The URL can be used to link to this page

Home My WebLink About196-037 • Z(oc) WELL LOG TRANSMITTAL# DATA LOGGED �l/1 /2015 M. K.BENDER To: Alaska Oil and Gas Conservation Comm. October 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 NOv 0 3 2415 AOGOG RE: Multi Finger Caliper(MFC): 3H-28A Run Date: 9/22/2015 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 3H-28A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20236-01 SCANNED 1 :F= 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: Mxe.lzez4z4kikj_eLedceat KR4-ti 3k— z A P Ilc,03-ic Regg, James B (DOA) From: Mahan, Wendy <Wendy.Mahan@conocophillips.com> Sent: Tuesday, February 10, 2015 2:52 PM `v{ Zl SOI I7 To: Regg,James B (DOA) �� Cc: NSK Env Coord Spills Waste Land &Other; 'Julie.Lina@caelusenergy.com' Subject: Caelus B-70 5-day preliminary incident report Attachments: Caelus B-70 well strike.docx Hi Jim, -5 u 2i✓A Attached is the required 5-day preliminary incident report for the 3bl- well strike incident. Please call if you have any questions. Thanks, Wendy Mahan/Nathan Visser Kuparuk Environmental Coordinators Phone: 907-659-7212 Fax: 907-659-7712 SCANNED C -2-6b PTA t`7(oc;7C Caelus B-70 wellhouse strike incident— Preliminary Written Report Description of event: On 2/5/2015 at approximately 0930 hrs a B-70 performing work for Caelus struck a Kuparuk wellhouse and wellhead 3H-28, damaging both. The well has been secured and leaks stopped. This included a small wisp of gas vented from the front lockdown screw on the tubing hangar, and also small drops of oil from the master bottom flange on the wellhead. The duration of the venting event was approximately two hours and an estimated 1 gal of hydraulic fluid was also spilled when the hydraulic panel dumped during the event. The well was killed by 1900 hrs. They spilled material will be cleaned up after the tree and wellhouse are removed. The gravel haul was stopped and an investigation conducted. The gravel haul has now resumed and their investigation is complete. Caelus created a_gravel berm on the drill site, to serve as a barrier between their gravel haul operations and ConocoPhillips property. (b) Within five days after the release, the operator shall submit a preliminary written report to the commission, followed by a final written report within 30 days, detailing the following facts: (1) the time of the incident; (2) the location where the incident took place; (3) the volumes of oil and gas released and recovered; (4) the cause of the release; (5) responsive actions taken to prevent additional releases; (6) plans, actions, equipment, or procedural changes to prevent or minimize the risk of future releases. gut, CLCA1 I �t s1.4� 1 r bltkV6-- r v 2a 3 7 CC�.lPk.fz;,. i44-5 1120P 55s�1 C04e-0 Nu� Svs 'T r„tatc. . , lass 4e - ('kcss aLl K ) J�- Prh tA,- f SVS Test Results 1960370 KUPARUK RIV UNIT 3H-28A Date Insp/ Test Retest Tested Oper Resn Period PILOT SSV SSSV 3/10/1997 OP 180 P Passed test P Passed test P Passed test 9/8/1997 OP 180 P Passed test P Passed test P Passed test 3/3/1998 OP 180 P Passed test P Passed test P Passed test 9/11/1998 OP 180 P Passed test P Passed test P Passed test 3/5/1999 IN 180 P Passed test P Passed test P Passed test 9/24/1999 OP 180 P Passed test P Passed test P Passed test 4/7/2000 OP 180 P Passed test P Passed test 9/11/2000 OP 180 P Passed test P Passed test 9/8/2001 OP 180 P Passed test P Passed test 3/9/2002 IN 180 P Passed test P Passed test 9/23/2002 OP 180 P Passed test P Passed test 3/7/2003 OP 180 P Passed test P Passed test 9/8/2003 OP 180 P Passed test P Passed test 3/18/2004 IN 180 P Passed test P Passed test 9/15/2004 OP 180 P Passed test P Passed test 3/7/2005 OP 180 P Passed test P Passed test 9/1/2005 IN 180 P Passed test P Passed test 3/19/2006 OP 180 P Passed test P Passed test 9/14/2006 OP 180 P Passed test P Passed test 3/5/2007 OP 180 P Passed test P Passed test 9/7/2007 IN 180 P Passed test P Passed test 1 3/9/2008 OP 180 P Passed test P Passed test 5/22/2008 IN 180 P Passed test P Passed test 4/25/2009 IN Misc P Passed test 4 Failed to hold DP 9/18/2009 OP 180 P Passed test 4 Failed to hold DP 12/1/2009 OP Misc P Passed test P Passed test 3/6/2010 IN 180 P Passed test P Passed test 9/17/2010 OP 180 P Passed test 4 Failed to hold DP 9/23/2010 OP Misc P Passed test P Passed test 3/6/2011 OP 180 P Passed test P Passed test 9/12/2011 OP 180 P Passed test P Passed test 3/25/2012 IN 180 P Passed test P Passed test 9/10/2012 OP 180 P Passed test P Passed test 3/22/2013 OP 180 P Passed test P Passed test 1/31/2014 OP Misc P Passed test P Passed test 3/22/2014 OP 180 P Passed test P Passed test 9/23/2014 IN 180 P Passed test P Passed test Friday,February 20,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~(.o -0~,7 File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~ncent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA RECEIVED ALA k OIL AND GAS CONSERVATION COMI. .;ION REPORT OF SUNDRY WELL OPERATIONS DEC 1 a 201 1.Operations Performed: Abandon r Repair w ell r• Rug Perforations r Perforate r Other r rAOGCC Alter Casing r Pull Tubing r•Stimulate-Frac fl Waiver r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17' Exploratory r 196-037 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service r 50-103-20236-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25532 • 3H-28A ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 12575 feet Plugs(measured) none true vertical 6189 feet Junk(measured) 12285 Effective Depth measured 12479 feet Packer(measured) 12060, 12164 true vertical 6109 feet (true vertical) 5778, 5858 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 5549 9.625 5591 3078 PRODUCTION 12528 7 12565 6181 Perforation depth: Measured depth: 12250-12280 True Vertical Depth: 5925-5949 SCANNED Tubing(size,grade,MD,and TVD) 3.5, L-80, 12161 MD,5855 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER"FHL"RETREIVABLE PACKER @ 12060 MD and 5778 TVD PACKER-BAKER SAB-3 PACKER @ 12164 MD and 5858 TVD SSSV-CAMCO SSSV @ 1830 MD and 1711 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl , Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17' Service r Stratigraphic r 16.Well Status after work: Oil l • Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Ian Toomey a 263-4773 Email Ian.A.Toomey(cr�conocophillips.com Printed Name Ian Toomey Title Wells Engineer Signature Phone:263-4773 Date VZ---r .. H ,r A9L\ t DEC 2 0 20 Form 10-404 Revised 10/2012 // ///27/ Submit Original Only f KUP PROD 3H-28A .i ConocoPhillips �g Well Attributes Max Angle&MD TD Alaska.Inc Wellbore API/UN Field Name Wellbore Status ncl(°) MD(ftKB) Act Btnr(ftKB) LafkkblMk{� 501032023601 KUPARUK RIVER UNIT I PROD ' 74.63 4,743.73 12,575.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) -Rig Release Date 3H-28A,12/13.20137:43:49 AM SSSV:TRDP 190 11/23/2012 Last WO'. 1 11/18/2013 4521 2/15/1996 Vertical schematic(actual) Annotation I Depth(ftKB) 'End Date Annotation Last Mod By End Date .Last Tag'. SLM 12,278.0 12/5/2013 Rev Reason:WORKOVER,PULLED haggea 12/13/2013 PLUG/CATCHER,GLV C/O,TAG Casing Strings i Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread HANGER.370 L='t CONDUCTOR 16 15.062 420 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...W7/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 41.4 5,590.6 3,077.9 36.00 J-55 BTC E� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 36.8 12,565.0 6,180.5 26.00 J-55 BTC-MOD . . , 4.4 Tubing Strings _ Tubing Description 'String Ma...'ID(in) I Top(ftKB) 'Set Depth(K../Set Depth(ND)(...'Wt(lb/ft) (Grade Top Connection 1 ��TUBING WO-2013 31/2 2.992 370 12,1608 5,855.4 9.30 L-80 18rnd EUE Completion Details CONDUCTOR;42.0-121.0 Nominal ID Top MB) Top(ND)(ftKB)I Top Inc)(°)I Item Des Com (in) 37.0 37.0 0.13 HANGER FMC TUBING HANGER 2.992 SAFETY VLV,1 829.6p 1,829.6 1,710.9 36.24 SAFETY VLV TRMAXX-5E 2.813"X-PROFILE(BxP) 2.812 ® 12,029.0 5,755.0 41.57 LOCATOR BAKER LOCATOR 2.990 ® 12,029.8 5,755.6 41.55 SEAL ASSY BAKER SEAL ASSY 2.990 1 12,046.2 5,767.9 41.29 PBR 80-40 BAKER POLISH BORE RECEPTACLE 4200 GAS LIFT.3.958.9 #'' 12,059.5 5,777.9 41.07 PACKER BAKER"FHL"RETREIVABLE PACKER 2.930 12,111.0 5,817.0 40.13 NIPPLE CAMCO"DS"NIPPLE w/RHC-M PLUG 2.812 12,154.4' 5,850.5 39.17 OVERSHOT BAKER POOR BOY OVERSHOT W/UPPER SEALS 6' 3.625 SWALLOW Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-Original I 31/21 2.992 12,141.0 12,190.31 5,878.41 9.30 L-80 I EUE 8RD SURFACE;41.45,590.6 d i C Completion Details I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Corn (in) . 12,155.4 5,851.2 39.15'NIPPLE CAMCO"W"NIPPLE W/SELECTIVE ID 2.812 GAS LIFT;7,4423 12,163.4 5,857.4 38.97,SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3.250 I 12,164.3 5,858.1 38.95 PACKER BAKER SAB-3 PACKER 3.250 12,169.2 5,862.0 38.84 XO Reducing CROSSOVER LTBC PIN x 3 1/2"B 3.000 . 12,180.2 5,870.5 38.59 NIPPLE CAMCO"D"NIPPLE ' 2.750 GAS LIFT,9,077.4 i = 12,18941 5,877.71 38.441 SOS (SHEAR OUT SUB 1 2937 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(NO) Top Intl Top'ftKB) (kKB) (°) I Des a Coin I Run Date 1 ID(in) GAS LIFT,11.304 6 Ir 12,285.0 5,952.9 37.82 FISH 1"DGLV W/BK LATCH @ UNKNOWN DEPTH 8/19/2013 0.000 . Perforations&Slots Shot Dens INTop(TVD) Btm(ND) (snotsk GAS LIFT;71,975.5 LOCATOR;12,029.0 Top(kKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,250.0 12,280.0 5,925.3 5,948.9 C-4,A-1,3H- 5/8/1996 4.0 IPERF 2 1/8"EnerJet;180 deg on 28 ph Mandrel Inserts St an Top(ND) Valve Latch Port Size TRO Run c SEAL ASSY;12,029.8 N. Top(ftKB) (kKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date in PER;12,0462 1 3,958.9 2,596.7'CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,301.0 12/3/2013 PACKER;12,059.5 �.- 2 7,442.3 3,805.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,337.0 12/32013 3 9,877.4 4,700.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,331.0 12/2/2013 4 11,304.6 5,297.8 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 12/3/2013 I 5 11,975.5 5,715.3 CAMCO KBMG 1 GAS LIFT- WY BK-5 0.000 0.0 11/17/2013 111 Notes:General&Safety NIPPLE;12,111.0 End Date Annotation ,,U 4/17/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 I 3/18/2009 NOTE:WORKOVER 8/192013 NOTE:DGLV W/BK LATCH LOST IN HOLE AT UNKNOWN DEPTH NIPPLE;12,155.4 i 1I OVERSHOT;12,154.4 �' LASEAL ASSY;12163.4 PACKER;72,764.3 NIPPLE;12,180.2 SOS;12,1894 IPERF,12250.0-12280.0 FISH;12,285.0 PRODUCTION;36.8-12.585.0 s 3H-28A Pre and Post Rig Well Work DATE SUMMARY PRE RIG WELL WORK 5/21/2013 AC EVAL TIFL FAILED IA INFLOWED 3233', AND PRESSURE INCREASED 30 PSI DURING 1 HOUR MONITOR. 6/9/2013 ATTEMPTED TO GAUGE TBG WITH 2.73"G.RING & ENCOUNTERED HEAVY SCALE @ 6823' SLM; BRUSHED AND BROACHED HEAVY SCALE TO 2.67"TO 7023'SLM. IN PROGRESS 6/10/2013 ATTEMPTED DMY FOR UNDERSIZED KOT AND UNABLE TO GET PAST 7145'SLM. BROACHED DOWN TO 7260' SLM w/ 1.985" BROACH. JOB POSTPONED (RECOMMEND CTU SCALE BLAST) 6/23/2013 Mill scale using 2.78" 3 bld junk mill to 12,000-ft ctmd, light motor work f/7425-ft to 8,640-ft and 11,493- ft to 12,000-ft ctmd, light to medium solids in 1.2:1 returns. Job in progress. 6/24/2013 Scale Blast form surface to 12,200-ft ctmd using slick diesel and diesel gel sweeps, made slow up/down pass across all GLM's and jewelry, little solids in 1:1 returns. Job complete. 7/1/2013 ATTEMPTED TO BRUSH n' GAUGE TBG (ENCOUNTERED HEAVY SCALE SUBSTANCE @ 7412' SLM & UNABLE TO WORK THROUGH). ORDER UP& PUMP 150 BBLS OF HOT SEA WATER TO CLEAN UP TBG &GAUGE TBG W/2.77"GAUGE RING DOWN TO D-NIPPLE @ 12,180' RKB. IN PROGRESS 7/2/2013 PULL 1" OV FROM STA#4 @ 11,389' RKB ( CHECK SCALED OPEN )AND REPLACED IN KIND. ASSISTED DHD IS TIFL, (FAILED TIFL). IN PROGRESS 7/2/2013 (AC EVAL): SI TIFL FAILED W/SLICKLINE. 7/3/2013 BRUSH & FLUSH TBG TO 4450' SLM; RAN D&D HOLE FINDER& UNABLE TO DETERMINE LEAK IN TBG. JOB IN PROGRESS 7/4/2013 LEAK DETECT W/HOLEFINDER AND DETERMINE IS BETWEEN 7432' RKB &7732 RKB. JOB SUSPENDED FOR PLAN FORWARD (BHP, TTP, ETC). 8/13/2013 RAN 2.65" DRIFT TO TD @ 12303.7' RKB. MEASURE SBHP @12265' RKB(3285 PSI)ATTEMPTED TO SET 2.81"CA-2 PLUG, WAS UNABLE TO PASS THROUGH 2.875" DS NIP @ 509' RKB, ATTEMPTED TO RUN 2.75"CA-2 PLUG, WAS UNABLE TO PASS THROUGH 2.81"W NIP @ 12155' RKB, IN PROGRESS 8/14/2013 BRUSHED NIPPLES @ 12096' RKB, 12155' RKB & 12180' RKB (DIFFICUILTY GETTING TOOLS TO FALL DUE TO DEVIATION), SET 2.75"CA-2 PLUG IN D NIP @ 12180' RKB, IN PROGRESS 8/15/2013 PULLED BK-OGLV FROM STA#4 @ 11389' RKB, LRS CIRC OUT WELL W/290bbIs INHIBITED SW & 110bbIs DIESEL,ATTEMPTED TO SET BK-DGLV IN STA#4 @ 11389' RKB, BROUGHT VALVE BACK, IN PROGRESS 8/16/2013 SET BK-DGLV IN STA#4 @ 11389' RKB.ATTEMPT TBG TEST, IA TRACKING. R/D FOR RIG JOB, IN PROGRESS. 8/18/2013 RAN JK RUNNING TOOL TO STA#4 @ 11389' RKB,VERIFIED THAT VALVE WAS DROPPED, RATTLED MANDRELS W/GAUGE RING & DOUBLE KNUCKLE, SET BTM-DGLV IN STA#4 @ 11389' RKB, MIT-T @ 3000psi FAILED, IA TRACKED WITH TUBING, RAN LEAK DETECT& PULLED AVA CATCHER FROM 12148'SLM, FOUND LEAK IN TUBING @ 7450' RKB, DROPPED VALVE WAS NOT IN CATCHER, IN PROGRESS 8/19/2013 CMIT T X IA TO 3000 PSI, PASSED. DROPPED 2.80"AVA CATCHER ONTO CA-2 PLUG @ 12180' RKB, RATTLED MANDRELS WITH 3-1/2" BLB, DOUBLE KNUCKLE &2.805"GAUGE RING, PULLED 2.80"AVA CATCHER FROM 12148'SLM, NO VALVE RECOVERED ***1" BK-DV IN HOLE @ UNKNOWN DEPTH***WELL READY FOR E-LINE CALIPER, IN PROGRESS. 8/20/2013 ATTEMPT TO LOG 24 ARM CALIPER IN 3.5"TUBING. 6 ARMS IN CALIPER TOOL READING OUT OF RANGE, SEND TOOLS OUT FOR REPAIR. JOB IN PROGRESS. 9/5/2013 PERFORM 24 ARM CALIPER LOG FROM 12178'TO SURFACE. LOG CORRELATED TO TUBING TALLY. TOOLSTRING TAGGED AT 12178'. JOB COMPLETE. 9/6/2013 (PRE RWO) : POT-T PASSED, PPPOT-T PASSED, POT-IC PASSED, PPPOT-IC PASSED, SCLD PASSED, FT T LDS'S (ALL GOOD). 10/17/2013 SET JUNK CATCHER ON PLUG @ 12,180' RKB; PULL DV @ 11,979' RKB (LEAVE OPEN); PULL GLV'S @ 9605' &6894' RKB; SET DV @ 9605' RKB. IN PROGRESS 10/18/2013 PULL GLV @ 2664' RKB. SET DV'S @ 6894'&2664' RKB. READY FOR BPV. ConocoPhillips Time Log & Summary WeWien Web Reporting Report Well Name: 3H-28 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 11/13/2013 2:00:00 PM Rig Release: 11/17/2013 11:59:00 PM Time Logs Date From To Dur " S. Debth E. Depth Phase Code Subcode T Comment 11/12/2013 24 hr summary Bridle up. Move rig off of well, and position rig to lay derrick over. Load&Move Pit Module, Downey Camp, and Shop. Move sub base from 1R-3 H pad. Sub base moving from 1R pad at 1700 HRS. Set Downey Camp,Truck shop and parts houses. 00:00 08:00 8.00 DEMOB MOVE MOB P Bridle up on the rig, and move rig off of well to lay derrick over. Prep rig and location to move. Dig out equipment form previous days blow- Phase 3. 08:00 00:00 16.00 MIRU MOVE MOB P Move truck shop, Pit module and Downey camp to 3 H pad.Spot pit module,and remove'jeep"from pits. Spot Downey camp and lay matting boards and pit liner. Install secondary restraints in the sheaves in the derrick per compliance with NOV inspection.The sub base started moving off of the 1R pad at 1700 HRS. 11/13/2013 Continue move Sub base from 1R pad to 3H pad. Sub base on location at 0430 HRS. Raise derrick.Secure on location. CPF3 Lead halted spotting over well 28, as a diesel spill was being cleaned up around the wellhead. Raised derrick, cattle chute, hook blocks to topdrive and bridal down derrick. Spot sub, pits and cuttings tank. Berm up rig and around tanks. Install service loop, install annulus valve. Rig accepted at 14:00 11/13/13. Take on Seawater at 20:45 to pits. Prep cellar and wellhead. Tree pressures before pulling BPV;Tbg=0 psi, IA=325 psi,OA=240 psi. Lubricate out BPV, RD lubricator and RU to kill well with 8.6 seawater. 00:00 05:00 5.00 MIRU MOVE MOB P Continue move sub base form 1R to 3H pad. Sub base on location at 0430 HRS.Spot on location and raise derrick. 05:00 06:00 1.00 MIRU MOVE MOB T CPF3 Lead operator called a halt to rigging up on the well as a result of a diesel spill that needed to be cleaned up.ACS was on location and had been cleaning up the well but not completed yet. Rig on standby while clean up operations going on. PJSM for raising the derrick while clean-up continued. 06:00 12:00 6.00 MIRU MOVE MOB P Raise derrick and cattle chute, RU Kelly hose,pin torque tube,set mats for cellar,spread Herculite and spot sub over well. Crew change. Page 1 of 6 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 12:00 18:00 6.00 MIRU MOVE MOB P Continue to spot modules and berm around rig. Swap pits to rig power and spot mud shack, berm entire rig. Rig accepted 14:00. 18:00 20:00 2.00 MIRU MOVE MOB P Bridle down derrick, hook blocks to top drive, install service loop and pull top drive out of rotary table and BD pups. Install annulus valve. 20:00 22:00 2.00 MIRU WHDBO RURD P Prepare cellar and PU lubricator; PT to 1500 psi. Pressures before pulling BPV;Tbg=0 psi, IA=325 psi, OA= 240 psi. Pull BPV and RD lubricator. 22:00 22:30 0.50 MIRU WHDBO RURD P RU circulation lines for secondary kill to tubing, IA and bleed tank. Air tested all lines; Good. 22:30 00:00 1.50 MIRU MOVE RURD P Remove cross brace from A leg, hang tongs, move subs, clean and clear rigfloor. Take on 8.6 ppg seawater to pits. 11/14/2013 PT surface lines to 3500 psi, bleed IA and Tbg to 0 psi and reverse circulate 8.6 seawater. Circulated 510 BBL to TT then take returns to pits for another circulation S to S. Monitor well for 30 minutes; Static. Install BPV and test from below with 1000 psi for 10 minutes; Good. ND tree, install blanking plug and PU BOP stack. Install BOPE. Bleed pressure off IA with 1.1 BBL returns diesel. RU for BOP test with 3 1/2"test joint to 250/3000 psi. 00:00 01:00 1.00 MIRU WHDBO PRTS P Continue to RU lines and take on seawater. Fill lines and PT lines and surface equipment to 3500 psi; Good. Bleed IA and tubing to 0 psi. 01:00 03:00 2.00 MIRU WELCTLCIRC P Circulate(reverse)8.6 ppg seawater down IA and take returns through tubing to tiger tank. Stage pumps up to 4 BPM with 870 psi initial pressure and 740 psi final pressure when 8.6 ppg weighed at the tiger tank. Shut down to RU to take returns to pits. 03:00 03:30 0.50 MIRU WELCTI RURD P Change circulating lines to take returns to pits through secondary kill line. Blow down lines and RD same. 03:30 06:30 3.00 MIRU WELCTLCIRC P Circulate 8.6 ppg seawater around for Surf to Surf circulation at 3 BPM with 340 psi. 06:30 07:30 1.00 MIRU WELCTL OWFF P Blow down all lines and monitor well 30 minutes for flow; Static. 07:30 08:00 0.50 MIRU WHDBO RURD P Install BPV as per FMC rep. Test to 1000 psi for 10 minutes. Blow down lines. 08:00 10:00 2.00 MIRU WHDBO NUND P ND and remove tree. MU blanking plug-10 turns to right, MU retrieval tool 9 1/2 turns LH turns. Exercise LDS;4"in.4 3/4"out. 10:00 12:00 2.00 MIRU WHDBO NUND P Install DSA, Install stack,tighten all connections, mount turn buckles and PU riser. Crew change. 12:00 15:00 3.00 MIRU WHDBO NUND P Install and check flanges on stack, center BOP stack and install riser. Page 2 of 6 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 15:00 17:00 2.00 MIRU WHDBO SEQP P PU 3 1/2"test joint,TIW and OX with dart valve. 17:00 18:30 1.50 MIRU WELCTL OTHR P Bleed pressure and drain 45 gal. from IA. Open to TT and no returns to tanks observed. Blow down lines and RU to bleed tank with no returns observed. Monitor IA for pressure; 0 psi. 18:30 19:00 0.50 MIRU WHDBO SEQP P PU test tools and fill stack and choke manifold. 19:00 22:30 3.50 MIRU WHDBO PRTS P Test BOPE; Upper and lower VBR, annular with 3.5"test joint, Kill, stand pipe, HCR and manual Kill, FOSV and IBOP.and valves; CH 1-11, 14-16 to 250/3000 psi for 5 minutes each. Tests waived witness by AOGCC rep.Jeff Turkington 11/13/13 19:21. 22:30 23:00 0.50 MIRU WHDBO PRTS P Perform Koomey test-drawdown. Initial pressure=3020 psi,after closing 1700 psi. Initial recovery of 200 psi was 20 seconds,with full recovery at 95 seconds. Closing times;bag= 16 sec, UPR, Blinds, LPR=6 sec, Choke Kill/HCR= 1 sec. 5 BU bottles avg= 1950 psi. Pump recovery times 2 PRs;electric=37 sec,air= 104 sec. 23:00 23:30 0.50 MIRU WHDBO PRTS P Test Blinds, CH 12&13, Inner and Outer test spool valves 250/3000 psi for 5 minutes. 23:30 00:00 0.50 MIRU WHDBO SEQP P Remove test joint,drain stack, blow down choke manifold and test pump. Crew change. 11/15/2013 LD test equipment, clean and clear floor. MU landing DP pups. Engage tubing hanger. Stage pull weight up to 140K indicated weight and tubing pulled free. Free PU=95K,SO=60K. Reverse 2X tubing volume, pull tubing and LD. Load pipe shed with tubing strap and drift 2.91". 00:00 01:00 1.00 MIRU WHDBO SEQP P LD test joint, Break down test joint, blow down surface lines and drain stack 01:00 02:00 1.00 COMPZ RPCOM PULL P MU retrieval tool and pull blanking plug, BPV 02:00 03:00 1.00 COMPZ RPCOM PULD P PU, Measure and MU landing DP pups. Engage tubing hanger and back out LDS. 03:00 03:30 0.50 COMPZ RPCOM PULL P MU landing DP pups. Engage tubing hanger. Stage pull weight up to 140K indicated weight and tubing pulled free. PU= 100K until seal assembly disengaged then Free PU= 95K, SO=60K. 03:30 04:30 1.00 COMPZ RPCOM CIRC P Reverse circulate 2 tubing volumes at 5 BPM with 1000 psi. 04:30 05:30 1.00 COMPZ RPCOM OWFF P Monitor well; Static. LD hanger and langing joints. RU GBR equipment for handling tubing. Page3of6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 12:00 6.50 COMPZ RPCOM PULL P Pull and LD 3.5"9.3#L-80 8rd tubing from 12000'to 7500'; PU=65K, SO= 50K. Crew change. 12:00 20:30 8.50 COMPZ RPCOM PULL P Pull and LD 3.5"9.3#L-80 8rd tubing from 7500'; Hole fill good 39.9 calculated to 40.4 BBL actual fill. Monitor well; Static. LD 378 joints tubing, hanger, pups, DS nipple, 5 GLMs with pups and seal assembly for 12012.02'SLM. 20:30 21:00 0.50 COMPZ RPCOM PULD P RD tongs and clean and clear floor. 21:00 00:00 3.00 COMPZ RPCOM PUTB P Load tubing in the pipe shed,strap and drift to 2.91"and stage for running. 11/16/2013 Continue to strap and drift tubing. PU and run completion as per running order to 10,686'. 00:00 09:00 9.00 COMPZ RPCOM PUTB P Load tubing in the pipe shed,strap and drift to 2.91"and stage for running. 09:00 12:00 3.00 COMPZ RPCOM RCST P Run completion; MU seal assembly and run 3 1/2"9.3#L-80 8rd EUE completion as per running order;to 1387'. Crew change. 12:00 21:00 9.00 COMPZ RPCOM RCST P Run completion; Run completion as per running order. run tubing from 1387'to 10203'with PU=80K, S0= 56K. 21:00 23:00 2.00 COMPZ RPCOM RCST P RU sheave for Camco control line as per Camco rep. PJSM with crew and Camco rep. Connect line to SSSV and test 6200 psi for 15 minutes; Good. 23:00 00:00 1.00 COMPZ RPCOM RCST P Continue running completion as per running order installing one SS band per joint above SSSV. Run completion to 10686'. Crew change. 11/17/2013 Run completion with control line. Tag up verifying with pump pressure, space out and complete control line to hanger. Total of 63 SS bands run on the control line. Displace well with corrosion inhibited brine; 320 BBL. Sting in completion and test tubing and IA 250/3500 psi; Good tests. Install BPV and ND BOP, NU tree with orientation verified by DSO. Tree tested good 250/5000,open SSSV with 6000 psi on control line. Freeze protect well with 80 BBL diesel by LRS. Dress tree and RD for rig move. Rig release 23:59 11/17/2013 00:00 02:30 2.50 COMPZ RPCOM RCST P Run completion with control line as per Camco rep and running order to joint#388; 12045', in the hole with 1 SS band on each joint above SSSV. PU=94K, SO=60K. Page 4 of 6 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T- Comment 02:30 04:00 1.50 COMPZ RPCOM RCST P MU joint#389 and verify seal engagement with pump pressure at 1 BPM with 50 psi and an increase to 250 as seals engaged at 12022'. Tag No-GO with 10K down weight at 12034.25'; 12.25'in on joint#389. LD joints 389, 388,and 387. PU and MU pups 8.20'and 2.32'for space out,joint#387 and hanger. RU to circulate CI in well. Complete control line to hanger and PT fittings with 6200 psi. Total of 63 SS bands run on the control line. 04:00 06:00 2.00 COMPZ RPCOM CRIH P Circulate in 320 BBLs of corrosion inhibited brine and chase with 100 BBL brine at 4 BPM with 720 psi. 06:00 06:30 0.50 COMPZ RPCOM RCST P Slack off, observe 5-10K drag as seals engaged and landed tubing hanger as per FMC rep and RILDS. 06:30 11:00 4.50 COMPZ RPCOM PRTS P Test tubing to 3500 psi for 30 minutes; Good test after chasing and fixing surface equipment leaks. Bleed tubing to 2500 psi and pressure up on the IA and test to 3500 psi for 30 minutes: Good test again after chaising and repairing surface equipment leaks. Bleed tbg and ann pressures to 0 PSI and pressure up on IA to 1950 psi and shear out. Establish circulation both directions,75 GPM; Good. 11:00 11:30 0.50 COMPZ WHDBO RURD P Set BPV and test to 1000 psi from below for 10 minute,with SSSV open, Good. Release pressure on control line closing SSSV. Disconnect from control line spool. 11:30 12:00 0.50 COMPZ WHDBO NUND P ND BOPE,wellhead and blow down all surface lines. RD control line equipment;spooler and sheave. Crew change. 12:00 12:30 0.50 COMPZ WHDBO NUND P Continue to blow down lines and work on wellhead. 12:30 14:30 2.00 COMPZ WHDBO NUND P ND BOP, pick and put on pedestal. 14:30 16:30 2.00 COMPZ WHDBO NUND P NU adapter and tree,orientation verified by DSO. FMC test void on tree 250/5000 psi for 10 minutes each; Good. Open SSSV with 6000 psi on control line. 16:30 17:00 0.50 COMPZ WHDBO NUND P FMC rep pulled BPV and installed tree test plug. 17:00 19:00 2.00 COMPZ WHDBO PRTS P Pressure test tree 250/5000 psi for 5 minutes each; Good. 19:00 19:30 0.50 COMPZ WHDBO RURD P Pull tree test plug as per FMC rep. 19:30 21:00 1.50 COMPZ WHDBO FRZP P Held PJSM with Little Red. RU LRS lines to freeze protect well with 80 BBL diesel to 2245'. PT LRS lines to 2500 psi; Good. Page 5 of 6 I • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 21:00 21:30 0.50 COMPZ WHDBO FRZP P PUmp 80 BBL diesel down the IA taking returns from tubing side to cuttings tank at 2 BPM with 1200 psi. 21:30 22:30 1.00 COMPZ WHDBO OWFF P Open well and allow to U-tube until static; Static. 22:30 23:30 1.00 COMPZ WHDBO RURD P Blow down and RD circulating hoses. Install BPV as per FMC rep. LRS PT BPV from below with 1000 psi for 5 minutes;Good. 23:30 00:00 0.50 DEMOB MOVE RURD P RD LRS and circulating hoses, install auxiliary valves on tree with gauges. Final pressures;Tbg=0 psi, IA=0 psi, OA=225 psi. Rig release at 23:59 11/17/2013 Page 6 of 6 POST RIG WELL WORK 111/30/20'13 DRIFTED TBG WITH 2.7' _L GUIDE TO 12143' SLM. IN PROGRE 12/2/2013 GAUGED TBG TO 2.80"TU 12137' SLM. PULLED SOV @ 11293', DVs @ 9865'&7430' RKB. SET GLV @ 9865' RKB. IN PROGRESS. 12/3/2013 PULLED DV @ 3947' RKB. SET OV @ 11293', GLVs @ 7430' &3947' RKB. BLED IA PRESSURE TO CONFIRM GLVs SET. IN PROGRESS. 12/4/2013 PULLED CATCHER @ 12141' SLM, PULLED EQ-PRONG @ 12151'SLM. UNABLE TO LATCH PLUG BODY @ 12151'SLM. BAILED FILL OFF F/N, MARKS ON BAILER BOTTOM. IN PROGRESS. 12/5/2013 BAILED FILL @ 12180' RKB. PULLED 2.75" CA-2 PLUG BODY @ 12180' RKB. TAGGED @ 12278' SLM. COMPLETE. ~ ~ COI'10C ~ ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 ~~ Anchorage, AK 99501 __ : ~~ ~ ~ , ~ _ ,... ~ :r'~;,~..~ ~~ _~~f u Dear Mr. Maunder: , n37 " ~~ ~~~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~` 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, d~G~'( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field D8t@ 08/11/09 ~~ ou ov o~n n_~ ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ~~ Corrosion inhibitor ~ Corrosion inhibitorl sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8!8/2009 3H-07 50103200790000 1870790 17" n!a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8l2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30l2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 H-28A 50103202360100 1960370 SF Na 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" Na 1.27 8/9/2009 3K-102 50029233786000 2071650 n!a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" Na 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'S" 4.50 20" 7/30l2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 ~c~sv~® • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oi18c Gas Cons. Carnmissron REPORT OF SUNDRY WELL OPERATIONS nnnr,..____ 1. Operations Pertormed: Abandon ^ Repair Well ^~ . Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 196-037 / 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20236-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 38' GL 3H-28A 8. Property Designation: 10. Field/Pool(s): ADL 25532 Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12575' feet true vertical 6192' feet Plugs (measured) Effective Depth measured 12479' feet Junk (measured) true vertical 6109' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 5550' 9-5/8" 5591' 3078' PRODUCTION 12521' 7" 12565' ~ ""6181" ' "` `" Perforation depth: Measured depth: 12250'-12280' true vertical depth: 5925'-5948' .`~s~~~~~ ~,? ~~~} ~ _:~ ~~^ , , Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12146' MD Packers & SSSV (type & measured depth) Baker'FHL' retrievable pkr, Baker'SAB-3' hydraulic pkr @ 12044', 12164' Camco landing nipple @ 508.5' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 198 865 1338 -- 160 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work : Oil Gas^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Bre kerb _ Title Wells Engineer f~~~ ~ ~ 9 ~iI Signature ~ ~i~-~" ~ ", ~~ Phone: 265-6845 Date / ~ l Pre ared b Sharon Allsu Drake 263-4612 Form 10-404 Revised 04/2006 Submit Original Only ~'~~ /r/s Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Tuesday, April 28, 2009 10:54 AM To: Maunder, Thomas E (DOA) Subject: RE: 3H-28A (196-037} Attachments: 3H-28A Pre-Post Rig Work.xls Tom, Attached is the pre/past rig work that has been done on this well, starting from when the well failed a TIFL. 9. ~nct ~Pac(~r ~rit&ng c~`/ `Wells 'Wor~Qver Engineer `Work# (907) 26S-68dS CeQ'# (907) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, Apri128, 2009 10:17 AM To: Packer, Brett B Subject: 3H-28A (196-037) Brett, t am reviewing the 404 for the recent workover on this well. Could you provide the pre/post rig work summary? Thanks in advance. Tom Maunder, PE AOGCC 4/30/2009 • C~ ~~~ ~~ ~~ Well Date Service T Event Descri tion 3H-28A 10/11/08 WELL RE-TIFL -FAILED (POST SL ) INTEGRITY 3H-28A 11/13/08 SLICK LINE PUMPED PDS MULTI FINGER CALIPER DOWN HOLE. LOGGED FROM 12250' TO SURFACE. DATA INDICATED CALIPER OPENED LATE, BOTTOM 1000' OF TBG NOT CALIPERED. SUSPENDED. 3H-28A 11!29/08 SLICK LINE DRIFTED TBG WITH 5' X 2.5" DD BAILER & TAG 12324' SLM. EST 54' RAT HOLE. *""OBTAINED SAMPLE OF STICKY SCALE`*`). GAUGED TBG TO 2.79" TO 12180' RKB. MEASURED BHP 3427 psi ~ 12265' RKB. JOB IN PROGRESS. 3H-28A 11/30108 SLICK LINE BRUSH & FLUSH TBG FROM SURFACE TO 12200' SLM. CONCENTRATING ON AREA FROM 10500' TO 12200" SLM. ATTEMPT TO SET 2.75" CA-2 PLUG @ 12180` RKB. PULLED PLUG. IN PROGRESS 3H-28A 1211108 SLICK LINE DRIFT TBG WITH 2.74" X 35" DMY PLUG TO 12200' SLM. SET 2.75" CA-2 PLUG 12180' RKB. PERFORMED POS{TINE & NEG TEST ON PLUG. '""'PASS"**. SET 3" CATCHER SUB ~ 12180' RKB (OAL= 88"). ATTEMPT TO PULL DMY VLV 12110' RKB. JOB IN PROGRESS. 3H-28A 12/2108 SLICK LINE P MY VLV 12110' RKB. LOAD WELL WITH DIESEL. CLEAN FLUID AFTER 350 BBLS AWAY. PERFORM 30 MIN GMIT TO 2500#. ""PASS'""` JOB COMPLETE 3H-28A 12/27108 SLICK LINE REPLACED 1" GLV @ 4996' RKB W/ DV. RIG DOWN & BRING UNIT TO Y- PAD TILL AM DUE TO RIG MOVE. JOB IN PROGRESS. 3H-28A 1/2109 SLICK LINE PULLED GLV'S aQ 7984' AND 10403'. SET DMY'S ~ SAME. LEFT CATCHER fN HOLE ABOVE PLUG 12184' RKB, READY FOR E-LINE. 3H-28A 1/4!09 WELL PRE-RWO, T-POT -PASSED, T-PPPOT;-PASSED, IC-POT -PASSED, IC- INTEGRITY PPPOT -PASSED, FUNCTION TEST LDS'S -PASSED 3H-28A 2124109 ELECTRIC LINE SHOT 2 318" CHEMICAL CUTTER AT 12140'. SHOT STRING HOT FR 12130'-12142'. 3H-28A 3!18/09 - NORDIC 3 RIG WORKOVER ,~,__ 3/25109 3H-28 3/28!09 SLICK LINE MIT TBG & IA 3000 PS{ GOOD. TAGGED 2.875" DS NIPPLE ~ 509' RKB WITH 2.845" CENT; UNABLE TO WORK THROUGH. GAUGED 2.875" DS NIPPLE WITH 2.80" G/R, NO PROBLEM. iN PROGRESS. 3H-28 3/29!09 SLIGK LINE PULLED B&R 12096' RKB. PULLED DVs ~ 2664', 6894° RKB. PULLED SON, SET GLV ~ 9605' RKB, PULLED D.~, SET OV ~ 11389' RKB. IP! PROGRESS. 3H-28A ,130,09 SLICK LINE SET GL`Js ~ 2664', 689'4' RKB. PULLED 2.81" RHC BODY ~ 12036' RKB. GAUGED TBG T O 2.80" TO 32140' RKB; UNABLE TO PASS POOR Bt)Y OVER SHOT. RAN LIB, INCONCLUSIVE. IN PROGRESS. 3H-2$A 3131109 SLICK LINE BAILED SAND & SCALE 12140' RKB. IN PROGRESS. ~g-i_~&~; ai11;i~ ~isf..>}~ i !het GAEL E~ :+AI~iJ ! `t IaL~ rat '€>11?° WLM. EST. 1?1Bt;,!' s,~,tf~ I~t ~s,~,~~~~-~. 3H-28A E 412109 SLICK LINE BAILED FILL FROM 12109 TO 12122' WLM. IN PROGRESS. ?'E-'E-28A 4<3E'09 SLICI'~ ==t~~'E BAILED FILL FROM 1'.121' TO 12132' b"JLM. PARTED WIRE LEAVENG 13$J' ~ E iRiE Fir O '^fiilE ['+ IRE i EF°4E E°' }-E ~1~~'! T € Z '"b y-~ R R€T9 TIl E f4 3R6 p-yn toryaT ~'c ![\r ~d ! L..EV! e~ 8!V !~11~~ ~. ?-1a7..P.~L,F wt[-f l.E~l.~`.L e":iVU 6 L.JI!~`7_ i3~ P'S'c IJiRTS~.,..,°J. 3:~-2 8A 4 141 0 9 K L 9 N E S LIC LM. 4N PR OG RES S. BA P LE D FI LL FROM 121 2 9' TO 121 39' W J) l}id°L~~~ ~~ 55 f ~ ~ '?f V1L!~J'x E SA i l ~LiE.ei4 ~Se YI_ ~g }, ~] 9~ i~ ,~ y ' } g p L. L /8 ! f ~L J}l i.=LT F5S-L ~RV~~ 1L~Ja! ~ -- !~ °fJ b'RY i-. ~~l i..LLSs' / E ~'"F~e 4!f i~iT ~~'L' ~A 12143' WLM. IN PROGRESS. .~: -c~, ~ r~'i3~s ~L.~34 ~~s~~= a~,~!L~L? r':LL ~ `~L3°~LE~ Gr,-2 ~L~~~ ~v 1~1 ~°~" ~:'aL?~.r. `~~+r71~~ETE. COtIOC Of~'1l~~I 35 ~ Air.: : c+. Irti' ... -_._._.. _.._ _e,N Cgn_Ag;.. _3_H; 2flA,,4,/1_7~.. Schematic - Aclu G MAN ER. 3T corvoucroR. o-1z1 NIPPLE. 509 - -- GAS LIFT, 2,664 SURFACE, _ _ _ __ 61-5.591 GAS LIFT, 6.894 GAS LIFT, 9.605 GAS LIFT. 11,389 GAS LIFT. 11,9]9 LOCATOR, 12,025 SEAL, 12,029 SBR, 12,031 - PACKER, 12,044 - NIPPLE, 12.096 - OVERSHOT, 12,135 NIPPLE. 12.155 SEPL. 12.163 PACKER, 12.164 NIPPLE, 12,180- SOB, 12,189 IPERF, 12.250-12,260 PRODUCTK)N, 37-12.565 TD (3H-2eA), 12 5T5 KUP • ~ 3H-28A ' Fieltl Name _ Max A Well Status Protl/Inj Type Incl (") ngle 8 MD MD (ftK8) TD Act Btrn (%K6) KUPARUK RIVER UNIT 'PROD 74.63 4,743.73 12,515.0 H25 (ppm) (Data Annotation Entl Date ( KB-Grd (ft) Rig Release Dati 125 1!1/2009 Last WO~ 3/24/2009 45.21 ~ 2/15/1996 Last lag: SLM 12,324.0 11/292008 Rev Reason: WORKOVER _L.. 4/17/2009 Casing Strings ( Casing Description _ 1String O.. String ID ... Top (ftKB) Set Depih (f... Se[ Depth (ND) ... String WI... String ... String Top Thrd iCONDUCTOR I 16 15.062 0.0 121.0 121.0 62.50 H-00 Casing Description i, String O._ String ID ... Top (ftK8) Set Dnpth (f... Sat Depth (ND) ... String Wt... String ... String Top Thr1i SURFACE ' 95/8 8.765 41.4 5,590.6 3,078.0 36.00 J-55 BTC Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ... String WI... String ... String Top Thrd PRODUCTION 7 i 6.151 36.8 _ 12,5650 _ 6,180.5 26.00 J-55 BTC-MOD _-_ Tubing Strings Tubmg Des iption -- String n... Str1ng ID ... Top (ftKBj - Sel Depth (f... - Set Depth (ND) .. String Wl... Str g String Top Thrd Stacker Packer 31/2 ~ 2.992 I 370 12145.5 I 5843.7 9.30 L80~ EUE8RD Rerom IP e ~ l 11 - ~ -. - _ _ C om ~letion De tails _ _ Top Depth I (ND) Top Intl Top (ftKB), (itKB) (°) Item Description _ Comment _ ID~) 37.0, 37.0 1.25 HANGER FMC Gen IV "s 118" 5,000 PSI TBG Hanger w/ 3 1/2 8RD Pup jt 1 3.500 508.5 '.~ 508.4( 3.98 NIPPLE Camco Landing "DS" Nipple w/ 2.875" Profile 2.875 12,028.8 5,755-6 41.96 LOCATOR Seal Assembly Locator - 2.980 12,029.2 5,755.9 41.95 SEAL Seal Assembly (12 H) w/ 2.00' Space out 2.980 12,030.8 5,757.1 41.92 SBR 80-00 Baker Polish Bore Receptacle 4.200, 12,044.2 5,766.8 41.62 PACKER (Baker 4782-7" 261! "FHL" Retreivable Packer ~ 2.930 12,095J~i 5,805.3 40.47 NIPPLE 'Camco "DS" Nipple w/ 2.812" r^rofle 2.812 12.139.1 ~ 5,838.81 1 39.51I OVERSHOT iBaker Poor Boy TBG Stub Overshot w/ upper seals 6'swallow . 3.625 M e ~ Set D D)... i,5tri 9 9 - ~ str3g 2~~ ~~~ T ~Zft4 ) ~~~ S s ~~~ $e Strin 9 P h~ g TUBING Orl inal - , 2.992 j I I 12 790.3 587 6 9.30 i L-80 0 ~ _- EUE8 _- rd ,Completion De Top Depth taits - --.-_ _. - - _ - (TV D) Top Incl Top (HKB) (ftK6) (°) .Item Description CommaM ID (in) 12,155.4 5,851.3 39.15 NIPPLE CAMCO'W NIPPLE w/NO GO 2.812" PROFILE 2.812 12,163.4'`` 5,857.5 38 97 SEAL BAKER MODEL'KBH-22' ANCHOR SEAL ASSEMBLY 3.250 12,164-3 5,858.21 3S.95 PACKER BAKER MODEL'SAB-3 HYDRAULIC PACKER 3.25011 Comment w/Alaska Schematic9.0 OD Valve I Latch 5¢e 1 1 • • ConocoPhillips Time Log & Summary WelNiew Web Reporting Report Well Name: 3H-28 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/19/2009 5:00:00 PM Rig Release: 3/25/2009 8:00:00 AM Time Logs - _ Date____ From To Dur S. Depth E_De~th Phase Code __ Subcode T Comment 3/18/2009 24 hr Summary Move Nordic Rig 3 from 1J-Pad to KCS "Y" heading toward 3H-Pad 15:00 15:30 0.50 COMPZ MOVE MOB P Move Nordic Rig 3 from 1J-174 to 1J-Pad entrance 15:30 17:00 1.50 COMPZ RPCOM OTHR X Crane came available after rig was released from 1J-174 and showed up on location prior to rig leaving. Set rig down and remove spooling unit and accessories from ri floor. 17:00 00:00 7.00 COMPZ MOVE MOB P Move Nordic Rig 3 from 1J-Pad to G-Pad access as of midni ht. 3/19/2009 Continue to Move rig from KCS "Y" towards 3H-Pad. MIRU Nordic Rig 3 00:00 02:00 2.00 MIRU MOVE MOB P Continue to Road rig from G-Pad access to 1 Y-Pad 02:00 04:30 2.50 MIRU MOVE RGRP T Change out brake assembly on movin s stem 04:30 07:00 2.50 MIRU MOVE OTHR P Standby with crews for CPAI field crew than eat 1Y-Pad 07:00 08:30 1.50 MIRU MOVE RGRP T Working on drive system. 08:30 16:00 7.50 MIRU MOVE MOB P Continue to move rig from 1Y-Pad to 3H. 16:00 17:00 1.00 MIRU MOVE OTHR P PJSM, Load New Replacement tree in cellar. Acce t ri 17:00 hrs on 3-19-09 17:00 18:30 1.50 MIRU MOVE OTHR T Continue to Prep 3H-28A to move over with ri 18:30 19:00 0.50 MIRU MOVE OTHR P Load adapter in cellar. 19:00 19:30 0.50 MIRU MOVE OTHR T Found gas leaking from a flange on . 3H-16A, just to the left of 3H-28A. Informed DSO and resolved the issue. 19:30 20:30 1.00 MIRU MOVE PSIT P Spot Rig on 3H-28A 20:30 00:00 3.50 COMPZ RPCOM OTHR P Berm up rig and spot aux. equip., Get steam working in cellar and load lubricator in pipe shed to warm up. Load pits w/ 541 bbls 9.5+ ppg KWF and continue to thaw everything out to et into workin order. 3/20/2009 RU Hardline to kill tank. Pull BPV, PT Kill lines to 250/2,500 psi. Circ.KWF. Set BPV ND Tree NU BOP. Test BOPE. Pull Blankin lu and BPV 00:00 02:00 2.00 COMPZ RPCOM OTHR P Install Hardline and air check. 02:00 03:00 1.00 COMPZ RPCOM MPSP P Lubricate out BPV Page 1 of 4 Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 05:30 2.50 COMPZ RPCOM CIRC P PJSM, PT Hardlines and kill lines @ 250/2,500 psi. Circulate 410 bbls @ 5 bpm @ 660 psi ICP w/ 180 psi choke side pressure. FCP @ 680 psi. Return Tank 1 over ran as crew was shutting down switch tanks @ 80% vol. 35 gallon spill in secondary containment. Switch returns tanks and clean up 35 gallon spill and um another 55 bbls to tank 2. 05:30 06:00 0.50 COMPZ RPCOM OWFF P Monitor well 06:00 06:30 0.50 COMPZ RPCOM MPSP P Set BPV 06:30 13:00 6.50 COMPZ RPCOM NUND P ND Tree. Set blanking plug. NU ROPE. 13:00 23:30 10.50 COMPZ RPCOM BOPE P Pressure test BOPE 250/2500 psi. Test waived by Bob Noble (AOGCC) on 3/19/09 @ 16:00. System pressure: 3,000 psi, Pressure after closure: 1,700 psi, 200 attained @ 25 sec., Full pressure attained @ 2 min. 14 sec., Nitro en: 4 bottles 2,100 si. 23:30 00:00 0.50 COMPZ RPCOM MPSP P Pull Blankin lu and BPV 3121 /2009 BOLDS, Pull Hanger to rig floor. Reverse circ.1 TBG vol., POOH laying down 3 1/2 TBG Decompletion. Call out Fishin tools for TBG dress off. Continue to Load 3 1/2 Recom letion TBG. 00:00 00:30 0.50 COMPZ RPCOM PULL P MU landing jt and Pull hanger to rig floor -pulled cut into @ 150k, 110k u wt 00:30 01:30 1.00 COMPZ RPCOM CIRC P Reverse circulate 106 bbls @ 8 bpm @ 2,000 psi. Blow down circulating eui. 01:30 16:30 15.00 12,140 2,146 COMPZ RPCOM PULL P POOH w/ 3 1/2 Decom letion from 12,140' to 2,146' 65k up wt. Strapping and kicking out decompletion, loading and strapping new tubin . 16:30 17:00 0.50 2,146 2,146 COMPZ RPCOM SVRG P Service Rig 17:00 20:30 3.50 2,146 0 COMPZ RPCOM PULL P Continue to POOH f/ 2,146' to 16.31' of chem. cut jt. Cut had small flare and would not o inside Poorbo Overshot. 20:30 00:00 3.50 0 0 COMPZ RPCOM OTHR T Call out fishing tools for TBG dress off - continue to Kick out 3 1/2 decompletion and Load, Drift and Tali 3 1/2 Recom letion TBG. 3/22/2009 Continue to Load 3 1/2 Recompletion TBG, MU and RIH w/Mud motor Dress off BHA. Pu and RIH w/ 3 1/2 TBG to 12,140'. Wash over and dress off TBG stub 12,140' to 12,146'. 00:00 04:00 4.00 0 0 COMPZ RPCOM OTHR 7 Continue to Load, rack and Tally 3 1/2 Recompletion TBG and Dress off BHA. 04:00 06:00 2.00 0 47 COMPZ RPCOM PULD T PJSM, PU and MU 3 1/2 TBG dress off ass . Page 2 of 4 J ~~ Time Logs _ Date From To Dur S. De th EDepth Phase Code Subcode T Comment _ _ _ 06:00 22:00 16.00 47 12,140 COMPZ RPCOM TRIP T RIH with dress off assembly on 3-1/2" tubin~Filling tubing while RIH to 12,140' filling TBG every 1,000'. 115k u wt, 60k do wt. 22:00 22:30 0.50 12,140 12,110 COMPZ RPCOM OTHR T Kelly up and Fill pipe @ 2 bpm @ 410 si, Establish arameters. 22:30 00:00 .1.50 12,110 12,146 COMPZ RPCOM MILL T Mill and wash over TBG stub f/ 12,140' to 12,146' @ 33 gpm @ 150 - 180 si. 3/23/2009 Continue to wash over and dress off TBG stub w/ mud motor milling BHA to 12,151' w/TBG stub @ 12,143'. PU and Shear out Circ Sub, CBU, Drop 2.867" Drift and POOH. LD Milling Assy. PU and MU 3 1/2 Recom letion ass and RIH to 12,154' w/shoe and 12,148' To of TBG stub. D0:00 05:00 5.00 12,146 12,152 COMPZ RPCOM MILL T Continue to wash over to 12,152' and Dress off TBG stub Cal 12.145'. Circulatin 2 b m 410 si. 05:00 06:30 1.50 12,152 12,136 COMPZ RPCOM CIRC T Drop ball and and circulate @ 2 bpm @ 355 psi @ 12,136' and shear out POS @ 2,000 psi. Circulate bottoms u 4 b m 470 si. 06:30 13:30 7.00 12,136 46 COMPZ RPCOM TRIP T Drop 2.867" Drift w/ 100' of wire. LD jt # 385 and POOH standin4 back 128 stands. 120k u wt, 55k do wt. 13:30 16:00 2.50 46 0 COMPZ RPCOM PULD T Lay down Baker milling BHA. Prepare pipe shed for completion. Unload millin a ui ment 16:00 16:30 0.50 0 0 COMPZ RPCOM SVRG P Service Block and Top Drive 16:30 00:00 7.50 0 12,154 COMPZ RPCOM PULD P PU and MU completion assembly. RIH on 3 1/2, 9.3#, L-80 EUE 8rd AB Mod. to 12,154'. 120k up wt, 57k do wt. 3/24/2009 Locate TBG stub @ 12,148' and Shear out OS. PU & Spot 100 bbls CRW132 w/ 9.6 ppg Brine. Locate stub and space out. Drop ball & Rod. Chase w/ slickline. Set FHL PKR, Shear out PBR & space out. MU & Land Hanger, RILDS. Set BPV. ND BOPE & NU Tree. FP, clean pits and surface equipment to handle filtered brine. 00:00 00:30 0.50 12,154 COMPZ RPCOM HOSO P Ta TBG Stub 12,148' and shear out OS, Slide over and No-Go. 120k u wt, 57k do wt. 00:30 02:00 1.50 COMPZ RPCOM CIRC P PU 6' and Pump 100 bbls 9.6 ppg brine w/ 1 % by Vol. CRW 132 corrosion inhibited brine followed by 85 bbls 9.6 ppg brine @ 3 bpm @ 390 si. Leavin 20 bbls in TBG. 02:00 04:00 2.00 COMPZ RPCOM PACK P Re-tag and space out 1' off stub. Dro ball and rod wait for 15 minutes attem t to Pressure u and set FHL PKR. -Made 4 attempts 'th no luck. Call out for slickline to chase down to RHC Plu . 04:00 05:00 1.00 COMPZ RPCOM OTHR T Wait on slickline unit to arrive. 05:00 08:30 3.50 COMPZ RPCOM SLKL T PJSM, RU slickline and RIH w/ blind box. RIH and sit down at 12089' SLM, zeroed 3' above rig floor. POOH and ri back SL tools. Page 3 of 4 ~ Time Logs _ ~ Date From To Dur S Depth E_ De th Phase Code Subcode T Comment _ 08:30 09:00 0.50 COMPZ RPCOM PACK P Pumping 0.5 bpm, tubing pressuring up. Indication of packer set at 1850 psi. Pressure up to 3000 psi and hold for 15 min. 09:00 11:00 2.00 COMPZ RPCOM HOSO P With 3000 psi on the tubing, shear out of PBR with 105 K#. Space out completion (1.63' ). Land tubing han er and RILDS. 11:00 12:30 1.50 COMPZ RPCOM PRTS P Pressure test tubing to 3000 psi / 15 min. Bleed tubino to 2250 osi. press test IA to 3000 si / 30 min. Bleed IA and then tubin to 0 si. Press up IA to 162.0 psi, shear SOV in G LM#3. 12:30 13:00 0.50 COMPZ RPCOM RURD P Rig down test equipment. Back out landin 'oint. Set BPV. 13:00 16:00 3.00 COMPZ RPCOM NUND P PJSM, ND BOPE. 16:00 20:00 4.00 COMPZ RPCOM NUND P PJSM, NU tree, pull BPV, set TWC, test tree and void_a_t 5,000 psi, good tests. 20:00 21:30 1.50 COMPZ RPCOM FRZP P RU LRS, test lines, pump 130 bbls diesel down IA at 2 b m, 1,350 si. 21:30 22:30 1.00 COMPZ RPCOM FRZP P Allow diesel to u-tube start cleaning circ lines, shakers, and its. 22:30 00:00 1.50 COMPZ RPCOM OTHR P Cont cleaning surface equipment for filtered brine. 3/25/2009 Finish pit cleani ng, RDMO well, start rig move to 2T Pad. Nordic Ri 3 released from 3H-28A on 3/25/2009 08:00 am 00:00 08:00 8.00 COMPZ RPCOM OTHR P Set BPV, dress tree, clean cellar, clean pits, laod equipment for move to 2T. Move of well. Nordic Ri 3 released from 3H-28A on 3/25/2009 08:00 am. Page 4 of 4 " '; WEll NAME 2C-09 2M-33 3H-21 3H-24 3H-28 3H-32 3K-12 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field April 29, 2004 PTD# SERVICE CEMENT TOP TYPE ft 1842210 Producer 54.0 1960720 Producer 40.0 1880080 Producer 34.0 1960150 Injector 25.0 1960370 Producer 20.0 2000010 Producer 10.0 1861650 Injector 48.0 Arctic Set 1115.7 PPG Cement \ ~\ --"? ,';¿ \S 1\ \ \) "/- Ci 5,1 &" c^'" \, VOLUME BBlS 9 5 5 3 4 2 10 "-..,(¡"-'\!:: '-J '- ~()\..}"",-c:: ~ \:), .:;, } ( L.\ I L-\ ! ~,? ( :), ~ \ '7 \ \ I -_J \ Go ,~ .]¡ c . \ ' . \(¿ \ b~ /+'t- ~ ~ ConocoPh ¡IIi pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 2, 2004 Mr. Tom Maunder ßrJ1u/ Alaska Oil & Gas Commission 5 'f 0 ~ 333 West ih Avenue, Suite 10 (I.-\.""' Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on April 29, 2004. Dowell-Schlumberger batch-mixed Arctic Set II cement to 15.7 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom ofthe void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, ~,~\(_ÇL~"'-.\.\"~ (.L,<>\~'\a c:::,~k~«(\~ . \ ~ ""ù \- '-.:.W'- '-::f>~,\ ~ \ -\,- \",c CE: U,-,,-Cc: ~~\- 4() \? .~ \l ~'-À \ \ \JQ-~ ~i(" (~ \ \ <-. ~ \!'-"'{¿ Ii"- \- \a ~~ \: ~ +- \~ ~ ,~\ \. ~ 'J-..)(( W '-.j--:';\~~-;Ì- V'-- .-\\~, r~, \ - Cù~~ '-.) C ~ C- . kífÎiV( S- (~- G t;j 7-tc~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment RECEIVED MAY 0 4 2004 Alaska Oil & Gas Cons. Commission Anchorage THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 05,200_1 PL M ATE IA L E W U N D E R T H IS M ARK E R C .J.X)RIXMFILM.DOC PERMIT DATA 96-037 7054 96-037 CDN 96-037 CD~ 96-037 CDR AOGCC Individual Well Geological Materials Inventory T DATA PLUS -- ~/MWD/MAD / CDR/CDN ~SEPIA ~L~SEPIA 96-037 CDR ~/BL Page: 1 Date: 05/13/98 RUN DATE RECVD 03/29/96 04/08/96 03/29/96 03/29/96 O4/08/96 10-407 ~OMPLETION DATE 5~/ ~ / q~/ DAILY WELL OPS R _~,/ ~/q~/ TO _)7~ /q~/ Are dry ditch samples required? yes ~~.And received? Was the well cored? Are well tests required? ~;es ~ ..... Received? Well is in compliance _ Initial COMMENTS yes ~_~Analysis & description receiYed? ARCO Alaska, Inc. Post Office Box 1003o0 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 4, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3H-28A (Permit No. 96-37) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3H-28A. If there are any questions, please call 263-4183. Sincerely, D. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad STATE OF ALASKA · ,~_ASKA OIL AND GAS CONSERVATION C,_,.¢IMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well . OIL ~] GAS E~ SUSPENDED E~ ABANDONE[~ SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-37 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20236-01 4 Location of well at surface ~"~' r,c~'~'- ';'~ ~-',~-~.-?; ......... 9 Unit or Lease Name ; .... ' Kuparuk River Unit 1123' FNL, 281'FWL, Sec. 12, T12N, R8E, UM ?,_~.-~'£~i ' ',li .~~_ ~ lO Well Number 971' FNL, 2580' FEL, Sec. 3, T12N, R8E, UM ~':~/~'~/4'~'~--~='iV&~flF.~z.n~.._, '" i'~i 3H-28A At Total Depth i -~"~-~ ¢ 11 Field and Pool 866'FNL, 2697' FEL, Sec 3 T12N, R8E, UM ........... ' ..... ~;~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Ri~l RKB 41' Pad 38' GL ADL25532 ALK2558 12 Date Spudded I 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 16 No. of Completions 15-Feb-96 sidetracked 26-Feb-96 08-May-96 (perrd)J NA feet MSL 1 17TotaIDepth(MD+TVD) 118 Plug Back Depth (MD+TVD) 19 DirectionalSurvey 120 Depth where SSSV set 21 Thickness of permafrost 12575'MD &6192'TVDI 12479'MD & 6109'TVD YES r~ NO [~I N/A feetMD = 1380'ss APPROX - -~... 22 Type Electric or Other Logs Run GR/CDR/CDN 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 30" 240 sx AS I cmt 9.625" 40# L-80 SURF. 5591' 12.25" 1070 sx AS 3, 790 sx Class G cmt 7" 26# L-80 SURF. 12565' 8.5" 200 sx Class G cmt 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 12190' 12164' 12250' - 12280' MD 4 spf 5925' - 5948' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED A' sands 194099# proppant in perfs, 13222# 20/40, 172594# 12/18, 11856# 10/14 27 PRODUCTION TEST Date First Production6/16/96 Method of OperaliOnGas(FIowing,Lift gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/15/96 5.9 TEST PERIOD ¢ 523 660 19 176 1262 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 171 1037 24-HOUR RATE I~ 2126 2683 77 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 1 2242' 5922' Bottom Kuparuk C 12264' 5939' Top Kuparuk A 12264' 5939' Bottom Kuparuk A 12316' 5980' Freeze protect annulus with diesel 31. LIST OF A'FYACHMENTS Daily Drilling History, Directional Survey :32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title ~'~ I~_, L~"-- ~ ~--~ DATE INSTRUCTIONS General' This form is designed for submitting a complete and correct well comoletion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 uate: 7/24/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:3H-28A RIG'PARKER 245 WELL ID: AK8445 AFC: AK8445 TYPE' -- STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD' KUPARUK RIVER UNIT SPUD'02/06/96 START COMP' BLOCK: FINAL' WI' 0% SECURITY:0 AFC EST/UL'$ OM/ 2030M API NUMBER: 50-103-20236-01 02/06/96 (1) TD' 0'( 0) SUPV:GRW DAILY: 02/07/96 (2) TD' 2560' ( 0) SUPV:GRW DAILY' 02/08/96 (3) TD: 5200' (2640) SUPV'GRW DAILY' 02/09/96 ( 4) TD' 5605' ( 405) S UP V: GRW DAILY: 02/10/96 (5) TD' 6881' (1276) SUPV:GRW DAILY: 02/11/96 ( 6) TD:10015' (3134) SUPV:GRW DAILY' 02/12/96 ( 7) TD:12397' (2382) SUPV:GRW DAILY: 02/13/96 ( 8) TD:14827' (2430) SUPV:GRW DAILY: 02/14/96 ( 9) TD.14940' ( 113) S UP V: RLM DAILY' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 N/U DIVERTER Move rig to 3H-28. Accept rig at 0400 hfs 2/6/96. $35,313 CUM: $35,313 ETD: $0 EFC: $35,313 MW: 10.0 N/U DIVERTER Function test diverter. Drill $68,636 CUM: $103,949 ETD: PV/YP: 25/34 APIWL' 12.0 from 121' to 2360' $0 EFC: $103,949 MW' 10.1 DRILLING Drill from 2360' to 5200' $96,931 CUM' $200,880 ETD' PV/YP: 19/29 APIWL: 11.2 $0 EFC: $200,880 MW' 0.0 PV/YP' CEMENTING Drill from 5200' to 5605' Run 9-5/8" $149,412 CUM' $350,292 ETD' o/ o casing. $0 EFC: APIWL: 0.0 $350,292 MW: 8.6 PV/YP: 4/ 3 APIWL: 18.5 CEMENTING Cement casing. CIP @ 0718 hrs. 2/9/96. Test all BOPE components to 300/3000 psi. Test casing to 2000 psi for 30 min. Drill cement, 10' of new hole to 5615' Run FIT. Drill 5615'-6881' $200,190 CUM: $550,482 ETD: $0 EFC: $550,482 MW' 9.0 DRILLING Drill from 6881' to 10015' $79,760 CUM' $630,242 ETD' PV/YP' 10/10 APIWL' 7.8 $0 EFC' $630,242 MW' 9.1 DRILLING Drill from 10015' to 12397' $87,077 CUM' $717,319 ETD' PV/YP' 11/12 APIWL' 6.8 $0 EFC' $717,319 MW: 10.6 DRILLING Drill from 12397' to 14827' $85,659 CUM: $802,978 ETD' PV/YP: 16/15 APIWL: 5.2 $0 EFC' $802,978 MW: 10.6 RIH TO SET PLUGS Drill from 14827' to 14940' to P&A Kuparuk section. $77,372 CUM: $880,350 ETD: PV/YP' 16/13 APIWL' 4.8 RIH with open ended drillpipe $0 EFC' $880,350 uate: 7/24/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 2 02/15/96 (10) TD:14940' ( 0) SUPV:RLM DAILY- MW: 10.6 PV/YP: 19/ 8 APIWL: 6.1 POOH Spot hi-vis pill at 14940' Lay balanced plug from 14765' to 14227' Pump cement. CIP at 1204 hrs. 2/14/96. Tag cement plug at 14330' POOH to 6200' spot 30 bbl hi-vis sweep. Lay balanced plug from 6000' to 5400' Pump cement. CIP at 0145 hrs. 2/15/96. $105,901 CUM: $986,251 ETD: $0 EFC: $986,251 02/16/96 (11) TD' 5597' ( 0} SUPV:RLM DAILY: MW' 9.2 PV/YP: 7/ 3 APIWL: 17.2 MAKE UP BHA Test BOPE. Make up BHA. RIH. Tagged kick off plug at 5566' Drilled cement from 5590' to 5597' POOH. $74,319 CUM' $1,060,570 ETD: $0 EFC' $1,060,570 02/17/96 ( 12} TD: 8867' (3270) SUPV'RLH DAILY' MW: 9.2 PV/YP: 7/ 3 APIWL: 17.2 SHORT TRIP Kick off plug and directional drill 8.5" hole from 5597' to 8867' Hole attempting to pack off. Wipe hole. $97,109 CUM: $1,157,679 ETD: $0 EFC: $1,157,679 02/18/96 ( 13} TD: 8867' ( 0} SUPV'RLM DALLY: MW: 9.1 PV/YP: 17/13 APIWL: 7.0 JAR ON STUCK PIPE Hole tight, hole packed off while pumping out 6th stand and stuck pipe with bit at 8308' Jar down on stuck pipe. RIH with RA source retrieving tool. Latched source and POOH. Pipe free at 8036' $0 CUM: $1,157,679 ETD: $0 EFC: $1,157,679 02/19/96 (14) TD: 8867' ( 0) SUPV:RLM DAILY' HW: 9.2 PV/YP: 14/13 APIWL: 6.0 JAR ON STUCK PIPE Finish repair to flow tube. Jar up and down on fish. No pipe movement. $84,274 CUM: $1,241,953 ETD: $0 EFC: $1,241,953 02/20/96 (15) TD: 8867' ( 0) SUPV:RLM DAILY' MW: 9.1 PV/YP: 15/14 APIWL: 6.0 POOH Jar on stuck pipe; no movement. Rig up and run free point, no improvement. Jar on stuck pipe; still no movement. Run string shot and fire same at 8036' CBU and POOH. $143,796 CUM: $1,385,749 ETD: $0 EFC: $1,385,749 02/21/96 (16) TD' 8867' ( 0) SUPV: RLH DAILY' MW: 9.4 PV/YP: 16/14 APIWL: 6.0 RUN IN WITH OEDP POOH, spider out, lay down fishing tools. Back off was achieved at 8036' Run in with open ended drill pipe to lay plug. $79,828 CUM: $1,465,577 ETD: $0 EFC: $1,465,577 02/22/96 (17) TD' 8867' ( 0) SUPV'RLM DAILY: $1,111,150 CUM: $2,576,727 ETD' MW: 9.2 PV/YP: 11/ 9 APIWL: 6.6 MAKE UP BHA RIH with open ended drill pipe to 8036' Spot hi-vis pill. Lay balanced cement plug from 7854' to 7185' CIP @ 1317 hrs. 2/21/96. Test BOPE equipment. Upper IBOP did not test. Remove and replace IBOP. Test upper IBOP to 300/3000 psi. $0 EFC: $2,576,727 Date: 7/24/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 02/23/96 (18) TD: 8498' ( 0} S UP V: RLM DAILY: 02/24/96 (19) TD: 10735' (2237) SUPV: RLM DAILY: 02/25/96 ( 20) TD:l1412' (677) SUPV:RLM DAILY: 02/26/96 (21) TD:12211' (799) S UP V: RLM DAILY: 02/27/96 ( 22) TD:12575' (364) S UP V: RLM DAILY: 02/28/96 ( 23) TD:12575' ( 0) S UP V: GRW DAILY: 02/29/96 ( 24) TD:12575' ( 0) SUPV: GRW DAILY: 03/01/96 ( 25) TD: 12575' ( 0) S UP V: GRW DAILY: MW: 9.2 PV/YP: 14/19 APIWL: 6.8 DRILLING RIH to 6819' Wash and ream intermittent cement stringers to top of plug at 7329' Directional drill from 7329' to 8498' $78,821 CUM: $2,655,548 ETD: $0 EFC: $2,655,548 MW: 9.3 PV/YP: 16/23 APIWL: 6.2 DRILLING Directional drill from 8498' to 9743'. Pipe torqued up and stuck while drilling at 9743' Took 15 minutes to work pipe free. Directional drill from 9743' to 10735' $85,301 CUM: $2,740,849 ETD: $0 EFC: $2,740,849 MW: 9.8 PV/YP: 15/25 APIWL: 5.2 DRILLING Directional drill from 10735' to 11110' Replace top drive counter balance pod on offside (damaged while jarring on fish) . Directional drill from 11110' to 11412'. Pipe stuck on bottom while making slide in angle dropping section. Worked pipe free. $82,775 CUM: $2,823,624 ETD: $0 EFC: $2,823,624 MW: 10.5 PV/YP: 15/20 APIWL: 5.4 DRILLING Increase mud weight to 10.5 ppg. POOH hole free, backreamed first 6 stands. Wash and ream from 11368' to 11412' Directional drill from 11412' to 12211' $96,901 CUM: $2,920,525 ETD: $0 EFC: $2,920,525 MW: 10.5 PV/YP: 17/26 APIWL: 4.6 MAD PASS W/LWD Directional drill from 12,211' to 12,575' RIH to 12,140' - mad pass starting point. $83,047 CUM: $3,003,572 ETD: $0 EFC: $3,003,572 MW: 10.6 PV/YP: 16/25 APIWL: 4.8 RUNNING 7" CASING Break circulation. Ream from 12013' Ratty from 12090'-12100' Make MAD pass from 12105'-12410' Ream to 12575'. Run 7" casing to 6440' $75,063 CUM: $3,078,635 ETD: $0 EFC: $3,078,635 MW: 8.6 PV/YP: 1/ 0 APIWL: 0.0 L/D DRILLPIPE Continue run 7" casing to 12565' Pump cement. CIP 1847 2/28/96. N/D BOPE. Install wellhead and test tree to 3000 psi/30 min. Freeze protect well. L/D drillpipe. $237,464 CUM: $3,316,099 ETD: $0 EFC: $3,316,099 MW: 8.6 PV/YP: 1/ 0 APIWL: 0.0 RIG RELEASED Released rig at 1500 hfs 2/29/96. Move rig. $62,201 CUM: $3,378,300 ETD: $0 EFC: $3,378,300 Date: 7/24/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 4 REMEDIAL AND COMPLETION OPERATIONS WELL-3H-28A RIG'PARKER 245 WELL ID' AK8445 AFC' AK8445 TYPE: -- STATE:ALASKA AREA/CNTY' NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:02/06/96 START COMP: BLOCK' FINAL: WI' 0% SECURITY:0 AFC EST/UL'$ OM/ 2030M API NUMBER: 50-103-20236-01 04/17/96 (26) TD: 12575' PB: 12479' SUPV: DEB DAILY: 04/18/96 (27) TD: 12575' PB: 12479' SUPV: DEB DAILY' RUNNING 3.5" COMPLETION MW: 8.5 SW Accept rig @ 0830 hrs. 4/16/96. N/D tree, N/U BOP's. Function test rams, test BOPE 250/5000 psi. Test 7" casing to 3500 psi for 30 min. OK. Run 3.5" completion w/jewelry. $29,085 CUM: $3,436,470 ETD: $0 EFC: $3,436,470 COMPLETED MW: 0.0 Continue running 3.5" tubing. Pressure tubing to 2500 psi and set 7" Baker PKR, hold pressure for 30 min., OK. Pressure annulus to 2500 psi for 15 min., OK. N/D BOP, N/U tree and test to 5000 psi for 15 minutes, OK. Release rig @ 1800 hrs. 4/17/96. $118,690 CUM: $3,673,850 ETD: $0 EFC: $3,673,850 End of WellSummary for Well'AK8445 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3H-28A(W4-6)) WELL 3H-28A DATE 05/08/96 DAY 1 JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0501961242.3 DAILY WORK UNIT NUMBER PERF A&C SANDS OPERATION COMPLETE ~ SUCCESSFUL YES _I_. YES Initial Tbg Press i Final Tbg Pressi20 PSI 675 PSI I KEY PERSON SWS-SCHWARTZ Initial Inner Ann i Final Inner Ann I 0 PSII 650 PSI I SUPERVISOR PENROSE Initial Outer Ann I 0 PSI I Final Outer Ann 0 PSI DALLY SUMMARY RAN CORRELATION GR/CCL, THEN 2 GUN RUNS TO PERFORATE THE INTERVAL 12,250' TO 12,280' (30') W/2-1/8" BIG HOLE ENERJETS @ 4 SPF, ORIENTED @ 180 DEG. HIGH ANGLE OF THE WELL (74 DEG) NECESSITATED PUMPING DOWN ALL THREE TOOL RUNS. TIME LOG ENTRY 08:30 SWS ARRIVE LOC. R/U. 09:15 PRE-JOB SAFETY MEETING. PRESSURE TEST EQUIPMENT TO 3500 PSI. 09:30 RIH W/GR/CCL. TOOL STOPPED @ 3300' DUE TO HIGH HOLE ANGLE. PUMP TOOLS DOWN W/DIESEL @ 2 BPM. 10:40 TAG PBTD @ 12,467' WLM. CORRECT DEPTH AND LOG 12,467' TO 12,020'. 10:50 POH. 11:30 OOH. R/D GR/CCL. HOLD SAFETY MTG, S/D RADIOS. P/U GUNS FOR PERF RUN #1. 12:15 RIH W/GUN RUN #1. PUMP GUN DOWN USING DIESEL@ 2 BPM. 13:40 ON BOTTOM, TIE IN. BLEED PRESSURE FROM WELL. S/I TBG AND ANNULUS. 14:00 FIRE GUN: PERF'D INTERVAL12,250' TO 12,280' (30') W/2-1/8" BIG HOLE ENERJET GUN @ 2 SPF ORIENTED 90 DEG CCW F/LOW SIDE OF HOLE. POH. 15:00 OOH. ALL SHOTS FIRED. L/D EXPENDED GUN STRIP, P/U GUN FOR PERF RUN #2. 15:15 RIH W/GUN RUN #2. PUMPED GUN DOWN USING DIESEL@ 2 BPM. 16:30 ON BO'I-I'OM, TIE IN. S/I TBG AND ANNULUS. 16:45 17:30 FIRE GUN' PERF'D INTERVAL 12,250' TO 12,280' (30') W/2-1/8" BIG HOLE ENERJET GUN @ 2 SPF ORIENTED 90 DEG CW F/LOW SIDE OF HOLE. (THE TWO GUN RUNS COMBINED YIELD A TOTAL SHOT DENSITY OF4 SPF, ORIENTED @ 180 DEG.) POH. OOH. ALL SHOTS FIRED. R/D SWS. 18:00 R/D COMPLETE, SECURE WELL, COI~N, IY ARCO hl.~, lng, WELL ~ ~-21~ ~TI~ 2 ~IC DELI~TI~ ~TE: WELL NEAI) L[~TION: L/IT(IV-S) 0.00 AZI~EITH FI~OM ROTARY TABLE TO T~RGE'r IS TIE IN POINT(TIP) MEASURED DEPTH TRUE VERT DEPTH INCLINATION AZIMUTH LATITUDE(~-S) DEPARTUR~(E/-W) 5632.00 3091.39 70.73 291.2~ 1592.95 -3678.37 DEP(E/-W) 0,00 312,74 PA(;Ii 1,10. 2 .. 31-1-2~ ~ CALCULATIONS CIRCULAR ARC TARGET STATION AZIMUTH LATITUDE S~'~ION INCLN. N/-S fi: d~ deg fi: 0,00 70,73 291.25 1592,95 65,33 66.86 294,20 1619.79 147,35 65.27 2?9.32 165B.19 231,I8 64,97 29?,94 1700.74 312,49 64.77 300.96 1742,92 D~ARTURR DISPLAC~)~I' at ~-W ft ft -3~78.37 4008.48 -3742,52 4078,01 -3618,71 4163,19 -3893.53 4248.77 -3%5,27 4331,41 AZI)'~J'rH deg 293,42 293.47 2?3.73 DIS lOOft 0,00 6,36 5,30 0,67 1,02 6080,08 6170,60 6265,77 6358.04 6452,8O 93,3 3274,53 ?0,5 3312.89 ?5,2 3354,06 92,3 3393.84 94,8 3434,21 395.58 65.40 302,90 1787.6~ 476.62 64.46 305.24 1833.57 561,91 64.30 307,61 1884.52 644.98 64.62 310,55 1937.00 730,66 64,95 311,02 -4037,06 4415,16 293,88 -4104.97 4495,8& 294.07 -4174.02 4579.73 294,30 -4238.64 4660,26 294.56 -4303.55 4742.64 294.85 2,00 2,57 2,25 2,90 0,56 6546,33 6827.06 7107,91 7339,00 7395.88 93,5 3471,84 280.7 3577,44 280.8 3683.26 221.1 3766,22 66,9 3789,67 816,25 67.60 312.10 2049,00 1076.37 68,21 313,42 2226,42 1336.50 67.52 312.69 2404,02 1541,40 68,40 314,60 2545.47 1604,01 70,5'5 313,86 2589,15 -4367.60 4824,69 295.14 -4558,56 5073.21 296.03 -4748.64 5322,49 296.85 -4896.92 5518,~ 297.47 -4941,80 5578,99 297,65 3.03 0.49 0,34 0,89 3.38 7583,63 7677,05 7865,10 8050.60 94,3 ~20.35 93,4 3849,96 93,4 3879.74 188,0 3941,40 185,5 4005,40 1693.19 71,49 311.23 2649,45 1781,68 71,57 308,16 2706,04 1~9,~ 71,25 20%03 2761.28 2047,24 70,47 308,78 2872,85 2220,70 69.17 30,6,83 2979,58 -~7,51 .5665,22 297,~ -5075.69 5751.98 298,06 -5144.89 ~.06 298.22 -5283.13 6013.71 298.54 -5420°68 6185.61 298.80 2.82 3.11 0.95 0,44 1.21 ~8,89 ~08.82 B796,~ 8985,49 9264,26 278,3 4106,67 279,9 4210.85 187,5 4279,14 189.2 4347,83 278,8 4456,36 2479.01 68,16 309,26 3139,30 2738.35 68,14 309.31 3303,80 2912,73 69,13 310,87 3416.22 3089,01 68.30 313.28 3534.35 3345.77 65,88 312,45 370~.02 -5624.81 6441,56 29~.17 -5825.92 6697.49 2'?9,56 -5959.46 6869.19 299.82 -6090,32 7041.57 300.13 -6278,51 7292,22 300.57 0,89 0.01 0,94 1.27 0,91 ~54~.76 982.7.70 10106.30 10386.89 10573.86 282,5 4570,02 280.9 4680,63 278,6 4787,84 280,6 4895,07 187,0 4968.31 3604.37 66.67 311,81 3682,51 3862,59 ~,96 311,82 4054.70 4119.65 67,79 315,63 4232.43 4378.80 67,28 313,39 4414,21 45'50.73 6&,&O 315.65 4534,81 -6470,3I 7545,78 300,97 -6662.77 77??,56 201,22 -6848.54 8050.84 201.72 -7033.42 8303,87 202,11 -7156.08 8471,95 202,36 0,35 0,10 1,30 0.76 1,17 10761,19 10852.53 10943.41 11035.82 11128.63 187,3 5043.68 91.3 5081,63 ?0,9 5120,51 92.4 5161.63 92.8 52O6.49 4722.0~ 65.95 314,31 4656.03 480~,17 64,95 312,87 4713.31 4887,31 64.39 312,53 4769,02 4969.95 62,50 310,52 4823.82 5051.24 59.96 311.28 4877,07 -7277.3~ 863~.38 202.61 -7337.~6 8720.96 302.71 -73~7,93 8801.87 202,81 -7459.81 8863.58 202.89 -7521,29 8964,13 302,96 0.74 1,80 0.71 2.82 2.83 11220.21 11311,55 11369.24 11459.44 11550.25 91.6 5253,31 91.3 5201.50 57.8 5332.34 90.1 5381.41 90.8 5433.21 512~o90 ~8,54 310,42 4928.55 5207.46 57,79 311,28 4979.31 5255,32 57.70 311.&8 5011.74 5331.87 56,30 312.I1 5062.30 5406,44 54,14 311,77 5112.15 -7580.82 9042.(79 203,03 -7639.52 9118.98 303.10 -7676,07 9167,31 203,14 -7732.23 9241.98 203.21 -7787.70 9315.70 203.28 1,75 1.15 0,90 1.57 2.40 P~£ ~, 3 3'1-2~ MEASURE~ INTERVAL VERTICAL TARGET STA?IO~ AZIMUTH LATITUDE D~PARTUR£ DISPI~AC~MBiT at AZIMUTH DLS DEPTH Df~ql~ SECTION INCLN. N/-S E/-W deg/. ft ft ft ft deg deg ft ft ft dm:j lOOft 11640.11 89,9 5487.~1 5477,99 51,45 311.03 5159.49 -7841,37 9386,~ 303,34 3.07 11730,24 90,1 5545,49 5547°00 48,53 313,10 5205,71 -7892,62 9454,79 303,41 3,68 11823.41 Y3,2 5607,93 5616,13 47,30 310.85 5251,96 -7944,01 9523,15 303,47 2,23 11913.85 ?0.4 ~70,78 5/81.09 44,65 309.62 5293.97 -7993,64 ~J87.72 303,52 3,09 12004,39 ?0,5 573.6,&6 5743,12 41,97 310,10 5333,77 -8041,32 9649,45 303.56 2,90 12095.82 91,4 5806;,44 5803,32 40,47 311,41 5373,09 -8084,96 9709,22 303,~ 1,90 1218S,71 90,9 5875,61 5841,07 38,45 312,13 5411.55 -0130,04 9764,40 303,65 2,28 12278,21 91,5 5947,52 5917,63 37,94 310,96 .~!49.07 -0172.3~ 9822.44 303,69 0.96 12485,23 207.0 6114,65 6039,72 34,37 312,12 5530,01 -8263,82 9943,43 303,79 1,76 ARCO Alaska, Inc. Date: April 3, 1996 Transmittal #: 9357 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. q&-.- l ~,; 1Q-21 ~£.. ~.~ 1Q-22A _,,/3H-28A r.,t r~- ~ ~",,,3 H_ 28A fl F--/..~ 1Q-20A Acknowledged: Dual Induction-SFL 02/29/96 Phasor Dual INduction-GR 02/1 7/96 CDR 02/17/96 CDN 02/27196 Pha~nOuctio~~_~ 02/02/96Date' 9434-10412 8342-9504 50-103-20236-01 50-103-20236-01 6950-7915 DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas. TX 75206 Sharon AIIsup-Drake DS Development ATO - 1205 Clifton Posey Geology ATO - 1251 ChapmanZuspan ., ,_., ;", V'/eiJS NSK 69 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 10097 Company: 3/29/96 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1. Q.-21 96085 DUAL INDUCTION-SFL 960229 1 1 1 1-~P,2~A / L~ .--;z ~ Xt 96074 PHASOR DUAL INDUCTION-GR 960217 I 1 3H-28A 96086 CDR/CDN 960227 I I 1 ..... ., SIGNED: ___ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, In( Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276' 1215 February 27, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Notification of Lost-in-Hole Radioactive Sources Dear Mr. Johnston: This letter is to notify the Comrrdssion Lhat b,,vo small radioactive sources were !eft in the wellbore of KRU Well 3H-28A. The drillstring became packed-off and stuck while tripping out of the hole on February 17, 1996. Subsequent fishing attempts were unsuccessful, and the BI-LA was covered with cement and the well sidetracked. Two small RA sources were left downhole: an Americium source that is part of the Anadrill CDN tool and a Cesium source that is part of the CDR tool. Both sources are contained in the respective tool collars and have been covered with cement per NRC regulations for abandonment. The NRC was notified of the abandonment plans prior to cementing the BHA with verbal approval given on February 20, 1996, by Linda Howell of the NRC. If you have any questions or need more details, please contact the Drilling Engineer, Den/se Petrash at 263-4183, or myself at 265-6206. Mike Z~ ~ Drill Site D_ear'elopment Supervisor cc: Blair Wondzell Den/se Petrash AOGCC ATO-1286- ._ FEB 29 1996 AR3B-6003-93 2,i2-2603 ALASIL OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 15, 1996 Mike Zanghi, Drill Site Supervisor ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 3H-28A ARCO Alaska Inc 96-37 1119'FNL, 281'FWL, Sec. 12, T12N, R8E, UM 843'FNL, 2632'FEL, Sec 3, T12N, R8E, UM Dear Mr. Zangt~i: Enclosed is the approved application for permit to re-cldil the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill [-1 Redrill X 1 b Type of Well Exploratory ~] Stratigraphic Test [--I Development Oil X Re-Entry [~ Deepen r-] Service ~] Development Gas ~] Single Zone X Multiple Zone E] 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 38' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25532, ALK 2558 4. Location of well at surface 7. Unit or property Name 11, Type Bond (see 2o AAC 25,025) 1119' FNL, 281' FWL, Sec. 12, T12N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8, Well number Number 972' FNL, 2492' FEL, Sec. 3, T12N, RSE, UM 3H-28A #U-630610 At total depth 9, Approximate spud date Amount 843' FNL, 2632' FEL, Sec. 3, T12N, RSE, UM 2/1 4/96 $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 3H-16 12458' MD 843' @ TD feet 11.7' @ 380' MD feet 2400 6150' TVD feet 1'6. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25,035(e)(2)) Kickoff depth 5700 feet Maximum hole angle 74.6° Maxirnumsurface 1823 pslg At total depth ('I'VD) 3200 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantit)/of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD linclude stage data) 8.5" 7" 26.0# L-80 BTCMOE 12417 41' 41' 12458' 6150' 150SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 14940' feet Plugs (measured) 14330'; tagged on 2/14/96 true vertical 6089' feet ___5400'; set on 2/15/96 Effective depth: measured 5400' feet Junk (measured) true vertical 301 9' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 8 0' 1 6' +200 CF 1 21' 1 21' Surface 5550' 9.625' 1070 SX AS III & 790 Sx G 559-1~'.~ Intermediate ..~ Production Liner FEB 1 5 1996 Perforation depth: measured "~,'~"-. Oi! & G~s Cons. Commis-sir~ true vedical Anr-,hnr;mR 20. Attachments Filing fee X Property plat ~--~ BOPSketch X Diverter Sketch r-] '-'i~i~ir~rogram X Drilling fluid program X Time vs depth plot I--I Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21, I~he foregoing is true and correct to the best of my knowledge Signed~-'~'~ ,~"x~ ~ /~;~.~ ~.,,)~ Title Drill Site Dev. Supv. Date ~1~' ~ Commission Use Only Permit Number I APl number I Approval date .... See cover letter for ?I so-/o..=, - o II other requirements Conditions of approval Samples required r'] Yes J~ No aud logrequired r-~ Yes ~;~ No Hydrogen sulfide measures [] Yes [~ No Directional survey required ~ Yes r'~ No Required workingpressureforBOPE r-! 2M l~ 3M r-I 5M r"l 1OM I'-I 15M Other: Origina! Signed By David w. Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 plicate KRU 3H-28A Permit to Drill Kuparuk River Unit Well 3I-I-28 was approved to drill by the AOGCC on 1/30/96 (Permit ~6-018, AP! #50-103-20236). The well was drilled to TD on 2/13/96. The net pay was uneconomic and the Kuparuk section was P & A'd on 2/14/96. By submittal of this Permit to Drill, ARCO Alaska, Inc. requests approval to sidetrack KRU 3H-28A to an alternate Kuparuk target (972' FNL, 2492' FEL, Sec. 3, T12N, R8E, UM) using the surface casing of KRU 3H-28. Please note that the above 3H-28A target was originally submitted to the AOGCC as the target for 3H-27. 3H-27 will no longer be drilled now that we are sidetracking 3H-28. Verbal approval of this submitted permit was given by Blair Wondzell on 2/15/96 as the sidetrack operations will be occurring soon. If you have any questions or comments regarding the attached procedure, please contact Mike Zanghi at 265-6206 or the Drilling Engineer, Denise Petrash, at 263-4183. , . , . . , , . , 10. 11. 12. 13. 14. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3H-28A Complete P & A operations on 8-1/2" open hole section of KRU 3H-28. Well 3H-28A will utilize the existing surface hole and surface casing of original Well 3H-28. Drill out kick off cement plug from +5400' to kick off point (5700'). A leak off test was performed at the surface casing shoe to 12.5 ppg EMW on 2/10/96. Kick off and drill 8-1/2" hole to total depth (12458') according to directional plan. Run LWD tools as needed. Run and cement 7" casing. (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.) ND BOPE. NU tubinghead full opening valve for cased hole cement bond logs. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3H-28A Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-4O 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% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% FEB 1 5 1996 Oil & Gas C.,,~,~. ,"'""~'~ Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. 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/ft. This shows that formation breakdown would occur before a surface pressure of 1,823 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3H-28A is 3H-16. As designed, the minimum distance between the two wells would be 11.7' @ 380' MD. Drilling Area Risks- Risks in the 3H-28A 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. 7" casing will be topset above the Kuparuk and Nordic Rig #1 will drill out a 6-1/8" hole, and run a 5" 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 10.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe was 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 gravel beds. ANNULAR PUMPING OPERATIONS Well KRU 3H-28A 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. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3H-28A 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 3H-28A be permitted for annular pumping occurring as a result of the drilling project on DS 3H, 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. The base of the permafrost is estimated at 1629' TVD / 1720' MD. A list of wells within one-quarter mile of 3H-28 (original well) is provided as the same wells are in proximity to 3H-28A sidetrack. 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 3H 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 3H-28A Max Pressure = 3420 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 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ;- ' '. ,if '- " FEB 1 5 PJ96 Alaska. Oi! & Gas Cons. ?:.,¢ ...."iO. :t'. :': ARCO ALASKA, [nc. Pad 3H 28 slot #28 Kuparuk River Unit North. Slope, Alaska CLEARANCE REPORT by Baker Hughes !NTEQ Your ref : 28 Version #9 Our-ref : prop1446 License : Date printed : 12-Jan-96 Date created : 27-0ct-95 Last revised : 12-Jan-96 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w150 0 47.688 Slot location is nTO 24 45.735,w150 0 39.451 Slot Grid coordinates are N 6000538.095, E 498654.333 Slot local coordinates are 1119.00 S 281.00 E Reference North is True North Main calculation performed with 3-D Minimt~n Distance method Object weltpath PGMS <O-8167'>,,1,Pad PGMS <O-9555'>,,3,Pad PGMS <O-8095'>,,4,Pad PGMS <O-7155'>,,5,Pad PGMS <O-7987'>,,6,Pad PGMS <O-8620'>,,7,Pad PGMS <O-6881'>,,8,Pad PGMS <O-7310,>,,9,Pad PGMS <O-8350'>,,2,Pad PGMS <O-6785'>,,10,Pad PGMS <O-7750'>,,11,Pad PGMS' <O-8650'>,,19,Pad PGMS <0-9770 >,,16,Pad PGMS <0-8614 >,,17, Pad PGMS <0-8460 >,,15,Pad PGMS <0-8250 >,,14,Pad Pr.~Is <0-7298 >,,12,Pad 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H 3H PGMS <0-7370 >,,13,Pad 3H PGMS <O-10234'>,,22,Pad 3H PGHS <O-11346'>,,21,Pad 3H PNSS <1506-2076'>,,20,Pad 3H PMSS <1622-4449~>,,20,Pad 3H PGMS <O-9050'>,,20,Pad 3H PMSS <1506-3878'>,~20~Pad 3H PGMS <O-10293'>,,18,Pad 3H PMSS <1743-6660~>,,26,Pad 3H PGMS <O-10730~>,,31,Pad 3H PGMS <O-12410'>,,25,Pad 3H PGMS <O-9360~>,,23,Pad 3H Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging fro~M.D. 13-Nov-91 427.1 40.0 120.0 13-Nov-91 375.1 450.0 450.0 13-Nov-91 351.3 475.0 14980.5 13-Nov-91 326.8 400.0 400.0 13-Nov-91 303.0 100.0 120.0 13-Nov-91 275.2 500.0 500.0 13-Nov-91 248.9 500.0 500.0 13-Nov-91 228.0 120.0 14980.5 13-Nov-91 399.9 400.0 14980.5 13-Nov-91 203.1 100.0 120.0 13-Nov-91 113.0 100.0 14980.5 13-Nov-91 86.2 725.0 725.0 13-Nov-91 11.7 380.0 380.0 13-Nov-91 36.0 625.0 625.0 13-Nov-91 12.8 475.0 475.0 13-N~v-91 38.2 100.0 14485.4 13-Nov-91 88.0 20.0 20.0 13-Nov-91 62.2 475.0 475.0 13~Nov-91 162.0 220.0 14980.5 13-Nov-91 137.0 100.0 120.0 13-Nov-91 112.0 20.0 300.0 13-Nov-91 112.0 20.0 14980.5 13-Nov-91 112.0 20.0 14838.1 13-Nov-91 112.0 20.0 300.0 13-Nov-91 61.9 220.0 3120.0 20-Mar-94 263.9 475.0 475.0 20-Apr-94 150.0 0.0 0.0 19-Apr-94 95.7 575.0 1575.0 31-0ct-95 96.1 550.0 550.0 L Point i KOP End of Drop iEnd of Hold To rg et .End of Hold End of Hold ' 1 'ARCO ALASKA I , Il0. Structure : Pad 5H Well : 28 · I Field : Kuparuk River Unit Location : North Slope, Alaska , WELL PROFILE DATA , MD Inc Dir -ND North East Beg/100! 5700 70.25 290.24 3114 1616 -3738 O.OOI 6407 66.58 .312.74 3377 1955 -4;295 3.00! 10832 66.58 .312.74 51.36 4710 -7277 0.00I 12161 40.00 .312.74 592,3 54;27 -805,3 2.00! ,o.oo o.oo,<.- West 12458 40.00 312.74 6150 5556 -819;5 O.OOJ 8800 8400 8000 7600 7200 6800 6400 6000 5600 5200 4800 4400 4000 3600 5200 - T/ Unit D (ROD) I I V Sidetrack Point 67.60 End of Drop & Turn66-80 Begin F~nol Drop AJ~ OJt & r~,-,~. Cons. ("~.~, ;' .....i ~ ~u,~.. ~:'.,:,:~ .~,;, (,rLt.~a tO[ Mchomg~ Created by : jo.~ For: D PETRASH Date plotted : 13-Feb-96 Plot Reference is 28A Version t~1. Coordinates ore in feet reference slot ~28. True VerUcol Depths ore reference RKB (Porker Scale 1 ' 200.00 6000 _5600 _ _5200 _4800 _4400 _ _3600 _ _3200 _2800 2400 Begin Final 66.00 ~ 62.00 58.00 54.00 50.00 46.00 6000 TARGET - T/ Unit D -- Top Unit C Base Kup TD 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 g200 9600 10000 10400 Scale 1 : 200.00 Vertical Section on 303.98 ozimufh with reference 0.00 N, 0.00 E from sial #28 .2000 _ 1600 - _1200 ARCO ALASKA, Inc, Pad 3H,28 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert. R E C T A N Depth Degrees Degrees Depth C 0 0 R D I 5700.00 70.23 290.24 3114.11 496.68 N 5800.00 69.54 293.35 3148.50 531.54 N 5900.00 68.90 296.49 3183.99 570.92 N 6000.00 68.31 299.65 3220.48 614.71 N 6100.00 67.79 302.83 3257.86 662.81 N PROPOSAL LISTING Page 1 Your ref : 28A Version #1 Last revised : 13-Feb-96 G U L A R Dogleg Vert N A T E S Deg/lOOFt Sect 3457.30 W 0.00 3544.47 W 3.00 3629.25 W 3.00 3711.40 ~ 3.00 3790.69 W 3.00 4002.97 Sidetrack Point 4094.74 4187.06 4279.66 4372.29 6200.00 67.33 306.04 3296.04 715.06 N 6300.00 66.93 309.27 3334.91 771.34 N 6400.00 66.60 312.51 3374.36 831.48 N 6406.88 66.58 312.74 3377.10 835.76 N 6500.00 66.58 312.74 3414.10 893.74 N 7000.00 66.58 312.74 3612.81 1205.11 N 7500.00 66.58 312.74 3811.51 1516.48 N 8000.00 66.58 312.74 4010.21 1827.85 N 8500.00 66.58 312.74 4208.92 2139.22 N 9000.00 66.58 312.74 4407.62 2450.59 N 9500.00 66.58 312.74 4606.32 2761.96 N 10000.00 66.58 312.74 4805.03 3073.32 N 10500.00 66.58 312.74 5003.73 3384.69 N 10831.82 66.58 312.74 5135.60 3591.33 N 10900.00 65.22 312.74 5163.44 3633.56 N 11000.00 63.22 312.74 5206.92 3694.67 N 11100.00 61.22 312.74 5253.53 3754.71 N 11200.00 59.22 312.74 5303.19 3813.61 N 11300.00 57.22 312.74 5355.86 3871.29 N 11400.00 55.22 312.74 5411.45 3927.69 N 11500.00 53.22 312.74 5469.92 3982.75 N 11600.00 51.22 312.74 5531.18 4036.38 N 11700.00 49.22 312.74 5595.16 4088.53 N 11800.00 47.22 312.74 5661.78 4139.13 N 11900.00 45.22 312.74 5730.97 4188.13 N 12000.00 43.22 312.74 5802.63 4235.45 N 12100.00 41.22 312.74 5876.68 4281.05 N 12161.01 40.00 312.74 5923.00 4308.00 N 12166.23 40.00 312.74 5927.00 4310.28 N 12208.01 40.00 312.74 5959.00 4328.50 N 12257.61 40.00 312.74 5997.00 4350.14 N 12457.61 40.00 312.74 6150.21 4437.38 N 3866.91 ~ 3.00 3939.85 ~ 3.00 4009.31 W 3.00 4013.96 ~ 3.00 4076.71 ~ 0.00 4413.71W 0.00 4750.71 ~ 0.00 5087.70 W 0.00 5424.70 W 0.00 5761.70 ~ 0.00 6098.69 ~ 0.00 6435.69 W 0.00 6772.68W 0.00 6996.33 ~ 0.00 7042.04 ~ 2.00 7108.17 ~ 2.00 7173.15 ~ 2.00 7236.90 14 2.00 7299.33 ~ 2.00 7360.38 ~ 2.00 7419.96 W 2.00 7478.01 ~/ 2.00 7534.46 W 2. O0 7589.22 14 2. O0 7642.25 ~ 2.00 7693.48 ~ 2. O0 7742.83 t4 2.00 7772.00 14 2.00 7774.46 ~ 0.00 7794.19 14 0.00 7817.61 ~ 0.00 7912.03 ~ 0.00 4464.70 4556.63 4647.84 4654.09 End of Drop & Turn 4738.54 5192.00 5645.47 6098.94 6552.41 7005.88 7459.35 7912.82 8366.29 8667.23 Begin Final Drop 8728,74 8817.73 8905.17 8990.95 9074,96 9157.10 9237.28 9315.39 9391,34 9465,04 9536.39 9605.32 9671.73 9710.98 TARGET - T/ Unit D (EOD) 9714.30 Top Unit C 9740,84 Top Unit A 9772,35 Base Kup Sands 9899.41TD Alt data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 12, T12N, R8E and TVD from RKB (Parker #245) (79.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 303.98 degrees. Declination is 0.00 degrees, Convergence is -0.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO ALASKA, Inc. Pad 3H,28 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 28A Version #1 Last revised : 13-Feb-96 Con~m~nts in we[[path MD TVD Rectangular Coords. Comment 5700.00 3114.11 496.68 N 3457.30 6406.88 3377.10 835.76 N 4013.96 10831.82 5135.60 3591.33 N 6996.33 12161.01 5923.00 4308.00 N 7772.00 12166.23 5927.00 4310.28 N 7774.46 12208.01 5959.00 4328.50 N 7794.19 12257.61 5997.00 4350.14 N 7817.61 12457.61 6150.21 4437.38 N 7912.03 Sidetrack Point End of Drop & Turn Begin Final Drop TARGET - T/ Unit D (EOD) Top Unit C Top Unit A Base Kup Sands TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3114.11 496.68N 3457.30W n/a 3114.11 496.68N 3457.30W 9 5/8" Casing n/a 3114.11 496.68N 3457.30~ 12457.61 6150.21 4437.38N 7912.03~ 7" Casing Targets associated with this we[[path Target name Position T.V.D. Local rectangular coords. Date revised 3H-G Rvsd 12-Jan-96 not specified 5923.00 4308.00N 7772.00~ 26-0ct-95 All data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 12, T12N, RBE and TVD from RKB (Parker #245) (79.00 Ft above mean sea level). Bottom hote distance is 9899.45 on azimuth 304.14 degrees from wellhead. Total Dogleg for wel[path is 47.79 degrees. Vertical section is from wellhead on azimuth 303.98 degrees. Declination is 0.00 degrees, Convergence is -0.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ I 7 6 5 4 3 13 5/8" 5000 PS, JOP 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. 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'FrOM 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 TESTTO 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 WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. Fr-r~ STATE OF ~ ALAb'I~A OIL AND GAS CONSERVATICN COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type ol~ Request: Abandon ~ Alter casing _ Change approved program _ m Pull tubing_ Operal~on Shutdown _ Re-enter suspended well _ Plugging _ Time extension SrJmulate Vedanta Perforate Other m m ! 6. Datum elevation (DF or KB) Suspend Repair well 5. Type ol Well: Development Exploratory Stmtigmphic Service 2. Name ct Operator ARC_O AIaska, $. Address P, O. Box 100360, AnchOrage, AK 99510 R.KB 41' Pad level 3.8' 7. Unit or Property r~ame Kuparuk River Unit feet 4. LocaMon of well at surface 1119' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 3559' FSL, 809' FEL, Sec. 4, T12N, RSE, Ury~ At effective depth At total depth ~3659' FSL, 1018' FEL, Se.c; 4, T12N: R. SE~ UM 12. Present well condition summary To,al Depth: measured true vertical 14940' feet Plugs None 6088' feet 8. Well number 3H-?.$ g, Permit number 96-018 lO. APl number 5o-1 03-20236 ~1. FiekUPo~ Kuparuk River Kuparuk River Oil Pool Effective depth: measured true vertical 14940' feet Junk None 6088' feet Ca~ng Structural Conductor Surface Intermediate Production Uner Perforation depth: Length 80' 5550' measured None true vertical Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Size 16' 9 -5/8 i3. Attachments Description summary of proposal _X._ Cemented Measured depth True vertical dep~ 250 SxAS I 121' 121' 1070 sx AS Iii & 5591' 3079' 790 sx Class G ..- :1-,,,,~, ~ ~ '~ '- Alaska 0il & Gas Cons. Ccmr~ission Anchors.ge DemiSed operation program ~ BOP sketch _ 14. EsCmated dnte for commencing operation 115. $[ak~s of well da~ifi~a~ ~s: ~/13/96 ~ Oil 16, If pmpo~t was ve~aly approved Name of approver Blair Wondze[I Date approved ~18/96 Se~i~e 7. I hereby ~i~n~,~,oregoing is t~, ~nd co~,t to ~, bee, of my ~o~edg.. Signed . , ~{ )..~ Title ~MI~IoNDfilt ~E Site ~LyDeV' Supv. Conditions ct approval: No~ ~mmission so represen~ve ~y Ntness Plug fn~egrity ~ BOP Test_ Loca~on clearance Mechanical Inlegd~ Tes~_ Subsequenl form require 10- SUspended ._ IApproval~. Approved. by the order of the Commission Form 10-403 Rev 06/15/88 Commissioner Date SUBMIT IN TRIPLICATE vvnLL. PERMIT CHECKLIST FI~.LD ~ POOL ~/~0/'0 ~ INi~ CL~S~/ /--~ / GEOL AREA UNIT~ //I~'" d9 ON/OFF SHORE ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... ENGINEERING RE~k%RKS 14. Conductor string provided ................ 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to -~~ psig. ~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ~ N - ' 34. Contact name/phone for weekly progress reports . . . //. Y N [exploratory only] GEOLOGY: RPC..~ ENGINEERING: COMMISSION: JDH ~---- JD , , Comments/Instructions: HOW/Ijb - A:\FORMS~,cheklist rev 11/95 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. LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/03/28 ORIGIN : FLIC REEL NAME : 96086 CONTINUATION # : PREVIOUS REEL : COf~IENT : ARCO ALASKA INC., KUPARUK 3H-28A, API# 50-103-20236-01 **** TAPE HEADER **** SERVICE NAM~ : EDIT mATE · 96/03/28 ORIGIN : FLIC TAPE NAME : 96086 CONTINUATION # : 1 PREVIOUS TAPE : COf~4ENT : ARCO ALASKA INC., KUPARUK 3H-28A, API# 50-103-20236-01 TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA SURFACE LOCATION 3H-28A 501032023601 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 28-MAR-96 BIT RUN 1 BIT RUN 2 BIT RUN 3 SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12 12N 8E 1119 281 79. O0 79. O0 38. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (?T) 8.500 9.625 5590.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 REMARKS: Well (sidetrack) drilled 22-FEB through 27-FEB-96 with CDR/CDN. Data was collected during drilling from 7329' to 11412'. The well was then drilled to TD w/o LWD and then a MADpass was collected from 12135' to 12520'. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGEDMWD Clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH MArD 7216.0 MAD 12039.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ ~IERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: There were no depth shifts applied per Dave Shafer. The Drilling pass a~dMADpass data were merged with absent values where no data was collected. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ STOP DEPTH 11412.0 12519.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BIT RUN NO. MERGE TOP MERGE BASE 1 7216.0 11412.0 2 12039.0 12519.0 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630356 O0 000 O0 ' 0 1 1 1 4 68 0000000000 RA MWD OH~ 630356 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~ 630356 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHPi~ 630356 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~M 630356 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~I 630356 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630356 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630356 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630356 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 630356 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO MWD G/C3 630356 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630356 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630356 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630356 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12519.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 908.707 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 · LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: DEPT. 7217.000 RA.MWD -999.250 RP.~SFD -999.250 VRA.~FD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD 45.900 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILENURiBER: 2 EDITED I~ERGEDMAD Clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUM~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD 12039.0 12519.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: MAD pass collected after drilling TD section. $ MAD RUNNO. MAD PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS~ Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630356 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD OH~ff4630356 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD Otfiv~f 630356 O0 000 O0 0 2 1 1 4 68 0000000000 VRA MAD OH~M 630356 O0 000 O0 0 2 1 1 4 68 0000000000 VRP MAD OPff4M630356 O0 000 O0 0 2 1 1 4 68 0000000000 DER MAD Otfl~4630356 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR 630356 O0 000 O0 0 2 1 1 4 68 0000000000 FET MAD HR 630356 O0 000 O0 0 2 1 1 4 68 0000000000 GR MAD GAPI 630356 O0 000 O0 0 2 1 1 4 68 0000000000 RHOBMWD G/C3 630356 O0 000 O0 0 2 1 1 4 68 0000000000 DRHOMWD G/C3 630356 O0 000 O0 0 2 1 1 4 68 0000000000 PEF MWD BN/E 630356 O0 000 O0 0 2 1 1 4 68 0000000000 CALNMWD IN 630356 O0 000 O0 0 2 1 1 4 68 0000000000 NPHIMWD PU-S 630356 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12519.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 908.707 FET.MAD GR.MAD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 LIS' Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: DEPT. 12040.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 FET.MAD GR.MAD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD 43.900 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJ~fBER: 3 EDITED MAD PASSES Clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCRENiENT: 0.5000 FILE SU~g~ARY LDWG TOOL CODE START DEPTH MAD 12039.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 12519.0 BASE~INEDEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD REMARKS: MAD data collected after drilling TD section. LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630356 O0 000 O0 0 3 1 1 4 68 0000000000 RA MAD OHMM 630356 O0 000 O0 0 3 1 1 4 68 0000000000 RP MAD OH~4~ 630356 '00 000 O0 0 3 1 1 4 68 0000000000 VRA MAD OH~IM 630356 O0 000 O0 0 3 1 1 4 68 0000000000 VRP MAD OH~v~ 630356 O0 000 O0 0 3 1 1 4 68 0000000000 DER MAD OH~4~ 630356 O0 000 O0 0 3 1 1 4 68 0000000000 ROP MAD FPHR 630356 O0 000 O0 0 3 1 1 4 68 0000000000 FET MAD HR 630356 O0 000 O0 0 3 1 1 4 68 0000000000 GR MAD GAPI 630356 O0 000 O0 0 3 1 1 4 68 0000000000 RHOBMWD G/C3 630356 O0 000 O0 0 3 1 1 4 68 0000000000 DRHOMWD G/C3 630356 O0 000 O0 0 3 1 1 4 68 0000000000 PEF MWD BN/E 630356 O0 000 O0 0 3 1 1 4 68 0000000000 CALNMWD IN 630356 O0 000 O0 0 3 1 1 4 68 0000000000 NPHIMWD PU-S 630356 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS' Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: DEPT. 12519.000 RA.MAD -999.250 RP.MAD -999.250 VRA.MAD VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 908.707 FET.MAD GR.MAD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE ' FLIC VERSION : O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IVXIMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ~ER : 1 DEPTH INCREMF~NT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 7216.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNIIOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 11412.0 25-FEB-96 FAST 2.5 4.0C MEMORY 12575.0 7216.5 11412.0 LIS' Tape Verification Listing Schlumberger Alaska Computing Center 28-~V~AR-1996 10:12 PAGE: BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIS./GR CDN NEUT/DENS $ 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 (0H7~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE '. MUD FILTRATE AT (MT): MUD CAKE AT (MT): 8O 57.8 68.4 TOOL NUMBER RGS059 NDS055 8.500 5590.0 LSND 10.60 46.0 9.3 500 4.6 2. 760 · 82.0 2.130 74.0 REMARKS: ************ RUN1 ************* DRILLED INTERVAL 7329' - 11412' RES TO BIT: 43.44', GR TO BIT: 53.86' NEUT TO BIT: 105.54', DENS TO BIT: 98.56' ************ RUN2 (MAD ONLY)*** RES TO BIT: 28.18', GR TO BIT: 38.6' NEUT TO BIT: 99.67', DENS TO BIT: 92.69' TD WELL @ 09:00 26-FEB-96 $ LIS FORMAT DATA TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): LIS 'Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630356 O0 000 O0 0 4 1 1 4 68 0000000000 RA LW1 Otff4M630356 O0 000 O0 0 4 1 1 4 68 0000000000 RP LW1 Ot~4M 630356 O0 000 O0 0 4 1 1 4 68 0000000000 DER LW1 OH~fl~630356 O0 000 O0 0 4 1 1 4 68 0000000000 ROP LW1 FPHR 630356 O0 000 O0 0 4 1 1 4 68 0000000000 FET LWl HR 630356 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW1 GAPI 630356 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LW1 G/C3 630356 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO LW1 G/C3 630356 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LW1 BN/E 630356 O0 000 O0 0 4 1 1 4 68 0000000000 CALNLW1 IN 630356 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI LW1 PU-S 630356 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11412.000 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 ROP.LW1 99.444 FET.LW1 -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO.LW1 -999.250 PEF. LW1 -999.250 CALN. LW1 -999.250 NPHI.LW1 DEPT. 7216.500 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 ROP. LW1 -999. 250 FET. LW1 -999. 250 GR. LW1 -999. 250 RHOB. LW1 DRHO. LW1 -999. 250 PEF. LW1 -999.250 CALN. LW1 - 999. 250 NPHI. LW1 -999.250 -999.250 -999.250 -999.250 -999.250 44.400 LIS ~ape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: 11 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION · O01CO1 DATE ' 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 2 MAD PASS NUMBER: 1 DEPTH INCRi~4ENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH MAD 12039.0 $ 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 .......... 12519.0 27-FEB-96 FAST 2.5 4.0C MEMORY 12575.0 12039.5 12519.0 80 34.4 34.4 LIS 'Tape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: 12 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIS./GR CDN NEUT/DENS $ 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~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) '. MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): TOOL NUMBER ........... RGS059 NDS055 8.500 5590.0 LSND 10.60 46.0 9.3 5OO 4.6 2. 760 82.0 2. 130 74.0 DRILLED IiTrERVAL 7329' - 11412' RES TO BIT: 43.44', GR TO BIT: 53.86' NEUT TO BIT: 105.54', DENS TO BIT: 98.56' ************ RUN2 (MAD ONLY)*** RES TO BIT: 28.18', GR TO BIT: 38.6' NEUT TO BIT: 99.67', DENS TO BIT: 92.69' TD WELL @ 09:00 26-FEB-96 $ LIS FORMAT DATA TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): LIS ~ape Verification Listing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630356 O0 000 O0 0 5 1 1 4 68 0000000000 RA MA1 OH~fi~630356 O0 000 O0 0 5 1 1 4 68 0000000000 RP MAi OH~M 630356 O0 000 O0 0 5 1 1 4 68 0000000000 DER MAi OH~M 630356 O0 000 O0 0 5 1 1 4 68 0000000000 ROP MAI FPHR 630356 O0 000 O0 0 5 1 1 4 68 0000000000 FET MAi HR 630356 O0 000 O0 0 5 1 1 4 68 0000000000 GR MAI GAPI 630356 O0 000 O0 0 5 1 1 4 68 0000000000 RHOB MAi G/C3 630356 O0 000 O0 0 5 1 1 4 68 0000000000 DRHOMA1 G/C3 630356 O0 000 O0 0 5 1 1 4 68 0000000000 PEF MAi BN/E 630356 O0 000 O0 0 5 1 1 4 68 0000000000 CALNMA1 IN 630356 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI MAi PU-S 630356 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12519.000 RA.MA1 -999.250 RP.MA1 -999.250 DER.MAi ROP.MA1 908.707 FET.MA1 -999.250 GR.MA1 -999.250 RHOB.MA1 DRHO.MA1 -999.250 PEF.MA1 -999.250 CALN.MA1 -999.250 NPHI.MA1 DEPT. 12039.500 RA.MA1 -999.250 RP.MA1 -999.250 DER.MAi ROP.MA1 -999.250 FET.MA1 -999.250 GR.MA1 -999.250 RHOB.MA1 DRHO.MA1 -999.250 PEF.MA1 -999.250 CALN.MA1 -999.250 NPHI.MA1 -999.250 -999.250 -999.250 -999.250 -999.250 43.800 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 28-MAR-1996 10:12 PAGE: 14 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/03/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/03/28 ORIGIN : FLIC TAPE NAME : 96086 CONTINUATION # : 1 PREVIOUS TAPE : CONk4ENT : ARCO ALASKA INC., KUPARUK 3H-28A, API# 50-103-20236-01 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 96/03/28 ORIGIN : FLIC REEL NAME : 96086 CONTINUATION # : PREVIOUS REEL : COf~4ENT : ARCO ALASKA INC., KUPARUK 3H-28A, API# 50-103-20236-01