0 0 2 1 1 4 DTSM DAS US/F 1022724 O0 000 O0 0 2 1 1 4 RSHC DAS 1022724 O0 000 O0 0 2 1 1 4 PR DAS 1022724 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 3677.000 TENS.AIT 2910.000 TEND.AIT 794.388 14TEM. AIT GRCH.AIT 35.969 CNTC. CNT 1072.301 CFTC. CNT 220.945 RCFT. CNT RCNT. CNT 938.265 NRAT. CNT 4.849 RTNR.CNT 5.473 NPHI.CNT NPOR.CNT 82.131 TNPH. CNT 77.709 DTCO.DAS 113.662 DTSM.DAS RSHC.DAS 1.997 PR.DAS 0.385 DEPT. 58.000 TENS.AIT -999.250 TEND.AIT -999.250 MTEM.AIT GRCH.AIT -999.250 CNTC. CNT -999.250 CFTC. CNT -999.250 RCFT. CNT RCNT. CNT -999.250 NRAT. CNT -999.250 RTNR.CNT -999.250 NPHI.CNT NPOR.CNT -999.250 TNPH. CNT -999.250 DTCO.DAS 195.976 DTSM. DAS RSHC.DAS 1.133 PR.DAS -0.568 68.102 229. 076 65. 080 262. 566 -999.250 -999.250 -999.250 237.455 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 13 FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCRE~tENT: 0.5000 FILE SUF~zARY VENDOR TOOL CODE START DEPTH DLL 4250.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 3940.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DLL DUAL LATERLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TE~IPERATURE (DEGF) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL 19-APR-98 8Cl-205 400 19-APR-98 1030 19-APR-98 4423.0 4413.0 3677.0 4400.0 TOOL NUMBER ........... HALS-E 8.000 3940.0 BRINE 10.10 8.5 8.1 115.0 O. 083 63.0 O. 081 63.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 14 TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.5 REMARKS: DEPTH CORRELATED TO PLATFORM EXPRESS OF 21-MAR-1998 RESISTIVITY RE-LOGGED WITH LATERLOG IN BRINE. HALS HIGH RESOLUTION LATERLOG USED. THIS FILE CONTAINS THE PASS #2 LATERLOG DATA AQUIRED AT A 0.5 FT SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022724 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DLL LB 1022724 O0 000 O0 0 3 1 1 4 68 0000000000 SP DLL MV 1022724 O0 000 O0 0 3 1 1 4 68 0000000000 GR DLL GAPI 1022724 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 PAGE: 15 ** DATA ** DEPT. 4418.000 TENS.DLL -999.250 SP.DLL -999.250 GR.DLL -999.250 DEPT. 3677.000 TENS.DLL -999.250 SP.DLL -999.250 GR.DLL -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed byfiles for other main pass tool strings per run. RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 FILE SU~E4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH DLL 4250.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: 3940.0 19-APR-9 8C1-205 400 1 1030 1 LIS Tap~e Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4423.0 4413.0 3677.0 4400.0 TOOL NUM DLL $ DUAL LATERLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : HALS -B 8.000 3940 .0 BRINE 10.10 8.5 8.1 115.0 0.083 0.081 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: DEPTH CORRELATED TO PLATFORM EXPRESS OF 21- RESISTIVITY RE-LOGGED WITH LATERLOG IN BRIN HALS HIGH RESOLUTION LATERLOG USED. THIS FILE CONTAINS THE PASS #2 LATERLOG DAT AT A 0.1667 FT SAMPLE RATE. $ LIS FORMAT DATA LIS TaPe Verification Listing '~ Schlumberger Alaska Computing Center 7-MAY-1998 12:21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NLIMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP DEPT FT 1022724 00 000 00 0 4 1 HLLD DLL OHMM 1022724 00 000 00 0 4 1 HLLS DLL OHMM 1022724 00 000 00 0 4 1 HRLD DLL OHMM 1022724 00 000 00 0 4 1 HRLS DLL OHMM 1022724 00 000 00 0 4 1 RXOZ DLL OHMM 1022724 00 000 00 0 4 1 ** DATA ** DEPT. 4418.000 HLLD.DLL -999.250 HRLS.DLL -999.250 RXOZ.DLL -999.250 HLLS.DLL ** END OF DATA ** LIS Tape Verification Listing '~ Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool strin Sadlerochit run presented first (primary depth control interval) followed by files for other main pass tool s RUN NUMBER: 2 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0883 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DLL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4250.0 3940.0 19-APR-9 8C1-205 400 1 1030 1 4423.0 4413.0 3677.0 4400.0 TOOL NUM DLL $ DUAL LATERLOG HALS -B LIS Tape Verification Listing '~ Schlumberger Alaska Computing Center 7-MAY-1998 12:21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.000 3940.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : BRINE 10.10 8.5 8.1 115.0 0.083 0.081 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: DEPTH CORRELATED TO PLATFORM EXPRESS OF 21- RESISTIVITY RE-LOGGED WITH LATERLOG IN BRIN HALS HIGH RESOLUTION LATERLOG USED. 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CHAN ** NAME SERV 1/NIT SERVICE API API API API FILE NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP DEPT FT 1022724 00 000 00 0 6 1 GR AIT GAPI 1022724 00 000 00 0 6 1 SP AIT MV 1022724 00 000 00 0 6 1 TENS AIT LB 1022724 00 000 00 0 6 1 HTEN AIT LB 1022724 00 000 00 0 6 1 MRES AIT OHMM 1022724 00 000 00 0 6 1 MTEM AIT DEGF 1022724 00 000 00 0 6 1 GDEV AIT DEG 1022724 00 000 00 0 6 1 CNTC PEX CPS 1022724 00 000 00 0 6 1 CFTC PEX CPS 1022724 00 000 00 0 6 1 RCFT PEX CPS 1022724 00 000 00 0 6 1 RCNT PEX CPS 1022724 00 000 00 0 6 1 TNRA PEX 1022724 00 000 00 0 6 1 RTNR PEX 1022724 00 000 00 0 6 1 TNPH PEX PU 1022724 00 000 00 0 6 1 NPHI PEX PU 1022724 00 000 00 0 6 1 NPOR PEX PU 1022724 00 000 00 0 6 1 DTCO DSI US/F 1022724 00 000 00 0 6 1 DTSM DSI US/F 1022724 00 000 00 0 6 1 RSHC DSI 1022724 00 000 00 0 6 1 PR DSI 1022724 00 000 00 0 6 1 GR DSI GAPI 1022724 00 000 00 0 6 1 GR FMI GAPI 1022724 00 000 00 0 6 1 ** DATA ** DEPT. 4418.000 GR.AIT -999.250 SP.AIT HTEN.AIT 88.537 MRES.AIT 0.512 MTEM.AIT CNTC.PEX 2084.371 CFTC.PEX 584.439 RCFT.PEX TNRA.PEX 3.621 RTNR.PEX 3.796 TNPH.PEX NPOR.PEX 42.267 DTCO.DSI -999.250 DTSM.DSI PR.DSI -999.250 GR.DSI 71.450 GR.FMI ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tap--~ Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool strin Sadlerochit run presented first (primary depth control interval) followed by files for other main pass tool s RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH AIT $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4418.0 3677.0 21-MAR-9 8B1-129 1430 2 800 2 4423.0 4413.0 6.0 4418.0 TOOL NUM GR AIT CNL LDT DSI FMI $ GAMMA RAY ARRAY INDUCT ION COMPENSATED NEUTRON DENS I TY DUAL SONIC INDUCTION FORMATION MICRO IMAGER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : HGR AIT-H HGNS HRDD DSST FMI 9.875 3672.0 £,~ S9 6 SE'O 89 8 59 L £L 9 99 S I 99 P 8E £L C 0 99 ~ 0 99 I : (MI) MMOQN-~LS qO0i ~i-~PqMMHI : (MI) NOILDZMMOD Z%OH :XLISNZ~ XIMLk~4 :XIM£¥M : (%tfMMZHL MO ~VNMZHLIdZ) ZdXL %O0~ ~00~ MO~nZN 00~'I 8c~£'0 ~SP'O O'OEI S'8 0 '69 OS'OI TE:EI 866T-X~UN-£ m~qu~o 6uTqndmoo ~Ms~I~ .... 6UTqST% uoTq~OT~T~SA ~d~i : Z~I~ LS~ O~ : Z~XL Z~I~ ~EOI : ZZIS DZ~ XIu~ £ /~0/86 : ~iv~ IODI00 : NOISHZA OI~ : ZDIA~ZS £00' LIGZ : Zk~fN Z%I~ £88'~ £IV'06~ ~S6'E £I~'09~ 6££'~ iI~'0I~ 000'8I~ I £ 0 00 000 00 f5£~0I MI iI~ G~I~ I £ 0 00 000 00 ~£~0I MMHO iI~ 06~ I L 0 00 000 00 ~L~0I ~MHO iI~ 09~ I L 0 00 000 00 ~EL~0I MMHO iI~ 0£~ I L 0 O0 000 O0 ~L~0I MMHO LI~ 0~ I L 0 00 000 00 ~L~0I MMHO LI~ 0I~ I L 0 00 000 00 ~L~0I L~ L~Z~ dk~fS ~Mi1N GOM $S~qO ZdXL DOq # HZGHO GI ~Mfl~ Z%I~ Id~ Id~ IdV I~ ZDIAHZS LIN/I AHZ$ ZMIfM I 99 0 I 99 9I 99 99 0 99 89 9£ 99 II I~:EI 866I-XtfM-£ ~sqU~D BuTqndmoD m~seI~ zsBx~qmnIqoS 0 ' E:L9£ SL8'6 H-~I~ : (i~) HL~ZG DNIS~D S~ZDDO% : (i~) HLdZQ ©NIS~D S~Z%%I~G : (NI) ZZIS £I~ Z%OH NZdO ~i~ DNIS~D ~R-~ Z~OHZ~O~ IN,4 ISG ~D MflN ~OOL 0'8I~ 0'9 0'£I~ 0'£~ 008 0£~I 6EI-I~8 6-~-IE ZdXL ~OOL ZGOD ~OOL HOGNZA (MOLL08 OL dOL) ©NIHLS qOOL : (~Hd~) ~ZZdS DNID©O7 : (i~) ~fA~ZLNI ©0~ MOLLO~ : (i~) EZDDO~ ~i : (i~) ~Z~I~ Ji :MOLLO~ NO ~Z©DO~ ZNIL :~Z~NZ NOIL~DD~ID ZMIL :NOI$~ZA :~ZDDO~ 0'L£9C 0'8I~ XZc~ : ZqI~ Oq : ZdXL ZqId ~0I : ZZIS DZ~ ~ L /S0/S6 : IODI00 : NOISHZA DIq~ : ZDIA~ZS 800' LIGZ : ZkKfN Z~I~ IE:EI 866I-XlfM-t LIS Tape" Verification Listing "~P~- Schlumberger Alaska Computing Center 7-MAY-1998 12:21 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPER3kTURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 10.50 69.0 8.5 3.5 120.0 0.484 0.358 1.200 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: THREE 1.5" STANDOFFS RUN ON INDUCTION TOOL. 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Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool strin Sadlerochit run presented first (primary depth control interval) followed by files for other main pass tool s RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1250 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FMI $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4414.0 3677.0 21-MAR- 9 8B1-129 1430 2 800 2 4423.0 4413.0 6.0 4418.0 TOOL NUM GR AIT GAMMA RAY ARRAY INDUCTION HGR AIT-H : (MI) ,~,~O(IN-~LS ~IOOJ, NOLSQN-~S :(MI) NOILDZ~OD ~OH :XLISMZ~ XI~i~qN :XI~L~M ~ZHLIdZ) ZdAi TOOL TOOL MO~L~ZN 00~'I 8S£'0 ~8~'0 0'0EI S'C 0'69 0S'0I 0 ' ~:/.9 C S/.8' 6 : (IL) HLdZ~ ONIS~O : (IL) HLdZQ ©MIS~D : (MI) ZZIS iI~ Z~OH NZ~O ~i~ ©NIS~D ~N%f Z~OHZ~O~ SN©H HZ©¥~qI OHDIM MOILDflGMI DIMOS XLISNZG MO~LQZN QZL~SNZdMOO ~INO IE:~I 866I-X~-£ ..... _,, 6UTqSTE uoTqeOT~T~A.~d~i SIT I~'£lO I~'£lO SEb'SI INZ'IAZG SE9'0I£ IN~'IZYH £LI'£I INZ'bEO SEI'LLg£ 'ZdZG AAA'El I~'IA~Q 000'0I£ I~'IZIfH I 6 0 00 000 00 bEAEEOI ©~ I~ IA~G I 6 0 00 000 00 bEAEEOI ©ZG I~ IZtfH I 6 0 00 000 00 bELEEOI ©~ I~ ~H I 6 0 00 000 00 bEAEEOI MI I~ ElD I 6 0 00 000 00 bELEEOI MI I~ bED I 6 0 00 000 00 bEAEEOT ~Z ~d~G E~flM Z~I~ Id~ Id~ Id~ Id~ ZDIAEZS LINfl A~ZS ZMVN ~ NIfHO - Z~XL £ZS ~ I 99 0 I 99 9I 89 99 SI 0 99 £I 89 S'0 89 8 S9 A £t 9 99 I 99 0 99 0 99 I ~ GHODZH NOILVDIZIDZdS L~HO~ ~G ~ TE: ET 866I I X[ - t ~quao 6uTqndmoD e~seIY xsB~sqmnIqmS ...... 6uTqsT% UOTqeOT~TXSA.~eL SI% LIS Tape~ Verification Listing ~-' Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool strin Sadlerochit run presented first (primary depth control interval) followed by files for other main pass tool s RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEX $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4418.0 3677.0 21-MAR- 9 8B1-129 1430 2 800 2 4423.0 4413.0 6.0 4418.0 TOOL NUM GR AIT GAMMA RAY ARRAY INDUCTION HGR AIT-H LIS Ta'pre' Verification Listing '~ .... Schlumberger Alaska Computing Center 7-MAY-1998 12:21 CNL LDT DSI FMI COMPENSATED NEUTRON DENSITY DUAL SONIC INDUCTION FORMATION MICRO IMAGER HGNS HRDD DSST FMI BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9.875 3672.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPER3tTURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 10.50 69.0 8.5 3.5 120.0 0.484 0.358 1.200 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: THREE 1.5" STANDOFFS RUN ON INDUCTION TOOL. BOWSPRING RUN ON NEUTRON TOOL. 4' OF STRETCH ADDED TO DEPTH GAMMA RAY DOES NOT REPEAT AT BOTTOM OF HOLE ACTIVATION OF FORMATION BY NEUTRON SOURCE SANDSTONE MATRIX, MDEN = 2.65 G/CC USED FOR POROSITY COMPUTATIONS. 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Schlumberger Alaska Computing Center 7-MAY-1998 12:21 MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 10.50 69.0 8.5 3.5 120.0 0 .A8A 0.358 1.200 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN) : 1.5 REMARKS: THREE 1.5" STANDOFFS RUN ON INDUCTION TOOL. BOWSPRING RUN ON NEUTRON TOOL. 4' OF STRETCH ADDED TO DEPTH GAMMA RAY DOES NOT REPEAT AT BOTTOM OF HOLE ACTIVATION OF FORMATION BY NEUTRON SOURCE SANDSTONE MATRIX, MDEN = 2.65 G/CC USED FOR POROSITY COMPUTATIONS. THIS FILE CONTAINS THE OPEN HOLE REPEAT PAS AQUIRED AT 0.25' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 : Z~I~ LS~ O~ : ZdXi Z~I~ ~0I : ZZIS DZ~ Xk~M £ /so/~6 : ~ IODI00 : NOIS~ZA DI~ : ZDIA~ZS SI0' LI~Z : ZkKfN Z~I~ LI~'G~I~ sLg'80E ~I~'06~ I£8'66I iI~'09~ iI~'0g~ £SL'6gI iI~'0I~ 000'~£0~ 'LdZG £L8'~ LI~'06~ LA6'[ LI~'09~V S9E'E iI~'0I~ 000'LI~ 'LdZG EI 0 00 000 00 f~L~EOI NI iI~ G~I~ ~I 0 00 000 00 fEL~0I MMHO ~I~ 06~ ~I 0 00 000 00 ~L~0I NNHO ~I~ 09~ ~I 0 00 000 00 ~EL~EOI NNHO iI~ 0£~ SI 0 00 000 00 ~L~0I R~NHO iI~ 0~ SI 0 00 000 00 ~ELESOI NNHO £I~ 0I~ fit 0 00 000 00 ~£~0I LZ idZ~ SW/1N Z~I~ I~ Id~ Id~ Id~ ZDIA~ZS iINfl A~ZS ZkSfN I 99 0 I 99 9I 89 99 SI ZD%~fA ZQOD ~dZ~ Z~XL IS:~I 866I-Xk~q-/. ~quso 5uTqndmoD e~seI~ zsS~qmnIqoS 5UTqST~ UOTqeOT~T~SA ~d~i .~oI~ Lis' Tape~ Verification Listing Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** FILE HEADER **** FILE NAME : EDIT .016 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 16 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH AlT PEX $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4418.0 4102.0 4418.0 4102.0 21-MAR- 9 8B1-129 1430 2 800 2 4423.0 4413.0 6.0 4418.0 TOOL NUM GR AIT CNL LDT $ GAMMA RAY ARRAY INDUCTION COMPENSATED NEUTRON DENS I TY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: HGR AIT-H HGNS HRDD 9.875 3672.0 LIoP'~ Tape Verification Listing ..... Schlumberger Alaska Computing Center 7-MAY-1998 12:21 MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) : MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT) : MUD FILTRATE AT (BHT) : MUD CAKE AT (MT) : MUD CAKE AT (BHT) : 10.50 69.0 8.5 3.5 120.0 0.484 0.358 1.200 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: THREE 1.5" STANDOFFS RUN ON INDUCTION TOOL. BOWSPRING RUN ON NEUTRON TOOL. 4' OF STRETCH ADDED TO DEPTH GAMMA RAY DOES NOT REPEAT AT BOTTOM OF HOLE ACTIVATION OF FORMATION BY NEUTRON SOURCE SANDSTONE MATRIX, MDEN = 2.65 G/CC USED FOR POROSITY COMPUTATIONS. THIS FILE CONTAINS THE OPEN HOLE REPEAT PAS AQUIRED AT 0.1667' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 LIS' Ta~ Verification Listing ~ Schlumberger Alaska Computing Center 7-MAY-1998 12:21 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 NAME ** SET TYPE - CHAN ** SERV UNIT SERVICE API API API API FILE NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP DEPT FT 1022724 00 000 00 0 16 1 RHOZ PEX G/C3 1022724 00 000 00 0 16 1 HDRA PEX G/C3 1022724 00 000 00 0 16 1 PEFZ PEX BN/E 1022724 00 000 00 0 16 1 DPHZ PEX PU 1022724 00 000 00 0 16 1 HMIN PEX OHMM 1022724 00 000 00 0 16 1 HMNO PEX OHMM 1022724 00 000 00 0 16 1 RXOZ PEX OHMM 1022724 00 000 00 0 16 1 RXO8 PEX OHMM 1022724 00 000 00 0 16 1 HCNT PEX CPS 1022724 00 000 00 0 16 1 HCFT PEX CPS 1022724 00 000 00 0 16 1 HGR PEX GAPI 1022724 00 000 00 0 16 1 RHFT PEX CPS 1022724 00 000 00 0 16 1 RHNT PEX CPS 1022724 00 000 00 0 16 1 DPHZ PEX PU 1022724 00 000 00 0 16 1 HTNP PEX PU 1022724 00 000 00 0 16 1 HNPO PEX PU 1022724 00 000 00 0 16 1 ** DATA ** DEPT. 4417.000 RHOZ.PEX -999.250 DPHZ.PEX 60721.211 HMIN.PEX 1.804 RXO8.PEX 1.928 HCNT.PEX 1895.508 RHFT.PEX 487.876 RHNT.PEX 1779.002 HNPO.PEX 41.754 DEPT. 4050.000 RHOZ.PEX 2.347 DPHZ.PEX 18.365 HMIN.PEX 3.655 RXO8.PEX 63.559 HCNT.PEX 3158.452 RHFT.PEX 1220.274 RHNT.PEX 2623.915 HNPO.PEX 26.976 HDRA.PEX HMNO.PEX HCFT.PEX DPHZ.PEX HDRA.PEX HMNO.PEX HCFT.PEX DPHZ.PEX ** END OF DATA ** ~N©H H-~I~ E©H NO~,T,fl,~N ~,~,T,%fSN,~0D NOI,T,DflGNI Alf~lf ~INO MD_N qO0£ 0'Sl~ 0'9 0 ' £I~ 0' 008 0£~I 6EI-I~8 ZdXi ~OOi Z~OD ~OOL ~O~NZA (MOLLOS Oi ~Oi) ©NI~LS ~OOi : (MHdM) GZZdS DNIDDO% :(LM) ~-~fAHZiMI DO% MOi£O8 :(L~)~ZDDO% GL : (i~) ~Z%%IH~ GL :MOLLO~ NO HZ©©0% ZMIL :GZ~NZ NOIL~%DD~ID ZMIL :NOISHZA ZH~fML~OS 0'EOI~ 0'8I~ 0'EOI~ 0'8I~ ~fitffI HZ(I%fZH ©O~I X,qd HLdZG dOLS HLdZ~ LR-~fLS ZGOD %00L HO~NZA ££80'0 ~ :~Z~MflN 'bUT~qS IOOq 'ssed qom~ ~o~ mqep ~pe~q 5oi pue s~A~no ~~H ~I~ O% : ZEAL Z%I~ ~EOI : ZZIS DZH ~ L /S0/86 : ~LVG I0OI00 : NOISHZA DI~ : ZDIA~ZS £I0' LI~Z : ZMtfN Z~I~ 07 : ZdXi Z~I~ ~g0I : ZZIS DZH Xk~ L /S0/86 : IODI00 : NOISHZA DI~ : ZDIAHZS 910' LIGZ : ZknfN ZqI~ IE:EI 866T-X~f~q-£ ~qu~o 6uTqndmoo ~s~IV xsb~qmnIqsS LIS Tap-~ Verification Listing ~ ' Schlumberger Alaska Computing Center 7-MAY-1998 12:21 LDT DENS I TY $ HRDD BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9.875 3672.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 10.50 69.0 8.5 3.5 120.0 0.484 0.358 1.200 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: THREE 1.5" STANDOFFS RUN ON INDUCTION TOOL. BOWSPRING RUN ON NEUTRON TOOL. 4' OF STRETCH ADDED TO DEPTH GAMMA RAY DOES NOT REPEAT AT BOTTOM OF HOLE ACTIVATION OF FORMATION BY NEUTRON SOURCE SANDSTONE MATRIX, MDEN = 2.65 G/CC USED FOR POROSITY COMPUTATIONS. THIS FILE CONTAINS THE OPEN HOLE REPEAT PAS AQUIRED AT 0.0833' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tap--~ Verification Listing ~' Schlumberger Alaska Computing Center 7-MAY-1998 12:21 TYPE REPR CODE VALUE 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP DEPT FT 1022724 00 000 00 0 17 1 HCAL PEX IN 1022724 00 000 00 0 17 1 ** DATA ** DEPT. 4417.000 HCAL.PEX 4.140 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .017 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Ta~ Verification Listing ~' ~' Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** FILE HEADER **** FILE NAME : EDIT .018 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 18 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEX CNT DSI $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 3677.0 3430.0 3677.0 3430.0 3677.0 6.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 21-MAR-9 8B1-129 1430 2 800 2 4423.0 4413.0 6.0 4418.0 TOOL NUM GR AIT CNL LDT DSI FMI GAMMA RAY ARRAY INDUCTION COMPENSATED NEUTRON DENSITY DUAL SONIC INDUCTION FORMATION MICRO IMAGER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS HGR AIT-H HGNS HRDD DSST FMI 9.875 3677.0 3672.0 0 99 89 EI 99 ,T,,4 S9 6 S'O 89 8 59 t CA 9 99 I 99 ~8 CA 0 99 0 99 ~ ~ODZ~ NOIi~OI~IOZdS L~OJ ~L~ ~ : (NI) ~JOGN-~LS ~00~ S9'~ NOLS~N-~S ~ZHL : (NI) NOILDZ~OD Z~OH :XLISNZ~ XI~i~q :XI~L~ :(~I~U~ZHL gO ~ZH£IdZ) ZdXi ~OOi ~OOL No~£naN 00~'I 8c5£'0 ~8~'0 0'0EI ~'£ ~'8 0'69 0S'0I I~:SI 866I-X~f~q-£ ~squ~O BuTqndmoD ~seIW ~6z~qmnIqoS .... 5UTqST~ UOTq~OT~T~aA ~i SI~ LIS Tape Verification Listing ~_/ Schlumberger Alaska Computing Center 7-MAY-1998 12:21 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 NAME ** SET TYPE - CHAN ** SERV UNIT SERVICE API API API API FILE NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP DEPT TENS HTEN MRES MTEM GDEV GRCH CNTC CFTC RCFT RCNT CRAT NRAT NPHI NPOR TNPH DTCO DTSM GR RSHC PR FT 1022724 00 000 00 0 18 1 AIT LB 1022724 00 000 00 0 18 1 AIT LB 1022724 00 000 00 0 18 1 AIT OHMM 1022724 00 000 00 0 18 1 AIT DEGF 1022724 00 000 00 0 18 1 AIT DEG 1022724 00 000 00 0 18 1 AIT GAPI 1022724 00 000 00 0 18 1 PEX CPS 1022724 00 000 00 0 18 1 PEX CPS 1022724 00 000 00 0 18 1 PEX CPS 1022724 00 000 00 0 18 1 PEX CPS 1022724 00 000 00 0 18 1 PEX 1022724 00 000 00 0 18 1 PEX 1022724 00 000 00 0 18 1 PEX PU-S 1022724 00 000 00 0 18 1 PEX PU-S 1022724 00 000 00 0 18 1 PEX PU-S 1022724 00 000 00 0 18 1 DSI US/F 1022724 00 000 00 0 18 1 DSI US/F 1022724 00 000 00 0 18 1 DSI GAPI 1022724 00 000 00 0 18 1 DSI 1022724 00 000 00 0 18 1 RCM 1022724 00 000 00 0 18 1 ** DATA DEPT. MTEM.AIT CFTC.PEX NRAT.PEX DTCO.DSI PR.RCM DEPT. MTEM.AIT CFTC.PEX NRAT.PEX DTCO.DSI PR.RCM 3677.000 68.102 220.945 5.473 139.517 0.333 6.000 -999.250 -999.250 -999.250 52.812 0.475 TENS.AIT GDEV.AIT RCFT.PEX NPHI.PEX DTSM.DSI TENS.AIT GDEV.AIT RCFT.PEX NPHI.PEX DTSM.DSI 2910.000 15.811 229.076 65.080 278.662 -999.250 -999.250 -999.250 -999.250 241.204 HTEN.AIT GRCH.AIT RCNT.PEX NPOR.PEX GR.DSI HTEN.AIT GRCH.AIT RCNT.PEX NPOR.PEX GR.DSI ~ ~OO& 0 ' 8T~'~' 0'9 0 ' O' 008 O£~l 6UT-T~8 ~aXZ 200£ aQOD 200Z EO~N~A (NOZZO~ OZ aOZ) DNZEZS 200Z :(L~) ~f~fA~ZLMI DO~ MOLLO~ :(L~) ~I-~fA~L~I ©0~ dOL : (L~)~ZDDO~ GL : (L~) ~Z~I~Q QL :MOLLO~ ~0 ~ZDD07 ZMIL :~ZQ~Z NOIL~DD~ID ZMIL 0'0£9£ 0'LLg£ ~f,T,~f~ ~Z(ZfZH : Z~I~ LS~ O~ : ZdXL Z~I~ ~0I : ZZIS DZ~ ~ £ /so/~6 : ~ IODI00 : ~OIS~ZA OI~ : ZDIA~Zg 610' LI~Z : Zk~fM Z~I~ O~ : Z~XL Z~I~ ~EOI : ZZIS DZH ~ L /SO/S6 : ~v~ TODI00 : ~OIS~ZA DI~ : ZOIAHZS 810' ~I~Z : ZM~fM Z~I~ I~:~I 866I-2L~-L ~equeD 6uTqndmoo e~seI~ : (NI) ,~,~OJN-~LS TOO J, MOLS~N-tfS ~k~q~ZHL : (MI) NOILDZ~OD Z~OH :XLISNZ~ XI~Lk~M :XI~LYM :(TYM~ZHL gO ~k~4~ZHLIdZ) ZEAL TOOL TOOL NO~L~ZN O0~'I 85£'0 ~8~'0 0'0ET S'C 5'8 0'69 0S'0I 0'~L9E 0'LL9E SL8'6 : (Id) HLdZJ ©MIS~D S~Z©©OT : (MI) ZZIS LIS ZTOH NZdO ~L~G ©NIS~D GN~f ZTOHZ~OS IN~ SN©H H-LI~ HZ©¥NI O%{DIN NOILYk~O,~ NOILDflGMI OLMOS q~fflG AL I SNZG NOILDfl~MI X~f Ihld ISG ~IND IE:EI 866I-X%f~-t za~uao 5uT~ndmoo e~seIV ~5xeqmnIqoS .... _ 5UT~STT UOT~eST~T~aA ~_4ei SIq LIS Tap-e Verification Listing -~- Schlumberger Alaska Computing Center 7-MAY-1998 12:21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP DEPT FT 1022724 00 000 00 0 19 1 HCNT PEX CPS 1022724 00 000 00 0 19 1 HCFT PEX CPS 1022724 00 000 00 0 19 1 HGR PEX GAPI 1022724 00 000 00 0 19 1 RHFT PEX CPS 1022724 00 000 00 0 19 1 RHNT PEX CPS 1022724 00 000 00 0 19 1 DPHZ PEX PU 1022724 00 000 00 0 19 1 HTNP PEX PU 1022724 00 000 00 0 19 1 HNPO PEX PU 1022724 00 000 00 0 19 1 ** DATA ** DEPT. 3677.000 HCNT.PEX 1068.713 RHFT.PEX 214.442 RHNT.PEX 917.549 HNPO.PEX 84.671 DEPT. 3430.000 HCNT.PEX 1244.211 RHFT.PEX 261.744 RHNT.PEX 1181.326 HNPO.PEX 46.726 HCFT.PEX DPHZ.PEX HCFT.PEX DPHZ.PEX ** END OF DATA ** LIS Ta'~e Verification Listing .... Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** FILE TRAILER **** FILE NAME : EDIT .019 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .020 SERVICE : FLIC VERSION : 00lC01 DATE : 98/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 20 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into PASS NUMBER: 1 DEPTH INCREMENT: 0.0883 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEX $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER(FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 3677.0 3430.0 21-MAR- 9 8B1-129 1430 2 800 2 4423.0 4413.0 6.0 4418.0 TOOL NUM GR AIT CNL LDT DSI FMI GAMMA RAY ARRAY INDUCTION COMPENSATED NEUTRON DENS I TY DUAL SONIC INDUCTION FORMATION MICRO IMAGER HGR AIT-H HGNS HRDD DSST FMI LIS Tap~e' Verification Listing ~- Schlumberger Alaska Computing Center 7-MAY-1998 12:21 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9.875 3677.0 3672.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : 10.50 69.0 8.5 3.5 120.0 0.484 0.358 1.200 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTON 2.65 TOOL STANDOFF (IN): 1.5 REMARKS: THREE 1.5" STANDOFFS RUN ON INDUCTION TOOL. BOWSPRING RUN ON NEUTRON TOOL. 4' OF STRETCH ADDED TO DEPTH GAMMA RAY DOES NOT REPEAT AT BOTTOM OF HOLE ACTIVATION OF FORMATION BY NEUTRON SOURCE SANDSTONE MATRIX, MDEN = 2.65 G/CC USED FOR POROSITY COMPUTATIONS. THIS FILE CONTAINS PASS #1 IN CASING AT 0.0 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 : Z%IS O% : ZdXi ZqI~ ~g0I : ZZIS DZH L /S0/86 : IODI00 : NOIS~ZA DI~ : ZDIA~ZS 0~0' LI~Z : ZMtfM ZqI~ L6£'0I XZd'%~DH 000'LLg£ 'LdZ~ I OE 0 O0 000 O0 ~E£~EOI NI XZd %~DH I OE 0 O0 000 O0 9ELEEOI i~ IdZ~ dMtfS ~MflM GO~ SS~%D ZdXi ©0% # ~Z~O ~I SMflN Z%I~ Id~ Id~ Id~ Id~ ZDIA~ZS LIN/1 A~ZS ZMtfN ~ NYHD - ZdXL LZS ~ I 99 0 I 99 9I 89 99 SI i~ 99 PI 0 99 £I 89 8~I 99 II I~ §9 6 580'0 89 8 S9 £ ££ 9 99 ~qu~o BuTqndmoo e~s~IV ~B~qmnIqsS LIS Ta~=~ Verification Listing .... " Schlumberger Alaska Computing Center 7-MAY-1998 12:21 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/05/ 7 ORIGIN : FLIC REEL NAME : 98197 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 2T-202, KUPARUK RIVER,