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Home My WebLink About198-052WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Static Bottom Hole Pressure Record: 3G -21A Run Date: 8/13/2019 1�JSG�� 3 123 6 September 20, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 3G -21A Digital Data in LAS format, Digital Log Image file RECEIVED 1 CD Rom 50-103-20148-01 SEP 2 4 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: QLV-1�7 Signed: XHVZE Pages NOT Scanned in this Well History File 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. /~'~'-' O ~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: /~ Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other Complete COMMENTS: Scanned by: Beverly Mildred Daretha~owell TO RE-SCAN Notes' Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ • • WELL LOG TRANSMITTAL LoIt /o sD M K BENDER To: Alaska Oil and Gas Conservation Comm. October 15, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 • ' Z Anchorage,Alaska 99501 swam RE: Multi Finger Caliper(MFC): 3G-21A DEC . X113 Run Date: 10/12/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook,Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook @halliburton.corn 3G-21A Digital Data(LAS),Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20148-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: Signed: STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMIS.] REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate J7 Other r Alter Casing r Rill Tubing r Perforate New Pool f" Waiver r Time Extension r Change Approved Program r' 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 IV Exploratory r _ ■ 198 - 052 3. Address: 6 . API Number: Stratigraphic r Service r° P. O. Box 100360, Anchorage, Alaska 99510 — 50 - 103 20148 - 01'° QQ 7. Property Designation (Lease Number): 8. Well Name and Number: . ADL 25548 s 3G - 21A 9. Field /Pool(s): ,. Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 12960 feet Plugs (measured) None true vertical 5983 feet Junk (measured) 12400 Effective Depth measured 12863 feet Packer (measured) 9704 true vertical 5959 feet (true vertucal) 5192 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 3974 9.625 4009 2979 PRODUCTION 11643 7 11678 5715 LINER 3259 3.5 12960 5983 RFCFIVFD Perforation depth: Measured depth: 12352' 12392', 12482' 12522' True Vertical Depth: 5834'- 5841', 5857' -5867' JAN 0 4 2017 Alaska iiii & Gas Cons, Commission Tubing (size, grade, MD, and TVD) 3.5, L -80, 9734 MD, 5205 TVD >'iret^orote Packers & SSSV (type, MD, and TVD) PACKER =BAKER C -2 ZXP LINER TOP PACKER @ 9704 MD and 5192 TVD SSSV =CAMCO DS LANDING NIPPLE NO GO @ 514 MD and 514 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 12352'- 12392; 12482' - 12522' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 181 832 200 -- 182 Subsequent to operation 826 699 549 -- 195 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p' f Service r Stratigraphic r 15. Well Status after work: 0i1.17 Gas r WDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ r WAG r" GINJ r SUSP '""' SPLUG 1 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: none Contact John Peirce ( 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date A 1 h RBDNIS JAN 0 4 2012 1 _ % 74" 7-* /2---- Form 10 -404 Revised 10/2010 Submit Original Only ,A I/4/ 3G -21A Well Work Summary DATE SUMMARY - 10/2/11 RUN CALIPER LOG FROM 12,4 .0 7,480', FREEZE PROTECT TO 3000' DATA GATHERED FROM CALIPER LOG. JOB IN PROGRESS. 10/8/11 BRUSH N FLUSH TBG WITH 50 BBL DSL. SET 2.75" CA -2 PLUG @ 9701' RKB. IN PROGRESS. 10/9/11 PULLED GLVs @ 3157' AND 8520' RKB, REPLACED WITH DVs. CONFIRMED SET. ATTEMPTED PULL OV @ 9687' RKB. IN PROGRESS. 10/10/11 PULLED OV @ 9687' RKB. LOADED WELL WITH 290 BBL INHIB SW, 70 BBL DSL; JUMPERED & U TUBED. SET DV © 9687' RKB. MIT TBG 4500 PSI, PASSED. MIT IA 3000 PSI, PASSED. PULLED CATCHER © 9701' RKB. IN PROGRESS. 10/11/11 PULLED 2.75" CA -2 PLUG @ 9701' RKB. READY FOR HPBD. 11/13/11 Pumped Kuparuk A -Sand refrac designed for seven main stages, 2 -10 ppa 16/20 Carbolite, and 25# crosslink gel at 20 -bpm. Screened out 2 -bbl into the 8 -ppa stage with 7 -ppa sand in tubing and at perfs. Pumped total of 70,350# proppant with estimated 46,435# behind pipe (29% design). The prop fracture treatment was preceded by a breakdown, scour stages, and data -frac using 25# linear and crosslink gel. 11/19/11 PERFORMED FCO TO 12,500' CTMD PUMPING GEL SWEEPS. POOH SLOWING DOWN ACROSS GLM'S HEAVY FRAC SAND IN RETURNS. FREEZE PROTECTED TBG TO 2500' TVD. JOB COMPLETE. 12/16/11 TAG CARBOLITE @ 3260' SLM, BRUSH & FLUSH CARBOLITE f/ 3260' SLM TO 10,500' SLM, IN PROGRESS. 12/17/11 RAN BRUSH TO 9500' SLM, ALTENATOR ON POWER PACK BROKE, IN PROGRESS. 12/18/11 BRUSH & FLUSH f/10,510' TO 12068' SLM, STALL OUT DUE TO DEV., SET CATCHER @ 9701' RKB, PULLED DV @ 9686' RKB, IN PROGRESS. 12/19/11 BRUSH AND FLUCH STA # 4@ 9686' RKB, SET OV © 9686' RKB, PULLED DVs @ 8520, 6445', 3161' RKB, ATTEMPT TO SET GLV @ 8520' RKB VALVE CAME BACK w/ CARBOLITE IN PACKING, IN PROGRESS. 12/20/11 SET GLVs IN STAs 1 & 2 UNABLE TO LEAVE GLV IN STA# 3, WILL ATTEMPT INT. LATCH IN AM, IN PROGRESS 12/21/11 ATTEMPT TO BRUSH STA# 3 @ 8520' RKB, BRUSH & FLUSHED TBG TO 8660' SLM, BRUSH STA# 3 @ 8520' RKB, IN PROGRESS. 12/23/11 SET 1" GLV © 8520' RKB ( 3/16" PORT / 1322 TRO), BAIL FRAC SAND FROM 8665' SLM TO 8710' SLM, PULLED AVA CATCHER © 9701' RKB. COMPLETE. ` p , a KUP 3G -21A Conoc 'hilli�°,�/�.�° tM/elMs Well Attributes Max Angle & MD TD A1BSf{a Wellbore API/OW! Field Name Well Status Inc! ( °) MD (MB) Act Btm (ftKB) 501032014801 KUPARUK RIVER UNIT PROD 80.51 12,270.47 12,960.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date 1 weu Como'- 3c -21A, 12,390011 e79:49 AM SSSV: NIPPLE Last WO: 37.01 11/19/1990 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 12,500.0 8/26/2011 Rev Reason: GLV C/O ninam 12/29/2011 HANGER. ∎ Casing Strings ANGER, 27 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 4,008.6 2,979.0 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd % PRODUCTION 7 6.276 35.0 11,677.6 5,715.0 26.00 J - 55 BTC AB - MOD i = Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd cor4DUCT -o s L iner DetaPls Top na 9.703.5 12,962.2 9.30 L - 80 BTC - MOD ' Top (ftKB) (ftKB) ( °) Rem D1.9:(1200), Comment ID (in) NIPPLE, 514 W- 9,703.5 5,191.7 64.35 PACKER BAKER C -2 ZXP LINER TOP PACKER 3.500 II III 1 9,717.3 6197.7 64.26 HANGER BAKER HMC LINER HANGER 4.375 / / 12,230.8 5,813.1 80.91 MARKER JT MARKER JOINT EXTENSION x.990 3 1FT, GAS L 161 7 Mli j Tubing Strings j Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f.,. Set Depth (TVD) ... String Wt... String _. String Top Thrd TUBING Top Depth 1/2 2.992 27.1 9,734.0 5,205.0 9.30 L - 80 EUE8RDMOD Completion (TVD) Top Inc! Nomi... 4 A Top (ftKB) (ftKB) (°) Item Description Comment ID (In) SURFACE. _.I ■ 27.1 27.1 0.45 HANGER FMC TUBING HANGER 3.500 35 513.5 513.5 7.29 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 9,701.0 5,190.6 64.36 NIPPLE CAMCO D NIPPLE NO GO 2.750 - 7 9,708.1 5,193.7 64.32 LOCATOR BAKER NO GO LOCATOR 2.992 LIFT, r GAS 6,4 5 r 9,709.3 5,194.2 64.31 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GAS LIFT, Top Depth 8,521 r.:._ -- (ND) Top Intl IN Top (ftK8) (ftKB) ( °) Description Comment Run Date ID (in) 12,400 5,842.3 79.20 FISH OV LATCH 1.5" OV w/RK LATCH LOST DOWNHOLE 6/3/1999 I I I 6/3/1999 GAS LIFT, t,= Perforations & Slots 9,687 Shot Top (TVD) Btm (TVD) Dens Top (ftKB) 8892 (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment NIPPLE, 9.701 I 1 12,352 12,372 5,833.9 5,837.3 10/6/2000 6.0 APERF 60 deg phasing; 2 1/2" HSD(PJ) 12,372 12,392 5,837.3 5,840.8 10/4/2000 6.0 APERF 60 deg phasing; 2 1/2" HSD(PJ) ye 12,482 12,502 5,856.5 5,861.7 5/31/1998 4.0 IPERF 180 deg phasing; 2 1/2" HC TCP/BH r 1 12,502 12,522 5,861.7 5,867.0 5/30/1998 4.0 IPERF 180 deg phasing; 2 1/2" HC TCP/BH LOCATOR, ill 9,708 Notes: General & Safety End Date Annotation 11/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SEAL ASSY, I I 9,709 , 1 / 1 PRODUCTION. • 3511.878 APERF, 12,352- 12,372 APERF, 12,372-12,392 FISH. 12,400 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run 12,482 -1 IP 2902 ERF, I Stn Top (MKS) (ftKB) (°) Make Mode! (in) s., Type Type (in) (Psi) Run Date Com... 1 3,161.5 2,640.2 65.30 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,322.0 12/20/2011 IPERF, 12,502-12.522 IPERF. 2 6,445.2 3,897.5 66.09 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,301.0 12/20/2011 3 8,520.6 4,710.3 66.96 CAMCO KBUG 1 GAS LIFT GLV BTM 0.188 1,322.0 12/23/2011 I 4 9,687.1 5,184.6 64.45 CAMCO MMM 1 1/2 GAS LIFT OV RK 0.250 0.0 12/19/2011 1 TD (3G-21A), 12,960 LINER. 9,704-12.962 ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 ,,y, ~~~~` ~ ~~~ F. ~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: z -~ ~_:,4 '~ '~_c f.~=' ~`~ ~. °~qR ' ~~ ~®p®9~~ ~~~®yg° B£®~~ e. °C~~99®® gs ~~®~i~ G~~ ~~~ ~ ~ ~ ~/ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed 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 February 15th 2009. The corrosion inhibitor/sealant was pumped March 10th and 11 ~`, 2009. 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 Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~(~ M.J. Loveland ;` ~~ ConocoPhillips Well Integrity Projects Supervisor ~J ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off T _r- Report of Sundry Operations (10-404) Kuparuk Fietd Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/95/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3!10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 STATE OF ALASKA '- .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 85 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchoracje, AK 99510-0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 2538' FNL, 195' FEL, Sec. 23, T12N, R8E, UM (asp's 498183, 5988562) 3G-21A At top of productive interval 9. Permit number / approval number 164' FSL, 68' FWL, Sec. 26, T12N, R8E, UM (asp's493171, 5980707) 198-052 At effective depth 10. APl number 50-103-20148-01 At total depth 11. Field / Pool 447' FNL, 124' FWL, Sec. 35, T12N, R8E, UM (asp's 493227, 5980095) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12960 feet Plugs (measured) Tagged PBTD (10/3/00) @ 12510' MD. true vertical 5983 feet Effective depth: measured 12510 feet Junk (measured) true vertical 5860 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 21 6 Sx AS I 115' 115' SURFACE 3923' 9-5/8" 1050 Sx AS III & 600 Sx 4008' 2974' Class G PRODUCTION 9775' 7" 225 Sx Class G 9860' 5255' 8' LINER 3257' 3-1/2" 519 Sx Class G 12960' - ~ 3 MA~ 2, 7 Perforation depth: measured 12352 - 12392'; 12482 - 12522' -~0f~?,. Alaska Oil & Gas Cons. Commissior] true vertical 5829 - 5836'; 5855 - 5864' Anchorage Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 9709' MD. O~[G[[~,~./~I Packers & SSSV (type & measured depth) Baker C-2 ZXP Liner Top Packer @ 9709' MD. Camco 'DS' Landing Nipple @ 507' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 468 217 277 134 Subsequent to operation 470 156 253 148 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~~"~"~ Dat~repared~y~j oh n pC'~lrc~e~215_ 6471 ,,,, Signed Title: ~ ~ .~ ~.~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3G-21A DESCRIPTION OF WORK COMPLETED ADD PERFORATING OPERATIONS 10/3/00: RIH & tagged PBTD at 12510' MD. 10/4/00: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations in the 'A3' sand as follows: Added perforations: 12372 - 12392' MD Used a 2.5" HSD carrier & shot the perfs at 6 spf at 60 degree phasing. POOH w/guns. RD. 10/6/00: MIRU & PT equipment. RIH w/perforating guns & shot 20' of perforations in the 'A3' sand as follows: Added perforations: 12352 - 12372' M D Used a 2.5" HSD carrier & shot the perfs at 6 spf at 60 degree phasing. POOH w/guns. RD. Returned the well to production w/gas lift & obtained a valid well test. 0mpliance Report File on Left side of folder 198-052-0 MD 12960 KupARU, J~ miT 3~2iX ......... 502 i05:20i48}0i ARCO TYD 05986" t,,Go'mpletion Date: 5/2~98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/I) D 8460 L DGR/EWR4-MD La'AL 9893-12960 OH 7/1/98 7/1/98 L DGR/EWR4-TVD F~4q~L 5275-5988 OH 7/1/98 7/1/98 R SRVY CALC t-4~'/9795.10-12960. OH 6/19/98 6/22/98 SPERRY MPT/GR/EWR4 OH 6/17/98 6/19/98 __ ,,~RY 9795.10-12960. OH 6/26/98 7/1/98 DailyR SRVY RPT 3-/~/~well Ops _ . ~ -9~ //C/~ Are Dry Ditch Samples Required? ye~ And Receiv ~ed.~ Was the well cored? yes ~' Analysis Description Received..~yer--m~"'~"~mple Sel~ Comments: Monday, May 01, 2000 Page 1 of 1 STATE OF ALASKA %~-- r 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: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 85' RKE 3. Address: Exploratory ~. 7. Unit or Property: P.O. Box 100360 Stratagrapic ~. Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2538' FNL, 195' FEL, Sec 23, T12N, R8E, UM 3G-21A At top of productive interval: 9. Permit number/approval number: 164' FSL, 68' FWL, Sec 26, T12N, R8E, UM 98-0052 At effective depth: 10. APl number: 72' FSL, 77' FWL, Sec 26, T12N, R8E, UM 50-103-20148-01 At total depth: 11. Field/Pool: 447' FNL, 124' FWL, Sec 35, T12N, FI8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 12960 feet Plugs (measured) None true vertical 5983 feet Effective Deptt measured 12863 feet Junk (measured) None true vertical 5956 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16'" 216 Sx AS I 115' 115' Surface 3976' 9-5/8" 1050 Sx AS III & z1008' 2974' 600 Sx Class G Production 9828' 7" 225 Sx Class G 9860' 5255' Liner 3257' 3-1/2" 519 Sx Class G 12960' 5983' Perforation Depth measured 12482'- 12522' true vertical 5855'-5864' r Tubing (size, grade, and measured depth) 3.5"', 9.3 lb/fi, L-80 @ 9709' Packers and SSSV (type and measured depth)'r ~'~ ; ~ ;'~r Packer: None; SSSV: None - Camco DS Nipple @ 507' 13. Stimulation or cement squeeze summary Perforate 'A' sands on 5/31/98, Intervals treated (measured) Treatment description including volumes used and final pressure (~} Perforated well w/2.5" HC gun TCP/BH/4SPF. FP 4320 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 1086 489 11 1343 148 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~J~l/~~ Title: Production Engineering Supervisor Date Form 10-404 Rev I SUBMIT IN DUPLICATE~~ ARCO Alaska, Inc. :UPARUK RIVER UNIT SERVICE REPORT 3G-21A(4-1)) WELL JOB SCOPE JOB NUMBER 3G-21A PERFORATE, PERF SUPPORT 0527981744.6 DATE 05/31/98 DAY 2 FIELD ESTIMATE DAILY WORK C/T PERF OPERATION COMPLETE SUCCESSFUL I KEY PERSON (~ Yes O No ~ Yes O No I DS-ANDERSON AFC# lOC# I DAILY COST ACCUM COST 999119 23ODS36G L $29,800 $81,325 InitialTbg JFinalTbg IlnitiallA fFinallA ]lnitialOA IFinalOA JTTLSize 1050PSlI 400 PSII 0 PSI 50PSI 0 PSI 0 PSl l 0.000 " UNIT NUMBER UNIT #3 SUPERVISOR GOBER Signed IMin ID 0.000" Depth OFT DALLY SUMMARY PERFORATE 12482' RKB TO 12502' RKB W/2 1/2" HOLLOW CARRIER TCP/BH/4SPF/180 DEG PHASING IN ONE 20' GUN RUN TIME LOG ENTRY 09:00 ARRIVE LOCATION - CHECK WELL PRESSURES - 1050 PSI ON TBG 09:15 BREAKDOWN PERF GUN - 1 SHOT CAME OUT OF GUN AT AN ANGLE APPROX 2" BELOW PORT - RU NEW TCP PERF GUN ON C/T - 8' FROM COIL CONNECT TO TOP SHOT ON GUN - 20' GUN/4SPF/180 DEG PHASING 09:30 RU LUBRICATOR - PRESSURE TEST LUBRICATOR TO 2200 PSI (CHECKED UDAC PRESSURE TRIP/OK) - PUMP INTO LUBRICATOR ANNULUS, NOT DOWN CFI' PER SWS - LUBRICATOR TESTED GOOD 09:45 OPEN UP WELL - START IN HOLE W/CT & GUN @ 85 FPM - HOLDING 1100 PSI ON WELL 10:00 1300' CTM - INC RUNNING SPEED TO 125 FPM 10:35 5250' CTM- WEIGHT CHECK 9600 LBS 10:40 CONTINUE RIH W/CT @ 125 FPM - HOLDING 1100 PSI ON WELL 11:05 8125' CTM - WEIGHT CHECK 12000 LBS 11:10 CONTINUE RIH W/CT @ 110 FPM - HOLDING 1100 PSI ON WELL 11:55 STOP CT @ 12546' CTM - DROP 5/8" STEEL BALL IN CT - START PUMPING SLICK SW @ 1.5 BPM 12:00 PULL UP AND SET FLAG ON CT @ HORSE HEAD - RESET DEPTH TO 12504' CTM (COIL CONNECTOR-DEPTH) - PU TO 12474' CTM (TOP SHOT ON PERF GUN @ 12482' RKB) - CONTINUE PUMPING @ 1.5 BPM 12:10 DECREASE RATE TO 0.5 BPM - 18 BBLS AWAY SINCE BALL DROP 12:15 BALL ON SEAT W/21.5 BBLS PUMPED (24.6 BBL COIL VOL) - STOP PUMP - BLEED OFF PRESSURE TO 1100 PSI 12:18 START PUMP - BUILD PRESSURE WITH PUMP HOLDING 1100 PSI ON ANNULUS - GUN FIRED WITH 4320 PSI - 100 PSI OVERBALANCE 12:20 BEGIN POOH W/CT @ 130 FPM - DECREASE PUMP RATE TO 0.5 BPM 13:20 5200' CTM - DEC PULL RATE TO 100 FPM - START PUMPING DIESEL FOR FREEZE PROTECT @ 1 BPM 13:45 2700' CTM - DIESEL @ CIRC PORTS OF FIRING HEAD - GETTING 1:1 RETURNS 14:10 350' CTM - DIESEL TO SURFACE - SHUT DOWN PUMP AND CLOSE IN RETURN LINE 14:15 OUT OF HOLE WITH CT - CLOSE IN WELL 14:25 HOLD TGSM - HANDLING OF FIRED TCP PERF GUNS ON SURFACE - WATCH FOR SHARP EDGES - USE AESOP PADS TO CATCH FLUIDS ON GUN 14:35 RD LUBRICATOR FROM WELLHEAD - INSPECT GUN - GUN FIRED OK- BREAKDOWN PERF GUN 15:00 BREAKDOWN RADIUS TOOLS - CUT 10' OFF OF CT - PREP CT FOR NEXT JOB 15:30 RD LUBRICATOR 17:00 RDMO CTU - LEAVE LOCATION - NOTIFY OPERATOR OF WELL STATUS SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $6,700.00 $18,525.00 DOWELL $19,500.00 $46,800.00 PDS $0.00 $4,200.00 RADIUS $0.00 $4,600.00 SCHLUMBERGER $3,600.00 $7,200.00 TOTAL FIELD ESTIMATE $29,800.00 $81,325.00 STATE OF ALASKA '--~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !. Operations performed: 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 2538' FNL, 195' FEL, Sec 23, T12N, R8E, UM At top of productive interval: 164' FSL, 68' FWL, Sec 26, T12N, R8E, UM At effective depth: 72' FSL, 77' FWL, Sec 26, T12N, R8E, UM At total depth: 447' FNL, 124' FWL, Sec $5, T12N, R8E, UM Operation Shutdown _ Stimulate~X Pull tubing _ Alter casing _ 5. Type of Well: Development X. Exploratory ~ Stratagrapic ~. Service ~. Plugging _ Perforate _ Repair well _ Other _ 6. Datum of elavation (DF or KB feet): 85' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 3 G -21A 9. Permitnumbe~approvalnumber: 98-0052 10. APInumber: 50-103-20148-01 11. Field/Pool: Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 12960 feet true vertical 5983 feet Effective Depfl measured 12863 feet true vertical 5956 feet Casing Length Conductor 80' Surface 3976' Production 9828' Liner 3257' Size 16" 9-5/8" 7" 3-1/2'" Plugs (measured) None Junk (measured) None Cemented 216 Sx AS I 1050 Sx AS III & 600 Sx Class G 225 Sx Class G 519 Sx Class G Measured depth 115' 4008' 9860' 12960' True vertical depth 115' 2974' 5255' 5983' Perforation Depth measured 12482'-12522' true vertical 5855'-5864' Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, L-80 @ 9709' Packers and SSSV (type and measured depth) Packer: None; SSSV: None - Camco DS Nipple @ 507' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 6/6/98. Intervals treated (measured) 12482'- 12502' Treatment description including volumes used and final pressure Pumped 100,439 lbs of 16/20 & 12/18 ceramic proppant into formation, fp was 8234 psi. ORi !NAL 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing 'Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 1689 1499 6 1341 150 15. Attachments MIT form 116. Status of well classification as: Copies of Logs and Surveys run _ I Daily Report of Well Operations ~X Oil _X Gas _ Suspended _ Service _ 17. I hereb~y certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Production Engineering Supervisor Date ~/ ~ Form 10-404 Re9 D6/15/88 SUBMIT iN DUPLICA ARCO Alaska, Inc. '(UPARUK RIVER UNIT SERVICE REPORT 3G-21A(4-1)) WELL JOB SCOPE JOB NUMBER 3G-21A FRAC, FRAC SUPPORT 0529982022.14 UNIT NUMBER DATE O6/06/98 DAY 1 FIELD ESTIMATE DALLY WORK A SAND REFRACTURE OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ('~ Yes O No ~_~ Yes O No DS-YOKUM AFC# ICC# I DAILY COST ACCUM COST KD2347 230 DS36G L $107,682 $107,682 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ITTLSize 1300PSll 500 PSll 50PSI 500 PSI 0PSI 0PSI 0.000 " SUPERVISOR JORDAN Signed IMin ID I Depth 0.000" 0 FT DALLY SUMMARY A SAND REFRAC SCREENED OUT EARLY. 100,439 LBS PROPPANT PLACED IN FORMATION, 52,991 LBS PROPPANT LEFT IN PIPE. MAX TREATING PRESSURE 8234 PSI. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - YOAKUM; LRS; APC. TGSM. PT 9600 PSI OK. 08:00 PUMP BREAKDOWN AND CONDITION STAGES ACCORDING TO PROCEDURE. STEPDOWN TEST, SHUTDOWN OBTAIN ISIP 2152 PSI. 09:30 PUMP DATAFRAC. SHUTDOWN AND OBTAIN ISIP 2097 PSI. ADJUST PAD. 11:15 PUMP FRAC PER PROCEDURE THROUGH 10 PPA. SCREENED OUT AT 10 PPA FLAT STAGE. MAX PRESS 8234 PSI. TOTAL 142,430 LBS PROPPANT PUMPED. TOTAL 100,439 LBS IN FORMATION AND 52,991 LBS PROPPANT LEFT IN PIPE. 13:00 RDMO DS FRAC UNIT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $5,000.00 $5,000.00 DIESEL $0.00 $0.00 DOWELL $99,682.00 $99,682.00 GASLI FT VALVES $0.00 $0.00 HALLIBURTON $0.00 $0.00 LITTLE RED $3,000.00 $3,000.00 TOTAL FIELD ESTIMATE $107,682.00 $107,682.00 WELL LOG TRANSMITrAL To: State of Alaska )daska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 July 1, 1998 RE: MWD Formation Evaluation Logs 3G-21A, AK-MM-80230 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3G-21A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20148-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20148-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska99518 · (907)563-3256 · Fax (907)563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 19,1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3G-21A (Permit No. 98-52) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 3G-21. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/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 OiL [~ GAS [] SUSPENDED [~] ABANDONED~ SERVICE ~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-0052 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20148-01 4 Location of well at surface 9 Unit or Lease Name 2538'FNL, 195'FEL, Sec. 23, T12N, R8E, UM f ..... .. L :,,_,:; ,~ Kuparuk River Unit At Top Producing Intervali" ..~.~~._ '. ~'~'~ -, ~~, it- 10 Well Number 164' FSL, 68' FWL, Sec. 26, T12N, R8E, UM ~ ~/,_.~_i~.' 3G-21A 447' FNL, 124' I=WL, Sec. 35, T12N, R8E, UM......... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Sedal No. Kuparuk River Oil Pool RKB 85', Pad 53' GL ADL 25548 ALK 2662 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 15-Ma¥-98 19-May-98 23-May-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 12960' MD & 5986' TVD 12863' MD & 5959' TVD YES M NO U N/A feet MD 1600' APPROX 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5# H-40 SURF. 115' 24' 216 sx AS I 9.625' 36.0# J-55 SURF. 4008' 12.25' 1050 sx AS III, 600 sx Class G 7' 26.0# J-55 SURF. 9860' 8.5' 225 sx Class G 3.5' 9.3# L-80 9704' 12960' 6.125' 519 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 9709' 9704' 12482'-12522' MD 5858'-5868' TVD 4 spT 26 ACID, FRACTURE, CEMEh DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12482'-12522' 100,439# proppant in formation; 51,991# proppant left in pipe 27 PRODUCTION TEST Date First Production of Operation (Flowing, gas lift, etc.) :"4o. oi;;.~ 6/11/98 Gas Lift Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBI CHOKE SIZE J GAS-OIL RATIO 6/14/98 18.00 TEST PERIOI' '1808 1273 25 176I 838 Flow Tubing Casing Pressure CALCULATED OIL-BBL IGAS-MCF WATER-BBt OIL GRAVITY-APl (corr) Press. 158 1225 24-HOUR RATE: 2202 m44 33 23° 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 130. ' ...... 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 Kuparuk C 12325' 5824' Bottom Kuparuk C 12352' 5828' Top Kuparuk A 12352' 5828' Bottom Kuparuk A 12760' 5927' Annulus left open - freeze protected with diesel. 31. LIST OF AIYACHMENTS Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 5/27/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3G-21A WELL_ID: 999119 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD: START COMP:05/10/98 RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20148-01 05/10/98 (C1) TD:11678' PB:11589' NU BOPE MW:12.3 LSND SUPV:MCH Move Zig from 3G-14A to 3G-21A. Accept rig @ 0730 hrs. 5/10/98. Pump mud to kill well. 05/11/98 (C2) TD:11678' PB:11589' pulling and laying down t MW:12.3 LSND SUPV:MCH Pump 12.3# mud and kill well. N/U BOPE and test. Pull tubing. Lay balanced cement plug. Laying down 3.5" tubing. 05/12/98 (C3) TD:11678' PB: 0' Conditioning mud MW:12.3 LSND SUPV:DW Continue to L/D 3.5" tubing. Test BOPE to 2500 psi, OK. 05/13/98 (C4) TD:11678' PB: 0' Milling window @ 9860' to MW: 9.6 LSND SUPV:DW Continue circulating cutting mud weight from 12.3 to 9.6 ppg. RIH with 7" Whipstock assembly. 05/14/98 (C5) TD: 9893' PB: 0' Sliding for direction MW: 9.6 LSND SUPV:DW RIH w/ 7" Whipstock and mill assembly to 9860' Set packer. Mill off 7" whipstock face cutting window from 9860' to 9872', drill from 9872' to 9893'. LOT @ 9860' MD, 13.8 ppg EMW. 05/15/98 (C6) TD:10585' PB: 0' Drilling Ahead 2/6.125" h SUPV:DW Drill 6.125" hole from 9893' to 11585' MW: 9.6 LSND 05/16/98 (C7) TD:11375' PB: 0' Short trip MW: 9.5 LSND SUPV:DW Continue drilling 6.125" hole form 10585' to 11375'. Hole in good condition up to 11375' tight hole. Started raising Date: 5/27/98 ARCO ALASKA INC. WELL SUMMARY REPORT mud weight from 9.7 to 11.4 ppg. Page: 2 05/17/98 (C8) TD:12075' PB: 0' 05/18/98 (C9) TD:12920' PB: 0' Drilling ahead @ 12300' MW:ll.4 LSND SUPV:DW Continue drilling 6.125" from 11375' to 11805' Perform FIT to 13.6 ppg EMW. Drill from 11805' to 12075' TD 6.125" hole @ 12960' M MW:ll.4 SUPV:DW Continue to drill 6.125" from 12075' to 12920' LSND 05/19/98 (C10) TD:12960' PB: 0' Circ. influx in csg press MW:12.0 LSND SUPV:MCH Drilling from 12920 to 12960' TD. Circ and condition mud f/3.5" liner. Wiper trip into shoe @ 9815', tight hole @ 11245, work pipe. Work tight hole from 12046 to 12360. Hole taking 1 bpm fluid. Spot lube rex pill. POH, hole not taking right amount of fluid. Shut well in. 05/20/98 (Cll) TD:12960' PB: 0' 05/21/98 (C12) TD:12960' PB: 0' Run 3.5" liner MW:12.1 LSND SUPV:MCH Circ thru choke, attempt to stop flow. Circ thru open choke, no gas on bottoms up, well still flowing. Circ. Pump pill. Laying down 3.5" DP MW:ll.6 LSND SUPV:MCH Run 3.5" liner. Tight hole form 11800 to 12400' Prepare for cementing liner. 05/22/98 (C13) TD:12960' PB: 0' 05/23/98 (C14) TD:12960' PB: 0' Loading pipe shed w/tbg MW:ll.6 LSND SUPV:MCH Pump cement. Set hanger and packer. Set storm packer. N/D BOPE - cleaning mud t MW: 0.0 LSND SUPV:MCH RIH w/3.5" completion assembly. Displace well to clean seawater. 05/24/98 (C15) TD:12960' PB: 0' Released rig @ 1000 hrs. MW: 0.0 SUPV:MCH Freeze protect well. Test tubing and annulus. N/D BOPE. N/U test tree. Release rig @ 1000 hrs. 5/24/98 End of WellSummary for We11:999119 Prepared by: S. ALLSUP-DRAKE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT '~' K1(3G-21A(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-21A PERFORATE, PERF SUPPORT 0527981744.6 DATE DAILY WORK UNIT NUMBER 05/30/98 MEMORY LOG AND PERFORATE UNIT #3 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 NOI YES DS-ANDERSON GOBER Signed Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 50 PSI 0 PSI 100 PSI 0 PSII 0 PSI DALLY SUMMARY IPDS MEMORY LOG WITH GAMMA RAY, CCL FOR PERF RUN TIE IN - PERFORATE 12502' RKB - 12522' RKB W/2 1/2" HOLLOW CARRIER TCP'S/BH/4 SPF/180 DEGREE PHASED IN ONE 20' GUN RUN TIME LOG ENTRY 08:00 MIRU DS 09:00 STATE REQUIRED FULL BOP FUNCTION/PRESS TEST STACK TO 4000 PSI - ALL GOOD 10:00 REPAIR LEAKS ON INJECTOR HEAD/ADD 25' LUB/CUT COIL CONNECTOR 11:15 PDS REMOVING COUNTER HEAD AND RIGGING UP THEIR EQUIPMENT 11:45 ADD RADIUS COIL CONNECTOR/PULL TEST HEAD TO 10,000#/PRESS TEST COIL CONNECTOR TO 3000 PSI - ADD CIRC SUB/DISCONNECT AND TWO X-OVERS TO 3/4" S.R. 12:15 ADD PDS 9.52' TOOL STRING - COIL ADAPTER/KNUCKLE JOINT/SWIVEL/X-OVER/BATTERY HOUSING/MEMORY SUB/GAMMA RAY SENSOR/CCL/BULL PLUG 12:30 RIH W/PDS MEMORY TOOL STRING TO PROVIDE GAMMA RAY TIE IN TO FLAG PIPE FOR PERF JOB 14:15 GETTING SW BACK TO TANK DUE TO PIPE DISPLACEMENT 14:25 STOP RIH @ 12550' CTM - PU TO 12501.4' CTM (PDS READING) - FLAG TBG @ HORSE HEAD PU W/CT - BEGIN LOG RUN @ 55 FPM - LOG FROM 12504' TO 11720' CTM 14:35 14:50 11720' CTM - INC PULL RATE TO 150 FPM 15:45 2600' CTM - DEC PULL RATE TO 100 FPM - START PUMPING SW @ 1 BPM TO DISPLACE DIESEL OUT OF REEL 16:15 500' CTM - SD PUMP 16:20 OUT OF HOLE W/CT - SI SWAB VALVE - BREAK DOWN MEMORY LOG TOOLS 16:40 DOWNLOAD MEMORY LOG DATA- APPEARS TO BE GOOD DATA 17:00 TGSM - TCP GUN HANDLING - WEAR SAFETY HARNESS WHEN WORKING IN MAN-LIFT 17:15 RU TCP PERF GUN ON CT - 8' FROM COIL CONNECT TO TOP SHOT ON GUN - 20' GUN/4 SPF/180 DEG PHASING I TIME LOG ENTRY 17:30 CORRELATE LOGS - PDS SCALE 5" = 100' - MWD LOG 5" = 105' - CORRELATE TO GAMMA RAY @ TOP OF 'A' SAND 18:30 PRESSURE TEST LUBRICATOR TO 2500 PSI - PUMP INTO LUBRICATOR ANNULUS, NOT DOWN TUBING PER SWS - LUBRICATOR TESTED GOOD 18:45 OPEN UP WELL - START IN HOLE W/CT & GUN @ 85 FPM 19:00 1300' CTM -INC RUNNING SPEED TO 110 FPM 20:45 STOP CT @ 12525' CTM - PU TO GET WEIGHT - STOP @ 12515' CTM 20:50 DROP 5/8" STEEL BALL IN CT - START PUMPING SLICK SW @ 1.5 BPM 20:55 21:05 21:15 21:20 PULL UP AND SET FLAG ON CT @ HORSE HEAD - RESET DEPTH TO 12504' CTM (COIL CONNECTOR DEPTH) - PU TO 12494' CTM (TOP SHOT ON PERF GUN @ 12502') - CONTINUE PUMPING @ 1.5 BPM DECREASE RATE TO 0.5 BPM - 16 BBLS AWAY SINCE BALL DROP BALL HIT W/22.5 BBLS PUMPED (24.6 BBL COIL VOL) - PRESSURE UP ON CT GUNS FIRED WITH 4500 PSI ON CT - 1100 PSI ON CSG - 100 PSI OVERBALANCE - INC PUMP RATE TO 1.5 BPM AND CIRCULATE - GUNS APPEARED TO HAVE FIRED 21:25 BEGIN POOH W/CT @ 130 FPM - DECREASE PUMP RATE TO 0.5 BPM 22:15 5200' CTM - DEC PULL RATE TO 100 FPM - START PUMPING DIESEL FOR FREEZE PROTECT @ 1 BPM 22:40 2650' CTM - DIESEL @ CIRC PORTS OF FIRING HEAD - GETTING 1:1 RETURNS 23:15 SHUT DOWN PUMP - OUT OF HOLE WITH CT - CLOSE IN WELL 23:30 RD LUBRICATOR FROM WELLHEAD - INSPECT GUN - GUN FIRED OK - LEAVE GUN DRAINING IN LUBRICATOR ON BACK DECK OVERNIGHT 00:00 SDFN - NOTIFY OPERATOR OF WELL STATUS ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(3G-21A(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-21A PERFORATE, PERF SUPPORT 0527981744.6 DATE DAILY WORK UNIT NUMBER 05/31/98 C/T PERF UNIT #3 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES DS-ANDERSON GOBER FIELD AFC# CC# Signed Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann t Initial Outer Ann I Final Outer Ann 1050 PSI 400 PSI 0 PSI 50 PSII 0 PSII 0 PSI DALLY SUMMARY PERFORATE 12482' RKB TO 12502' RKB W/2 1/2" HOLLOW CARRIER TCP/BH/4SPF/180 DEG PHASING IN ONE 20' GUN RUN I TIME LOG ENTRY 09:00 ARRIVE LOCATION - CHECK WELL PRESSURES - 1050 PSI ON TBG 09:15 BREAKDOWN PERF GUN - 1 SHOT CAME OUT OF GUN AT AN ANGLE APPROX 2" BELOW PORT - RU NEW TCP PERF GUN ON C/f' - 8' FROM COIL CONNECT TO TOP SHOT ON GUN - 20' GUN/4SPF/180 DEG PHASING 09:30 RU LUBRICATOR - PRESSURE TEST LUBRICATOR TO 2200 PSI (CHECKED UDAC PRESSURE TRIP/OK) - PUMP INTO LUBRICATOR ANNULUS, NOT DOWN CFI' PER SWS - LUBR__.-ICATOR TESTED GOOD 09:45 OPEN UP WELL - START IN HOLE W/CT & GUN @ 85 FPM - HOLDING 1100 PSI ON WELL 10:00 1300' CTM - INC RUNNING SPEED TO 125 FPM 10:35 5250' CTM - WEIGHT CHECK 9600 LBS 10:40 CONTINUE RIH W/CT @ 125 FPM - HOLDING 1100 PSI ON WELL 11:05 8125' CTM - WEIGHT CHECK 12000 LBS 11:10 CONTINUE RIH W/CT @ 110 FPM- HOLDING 1100 PSI ON WELL 11:55 STOP CT @ 12546' CTM - DROP 5/8" STEEL BALL IN CT - START PUMPING SLICK SW @ 1.5 BPM 12:00 12:10 12:15 BALL ON SEAT W/21.5 BBLS PUMPED (24.6 BBL COIL VOL) - STOP PUMP - BLEED OFF PRESSURE TO 1100 PSI 12:18 START PUMP - BUILD PRESSURE WITH PUMP HOLDING 1100 PSI ON ANNULUS - GUN FIRED WITH 4320 PSi - 100 PSI OVERBALANCE 12:20 BEGIN POOH W/CT @ 130 FPM - DECREASE PUMP RATE TO 0.5 BPM 13:20 5200' CTM - DEC PULL RATE TO 100 FPM - START PUMPING DIESEL FOR FREEZE PROTECT @ 1 BPM 13:45 2700' CTM - DIESEL @ CIRC PORTS OF FIRING HEAD - GETTING 1:1 RETURNS PULL UP AND SET FLAG ON CT @ HORSE HEAD - RESET DEPTH TO 12504' CTM (COIL CONNECTOR DEPTH) - PU TO 12474' CTM (TOP SHOT ON PERF GUN @ 12482' RKB) - CONTINUE PUMPING @ 1.5 BPM DECREASE RATE TO 0.5 BPM - 18 BBLS AWAY SINCE BALL DROP TIME LOG ENTRY 14:10 350' CTM - DIESEL TO SURFACE - SHUT DOWN PUMP AND CLOSE IN RETURN LINE 14:15 OUT OF HOLE WITH CT - CLOSE IN WELL 14:25 HOLD TGSM - HANDLING OF FIRED TCP PERF GUNS ON SURFACE - WATCH FOR SHARP EDGES - USE ABSORB PADS TO CATCH FLUIDS ON GUN 14:35 RD LUBRICATOR FROM WELLHEAD - INSPECT GUN - GUN FIRED OK - BREAKDOWN PERF GUN 15:00 BREAKDOWN RADIUS TOOLS - CUT 10' OFF OF CT - PREP CT FOR NEXT JOB 15:30 RD LUBRICATOR 17:00 RDMO CTU - LEAVE LOCATION - NOTIFY OPERATOR OF WELL STATUS SURVEY CALCULATION AND FIELD WORKSHEET r ~~ Job No. 0450-97827 Sidetrack No. 1 Page 1 of 2 I:Ll[~:l=[.-I Company ARCO ALASKA, INC. Rig Contractor & No. Nordic-Rig#2 Field KUPARUK RIVER UNIT I~ Well Name & No. PAD 3G/21A Survey Sec.'ion Name Definitive Survey BHI Rep. ERWIN SALVATIERRA WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2538.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[--] SS[-] Target Description Target Coord. F_JW Slot Coord. E/W -195.00 Magn. Declination 27.410 Calculation Method MINIMUM CURVATURE 'Target Direction (DD) Build\Walk\DL per: 100ft~ 30m0 10m~ Vert, Sec. Azim. 176.48 Magn. to Map Corr, 27.410 Map North to: OTHER SURVEY DATA (~ ~')./F') ~- ~ Total Coordinate Build Rate Walk Rate~' v~- v .J ~ Survey Survey Incl. Hole Course Vertical Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (F-'I~ (FT) (FT) (F'~ (Per 100 FT) Drop (-) Left (-) GMS 9795.10 63.78 215.48 5231.60 5126.30 -5444.30 -5023.40 TIE IN POINT 15-MAY-98 MWD 9860.00 63.46 214.87 64.90 5260.44 5170.98 -5491.82 -5056.89 0.98 -0.49 -0.94 4 3/4' M1 1.5 DEG AKO . 15-MAY-98 MWD 9978.35 66.57 202.62 118.35 5310.58 5261.53 -5585.69 -5108.22 9.74 2.63 -10.35 15-MAY-98 MWD 10003.67 66.83 200.49 25.32 5320.59 5282.59 -5607.32 -5116.76 7.79 1.03 -8.41 15-MAY-98 MWD 10042.05 68.55 201.96 38.38 5335.16 5314.83 -5640.42 -5129.62 5.71 4.48 3.83 ~ ~'~ 'l'JI~' I ~ I A ~1 15-MAY-98 MWD 10074.10 69.26 200.20 32.05 5346.70 5342.02 -5668.32 -5140,37 5,58 2.22 -5.49 U I L3 I L 15-MAY-98 MWD 10105.71 70,93 195.28 31.61 5357.47 5369.71 -5696.61 -5149,41 15.56 5.28 -15,56 15-MAY-98 MWD 10137.61 74,00 192,82 31,90 5367.08 5398,70 -5726,12 -5156,79 12.11 9.62 -7,71 15-MAY-98 MWD 10168,67 75.23 187,02 31.06 5375.32 5427,82 -5755.60 -5161,94 18.43 3.96 -18,67 15-MAY-98 MWD 10200,77 75,15 184,91 32.10 5383,53 5458,42 -5786,47 -5165,17 6,36 -0,25 -6.57 15-MAY-98 MWD 10233.33 75,42 183,20 32,56 5391,80 5489,64 -5817,88 -5167.40 5,15 0,83 -5.25 15-MAY-98 MWD 10263.28 75.51 181.46 29.95 5399.32 5518.48 -5846.85 -5168.57 5.63 0.30 -5.81 15-MAY-98 MWD 10295.36 75.63 178.47 32.08 5407.31 5549.48 -5877.91 -5168.56 9.03 0.37 -9.32 · 16-MAY-98 MWD 10337.84 78.13 173.13 42.48 5416.96 5590.83 -5919.15 -5165.52 13.58 5.89 -12.57 ~. 15-MAY-98 MWD 10390.44 74.93 178.11 52.60 5429.22 5641.96 -5970.13 -5161.60 11.03 -6.08 9.47 15-MAY-98 MWD 10485.66 74.18 177.00 95.22 5454.58 5733.72 -6061.82 -5157.68 1.37 -0.79 -1.17 16-MAY-98 MWD 10579.36 73.74 176.29 93.70 5480.47 5823.77 -6151.72 -5152.41 0.87 -0.47 -0.76 16-MAY-98 MWD 10672.15 74.88 176.46 92.79 5505.56 5913.10 -6240.87 -5146.77 1.24 1.23 0.18 16-MAY-98 MWD 10766.97 75.06 175.59 94.82 5530.15 6004.67 -6332.23 -5140.42 0.91 0.19 -0.92 16-MAY-98 MWD 10861.95 78.66 176.12 94.98 5551.74 6097.14 -6424.46 -5133.74 3.83 3.79 0.56 16-MAY-98 MWD 10955.31 78.82 175.68 93.36 5569.97 6188.70 -6515.79 -5127.19 0.49 0.17 .0.47 16-MAY-98 MWD 11050.53 78.57 174.90 95.22 5588.64 6282.05 -6608.85 -5119.52 0.85 -0.26 .0.82 16-MAY-98 MWD 11144.28 78.31 173.66 93.75 5607.43 6373.83 -6700.24 -5110.37 1.33 -0.28 -1.32 16-MAY-98 MWD 11237.84 78.13 173.13 93.56 5626.53 6465.29 -6791.22 -5099.84 0.59 .0.19 -0.57 --[l_r~-=l Company ARCO ALASKA, INC. Rig Contractor & No. Nordic - Rig #2 Field KUPARUK RIVER UNIT Well Name & No. PAD 3G/21A Survey Section Name Definitive Survey BHI Rep. ERWIN SALVATIERRA ~jllli~"~i~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2538.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE~ SS~ Target Description Target Coord. EJW Slot Coord. EJW -195.00 Magn. Declination 27.410 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build~Walk\DL per: lOOft[~ 30m~ 10m~ Vert. Sec. Azim. 176.48 Magn. to Map Corr. 27.410 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (F'I~ (F'r} (Per 100 F~ Drop (-) Left (-) -- 17~MAY-98 MWD 11332.27 78.35 172.79 94.43 5645.77 6557.56 -6882.97 -5088.51 0.42 0.23 -0.36 _. 17-MAY-98 MWD 11424.99 78.66 171.73 92.72 5664.25 6648.17 -6973.00 -5076.27 1.17 0.33 -1.14 17-MAY-98 MWD 11519.41 78.47 171.19 94.42 5682.97 6740.37 -7064.52 -5062.53 0.60 -0.20 -0.57 17-MAY-98 MWD 11612.23 79.03 176.67 92.82 5701.09 6831.27 -7155.01 -5052.91 5.82 0.60 5.90 _, 17-MAY-98 MWD 11706.86 79.32 177.11 94.63 5718.86 6924.22 -7247.82 -5047.87 0.55 0.31 0.46 17-MAY-98 MWD 11799.62 79.50 176.91 92.76 5735.91 7015.39 -7338.87 -5043.11 0.29 0.19 -0.22 17-MAY-98 MWD 11958.02 79.67 176.00 158.40 5764.55 7171.18 -7494.36 -5033.48 0.58 0.11 -0.57 17-MAY-98 MWD 12114.68 80.30 175.51 156.66 5791.79 7325.44 -7648.21 -5022.06 0.51 0.40 -0.31 17-MAY-98 MWD 12270.47 80.51 176.28 155.79 5817.76 7479.04 -7801.43 -5011.06 0.51 0.13 0.49 18-MAY-98 MWD 12428.29 78.92 175.23 157.82 5845.94 7634.31 -7956.28 -4999.57 1.20 -1.01 -0,67 18-MAY-98 MWD 12585.10 74.26 174.46 156.81 5882.29 7786.74 -8108.15 -4985.88 3.01 -2.97 -0.49 18-MAY-98 MWD 12679.51 73.98 173.93 94.41 5908.13 7877.47 -8198.49 -4976.69 0.62 -0.30 -0.56 18-MAY-98 MWD 12773.96 73.89 174.64 94,45 5934,26 7968.16 -8288,80 -4967.66 0.73 -0,10 0.75 18-MAY-98 MWD 12867.27 73.74 174.56 93.31 5960.27 8057.73 -8378.02 -4959.22 0.18 -0.16 -0.09 18-MAY-98 MWD 12894.70 73.72 174.75 27.43 5967.96 8084,05 -8404.23 -4956.77 0.67 -0.07 0.69 18-MAY-98 MWD 12960.00 73.72 174.75 65.30 5986.26 8146.70 -8466.65 -4951.03 0.00 0.00 0.00 Projected Data - NO SURVEY Kuparuk Unit Kuparuk 3G 3G-21A SURVEY REPORT ORIGINAL 26 June, 1998 Your Ref: API-501032014801 Last Survey Date 19-May.98 Job# AKMMS0230 KBE- 85.10' DRILLING SERVICES A, DIVISION OF DIU~B IND[I~rf'RIE~, RECEi~,'ED JUL 0~ ~9,~8 ..,,.r',:-I ~o G~ Cons. A,'~c~rage Survey Ref: svy26 Sperry-Sun Drilling Services Survey Report for 3G-21A Your Ref: AP1-501032014801 Kuparuk Unit Measured Depth (ft) 9795.10 9860.00 9882.60 9914.60 9946.39 9978.35 10003.67 1 O042.05 10074.10 10105.71 10137.61 10168.67 1 O2O0.77 10233.33 10263.28 10295.36 10390.44 10485.66 10579.36 10672.15 10766.97 10861.95 10955.31 11050.53 11144.28 11237.84 11332.27 11424.99 11519.41 11612.23 63.780 63.460 64.380 64.280 66.24O 66.570 66.830 68.550 69.260 7O.93O 74.000 75.230 75.150 75.420 75.510 75.630 74.930 74.180 73.740 74.880 75.060 78.660 78.820 78.570 78.310 78.130 78.350 78.660 78.470 79.030 215.480 214.870 212.480 209.140 205.860 202.620 200.490 201.960 200.200 195.280 192.820 187.020 184.910 183.200 181.460 178.470 178.110 177.000 176.290 176.470 175.590 176.120 175.680 174.900 173.660 173.130 172.790 171.730 171.190 176.670 Sub-Sea Depth (ft) 5141.69 5170.53 5180.46 5194.33 5207.63 5220.43 523O.45 5245.02 5256.55 5267.32 5276.93 5285.18 5293.38 5301.66 5309.17 5317.17 5341.33 5366.69 5392.58 5417.67 5442.26 5463.85 5482.08 5500.74 5519.53 5538.63 5557.88 5576.36 5595.08 5613.20 Vertical Depth (ft) 5226.79 5255.63 5265.56 5279.43 5292.73 5305.53 5315.55 5330.12 5341.65 5352.42 5362.03 5370.28 5378.48 5386.76 5394.27 5402.27 5426.43 5451.79 5477.68 5502.77 5527.36 5548.95 5567.18 5585.84 5604.63 5623.73 5642.98 5661.46 5680.18 5698.30 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 5444.30 S 5023.40W 5491.82 S 5056.89W 5508.72 S 5068.15W 5533.48 S 5082.92W 5559.09 S 5096.24W 5585.79 S 5108.26W 5607.42 S 5116.80W 5640.51S 5129.66W 5668.41 S 5140.41W 5696.71 S 5149.46W 5726.21S 5156.84W 5755.70 S 5161.99W 5786.56 S 5165.21W 5817.97 S 5167.44W 5846.94 S 5168,62W 5878.01S 5168.60W 5969.92 S 5165.86W 6061.62 S 5161.94W 6151.52 S 5156.67W 6240.67 S 5151.03W 6332.02 S 5144.69W 6424.26 S 5138.01W 6515.59 S 5131.46W 6608.64S 5123.80W 6700.03 S 5114.64W 6791.01 S 5104.11W 6882.77 S 5092.78W 6972.80 S 5080.54W 7064.32 S 5066.80W 7154.80 S 5057.18W 5983117.49 N 493160.11 E 5125.61 5983069.97 N 493126.60 E 0.976 5170.99 5983053.08 N 493115.35 E 10.334 5187.15 5983028.32 N 493100.57 E 9.412 5210.97 5983002,72 N 493087.24 E 11.216 5235.71 5982976.02 N 493075.21 E 9.347 5261.62 5982954,39 N 493066.67 E 7.794 5282.68 5982921.30 N 493053.80 E 5.713 5314.93 5982893.40 N 493043.04 E 5'.582 5342.11 5982865.11 N 493033.99 E 15.558 5369.80 5982835.61 N 493026.60 E 12.111 5398.80 5982806.12 N 493021.44 E 18.434 5427.91 5982775.26 N 493018.21 E 6.360 5458.52 5982743.85 N 493015.98 E 5.147 5489.73 5982714.88 N 493014.79 E 5.632 5518.57 5982683.82 N 493014.80 E 9.034 5549.58 5982591.90 N 493017.53 E 0.822 5641.49 5982500.20 N 493021.42 E 1.372 5733.26 5982410.31 N 493026.66 E 0.867 5823.31 5982321.15 N 493032.28 E 1.243 5912.64 5982229.79 N 493038.60 E 0.916 6004.21 5982137.56 N 493045.26 E 3.829 6096.68 5982046.23 N 493051.78 E 0.493 6188.24 5981953.17 N 493059.43 E 0.845 6281.59 5981861.78 N 493068.56 E 1.325 6373.37 5981770.79 N 493079.07 E 0.587 6464.83 5981679.04 N 493090.38 E 0.423 6557.10 5981589.01N 493102.60 E 1.169 6647.71 5981497.48 N 493116.32 E 0.596 6739.90 5981406.99 N 493125.91 E 5.822 6830.81 Comment Tie-in survey Window Point Kuparuk 3G Continued... 26 June, 1998 - 3:26 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3G-21A Your Reft AP1-501032014801 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 11706.86 79.320 177.110 5630.97 5716.07 11799.62 79,500 176.910 5648.02 5733.12 11958.02 79,670 176.000 5676.65 5761.75 12114.68 80,300 175,510 5703.90 5789.00 12270.47 80.510 176.280 5729.87 5814.97 12428.29 78.920 175.230 5758.04 5843.14 12585.10 74.260 174.460 5794.40 5879.50 12679.51 73.980 173.920 5820.23 5905.33 12773.96 73.890 174.640 5846.37 5931.47 12867.27 73,740 174.560 5872.38 5957.48 12894.70 73.720 174.750 5880.06 5965.16 12960.00 73.720 174.750 5898.37 5983.47 7247.61S 5052.14W 5981314,18 N 493130,93 E 0.550 6923.75 7338.67 S 5047.38W 5981223.13 N 493135.67 E 0.287 7014.93 7494.16 S 5037.75W 5981067.63 N 493145.26 E 0.575 7170.72 7648.01S 5026.33W 5980913.78 N 493156.65 E 0,507 7324.98 7801.22 S 5015.33W 5980760.56 N 493167.60 E 0.506 7478.58 7956.07 S 5003.84W 5980605.71 N 493179.06 E 1.201 7633.84 8107.95 S 4990.15W 5980453.83 N 493192.71 E 3.010 7786.27 8198.29 S 4980.96W 5980363.49 N 493201.88 E 0,625 7877.01 8288.60 S 4971.91W 5980273.18 N 493210.91 E 0,739 7967.70 8377.81S 4963.48W 5980183.96 N 493219.32 E 0.181 8057.26 8404.03 S 4961.03W 5980157.74 N 493221.76 E 0.669 8083.58 8466.45 S 4955.29W 5980095.32 N 493227.48 E 0,000 8146.24 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 176.480° (True). "Based upon Minimum Curvature type calculations, at a Measured Depth of 12960.00ft., The Bottom Hole Displacement is 9809.98ft., in the Direction of 210.340° (True). Comment Projected Survey Kuparuk 3G Continued... 26 Jun~1998 - 3:26 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3G-2'IA Your Ref: API-501032014801 Kuparuk Unit Kuparuk 3G Comments Measured Depth (ft) 9795.10 9860.00 12960.00 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 5226.79 5444.30 S 5023.40 W Tie-in survey 5255.63 5491.82 S 5056.89 W Window Point 5983.47 8466.45 S 4955.29 W Projected Survey 26 June, 1998 - 3:26 - 4 - DrillQuest 26-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 3G-21A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,795.10' MD 9,860.00' MD 12,960.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Ino, Company I::1 IR I I_ I_ I Al [:i WELL LOG TRANSMITTAL To: State of Alaska June 17, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: ~MWD Formation Evaluation Logs 3 G-21 A, A~-~-80230 1 LDWG formatted Disc with verification listing. API#: 50-103-20148-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETrER TO TIlE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: Signed: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHQNE: (907) 279-1433 FAX: ~907) 276-7542 March 18. 1998 Mike Zanghi Drilling Superintendent .ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 3G-21A ARCO Alaska. Inc. Permit No. 98-52 Sur. Loc. 2538'FNL. 195'FEL. SEC. 23. TI2N. R08E. UM Btmnholc Loc. 69'FSL. 7YFWL, SEC. 26, T12N. R08E. UM Dear Mr. Zanghi: Enclosed is the approved application for permit to rcdnll the above referenced well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max.' be given field inspector on the North Slope pager at 659-3607. David W. J~ Chaim~an BY ORDER OF THE COMMISSION dlffEnclosurcs CC: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. · .- J STATE OF ALASKA ...... ._~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 ta. Type of Work Ddll Redrill X I lb Type of Well Exploratory Stratigraphic Test Development Oil X · Re-Entry Deepen Service 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 85', Pad 53' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548,~'~LK 2662 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 195' FEL, Sec. 23, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 491' FSL, 39' FWL, Sec. 26, T12N, R8E, UM 3G-21A #U-630610 At total depth 9. Approximate spud date Amount 69' FSL, 73' FWL, Sec. 26, T12N, R8E, UM 4/1/98 $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 3G-20 12,574' MD 39'@ Target feet 25'@ surface feet 2560 5936' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 9869' feet Maximum hole angle 76.5° Maximum surface 2957 psig At total depth (TVD) 3600 psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~lht Grade Couplin~l Len~]th MD TVD MD TVD (include stage data) 6-1/8" 3-1/2" 9.3# L-80 EUE-mod 2855' 9719' 5193' 12574' 5936' 519 sxs Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations· Present well condition summary Total depth: measured 11699 feet Plugs(measured) i"',:"~ ;~ ~'~ FY true vertical 6040 feet Effective depth: measured 11589 feet Junk (measured),~¢.~,~ ~t(~._" ;' true vertica 5998 feet ~ Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 16" 216 sx AS Ill 115' 115' Surface 3973' 9-5/8" 1050ax ASIII, 600 sx Class G 4008' 2977' Intermediate Production 11,643' 7" 225 sx Class G 11678' 6032' Liner Perforation depth: measured 11222'-11330' MD ORIGINAL true vertical 5857'-5900' TVD 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch Drilling program X Ddlling fluid program X . Time¥s depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21.1 hereby certify that the for~goin2~'"~rue/and correct to the best of my knowledge (Contact William Isaacson at 263-4622 with questions.) Signed ~_~////f '/~-CommissionTitleuse Only D ri I ling Superintendent Date Permit Number AF~umb~r Approval date ,=,.-.-.-.-.-.-.-.%~ ,,.,i ~ ....z I See cover letter for ~¢~--- O0~)-~/~.~'~ ~ "~/'50-/'0 ~- ~ O J~ 00 '0~ -,~//~Oy)l~ other requirements approval Samples required Yes __ No X Mud Icg required Yes __ No Conditions of Hydrogen sulfide measures Yes ~ No__ Directional survey required Yes _~ No __ · Required working pressure forBOPE 2M __ 3M __ 5M X 10M __ 15M __ Other: David0riginaIW, Signed By Johnston byorder of Approved by Commissioner the commission Date . Form 10-401 Rev. 7-24-89 , ~nit in triplicate REDRILL PLAN SUMMARY Well 3G-21A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location' MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: producer 2538' FNL, 195' FEL, SEC 23, T12N, R8E, UM 491' FSL, 39' FWL, SEC 26, T12N, R8E, UM 69' FSL, 73' FWL, SEC 26, T12N, R8E, UM 12,574' 5936' Nordic Rig 2 4-1-98 11 Drill Fluids Proqram: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Window in 7" casing 9.6 >25 15-35 85-95 20-30 30-40 __ 8.5-9.5 Kick off to weight up 9.6-9.7 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 12.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page I Casing/Tubing Program: Hole size Csgfrbg 6-1/8" 3-1/2", 9.3#, L-80, EUE-Mod Tubing 3-1/2", 9.3#, J-55, EUE-Mod Length Top (MDrFVD) Btm (MD/I'VD) 2855' 9719'/5193' 12574'/5936' 9690' 29'/29' 9719'/5193' Cement Calculations: Casing to be cemented: 3-1/2" in 6-1/8" open hole Volume = 519 sxs of class G Blend @ 1.19 cu flYsx Based on: Shoe volume, open hole volume + 52%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working 'pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2957 psi and is calculated using a gas column to surface. The expected leak-off at the window cut in the 7" casing is estimated at 14.0 ppg EMW. With an expected formation pressure in the Kuparuk of 3600 psi and a gas gradient of 0.11 psi/fi, this shows that formation breakdown would not occur before a surface pressure of 2957 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drillinq Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K-10 and K-5 intervals. The sidetrack 3G-21A, will kick off out of the 7" casing below both the K-10 and K-5 intervals. The 7" casing is not expected to have cement at the planned kick-off window. If the Formation Integrity Test shows that the K-10 and K-5 intervals are not isolated and will not hold the desired equivalent mud weight, a cement squeeze at the window could be performed to help isolate these intervals. Off-set drilling data shows that wells in the area of 3G-21A have been drilled to TD with 12.4 ppg mud and no loses. The kick-off point in 3G-21A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 9869' MD / 5260' TVD 76.5° (in sidetrack portion) No Hazards 69.6° (in original portion) Page 2 Logging Program: Open Hole Logs: Cased Hole Logs: GR/Resistivity GR/CCL Notes: All drill solids generated from the 3G-21A sidetrack will be hauled to CC-2A in Prudhoe Bay for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 3G-21A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU slickline unit. RIH and dummy-off entire gas lift string. 2. RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in tubing tail immediately below production packer. Mix cement. Circulate the cement dow. n coil to immediately above circulating valve on top of retainer. Close circulation valve and down-squeeze cement below retainer into A & C Sand perfs. Use sufficient volume to fill tubing down through tubing tail and 7" casing from top of fill to tubing tail, plus excess to squeeze away into perfs. Unsting from retainer and circulate well clean on top of inflatable retainer. RDMO CTU. 3. RU slickline unit. RIH and pull dummy valve from GLM at 11,037' MD RKB, leaving an open pocket. WORKOVER RIG WORK: 1. MIRU Nordic Rig 2. Lay hard-line to tree. 2. Verify well is dead. Load pits w/water. Circulate well to water. 3. Set BPV. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH standing back tubing and laying down all jewelry. 5. PU Baker 7" 'N-I' permanent bridge plug on E-line. RIH and set bridge plug at 9894' MD RKB. POOH RD E- line. Test wellbore to. 3500 psi, testing bridge plug and cement plug to ensure isolation from perforations. 6. MU and RIH with bottom trip whipstock and window milling assembly. Tag bridge plug and set down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and mill window in 7" casing. POOH LD milling assembly. RIH w/6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off well, and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. Run 3-1/2" liner to TD w/150' of overlap to top of milled window. Cement liner. Set liner hanger and liner top packer. POOH w/DP. 10. Pressure test casing and liner lap to 3500 psi for state test. 11. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. Clean out well to PBTD w/coiled tubing. Perforate through tubing. , . . 12. 13. Lower Limit: 9 days Expected Case: 11 days Upper Limit: 18 days No problems milling window, drilling new hole, or running completion. Difficulties encountered milling window, or drilling new hole. WSI 3/5/98 Page 4 CreoteU ',y .nc. For: B ISAACSON Date plotted : 25-Feb-98 Plat Reference ;a 2lA Vets;on J~9. I rru;O~er;[;;tejep~r; ;n feet refer~:c~K~l~tN~dli~ JI)'I 176.48 AZIMUTH 7207' (TO TARGET) · *=Plane of Proposal*** TARGET ANGLE 76.53 DEG 5000 5200 5400 5600 5800 6000 I V 6200 ARCO Alaska, Inc. Structure : Pad 56 Well: 21A Field : Kuparuk River Unit Location : North Slope, Alaska -. <- West (feet) 6400 6200 6000 5800 5600 5400 5200 5000 4800 4600 I I I I I I I I I I I } I t I I t ' ~ SURFACE LOCATION: 2538' FNL, 195' FEL SECi 23, T12N, R8E 7 Casing EOC TARGET LOCATION: 491' FSL, 39' FWL SEC. 26, T12N, RSE TARGET TVD=5801 TMD=119g6 0EP=7207 SOUTH 7551 WEST 5046 Base HRZ K- 1 Marker · 52CC I - 5400 r' 5600 -5800 L TARGET - Top Unit C41 ½ } A5 Interval A2 Interval y 7600 Interval i 7800 l Bose Kup Sands [8000 [ m,oc^r,ON: l x/x~ I69' FSL. 73' FWL v-....~.~x . [ SEC. 26, T12N, ESE j - Casing Pt 64.13~x'~'KOP - 7" CSG PT TVl]=5260 TMD=9869 DEP=§I78 -~.c~2~ ~ DLS: 10.00 deg per 100 ft ~-8200 74.37~DEP=5510 b ~ ~5631 TMD=11266 DEP=6498 RKERTVD=5749 TMD=11775 DEP=6990 MD= 12374 DEP=7575 TI) - CSG PT 'C~D=5936 TMD=12574 DEP=7769 i i i i i i i i i i i [i i i ii i i i ii i i i i i i i i 5000 5200 5400 5600 5800 6000 8200 6400 6600 6800 7000 7200 7400 7600 7800 Vertical Section ~feef) -> Azimuth 176.48 with reference 0.00 N, 0.00 W from slot #21 6000 6200 I6400 O (" 6600 680O i7o00 I V t7200 7400 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST 6 PIPE RAM 5 BLIND RAM~= I MUD ~ CROSS 4 I' 3 PIPE RAM ~ 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. I~,oP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THATTEST 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 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE lINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL lINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 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 BO'I-rOM PIPE RAMS. TEST BO'I-i'OM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2, 11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16"- 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16" - 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSI SINGLE GATE W/BLIND RAMS 6. 7-1/16" - 5000 PSi SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER NORDIC RIG ~f2 LEVEL 1 z 12'-4' I'nRES: 40-57 il! 28'-6" 73'-0' 4 II ~ SPIRAL STAIRS - EMSCO F-800 TRIPLEX MUD PUMP .: ..-- 25'-0' 40--57 I EMSCO F-800 1 (~ TRIPLEX MUD I PUMP SPIRAL .t STAIRS - coNTRoL ~CONSOLE i 36'-0' 53'-0' , ! I NORDIC RIG LEVEL · ~ MUD TANK HoPP~I~"rl 750 BR A~MU~R 80 HP C~ BROOKS BOI~ STAIRS MODULE /I ucc PARTS BINS 123'-0' HOIST · NORDIC RIG LEVEL USTE::R AIR HEATER MUD TANK 75O BBLS SPIRAL I(:HO WATER TANK /GLYCOL TANK 15'-7' 15'-6" H'YDR^UUC 15'-6' 7'-11' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS l.jTypej f Request: Abandon X_~ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing _ Repair well _ Plugging X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate_ Other .~.X Plugback for Redrill I 5. Type of Well: i 6. Datum elevation (DF or KB) 2. Name of Operator i Development ~ ARCO Alaska, Inc. i Exploratory _ ! 90' RKB, Pad 53' GL feet 3. Address i Stratigraphic _ I 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 ~ Service I Kuparuk River Unit i -- I 4. Location of well at surface i 8. Well number 2538' FNL, 195' FEL, Sec. 23, T12N, RSE, UMI, 3G-21 At top of productive interval I 9. Permit number 1585' FSL, 728' FEL, Sec. 27, T12N, RSE, UM~ 90-148 At effective depth I 10. APl number 1344' FSL, 929' FEL, Sec. 27, T12N, R8E, UM i 50-103-20148 At total depth I 11. Field/Pool 1241' FSL, 1016' FEL, Sec. 27, T12N, R8E, UM . Kuparuk River 12. Present well condition summary Total Depth: measured 11,699 feet Plugs (measured) None (approx) true vertical 6040 feet Effective depth: measured 11,588 feet Junk (measured) (approx) true vertical 5998 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 16" 216 sx AS III 115' 115' Surface 3973' 9 5/8" 1050 sx AS III 4008' 2977' Intermediate & 600 sx Class G Production 11,643' 7" 225 sx Class G 11,678' 6032' Liner Perforation depth: measured 11222'-11330' true vertical 5857'-5900' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 11,123' Packers and SSSV (type and measured depth) Baker 'FHL' Retr. Pkr @ 11,098' MD, Camco 3-1/2" 'TRDP-1AENC' SSSV @ 1@06' MD 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch Contact William Isaacson at 263-4622 with any questions. 14. Estimated date for commencing operation ! 15. Status of well classification as: March 15, 1998 ! Oil X Gas _ Suspended _ 16. If proposal was verbally approved Name of ap.p.r~ver Date approved ! Service ~ 7. I hereby certif~ tha~fle foregoing is true and correct to the best of my knowledge. Signed ~/- [ Date " Title Drilling Superintendant '~- ~ -J L? ~,'"~ ' FOR COMMISSION USE ONLY Conditions of approval: N?tify Commission so representative may witness IApproval No. Plug integrity--'" BOP Test Location clearance I Mechanical Integrity Test ~ Subsequent form require 10-~ Approved by the order of the Commission k~' (~ '0' Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE · WELL PERMIT CHECKLIST COMPANY I~(,0 WELLNAME ~ ~ '"~] ~ PROGRAM:expDdevrqredrll,j~servF'lwellboresegE:ann. disposalparareql'i FIELD&POOL H ~ 0 1~0 INIT CLASS O't~U I - O~ I GEOLAREA C~ C~ 0 UNIT# 1 1 l (¢ ~ ON/OFF SHORE, ADMINISTRATION 1. Permit fee attached ....................... ~) N 2 Lease number appropriate ................... ~~, N 3. Unique well name and number ................ N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... ~ N 6. Well located proper distance from other wells .......... ~ N 7. Sufficient acreage available in drilling unit ........... (~ N 8. If deviated, is wellbore plat included ............ (~ N 9. Operator only affected party ...... (~. N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ...... l~ N 12 Permit can be issued without administrative approval. ~ N 13. Can permit be approved before 15-day wait ........... N ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... _(~ N 19. Casing designs adequate for C, T, B & permafrost ...... (~ N 20. Adequate tankage or reserve pit ................ N 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. DOPEs, do they meet regulation ................ (2~ N 26. DOPE press rating appropriate; test to .:~::::~'"~ psig. (~ N 27. Choke manifold complies w/APl RP-53 (~/lay 84) ........ (~ N 28 Work will occur without operation shutdown ........... (~ N 29 Is presence of H:,S gas probable ................. (~ N GEOLOGY 30 Permit can be issued w/o hydrogen sulfide measures.~....,,..,.,,~. Y N 31. Data presented on potential overpress~ ..... Y N 32. Seismic analysis of shallow~.g,.a,s.~-.~re"~. ........... Y N 33. Seabed cond~ off-shore) ............ Y N 34. Cont~onefor we_eklyprogress reports ....... Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION' RPC___~_ BEW__ DWJ~ JDH RNC~ CO LO ~'!1~, Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Sun Jun 14 13:10:30 1998 Reel Header Service name ............. LISTPE Date ..................... 98/06/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Tape Header Service name ............. LISTPE Date ..................... 98/06/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services 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: ELEVATION (FT MWD RUN 2 AK-MM-80230 E. CRIBBS D. WESTER FROM MSL 0) 3G-21A 501032014801 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 14-JUN-98 23 12N 08E 2538 195 JUN 1 9 1996 Oil & Gas Cons. Commission KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS:' 85.10 83.60 53.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT)' 16.000 115.0 9.625 4009.0 7.000 9860.0 6.125 12960.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS AND DEPTH SHIFTING OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN STEVE MOOTHART OF ARCO ALASKA, INC. AND A. TURKER ON 06/10/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTIONAL ONLY TO SET A WHIPSTOCK AND IS NOT PRESENTED. TOP OF WHIPSTOCK SET AT 9860'MD, 5260'TVD (KICK-OFF POINT). 4. MWD RUN 2 IS DIRECTIONAL WITH ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 5. MWD RUN 2 REPRESENTS WELL 3G-21A WITH API # 50-103-20148-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12960'MD, 5988'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 ....... 98/06/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9841.0 RPD 9860 5 RPM 9860 5 RPS 9860 5 RPX 9860 5 FET 9863 5 ROP 9865 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 12907.5 12914.5 12914.5 12914.5 12914.5 12914.5 12960.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 9893.0 12960.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPD MWD OHMM 4 1 68 16 5 RPX MWD OPZMM 4 1 68 20 6 RPM MWD OHMS4 4 1 68 24 7 FET MWD OHM/~ 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 9841 12960 11400.5 6239 9841 Last Reading 12960 ROP 2.283 1624.84 71.9836 GR 33.874 571.701 152.561 RPS 0.1072 2000 12.8886 RPD 0.065 2000 20.4889 RPX 0.1109 2000 19.7836 RPM 0.1127 2000 23.6803 FET 0.6015 21.8282 1.5865 6191 6134 6109 6109 6109 6109 6103 9865 9841 9860.5 9860.5 9860.5 9860.5 9863.5 12960 12907.5 12914.5 12914.5 12914.5 12914.5 12914.5 First Reading For Entire File .......... 9841 Last Reading For Entire File ........... 12960 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/14 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 ....... 98/06/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9841.0 RPD 9860.5 RPM 9860.5 RPS 9860.5 RPX 9860.5 FET 9863.5 ROP 9865.0 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 12907.5 12914.5 12914.5 12914.5 12914.5 12914.5 12960.0 19-MAY- 98 S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REA_L-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL ,STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 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 (OHMS) 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 ....................... ISC 5.07 DEPII 2.22A / SP4 5.03 MEMORY 12960.0 9893.0 12960.0 66.6 80.5 TOOL NUMBER P0882SP4 P0882SP4 6.130 6.1 LSND 11.40 43.0 9.5 1200 4.5 1.450 .710 1.650 1.500 65.6 .6 Datum Specification Block sub-type...0 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 2 FT/H 4 1 68 MWD 2 API 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMM 4 1 68 MWD 2 OHMS4 4 1 68 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 Name Min Max Mean DEPT 9841 12960 11400..5 ROP 2.283 1624.84 71.9836 GR 33.874 571.701 152.561 RPX 0.1109 2000 19.7836 RPS 0.1072 2000 12.8886 RPM 0.1127 2000 23.6803 RPD 0.065 2000 20.4889 FET 0.6015 21.8282 1.5865 Nsam 6239 6191 6134 6109 6109 6109 6109 6103 First Reading 9841 9865 9841 9860.5 9860.5 9860.5 9860.5 9863.5 Last Reading 12960 12960 12907.5 12914.5 12914.5 12914.5 12914.5 12914.5 First Reading For Entire File .......... 9841 Last Reading For Entire File ........... 12960 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/06/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/06/14 Scientific Technical Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Physical EOF Physical EOF End Of LIS File