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196-102
• • /2-.61-c 3c1 WELL LOG TRANSMITTAL# DATA LOGGED �i/t t�/201�j iv1.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 5, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ` CAN i i E RE: Leak Detect Log with TMD3D: 3F-19 Run Date: 9/28/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3F-19 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-22680-00 Leak Detect Log with TMD3D (Field print) 1 Color Log 50-029-22680-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn; Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MA/2-04-40,017) 6.eivefir WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. S/ o?' Well History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # - 0 Diskettes - # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No 0 Mud Logs # 0 Other # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged U Abandoned W Suspended U WAG 0 20AAC 25.105 20AAC 25.110 No. of Completions - Other - GINJ 0 WINJ 0 WDSPL 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 37' FSL, 124' FEL, Sec. 19, T12N, A9E, UM At Top Productive Horizon: 690' FNL, 301' FEL, Sec. 19, T12N, A9E, UM Total Depth: 379' FNL, 334' FEL, Sec. 19, T12N, A9E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 508376 y- TPI: x- 508177 y- Total Depth: x- 508141 y- 18. Directional Survey: Yes D No~ 5985860 5990412 5990726 Zone- 4 Zone-4 Zone- 4 21. Logs Run: 5. Date Comp., Susp., or Aband.: February 5,2004 6. Date Spudded: June 22, 1996 7. Date TD Reached: June 29,1996 8. KB Elevation (It): 30' AKB 1 54' AMSL 9. Plug Back Depth (MD + TVD): 3538' MD 12896' TVD 10. Total Depth (MD + TVD): 8132' MD 16290' TVD 11. Depth where SSSV set: Landing Nipple @ 510' 1b. Well Class: Development 0 Exploratory D Service 0 Stratigraphic Test 0 12. Permit to Drill Number. .I 196-102/304-014 13. API Number: 50-029-22680-00 14. Well Name and Number. 3F-19 15. FieldlPool(s): Kuparuk Aiver Field Kuparuk Aiver Oil Pool 16. Property Designation: ADL 25632 17. Land Use Permit: ALK 2565 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: CASING SIZE 16" 7.625" GRADE H-40 L-80 CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 121' Surface 3986' HOLE SIZE CEMENTING RECORD 24" 260sxASI 9.875" 1060 sx AS III, 330 sx Class G 22. WT. PER FT. 62.5# 29.7# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number, if none, state "none"): 7644'-7654' MD 7852'-7872' MD 5908'.5915' TVD 6069'.6084' TVD 26. Date First Production Date of Test Hours Tested OIL-BBL Form 10-407 Revised 2/2003 1380' 55 AMOUNT PULLED CIBP @ 7000' kick off plug from 3615'-4435' ,/ 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 7553' PACKER SET (MD) nla 25. ACID, FRACTURE. CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 3615'-4435' 168 5X 17.0 ppg Class G WATER-BBL GAS-MCF WATER-BBL PRODUCTION TEST Method of Operation (Flowing. gas lilt. etc.) abandoned Production for OIL-BBL GAS-MCF Test Period --> Flow Tubing Casing Pressure Calculated press. psi 24-Hour Rate -> 27. CORE DATA Brief description of lithology. porosity, fractures. apparent dips and presence of oil, gas or water (attach separate sheet. if necessary)'RECE '- Submit core chips; if none. state 'none". ¡ '1.~~t..1 , ." --.,..,! \72 ~ ~ ~~ ~ ..k~ ,-(¿'I- ¡ " r \ø..~Jr NONE i ";tf} I ~ c> "'1ì 1ft- <fy{) fil ~ :.:C-.:'- '=' CONTINUED ON REVERSE SIDE CHOKE SIZE IGAS-OIL RATIO OIL GRAVITY. API (corr) not available '-~ MAY 1 0 ?OO4 Alaska Oil & Gas Lei. ~ ~.."..¡ssion Anchorage ABOMS 8FL Submit in duplicate MAY 1.~ 'lUU~ ~ ý' 29. FORMATION TESTS 28. GEOLOGIC MARKERS NAME MD TVD Include and briefly summarize test results. List intervals tested. and attach detailed supporting data as necessary. If no tests were conducted, state "None" . 3F-19 N/A RECEIVED MAY 1 0 2004 Alaska Oil & Gas Cons. Comm¡::i¡',I.HI Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kel~y McL re@265-605!h ...\ .~t'jú..v..>- ,,-;;l"-uf printed Na~ .. B¡~hom~s Title: Signature \ ~ \ \. ~Phone Kuparuk Team Leader "7..bS- ~-B ~O Date r!;"l (. árr Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). \tem 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1. and in item 23 show the producing intervals for only the interval reported in item 26. (submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of operation: Flowing, Gas Lift. Rod Pump. Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none. state "None". O~\G'NAL Form 10-407 Revised 2/2003 TUBING (0-2407. OD:3.500, ID:2,992) PLUG (7000-7012. OD:5.500) FISH (7480-7481. OD:1,500) FISH (7481-7483, OD:1.000) NIP (7533-7534. OD:3.500) LOCATOR (7541-7542. OD:3,500) TUBING (7012-7553. OD:3.500. ID'2.992) m (7553-7554. OD'3,500) Perf (7644-7654) Perf (7852-7872) ConocoPhillips Alaska, Inc" 3F~19 %I 4 I!Ii :J 7852 - 7872 6069 - 6084 A-3 ~as L.Ift:MàRdrelSA/äÞìês. ' . St I MD I TVD I ~~~ I Man Type I 1 7480 5781 BST AXT 1. Broken Latch Other,,(plu!:.Is,:j,qUi'P;¡etc:) . JEWELRY , Depth TVD Type 510 508 NIP 7000 5407 PLUG 7533 5822 NIP 7541 5828 LOCATOR 7553 5837 TTL -Flšh':FISH- Depth I 7480 FISH 7481 FISH GeßèrarNÓ\es Date Note 12/9/1998 Dropped 1.875" roller in rat hole. 8/29/2001 UNABLE TO PASS 2.52" GAUGE RING BELOW 7330' DUE TO BARIUM SCALE 8/30/2001 UNABLE TO PASS A 1.99" BROACH BELOW 7560' DUE TO BARIUM SCALE. 5/4/2002 WORKOVER - UNABLE TO PULL TBG BELOW TBG CUT. SET PLUG & SECURED WITH 13.3 PPG MUD. FP'D, TEMPORARY ABANDONMENT. API: 500292268000 SSSV Type: NIPPLE Annular Fluid: Reference Log: Last Tag: 7867 Last Tag Date: 7/1212000 Cå$iÀgî$tôncr ..;ÁL:l&'I'RING$ Description CONDUCTOR SUR. CASING PROD. CASING LINER Tilblríg ;$tñ"g~ dUSING', Size I Top 3.500 0 3.500 7012 Pinoiãtlons:SUmmàiY,¡ Interval TVD 4180-4182 3352-3353 4390 - 4392 3501 - 3503 7644 - 7654 5908 - 5915 .. Description KRU 3F-19 Well Type: PROD Orig 8nt1996 Completion: Last W/O: Ref Log Date: TD: 8132 ftKB Max Hole A~gle:.. 46 deQ,(â) 4764 Size 16.000 7.625 5.500 3.500 Angle @ TS: 40 deg (â) 7628 Angle @ TD: 36 deg @ 8132 Rev Reason: PERFS Last Update: 1/30/2004 Bottom 2407 7553 Top Bottom TVD Wt Grade Thread 0 121 121 62.50 H-40 0 3986 3214 29.70 L-80 0 7549 5834 15.50 L-80 7549 8127 6286 9.30 L-80 " , TVD [ Wt [ Grade I Thread 2098 9.30 L-80 EUE8RD 5837 9.30 L-80 EUE 8RD MOD .. Zone Status Ft SPF 2 4 2 4 10 4 Date Type Comment 1/28/2004 APERF 2.5" DMY Gun 1/28/2004 APERF 2.5" DMY Gun 2/3/1999 APERF 180 deg. phsg +1- 90 deg.; 2.5" HC, DP 8nt1996 IPERF 180 deg. phasing, 2 1/2" BH C-4 20 4 . , '" V Mfr I V Typ~ I V OD Latch " Port I -fRO I ~~: I C~~t DMY I 1.0 T1 0.000 0 2/17/1999 (1) Description NO-GO Cameo 'DS' Landing Nipple CIBP SET 5/4/2002 NO-GO Cameo 'D' landing Nipple. Broached scale to 2.74" to 7533 on 8/30/99; broached seale to 2.74" to 7860 on 10/17/99 Baker 'GBH-22' Locator ID 2.812 0.000 2.750 3.000 2.992 ... , I Comment 2.74" SWAGE WIXO LOST, STUCK IN GLM #5 9/6/01 1" BROKEN LATCH LOST 9/6/01 - - , , Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/1/2004 00:00 - 00:15 0.25 MOVE SFTY MOVE Held PJSM on moving rig over well and hazards with moving rig between 2 wells, cold weather and slick pad. NOTE: Moved rig from 10 pad to F pad 1-31-04 and cont to prep rig for acceptance while wells group removed 2 Thermo Syphons by well 00:15 - 01:30 1.25 MOVE OTHR MOVE Layed out liner around well and set in rigs cellar mats 01 :30 - 02:30 1.00 MOVE MOVE MOVE Moved rig 250' down F pad and spotted over we1l3F-19A 02:30 - 09:00 6.50 MOVE RURD RIGUP Leveled rig, built berm and spotted cuttings box, took on seawater in pits, welder cont to build new door for mud pits 09:00 -11:30 2.50 WELCTL OTHR RIGUP Held PJSM with crew and valve group, pulled VR plug, RU lubricator and pulled BPV, SITP 540 psi, SICP 540 psi, OA 500 psi 11:30 -14:00 2.50 MOVE RURD RIGUP RU circ lines in cellar and pressure tested lines to 3,500 psi, welder completed installing new door between mud pits and pump room 14:00 - 16:00 2.00 MOVE OTHR RIG UP Pressure tested mudline to 500/3,500 psi, had leak at 1,500 psi and replaced seal on 4" valve, retested and ck ok, pressure tested standpipe to 500/5,000 psi and ck ok 16:00 - 16:15 0.25 MOVE SFTY RIGUP Held PJSM, discussed with rig crew on the hazards of circ out diesel to tank, trapped pressures and spills. Use good communication 16:15 - 17:30 1.25 MOVE RURD RIGUP Blew air thru lines prior to circ out diesel and found 2 lines with ice plugs, thawed lines and rechecked lines 17:30 - 18:00 0.50 DRILL CIRC DECOMP RU & Circ out freeze protect diesel with seawater thru 3 1/2" kill string at 2,407', circ 1 1/2 x cap 18:00 - 19:00 1.00 DRILL OTHR DECOMP Allowed well to U-tube diesel from below kill string, Held Pre Spud/PJSM with rig crew on upcoming operations 19:00 - 20:00 1.00 DRILL CIRC DECOMP Circ an addition hole cap from 2,407' with seawater to help circ out diesel, blew down lines 20:00 - 20:30 0.50 WELCTL OTHR DECOMP Installed BPV 20:30 - 22:00 1.50 WELCTL NUND DECOMP Held PJSM, ND tree and set outside cellar, NORM Tree & ck ok 22:00 - 22:30 0.50 WELCTL OTHR DECOMP Installed FMC blanking plug 22:30 - 00:00 1.50 WELCTL NUND DECOMP Began NU 11" 5M BOP stack, installed 71/16" 5M x 11" 3M Spool and set on stack and cont NU BOPE NOTE: ACCEPTED RIG at 12:00 Hrs 2-1-04 2/212004 00:00 - 05:00 5.00 WELCTL NUND DECOMP Fin NU 11" 5M BOP stack on 71/16" 5M x 11" 3M Spool, found 1 stud too short on 11" flange on btm of stack and changed out 05:00 - 12:30 7.50 WELCTL BOPE DECOMP Note @ 06:00 was informed that a floorhand had hurt his foot while working on rig at 10 pad on 1-29-04, sent hand to KUP clinic and was treated as a first aid, hand then went to town on days off and was to see an doctor in town RU and tested all valves, manifold, rams and annular to 250 psi low and 3,000 psi high per AOGCC permit. At start of BOP test OA press 175 psi, IA 175 psi, bled OA to -0- and cont to monitor and bleed off, IA press increased to 250 psi while testing, bled off press and gained 8 gals with -0- press Note: John Crisp with AOGCC witnessed test Held safety meeting with rig crew and Tom Sanchez, CPAI safety rep and discussed importance of reporting accidents no matter how small as soon as they occur RD BOP testing equipment and blew down all lines and manifold Repaired leak on btm flange of riser Pulled BPV, backed out LDS and PU 40K up wt and PU and unlande hanger, no problems 12:30 - 13:00 0.50 WELCTL SFTY DECOMP 13:00 - 14:00 14:00 - 16:30 16:30 - 17:00 1.00 WELCTL OTHR DECOMP 2.50 RIGMNT RGRP DECOMP 0.50 DRILL PULD DECOMP Printed: 4/15/2004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/2/2004 17:00-18:00 1.00 DRILL CIRC DECOMP 18:00 - 21:00 3.00 RIGMNT RGRP DECOMP 21 :00 - 00:00 3.00 DRILL PULD DECOMP 2/3/2004 00:00 - 01 :30 1.50 DRILL CIRC DECOMP 01 :30 - 02:00 0.50 DRILL CIRC DECOMP 02:00 - 03:00 1.00 DRILL CIRC DECOMP 03:00 - 03:30 0.50 DRILL OBSV DECOMP 03:30 - 04:30 1.00 DRILL CIRC DECOMP 04:30 - 08:00 3.50 DRILL TRIP DECOMP 08:00 - 09:30 1.50 DRILL TRIP DECOMP 09:30 - 09:45 0.25 DRILL DEQT DECOMP 09:45 - 10:30 0.75 DRILL TRIP DECOMP 10:30 - 12:00 1.50 WELCTL BOPE DECOMP 12:00 - 20:00 8.00 WELCTL NUND DECOMP 20:00 - 22:00 2.00 WELCTL NUND DECOMP 22:00 - 00:00 2.00 RIGMNT RGRP DECOMP 2/4/2004 00:00 - 04:00 4.00 RIGMNT RGRP DECOMP 04:00 - 05:30 1.50 WELCTL NUND DECOMP 05:30 - 07:00 1.50 WELCTL CIRC DECOMP 07:00 - 07:30 0.50 WELCTL BOPE DECOMP 07:30 - 09:00 1.50 DRILL TRIP DECOMP 09:00 - 10:00 1.00 DRILL TRIP DECOMP 10:00 - 10:15 0.25 LOG SFTY DECOMP 10:15 - 12:15 2.00 LOG ELOG DECOMP 12:15 - 14:15 2.00 LOG ELOG DECOMP 14:15 - 17:00 2.75 LOG ELOG DECOMP 17:00 - 18:00 1.00 FISH FISH DECOMP 18:00 - 20:00 2.00 FISH FISH DECOMP Circ out approx 10-20 bbls of diesel that had swapped while testing BOP's, circ hole clean with seawater, blew down lines and PU & LD Hanger, found riser had a slight leak at btm flange Repaired riser flange, attempted to tighten with no success, removed flange and resealed and checked ok TIH with used 3 1/2" Kill string while PU new 3 1/2" 9.3# L-80 Tbg, TIH to 4,371', had calc displacement on TIH, OA bled down to -0- psi Washed down from 4,371' to 4,402', circ btms up at 31/2 bpm, 400 psi, at btms up had gray water only, no cement or mud Washed down from 4,402 and tagged hard cement at 4,435', set 15K down on plug Circ hole clean at 4,435' with seawater, circ 1.5 x hole cap at 4 bpm, 600 psi, st wt 52K, dn wt 45K Monitored well-static, OA -0-, keeping bled down thru bleed down tank with very little returns out OA Circ btms up with very little gray water at btms up, circ at 4 bpm 550 psi POOH with 3 1/2" tbg, strapped last 25 stds out, LD "DS' nipple MU Baker 51/2" retrievable bridge plug and RIH, set BP at 982', st wt up 29K, 27K dn Pressure tested BP to 1,000 psi for 15 min & ck ok POOH & LD Baker setting tool MU test plug on 5 1/2" test it. RIH & set, pressure tested lower pipe rams to 250 psi low, 3,000 psi high, POOH & LD test it and blew down lines ND BOP's & 71/16" 5M x 11" 3M Spool, ND tbg head and removed same with no problems, removed 51/2" csg pack-off, tack welded slips to csg and dressed off 5 1/2" csg, installed new FMC pack-off NU 11' 3M x11" 5M spool, NU BOP's, choke and kill lines, unable to MU kill line, couldn't find 3" Grayloc seal ring for kill line Waiting on 3" Grayloc seal ring for kill line to be delivered to rig Waited on new 3" Grayloc seal ring for kill line to arrive from Nordic rig 2 @ Endicott Fin NU kill line and riser, filled hole and seawater was coming out OA due to seals on pack-off not energized RU to circ, pumped down csg and around pack-off and energized pack-off Tested 11' 3M flange, choke and kill lines to 250 psi and 3,000 psi MU Baker retrieving tool and RIH to 982' and latched onto bridge plug and released, monitored well 15 min while allowing elements to relax and hole was static POOH and LD bridge plug and retrieving tool Held PJSM with rig crew and Schlumberger wireline (SWS) on RU and running string shot and chemical cutter RU SWS, MU 4.77" gauge ring/junk basket and RIH, tagged btm at 4,449' WL, POOH MU 14' string shot and RIH, set off string shot from 4,163' to 4,177' to clean off ID of csg and POOH MU 4 9/16" Pipe Recovery chemical cutter and RIH, cut 51/2" csg at 4,175', corr log back to perf log ran 1/28/04, saw both sets of perfs shot previously, POOH & RD OA -0- psi MU Baker 51/2" Csg spear with pack-off, RIH to 28' and speared 51/2' csg pack-off, POOH & LD pack-off RIH and speared 5 1/2" csg at 29', PU and began working 5 1/2" csg, Printed: 4115/2004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/4/2004 18:00 - 20:00 2.00 FISH FISH DECOMP pulled slips up out of csg head, worked csg up to 300K up wt with no movement, +1- 67" of stretch, calc csg wt 65K, pressured up on csg staging press up to 1,000 psi with no drop in pressure, no change when working pipe with or without press, released spear, POOH and LD 20:00 - 22:15 2.25 FISH ELiN DECOMP RU SWS and RIH with 13' string shot and set off same at 4,074' to 4,087', POOH 22:15 - 00:00 1.75 FISH ELiN DECOMP MU 4 9/16' chemical cutter and RIH, cut 51/2" csg at 4,085', started POOH 2/5/2004 00:00 - 00:45 0.75 FISH ELiN DECOMP Fin POOH with e-line after chemical cutting 5 112" csg at 4,085' WL, RD SWS 00:45 - 02:00 1.25 FISH FISH DECOMP MU 5 1/2" csg spear, RIH to 29' and engaged csg, worked csg up to 300K up wt while working pump pressure up to 1,000 psi, worked csg free, pulled spear to rig floor with 90K up wt and found 1/2 of outer csg slips missing 02:00 - 02:30 0.50 FISH PULD DECOMP Released spear from 51/2" csg and LD 02:30 - 03:00 0.50 FISH RURD DECOMP RU GBR's tongs & elevators 03:00 - 04:00 1.00 FISH PULD DECOMP PU to 1 st connection and recovered slip segement, LD cut piece with slips tack welded onto csg and MU safety valve on 5 1/2" csg, broke out spear, then MU pump in sub 04:00 - 07:30 3.50 FISH CIRC DECOMP Est circ at 1 bpm at 40 psi, (freeze protect diesel u-tbg), staged pump rate up to 4 bpm at 200 psi, circ 2x btms up with seawater, no heavy mud back at btms up, displaced hole from seawater to new 9.8 ppg LSND mud, circ hole at 4 bpm at 320 psi, reciprocated pipe with 78K up wt and 57K dn wt, circ till hole clean with 9.8 ppg mud in & out 07:30 - 16:00 8.50 FISH PULL DECOMP POOH LD 93 its of 51/2' 15.5# L-80 EUE LTC csg, 1-cut piece and 17 stright blade centralizers, total pipe recovered 4,043.40', NORM csg and ck ok, didn't have thread protectors for LTC pipe, plugged both ends with absorbant then covered with plastic bags, backloaded csg onto truck and sent to Tuboscope, RD GBR's tools 16:00 - 18:00 2.00 CEMENTTRIP DECOMP MU 3 1/2" mule shoe and RIH with 3 1/2" tbg to PBTD 4,435' 18:00 - 20:30 2.50 CEMENTCIRC DECOMP Circ hole clean and conditioned mud to 9.8 ppg in & out, staged pump rate up to 5 bpm at 500 psi, mixed weighted hi vis pill 20:30 - 21:15 0.75 CEMENTCIRC DECOMP Pumped and spotted balanced 12 bbls of 12.1 ppg weighted hi vis pill / 21:15 - 21:45 0.50 CEMENT TRIP DECOMP POOH from 4,435' to 4,298', LD 2 singles of 31/2" tbg 21:45 - 22:45 1.00 CEMENTCIRC DECOMP Circ btms up monitoring for wt'd pill and didn't see any pill at btms up circ hole at 4 bpm at 350 psi, held PJSM with Dowell & rig crew on pumping cmt plug and batch mixed cmt 22:45 - 23:15 0.50 CEMENT PUMP DECOMP Tumed over to Dowell, pumped 5 bbls FW, tested lines to 3,500 psi, pumped add. 5 bbls FW, followed with 30 bbls, 168 sxs of 17.0 ppg, 1.0 ,/ yield class "G' cmt with additives and 2.5 bbls FW behind, tumed over to rig and displaced cement to balance plug with 24.5 bbls of 9.8 ppg mud, ave 4 bpm at 600 psi, slowed rate last 3 bbls, CIP at 23:15 hrs, calc TOC in gauge hole 3,538' ./ 23:15 - 00:00 0.75 CEMENTTRIP DECOMP POOH slow from 4,298' to 3,615', plug balanced 2/6/2004 00:00 - 01 :30 1.50 CEMENT CIRC DECOMP Circ hole clean at 3,615' after setting balanced cement kick-off plug, staged pump rate up to 6 bpm at 450 psi, at btms up had 20 bbls of cement contaminated mud back, max wt 10.3 ppg, MW going in 9.8 ppg, blew down lines 01 :30 - 02:00 0.50 RIGMNT RGRP DECOMP Repaired middle boot on riser 02:00 - 06:30 4.50 DRILL PULD DECOMP POOH & stood back 9 stds of new 31/2' 9.3# L-80 EUE-M tbg (22 stds total in derrick) POOH LD 75 its, 2,372' of used 3 1/2" 9.3# L-80 EUE-M tbg used for kill string, NORM tbg & ck ok 06:30 - 08:00 1.50 WELCTL EaRP DECOMP Installed test plug, changed out lower pipe rams from 51/2" csg to 4" PrInted: 4/15/2004 2:15:05 PM ~ , ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/612004 06:30 - 08:00 1.50 WELCTL EaRP DECOMP DP 08:00 - 09:00 1.00 WELCTL BOPE DECOMP RU & tested lower 4" rams to 250 psi and 3,000 psi, RD 09:00 - 14:30 5.50 DRILL PULD DECOMP RU & PU 146 its of 4" HT 38 DP & stood back in derrick 14:30 - 18:45 4.25 DRILL RIRD DECOMP RU rig floor & top drive for 4" HT 38 DP, loaded 78 add. its of 4" DP and 28 its of spiral wt in pipe shed and strapped, Installed wear bushing 18:45 - 19:00 0.25 DRILL SFTY DECOMP Held PJSM with rig crew and Sperry-Sun on PU & MU BHA 19:00 - 00:00 5.00 DRILL PULD DECOMP PU & MU 6 3/4" BHA #1, orient and upload MWD and surface tested, blow down, RIH PU spiral wt DP to 500' 217/2004 00:00 - 01 :00 1.00 DRILL PULD DECOMP Fin MU BHA #1, PU 20 its 3 1/2" spiral Wt DP RIH to 1,090' 01:00-04:15 3.25 DRILL TRIP DECOMP Cont RIH with BHA #1 PU 4" HT 38 DP, RIH to 3,551', est circ and washed down and tagged TOC at 3,612', (est TOC @ 3,615') ,/ 04:15 - 05:30 1.25 DRILL CIRC DECOMP Circ hole evening MW in & out at 9.8 ppg, circ at 325 gpm at 1,900 psi, rot wt 70K, up wt 80K, dn wt 65K 05:30 - 07:00 1.50 DRILL DEQT DECOMP RU and tested 7 5/8" csg to 3,000 psi for 30 min, good test, RD 07:00 - 11 :00 4.00 DRILL DRLG DECOMP Drilled hard cement inside csg from 3,612' to 3,979', 5' below csg shoe, drilled at 5K wob, 60 rpm's, 325 gpm at 2,000 psi 11:00-14:15 3.25 DRILL DRLG DECOMP Time drilled to sidetrack well from 3,979' to 4,010', sidetracked well at 4,010' and drilled 25' of new formation to 4,035'MD/3,246'TVD for LOT, 2-4K wob, circ at 325 gpm, 2,300 psi 14:15 - 15:00 0.75 DRILL CIRC DECOMP Circ hole clean evening MW in & out at 9.7 ppg for LOT 15:00 - 16:30 1.50 DRILL LOT DECOMP RU and performed LOT to 13.3 ppg EMW with 600 psi at 3,202' TVD and 9.7 ppg MW, RD 16:30 - 00:00 7.50 DRILL DRLG INTRM1 Drilled 6 3/4" hole per directional plan from 4,035' to 4,685' MD/3,707' TVD (650') ART 3.6 hrs, AST .25 hrs, 2-5K wob, 60 rpm's, 133 spm, 325 gpm, off btm pressure 2,000 psi, on btm 2,200 psi, off btm torque 3K ft-Ibs, on btm 5K ft-Ibs rot wt 80K, up wt 85K, dn wt 75K, displaced out mud used to drill cmt with new 9.8 ppg LSND, pumped 1 weighted hi vis sweep at 2# over MW and had 20% increase in cuttings 2/8/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 63/4" hole per directional plan from 4,685' to 5,791' MD/4,470' TVD (1,106') ART 7.39 hrs, AST .83 hrs, 5-10K wob, 60-80 rpm's, 133 spm, 325 gpm, off btm pressure 2,550 psi, on btm 2,750 psi, off btm torque 9K ft-Ibs, on btm 10,500 ft-Ibs, rot wt 83K, up wt 115K, dn wt 70K, 9.8 ppg MW in & out, pumping weighted sweeps every 300-400' with 10-20% increase in cuttings 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled from 5,791' to 6,672' MD/5,080' TVD (881'), ART 6.21, AST .41 hrs, 5-8k wob, 80 rpm's, 130 spm, 320 gpm, off btm pressure, 2,800 psi, on btm 3,100 psi, off btm torque 12,200 ft-Ibs, on btm 13,300 ft-Ibs, rot wt 85K, up wt 125K, dn wt 75K, cont pumping wt'd sweeps with 10-20% increase in cuttings 2/9/2004 00:00 - 16:30 16.50 DRILL DRLG INTRM1 Drilled 6 3/4' hole per directional plan from 6,672' to 7,615' MD/5,776' TVD, (943') 51/2" csg pt, ART 7.08 hrs, AST 2.41 hrs, 5-10k wob, 80 rpms, 300 gpm, off btm pressure 2,900 psi, on btm 3,100 psi, off btm torque 8,200 ft-Ibs, on btm 10,100 ft-Ibs, raised MW to 10.5 ppg while drlg per mud program, added 1.3% lubricants to mud, rot wt 100K, up wt 11 OK, dn wt 92K, pumped sweeps every 3-400' with little to no increase in cuttings, changed out liners and swabs on #1 while drlg at a reduced circ rate 16:30 - 18:30 2.00 DRILL CIRC INTRM1 Pumped weighted hi vis sweep and circ hole clean, had no increase in cuttings at btms up, circ at 300 gpm, 2,900 psi and 80 rpm's Note: Held Pre-Tour safety mtg with new crew on rig while circ 18:30 - 22:30 4.00 DRILL WIPR INTRM1 Wiped hole to shoe with no problems, precautionary backreamed out 10 stds at drlg rate from 7,615' to 6,675', POOH 3 stds hole not taking calc fill, pumped out 3 stds then cont POOH on elevators wet, hole Printed: 4/15/2004 2:15:05 PM ,( ( Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 13, 2004 ~~.ECE'VE[~ FEB 1 7 2004 Ala~kri nil \~ Gas Cons Cwnr'r~~¡on .4nrhorag~ 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 3F-19 (APD # 196-102) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforating operations on the Kuparuk well 3F-19. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ~. M.~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad FE'F~ 1 B lOO~. Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 96' . . 1. Operations Performed: (' ( ~,:,..."", "!"""" . ';"cCEIVEJJ FEB 1 7 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Abandon REPORT OF D D RepairWell D D Pull Tubing D Perforate 0 varianc~.nr.Gp'}.nnular Disp. D Stimulate D Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 196-1 02 / 6. API Number: 50-029-22680-00 DRY WELL OPERATION~ D Plug Perforations D Perforate New Pool D 4. Current Well Status: Development 0 Stratigraphic D Suspend Exploratory D Service D 9. Well Name and Number: 3F-19 8. Property Designation: ADL 25632, ALK 2565 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 8132' feet true vertical 6290' feet measured 7867' feet true vertical feet Length Size MD 121' 16" 121' 3890' 7-5/8" 3986' 7453' 5-1/2" 7549' 578' 3-1/2" 8127' Plugs (measured) Junk (measured) 70001 TVD Burst Collapse 121' 3214' 5834' 6286' Measured depth: 4180'-4182',4390'-4392',7644'-7654',7852'-7872' true vertical depth: 3352'-3353',3501'-3503',5908'-5915',6069'.6084' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7553' MD. Packers & SSSV (type & measured depth) no packer nipple= 510' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl SI SI Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubin Pressure Casin Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations_X 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. Sundry Number or N/A if C.O. Exempt ..... Contact Printed Name Signature WDSPLD . .- Mike Mooney @ 263-4574 Mike Mooney Wells Group Team leader Date Title Phone \)..~("~~~ ^~ K.. -.~I Ii i \ Ii F' : 1....,./ l t \~ t1. . Form 10-404 Revised 2~2~~~ ,-.. .' Ii"" r. D "11 ('¡) 2. OO,Q ': ~';;'.. ',' ~':"'J r: .... ) IT" [~O 1 tI) - ~ f-{t ConocoPhillips Alaska, Inc. 3F-19 TUBING (0-2407, 00:3.500, 10:2.992) PLUG (7000-7012, 00:5.500) FISH (7480-7481, 00:1.500) FISH (7481-7483, 00:1.000) NIP (7533-7534, 00:3.500) LOCATOR (7541-7542, 00:3.500) TUBING (7012-7553, 00:3.500, 10:2.992) TTL (7553-7554, 00:3.500) Perf (7644-7654) Perf (7852-7872) ( (' KRU 3F-19 API: 500292268000 SSSV Type: NIPPLE Rev Reason: PERFS Last U date: 1/30/2004 Grade H-40 L-80 L-BO L-BO Thread Size 16.000 7.625 5.500 3.500 Bottom 121 3986 7549 8127 Wt 62.50 29.70 15.50 9.30 TVD 121 3214 5834 6286 To 0 0 0 7549 Thread EUE8RD EUE 8RD MOD NO-GO Cameo 'DS' Landin CIBP SET 5/4/2002 NO-GO Camco 'D' Landing Nipple. Broached scale to 2.74" to 7533 on 8/30/99' broached scale to 2.74" to 7860 on 10/17/99 Baker 'GBH-22' Locator ID 2.812 0.000 2.750 7541 5828 7553 5837 FIsh.. FISH De th 7480 FISH 7481 FISH General Notes Date Note 12/9/1998 Dro ed 1.875" roller in rat hole. 8/29/2001 UNABLE TO PASS 2.52" GAUGE RING BELOW 7330' DUE TO BARIUM SCALE 8/30/2001 UNABLE TO PASS A 1.99" BROACH BELOW 7560' DUE TO BARIUM SCALE. 5/4/2002 WORKOVER - UNABLE TO PULL TBG BELOW TBG CUT. SET PLUG & SECURED WITH 13.3 PPG MUD. FP'D TEMPORARY ABANDONMENT. Comment 2.74" SWAGE W/XO LOST STUCK IN GLM #5 9/6/01 1" BROKEN LATCH LOST 9/6/01 Date 01/28/04 ,\ ~' 3F-19 Event History Comment MITTO 1950 PSI PASSED.TAGGED PBTD AT 4435' WITH 10' X 21/2" DUMMY GUN - PERFORATED: 4390'-4392'. UNABLE TO CIRCULATE TO OA THROUGH THESE PERFS. ADDED PERFS: 4180'-4182'. Page 1 of 1 2/11/2004 '--~ ¡ ~ ~, ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.J.thomas@conocophillips.com December 29,2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Plug & Abandon Original Well bore, Producer 3F-19 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Plug & Abandon the original well bore for the 3F- 19 well, an onshore Producer well, and then sidetrack KRU 3F-19A, a development well. Note: it is planned to abandon the original well bore by setting a permanent cast iron bridge plug in the 5.5" casing at 4375' MD and cutting and pulling the 5.5" casing from a depth of 4350' MD, just below the 7-5/8" casing shoe. A 500' cement plug will then be placed on top of the cast iron bridge plug with the top of cement inside the 7-5/8" casing (approximately 125'). The cement plug will then be used as a kick off plug for sidetracking the well bore to a new bottom hole location. The wellbore will be top set above the productive sands and then a 4-3/4" hole section will be drilled with a 3-1/2" liner run and cemented. The top of cement will be above the liner top. (Details attached in 3F-19A sidetrack Drilling Program). This well is to be completed as a 3-1/2" mono-bore producer. The liner portion of the mono-bore will be cemented top-to-bottom using a liner hanger. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The spud date is expected to be approximately 02/01/04. If you have any questions or require any further information, please contact Kelly McLure at 265-6059. Sincerely, Kelly GKA Drilling Engineer S[;j~!~~lE[: ~JÅN ~ @ 2004 4 ( ( , STATE OF ALASKA l , \{p ALASKA OIL AND GAS CONSERVATION COMMISSION ~ II APPLICATION FOR SUNDRY APPROVAL /{p I!f!< 20 MC 25.280 ( J ~ 1t71 ¡ 1. Type of Request: Abandon 0 Suspend D Operational shutdown D Perforate D Variance D Annular d¡sposO) Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Other D Change approved program D Pull Tubing D Periorate New Pool D Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 196-102 3. Address: Stratigraphic D Service D 6. API Number: . P. O. Box 100360, Anchorage, Alaska 99510 50-029-22680-00 7. KB Elevation (ft): 9. Well Name and Number: 30' RKB, 54' AMSL 3F-19 8. Property Designation: 10. Field/Pools(s): ADL 25632 / ALK 2565 Kuparuk River Field / Kuparuk River 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): 8132' 6290' 7867' 6080' 7000' 7480' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 1611 1211 1211 Surface 38901 7.62511 39861 32141 Intermediate Production 74531 5.511 75491 58341 Liner 5781 3.511 8121' 62861 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 76441-76541,7852'-78721 59081-59151,60691-60841 3.511 L-80 2401' /75531 Packers and SSSV Type: Packers and SSSV MD (ft): Landing Nipple, no packer nipple @ 510' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch D Exploratory D Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/10/2004 Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kellv McLure @ 265-6059 Printed Name R. Thomas Title Kuparuk Team Leader Signature -\.._~....> -----, .L-., . Phone 265-6830 Date I. (/ Y'l~ ''r'' ''., ~ ~ r..:"",I'\" illI,,,,,,.n,,,/,,,, \ COMMISSION USE ONLY Conditions of approval: Notify comm~ssion so that a representative may witness I R Ët; ÈIVE 0 .3£>1-1Y., Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D JA N 1 4 2004 f Other: Alaska Oil & Gas Cons. Commission Anchorage Subsequent Fonn R~~~~ By IRImMs BFI.. JAN 2 û 20M Sarah Palin BY ORDER OF Approved by: COMMISSIONER THE COMMISSION Date: ,II~ ¡;, tf f I Form 10-403 Revised 2/2003 0 RIG I N A L SUBMIT IN DUPLICATE ( ( KRU 3F-19 ConocoPhillips Alaska, Inc. I_I 3F-19 API: 500292268000 Well Type: PROD Anole @ TS: 40 deo @7628 SSSV Type: NIPPLE Orig 8/7/1996 Angle @ TO: 36 deg @ 8132 TUBING Completion: (0-2407, Annular Fluid: Last W/O: Rev Reason: format update by 00:3.500, 1100 10:2.992) Reference Loa: Ref Log Date: Last Update: 12/10/2002 LastTaa: 7867 TO: 8132 ftKB Last Taa Date: 7/12/2000 Max Hole Angle: 46 dea @ 4764 CasinQ StrinQ - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 SUR. CASING 7.625 0 3986 3214 29.70 L-80 PROD. CASING 5.500 0 7549 5834 15.50 L-80 LINER 3.500 7549 8127 6286 9.30 L-80 Tubina String - TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 1 2407 I 2098 I 9.30 1 L-80 I EUE8RD 3.500 I 7012 1 7553 I 5837 I 9.30 I L-80 1 EUE 8RD MOD Perforations SummarY ... .. -- .. ... . . Interval TVD Zone Status Ft SPF Date TVDe Comment 7644 -7654 5908 - 5915 C-4 10 4 2/3/1999 APERF 180 deg. phsg +/- 90 deg.; 2.5" He. DP 7852 - 7872 6069 - 6084 A-3 20 4 8/7/1996 IPERF 180 deg. phasing, 21/2" BH Gas Lift MandrelsNalves St I MD I TVD I Man Man I V Mfr I V Type ì V ODì Latch I Port I TRO I Date I Vlv Mfr Type Run Cmnt 1 1 74801 57811 BST I AXT 1 I DMY I 1.0 1 T1 10.000 1 0 12/17/19991 (1) 1. Broken Latch Other plugs, equip., etc. - JEWELRY DeDth TVD Type DcscriDtion ID PLUG 510 508 NIP NO-GO Cameo 'DS' LandlnQ Nicole 2.812 7000 5407 PLUG CIBP SET 5/4/2002 0.000 (7000-7012, ...... ( 7533 5822 NIP NO-GO Cameo '0' Landing Nipple. Broached scale to 2.74" to 7533 on 2.750 00:5.500) 8/30/99; broached scale to 2.74" to 7860 on 10/17/99 7541 5828 LOCATOR Baker 'GBH-22' Locator 3.000 7553 5837 TTL 2.992 Fish'; FISH .".. '..' Depth Description I Comment 480-FIS~ 0"__' ". 7480 IFISH 12.74" SWAGE WIXO LOST, STUCK IN GLM #5 9/6/01 (7 . 748 , .~ .~ 7481. 1 FISH. ". 11" BROKEN LATCH LOST 9/6/01 00.1.500) N'':>.- ....,. General Notes '.' .. . . .... r . Date Note . 12/9/1998 Dropped 1.875" roller in rat hole. FISH \( 8/29/2001 UNABLE TO PASS 2.52" GAUGE RING BELOW 7330' DUE TO BARIUM SCALE (7481-7483, h 8/30/2001 UNABLE TO PASS A 1.99" BROACH BELOW 7560' DUE TO BARIUM SCALE. 00:1.000) ... < 5/4/2002 WORKOVER - UNABLE TO PULL TBG BELOW TBG CUT. SET PLUG & SECURED WITH 13.3 PPG ) MUD. FP'D TEMPORARY ABANDONMENT. NIP .... (7533-7534, 00:3.500) 0 , C'\ i t>- ~,\u:o~"'\ ~~ C>.~. ~~~çj ",:, ~~~': I ~.c.~ ~ LOCATOR \ ....) b'\ ~'t ~~ t:;;. ~~ \:~ D~ \ \~ c.J b 0'\- \ \.... ~'0.. ~ \'° "... ~~ ~ \. \ \, ' 00:3.500) '-'-'- PO~~\ ~ \Q ~O YÇ:-\ \\<!::.~~ --\4 <:"0,""S.~c:i\o \"- 0\-- TUBING> ..Ç, ":> ". "\) Q:~,,\ "'"> ,Ç\(), \~,\.\..ö..~o.œ~~\c:::. "'. c..~> ......... ~'- (7012-7553, ..... . '--.' . 00:3.500, ~<è tl Û-'? ~ ~\0 \' \<-\ \ \ ~ o,~ <:> "Ú1- '-.) ~ 10:2.992) . . ("'\ J ' - cd=; S~'" \--'< ú. \ \ì V \ \..I ~ ~ <t èJ -\-,,(~ \ Iod~ . ~~ =3 ¡i= Tk ~\\V0Û--'7S0"'7~'l~<:cJ S/I~~Od-, !¡, II Perf :=J I'" = Y(J ?)¡ /I (7852-7872) ~ I: ~ ¡k;t;t.. ' IV 1ft .~ i- . '-111 I!I '-- I ":> II ( 1dry to Re-enter and Abandon, Well 3F-19A "\ Revision No.O Saved: 15-Jan-04 3F-19A Drillina Proaram Pre-Rig Well Work: 1. Check all lock down screws on the 7-1/16" x 5M tubing head flange. Test the packoffs on the 5.5" casing. 2. File Sundry notice - plug back. Notify AOGCC field inspector 24 hours before commencing work. 3. RIH and and perforate the 5.5" casing at 43601 MD. 4. Circulate kill weight fluid and clean up the annulus Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI/RU Nordic 3. Install blanking plug on top of the back pressure valve.--- 2. NU and test the 11"x 5K" BOPE to 250# / 3500# 3. Engage the 3-1/2" tubing with a spear. L/D the tubing hanger. 4. P/U and run a storm packer, hang off in the 5-1/2" casing. 5. N/D BOP/s. Remove tubing head adapter and packoff. Tack weld the slips/packoff to the 5.511 casing. Install the doughnut to be used as a packoff for testing. 6. NU Bopls to the 11", 3000 psi flange & test 7. POOH w/ storm packer & rack back 9001 of the 3-1/211 tubing for the cmt stinger. RU wireline set a CIBP inside the 5.5" casing at 43751 MD. POOH. ~- <~'.~ A 8. PU & RIH ~ith ë;1 chemical cutter and cut the 5.5" casing at 43501 MD. Run spear & pull the 5-1/21/ casing a~d .. . ,.:),--JC C".", \ L/D the casing. ~,") "? .,....\J \ ' " vP" 9. Displace the hole with new LSND mud. 110. RIH w/ 3-1/21' tubing string and to spot a 500' balanced cement plug on top of the CIBP with the TOC inside the 7-5/8" shoe at approximately 38751 MD. POOH 3 stands and circulate above the cement plug. 11. POOH and LD 3-1/2" tubing. -I.' 12. PU BHA, 4.0" DP, and RIH to TOe. Check for cement hardness and ~~-;-;~nds if cement is not hard and wait 1 ~ on cement. ~y:.....13. Drill the Intermediate hole section with an 6-3/4" bit to the top of the C4 sand and top set at approximately ~..,."~ 7705' with 5.5", 15.5#, L-80 casing. ~ -::¿<'J 14. P/U a 4-3/4" PDC bit, MWD, LWD, non-mag flex collars, jars, and DP as required. '"3 ~> \~~ 15. Test casing to 3500 psi, drill cmt, float equip, drill 201 new hole. Perform LOT = 14.5 ppg. ~ 16. Drill ahead, (Sperry Sun Directional Program attached). Maintain the LSND mud properties as per the MI program. The MW should be 11.5 ppg at the Top/C4: 777T MD/5884/IVD. 3F-19A DRILLING PROGRAM. doc Page 1 of 2 Printed: 15-Jan-04 ¡ill ldry to Re-enter and Abandon, Well 3F-19A \ 'Revision No.O Saved: 15-Jan-04 17. Continue drilling into the Miluveach Shale to give .:t 200' of rat hole below the base of the Kuparuk A. The proposed TD is .:t 8242' MD, 6281' TVD. At TD, circulate bottoms and make a wiper trip. RIH to TD. Circulate and condition the hole to run the liner. POOH. 18. R/U and run the 3-1/2" liner to TD. The required overlap is ~ 150': TaL = 7555' MD. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. 19. Cement liner as per cement program. Release from liner. Set ZXP. 20. Displace the well above the TaL with seawater (.:t 115 bbl) and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 21. R/U and RIH with the 3-1/2" tubing tag the TaL. Set packer & shear out of PBR. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TaL to 3500 psi. Bleed off all pressures. 22. Install a TWC. ND BOPE. NU and test the 4-1/16" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to .:t 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve (114 bbl). Install a BPV. R/D and M/O Nordic 3. Post-Rig Well Work: 1. Pull the BPV. R/U SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. R/D SLU. 3. R/U E-Line. Run cement bond log inside the liner. 4. Perforate the Kuparuk as directed. RID E-Line. 5. Install new "s" riser and replace the well house(s). 3F-19A DRILLING PROGRAM. doc Page 2 of 2 Printed: 15-Jan-04 ~ 11i' - 3F-19A PROPOSED ConocriPhmips SIDETRACK COMPLETION 3-1/2" SM FMC Gen IV tubing hanger with 3-1/2" L-BO EUE Brd pin down 3-1/2", 9.3#, L-BO EUE Brd tubing to surface- all special drift 2.91" 3-1/2" Cameo 'DS' landing nipple with 2.B7S" ID No-Go profile set at +/-SOO' MD 3-1/2" 9.3# L-BO EUE Brd Mod tubing to GLM GLM Placement. Valves #1-4: 3-%" x 1" KBG2-9 mandrels with DV and 6 Ft. handling pups insllled on top and bottom Top of Cement plug Place gas-lift mandrels at the following depths: TVD Approx MD Valve set @ +-3B7S' MD 2450 2912 1.00 3825 4864 1.00 7-S/B" 29.7# 4675 6087 1.00 LBO casing @ 5250 6914 \.00 3974' MD / 5685 7530 1.00 3202' TVD Depth adjusted for 3-1/2" 9.3# L-BO EUE Brd Mod tubing as necessary Nordic 3 RKB Sidetrack KOP @ +/- 4224' MD, +- PACKER ASSEMBLY 33BO" TVD Baker Slim Line BO-40 12 Ft. PBR w/ K anchor. <:LS\' \0 Baker S-%" SABL permanent packer w/ 2.7B" ID s.'-,,¡, 110ft. Pup joint 3-'h" 9.3# L-BO EUE-Mod B Rd '---tIf 2.7S Halliburton [)([JNipple with RHC Plug Installed (high pressure) ~'O 'l 110ft. Pup joint 3-%" 9.3# L-BO EUE-Mod B Rd S-%" 1S.S# Casing 3-%" WLEG with 3-'h" EUE-Mod Box up Cut @+-43S0' MD Baker "K.1" CIBP @ 2.B1" Cameo D +/- 4375' MD LINER ASSEMBLY 5-%" Flex-Lock Liner Hanger Packer 3-'h" X 5-'h" HMC Hydraulic Liner Hanger 3-'h" IBT-Mod or EUE-Mod Liner as needed Baker "K-1" CIBP @ 3-'h" Landing Collar +1- 7000' MD One Joint 3-%" IBT-Mod or EUE-Mod Tubing 3-%" Float Collar Two Joints 3-%" IBT-Mod or EUE-Mod Tubing 3-'h" Float Shoe Top liner set at 7555' MDI 5B24' TVD Original Well bore 3-%" X 5-%" Long Top set 5.5" csg at String B127' MD TD 7705' MD/5B24' TVD C4 & C1 sands Estimated BHA 3950 psi 8242' MD/6281' TVD Drawn b Jose I uaz 01-0B-04 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 May 13, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 . Subject: Report of Sundry Well Operations 3F-19 (196-102 / 302-151) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the KRU well 3F-19. If there are any questions, please contact me or Skip Coyner at 265-6074. Sincerely, R. Thomas Kuparuk Drilling Team Leader Phillips Drilling RT/skad 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 _XX Suspend 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 96 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 5239' FNL, 126' FEL, Sec. 19, T12N, R9E , UM (asp's 508372, 5985863) 3F-19 At top of productive interval 9. Permit number / approval number 690' FNL, 301' FEL, Sec. 19, T12N, R9E, UM 196-102/302-151 At effective depth 10. APl number 50-029-22680 At total depth 11. Field / Pool 376' FNL, 334' FEL, Sec. 19, T12N, R9E, UM (asp's 508141, 5990726) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8132 feet Plugs (measured) Baker CIBP @ 7000' MD true vertical 6290 feet Effective depth: measured 7012 feet Junk (measured) Fish @ 7012' true vertical feet Casing Length Size Cemented : Measured Depth True vertical Depth CONDUCTOR 121' 16" 260 sx AS 1 121' 121' SUR. CASING 3890' 7-5/8" 1060 sx AS III, 330 sx Class G 3986' 3214' PROD. CASING 7453' 5-1/2" 250 sx Class G 7549' 5834' LIN E R 578' 3-1/2" included above 8127' 6286' LINER Perforation depth: measured 7644' - 7654', 7852' - 7872' true vertical 5908' ~ 5915', 6069' - 6084' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 2407' MD. Packers & SSSV (type & measured depth) no packer NO-GO CAMCO 'DS' LANDING @ 491' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation SI Subsequent to operation SI 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __XX Service __ Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Veto Coyner265-6074 Signed / , _ Title: Kuparuk Drilling Team Leader Date f R. Thomas Prepared b~ Sharon Aflsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE ~ DS Nipple 3F- 19 Suspended 5/5/02 3-1/2", 9.3#, L-80, EUE at 2407' MD 7-5/8", 29.7#, L-80 at 3986' MD (3214' TVD) 13.3 ppg Mud 5-1/2, 15.5#, L-80 at 7536' MD The Fish (518.40'). TOF at 7012' MD · (1) 3.5" tubingjnt (Chemical cut) · (13) 3.5" tubing joints · (1) 3.5" pupjnt Baker CIBP ~ at 7000' MD · The fish is plugged inside the GLM. · We cannot inject Past the fish. · (1) "ATX" GLM · (1) 3.5" pupjnt · (1) 3.5" tubing joint · (1) 2.75" DS nipple ~ · (1) 35"pupjnt · (1) B'aker GBH-22 locator seal assembly 5" x 4" CSR 7536' - 7548' MD 5-1/2" x 3-1/2" Crossover Est'd BHP = 3850 psi [ Zone C-4: 7644' - 7654' MD, 5908' - 5915' TVD Zone A-3: 7852' - 7872' MD, 6069' -6084' TVD 3-1/2, 9.3#, L-80 at 8127' MD (6286' TVD) : :: OPerati ,s summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: 4/12/2002 20:00-00:00 4.00 MOVE MOB MOVE Prepare rig and camp f/ move to 3F-19. L/ D kelly hose and cement hose. Remove geol ograph line, install "A" leg brace. Preparing derrick board sidewalls. Prepare pipe shed f/ move. Prepare shop, sewer plant, halfw ay house and camp f/ move. 4/13/2002 00:00-01:00 1.00 MOVE DMOB MOVE Working to prepare rig for move to 3F-19 W O. Open wing windwalls on board. Drop top windwalls and "C" section. 01:00-05:00 4.00 MOVE DMOB MOVE Open wing walls on cattle chute. Remove co vers on deadman and drawworks. Pull cattle chute back. Coil up geronimo line. Riggin g down in pump room f/ move. Cleaning pits 05:00-12:00 7.00 MOVE DMOB MOVE RU to lower "C" section. Lower "C" section. Secure blocks. Note: Camp is moving f/ Grizzly location to 3F-19. Steve McCaull y smashed side of ring finger, left hand, req uired 9 stitches. SDS plant trailer had broken wheel studs that were replaced @ mile marker 23 (7 miles f/ location) 3 hrs t o repair SDS plant trailer had broken wh eel studs that were replaced @ mile mark er 10 (20 miles f/ location) 2 hrs to repair Both camp uits had some broken wheel st uds that were replaced @ mile marker 8 ( 22 miles f/ location) 1hr or less These were fixed while cat pulled units up the hill to marker 7. 12:00-00:00 12.00 MOVE DMOB MOVE Prepare derrick & lower onto headache rack. Clean up & PU rig floor, pipe shed, pits an d cellar. PU berm f/ dewater, repair demco 2 "valve on mud manifold. Grease and work cement valves. Blow down water. Rig down d e-water house. Camp moving : Camp left marker 7 after crew swap and wheel studs r eplaced @ 1400 hrs, arrived @ 2P raod @ 1 630 hrs. Camp continued to move. camp @ CPF 2 @ midnight 4/14/2002 00:00-12:00 12.00 MOVE DMOB MOVE Preparing rig for move f/ Grizzly location to 3F-19 we. Double checking lines, valves, p umps in pits, blow down steamlines and heat ers. Disconnect service lines to pits. Move Iconnex's from front of pits. Function test co !Id start on pits. Move fuel tank f/ access to 3its. Secure contents of pipe shed. Load out trucks and equipment. Unhook rig power. S tart cold starts to pipe shed and pits. Load pits and pipe shed. Prepare to move. 12:00-00:00 12.00 MOVE DMOB MOVE Pits and pipe shed left Grizzly location @ 1 230 hrs. Arrived @ 2P pad stagging area @ 2000hrs. Left Grizzly location @ 2230 hrs with sub base. i Printed: 5/13/2002 9:24:39AM O eratiOns summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: Description of Operations 4/15/2002 00:00-13:00 13.00 MOVE DMOB MOVE Moving sub f/ Grizzly location to 3F-19 we. Had flat on tire on off driller's side @ 00:30 hrs approx 10 miles f/ location (Mile marke r 20). Build ice pad f/ tire replacement. Re move outside off driller side tire f/ module. Set module on mats. Disconnect Peak Sow f/ load. Fuel pits and pipe shed. Trucks goin g to move pits and pipe shed f/ 2P area to 3 F while removing tire f/ sub and getting repl acement ready. Pits and pipe shed leave 2P stagging area @ 0930 hrs, arrive @ 2N pad @ 1300 hrs. Let tire truck pass while @ 2N and get back to drilling module @ mile mar ker 20 (10 miles f/ Grizzly pad). 13:00-15:30 2.50 MOVE DMOB MOVE Moving pits and pipe shed f/ 2N pad towards 3F pad. Arrive @ 2M pad @ 1500 hrs. Chec k tires and fuel pipe shed.. Replaced tire o n outside, off driller side sub module, ready with subbase module @ 1500 hrs. Arrive @ CPF-2 @ 1800 hrs. 15:30-18:00 2.50 MOVE DMOB MOVE Leave 2M pad with pits and pipe shed, arriv e @ CPF-2 @ 1800 hrs. 18:00-19:00 1.00 MOVE DMOB MOVE Fuel modules @ CPF 2. Check equipment. W ait f/ crew change f/ CPF 2. 19:00-00:00 5.00 MOVE DMOB MOVE Leave CPF 2 @ 1915 hrs. arrive @ 3[] pad @ 2200 hrs. Set pit module down @ 3B. Conti nue to 3F pad w/ pipe shed module. Arrive @ 3F with pipe shed module @ 2240 hrs. Se t dodule down. Fuel pits and pipe shed modu les. Trucks will go back to sub module @ mi le 20 (10 miles f/ Grizzly location) to contin ue moving. 4/16/2002 00:00-09:00 9.00!MOVE DMOB MOVE Sub left mile 20 (10 miles f/ Grizzly pad) to continue move to 3F-19. Arrive @ RSP (6x6 pad) area @ 0630 hrs. Take weight off tires Fuel up, wait f/ crew change. 09:00-13:30 4.50 MOVE DMOB MOVE Jack drilling module up. Move to junction of Meltwater and Ice roads. Wait while measur ements are taken to determine width of road Move rig back to Heavenly & ice Road inte rsection to keep road open. 13:30-15:00 1.50 MOVE DMOB MOVE Lounsberry continue to measure the new rea d section of Meltwater road. Lounsberry mea surement results discussed with Peak Truck Pusher, Nabors Toolpusher, PAl Rig Supervi sor, NSK Field Supervisor, Sim/eps coordin ator,Team Leader. 15:00-17:00 2.00 MOVE DMOB MOVE Move sub module back to 6 x 6 pad (RSP). S et module down @ 6x6 pad, remove trucks. 17:00-00:00 7.00 MOVE MOVE Remove doors and inspection covers f/ # 1 b oiler, prep f/ rolling tubes, clean up around sub module, travel back to Grizzly pad to fu el loader. Printed: 5/13/2002 9:24:39 AM : OPerati nssummarY:Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: ~'Udbe :: Description of Operations 4/17/2002 00:00-12:00 12.00 Prep Rig 245 f/ start up. RU heat to Cat 353 engine. Hookup exhaust, air intakes, air st arters on 399;s (#1& #2). Plumb heat up to generator room. Motorman @ 6x6 pad with 1 9E su working on boiler # 1. Floor hand and roustabout fueling pits and cleaning up shop Forklift operator on 3F pad. 2P> 2N rca d:: AIC adding material to road for width of 30' and also adding lift to another 1 mile s ection of road. Lounsberry surveying and ch ecking some compaction. 12:00-17:00 5.00 Prep Rig 245 f/ start up with driller, 3 floor hands and 1 rstabout. Motorman working o n # 1 boiler @ 6x6 pad. AIC working on 2 P>2N road until 1800 hrs. 17:00-00:00 7.00 Forklift operator, 1 rstabout @ camp unloadi ng trucks. Derrickman & pitwatcher work on pit module. Driller, floorhands and rstabo ut return to 6x6 pad to check out road f/ 2P >2N. 4/18/2002 00:00-03:00 3.00 MOVE DMOB MOVE Prepare to move sub base module f/ 6x6 pad 03:00-06:30 3.50 MOVE DMOB MOVE Move f/ 6x6 pad, arrive @ 2N pad @ 0630 hr s . 06:30-07:30 1.001MOVE DMOB MOVE Crew change, check things over. 07:30-12:00 4.50 MOVE DMOB MOVE Leave 2N pad @ 0730 hrs, arrive @ 2B pad @ 1 200 hrs 12:00-17:30 5.50 MOVE DMOB MOVE Leave 2B pad and arrive @ 3F w/ sub modul e @ 1730 hrs. 17:30-21:00 3.50 MOVE DMOB MOVE Remove jeep and spot sub base over hole f/ 3F-19. ;21:00-22:00 1.00 MOVE DMOB MOVE Spot Pipe shed, mate to sub base. 122:00-23:30 1.50 MOVE DMOB MOVE Bring pit module to 3F pad (was stagged @ 3B pad until sub was on location). Position pits in relation to rig. Preparing to set pits. 23:30-00:00 0.50 MOVE DMOB MOVE Position pits in relation to rig, prepare to s et. 4/19/2002 00:00-01:30 1.50 MOVE DMOB MOVE Finish setting pit module. 01:30-06:00 4.50 MOVE RURD MOVE Rig up: Scope out companian way between p its and sub module. Hook up choke line, she ck hose and all service lines between modul es. Setup berms under all bolster jacks. Ins pect derrick prior to raising. Hookup flowlin e to pits. Work on boiler. Insulate companio nways between modules and in cellar. Instal ;I sissorlift on pipe shed. 06:00-12:00 6.00 MOVE RURD MOVE Finish prep derrick to raise. PJSM on raisin g derrick. Raise derrick f/ stand, uncradle b locks. Lower Derrick board. PJSM f/ scope o ut of derrick. Scope out derrick. Raise "C" s lection. Raise oupper windwalls on "C" sectio n. L/D plywoo in cellar 12:00-18:00 6.00 MOVE RURD MOVE Finish R/U derrick board and "C" section. R Printed: 5/13/2002 9:24:39 AM : OP rati s summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm @ ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: ~:~8~ l~Udb ~ha~il Description of Operations 4/19/2002 12:00-18:00 6.00 MOVE RURD MOVE U throat on pipe shed. Install wind walls aro und rig floor. RU derrick ladder. Turn steam and water on to rig and pits. Put # 1 boiler on line. 18:00-22:00 4.00 MOVE RURD MOVE Remove all tools and equipment not being u sed f/ rig floor and upper pipe shed. Put saf ety valves, slips & elevators in upper pipe s hed on rig floor. Set De- water house. 22:00-00:00 2.00 MOVE RURD MOVE RU choke line and valves. RU super choke. 4/20/2002 00:00-04:30 4.50 WELCTLOTHR WRKOVR RU choke line and manifold. Test to 250 psi Iow and 3500 psi. high. Test # 1: Valves 4 ,10,11,15. Hi press nipple leaking, repair sa me. Restest OK. Test # 2: Valve # 8,9,3,10 Test # 3: Valves 7,14,2 Test # 4: Valves 6,1,13. Function test super choke and manu al choke. Blowdown & R/D test equipment 04:30-09:30 5.00 WELCTLOTHR WRKOVR RU to L/D 3 1/2" tubing. Try to get more hea t in cellar. Help mech install new sensator on deadman anchor f/ weight indicator. Run 2" hardline from flareline on choke manifol d to well 3F-9 production flowline. 09:30-10:30 1.00 WELCTLOTHR WRKOVR Test hardline to 3500 psi f/ 15 min. Replace leaking lo-torque valve. Re test OK. 10:30-11:00 0.50 WELCTLOTHR WRKOVR Clear all lines and pumps of diesel. 11:00-11:30 0.50 WELCTLOTHR WRKOVR Finish mixing 20 bbl Hi vis sweep. PU all eq uipment. 11:30-12:00 0.50 WELCTLOTHR WRKOVR Well startup meeting w/ co rep, safety rep, DS operator, vac truck drivers, wellhead rep I , casing hands, toolpusher, both crews. 12:00-13:00 1.00 WELCT OTHR WRKOVR PJSM, RU circulating lines. 13:00-15:00 2.00 WELCT4OTHR WRKOVR RU lubricator and Pull B/PiV' 15:00-16:00 1.00 WELCT~SFTY WRKOVR PJSM, prepare to kill we . 16:00-18:00 2.00 WELCTIJOBSV WRKOVR Open well. Let pressure stabilize. Tbg 1420 psi. Ann 1300 psi. 18:00-20:30 2.50 WELCTLClRC WRKOVR Circ well with warm sea water f/ 3088 stroke s. Final circ press 500 on tbg. 175 psi on i casing @ 23 spm (2BPM). 20:30-22:00 1.50 WELCTLOBSV WRKOVR Shut in, blow down lines. Let pressures stab lize. 1220 psi tbg final 1160 psi annulus f inal 22:00-23:30 1.50 WELCTLKILL WRKOVR Transfer f/ vac truck to pits 12.8+ wt Baradr ilN. Weight up to 13 ppg. 23:30-00:00 0.50 WELCTL WRKOVR Pump 12.3# hi vis spacer, 190 strokes (16 b bls) SPR w/ 8.5 ppg while circ @ 7000', 5407'TVD # 1 6 spm = 150 psi. # 1 @ 12 s pm = 245 psi. 4/21/2002 00:00-01:00 1.00 WELCTLKILL WRKOVR Pump 13 ppg Baradrill N Kill weight mud. I CP= 1BPM @ 1100 psi Pill to surface @ 170 6 strokes. Shut in well. 01:00-02:30 1.50 WELCTLKILL WRKOVR Blow down lines running to production flow I ne @ well 3F-9. Swap returns from choke m anifold to outside tank. Line froze to tank. "haw out line. Take returns to outside tank. I Printed: 5/13/2002 9:24:39 AM : : .OPeratiOns summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: :i:i: Description of Operations 4/21/2002 02:30-03:30 1.00 WELCTL WRKOVR Continue to pump kill weight mud to surface taking returns to outside tank. 1 bpm @ 50 0 psi. With 1896 strokes & 600 psi pump t o 2145 strokes to tank. Blow down lines to tank. 03:30-06:00 2.50 WELCTLKILL WRKOVR Line up on gas buster, reroute to possum be Ily. Pump @ l bpm & 800 psi, increase to 1. 5 bpm & 1050 psi, then 2bpm & 1400 psi, th en 2 1/2 bpm & 1800 psi. 13ppg mud back @ 2915 strokes. (pumped kwm around 1 1/2 times after displacing seawater). 06:00-07:00 1.00 WELCTLOBSV WRKOVR Shut down pumps. Bleed off pressure. Monit or well. OK. Blow down lines (choke and m ud) 07:00-09:00 2.00 WELCTLNUND WRKOVR FMC set BPV. Drain tree. N/D tree 09:00-11:00 2.00 WELCTLNUND WRKOVR Dress tbg hanger. Install test plug. 11:00-19:00 8.00 WELCTLNUND WRKOVR NU BOPE. 19:00-22:00 3.00 WELCTLNUND WRKOVR Change upper and lower pipe rams to 3 1/2". 22:00-23:00 1.00 WELCTLBOPE WRKOVR Test all valves in choke manifold to 250 psi ow and 3500 psi high. 23:00-00:00 1.00 WELCTLBOPE WRKOVR RU test equipment f/ testing rams. 4/22/2002 00:00-01:30 1.50 WELCTLBOPE WRKOVR Test BOPE. Test annular preventer & manu al valve on choke line side, and kill line sid e to 250 psi and 3500 psi. OK Test upper pi pe rams and both outside HCR valves. Not a good test. Trouble shoot problem. 01:30-02:30 1.00 WELCTLBOPE WRKOVR Suck fluid f/ BOPE stack. L/D landing joint. Blow down surface lines. 02:30-03:00 0.50 WELCTLBOPE WRKOVR RU and test TIW valve and inside BOP valve R/D test equipment. 03:00-05:00 2.00 WELCTHOTHR WRKOVR PU test joint. Back out test plug. MU landin g joint and circ headpin to pump thru landin g joint and BPV to circ well. Attatch choke line to take returns f/ 5-1/2" x 3-1/2" annulu s thru choke to pits while circulating. 05:00-06:00 1.00 WELCTLOTHR WRKOVR Blow down surface lines. RU to test choke Ii ne connection to 3500 psi. Test f/ 15 min. O K. 06:00-11:00 5.00 WELCTLCIRC WRKOVR Break circulation @ 1BPM @ 1500 psi. Circ thru BPV and GLM @ 7000'. Circ total of 34 00 strokes. Weight on returns varied f/ 13. ! 3 to 12.4 Final circ press 1850 psi @ 1bp m w/ 13.3ppg Baradrill N. 11:00-13:00 2.00 WELCTLOBSV WRKOVR Monitor well. No flow on either side. L/D lan ding joint. Pull BPV. RU to pump thru land ng joint, BPV removed, thru GLM @ 7000', t aking returns thru 5 1/2" x 3 1/2" annulus a nd choke manifold to pits. 13:00-15:00 2.00 WELCTLClRC WRKOVR Circulate through choke @ 1BPM w/ 1500 to 2400 psi. Circ 2000 strokes, monitor well, n o flow either side. R/D pumping equipment. 15:00-16:00 1.00 WELCTLNUND WRKOVR nstall BPV. PJSM. N/D BOPE to set another Printed: 5/13/2002 9:24:39 AM i s:umma RePort Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: i ::: ', : :: : i: : : : i:: : ii:: : ..... : : :::: :: : ;::::':: :'::::: ::: : :: ::::::::~:::::: ::::: :: :: :::Sub: : ;;;:F:rom :,;To::; :: Hours:;l:r:Code:::;;~;: :d;::;: :;:Phase: ;::::,:::; ::: : : Description of Operations 4/22/2002 15:00-16:00 1.00 WELCTLNUND WRKOVR test plug to test BOP stack. 16:00-18:30 2.50 WELCTLNUND WRKOVR Install test plug. NU BOPE. 18:30-19:30 1.00 WELCTLBOPE WRKOVR Attempt to test blind rams. Fluid leaked by t est plug. Torque Iockdown screws, retest. N O test. 19:30-21:00 1.50 WELCTLJBOPE WRKOVR Pull test plug. MU landing joint in hanger. 21:00-00:00 3.00 WELCTLBOPE WRKOVR Test BOPE against landing joint. Test upper pipe rams and annular to 250 psi Iow and 3 500 psi high. Test Kill line valves and chok e line valves. Blow down choke and kill line s. Test witness waived by AOGCC rep Chuc k Scheve. 4/23/2002 00:00-00:30 0.50 WELCTLOTHR :WRKOVR Prep rig floor to pull tubing--MU head pin an d hose 00:30-01:30 1.00 WELCTLOTHR WRKOVR L/D landing joint. Pull BPV. 01:30-02:00 0.50 CMPLTNPULD WRKOVR MU landing joint. RU headpin. PdSM prior to pull tubing. 02:00-04:30 2.50 CMPLTNPULD WRKOVR Back out LDS on hanger. Pull tubing hanger :free w/ 87K. Continue to pull tubing out of r !ecepticle. Landing joint threads failed w/ ap IPrOX 115K on weight ind. (100k pull on strin g--20' of pipe out of hole) 04:30-07:30 3.00 FISH OTHR WRKOVR Pump out BOPE stack. L/D landing joint. Wa ting on Baker fishing tools. Hanger is abov e tbg spool, free in stack. Hanger L/D Iocat on is 6.8' above tbg L/D screw position. 07:30-08:30 1.00 FISH PULD WRKOVR PU fishing tools. PJSM. 08:30-10:00 1.50 FISH OTHR WRKOVR Latch onto fish w/ spear. Pulling on tbg stri ng up to 124 K. 2-3/8" connection (pin) br oke on fishing assembly. L/D remaining fish ng string. RU 4" pup joints and floor valve f/ well control. 10:00-11:00 1.00 FISH OTHR WRKOVR Waiting on overshot tools to latch onto exte nded neck of hanger (5.5") & overshot to cat ch spear (2- 3/8") 11:00-12:00 1.00 FISH PULD IWRKOVR MU 2- 3/8" overshot. Pull 115K. Decide to re treive spear f/ hanger. L/D spear. 12:00-15:00 3.00 FISH PULL WRKOVR PJSM. MU overshot. Latch onto tbg hanger w / 5.5" overshot. Work tubing string up hole. Retreive tbg hanger, 3.67' pup joint and 6.1 5' pup joint. L/D fishing assembly. 15:00-21:30 6.50 CMPLTN, PULD WRKOVR MU joint of HWDP and x-o to tbg string. RU circulating equipment. Circulate and work pi pe w/ 150 k to 70 k while circ hole w/ 13.3 p pg mud. 21:30-22:30 1.00 CMPLTNPULD WRKOVR Pulled 21 .81' out on first full joint in hole. Pipe parted w/ 178 k on weight indicator (16 3 k pull on string). Check drilling line @ crc wn sheaves & drawworks drum. Tag fish in hole 48.5' below rotary table. 22:30-23:00 0.50 CMPLTIX PULD WRKOVR _/D HWDP and pump in equipment. L/D 1 f ull joint of 3-1/2" tbg and parted joint. (32. 88' and 13.45') Printed: 5/13/2002 9:24:39 AM ::i OPeratiOns summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: 4/23/2002 23:00-23:30 0.50 FISH OTHR WRKOVR Clear floor of extra tools. 23:30-00:00 0.50 FISH OTHR WRKOVR Waiting on fishing tools. 4/24/2002 00:00-04:30 4.50 FISH OTHR WRKOVR Inspect weight indicator system and rig mai nt while waiting on fishing tools. 04:30-05:00 0.50 FISH PULD WRKOVR PU fishing tools consisting of 3 1/8" DC's a nd ¢irc equipment. 05:00-07:00 2.00 FISH OTHR WRKOVR Housekeeping and inspect brakes on drawwo rks while waiting on varies sizes of grapple s for overshot. 07:00-07:30 0.50 FISH PULD WRKOVR R/D and L/D fishing tools consisting of 3 1/ 8" DC's and circ equipment. 07:30-09:00 1.50 WELOTLBOPE WRKOVR Set test plug for BOPE test. RU to test BOP E. Witness of test waived by AOGCC rep Ch uck Scheve. 09:00-10:30 1.50 WELCTLBOPE WRKOVR Test BOPE to 250 psi Iow and 3500 psi high. 1st test: Lower pipe rams. Fix leaking bus hing. Repeat test, OK. Function Test Accum ulator. 2nd test: Blind rams and HOR valve s on choke and kill lines. Blow down and R/ d test equipment. 10:30-14:00 3.50 FISH PULD WRKOVR PU (2) 3 1/8" DC's to fish with. MU 4 1 1/16" overshot w/ 3 1/8" grapple. Engage fish -pu II off of fish twice.. POOH. LID overshot and 3 1/8" dc's. R/D pumping equipment. 14:00-16:00 2.00 FISH PULD WRKOVRiMU 4 11/16" overshot w/ 3 1/16" grapple on !a jt of 3 1/2" tubing, pick up pup joints, get over fish. PU 15 k, pull free of fish. POOH , change grapple to 3 1/2" and add extensio n. TIH. 16:00-18:00 2.00 FISH RURD WRKOVR Get over fish. PU 10 K. L/D top pup. RU to c rc thru GLM @ 7000'. 18:00-20:30 2.50 FISH CIRC WRKOVR Circ @ 2bpm w/ 1750 psi. 20:30-22:30 2.00 FISH SLIN WRKOVR R/D pumping equipment. RU HOWCO slicklin e to drift tubing. RIH to 1783' w/ 2.48" drift Stopped. POOH w/ 2.48" drift. 22:30-00:00 1.50 FISH SLIN WRKOVR HOWCO RIH w/ 2.48" top centralizer, 11' of 2.385" drift, and 2.515" centralizer on bott om, 4/25/2002 00:00-00:30 0.50 FISH SLIN WRKOVR Continue in hole w/ HOWOO 2.48" top centra lizer, 11' of 2.385" drift, and 2.515" centrali zer on bottom 00:30-02:30 2.00 FISH SLIN WRKOVR Continue to RIH w/ slickline. At 5000' pump @ l bpm, 1100 psi to help line in hole. Rea ched 6982' w/ drift. 02:30-03:00 0.50 FISH SLIN WRKOVR R/D Howco slickline tools. 03:00-06:00 3.00 FISH ELIN WRKOVR RU Schlumberger WL 06:00-06:30 0.50 FISH ELIN WRKOVR PJSM prior to running explosives in hole. 06:30-11:00, 4.50 FISH ELIN WRKOVR MU COL and string shot @ 320 grain. RIH to I 1000'. Log 1000' to 200'. String shot @ 946 to 952' WLM (Rig 245 orig. measurements) POOH w/ WL. 11:00-12:30 1.50 FISH CIRC WRKOVR RU to circ. Circ 78 deg mud @ lbpm & 1200 psi. Returns @ 68 deg. I Printed: 5/13/2002 9:24:39 AM i Perati°nS summary RePort Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: ~!~: Date ~:~l~From~To Hours:~: ,Code~l~:,: ,~ Phase ~: ~: Description of Operations 4/25/2002 12:30-15:00 2.50 FISH ELIN WRKOVR PdSM. Run CCL & chemical cutter. Cut @ 94 8' WLM(rig 245 orig. measure) POOH w/ C CL and chemical cutter. 15:00-16:30 1.50 FISH ELIN WRKOVR R/D Schlumberger and pumping equipment. L /D baker fishing tools and parted jt of 3 1/2 "tubing. 16:30-18:00 1.50 FISH PULL WRKOVR PJSM. L/D 3 1/2" tubing fish. Total of all j oints from this fishing job' 1 parted joint, 2 6 joints and the cut joint. 18:00-21:30 3.50 FISH IPULD WRKOVR PU overshot, x-o, 30 joints 3 1/2" tubing, 10 ' tubing pup joint. RIH to top of fish @ 945' (Rig 19E RT) (Rig 245 RT = 951') PU 1 jt of 3 1/2" HWDP & safety valve, RU circ. hose. 21:30-23:00 1.50 FISH FISH WRKOVR Establish circulation. Latch onto fish. PU to 65K weight indicator weight. Pull off of fish Latch back onto fish. PU to 80 k on weight indicator. 23:00-00:00 1.00 FISH ClRC WRKOVR Circ @ 2.5 bpm , 30 spm & 1500 psi. 4/26/2002 00:00-01:00 1.00 FISH ClRC WRKOVR Circ @ 2bpm w/ 1300 psi. Up rate to 3bpm & 1 400 psi. 01:00-01:30 0.50 FISH ClRC WRKOVR Circ @ l bpm w/ 350 psi. Work pipe f/ 50k to 115k. Increase circ rate to 3.5 bpm & 1800 psi. Overshot grapple released whith pull o f 140k and .5 bpm circ rate. Try to re-engag e fish. Could not get over top of fish @ 945' 01:30-03:30 2.00 FISH PULD WRKOVR L/D (2) 3 1/2" HWDP. POOH w/ 10 stands 3 1/2" tubing and 10' tubing pup joint. 03:30-05:00 1.50 FISH PULD WRKOVR Change out grapple and packoff on overshot Add bowl extension. 05:00-06:00 1.00 FISH TRIP WRKOVR RIH w/ new grapple and packoff on 10 stand s 3 1/2" tbg. 06:00-06:30 0.50 FISH FISH WRKOVR Engage fish @ 945'. 06:30-07:30 1.00 FISH ClRC WRKOVR RU to circ. 07:30-09:00 1.50 FISH ClRC WRKOVR RU side entry sub. Perform stretch test f/ 7 5k to 125k. 23" f/ 75k to 100k= 5957' 21" f / 100k to 125k= 5700' 09:00-11:30 2.50 FISH ELIN WRKOVR RU Schlumberger to run freepoint. Hang she ave in derrick. Baseline stretch readings @ 2320'. 11:30-12:30 1.00 RIGMNTOTHR WRKOVR Straighten wraps on deadman f/ drilling line Caused by jumping off of fish. Hang blocks and realign wraps. 12:30-21:30 9.00 FISH ELiN WRKOVR Run freepoint w/ Schlumberger down to 7045 WLM. Freepoint to 7030' WLM. POOH w/ fr eepoint. Stretch baseline @ 2320' - .... 100 % free Some troubleshooting of operation o f tools. 3514'----100% free 4995'----100% f ree 6108'----100% free 6931'----100% free 6997'----100% free 7030'----100% free 21:30-00:00 2.50 FISH ELIN WRKOVR PJSM. Run 8' stringshot in hole. 4/27/2002 00:00-02:30 2.50 FISH ELIN WRKOVR RIH w/ Schlumberger string shot w/ 240 grai I I I Printed: 5/13/2002 9:24:39 AM :: op ati nssummarYlReport Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date' 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: ':::Date,~,:;~:::Erom~To ~Hours: Code : .... ,~:~: ':~Phase : ':::::,,,:, Description of Operations :Code: :: :: 4/27/2002 00:00-02:30 2.50 FISH ELIN WRKOVR n charge. Shoot 6999' to 7007' WLM. POOH 02:30-03:30 1.00 FISH ELIN WRKOVR RU Bromium Trichloride chemical cutter w/ COL and weight bars. 03:30-04:00 0.50 FISH SFTY WRKOVR PJSM w/ Schlumberger on chemical cutters. 04:00-06:30 2.50 FISH ELIN WRKOVR RIH w/ Schlumberger chemical cutter. Expen d guns @ 7004' WLM. @ 0600 hrs. POOH. To ols stuck in top GLM @ 3395' WLM. Pull 360 0 lbs. line pull. Safe pull is 4000 lbs. 06:30-09:00 2.50 FISH CIRC WRKOVR Pump @ .5 bpm and 1050 psi. Increase pump s to .75 bpm and 1300 psi. Work pipe w/o pu mps 72 K up wt. Set slips, pump .75 bpm & 1400 psi. Increase pumps to 1.5 bpm @ 200 0 psi. Circ bottom's up @ 1.5 bpm. 14.4ppg mud to surface @ 700 strokes 13.3 ppg mu Id to surface @ 1 100 strokes. Final circ rat ia and pressure = 2.7 bpm & 1700 psi. 09:00-11:30 2.50 FISH ELIN WRKOVR Try to work Schlumberger tools free. No goo d. Get slow pump rates @ .5 bpm up to 2 bp m. 11:30-12:00 0.50 FISH ELIN WRKOVR Pull on Schlumberger line to 3800 lbs line p ull. Pulled free through tight spot @ 3395' WLM. 12:00-13:00 1.00 FISH ELIN WRKOVR POOH w/ Schlumberger tool string to 200'. P JSM on tool extraction. Con't POOH w/ Schl umberger chem cutter tools. 1 anchor was s ticking out-- causing downhole problem. 13:00-15:00 2.00 FISH ClRC WRKOVR RU circulating equipment and circ 36 spm @ 1850 psi f/ 2150 strokes. 15:00-17:00 2.00 FISH TRIP WRKOVR POOH fishing assembly 10 stands. Stand ba ck in derrick. ;17:00-17:30 0.50 FISH PULL WRKOVR L/D cut joint # 103. Length of piece = 9.72'. L/D overshot. 17:30-19:30 2.00 FISH PULL WRKOVR POOH, stand back 25 stands of fish (3 1/2" 9.3 #/ft L-80 tubing) 19:30-21:00 1.50 FISH PULL WRKOVR L/D GLM with pups, L/D 10 singles of 3 1/2" EUE tubing. Mud running out of tubing strin g weighed 12 ppg. 21:00-00:00 3.00 FISH ClRC WRKOVR Circ out 12 ppg mud from tubing string. Circ out 47 bbls of 13 ppg or less mud. Circ tor al of 1709 strokes. Circ @ .5 bpm = 400 psi Circ @ 2 bpm = 800 psi. 4/28/2002 00:00-03:30 3.50 FISH PULL WRKOVR Monitor wel. POOH L/D 93 joints 3 1/2" tubi ng. Monitor well. 03:30-05:30 2.00 WELCTLBOPE WRKOVR Set test plug. Inspect lower ram cavities. O K. Change upper pipe rams to 2 7/8" 05:30-06:30 1.00 WELCTLBOPE WRKOVR RU to test upper pipe rams. 06:30-08:30 2.00 WELCTLBOPE WRKOVR 'est upper rams and HCR on choke side to 2 50 psi Iow & 3500 psi high. Test inside bop (dart valve) 250 psi Iow & 3500 psi high. 08:30-09:30 1.00 WELCTLOTHR WRKOVR Set wear bushing in wellhead. 09:30-10:00 0.50 FISH OTHR WRKOVR Clean rig floor 10:00-12:30 2.50 FISH IPULD WRKOVR PU & MU fishing BHA. MU spear & jars on 3 I 3/8" DC's. Printed: 5/13/2002 9:24:39 AM : o .erati ns summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: ~rsI I h~: : : ~ Description of Operations 4/28/2002 12:30-16:00 3.50 FISH TRIP WRKOVR PU 2 7/8" drill pipe, RIH to 2056' (55 joints) 16:00-17:00 1.00 FISH CIRC WRKOVR Circulate and condition mud. 17:00-19:00 2.00 FISH TRIP WRKOVR Continue to PU 2 7/8" dp, RIH to 4056' (120 joints). 19:00-20:00 1.00 FISH CIRC WRKOVR Circ and condition mud @ 2bpm w/ 1850 psi f/ 1046 strokes. 20:00-21:30 1.50 FISH TRIP WRKOVR PU 2 7/8" DP. RIH to 6043' (185 joints). 21:30-23:00 1.50 FISH CIRC WRKOVR Circ and condition mud @ 2bpm w/ 2500 psi f/ 1441 strokes. 23:00-00:00 1.00 FISH TRIP WRKOVR PU 2 7/8" DP, RIH to 6964' (215 joints). iPU wt 85 k SO wt 40 K 4/29/2002 00:00-01:00 1.00 FISH CIRC WRKOVRiRU to circ- PU 2 more 2 7/8" dp( joints 216 !& 217), ICP @ 14 spm = 2000 psi. Circ @ 20 spm & 2000 psi. Circ 1100 strokes. 01:00-02:00 1.001FISH FISH WRKOVR Engage fish. Jar on fish. Fish came loose w hile trying to work down. 02:00-03:30 1.501FISH CIRC WRKOVR Circ @ 1.5 bpm & 1900 psi. Circ 1330 stroke s 03:30-04:00 0.50 FISH FISH WRKOVR Try to go down. Taking weight. L/D single & circ equip. 04:00-05:00 1.00 FISH TRIP WRKOVR Monitor well. POOH 1 stand. Drop dart to op en pump out sub. Pump dry job 14ppg, open sub w/ 2800 psi. 05:00-10:30 5.50 FISH TRIP WRKOVR POOH wet 72 stands 2 7/8" dp w/ fishing as sembly. 10:30-12:30 2.00 FISH TRIP WRKOVR Monitor well @ BHA. Clean up rig floor. L/D accelerator jars and (2) 3 3/8" DC's. Set ba ck DC's. No fish. Calc hole fill 33.7 bbls--- -Actual hole fill 35.5 bbls= 1 .8 bbls over cai C. 12:30-13:00 0.50 FISH OTHR WRKOVR Redress grapple on spear. Redress pump ou t sub. 13:00-18:30 5.50 FISH TRIP WRKOVR MU BHA & RIH w/ 2 7/8" DP to fish 3 1/2" tu bing. Displacement 3.2 bbls under calc. 18:30-19:30 1.00 FISH CIRC WRKOVR Circ @ 2 bpm & 2500 psi, total of 1300 stro kes. 19:30-00:00 4.50 FISH JAR WRKOVRILatch onto fish @ 7012' dp measurement. Ja r up @ 135k weight indicator. String weight 77 k with pump on. 4/30/2002 00:00-05:00 5.00 FISH JAR WRKOVR Jar on fish @ 7012' Work pipe f/ 30k to 210 k. Unsuccesfull jaring fish free. Moved 8' u p hole. 05:00-05:30 0.50 FISH OTHR WRKOVR Disengage f/ fish. 05:30-07:00 1.50 WELCTLOTHR WRKOVR R/D circ head. L/D single dp. Stand back 2 stands in derrick. PU/MU HOWCO RTTS w/ c ontrol valve (storm packer). RIH w/ 2 single / S of 2 7/8" dp. Set packer @ 36' 07:00-07:30 0.50 WELCTIIOTHR WRKOVR test HOWCO RTTS & controlvalve to 1000 p OTHR WRKOVR si. 07:30-08:00 0.50 WELCTL R/D blow down all test lines. Bleed off pres sure on 7 5/8" x 5 1/2" annulus. 08:00-09:00 1.00 WELCTLNUND WRKOVR N/D BOP stack. Remove tubing spool. Printed: 5/13/2002 9:24:39AM i i : :~i,~,~S ALASKA INc. Page 11 of 13 OPeratiOns summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: ; : :::::!:: ::; : :;: ::::!::::: :: ;' : : :::I :;::: ': i:: : :::;::::::I 4/30/2002 09:00-10:30 1.50 WELCTLNUND WRKOVR Remove packoff f/ 5 1/2" csg. Replace pack off w/ Gen 4 packoff. Install new FMC Gen 4 tubing spool. 10:30-14:30 4.00 WELCTLNUND WRKOVR Change out bottom bolts on adapter spool (7 1/16 5M x 11" 5M). Change Driller side ai r hoist line. Set BOP stack back in place. NU BOPE. 14:30-16:00 1.50 WELCTLBOPE WRKOVR PJSM. RU test equip. Test breaks to 250 psi and 3500 psi. 16:00-17:30 1.50 WELCTLOTHR WRKOVR R/D test equip. Set wear bushing. 17:30-18:00 0.50 RIGMNT;RGRP WRKOVR Electrician repair fuses in SCR. 18:00-20:00 2.00 FISH ClRC WRKOVR RU circ equip. PU 2 its 2 7/8" dp, retrieve s term packer, L/D HOWCO RTTS. 20:00-21:00 1.00 FISH TRIP WRKOVR Attempt to run blocks up to latch onto a sta nd of 2 7/8 dp. Wind blowing. Stopped block s. Hit girt in derrick. Sent up man to inspec t girt. OK. 21:00-22:00 1.00 FISH TRIP WRKOVR PU 6 joints of 2 7/8" dp instead of 2 stands. Latch onto fish. 22:00-23:00 1.00 FISH FISH WRKOVR Work left hand torque in pipe. DP backed of f. Screw back into DP. Release f/ fish. 23:00-00:00 1.00 FISH ClRC WRKOVR Circ & cond mud @ 22 spm w/ 2200 psi. 5/1/2002 00:00-09:00 9.00 FISH ClRC WRKOVR Circ @ 2 bpm & 2200 psi. Phase 3 weather c onditions. Work on housekeeping & rig clean up. Service drawworks, inspect input chains 09:00-11:00 2.001 FISH OTHR WRKOVR RU to test 51/2" x 3 1/2" casing, to see if c an pump by fish. Pressured up to 690 psi (. 423 bbls)--pressure down to 525 psi in 1 hr. Lost 165 psi in 1 hr. Bleed 9 gal (.21bbl s) f/ 7 5/8" x 5 1/2" annulus while monitorin g pressure. 11:00-13:30 2.50 FISH ClRC WRKOVR Circ @ 2 bpm & 2200 psi. Still phase 3 weat her. 13:30-15:00 1.50 FISH OTHR WRKOVR Close annular preventer, open 7 5/8" x 5 1/2 "to atmosphere. Pressure up to 1100 psi on 5 1/2"x 3 1/2" casing (.6 bbls fluid)--pressu re down to 895 psi in 1 hour. Lost 205 psi in 1 hr. 7 5/8" x 5 1/2" annulus gave back 24.79 gal (.59 bbls) to bleed tank. 15:00-15:30 0.50 FISH OTHR WRKOVR R/D pumping equipment. Blow down lines. 15:30-00:00 8.50 FISH TRIP WRKOVR Change f/ Phase 3 to Phase 2 weather cond itions. POOH L/D 2 7/8" DP w/ fishing assem bly. 5/2/2002 00:00-02:00 2.00 FISH TRIP WRKOVR Finish L/D 2 7/8" drill pipe. 02:00-02:30 0.50 FISH TRIP WRKOVR RIH w/ 2 stands 2 7/8" dp f/ Derrick. L/D sa me 02:30-03:00 0.50 FISH OTHR WRKOVR Monitor well. Clean up rig floor. 03:00-04:00 1.00 FISH TRIP WRKOVR L/D (11) 3 3/8" DC's and fishing assembly 04:00-04:30 0.50 FISH OTHR WRKOVR Clean up rig floor. Prep to wireline w/ Schlu mberger. 04:30-05:00 0.50 ABANDh PLUG SUSPEN RU Schlumberger WL. 05:00-08:00 3.00 ABAND~OTHR SUSPEN Schlumberger RIH w/ 4.5" guage ring and ju / Printed: 5/13/2002 9:24:39AM ; :: : i i:::::::: fl :: :;; ::i: : ;::i::i i:: :i : :i i i i ;;O erations summary Report Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: ' Description of Operations 5/2/2002 05:00-08:00 3.00 ABANDNOTHR SUSPEN nk basket to 6982'. 08:00-09:00 1.00 ABANDhPLUG SUSPEN RU Schlumberger WL to run Baker Model K-1 wireline set ClBP. 09:00-11:00 2.00 ABANDhPLUG SUSPEN RIH w/ Baker model K-1 wireline bridge plug (4.3" OD) on Schlumberger WL. Set Top of Bridge plug @ 7000' WLM. 11:00-11:30 0.50 ABANDh. PLUG SUSPEN Schlumberger POOH w/ wireline. Running/se tting tool string stuck in hole @ 5830' WLM. 11:30-15:00 3.50 ABANDhPLUG SUSPEN Pull and work wireline to maximum of 6300 I bs line pull. Would not free up. Rig up to pu II free of rope socket w/ "T- Bar" and elevat ors w/ rig. Pull free w/ 7K overpull on weigh t indicator. Schlumberger POOH w/ wireline and rope socket. 15:00-17:00 2.00 ABANDI~OTHR SUSPEN RU to test casing to 1225 psi f/ 20 rain, the n increase to 2600 psi f/ 10 min. 10 min tes !t @ 2600 psi--lost 15 psi. 17:00-19:00 2.00 FISH TRIP SUSPEN !PU BHA to fish Schlumberger toolstring f/ w TRIP !ell. Top of toolstring @ 5823' WLM. 19:00-00:00 5.00 FISH SUSPEN Trip in hole w/ fishing assembly and 3 1/2" t I ubing to catch Schlumberger toolstring. 5/3/2002 00:00-00:30 0.50 FISH TRIP WRKOVR PU used 3 1/2" 9.3#/ft, EUE, L-80 tubing fro m pipe shed, RIH 00:30-01:00 0.50 FISH ITRIP WRKOVR PU 10 stands of the new 9.3#/ft, EUE, L-80 WRKOVR tubing from derrick. 01:00-02:00 1.00 FISH ClRC CBU pumping @ 30 spm & 1800 psi. 02:00-03:00 1.00 FISH FISH WRKOVR Attempt to engage fish @ 5823'. Pumping 8 spm & 600 psi. Up wt 65 k Down wt 35 k No success, PU 1 single, pumped single dow n NO fish I ' · 03:00-04:30 1.50 FISH OTHR WRKOVRpipe Load shed· and strap 3 1/2" tubing f/ outside into 04:30-07:30 3·00 FISH FISH WRKOVR PU 3 1/2" EUE old tubing f/ pipe shed, RIH w/ fishing assembly. 07:30-09:00 1.50 FISH ClRC WRKOVR CBU @ 20 spm & 2500 psi until mud evens o ut @ 13·3 ppg. 09:00-09:30 0.50 FISH FISH WRKOVR Tag fish @ 6988' dpm. Up wt 80 k Down w t 35 k 09:30-10:00 0.50 FISH OTHR WRKOVR Blow down lines and clean rig floor· 10:00-12:00 2.00 FISH FISH WRKOVR,POOH w/ fishing assembly f/ 6988' to 4076'· 12:00-16:00 4.00 FISH FISH WRKOVR POOH w/ fishing assembly f/ 4076' to surfac e. NO fish. 16:00-16:30 0.50 FISH PULD WRKOVR Breakdown overshot and inspect 3 3/8" grap 31e. 16:30-18:00 1·50 FISH PULD WRKOVR Grapple showed signs of being over fish· Ch ange grapple to 3 5/8". Change crossover bushing to one with 3 11/16" ID. 18:00-23:30I 5.50 FISH TRIP WRKOVR RIH w/ fishing assembly to 6966' (70 stands of 3 1/2" eue tubing). 23:30-00:00 0.50 FISH iTRIP WRKOVR PU single 3 1/2" tubing, RU circ equip· Brea i k circ @ l bpm & 1500 psi. PU wt w/o pumps ClRC 80 k SO wt w/o pumps 38 k 5/4/2002 00:00-01:00 1.00 FISH WRKOVR Circ @ 34 spm & 2500 psi prior to engage fi I Printed: 5/13/2002 9:24:39 AM Legal Well Name: 3F-19 Common Well Name: 3F-19 Spud Date: 4/2/2002 Event Name: WORKOVER/RECOMP Start: 4/10/2002 End: 5/5/2002 Contractor Name: naborscm@ppco.com Rig Release: 5/5/2002 Group: Rig Name: Nabors 19E Rig Number: i: i ~at~: 'i: '~!~i:~ l:~i~rs' ~ !i~ :~ih~ Description of Operations 5/4/2002 00:00 - 01:00 1.00 FISH CIRC WRKOVR s h. 01:00-02:30 1.50 FISH FISH WRKOVR Tag fish @ 6979'. Jar on fish. 02:30-03:00 0.50 FISH OTHR WRKOVR Blow down circulating lines. RU to L/D 3 1/2 "tubing--fishing string. 03:00-11:30 8.50 FISH TRIP WRKOVR POOH w/ Schlumberger WL tool string fish f/ 6979' to surface. 11:30-12:00 0.50 FISH TRIP WRKOVR L/D Schlumberger WL toolstring. Appears that tools never fired to set Baker K-1 retai ner in 5 1/2" @ 7000'. 12:00-13:30 1.50 FISH OTHR WRKOVR L/D fishing tools and Baker equipment. 13:30-15:00 1.50 WELCTLOTHR WRKOVR Pull wear bushing f/ FMC Gert 4 tubing head. Damage to wear bushing due to L/D screws being screwed in too tight. 15:00-16:00 1.00 CMPLTNRUNT WRKOVR PJSM. RU to run 3 1/2" tubing "kill string" t o 2407'. 16:00-17:30 1.50 CMPLTNRUNT WRKOVR MU hanger to landing joint, run hanger in tu bing spool to check for fit after having some trouble pulling wear bushing. 17:30-19:30 2.00 CMPLTNRUNT WRKOVR RIH w/ 3 1/2" tubing f/ derrick. Run total of 75 joints old tubing. Place Camco DS nipple w/ 2.812 packing bore @ 509.87'. Run tubin g to 2407.34'. 19:30-21:30 2.00 CMPLTNOTHR WRKOVR Drain BOP stack. Flush pumps and lines w/ f resh water. Pump through kill and choke lin es, cement line, fillup line. and poor boy de gasser. Blow down all lines. 21:30-23:00 1.50 CMPLTh, OTHR WRKOVR Land 3 1/2" tubing kill string @ 2407.34'. R U to test and test 5 1/2" casing to 2500'. Le ak on headpin RU @ floor. Tighten headpin and retest to 2500 psi f/ 30 min. Chart test. nitial pressure 2500 psi, final 2475 psi. Go od test. 23:00-00:00 1.00 CMPLTNOTHR WRKOVR R/D GBR tools and remaining Baker tools fro m rig floor. 5/5/2002 00:00-01:00 1.00 ABANDi~OTHR CMPLTN Laying down GBR tubing tools and Baker Fis hing tools. 01:00-05:30 4.50 ABANDIXNUND CMPLTN Nipple Down BOPE. 05:30-09:30 4.00 ABANDr~NUND CMPLTN Nipple up tree. Test packoff to 5000 psi. Te st tree to 4000 psi. 09:30-12:00 2.50 ABANDNOTHR CMPLTN Freeze protect well by pumping 49 barrels di esel down 3.5" x 5.5" annulus taking returns up tubing, tubing tail at 2407'. 12:00-12:30 0.50 ABANDNOTHR CMPLTN Install BPV and VR plug on 3.5" x 5.5" annul us valve. !12:30-18:00 5.50 ABANDNOTHR CMPLTN Clean mud tanks. Clean up in cellar. Releas e rig at 1800 hours 05/05/2002. :18:00-00:00 6.00 MOVE DMOB DEMOB Rigging down for move to Prudhoe Bay. ! Printed: 5/13/2002 9:24:39 AM PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 April 30, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 3F-19 Application for Sundry Approval (APD 196-102) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to suspend the Kuparuk well 3F- 19. If you have any questions regarding this matter, please contact Skip Coyner at 265-6074. Sincerely, Kuparuk Drilling Team Leader PAI Drilling RT/skad RECEIVED A?'R 3 0 2002 J~Jas[~ Oil & Gas (Jofif¢. (jofflfi'ii~giof, A~lchorag¢ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_XX Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5239' FNL, 126' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 690' FNL, 301' FEL, Sec. 19, T12N, R9E, UM At effective depth At total depth 376' FNL, 334' FEL, Sec. 19, T12N, R9E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (asp's 508372, 5985863) (asp's 508141, 5990726) 6. Datum elevation (DF or KB feet) RKB 96 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3F-19 9. Permitnumber/approvalnumber 196-102 10. APInumber 50-029-22680 11.Field/Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' SUR. CASING 3890' PROD. CASING 7453' LINER 578' LINER Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) Size 16" 7-5/8" 5-1/2" 3-1/2" 8132 6290 7867 6080 feet Plugs (measured) feet feet Junk (measured) feet Oemented 260 sx AS 1 1060 sx AS III, 330 sx Class G 250 sx Class G included above 7644'-7654',7852'-7872' 5908'-5915',6069'-6084' 3-1/2", 9.3#, L-80 Tbg @ 7553' MD. no packer NO-GO CAMCO 'DS' LANDING @ 491' MD. Measured Depth True vertical Depth 121' 121' 3986' 3214' 7549' 5834' 8127' 6286' .m~ '-z G~S C0fl~,, Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation April 30, 2002 16. If proposal was verbally approved 'Date approved 15. Status of well classification as: Oil __X Gas _ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Kuparuk Drilling Team Leader R. Thomas FOR COMMISSION USE ONLY Questions? Call Skip Coyner 265-6074 Date Prepared b,y Sharon AIIsup~Drake 263-4612 Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- L~.~_..% Ong~nai Signed By Approved by order of the Commission Camm)/Oech81i Tayl~~ Commissioner J Approval no. Form 10-403 Rev 06/15/88 · , / SUBMIT IN TRIPLICATE 3F- 19 Suspend The Well Well Geometry (see diaqram): Production Casing 5-1/2" 15.5# L-80 Surf - 7549' Tubing 3-1/2" 9.3# L-80 Surf - 7541' Camco "DS" nipple 491' (ID = 2.812") & 7533' (NoGo = 2.75") GLM's 3419', 5060', 6173', 7000', 7480' Baker GBH-22 Locator 7541' w/tail pipe to 7553' (4.5" OD) Maximum angle is 45.5° at 3060' MD Maximum Dog Leg is 4.9°/100' at 453' MD Kick Off Point + 280' BHP is = 3870 psi @ 5908' TVD Fish (518.40'): · (1) ·(13) · (1) · (1) · (1) · (1) · (1) · (1) · (1) 3.5" tubing jnt (Chemical cut) 3.5" tubing joints 3.5" pup jnt "ATX" GLM 3.5" pup jnt 3.5" tubing joint 2.75" DS nipple 3.5" pup jnt Baker GBH-22 Iocator seal assembly Ric~ Work: 1. Set at storm packer and repair the casing head packoffs. Test same to 3000 psi. 2. Circulate and condition the mud. Add biocide as required. LDDP and the storm packer. 3. RU E-Line. Run a gage ring and junk basket to TOF at > 7000' MD. Set a CIBP at TOF. 4. RIH with the tubing out of the derrick (+_ 2400') for a freeze protect string. Install a "DS" nipple in the tubing at +_ 500' MD. Hang the tubing in the tubing head. RILDS. Test the CIBP and casing to 2500 psi for 30 minutes on chart. Set a BPV/TWC & VR plug. ND BOP's. NU Tree. Test the tree to 4000 psi. 6. Freeze protect to 1500' TVD. RDMO Nabors 19E. . 4/30/02 VMC Version 1 13 ppg Mud · The fish is plugged inside the GLM. · We cannot inject Past the fish. 3F- 19 (T/A Proposal) 7-5/8", 29.7#, L-80 at 3986' MD (3214' TVD) 5-1/2, 15.5#, L-80 at 7536' MD The Fish (518.40'). TOF at 7012' MD · (1) 3.5" tubingjnt (Chemical cut) · (13) 3.5" tubing joints · (1) 3.5" pupjnt · (1) "ATX" GEM · (1) 3.5" pupjnt · (1) 3.5" tubing joint · (1) 2.75" DS nipple · (1) 3.5" pupjnt · (1) Baker GBH-22 locator seal assembly 5" x 4" CSR 7536' - 7548' MD 5-1/2" x 3-1/2" Crossover IEst'd BHP = 3850 psi I Zone C-4: 7644' - 7654' MD, 5908' - 5915' TVD Zone A-3: 7852' - 7872' MD, 6069' - 6084' TVD 3-1/2, 9.3g, L-80 at 8127' MD (6286' TVD) Re: 3F-19 Workover Subject: Re: 3F-19 Workover . Date: Wed, I May 2002 15:41:42 -0800 From' '¥ern M Coyner" <vmcoyne@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Last fall, we stuck a slick line swage in the bottom GLM at 7480' MD. Attempts to retrieve the swage were futile. While attempting to fish the swage, we knocked scale off the tubing wall and it covered up the fish. We cannot pump through the fish inside GLM #1 but formation pressure does leak through to surface. The well was shut in and it was decided to do a dg workover. When the well was shut in six months ago, it had a 9.3 ppg gradient. Since being shut in, the WAG injectors have caught up and the BHP is now equivalent to a 12.6 ppg gradient. This was confirmed during pre-rig preparation work. The asset group decided to use BARADRILn for kill fluid instead of expensive brine. The problem is that we could only circulate through GLM #2 located 510' above the Iocator seal assembly. We believe that we dropped out CaCO3 in the IA between GLM's #1 and #2 while we were killing the well. Whether that actually happened or not is debatable but the bottom line is that we cannot jar the fish loose. We cannot pump through the tubing because of the original slick line fish and we cannot bullhead around the outside of the fish because it's packed off: pressure bleeds off from 1100 psi to 900 psi in an hour. In that we have a 3-1/2" EUE fish stuck inside 5-1/2" casing, further options are extremely limited and we have decided to suspend the well/operation. The well will be evaluated for sidetrack potential and/or additional workover efforts. Of interest is the tubing failure we had when initially trying to pull out of the casing seal recepticle at 7450' MD. The 3-1/2", 9.3#, L-80, EUE tubing has a body yield of 207,200#. We limited the pull to 80%: 165,700# but the second joint below surface failed in tension anyway: a classib hourglass neck-down and part. Furthermore, all of the first 20 joints sufferred plastic deformation and a few joints were + 34' long. The investigation is ongoing. Let me know if you have further questions or suggestions. We should be laying down the work string as soon as the Phase III lets up. Skip Coyner 265-6074 1 of 1 5/1/02 5:13 PM PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 07/21/98 RUN RECVD 96-102 96-102 96-102 CBL ARC5 7540 10-407 ~7460-7876 /949-8088 ~~SCHL~ ARC5 ~OMPLETION DATE ~/ ~ / ~/ FINAL 09/25/96 FINAL 12/06/96 1 12/06/96 / o/~ ~ I¢~ DAILY WELL OPS P, b//¥/~/ Are dry ditch samples required? yes ~d received? Was the well cored? yes ~alysis & description received? Are well tests required?.~-! yes Received? y~-~no ........... Well is in compliance InStial COMMENTS 12/5/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10611 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 3F-19 ~1(~-IC~'7... ~-~75'-10 96197 ARC5 960629 I I 1 SIGNED- Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ARCO Al.aska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 25, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-19 (Permit No. 96-102) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3F-19. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development O¢i6i qAL DKP/skad OCT ? 9 !.9{~-S a~ao,.-,,,, o,,~ Of! & Gas Cons. Corrmxss~on Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION U,..,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS [--"] SUSPENDED [~ ABANDONED [] SERVICE r'~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-102 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~ ....................... 50-029-22680 4 Location of well at surface I (;U;',,i ?i.:.:'i !'~!~ ' 9 Unit or Lease Name 37' FSL, 124' FEL, Sec. 19, T12N, R9E, UM i Kuparuk River Unit -' i 10 Well Number At Top Producing Interval i . 690' FNL, 301' FEL, Sec. 19, T12N, ReE, UM ~ ~.__~"; ! ~i'~~i; 3F-19 .............__ r~ '55o !. 11 Field and Pool - At Total Depth 379' FNL, 334' FEL, Sec. 19, T12N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Rig RKB 41', PAD 55'I ADL 25632 ALK 2565 12 Date Spudded22_Jun_96 13 Date T.D. Reached29_Jun_96 14 07-Aug-9eDate Comp. , Susp. or Aband. (per f'd) 115 water Depth' if OffshOreNA feet MSL 116 No. of Completionsl 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey J20 Depth where SSSV set 21 Thickness of permafrost 8132' MD & 6290' TVD 8062' M D & 6233' TVD YES IXI NO LII NA feet MD = 1380' ss APPROX 22 Type Electric or Other Logs Run ARC5/GR, G R/CCL/SLTJ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WI' GRADE TOP BTM HOLE SIZE CEMEN1- RECORD 16" 62.5# H-40 SURF. 121' 24" 260 sx AS I 7.625" 29.7# L-80 SURF. 3986' 9.875" 1060 sx AS III Lead, 330 sx Class G Tail 5.5" x 3.5" 15.5#/9.3# L-80 SURF. 8127' 6.75" 250 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/MDI 3.5" 7553' 7852'-7872' MD 4 SPF 6069'-6084'TVD :26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7852'-7872' total of 247,048# proppant placed in perfs, left 13627# in wellbore. 27 PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) 8/14/96J Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/7/96 8 TEST PERIOD I~ 263 378 122 176 1206 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY~APl (corr) Press 189 930 24-HOUR RATE I~ 790 1136 366 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL '"T ? .9 luu:o Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~_9. 30. ' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, ~4EAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7628' 5895' Bottom Kuparuk C 7708' 5957' Top Kuparuk A 7830' 6052' Bottom Kuparuk A 8000' 61 83' Annular pump volume: Categories: 1. 15294 2. 100 3.0 Total this period: 15394 Total to Date: 15394 FREEZE PROTECT ANNULUS WITH DIESEL 31. LIST OF A-I-rACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ail 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". ~ ...... ~ ~ ~ 1\/,, ::, · Form 10-407 0("'[ O r} '~:'"'' Date: 7/3/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:3F-19 RIG:PARKER WELL ID: AK8573 AFC' AK8573 -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST TYPE' FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK: FINAL: WI: 55% SECURITY:0 AFC EST/UL'$ OM/ OM API NUMBER: 50-029-22680-00 6/14/96 (1) PBTD: 121' (0) SUPV:DCL DAILY: MW: PV/YP: APIWL: MOVE RIG FROM 2M TO 3F Prep rig for skid. Prep rig for move. $29,108 CUM: $29,108 ETD: $0 EFC:$29,108 6/15/96 (2) PBTD: 121'(0) SUPV:DCL DAILY: MW: PV/YP · APIWL · MOVE RIG AT 4 CORNERS Pre-job safety meeting. Move drill and utility modules 1.9 miles. $29,108 CUM: $58,216 ETD' $0 EFC:$58,216 6/16/96 (3) PBTD: 121'(0) SUPV:DCL DAILY' MW: PV/YP: APIWL: MOVE RIG AT CPF-2 Move drill and utility modules to 4 corners. Move modules. $3110 CUM' $61,326 ETD' $0 EFC:$61,326 6/17/96 (4) PBTD: 121'(0) SUPV:DCL DAILY: MW: PV/YP: APIW-L: UTILITY @ Y - DRILL MOD @ 2Z Continue to move drill and utility modules. $19,078 CUM: $80,404 ETD: $0 EFC:$80,404 6/18/96 (5) PBTD: 121'(0) SUPV:DCL DAILY: MW: PV/YP: APIWL: UM AT CPF3, DM 1 MI PAST iQ Move rig from 2Z to iQ. Lay plywood as needed. $19,128 CUM: $99,532 ETD: $0 EFC:$99,532 6/19/96 (6) PBTD' 121' (0) SUPV:DCL DAILY: MW: PV/YP' APIWL' PREP ROAD FROM 3B TO 3F Move drill module and utility module to 3B intersection. $19,413 CUM: $118,945 ETD: $0 EFC'$118,945 6/20/96 (7) PBTD: 121' (0) SUPV:DCL DAILY: MW: PV/YP' APIWL' SKID RIG OUT Move rig module and utility module to 3F. $35,836 CUM' $154,781 ETD: $0 EFC'$154,781 6/21/96 (8) PBTD: 121' (0) SUPV:DCL DAILY: MW: 9.0 PV/YP: 16/14 APIWL: 14.4 DRILLING AT 500' Accept rig @ 0600 hfs 6/21/96. Function test diverter. $130,073 CUM' $284,854 ETD: $0 EFC:$284,854 6/22/96 (9) MW: 10.0 PV/YP: 17/18 APIWL: 8.8 PBTD: 3866' (3745) SHORT TRIP @ 3996' (TD) SUPV:DCL Drilling and MWD survey from 121' to 3866' DAILY: $82,170 CUM: $367,024 ETD: $0 EFC:$367,024 6/23/96 (10) PBTD: 3996'(130) SUPV:DCL DALLY: MW: 10.0 PV/YP: 20/16 APIWL: 9.4 TEST BOPE Drilling and MWD survey from 3866' to 3996'. POH. Hole tight and swabbing. Backream and circ from 3300' to HWDP. RIH to TD. No problems. Pre-job safety meeting. RIH with 7-5/8" casing. Land casing with shoe at 3986'. Pump cement. $168,762 CUM: $535,786 ETD: $0 EFC:$535,786 6/24/96 (11) PBTD: 5103' (1107) SUPV:DCL DAILY: MW: 8.7 PV/YP: 8/8 APIWL: 8.8 DRILLING Test BOPE to 300/3000 psi. Test 7-5/8" casing to 2000 psi. Drill out cement, float equipment and new formation to 4006'. Performed FIT to 12.5 EMW. Drilling and MWD 6-3/4" hole from 4006' to 5103' $98,137 CUM: $633,923 ETD: $0 EFC:$633,923 6/25/96 (12) MW: 10.7 PV/YP: 14/11 APIWL: 6.2 PBTD: 7532' (2429) DRILLING SUPV:DCL Directional drill 6.75" hole from 5103' to 5208'. Hole packed off. Regain circulation and circulate hole clean. Large amounts of clay. Directional drill 6.75" hole from 5208' to 7532' DAILY: $92,073 CUM: $725,996 ETD: $0 EFC:$725,996 6/26/96 (13) PBTD: 7901'(369) SUPV:RLM DAILY: MW: 11.7 PV/YP: 26/18 APIWL: 4.2 KILLING WELL Took kick in 'A' sand, weighting up on choke to 11.7. $91,431 CUM: $817,427 ETD: $0 EFC:$817,427 6/27/96 (14) PBTD: 7901'(0) SUPV:RLM DAILY: MW: 12.4 PV/YP: 27/15 APIWL: 4.2 CIRC 12.6 MUD 12.4 OUT Well shut in. Circulate through open well and weight up. $90,278 CUM: $907,705 ETD: $0 EFC:$907,705 6/28/96 (15) PBTD: 8068' (167) SUPV: RLM DAILY: MW: 12.6 PV/YP: 26/17 APIWL: 4.0 CIRC AT TD Continue to circulate mud into well. Monitor well. Static. Directional drill from 7901' to 8068' $82,087 CUM: $989,792 ETD: $0 EFC:$989,792 6/29/96 (16) PBTD: 8132'(64) SUPV:RLM DAILY: MW: 12.6 PV/YP: 34/26 APIWL: 3.8 RUN PRODUCTION CASING Directional drill from 8068' to 8132'. Short trip to 7165' Pumped out through Kuparuk. RIH hit bridge 5' off bottom. Circulate and condition mud, no gas cut on bottoms up. POOH to 5621'. Monitor well, flowing. RIH to 7942' hit bridge. Circulate bottoms up. No gas cut mud. RIH to 8132' Circulate bottoms up. Monitor well static. It was determined that the well flow was caused by a slow falling pill. RU to run casing. Held pre-job safety meeting. $74,873 CUM: $1,064,665 ETD: $0 EFC:$1064,665 6/30/96 (17) PBTD: 8132'(0) SUPV:RLM DAILY: MW: PV/YP: APIWL: TEST BOPE Run 3.5" x 5.5" casing to 8127'TD. Cement casing. No returns to surface while cementing. CIP at 1535 hrs. 6/30. Floats did not hold. Shut in cement head with 1800 psi. Bleed off casing. Floats holding. Nipple down. Install and torque pack off. $155,707 CUM: $1,220,372 ETD: $0 EFC:$1,220,372 7/1/96 (18) PBTD: 8132'(0) SUPV:RLM DAILY: 7/2/96 (19) PBTD: 8132'(0) SUPV:RLM DAILY: MW: PV/YP: APIWL: RIG RELEASED Test all lines, valves, rams and hydril to 300/3000 psi. Held pre-job safety meeting. Run 3.5" completion. Test 3.5" x 5.5" casing to 3500 psi for 30 minutes. Freeze protect tubing and annulus. Release rig @ 0530 hrs. 7/2/96. $167,151 CUM: $1,387,523 ETD: $0 EFC:$1,387,523 MW: PV/YP: APIW-L: RIG RELEASED AT 0530 7/2/96 Install tubing head adaptor and master valve. Freeze protect 7-5/8" x 5.5" annulus. $39,915 CUM: $1,427,438 ETD: $0 EFC:$1,427,438 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A Kl(3F-19(W4-6)) 3F-19 DATE ,0,8/07/96 DAY 3 JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERF 'A' SAND OPERATION COMP~ [ SUCCESSFUL YES [ YES 0 PSI[ 1400 PSI [ 0 PSI SUMMARY JOB NUMBER 072596200O.5 UNTF ~ER KEY PERSON SUPERVISOR SWS-BAILEY PAIGE Final Irmer Ann I Initial Outer Ann I Final Ou% Ann 0 PSI 750 PSI 750 PSI DAILY [ PERF 'A' SAND INTERVAL 7852'-7872' (REF SLTJ DATED 7/27/96) USING 2-1/2" HOLLOW CARRIER W/BH CHARGES, 4 SPF, 180 DEGpH, ORIENTED 166 DEG CCW F/LOWSIDE. [ TIME LOG ENTRY 08:45 MIRU SWS. HELD SAFETYMTG. 10:00 11:00 12:00 13:00 PT LUB TO 2500~; TEST OK. Rill W/GUN#1 - CCL, MPD, 2-1/2" HOLLOW CARRIER W/BH CHARGES, 4 SPF, 180 DEG PH, ORIENTED 166 DEG CCW F/HIGH SIDE TO SHOOT 7852'-7872' (REF SLTJ DATED 7/27/96) IN POSITION TO SHOOT PERF INTERVAL; PUT 16004 ON WELLHEAD (200~ OVERBALANCED). FIRED GUN; WHP DECR TO 14008. POH. AT SURF W/GUN#l; ALL SHOTS FIRED. RDMO TO 1Q-02A. -P~E NO, LOCATION I LOCATION 2 ALASI<A I~NFt'IC DECLINATION - 27,71 ~RID CONVE~ENCE ~LE- 0 ~ HFJ~D ~TION: LAT(N/-S). O,OO RECE VEu AUG 20 1998 Alaska Oit & Gas Cons, t, orlmission Anchomg~.~ AZIMUTH ~ RDT~¥ TABLE TO TAR~ IS TIE IN POINT(TIP) TRUE VimT i)B~m INCLtI~TtON - I.,ATtTUI)E(tU-8) 121.00 121,00 0o00. 0,00 0.00 0.00 358,37 PAGE NO. 2 ~:AgJREI) I~ V~TIC~L DEPTH DEPTH ft 121.00 182.00 271,00 364,00 453,00- 550.80 647.79 740.23 8~2,80 924,23 ft 61.0 89.0 93.0 89.0 97.8 97.0 . 92.4 92.6 91.4 ft 121,00 I82.00 363.92 452,44 548,61 643,11 732.80 822,01 - 909,41 t015,69 1105,85 1200,04 1292.73 1387,32 91,5 995.72 90.2 1079,29 94,2 1164.56 92,7 1246.59 94,6 1329,44 TARGa' S]~'TION ft' 0.00 -0.04 0.06 3.20 12.20 ' 29o65 51.29 73.44 97+98 124.60 I.~I,70 188,45 228;26 271,17 316,53 1479,13 1572,70 1663,69 !75~6,76 1849,8t 203,68 2309,25 2689,16- 3(Y59,64 3702.83 - 3923,21 4122.49 .4306,25 4488,92. 91,8 93,6 ~.0 93,1 93.1 183.9 275,6 1408,38 363.24 1486,62 414,48 1560,89 466.96 1634,23 524.20 1704.00 585.73 1836,17. 713,53 2029.01- 910.23 379,9 2295,~ '1180,~ 370.5 2557,07 1442,92 369.7 273.5 220,4 199.3 I83,8 t82,7 2818~40 1704,41 3013,04 1696,52 316%72 205:1..~ 3311.33- 2191+65 3441,23 2321,41 3571,95 2448.85 SI'ATI~ iNCI)lo deg 0,00 0,50 0,50- '3,75 I2,73 13,31 14,66 16,35 17,76 20.84 23.25 26,95 28,58 29,11 43,16 44.93 46.28 44.64 45.54 44.51 44,74 45,24 43,38 AZIMb~H deg 0.00 62,00 12,00 4,00 .6.49 6,18 5.46 5.94- 4.63 2.3'9 3,83- 5,52 3.95 lvgl 1,44 0.93 359,83 359.88 356.66 3r-~,66 357,54 356,10 354~I4 357,68 LATITtff)I~ N/-S ft 0,00 -0,04 0.09 3,26 12,29 29,79 51,51 73,73 98,35 125,05 155,21 189,02 228,9I 271,94 317,41 364,21 -415,5I 468,04 714.67 .911, I1 tt81,03 1443,04 1704.36 1896,42 2051,31 219t.30 2320.79 2448.03 4764.t9 5227,4.4 5780,18 275.3 3767,01 280.0 3965,90 183,3 4100,91 278.6 4304.79 274,! 4503,05 2642.99 2839,76 2'763,65 3153,50 3342,68 356.79 354,86 357,40 357,92 355,21 2641,98 2838.43 2962, I3 3t51.84 3340.77 6059.80 6335.29 6612,3'-7 6797.08 6981,81 279.6 275,5 277.1 184.7 184.7 4707,45 35.'99,.40 4908,00. 3722.21 5110,53 3910,93 52~,81 4032,03 5392,52 4149,31 42,60 43,77 42.11 40,01 :38+83 359,09 L-'~,98 353,49 35'7,60 359,10 3531,~ 371%96 3908.27 4029.15 4146,38 3F-19 DBF'ARTURE DISPLACEMENT at AZIllYltt E/-W ft ft 0,00 0,00 0,26 0,27 0.99 1.00 1.98 3,81 3,02 12,65 deg 0,00 98.00 84,74 31.32 13,81 4;71 30,16 7,I2 52,00 9.38 74'33 11,84 I4,30 125,86 8.~ 7,87 · 7.25 6,87· 6,52 16,14 17-.60 . 19,80 156,~ 189,84 229,76 272,94 318,57 5.94 5.32 4.94 4.90 4,88 29.45 30.94 32.02 32.37 32.22 365.40 469,14 526.31 587.75 4,62 4,26 3,91 3.53 3,14 30,52 t8.64 ~-2,3t' -16.05 715.32 911.30 1181.04 1443,13 1704.56 2.45 1.t7 359,89 35%36 359,14' -30.43 -43.35 -54,41 -63,57 -72,97 -87,20 -95,60 ~103.34 -II4,67 1896,66 2051.62 2191,73 2321.43 2448,85 2642.~ 283%77 29.53,67 3153,53 3342,74 359,08 ~9.01 ~8,87 350,51 358.42 358,24 358.15 358.12 358,03 -124.21 -132,40 -149.67 -159.18 -162,58 3533.49 3722.32 3911.13 4032,29 4149.57 357,99 357,96 357.81 357,74 357.75 lOOft 0,00 0,82 0,35 3.71 4.85' 4,86 0,60 1.47 1,83 1,61 3,44 2:68 3.98 1.95 0,98 2,13 2,27 3,70 3,74 1.07 1.18 0,59 0,27 ,0.35 0.I0 0.~ 0.51 0,79 1,67 1,10 1.26 1,10 0,67 0,70 0,92 0.91 1,85 0,82 P~E ~, 3 ft . 716~.10 7441.20 7626.80 7 8 82 SURVE~ ~TIONS 8132.00 f.t ft ft 183.4 5536.36 4263.00 276,!'- 5751,49 4435.82 185.5 5894.32 4553.96 372,0- 6182,I8 4788J9 43,2 6216~53 4814,74 ? · 3F-l? LATITUDE D~4rUP, E DISPL4C~ at ~ZII~JT~ N/-$ de§ ft ft ft 355.78 4259.97 -I67.63 4263.27 355.~ 4432,48 -181.12 4436.18 353'85 4550,35 -172,32 4554.41 353.~ 4784.53 -218,61 4787o53 354.86 4810.62 -221.32 4815,7I 4867.31 35,.68 354.88 4862.88 -226,00 deg' 357.75 357.66 357.58 357.38 357.37 DIS IOOft 1~24 0.51 0.16 8,12 4868,13 357.34 0.02 ARCO Alaska, Inc. Date: September11, 1996 Transmittal #: 9735 RETURN TO: ARCO Alaska, inc. Attn.: Bethany Lilly Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 3G-25 Cement Bond Log 07-25-96 3F-19 Cement Bond Log 07-27-96 3F-18 Cement Bond Log 07-26-96 3F-17 Cement Bond Log 07-27-96 2M-35 Cement Bond Log 07-28-96 2M-34 Cement Bond Log 07-31-96 Receipt Acknowledge Date: DISTRIBUTION: Sharon AIIsup-Drake DS Development ATO-1205 Lam/Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 27OO-352O 7460-7876 60O0-677O 6~60-7045 14000-14775 16240-16560 Chapman/Zuspan NSK Wells Group NSK69 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 1, 1996 Blair Wondzell, P. !. Supervisor FROM: Bobby Fos~er,~ ' SUBJECT: Petroleum Inspector FILE NO: ACXIGADD.doc BOPE Test - Parker 245 ARCO - KRU - 3F-19 PTD # 96-0102 Kuparuk River Field Monday, July 1, .1996: ! traveled this date to ARCO's KRU well 3F-19 being drilled by Parker rig 245 and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows there was 1 failure. A valve leaked in the choke manifold - This will be repaired and a inspector will be notified. The rig was very clean and all equipment seemed to be in good working order. The location was clean an dali extra equipment was stored properly and there was good access to all areas of the rig. Summary: i witnessed the weekly BOPE test on Parker rig 245 drilling ARCO's KRU well 3F-19 - test time 2hours - 1 failure. Attachment: ACXIGADD.XLS X Unclassified , , Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: Drlg Contractor: PARKER Operator: ARCO Well Name: 3F-19 Casing Size: 5.5 X 3.5" Set @ Test: Initial Weekly Rig No. 245 PTD# Rep.: Rig Rep.: 8127' Location: Sec. Other 96-102 DATE: 7/1/96 Rig Ph.# 659.767 BOBBY MARRISON JOHN CRISP 10 T. 12N R. 9E Meridian Um. Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gert) PTD On Location YES Standing Order Posted YES BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Pipe Rams 1 Blind Rams 1 Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Sec. YES Test Pressure P/F 300/3,000 P 300/3,000 P 300/3,000 300/3,000 1 300/3,000 1 300/3,000 2 300/3,000 NIA P P P P MUD SYSTEM: Visual Alarm Tdp Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP 1 Lower Kelly / IBOP 1 Ball Type 1 Inside BOP Pressure P/F 300/3,000 P 300/3,000 P 300/3,000 P I 300/3,000 P CHOKE MANIFOLD: No. Valves 11~ No. Flanges 38 Manual Chokes 1 Hydraulic Chokes Test Pressure 300/3,000 300/3,000 Functioned Functioned P/F P P ACCUMULATOR SYSTEM: System Pressure 3,000 P Pressure After Closure 1,500 P 200 psi Attained After Closure 0 minutes ' '31 System Pressure Attained 2 minutes 32 Blind Switch Covers: Master: YES Remote: Nitgn. Btl's: 6 @ 2050 Av~l. Psig. sec. sec. YES ! Number of Failures: '" i ...... ,Test '~'~i"~0i~'~'"" N~r"of"val~s'te'~d ...... '"24 ...... R~'Pa'i'r'~r'R'~placen~erit''°f Failed' IEquipment will be made with~ I cl-~ys. Notify the Inspector and follow with written or Faxed verification to lthe AOGCC Commission Office a~ 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 !If y°ur call is n°t returned by the inspect°r within 12 h°urs please c°ntact the p' !' supervis°r at: I 279-1433 · . I ' I I I I I I! ' REMARKS: Failure: A valve leaked in the choke maniflod - to be repaired and the AOGCC inspector notified. Distribution: orig-Well File c - OperJRig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-O21L (Rev. 12/94) ACXIGADD.XLT Memo' ARCO' Well KRU 3F-19 Kick: 26June96 To: jaacVid Johnston ckerman Babcock k Hartz 27Jun96 Update 3' 01Jul96 Fm: Blair Wondzell c:\aogccgen\kru3f-19.kic) Bobby called about 9:02 pm last night (26Jun96) and reported that he had just received information of a kick on Parker 245 drilling KRU Well 3F-19. While drilling at'approx. 8000' (7901'md, 6058'tvd in the "A" sand -- expected 3250 psig) with 10.7 ppg mud they took a kick; they weighted up to 11.1 ppg and circulated around'; the well was still trying to flow - sidpp - 130 psig; sicp = 305 psig. They then weighted up to 11.7 ppg mud. With 11.7 ppg mud around, the well is still not "laying down"; they are now weighting up to 12.0 ppg. They should know by noon if that will work: if not they will circulate a heavy pill to bottom, come out and go back in without the mud motor and equip. The pipe is free. 8:45 pm 6/27/96. Bobby called with the following information: now circulating the well, 12.4 in, 12.1 out. Shut-in for 15 minutes, gained 12 psig. Will go to 12.6 ppg and circulate, will also mix 15 ppg mud for emergency use. . 7:4,5 pm 6/28/96. Bobby called: now circulating 12.6 in, 12.5 out. Plan to circ BU, make sure its stabilized, and make a short trip. If OK, will finish drilling to TD, about 300'. 9:17 am 6/30/96. Talked to Bobby. On KRU 3F-19, the kick was killed with 1 2.6 ppg mud. Now running 7" prOduction casing; about 3/4 of the way in. 7:55 am 7/01/96. Bobby called with update on 3F-19. Finished running 7" casing; cemented 7" without problems. Final report on the 6/26/96 kick, KRU well 3F-19. Jun. 24. 1996 ~-. 3'59PM ARC~.,ALASKA INC .No, U35Y ?, i/7. ARCO Alaska FACSIMILE . TRANSMISSIO_..N ___ · Cumber of Pages (Cover +): Phone: Location: Kuparuk Drill Site Development P, O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 ATe- 1209 FAX #: Phone #: RECEIVED JUN 2,5 199~ Alaska 011 & Ga~ Con~. Commission Anchorage Jun, 3' 59FM ARCO~.,ALASKA I~tC CASING AND LEAK-OFF FI~ACTURE TESTS .No. U~b~ ~, Well Name: KRU 3F-19 Supervisor:. Donald Lutrick Date: 6/24/96 Casing Size and Description: Casing Setting Depth: Mud Weight: 8.5 .5/8, 29.7#, L-80, BTC 3986' TMD 3214' TVD PPg EMW ~- Leak-off Pressure (P_LO) + MW 0.O52 x TVD EMW = 670 psi / (0.052 x 3214 fi) + 8.5 ppg = 12.5 ppg 2000 1900 1600 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 5{]0 400 300 200 100 0 RECEIVED JUN 2 5 1996 Alaska 011 & ea~ Con~. Commission Anchorage ST/~TE OF,~J..A~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator Abandon Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate __ Change approved program_ Pull tubing_ Variance _ Perforate _ Other 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ 4. Location of well at surface 37' FSL, 124' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 4733' FSL, 256' FEL, Sec. 19, T12N, R9E, UM (projected) At effective depth ~;-';~'7 · · ,At-*.~t~i d~pth 51097 'FSL, 267' FEL, Sec. 19, T12N, R9E, UM (projected) 12. Present well condition summary Total Depth: measured 3996' feet Plugs None true vertical Rig RKB 41' Pad level 55' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3F-1~) 9. Permit number ~)6-102 10. APl number 50-029-22680 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 3225' feet (Note: still drilling to TD at current time) Effective depth: measured 3996' feet Junk None true vertical 3225' feet 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3945' 7-5/8" measured None true vertical Tubing (size, grade, and measured depth N(~e Packers and SSSV (type and measured depth) None Attachments Description summary of proposal X Cemented Measured depth True vertical depth 250 Sx AS I 121 ' 121' 1060 sx AS III & 3986' 3218' 330 sx Class G ORIGINAL ECEIVED dUN 2 4 '!99 Cas Cons, Commission Anchorage Detailed operation program _ BOP sketch_ 14. Estimated date for commencing operation 6/28/96 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~X Gas _ Suspended Service 17. ~--.h~e/by~ertify that the foregoing is true and correct to the best of my knowledge. Si~ln _ -~o~' k/~.~_~,~Title Drill Site Dev. Supv. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test_ Mechanical Integrity Test _ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Date Location clearance Subsequent form require Original Signed David W. Johnston IApproval No~---"~ , Commissioner Date /-~'"~' Approved Copy R.eturned SUBMIT IN TRIPLICATE KRU 3F-19 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 3F-19 for basic details on the cementing operation. Additional information is offered below in support of ARCO Alaska Inc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25.030). Surface Hole TD: 3996' MD / 3225' TVD Sur._f~:.ace Hole Conditions: No problems were seen while drilling in the surface hole. .~?ell swabbed through the Ugnu and top West Sak while tripping from 3300'-_+1800' "i:d~D::a-nd in the permafrost from 1748'-1377' MD, but cleaned up during the trip. Casing was run to bottom without problems, with precautionary circulation occurring at 2550'. No fill was seen on bottom, and the casing was circulated for two. hole volumes at good rate (10 bpm). All circulation while drilling and running casing saw full returns. Casing Placement: The fluted hanger was landed as planned. The surface casing shoe was placed at 3986' MD, 10' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Cement was at surface 60 bbl into the displacement. Full returns were seen while circulating on bottom prior to cementing and during the cementing operation itself until cement returns were seen. Returns slowly declined to nothing by the time the plug was bumped. 20 bbls of 11.6 ppg cement were received at the flowline during this time, with 12 additional bbl in the diverter and riser. Casing was reciprocated until pumping the tail slurry, when the hole became sticky and the pipe was landed. Pump rates were excellent for the entire operation (6-10 bpm). Excess on the lead slurry was 225% (3.25 times the calculated gauge hole volume) and 15% on the tail. These excess factors are based on historical data and are calculated with the intent of bringing cement to surface during the primary job. Cement reached surface with good circulation and reciprocation attained. Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. RECEIVED JUN 2 4 ]996 Ala~l~ 0il ~:,. q~s Oozes. Commission ARCO Alaska, Inc. Well#: Casing Size 7 5/8" Centralizers Mud ~...~pacer · 'Laad Cement Tall Cement Displacement Cementincj Details 3F-19 Field: KUPARUK Date: 6/24/9 6 Hole Diameter Hole Angle I Shoe Depth Float Depth 9 7/8" 44° I 3,986' 3,898' State type used, intervals covered and spacing Ran 23 B/W bowspring centralizers. Run in center of first 2 jts. and on next 21 collars. The float equip, was Weatherford. Weight 10.2+/1 0.0 Gels before 5/13 Type Water YP(prior cond) 18 lbs/100 ft2 Gels after 3/8 Type I Mix wtr temp AS 3 I 60 YP(after cond) I PV(prior cond) 16 lbs/100 ft21 22 cP Additives .25 #/sk D29 Total Volume Circulated 750 bbls Volume 40 % washout No. of sacks 1060 Weight 12.1 PV(after cond) 20 cP Weight 8.3 PPG Yield 1.94 Type G Additives G , 0.25 #/sk D29, 0.2% D46 Rate(before tail at shoe) 8 Reciprocation length 15' Calculated top of cement Surface Theoretical Displacement 179 2315 6/24/96 0.3% D65, 1% S1 Rate(tail around shoe) 6 BPM Reciprocation speed 10 fpm Actual Displacement 181 Bumped plug Floats held Yes Yes · Include whether full returns were obtained, reci 3rocation throughout operation and any other pertinent Information. Remarks: Str. Wt. Up 190 Str. Wt. Dn 140 Str. Wt. Mud 161 Had full returns until cement at surface, cement at surface 60 bbls into displacement. Returns gradually diminished. No returns just before plug bumped. Approx 20 bbls 11.6 ppg cement at surface. Cement Company IRig Contractor I Signature Dowell Parker I Donald Lutricl~ ~ ~ ~ ! ~ / r' !~ dUN 2 4 Alaska Oil a Bas ',.3'er, s. COmlTiissJon ARCO Alask~lnc. Post Offic8 Ancv, o rs_cje. ,~.iasKa Telephone ,~07 275 ! June 24,1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Annular Pumping Approval for KRU Well 3F-19 Dear Mr. Johnston: .~:I<:i~paruk River Unit Well 3F-19 was permitted to drill on June 4, 1996. The "~'~rmit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOGCC. We believe that the 3F-19 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. If you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 2634183, or myself at 265-6206. Sincerely, Mike Zanghi Drill Site Development Supervisor R! C IVED JUN ~ 4 199~o Alaska 0il & 63.s Oor~s, Commission Ai!C,iul ~j~ AR3B-6003-93 ;242-2603 TONY KNOWLES, GOVERNOR June 4, 1996 CONSERVATION CO~SS~IO~ 3001 PQRCUPINE DRIVE ANCHORAGE, ALASKA 99501 -,3192 PHONE: (.907) 27.9-143,3 FAX: (507) 276-7542 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 3F-19 ARCO Alaska, Inc. 96-102 37'FSL, 124'FEL, Sec 19, T12N, R09E, UM 5109'FSL, 267'FEL, Sec 19, T12N, R09E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field 9-3607. David W.kd,,oh nston -"'---% Chairman BY ORDER OF THE COMMISSION sih/encl c: Dept of Fish & Game, Habitat Section - w/o enci Dept of Environmental Conservation - w/o encl STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry D Deepen J-J Service D Development Gas J"J Single Zone X Multiple Zone J"'J 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 55' feet Kuparuk River Field 3. Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25632,U"ALK 2565 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 37' FSL, 124' FEL, Sec. 19, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 4733' FSL, 256' FEL, Sec. 19, T12N, R9E, UM 3F~19 #U-630610 At total depth 9. Approximate spud date Amount 5109' FSL, 267' FEL, Sec. 19, T12N, R9E, UM 6/1 1/96 $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 3F-12 8316' MD 4733 @ TD feet 12.7' @ 450' feet 2448 6347' 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 44.3° Maxirnumsurface 191 0 psig At total depth ('rVD) 3200 psig 18. Casing program Settir~! 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 9.875' 7.625" 29.7# L-80 LTC 3961' 41' 41' 4002' 3226' 650 Sx Arcticset III & HF-ERW 330 Sx Class G 6.75' 5.5" 15.5# L-80 LTCMOE 7620' 41' 41' 7661' 5847' 230 Sx ClassG HF-ERW Top 500' above Kuparuk 6.75' 3.5' 9.3# L-80 EUESrdlV 655' 7661' 5847' 831 6' 6347' 19. To be completed for Redrill. Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural SOu°r~dacUect°r R E C E IV E D Intermediate Production Liner MAY 1996 Perforation depth: measured true vertical Alaska 011 & Gas Cons, ~mmJssion Anchorage 20. Attachments Filing fee X Property plat J-J BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report J-'J 20 AAC 25.050 requirements X 21. I hereby cerlily that the j)regoing is true ~jnd correct to the best of my knowledge Signed Title Drill Site Develop. Supv. Date Commission Use Onl)/ rm~~0u J I ~/_//c J see cover letter lor Pa m_be[ 0~ 50P. O.t.,q,,, ~. ~,, ~O~0 Approvaldate~ ~ '~(~ other requirements Conditions of approval Samples required ["J Yes J~ No Mud log/required D Yes J~' No Hydrogen suffidemeasures J~J Yes J--J No Directional surveyrequired J~ Yes [] No Required working pressure for BOPE J--J 2M J~ 3M D 5M J-J 10M D 15M Other: Original Signed By by order o, ~/(._/ /(2')~ Approved by David V~. Johnston Commissioner the commission Date ~- Form 10-401 Rev. 7-24-89 r~it in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3F-19 I , . . . . . . . . 10. 11. 12. 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,002')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (8,316') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 3-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. RECEIVED MAY ;~ 8 1996 Alaska 011 & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM Well KRU 3F-19 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% ing 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 General Notes- Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 1,910 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3F-19 is 3F-12. As designed, the minimum distance between the two wells would be 12.7' @ 450'. Drilling Area Risks- Risks in the 3F-19 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill ~(~1~V ~ D MAY 2 8 1996 Alaska 0il & G~s Cons. Cemmtssion ANNULAR PUMPING OPERATIONS WELL KRU 3F-19 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. (Note that cement rinseate will not be injected down the dedicated disposal well b~t 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 3F-19 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3F-19 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3F surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3513 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 58 57 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wJ~l~ '~J~i['l:~l with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2), MAY 2 ii 1996 Alaska 011 & Gas Cons. Commission Anchorage ARCO ALASKA, Inc. Pad 3F 19 slot #19 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT Baker Hughes INTEQ Your ref : 19 Version Our ref : prop1500 License : Date printed : 16-May-96 Date created : 9-Jan-96 Last revised : 16-May-96 Fietd is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 22 20.956,w149 55 51.299 SLot Location is n70 22 21.320,w149 55 54.927 SLot Grid coordinates are N 5985860.118, E 5083~5.885 SLot local coordinates are 37.00 N 124.00 W Reference North is True North Main caLcuLation performed with 3-D Minimum Distance method Object wet tpath Pl~tS <O-8600'>,,16,Pad 3F PGMS <O-8108'>,,13,Pad 3F P~NS <O-8730'>,,1,Ped 3F PGI4S <O-?455'>,,15,Pad 3F PG#S <O-6975'>,,14,Pad 3F PGNS <O-7570'>,,12,Pad 3F PG~IS <O-8600'>,,11,Ped 3F PGMS <O-6650'>,,10,Pad 3F PC~tS <O-?050'>,,8,Pad 3F P~lS <O-8070'>,,?,Ped 3F P~NS <O-TT17'>,,6,Pad 3F PGNS <O-8875'>,,5,Pad 3F PGNS <O-6913'>,,4,Pad 3F PCaqS <O-7966'>,,3,Pad 3F PGMS <O-7864'>,,2,Pad 3F PGMS <O-T785'>,,9,Pad 3F 3F-C Version ~5,,3F-C,Pad 3F 3F-18(D) Version #6,,3F-D,Pad 3F CLosest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 21-Nov-91 105.1 625.0 625.0 21-Nov-91 35.9 550.0 550.0 21-Nov-91 311.7 325.0 7320.7 21-Nov-91 76.6 700.0 700.0 21-Nov-91 54.0 625.0 4280.0 21-Nov-91 12.7 450.0 450.0 21-Nov-91 13.1 100.0 8120.0 21-Nov-91 38.3 240.0 240.0 21-Nov-91 136.5 120.0 120.0 21-Nov-91 161.8 60.0 120.0 21-Nov-91 188.0 20.0 20.0 21-Nov-91 212.0 160.0 160.0 21-Nov-91 237.4 100.0 759~.1 21-Nov-91 262.3 120.0 7599.1 21-Nov-91 287.0 20.0 20.0 21-Nov-91 62.3 100.0 7320.7 16-May-96 123.3 601.2 601.2 16-May-96 150.5 300.0 ECEIVED MAY 2 8 1996 Alaska 011 & Gas Cons. Commission Anchorage Created by : jones For: ]) IDote plotted : 16-May-96 IPIot Reference is 19 Version ~3. Coordlnotes ore in feet reference slot ~19. ITrue Vertical Depths ore reference RKB (Porker ~245). ANCO ALASKA, Structure : Pad SF Well : 19 Field : Kuporuk River Unit Location : North Slope, Alaska N 1.61 DEG W 4697' (TO TARGET) s~.,: moo <-- West : East --> 800 400 0 400 800 400 _ C) - 0 _ .. _ __e 400 _ - 800 _ _ 1200_ _ 1600_ O_ - 2000_ -- ~ 2400_ © _ 2800_ - 5200_ -- 3600_ - 4ooo_ -- 4400 _ _ I 4800_ V -- 5200_ _ 5600_ _ ~000_ _ 6400_ _ 6800 RKB ELEVATION: 96' TD LOCATION: 5109' FSL, 267' FEL SEC. 19, T12N, R9E KOP TVD=500 TMD=500 DEP=O 5.00 6.00 9.00 12.00 15.00 18.00 BUILD 3 DEG / 100' 21.00 24.00 27.00 30°00 33.00 36.00 .~9.00 B/ PERMAFROST TVD=1546 TMD=1657 DEP=462 42.00 EOC TVD=1654 TMD=1778 DEP=544 TARGET LOCATION: 4733' FSL, 256' FEL SEC. 19, T12N, R9E T/ UGNU SNDS TVD=1896 TMD=2143 DEP=799 TARGET TVD=5899 TMD=7731 DEP=4697 NORTH 4696 WEST 132 ase Kup Sands Top A3 Interva,[~ ~ '%xToP Unit A / ].\Top Unit B Top Unit C Begin A~gle Drop Base HRZ Colville Sands MAXIMUM ANGLE 44.32 DEG T/ W SAK SNDS TVD=2546 TMD=5052 DEP=1434 7 5/8 Casing Pt B/ W SAK SNDS TVD=3026 TMD=3723 DEP=1903 7 5/8" CSG PT TVD=3226 TMD=4002 DEP=2098 COLVILLE SNDS 'fVD=4246 TMD=5428 DEP=3094 SURFACE LOCATION: 37' FSL, 124' FEL SEC. 19, T12N, R9E Base West Sak Sands Top West Sak Sands Top Ugnu Sands EOC Base Permafrost , 5600 _5200 _4800 _4400 _4000 _3600 - _3200 I _2800 _2400 _ _2000 _ 1600 _1200 _ 800 _ _ 400 ~'- _ .. _ 0 0 _ 0 C) _ 400 o B/ HRZ TVD=5721 TMD=7490 DEP=4535 TARGET - T/ UNIT D (EOD) TVD=5899 TMD=7?31 DEP=4697 ~ .... T/ UNIT C WD=5910 TMB=7745 DEP=4707 T/ UNIT B WD=5975 TMD=7828 0EP=4760 T/ UNIT A WD=6067 TMD=7950 DEP=4858 T/ A5 I~ERVAL WD=6081 ~M0=7968 DEP=4850 B/ KUP SNDS WD=6194 TMD=8] 40 DEG ~o o .oo ~oo ~oo ,~oo ~ooo ~o ~oo ~oo ~oo .ooo Scale 1 ' 200.00 Vedicel Section on 358.59 ~zimufh wHh reference 0.00 N, 0.00 E from sial ~~~~,~mmt~ion iCreeted by : jones For: D PETRASH , iDete plotted : 16--Moy-96 Plot Eeference is 19 Version ICoordnotes <3re in feet reference slot ~19, True Vertical Depths are reference RKB [:Parker #245), 680 _ 640_ _ 600_ _ 560_ _ 520_ 480_ 360_ 320_ - 4O ARCO ALASKA, Structure : Pad 5F Well : 19 Field : Kuporuk River Unit Locafion : North Slope, Alaska < W e s f ~co,~ 1 ' 20.00 oo 17oo~ 70o 1500 L 1 900 1700 ~SNN~ 00590~ 11 O0 ~00~ 17o0 1500 1300 1100 900 7OO 1700 1900 _640 _600 _56O _ _520 _ _480 _ _440 400 _56o I I _320 - Z _280 0 - -5 _240 ' ! ' _ _200 160 Naska OIF&~(~asc°n~tTal~missi°n Anc~rage /Zoo -bx£ 50O 0 I I I I I I I I I , , , , , I ' ~0f''~lI~ OI i99~2 320 280 240 200 160 120 80 40 0 40 80 120 ~ 60 200 0 0 < Wesf _ 40 O0 o ,. 8O KL, PARUK RIVER UNIT 20" DIVERTER SCHEMATIC I 5 4 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 2. 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 WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(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 SPOOL WITH ONE 16" OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. R E £ E I V E DDKP11/9/94 MAY ~ ~ 1~g6 AI~ 011 & Gas Cons. Commission Anchorage I ,6 , 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. 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 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 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 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 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 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW 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 BO-I-rOM PIPE RAMS. TEST BO-FrOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 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 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 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. VBRS VVlLL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PiPE ODS AS APPROPRIATE. RECEIVED MAY 2 8 1996 Alllkl 011 & Gas Cons. Commission Anchorage · WELL PERMIT CHECKLIST ,. v FIELD & 'POOL, ,.,..~..~,-------,, -..~==,--,,-.,~=,-...~. ' HR o (0o ADMINISTRATION DATE INIT CLASS ~eV' [- O; 1 ENGINEERING APPR .,~ - GEOL AREA 1. Permit fee attached ....................... ,~ N 2. Lease number appropriate ................... ~.~T~' N 3. Unique well name and number ................. ,~ N 4. Well located in a defined pool .................. ,.~ N 5. Well located proper distance from drlg unit boundary ..... ~) N 6. Well located proper distance from other wells ......... {~ N 7. Sufficient acreage available in ddlling 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 ...... '.1~ N 12. Permit can be issued without adminis~al~ve approval .... N 13. Can permit be approved before 15-day wait .......... (~) N 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided .................. .~,~ N Surface casing protects all known USDWs ......... ~ 'N CMT vol adequate to circulate on conductor & surf csg . . . ~: N CMT vol adequate to tie-in long string to surf csg ....... CU'l' will cover ail known productive hodzons ......... Casing designs adequate for C, T, B & permafrost ..... (. ~' N Adequate tankage or reserve pit ................ ( ) N If a re-drill, has a 10-403 for abndnmnt been approved .... Adequate wellbore separation proposed ............ If diver{er required, is it adequate ................ ~ N Drilling fluid program schematic & equip list adequate .... .(,~ N BOPEs adequate ............. ._ .......... ~)~ N BOPE press rating adequate; test to -~ psig. ~) N Choke manifold complies w/APl RP-53 (May 84) ....... Work will occur without operation shutdown .......... Is presence of H2S gas probable .............. PROGRAM: exp [] dev~ reddl [] serv [] wellbore seg [] ann. disposal para req ,~ UNIT# / II ~ O ON/OFFSHORE ~ v~ REMARKS GEOLOGY 30. Permit can be issued w/o hydrogen sulfide m~N 31. Data presented on potential overpre~t, ffe-Zb'~es ....... Y j~Ni I ,,, 32. Seismic analysis of shes ............. 34.~~e/phone for weekl~ procjres..s, repo~.. ...... Y N A~. r~ od~ 33. Seabed cond~...~y (if off-shore)lexp,oratory ............ only] Y N/'' GEOLOGY: RPC ~ ENGINEERING: COMMISSION: BE~-~/r¢I5 DWJ JDH "='~. JDN TAB'~ ,i-'~ HOW/lib - A:~FORMS~heklist rev 4,/96 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. * ALASKA COMPUTING CENTER . ****************************** . ............................ * ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 3F-19 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22680-00 REFERENCE NO : 96197 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-NOV-1996 12:56 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/11/27 ORIGIN : FLIC REEL NAME : 96197 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA INC., KUPARUK 3F-19, API #50-029-22680-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/11/27 ORIGIN . FLIC TAPE NAME : 96197 CONTINUATION # : 1 PREVIOUS TAPE : COI4~ENT : ARCO ALASKA INC., KUPARUK 3F-19, API #50-029-22680-00 TAPE HEADER KUPARUK RIVER MWD 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 !ST STRING 2ND STRING 3F-19 500292268000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 27-NOV-96 BIT RUN 1 96197 MILTON LUTRICK BIT RUN 2 BIT RUN 3 19 12N 9E 37 124 96.00 96.00 55.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 3986.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-NOV-1996 12:56 3RD STRING PRODUCTION STRING REMARKS: Well drilled 24-JUN through 29-JUN-96 with ARC5 only. Ail data was collected in a single bit run. Due to tool failure, only the 10" and 16" resistivities are pre- sented. Log depth corrected to SWS CBT run 27-JUL-96. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/11/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUAiBER: 1 EDITED MERGEDIff~rD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUN~4A~Y LDWG TOOL. CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 3949.0 8130.0 BASELINE DEPTH 88888.0 7892.0 7870.5 7853.0 7837.5 7822.0 7726.0 7709.5 7707.0 7694.5 7677.0 7660.5 7630.5 7625.5 7594.0 7575.0 7563.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... 88886.0 7890.0 7871.5 7853.5 7837.0 7822.0 7726.0 7709.0 7707.5 7695.0 7678.0 7660.5 7630.5 7627.0 7594.5 7575.0 7564.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-NOV-1996 12:56 PAGE: 7543.0 7525.5 7522.5 7516.5 7509.0 7474.5 7453.0 3987.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 7542.5 7525.5 7522.0 7517.5 7509.0 7475.5 7452.5 3987.0 BIT RUN NO. MERGE TOP MERGE BASE The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. Ail other MWD curves were carried with the GR. Due to tool failure, only the 10" and 16" resistivities are presented. Log was depth corrected to SWS CBT logged 27-JUL-96. $ LIS FORMAT DATA ** 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 O. 5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-NOV-1996 12:56 PAGE: ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RP2LXMWD OtflVl~ O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OP~4~ O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8130.000 ROP.MWD 20.394 RP~X.MWD -999,250 RPX.MWD -999.250 DEPT. 8000.000 ROP.MWD 13.633 RPXX.MWD 2,760 RPX. MWD 2.854 DEPT. 6000,000 ROP.MWD 137.556 RPX~.MWD 2,003 RPX.MWD 2.101 DEPT. 4000,000 ROP.MWD 444.729 RPXX.14WD 3.074 RPX.MWD 3.381 DEPT. 3949.000 ROP.MWD -999.250 RPXzY.MWD -999,250 RPX.MWD -999.250 FET.MWD -999.250 GR.MWD -999.250 FET.MWD 4.541 GR.MWD FET.MWD 0,322 GR.MWD FET,MWD 1.108 GR.MWD FET.MWD 5.475 GR.MWD 77.631 149.031 71.454 44. 017 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/11/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-NOV-1996 12:56 PAGE: FILE HEADER FILE i~JMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH MWD 3894.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8132.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) '. FLUID LOSS (C3): RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 29-JUN-96 IDEAL4.0 4.0 MEMORY 8132.0 3949.0 8132.0 80 35.6 45.6 TOOL NUMBER ARC5-475 013 6. 750 3986.0 LSND 12.60 54.0 9.2 4.3 2. 620 78.0 2.470 78.0 2.770 78.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-NOV-1996 12:56 PAGE: TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 3996' - 8132' HOLE ANGLE AT TD = 35.68 DEG RES TO BIT: 44.8'; GR TO BIT: 47.9' TD WELL @ 05:00 29-JUN-96 DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 24 1 0.5 FT 42 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 RPXX LW1 OP~ff4 O0 000 O0 0 2 1 1 4 68 0000000000 RPX LW1 OP~4 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-NOV-1996 12:56 PAGE: ** DATA ** DEPT. 8132.000 ROP.LW1 20.394 RPXX.LW1 2.487 RPX.LW1 2.583 DEPT. 8000.000 ROP.LW1 21.681 RPXX.LW1 2.643 RPX. LW1 2.875 DEPT. 6000.000 ROP.LW1 142.583 RPXX.LW1 1.918 RPX.LW1 2.136 DEPT. 4000. 000 ROP. LW1 444. 729 RPXX. LW1 3. 074 RPX. LW1 3. 381 DEPT. 3894 . 000 ROP. LW1 - 999. 500 RPXX. LW1 87. 588 RPX. LW1 369. 243 FET. LW1 FET. LW1 FET. LW1 FET. LW1 FET. LW1 3. 472 4. 563 0.322 1.108 0.000 GR. LW1 GR. LW1 GR. LWi GR. LW1 GR. LW1 73.635 76.406 144.689 71.454 5.336 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/11/27 ORIGIN : FLIC TAPE NAME : 96197 CONTINUATION # : 1 PREVIOUS TAPE : CO~4MEigT : ARCO ALASKA INC. , KUPARUK 3F-19, API #50-029-22680-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/11/27 ORIGIN : FLIC REEL NAME '. 96197 CONTINUATION # : PREVIOUS REEL : CO~94ENT : ARCO ALASKA INC., KUPARUK 3F-19, API #50-029-22680-00
