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193-195
RECEIVED • �a -\�, MAR 07 2017 2- 003G WELL LOG TRANSMITTAL#903766447 AOGCC To: Alaska Oil and Gas Conservation Comm. February 28, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED 371/201, vl K BENDER RE: Multi Finger Caliper : 3M-24 Run Date: 1/6/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3M-24 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22432-00 Multi Finger Caliper (Field Log) 1 color log 50-029-22432-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 SCANNED ft 2 7.1 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: �Q��as-ttit6.e„,e2t. 1 STATE OF ALASKA ALOIL OIL AND GAS CONSERVATION COMMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing D. Operations Shutdown Performed: Suspend I- Perforate Other Stimulate fl Alter Casing F Change Approved Program Plug for Redrill r Perforate New Pool r Repair Well F Re-enter Susp Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development IF ENDloratory I- 193-195 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic ", Service 50-029-22432-00 7.Property Designation(Lease Number): 8.Well Name and.Number: ADL 25523,ADL 25524 KRU 3M-24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12490 feet Plugs(measured) None true vertical 6361 feet Junk(measured) 12240 Effective Depth measured 0 feet Packer(measured) 11738 true vertical 0 feet (true vertical) 5835 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 5269 9 5/8 5310 3286 PRODUCTION 12441 7 12470 6347 RECEIVED Perforation depth: Measured depth: 12132-12152, 12162-12198, 12208-12230, 12230-12244 FEB 1 0 2017 True Vertical Depth: 6110-6124,6131-6156,6163-6179,6179-6189 AOG CC Tubing(size,grade,MD,and TVD) 3.5, L-80, 12193 MD,6153 TVD Packers&SSSV(type,MD,and ND) PACKER -BAKER FHL RET. PACKER @ 11738 MD and 5835 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: ( 1`NED PR ;1 8 Z017, 13. 1 Representative Daily Average Production or Injection Data Oil-Bbr Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 173 46 445 1056 158 Subsequent to operation 0 o 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 57 Exploratory r Development F Service r Stratigraphic I- Copies of Logs and Surveys Run fl 16.Well Status after work: Oil F Gas I- WDSPL I- Printed and Electronic Fracture Stimulation Data E GSTOR WINJ WAG r GINJ I- SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-564 Contact Daniel Kane(7a.265-6048 Email Daniel.Kanee.conocoDhilliDs.com Printed Name Daniel Kane Title Sr. Wells Engineer Signature Phone:265-6048 Date 1CP—PeR- 21SC7- V rL- 3/z5. //g" Form 10-404 Revised 5/2015 , A, /7 RBDMS ./L FE3 1 0 2017Submit Original Only • • , Operations Summary (with Timelog Depths) t o 3M-24 ConocoPtaiiliips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/14/2016 12/14/2016 1.25 MIRU MOVE RURD P Complete rig down check list. 0.0 0.0 20:00 21:15 12/14/2016 12/14/2016 0.25 MIRU MOVE SFTY P PJSM w/Peak trucking 0.0 0.0 21:15 21:30 12/14/2016 12/14/2016 1.00 MIRU MOVE MOB P Pull Pits from sub and stage on pad. 0.0 0.0 21:30 22:30 12/14/2016 12/14/2016 0.75 MIRU MOVE MOB P Pull Sub off well,stage on pad for 0.0 0.0 22:30 23:15 workover prep work on rig prior to move 12/14/2016 12/15/2016 0.75 MIRU MOVE RURD P Begin prep work in cellar,swap out 0.0 0.0 23:15 00:00 pedestal,remove choke line. 12/15/2016 12/15/2016 11.50 MIRU MOVE RURD P Continue rig prep on 1B pad,remove 0.0 0.0 00:00 11:30 choke hose and hang ODS,install new pedistal,change out HCR B5 to manualvalve,Koomy hoses for 11" single stack,remove Otis Adapter from top of bag,install air adaptor on top of bag,pick stack off of stand and secure for travel,secure flow box to drip[pan and bolt up flow line. 12/15/2016 12/15/2016 1.00 MIRU MOVE RURD P PJSM with Peak and then place Jeeps 0.0 0.0 11:30 12:30 under sub and pits modules. 12/15/2016 12/15/2016 1.10 MIRU MOVE RURD T Wait on PEAK Tire Man to arrive and 0.0 0.0 12:30 13:36 check tires per procedure. 12/15/2016 12/15/2016 1.90 MIRU MOVE RURD T PEAK Tire Man arrives and checks all 0.0 0.0 13:36 15:30 76 tires(Jeeps and Rig tires). 12/15/2016 12/15/2016 2.00 MIRU MOVE MOB P Commence moving rig off of 1B Pad 0.0 0.0 15:30 17:30 12/15/2016 12/15/2016 1.17 MIRU MOVE MOB P Stop at 1Q Pad pull over area to 0.0 0.0 17:30 18:40 facilitate field changeout for CPF-3 and STP personnel. 12/15/2016 12/15/2016 2.09 MIRU MOVE MOB P Resume moving rig to 3M-24. 0.0 0.0 18:40 20:45 12/15/2016 12/15/2016 2.24 MIRU MOVE RURD P At 3M Pad,drop jeeps,hang tree in 0.0 0.0 20:45 23:00 cellar,prep well cellar area,place tree SSV,TBG Head Adapter and Tubing Head behind existing tree. 12/15/2016 12/16/2016 1.00 MIRU MOVE MOB P Spot Sub over 3M-24 wellhead 0.0 0.0 23:00 00:00 12/16/2016 12/16/2016 0.50 MIRU MOVE MOB P Sit Sub down on mats. 0.0 0.0 00:00 00:30 12/16/2016 12/16/2016 1.50 MIRU MOVE RURD P Spot Pits and sit down on mats. 0.0 0.0 00:30 02:00 12/16/2016 12/16/2016 1.00 MIRU MOVE RURD P Rig up rig and complete Post-Rig 0.0 0.0 02:00 03:00 Move Checklist. 12/16/2016 12/16/2016 1.00 MIRU MOVE RURD P Rig up hardline to tanks,begin 0.0 0.0 03:00 04:00 manifold in cellar and chokehouse. Bring on fluids to the pits. Rig accepted at 0400 hrs. 12/16/2016 12/16/2016 3.00 MIRU WELCTL RURD P Continue well kill prep,complete cellar 0.0 0.0 04:00 07:00 manifold,finish bringing in fluids 12/16/2016 12/16/2016 2.50 MIRU WELCTL MPSP P Bring in lubricator,install,pressure 0.0 07:00 09:30 test and lubricate out the BPV. Rig down lubricator. 12/16/2016 12/16/2016 1.00 MIRU WELCTL SFTY P Hold PJSM for pressure testing 0.0 0.0 09:30 10:30 hardline from tree to tanks and hold the Pre-Spud Meeting with all day-shift hands. Page 1/19 Report Printed: 1/10/2017 • • Operations Summary (with Timelog Depths) 0-4 3M-24 CsnocePtaiitiaps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 12/16/2016 12/16/2016 0.50 MIRU WELCTL SEQP P Pressure test hardline. Good test-no 0.0 0.0 10:30 11:00 leaks. 12/16/2016 12/16/2016 0.70 MIRU WELCTL KLWL P Begin well kill operations by first 0.0 0.0 11:00 11:42 pumping 60 bbls down the IA taking returns out the tubing to displace diesel out of the well with kill weight brine. 12/16/2016 12/16/2016 4.25 MIRU WELCTL KLWL P Diesel has been displaced out of well. 0.0 0.0 11:42 15:57 Switch to start pumping down the tubing with 11.6 ppg NaCUNaBr kill weight brine w/1.5%Safe Lube, Pumped 699 bbls,5 bpm @ 1600 psi. 12/16/2016 12/16/2016 0.50 MIRU WELCTL OWFF P Shut down pumps,observe SICP& 0.0 0.0 15:57 16:27 SITP.Tbg 0&IA O. 11.5 heavy fluid sample out. 12/16/2016 12/16/2016 0.50 MIRU WELCTL CIRC P Continued circulating the long way 0.0 0.0 16:27 16:57 another 80 bbls. 12/16/2016 12/16/2016 1.30 MIRU WELCTL OWFF P Watched SICP&SITP/30 mins. 0.0 0.0 16:57 18:15 Opened whitey in cellar,U-tubed tbg to IA to verify dead well.Well is dead. blow down TT lines and manifolds.Rd and secure cellar. 12/16/2016 12/16/2016 1.00 MIRU WHDBOP MPSP P PJSM,set 3"type HP BPV,line up 0.0 0.0 18:15 19:15 and PT BPV from below to 1000 psi for 10 mins.Good test. 12/16/2016 12/17/2016 4.75 MIRU WHDBOP NUND P PJSM,Funtion test LDS(2 gland nuts 0.0 0.0 19:15 00:00 seized up,lock down screws will turn, gland nuts flagged)ND tree.4.0k to free up,lay down same,inspect threads,good shape,install sealing plug off tool and dart,9 right hand turns for landing joint, 17"from center of LDS to top of dart,8 right hand turns to equilize and 4.5 right hand turns to retrieve sealing plug,secure cellar. 12/17/2016 12/17/2016 10.00 MIRU WHDBOP NUND P PJSM,bring in flow cross,NU BOPE, 0.0 0.0 00:00 10:00 RKB's to stack component lengths. Install 2-5/8"x 3-1/2"vrbl rams in upper cavity of middle stack.Function tested RAM's to verify correct hydraulic hose alignment,grease choke and stack. 12/17/2016 12/17/2016 1.00 MIRU WHDBOP RURD P Begin filling BOP stack and 0.0 0.0 10:00 11:00 commence with Shell Test. 12/17/2016 12/17/2016 0.50 MIRU WHDBOP RURD P Leaking flange at the 11"x 7"on the 0.0 0.0 11:00 11:30 Low Pressure Test bleed pressure off/re-tighten/resume Low pressure test with no issues. 12/17/2016 12/17/2016 1.40 MIRU WHDBOP RURD T Begin High Pressure Shell Test and a 0.0 0.0 11:30 12:54 marked yellow gland nut on the Tubing Hanger starts to leak.Bleed pressure off.Unsuccessful attempts to tighten/loosen gland nut.Call out Cameron Hand from KCC who has to go to 2S Pad to retrieve packing and wrenches from other Tool Hand's truck. 12/17/2016 12/17/2016 1.37 MIRU WHDBOP WAIT T Wait on Cameron Tool Hand 0.0 0.0 12:54 14:16 Page 2/19 Report Printed: 1/10/2017 • 410 Man, lii Operations Summary (with Timelog Depths) &MIAS 3M-24 Conoc.oPhillips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKS) 12/17/2016 12/17/2016 0.33 MIRU WHDBOP EQRP T Cameron Tool Hand arrives and 0.0 0.0 14:16 14:36 attempts to repair leaking gland nut. 12/17/2016 12/17/2016 0.30 MIRU WHDBOP RURD P Gland nut leak repaired!! Finish Shell 0.0 0.0 14:36 14:54 Test. 12/17/2016 12/18/2016 9.10 MIRU WHDBOP BOPE P Begin BOP Test(State Witnessed by 0.0 0.0 14:54 00:00 AOGCC representative Lou Grimaldi) Fail/Pass B6 and R2,replaced R2 valve,retest,all good. 12/18/2016 12/18/2016 0.25 MIRU WHDBOP RURD P Complete Initial BOPE test.RD BOPE 0.0 0.0 00:00 00:15 equipment. 12/18/2016 12/18/2016 0.75 MIRU WHDBOP SFTY P Pre spud with night crew(Luke Jury's 0.0 0.0 00:15 01:00 crew)PJSM-retrieving sealing plug/ BPV 12/18/2016 12/18/2016 0.75 MIRU WHDBOP MPSP P Drain stack,PU dry rod,8 RH turns, 0.0 0.0 01:00 01:45 confirm no pressure under BPV/ sealing plug,5-1/4 RH turns and retrieve Camron sealing plug/3"HP BPV,LD BPV equipment 12/18/2016 12/18/2016 2.35 COMPZN RPCOMP RURD P PJSM-Rig-up for pulling upper 12,009.1 12,009.1 01:45 04:06 completion.Install elevators.Post test valve alaignment,grease choke and stack. 12/18/2016 12/18/2016 2.00 COMPZN RPCOMP RURD P PJSM-MU landing joint(2ea. 10 ft 12,009.1 12,009.1 04:06 06:06 pups&lea.8 ft pup)and head pin. RIH,MU to tbg hanger with 11.5 RH turns. 12/18/2016 12/18/2016 1.10 COMPZN RPCOMP RURD P PJSM with day shift crew on pulling 12,009.1 12,009.1 06:06 07:12 tubing hanger. Bring Top Drive down on top of wooden block which is on top of the pups screwed into hanger (pipe has been marked at roatry table level). 12/18/2016 12/18/2016 0.56 COMPZN RPCOMP PULL P Set down 12k. Cameron Hand is 12,009.1 12,009.1 07:12 07:45 BOLDS. 12/18/2016 12/18/2016 0.16 COMPZN RPCOMP RURD P Cameron Hand has finished backing 12,009.1 12,009.1 07:45 07:55 off lock down screws.Raise Top Drive off of landing joint pipe does not move which indicates tubing not under very much compression.Remove wooden block and metal plate off of top of landing joint.Move Top Drive out of the way. 12/18/2016 12/18/2016 0.12 COMPZN RPCOMP RURD P Attach circulation hose to top of TIW 12,009.1 12,009.1 07:55 08:02 Valve.IA left open to atmosphere with a hand monitoring it. Page 3/19 Report Printed: 1/10/2017 • Operations Summary (with Timelog Depths) 3M-24 Conoco hiilips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation.. (ftKB) End Depth(ftKB) 12/18/2016 12/18/2016 1.20 COMPZN RPCOMP PULL P Begin pulling tubing out of 12,009.1 12,009.1 08:02 09:14 bowl starting moving north at 64k PUH with about 84k on now floor hand observing hole for fluid/gas while PUH at 115k.Have pulled up about 10'or so which is probably just pipe stretch. Seals still in PBR.Bring pump online at 2 bpm to try and hydraulically"lift" the pipe up weight falls off to about 85k PUH some more back to 110k now now at 118k..confere with town engineer as per procedure at 118k have permission to go to 165.7k.The current elevators will only go to 140k however PUH to 120k and hold up to 140 + evryone is confident thgat the 7"tubing hanger is hanging up in the stack. NOTE: IA was closed once tubing hanger came off of bowl. 12/18/2016 12/18/2016 1.96 COMPZN RPCOMP PULL P Continue with pulling and 12,009.1 12,009.1 09:14 11:12 pushing moderate amounts of gas comes up hole occasionally contacted Weatherford about getting a 150 ton rated elevator brought over from Deadhorse.We are currently pumping a bottom's up as mentioned earlier to remove gas from downhole and to clear up the fluids somewhat.After pumping a bottom's up,drain the stack and visually check to see if indeed the hanger is catching on something in the stack. Aftter draining stack found the primary hanger rubber seal is out and partially torn.Fish seal out with a piece of 20'stainless tubing. 12/18/2016 12/18/2016 0.75 COMPZN RPCOMP PULL P Once again try pulling hanger to rig 12,009.1 12,009.1 11:12 11:57 floor while keeping a visual on the hanger. Did verify the OD of the hanger is 6.95"and not 7.0" Pull up to 149k can see hanger geeting caught on the Driller's side where the 11"goes back to 7 1/16".Rig up another cable to pull side tension with.Pull up to 150k and work pipe and it pulls free pops up and it appears to have pulled the seals out of the PBR. Cancel 150 ton Elevator from Weatherford. Page 4/19 Report Printed: 1/10/2017 02. .• Operations Summary (with Timelog Depths) 111.74 3M-24 Conoccif ti111ps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr)' Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 12/18/2016 12/18/2016 2.00 COMPZN RPCOMP PULL T Elevator will not release.Send a man 12,009.1 12,009.1 11:57 13:57 up in the ManRider.Still unable to relaese the elevator.Only option left is to set the hanger back in the bowl and continue troubleshooting teh elevator. In the course of messing with the elevator we have now loosen 4 wraps on the Top Drive winch cable drum continue working both issues 12/18/2016 12/18/2016 1.29 COMPZN RPCOMP PULL T Winch is repaired and elevators 12,009.1 12,009.1 13:57 15:14 released.Clean and inspect elevators. Re-install,but elevators continue to stick and have great difficulty getting released. Order a 75 ton YT elevator from Weatherford in Deadhorse. In the meantime try pulling the hanger back up through the stack again.Getting hung up again.Rig up several lines to pull tension on pipe to try and centralize hanger through stack. 12/18/2016 12/18/2016 0.40 COMPZN RPCOMP PULL P We have pulled the hanger through 12,009.1 11,980.0 15:14 15:38 the stack again.Offline with pump. Remove the hanger pup and re-install the landing joint to the tubing. 12/18/2016 12/18/2016 2.00 COMPZN RPCOMP CIRC P RBIH with tubing until engage PBR. 11,980.0 12,007.1 15:38 17:38 PUH 2 ft and begin pumping 50 bbl viscofied sweep chased by 450 bbls KWF at maximum rate. Note:Having a hell of a time getting the square shouldered collars from hanging up in the stack when RBIH 12/18/2016 12/18/2016 0.36 COMPZN RPCOMP OWFF P Shut down pumps,blow down lines, 12,007.1 12,007.1 17:38 18:00 monitor well. 12/18/2016 12/18/2016 2.00 COMPZN RPCOMP RURD P PJSM-Crew changeout,laying down 12,007.1 12,007.1 18:00 20:00 tubing.Well static,dificulty with elevators again,lay down landing joint,TIW and head pin,change out elevators,prep floors for laying down 3-1/2"gas lift completion. 12/18/2016 12/19/2016 4.00 COMPZN RPCOMP PULL P TOOH laying down 3-1/2"gas lift 12,007.1 9,803.4 20:00 00:00 completion,joints#377 to#363, 2.875"DS nipple and joints#362 to #307(70 jts)as of midnight,no over pulls encountered. 12/19/2016 12/19/2016 14.25 COMPZN RPCOMP PULL P Continue TOOH laying down 3-1/2" 9,803.4 0.0 00:00 14:15 gas lift completion from joint#306 and jewelry, Corrosion not seen until after first ten foot pup past the 3rd GLM. From here to 19 joints had some corrosion on either the collars or pipe or both. 12/19/2016 12/19/2016 4.00 COMPZN WELLPR RURD P Rig down Rig workover equipment 0.0 0.0 14:15 18:15 and prep rig for CTU operations. Install wear bushing,N/D flow riser, install 7 1/16"adapter flange and 7" lubricator. Page 5/19 Report Printed: 1/10/2017 . • °' Operations Summary (with Timelog Depths) 0 3M-24 ConocoPhillips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/19/2016 12/19/2016 2.00 COMPZN WELLPR RURD P Install TTS Cablehead adapter with 0.0 0.0 18:15 20:15 Statewide Tool Hand and Rig Electrician. 12/19/2016 12/19/2016 1.00 COMPZN WELLPR RURD P Stab onto lubricator and pressure test 0.0 0.0 20:15 21:15 recently installed adapter flange and lubricator. 12/19/2016 12/19/2016 1.00 COMPZN WELLPR DISP P Displace coil to KWF. 0.0 0.0 21:15 22:15 12/19/2016 12/20/2016 1.75 COMPZN WELLPR BHAH P Pop off lubricator and install CASTM 0.0 30.3 22:15 00:00 BHA after PJSM. 12/20/2016 12/20/2016 1.50 COMPZN WELLPR BHAH T Surface test failed,no power to CAST- 30.3 30.3 00:00 01:30 M tool,trouble shoot,jumper wire to GO connector pinched when put together,repalce and surface test good. 12/20/2016 12/20/2016 0.75 COMPZN WELLPR BHAH P Surface test good. Bump up 4.3 ft. 30.3 30.3 01:30 02:15 stab injector. 12/20/2016 12/20/2016 3.75 COMPZN WELLPR TRIP P RIH with CAST-M logging tool BHA 30.3 11,960.0 02:15 06:00 #1,RIW 14k,log HRZ against original CBL,plus 8 ft correction,continue in hole. 12/20/2016 12/20/2016 0.35 COMPZN WELLPR DLOG P On depth,begin logging up 300 ft at15 11,960.0 11,660.0 06:00 06:21 fpm, PUW 28k, RBIH to 11,960 ft for second pass,RIW 14k. 12/20/2016 12/20/2016 0.15 COMPZN WELLPR DLOG P RBIH to 11,960 ft for second pass, 11,660.0 11,960.0 06:21 06:30 RIW 14k. 12/20/2016 12/20/2016 7.50 COMPZN WELLPR DLOG P On depth,perform a short strip,POOH 11,960.0 5,992.0 06:30 14:00 logging at 15 fpm to 5,992 ft,PUW 28k.pulled 29.5k at 10,960 ft,30.5k at 10,270 ft 12/20/2016 12/20/2016 1.00 COMPZN WELLPR TRIP P RBIH,paint 8,950'EOP flag for next 5,992.0 8,950.0 14:00 15:00 run referance. 12/20/2016 12/20/2016 1.75 COMPZN WELLPR TRIP P POOH 8,950.0 32.2 15:00 16:45 12/20/2016 12/20/2016 1.43 COMPZN WELLPR BHAH P On surface,flow check,PJSM-LD 32.2 32.2 16:45 18:10 BHA#1 CAST-M logging tool 12/20/2016 12/20/2016 1.50 COMPZN WELLPR CTOP P Displace reel to fresh water,PT inner 32.2 0.0 18:10 19:40 reel valve,tiger tank line,and pac-off. 12/20/2016 12/20/2016 0.50 COMPZN WELLPR CTOP P Swap reel back to workover fluid, 0.0 0.0 19:40 20:10 12/20/2016 12/20/2016 2.20 COMPZN WELLPR BHAH P PJSM,MU welltec and HES tools, 0.0 49.7 20:10 22:22 surface test welltec tools. 12/20/2016 12/21/2016 1.62 COMPZN WELLPR TRIP P RIH,with TorcPlug and HES pulling 49.7 3,744.2 22:22 00:00 tools 12/21/2016 12/21/2016 2.00 COMPZN WELLPR TRIP P Continue RIH,w/TorcPlug 3,744.2 8,999.7 00:00 02:00 12/21/2016 12/21/2016 0.50 COMPZN WELLPR TRIP P No correction,(using CTES lower 8,999.7 8,990.0 02:00 02:30 counter),PUH to setting depth 8,990' 12/21/2016 12/21/2016 1.50 COMPZN WELLPR PRTS P RU chart recorder,PUW 24 k,RIW 12 8,990.0 8,990.0 02:30 04:00 k,set TorcPlug,wait 15 mins (simops),test casing to 2,500 psi, (good test),freeze protect chart recorder.release plug,confirm plug is free,PUW 24k 12/21/2016 12/21/2016 1.00 COMPZN WELLPR TRIP P RIH to retrieve CAT SV plug, 8,990.0 12,000.0 04:00 05:00 Page 6/19 Report Printed: 1/10/2017 0 o 0 Operations Summary (with Timelog Depths) 3M-24 CoriocoPhitlijps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/21/2016 12/21/2016 1.25 COMPZN WELLPR FISH P PUW-30k,RIW 12 k,RIH slowly to 12,000.0 12,028.0 05:00 06:15 pass GS thru PBR,set down 2.5k as per Halliburton rep,PUW 31k,did not appear to latch,sat down again with same results,PU to 11,995 ft. 12/21/2016 12/21/2016 1.00 COMPZN WELLPR CIRC P Ciculate bottoms up. 12,028.0 11,995.0 06:15 07:15 12/21/2016 12/21/2016 1.25 COMPZN WELLPR PRTS P Shut in choke,pressure tbg to 900 psi, 11,995.0 12,028.0 07:15 08:30 lost 60 psi in 10 minutes,RBIH,set down 3k at 12,028 ft(CSV at 12,038 ft)casing 950 psi,lost 50 psi in 10 minutes, PUW 29k,no overpull or drop off in pressure,unable to latch into CSV,suspect fill, 12/21/2016 12/21/2016 3.00 COMPZN WELLPR TRIP P Bleed casing to 0 psi, PUH and paint 12,028.0 52.4 08:30 11:30 EOP flag at 11,850 ft.POOH keeping hole full. 12/21/2016 12/21/2016 0.50 COMPZN WELLPR OWFF P On surface,flow check good.PJSM 52.4 52.4 11:30 12:00 LD tools over dead well. 12/21/2016 12/21/2016 0.50 COMPZN WELLPR BHAH P Lay down BHA#2 TorcPlug tools,3" 52.4 0.0 12:00 12:30 GR packed full of fill,dogs jammed in release position,shear pin good. 12/21/2016 12/21/2016 0.60 COMPZN WELLPR BHAH P LD Thru tbg solutions cable head.Re- 0.0 0.0 12:30 13:06 head up with BHI CoilTrak cable head. 12/21/2016 12/21/2016 1.35 COMPZN WELLPR BHAH P MU BHI CoilTrak cable head,P/T 0.0 0.0 13:06 14:27 3,500 psi 12/21/2016 12/21/2016 0.90 COMPZN WELLPR BHAH P MU BHA#3 CoilTrac tools,Bi-Di jars 0.0 50.6 14:27 15:21 &3"G spear, 12/21/2016 12/21/2016 2.25 COMPZN WELLPR TRIP P RIH with BHA#3 50.6 11,900.0 15:21 17:36 12/21/2016 12/21/2016 0.25 COMPZN WELLPR TRIP P Correct to the EOP flag plus 16.0', 50.6 11,900.0 17:36 17:51 12/21/2016 12/21/2016 0.35 COMPZN WELLPR TRIP P Wash down thru PBR down to top of 11,900.0 12,027.0 17:51 18:12 CSV.tagging 12,027' 12/21/2016 12/21/2016 0.25 COMPZN WELLPR TRIP P PUH tie into the formation 12,027.0 11,800.0 18:12 18:27 12/21/2016 12/21/2016 0.30 COMPZN WELLPR DLOG P log formation between 11,800'to 11,800.0 11,872.0 18:27 18:45 11,872',plus 4.0',correct to the CBL. 12/21/2016 12/21/2016 0.25 COMPZN WELLPR TRIP P Wash done thru PBR to top of CSV, 11,872.0 12,030.8 18:45 19:00 PUW 30 k 12/21/2016 12/21/2016 0.25 COMPZN WELLPR TRIP P Shut down pump,stab into CSV, 12,030.8 12,021.0 19:00 19:15 pressure up to 100 psi,WHP, PUW 39 k CTWS,minus 1.0 k DHWOB. WHP dropped to 0 psi, 12,021',bring pump up losing 0.44 bpm 12/21/2016 12/21/2016 0.45 COMPZN WELLPR TRIP P POOH,pumping 1.5 bpm at 4,000 psi, 12,021.0 11,150.0 19:15 19:42 losing 0.50 bpm,PUH to 11,150',shut down pump monitor annular pressure sensor depth 11,130',TVD 5,482', annular pressure 3280', 12/21/2016 12/21/2016 2.00 COMPZN WELLPR TRIP P POOH,pumping 1.5 bpm at 4,000 psi, 11,150.0 53.0 19:42 21:42 losing 0.5 bpm, 12/21/2016 12/21/2016 0.50 COMPZN WELLPR OWFF P Tag up at surface,check well for flow, 53.0 53.0 21:42 22:12 PJSM,static losses 4 bph. 12/21/2016 12/21/2016 1.00 COMPZN WELLPR BHAH P LD BHI Coiltrak tools and fish. 53.0 0.0 22:12 23:12 Page 7/19 Report Printed: 1/10/2017 0 0.."I k Operations Summary (with Timelog Depths) X 3M-24 Pnitiips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X. Operation (ftKE) End Depth(ftKB) 12/21/2016 12/22/2016 0.81 COMPZN RPCOMP BHAH P Remove BHI upper quick sub and 0.0 0.0 23:12 00:00 crossover,rehead TTS 2.0"Go E-line head. 12/22/2016 12/22/2016 0.50 COMPZN RPCOMP BHAH P Finish MU 2.0"Go E-line head. 0.0 0.0 00:00 00:30 12/22/2016 12/22/2016 0.50 COMPZN RPCOMP SFTY P PJSM for MU tools 0.0 0.0 00:30 01:00 12/22/2016 12/22/2016 2.25 COMPZN RPCOMP BHAH P MU Welltec Stroker assembly. 0.0 85.3 01:00 03:15 12/22/2016 12/22/2016 0.25 COMPZN RPCOMP TRIP P Tag up for a zero,troubleshoot E-line 85.3 85.3 03:15 03:30 current spike. 12/22/2016 12/22/2016 2.95 COMPZN RPCOMP BHAH T PJSM,unstab the QTS,break 2"Go E 85.3 85.3 03:30 06:27 -line head,pull stroker tool OOH, space out DP across the variables, (contingency-disconnect stroker tool, install TIW valve into DP),trouble shoot TTS head.burnt connector, repair,MU BHA#4,Surface test good. 12/22/2016 12/22/2016 2.50 COMPZN RPCOMP TRIP P RIH with BHA#4 Stroker tool 85.3 10,712.8 06:27 08:57 assembly. 12/22/2016 12/22/2016 0.30 COMPZN RPCOMP SFTY P Plus 2.44 ft correction at 10,710.5 ft 10,712.8 10,712.8 08:57 09:15 EOP flag.Safety meeting and job parameters 12/22/2016 12/22/2016 0.70 COMPZN RPCOMP TRIP P Continue RIH with BHA#4,PUW at 10,712.8 12,004.0 09:15 09:57 11,508 ft 31k,RBIH to top of PBR at 12.004 ft,PU to 38k to confirm latch, extend stroker piston. 12/22/2016 12/22/2016 1.50 COMPZN RPCOMP FISH P Set anchors,Pull 65k three times,no 12,004.0 11,993.0 09:57 11:27 movement,Pull 84k three times,no movement,Pull 104k three times, packer assembly sheared loose, pulling up 30 to 45k,release anchors, CTW dropped 38k to 34k,PU to 65k, unable move,RBIH to 38k CTW,reset anchors,actuate piston,stroker pulling 70k for 1 ft,release anchors,CTW dropped 38k to 34k,PU to 65k no movement up,confer with town, limited PUW by cable head shear pins,getting out of safe casing with anchors and limited cycles on stroker per WeilTec rep. Page 8/19 Report Printed: 1/10/2017 I Operations Summary (with Timelog Depths) 01.4 3M-24 ConocoPhillips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS)` 12/22/2016 12/22/2016 0.85 COMPZN RPCOMP CIRC P Bullhead 35 bbls to formation 3.3 bpm 11,993.0 12,006.0 11:27 12:18 at 980 psi(losses in last 16 hrs after opening up formation is 100 bbls, approx 8 bph static)shut down,WHP 980 to 0 psi in 4 minutes(9.2 bbl return,3.3 to 1.3 bpm flow back rate) shut in choke, WHP 0 to 50 psi in 5 min,coil 50 psi, Bleed WHP 50 to 0 psi in 4 min.(2.2 bbl return, 1.3 to.5 bpm flow back rate)shut in choke) WHP 0 to 11 psi in 15 minutes,coil 43 psi. RIH,stack 13k on packer at 12,006 ft, PU to neautral,set anchors,stroke down 10k, PUW 29k,5.5"GS sheared. 12/22/2016 12/22/2016 0.50 COMPZN RPCOMP OWFF P Open up to monitor well,WHP 11 to 0 12,006.0 12,006.0 12:18 12:48 psi,Flow out.5 bpm to 0 in 15 min, well static for 15 minutes. 12/22/2016 12/22/2016 2.35 COMPZN RPCOMP TRIP P POOH,Paint EOP to low for next BHA 12,006.0 87.8 12:48 15:09 (300 ft OAL)use EOP flag at 10,710.5 ft,POOH 12/22/2016 12/22/2016 0.50 COMPZN RPCOMP OWFF P On surface,monitor well for flow, 87.8 87.8 15:09 15:39 PJSM-lay down BHA#4 over open hole. 12/22/2016 12/22/2016 0.85 COMPZN RPCOMP BHAH P LD BHA#4 WelITec Stroker assembly 87.8 0.0 15:39 16:30 and TTS cable head 12/22/2016 12/22/2016 1.50 COMPZN RPCOMP CTOP P PJSM-Cut off BHI CTC and install 0.0 0.0 16:30 18:00 Baker external CTC. 12/22/2016 12/22/2016 0.25 COMPZN RPCOMP CTOP P Pull test CTC to 50 k,PT to 3,500 psi, 0.0 0.0 18:00 18:15 PT choke manifold. 12/22/2016 12/22/2016 0.50 COMPZN RPCOMP CTOP P Crew change,PJSM for plan forward, 0.0 0.0 18:15 18:45 and short safety stand down with crews,because of recent incident with ASRC,making sure crew was in the game and focused. 12/22/2016 12/22/2016 1.50 COMPZN RPCOMP CTOP P MU BHA for pumping e-line slack out 0.0 0.0 18:45 20:15 of reel, 12/22/2016 12/22/2016 1.00 COMPZN RPCOMP CTOP P Pump slack forward 1.9 bpm at 3850 0.0 0.0 20:15 21:15 psi,unstab INJH,break off BHA,pull e -line from well,cut from CTC,cut 315' of eline,installed boot eline 12/22/2016 12/23/2016 2.75 COMPZN RPCOMP BHAH P PJSM,MU fishing BHA#5 0.0 307.5 21:15 00:00 12/23/2016 12/23/2016 2.30 COMPZN RPCOMP TRIP P RIH,with packer fishing tools 307.5 10,934.9 00:00 02:18 12/23/2016 12/23/2016 0.25 COMPZN RPCOMP TRIP P Stop at the EOP flag 10,627.5',no 10,934.9 11,999.6 02:18 02:33 correction,continue IH,PUW 33 k at 11,950' 12/23/2016 12/23/2016 2.00 COMPZN RPCOMP FISH P Bring pump up to 1.0 bpm,engage 11,999.6 11,999.6 02:33 04:33 fish,set down 6 k CTSW,PUH to 60 k,work packer up jarring 65 k-70 k. straight pull to 75 k-80 k,@14 jar licks -make call to Nabors town,to get approval to pull max pull 100 k. Page 9/19 Report Printed: 1/10/2017 0 r Operations Summary (with Timelog Depths) `= 3M-24 Conocophitll Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/23/2016 12/23/2016 0.50 COMPZN RPCOMP FISH P Discuss plan forward with town,stack 11,999.6 11,999.6 04:33 05:03 0 on fish,pumps on,release off fish. 12/23/2016 12/23/2016 2.45 COMPZN RPCOMP TRIP P POOH with BHA#5,start loading 11,999.6 307.5 05:03 07:30 pipe. 12/23/2016 12/23/2016 0.50 COMPZN RPCOMP OWFF P Observe well for flow.PJSM-LD BHA 307.5 307.5 07:30 08:00 over open hole. 12/23/2016 12/23/2016 2.50 COMPZN RPCOMP BHAH P LD BHA#5,excellerators damaged, 307.5 0.0 08:00 10:30 pics in folder. 12/23/2016 12/23/2016 0.50 COMPZN RPCOMP RURD P Clean and clear floors. 0.0 0.0 10:30 11:00 12/23/2016 12/23/2016 4.00 COMPZN RPCOMP RURD P PJSM-Switch equipment over to pipe 0.0 0.0 11:00 15:00 operations,annular boot flange,bell nipple,elevators,continue loading/ tally pipe,bring in fishing BHA. 12/23/2016 12/23/2016 4.00 COMPZN RPCOMP BHAH P PJSM-MU BHA#6 Packer Fishing 0.0 220.6 15:00 19:00 assembly 12/23/2016 12/23/2016 0.60 COMPZN RPCOMP RURD P PJSM,check DP equipment,prep rig 220.6 220.6 19:00 19:36 floor 12/23/2016 12/24/2016 4.40'COMPZN RPCOMP PULD P PU/Run- 2-7/8"S-135, 10.4#,HT 220.6 2,736.4 19:36 00:00 Pac DP 12/24/2016 12/24/2016 3.00 COMPZN RPCOMP PULD P Continue TIH with 2-7/8"S-135 HT DP 2,736.4 4,463.9 00:00 03:00 12/24/2016 12/24/2016 3.00 COMPZN RPCOMP OTHR P Load&tally 185 joints of DP into the 4,463.9 4,463.9 03:00 06:00 pipe shed 12/24/2016 12/24/2016 6.70 COMPZN RPCOMP PULD P PU/Run- 2-7/8"S-135, 10.4#,HT 4,463.9 10,281.5 06:00 12:42 Pac DP 12/24/2016 12/24/2016 1.30 COMPZN RPCOMP OTHR P PJSM-Load&tally 55 joints of DP 10,281.5 10,281.5 12:42 14:00 into the pipe shed(375 total loaded and tallied) 12/24/2016 12/24/2016 2.00 COMPZN RPCOMP PULD P PU/Run- 2-7/8"S-135, 10.4#,HT 10,281.5 11,948.5 14:00 16:00 Pac DP to joint#372, UP wt-116k,DN wt-55k 12/24/2016 12/24/2016 0.25 COMPZN RPCOMP SFTY P PJSM-plan forward picking up higher 11,948.5 11,948.5 16:00 16:15 rated handling equipment. 12/24/2016 12/24/2016 1.45 COMPZN RPCOMP FISH P MU to torque spec XO and 3-1/2"floor 11,948.5 11,984.0 16:15 17:42 valve,change out elevators to 250T bottlenecks,MU one at a time to joints #273 and 274 in mouse hole and RIH, MU to joint#275, Up wt 108k,DN wt 60k.Sat down at 10k,4 ft in on joint #375 at 11,984 ft.mark pipe,PU 130k, packer fish engauged, 12/24/2016 12/24/2016 1.25 COMPZN RPCOMP FISH P PU to twice160k,jars fired,pull 200k 11,984.0 11,984.0 17:42 18:57 mark pipe,no movement,set down 10 k,PUH to 180 k,jars fired pulled 200 k,set back down 10 k,PUW to 190 k, jars fired,lost weight,PUW 100 k. attempt to re-engage fish and were unsuccessful,discussed with town, decision was made to TOH to inspect BHA. 12/24/2016 12/24/2016 1.00 COMPZN RPCOMP PULD Laydown 1 jt of DP,MU TIW valve 11,984.0 11,984.0 18:57 19:57 and head pin,close 2 5/8"x 3 1/2" variables,bullhead 35 bbls,shut pump down, 12/24/2016 12/24/2016 2.00 COMPZN RPCOMP OWFF P Check well for flow,RD circulating 11,984.0 11,984.0 19:57 21:57 hose and chiksan. Brake head pin. Page 10/19 Report Printed: 1/10/2017 • Operations Summary (with Timelog Depths) 0,K,,,'... 0 3M-24 Co(tocoPthitllps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/24/2016 12/25/2016 2.05 COMPZN RPCOMP PULD P PJSM,LD 2 7/8"DP on singles. 11,984.0 10,596.0 21:57 00:00 12/25/2016 12/25/2016 14.00 COMPZN RPCOMP PULD P Continue TOH with DP. 10,596.0 535.0 00:00 14:00 12/25/2016 12/25/2016 0.50 COMPZN RPCOMP RGRP T Work on Oil Country tongs,swap over 535.0 535.0 14:00 14:30 to little jerks to complete LD DP. 12/25/2016 12/25/2016 0.50 COMPZN RPCOMP PULD P Continue laying down last 10 joints. 535.0 220.6 14:30 15:00 12/25/2016 12/25/2016 0.65 COMPZN RPCOMP BHAH P Monitor well for flow.PJSM-LD BHA 220.6 220.6 15:00 15:39 over dead well.Prep floors to LD BHA #6 12/25/2016 12/25/2016 1.75 COMPZN RPCOMP BHAH P LD BHA#6, 220.6 0.0 15:39 17:24 12/25/2016 12/25/2016 0.50 COMPZN RPCOMP PULL P Found that we had pulled the PBR out 0.0 0.0 17:24 17:54 of the packer.pictures are on the s:drive(PBR from BHA#6).remove fish from spear, 12/25/2016 12/25/2016 4.00 COMPZN WHDBOP RURD P Prep test joints and rig for weekly BOP 0.0 0.0 17:54 21:54 test, 12/25/2016 12/26/2016 2.10 COMPZN WHDBOP BOPE P Start weekly BOPE test,low pressure 0.0 0.0 21:54 00:00 250psi/high pressure 3,500 psi,test witness waived per AOGCC,Matthew Herrera @ 12/23/16 12:05pm 12/26/2016 12/26/2016 6.50 COMPZN WHDBOP BOPE P Continue weekly BOP test,250 psi 0.0 0.0 00:00 06:30 low/3,500 psi high, 12/26/2016 12/26/2016 3.00 COMPZN WHDBOP RURD P Rig down BOPE test equipment,pull 0.0 0.0 06:30 09:30 test plug,install wear ring,post BOPE test greasing,inspect/service top drive&crown,clean and clear floors, prep floors to run DP, 12/26/2016 12/26/2016 2.50 COMPZN RPCOMP BHAH P PJSM-MU BHA#7 Packer fishing 0.0 223.5 09:30 12:00 assembly, ITCO spear w/2.949"to 3.06"range grapple,drain sub, bumper sub,oil jars,6 ea.4-3/4"DC, Intensifier,XO,XO,XO 12/26/2016 12/26/2016 5.25 COMPZN RPCOMP PULD P Single in hole with BHA#7 on 2-7/8" 223.5 6,005.0 12:00 17:15 HT-PAC DP 12/26/2016 12/26/2016 1.50 COMPZN RPCOMP OTHR P PJSM-load shed with 2-7/8"S-135, 6,005.0 7,421.0 17:15 18:45 10.4#,HT Pac DP 12/26/2016 12/27/2016 5.25 COMPZN RPCOMP PULD P TIH w/fishing tools on DP 7,421.0 9,779.0 18:45 00:00 12/27/2016 12/27/2016 1.00 COMPZN RPCOMP PULD P Continue TIH with DP(Joint 304) 9,779.0 10,155.0 00:00 01:00 12/27/2016 12/27/2016 0.65 COMPZN RPCOMP OTHR P PJSM-load shed with 2-7/8"S-135, 10,155.0 10,155.0 01:00 01:39 10.4#,HT Pac DP 12/27/2016 12/27/2016 3.35 COMPZN RPCOMP PULD P Continue TIH with DP 10,155.0 11,948.5 01:39 05:00 12/27/2016 12/27/2016 2.00 COMPZN RPCOMP FISH P Up wt at joint#373 99k,Dn wt 57k, 11,948.5 11,998.0 05:00 07:00 change out to 3-1/2"bottle neck elevators,MU XO&3-1/2"TIW to joint #374,TIH,MU XO&TIW to joint #375,TIH,UP/DN 102k/61k,set down 18 ft in on joint#375,PU 50k over,let jars hit,straight pull to 100k over,attempt 50k over 3 times,no movement,PU 80 k over,let jars hit, straight pull 100k over,on 3rd 80k jar tools freed up, PUW 102k,unable to re-engage, Page 11/19 Report Printed: 1/10/2017 `' Operations Summary (with Timelog Depths) 00* , t 3M-24 conoccsPhitlips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End,Depth(EKE) 12/27/2016 12/27/2016 1.00 COMPZN RPCOMP FISH P Confer with town,sat down eight times 11,998.0 11,980.0 07:00 08:00 to max-40k,fish not moving down, unable move past 11998 ft. 12/27/2016 12/27/2016 1.75 COMPZN RPCOMP CIRC P Lay down joint#375, MU head pin to 11,980.0 11,980.0 08:00 09:45 TIW,shut in bag,bullhead 35 bbls down backside, 12/27/2016 12/27/2016 1.50 COMPZN RPCOMP OWFF P Monitor well for breathing. Flowback 11,980.0 11,980.0 09:45 11:15 decreasing over time.Well static after 60 minutes(14bbls back).Observe well for additional 30 minutes.Static. 12/27/2016 12/28/2016 12.75 COMPZN RPCOMP PULD P POOH with fishing BHA,and possible 11,980.0 11:15 00:00 fish.No extra drag or overpulls observed while coming out of the hole. 12/28/2016 12/28/2016 2.00 COMPZN RPCOMP PULD P Continue laying down DP 1,699.0 252.2 00:00 02:00 12/28/2016 12/28/2016 1.75 COMPZN RPCOMP BHAH P Monitor well for flow.PJSM-LD BHA 252.2' 0.0 02:00 03:45 over dead well,LD BHA#7 12/28/2016 12/28/2016 1.75 COMPZN RPCOMP PULL P OOH,Remove fish from spear,fish 0.0 0.0 03:45 05:30 length 17"-19" 12/28/2016 12/28/2016 1.00 COMPZN RPCOMP RURD P Crew change.Clean and clear rig 0.0 0.0 05:30 06:30 floor.Prep to swap drilling line. 12/28/2016 12/28/2016 7.00 COMPZN RPCOMP SLPC P PJSM.Re-string new drilling line. 0.0 0.0 06:30 13:30 12/28/2016 12/28/2016 1.00 COMPZN RPCOMP BHAH -P PU fishing BHA#8. 0.0 0.0 13:30 14:30 12/28/2016 12/29/2016 9.50 COMPZN RPCOMP PULD P Single in hole with BHA#8 on 2-7/8" 0.0 6,665.6 14:30 00:00 DP. 12/29/2016 12/29/2016 7.50 COMPZN RPCOMP PULD P Continue TIH with BOT fishing BHA# 6,665.6 11,790.0 00:00 07:30 8 12/29/2016 12/29/2016 1.00 COMPZN RPCOMP RURD P MU Head pin,TIW and hose to top 11,790.0 11,790.0 07:30 08:30 joint of DP. 12/29/2016 12/29/2016 0.75 COMPZN RPCOMP CIRC P Line up to pump down DP.Circulate at 11,790.0 11,980.0 08:30 09:15 3+bpm while recipricating pipe. RD and blow down hose. 12/29/2016 12/29/2016 0.25 COMPZN RPCOMP FISH P RIH and engage fish.Slacking off 17ft 11,980.0 11,997.0 09:15 09:30 into joint 375.Made it 4 feet deeper with 5 Klbs down.Measurements indicate 4.5 ft spear travel into the fish. Confirm engagement with 20KIbs overpull. PUW=109Klbs,SOW=65Klbs. Begin jarring operations. 12/29/2016 12/29/2016 0.50 COMPZN RPCOMP JAR P Jar hits 1-3 at 165KIbs followed by 11,997.0 11,997.0 09:30 10:00 straight pull to 200Klbs. Jar hits 4-9 at 190Klbs followed by straight pull to 205Klbs Jar hits 10-11 at 200Klbs followed by striaght pull to 215 Klbs Jar hits 12-14 at 195Klbs followed by straight pull to 210Klbs Jar hit 15 at 200Klbs(90Klbs overpull) weight dropped to 170KIbs.Picked up and broke over to 110KIbs. Appears packer has shear released and fish is free. Page 12/19 Report Printed: 1/10/2017 ` Operations Summary (with Timelog Depths) OVI 3M-24 Conocot thps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start lime End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/29/2016 12/29/2016 0.75 COMPZN RPCOMP CIRC P RIH to space out top joint for head pin 11,997.0 12,011.0 10:00 10:45 and hose(packer fish 14ft deeper than hang up depth during fishing operations). Bullhead 35 bbls at 2 bpm and 800 psi. 12/29/2016 12/29/2016 1.50 COMPZN RPCOMP OWFF P Monitor well for breathing. Flowback 12,011.0 12,011.0 10:45 12:15 decreasing over time.Well static after 60 minutes(11.6 bbls back). 12/29/2016 12/29/2016 0.50 COMPZN RPCOMP RURD P Rig down head pin,TIW and hose. 12,011.0 12,011.0 12:15 12:45 Blow down hose. Change elevators. 12/29/2016 12/30/2016 11.25 COMPZN RPCOMP PULD P Begin singling out of hole with BHA 12,011.0 4,779.0 12:45 00:00 #8. BHA dragging,PUW=116KIbs. Swabbing while pulling,reduce tripping speed. 12/30/2016 12/30/2016 7.25 COMPZN RPCOMP PULD P Continue TOH with DP 4,779.0 200.0 00:00 07:15 12/30/2016 12/30/2016 2.00 COMPZN RPCOMP BHAH P PJSM. LD fishing BHA#8. 200.0 0.0 07:15 09:15 Recovered FHL packer body.Missing tubing tail assembly.Spear fully enagaged into mandrel,no-go landed out at top of fish. 12/30/2016 12/30/2016 0.75 COMPZN RPCOMP BHAH P Clean and clear rig floor.Discuss 0.0 0.0 09:15 10:00 fishing results with town team. 12/30/2016 12/30/2016 2.00 COMPZN WELLPR RURD P Reconfigure riser fot CT operations. 0.0 0.0 10:00 12:00 12/30/2016 12/30/2016 ' 0.50 COMPZN WELLPR CTOP P Perform e-line slack management. 0.0 0.0 12:00 12:30 Pump coil volume back. 12/30/2016 12/30/2016 1.00 COMPZN WELLPR BOPE P Pressure test inner reel iron and 0.0 0.0 12:30 13:30 stripper 250/3500 psi. 12/30/2016 12/30/2016 2.50 COMPZN WELLPR CTOP P i Continue preparing rig for CT 0.0 0.0 13:30 16:00 operations.Start cutting coil for slack management.trimmed 161'of coil(no wire),dress CT for CTC installation 12/30/2016 12/30/2016 2.75 COMPZN WELLPR WAIT T Phase 3 weather conditions 0.0' 0.0 16:00 18:45 12/30/2016 12/30/2016 2.00 COMPZN WELLPR CTOP P PJSM install CTC,pull test to 50k,and 0.0 0.0 18:45 20:45 PT to 3,500 psi 12/30/2016 12/30/2016 0.35 COMPZN WELLPR CTOP P Install nozzle,Pump slack forward, 0.0 0.0 20:45 21:06 12/30/2016 12/30/2016 1.50 COMPZN WELLPR CTOP P Rehead BHI upper quick, PT CTC to 0.0 0.0 21:06 22:36 3,500 psi. 12/30/2016 12/31/2016 1.41 COMPZN WELLPR BHAH P PU/MU drift BHA#9 0.0 53.4 22:36 00:00 12/31/2016 12/31/2016 0.75 COMPZN WELLPR BHAH P Finished MU drift BHA#9 53.4 53.4 00:00 00:45 12/31/2016 12/31/2016 2.75 COMPZN WELLPR TRIP P RIH with drift BHA#9 w/6.0"OD junk 53.4 11,785.0 00:45 03:30 mill on coil 12/31/2016 12/31/2016 0.25 COMPZN WELLPR DLOG P Log formation no correction,PUW 11,785.0 12,016.0 03:30 03:45 31.5 k Page 13/19 Report Printed: 1/10/2017 • • 0, Operations Summary (with Timelog Depths) 3M-24 ConocJPhillips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE). 12/31/2016 12/31/2016 0.50 COMPZN WELLPR TRIP P Set down 12,016' 12,016.0 12,230.0 03:45 04:15 4 k CTSW,zero DHWOB,PUW 37 k, PUH 12,004', RBIH clean 12,030',PUW 32.5 k,PUH 12,025' RBIH clean12,062',PUW 32.5 k,PUH 12,060' RBIH clean12,100',PUW 32.5 k,PUH 12,092' RBIH clean12050',PUW 33 k,PUH 12,142' RBIH clean12,200',PUW 33 k,PUH 12,193' RBIH clean 12,230',PUW 33 k, 12/31/2016 12/31/2016 2.00 COMPZN WELLPR TRIP P POOH, Paint EOP flag at 11,300 ft. 12,230.0 53.0 04:15 06:15 Continue POOH. 12/31/2016 12/31/2016 0.50 COMPZN WELLPR OWFF P Flow check at surface.Static. 53.0 53.0 06:15 06:45 12/31/2016 12/31/2016 1.00 COMPZN WELLPR BHAH P PJSM.LD BHA#9.BHA in good 53.0 0.0 06:45 07:45 condition.No damage. 12/31/2016 12/31/2016 2.50 COMPZN RPCOMP RURD P RU to run lower completion.Arrange 0.0 0.0 07:45 10:15 pipe shed in running order. 12/31/2016 12/31/2016 2.50 COMPZN RPCOMP RURD P Clean and straighten rig floor,dress 0.0 0.0 10:15 12:45 threads on,RU 3.5 elevators,service INJH 12/31/2016 12/31/2016 7.00 COMPZN RPCOMP PUTB P MU lower completion BHA,remove 0.0 516.2 12:45 19:45 upper check valves and no float valve sub. 12/31/2016 12/31/2016 4.00 COMPZN RPCOMP RCST P RIH,pumping min rate 0.30 bpm at 516.2 11,750.0 19:45 23:45 277 psi,58 fpm 12/31/2016 1/1/2017 0.25 COMPZN RPCOMP DLOG P Log formation for tie in 11,750'- 11,750.0 11,790.0 23:45 00:00 11,790' 1/1/2017 1/1/2017 0.75 COMPZN RPCOMP DLOG P Continue logging down 11,790.0 11,881.0 00:00 00:45 1/1/2017 1/1/2017 0.25 COMPZN RPCOMP RCST P RIH to setting depth 12,192.87',PUW 11,881.0 12,193.0 00:45 01:00 35 k 1/1/2017 1/1/2017 2.00 COMPZN RPCOMP CIRC P Circulate 55 bbl corrison inhibitor, 12,193.0 12,193.0 01:00 03:00 close EDC,line up to the kill line, bullhead 13 bbl of CI down hole. 1/1/2017 1/1/2017 0.50 COMPZN RPCOMP PACK P PUH out of compression 33 k CTWS, 12,193.0 11,725.0 03:00 03:30 Set packer Pressure up to 500 psi, 1000 psi, 1,700 psi(sheared out),2,000 psi, plus 16.8'DHWOB. 1/1/2017 1/1/2017 2.00 COMPZN RPCOMP TRIP P Remove length of lower completion 11,725.0 76.0 03:30 05:30 from counters, POOH 1/1/2017 1/1/2017 0.50 COMPZN RPCOMP OWFF P Observe well for flow.Static. 76.0 0.0 05:30 06:00 1/1/2017 1/1/2017 1.50 COMPZN RPCOMP BHAH P PJSM.LD lower completion running 0.0 06:00 07:30 tools BHA#10. 1/1/2017 1/1/2017 0.50 COMPZN RPCOMP BHAH P Clean and clear rig floor. Prepare to 0.0 0.0 07:30 08:00 run next BHA. 1/1/2017 1/1/2017 0.50 COMPZN RPCOMP BHAH P PJSM.PU BHA#11,BOT inflatable 0.0 51.0 08:00 08:30 test packer. 1/1/2017 1/1/2017 2.00 COMPZN RPCOMP TRIP P Bump up.Reset counters.RIH.Tie-in 51.0 9,060.0 08:30 10:30 to EOP flag.No correction. Position test packer on depth. 1/1/2017 1/1/2017 0.25 COMPZN RPCOMP MPSP P Close EDC.Set inflatable packer per 9,060.0 9,060.0 10:30 10:45 BOT. Page 14/19 Report Printed: 1/10/2017 • • 0 Operations Summary (with Timelog Depths) t 3M-24 ConocoPhitlips �fxk.3 Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase - Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 1/1/2017 1/1/2017 0.75 COMPZN RPCOMP PRTS P Pressure test casing,packer and plug 9,060.0 9,060.0 10:45 11:30 below test packer to 3,000 psi for 30 minutes.Good test. 1/1/2017 1/1/2017 0.50 COMPZN RPCOMP MPSP P PU and release test packer. Wait for 9,060.0 9,060.0 11:30 12:00 elements to relax. 1/1/2017 1/1/2017 2.50 COMPZN RPCOMP TRIP P POOH with BHA#11. Paint flags for 9,060.0 51.0 12:00 14:30 future milling run and casing patch run. 1/1/2017 1/1/2017 0.50 COMPZN RPCOMP OWFF P Observe well for flow.Static. 51.0 51.0 14:30 15:00 1/1/2017 1/1/2017 1.00 COMPZN RPCOMP BHAH P PJSM.LD BHA#11. 51.0 0.0 15:00 16:00 1/1/2017 1/1/2017 2.50 COMPZN WELLPR CTOP P Cut CTC.RU and pump slack forward, 0.0 0.0 16:00 18:30 recovered 61 ft of E-line, Installed BOT 3.090 OD,Slip type CTC,PT 3,500 psi. 1/1/2017 1/1/2017 4.00 COMPZN WELLPR BHAH P MU BOT Milling BHA#12, 0.0 227.3 18:30 22:30 1/1/2017 1/2/2017 1.50 COMPZN WELLPR TRIP P RIH,w/Fixed Blade Stabalizer and 227.3 5,126.0 22:30 00:00 Stabilizer Mill 1/2/2017 1/2/2017 0.70 COMPZN WELLPR TRIP P Continue RIH for tie in depth,set 5,126.0 6,961.0 00:00 00:42 down at 6,961',PUH 23 k.rate 1.83 bpm at 4230 psi. 1/2/2017 1/2/2017 2.25 COMPZN WELLPR MILL P Mill section 6,961'-7045', 1.85 bpm at 6,961.0 7,045.0 00:42 02:57 4,500 psi 1/2/2017 1/2/2017 0.25 COMPZN WELLPR TRIP P Continue RIH,set down minus 15 k 7,045.0 7,577.0 02:57 03:12 1/2/2017 1/2/2017 0.50 COMPZN WELLPR MILL P Mill 7,577'-7586'1.85 bpm at 4,500 7,577.0 7,586.0 03:12 03:42 psi.Multiple stalls and pick ups. 1/2/2017 1/2/2017 2.81 COMPZN WELLPR MILL P RIH and tag up at 7594.Work through 7,586.0 8,113.0 03:42 06:30 several tight spots at 7594 ft,7646,ft, 7898 ft,8073 ft,8113 ft. 1/2/2017 1/2/2017 7.00 COMPZN WELLPR MILL P Crew change.Continue to work mills 8,113.0 8,569.0 06:30 13:30 down.Tight apots at 8331 ft,8374 ft, 8394 ft,8517 ft,and 8569 ft. 1/2/2017 1/2/2017 0.75 COMPZN WELLPR CIRC P PU.Circulate 20 bbls HiVis pill with 8,569.0 8,563.0 13:30 14:15 1.5%Safelubs and 2.5%Lube 776. 1/2/2017 1/2/2017 0.75 COMPZN WELLPR MILL P Continue milling after pill exited mill. 8,563.0 8,572.0 14:15 15:00 Worked through 8563 to 8572 ft.Saw improved milling performance with lube pill across milling area. 1/2/2017 1/2/2017 1.75 COMPZN WELLPR TRIP T POOH to prepare for BOP test. 8,572.0 227.3 15:00 16:45 1/2/2017 1/2/2017 0.50 COMPZN WELLPR OWFF T Check well for flow,PJSM 227.3 227.3 16:45 17:15 1/2/2017 1/2/2017 2.50 COMPZN WELLPR PULD T LD milling BHA#12 227.3 0.0 17:15 19:45 ""'Note:Cut 58'of E-line 1/2/2017 1/2/2017 2.00 COMPZN WELLPR BHAH P Swap over from Coil riser to Workover 0.0 0.0 19:45 21:45 riser,for BOP testing. 1/2/2017 1/2/2017 2.00 COMPZN WELLPR RURD P MU,test joints 0.0 0.0 21:45 23:45 1/2/2017 1/3/2017 0.25 COMPZN WHDBOP BOPE P Test BOPE,AOGCC(Guy Cook) 0.0 0.0 23:45 00:00 waived witness,test BOPE and annular 250psi low/3,500psi high. 1/3/2017 1/3/2017 8.00 COMPZN WHDBOP BOPE P Continue Testing BOPE,AOGCC 0.0 0.0 00:00 08:00 (Guy Cook)waived witness,test BOPE and annular 250psi low/3,500psi high. Page 15/19 Report Printed: 1/10/2017 • ;-•0 Operations Summary (with Timelog Depths) 3M-24 ConocoPhiflips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 1/3/2017 1/3/2017 3.00 COMPZN WHDBOP RURD P Break down TIW valves, PJSM, 0.0 0.0 08:00 11:00 change out WO riser for CT lubricator. 1/3/2017 1/3/2017 2.00 COMPZN WELLPR PRTS P Ru and repare to test IRV and 0.0 0.0 11:00 13:00 stripper.Pump forward to fluid pack reel.Close blind/shear rams. PT to 250/3500 psi. 1/3/2017 1/3/2017 3.00 COMPZN WELLPR CTOP T PU injector.Observe boot missing 0.0 0.0 13:00 16:00 from e-line. Replace same. Inspect BOPE.Small section of e-line found and recovered from ram cavity. ****Note:4.0 hrs DT 1/3/2017 1/3/2017 2.00 COMPZN WELLPR BOPE T Attemp to test door seals and upper 0.0 0.0 16:00 18:00 blind shears,remove riser and set test plus,retest successful. 1/3/2017 1/3/2017 2.25 COMPZN WELLPR CTOP P Swap riser over to Coil operations,PT 0.0 0.0 18:00 20:15 and chart test 1/3/2017 1/3/2017 2.50 COMPZN WELLPR BHAH P MU BHA,tag up reset counters to 0.0 130.1 20:15 22:45 zero 1/3/2017 1/4/2017 1.25 COMPZN WELLPR TRIP P RIH w/redressed dual mill BHA#13 130.1 2,317.0 22:45 00:00 1/4/2017 1/4/2017 1.50 COMPZN RPCOMP TRIP P Continue RIH,PUW 23 k,set down at 2,317.0 8,516.0 00:00 01:30 8516 ft. 1/4/2017 1/4/2017 7.00 COMPZN RPCOMP MILL P Mill interval 8,516-8,564'- 8,516.0 8,564.0 01:30 08:30 Pumped lube pills.No improvement in milling performance. 30+stalls on the motor. Can not make forward progress. 1/4/2017 1/4/2017 1.50 COMPZN RPCOMP TRIP P Made decision to POOH and 8,566.0 140.0 08:30 10:00 reconfigure BHA. 1/4/2017 1/4/2017 0.50 COMPZN RPCOMP OWFF P OWFF.PJSM for LD BHA#13. 140.0 140.0 10:00 10:30 1/4/2017 1/4/2017 1.75 COMPZN RPCOMP BHAH P LD BHA#13.Overall BHA looks good. 140.0 0.0 10:30 12:15 Most of the wear on the mills was on the front edges of the lower mill.Did not appear that the upper mill was working on the 7"casing ID. 1/4/2017 1/4/2017 1.00 COMPZN RPCOMP BHAH P Remove upper stabilizer mill from 0.0 127.0 12:15 13:15 string.PU BHA#14 with single lower mill only. 1/4/2017 1/4/2017 2.00 COMPZN RPCOMP TRIP P RIH with BHA#14.PUW 25 k, 127.0 8,555.0 13:15 15:15 continue IH 1/4/2017 1/4/2017 0.75 COMPZN RPCOMP MILL P Tag up at 8557 ft.Resume milling 7" 8,555.0 8,555.0 15:15 16:00 casing ID. Not making headway, discuss with town,decision was made to POOH 1/4/2017 1/4/2017 1.75 COMPZN RPCOMP TRIP P POOH 8,555.0 127.3 16:00 17:45 1/4/2017 1/4/2017 2.00 COMPZN RPCOMP PULD P PJSM,check well for flow,LD milling 127.3 0.0 17:45 19:45 BHA#14 1/4/2017 1/4/2017 3.75 COMPZN RPCOMP WAIT P Wait in tools from Deadhorse. 0.0 0.0 19:45 23:30 1/4/2017 1/5/2017 0.50 COMPZN RPCOMP PULD P PJSM,load under reamer into the 0.0 92.0 23:30 00:00 pipe,shed,MU Milling BHA#15 1/5/2017 1/5/2017 1.00 COMPZN RPCOMP PULD P Continue MU Milling BHA 92.0 126.6 00:00 01:00 Page 16/19 Report Printed: 1/10/2017 ' Operations Summary (with Timelog Depths) 0 3M-24 ConocoPhillips Rk�ka Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/5/2017 1/5/2017 1.50 COMPZN RPCOMP TRIP P RIH 126.6 8,782.0 01:00 02:30 1/5/2017 1/5/2017 0.25 COMPZN RPCOMP TRIP P Correct to the EOP flag plus 33.0 ft. 8,782.0 9,120.0 02:30 02:45 continue IH 1/5/2017 1/5/2017 2.50 COMPZN RPCOMP UREM P Underream 7"casing ID across 9,120.0 8,568.0 02:45 05:15 expandable casing patch setting area, with Baker UR dressed with 6.25" knives, Pump rate 1.7 bpm at 3,850 psi. Reamed up hole from 9120 ft to 8560 ft at 5 fpm.Reamed up through section that we had trouble milling though at 3 fpm with no issues. 1/5/2017 1/5/2017 1.50 COMPZN RPCOMP TRIP P POOH,pumping across the top 8,568.0 126.6 05:15 06:45 1/5/2017 1/6/2017 17.25 COMPZN RPCOMP WAIT T Waiting on weather,Phase 3. Heavy 126.6 126.6 06:45 00:00 equipment convoy to the rig for crew change. 1/6/2017 1/6/2017 7.50 COMPZN RPCOMP WAIT T Waiting on Weather. Phase 3,perform 126.6 126.6 00:00 07:30 Post Blow checklist 1/6/2017 1/6/2017 1.00 COMPZN RPCOMP BHAH P Phase 1 in the field.Crew change. 126.6 0.0 07:30 08:30 PJSM.LD under-reamer BHA. All under-reamer blades accounted for.Wear observed on the tips of the blades as expected.Overall BHA in good shape. 1/6/2017 1/6/2017 0.75 COMPZN RPCOMP OTHR P Clean and clear Rig Floor 0.0 0.0 08:30 09:15 1/6/2017 1/6/2017 2.00 COMPZN RPCOMP PULD P PJSM,MU caliper BHA#16 0.0 127.0 09:15 11:15 1/6/2017 1/6/2017 1.75 COMPZN RPCOMP TRIP P RIH,re-paint 8,656'EOP flags on the 127.0 9,251.0 11:15 13:00 way IH. 1/6/2017 1/6/2017 0.40 COMPZN RPCOMP WAIT P Wait for Caliper to open 9,251.0 9,251.0 13:00 13:24 1/6/2017 1/6/2017 0.60 COMPZN RPCOMP DLOG P Start logging at 50 fpm uphole untill 9,251.0 6,943.0 13:24 14:00 tool timed out, 1/6/2017 1/6/2017 1.25 COMPZN RPCOMP TRIP P POOH 6,943.0 127.0 14:00 15:15 1/6/2017 1/6/2017 0.50 COMPZN RPCOMP 'OWFF P Check well for flow,PJSM 127.0 127.0 15:15 15:45 1/6/2017 1/6/2017 1.25 COMPZN RPCOMP PULD P LD logging BHA#16 127.0 0.0 15:45 17:00 1/6/2017 1/6/2017 4.50 COMPZN RPCOMP OTHR P Clear and prep rig floor,Wait on 0.0 0.0 17:00 21:30 caliper data processing. 1/6/2017 1/7/2017 2.50 COMPZN RPCOMP BHAH P PJSM,PU/MU MetalSkin Cased Hole 0.0 129.0 21:30 00:00 Liner 1/7/2017 1/7/2017 2.25 COMPZN RPCOMP BHAH P Continue PU/MU BHA#17 w/Metal 129.0 150.0 00:00 02:15 Skin cased hole Liner 1/7/2017 1/7/2017 3.25 COMPZN RPCOMP BHAH P Install 2-7/8"elevators, PU/MU spacer 150.0 303.0 02:15 05:30 pipe. 1/7/2017 1/7/2017 1.50 COMPZN RPCOMP BHAH P PJSM.Crew change.stab coil,MU 303.0 303.0 05:30 07:00 injector. 1/7/2017 1/7/2017 3.75 COMPZN RPCOMP TRIP P Bump up.reset counters.RIH with 303.0 9,074.0 07:00 10:45 casing patch BHA.Correct to first EOP flag at 8656 ft. Confirm depth with second EOP flag at 8800 ft. PU and position patch on depth. Page 17/19 Report Printed: 1/10/2017 • • m =° Operations Summary (with Timelog Depths) oaf 3M-24 ConocoPhillips Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/7/2017 1/7/2017 4.00 COMPZN RPCOMP OTHR P Begin expandable casing patch setting 9,074.0 8,930.0 10:45 14:45 sequence.Pressure up to 4500 psi. Good indication of cone movement. Bleed off pressure.Move 5 ft uphole. Pressure up to 4500 psi to move cone. Repeat. After 31 strokes,Cone exited top of patch at 8930 ft as planned.Lost 18KIbs 1/7/2017 1/7/2017 1.50 COMPZN RPCOMP PRTS P PU to 8600.Line up and PT 7"casing 8,771.0 8,795.0 14:45 16:15 to 2500 psi for 30 minutes. Good test. 1/7/2017 1/7/2017 1.25 COMPZN RPCOMP TRIP P POOH. 8,795.0 302.0 16:15 17:30 1/7/2017 1/7/2017 0.50 COMPZN RPCOMP OWFF P Check well for flow,PJSM 302.0 302.0 17:30 18:00 1/7/2017 1/7/2017 3.00 COMPZN RPCOMP PULD P LD ECP BHA#17 302.0 0.0 18:00 21:00 1/7/2017 1/7/2017 1.50 COMPZN RPCOMP OTHR P Load out WFT equipment 0.0 0.0 21:00 22:30 1/7/2017 1/7/2017 0.25 COMPZN RPCOMP OTHR P PJSM,pull wear ring 0.0 0.0 22:30 22:45 1/7/2017 1/8/2017 1.25 COMPZN RPCOMP OTHR P Change out CT riser for workover 0.0 0.0 22:45 00:00 riser. 1/8/2017 1/8/2017 1.50 COMPZN RPCOMP OTHR P Continue to prep RF for tubing.Clear 0.0 0.0 00:00 01:30 Mast of Ice Build up. 1/8/2017 1/8/2017 0.50 COMPZN RPCOMP SFTY P PJSM,for MU tubing,cofirm pipe shed 0.0 0.0 01:30 02:00 count, 1/8/2017 1/8/2017 4.00 COMPZN RPCOMP PUTB P Start MU upper completion as per 0.0 1,654.0 02:00 06:00 tally. 1/8/2017 1/8/2017 6.00 COMPZN RPCOMP PUTB P Continue running upper completion 1,654.0 3,571.0 06:00 12:00 per tally. 1/8/2017 1/8/2017 6.00 COMPZN RPCOMP PUTB P Continue running upper completion 3,571.0 5,487.3 12:00 18:00 per tally. 1/8/2017 1/9/2017 6.00 COMPZN RPCOMP PUTB P Crew Change,PJSM,continue PU 5,487.3 8,502.0 18:00 00:00 tubing 1/9/2017 1/9/2017 3.75 COMPZN RPCOMP PUTB P Continue PU tubing. 8,502.0 10,616.0 00:00 03:45 1/9/2017 1/9/2017 3.50 COMPZN RPCOMP PUTB P Stab seal assembly into PBR.Mark 11,734.0 11,734.0 03:45 07:15 landing joint and calculate space out. PU and LD 2 joints.Add spacer pup. Make up full joint below hanger and landing joint. 1/9/2017 1/9/2017 3.75 COMPZN RPCOMP CRIH P Line up and spot 11.6 ppg CI brine in 11,734.0 11,734.0 07:15 11:00 the IA. Pumping 3.5bpm at 510 psi. Underdisplace leaving 5 bbls inside tubing per program.Observed CI brine in returns. 1/9/2017 '1/9/2017 5.00 COMPZN RPCOMP PUTB P PUW 74 k,RIW 49 k Joint#367 10,616.0 11,734.0 11:00 16:00 1/9/2017 1/9/2017 2.00 COMPZN RPCOMP THGR P Land tubing hanger.RILDS. 11,734.0 11,734.0 16:00 18:00 1/9/2017 1/9/2017 0.50 COMPZN RPCOMP PRTS P Pressure test tubing and chart. P.T. to 11,734.0 11,734.0 18:00 18:30 3,500 psi for 30 minutes. Passing test. 1/9/2017 1/9/2017 1.50 COMPZN RPCOMP PRTS P Peform CMIT-T x IA TO 2,500 psi 11,734.0 11,734.0 18:30 20:00 for10 minutes and chart. Passing test. Page 18/19 Report Printed: 1/10/2017 • Operations Summary (with Timelog Depths) z SL� 3M-24 Cor�lvtilps Rig: NABORS CDR2-AC Job: RECOMPLETION Time Log > Start Depth Start Time: End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 1/9/2017 1/9/2017 1.00 COMPZN RPCOMP OWFF P L/D landing joint. Monitor TBG/IA for 11,734.0 11,734.0 20:00 21:00 30 minutes. 1/9/2017 1/9/2017 2.75 COMPZN RPCOMP FRZP P Use LRS to pump 50 bbls diesel down 11,734.0 11,734.0 21:00 23:45 IA for freeze protection. Monitor IA/ TBG for 10 minutes.Bleed IA down to 1/9/2017 1/10/2017 0.25 COMPZN WHDBOP MPSP P Decision made to set BPV and dart 11,734.0 11,734.0 23:45 00:00 with Cameron Tool Hand after draining and washing out the BOPE stack. 1/10/2017 1/10/2017 1.00 COMPZN RPCOMP MPSP P Continuing BPV and dart setting 11,734.0 11,734.0 00:00 01:00 operations with Cameron Tool Hand. 1/10/2017 1/10/2017 0.84 COMPZN RPCOMP MPSP P Pressure test the BPV by applying 11,734.0 11,734.0 01:00 01:50 1,200 psig on the IA for 10 minutes. Passing test. 1/10/2017 1/10/2017 COMPZN P PJSM for changing out rams in BOPE 11,734.0 01:50 01:50 and then N/D BOPE. Page 19/19 Report Printed: 1/10/2017 s KUPD 3M-24 Con©coPhillips Well Attributellr Max Angle TD Alaskainc. r Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Corrocc hilhpa 500292243200 KUPARUK RIVER UNIT PROD 70.03 9,189.96 12,489.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-24,2/10/2017 6.0823 AM SSSV:NIPPLE 200 12/11/2015 Last WO: 1/3/2008 41.00 1/26/1994 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,220.0 7/25/2016 Rev Reason:GLV C/O pproven 11/19/2016 HANGER;25.2 !Eva I Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR _ 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1.! SURFACE 95/8 8.921 41.0 5,310.4 3,285.6 4700 L80 BTC Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wtken(I...Grade Top Thread PRODUCTION 7 6.276 29.5 12,470.2 6,347.4 26.00 L-80 BTC-MOD Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;42.D-121.8 I TUBING 3 1/2 2.995 0.0 12,193.0 6,152.9 9.30 L-80 EUE 8rd M COMPLETION Completion Details lit Nominal ID Mandrel;3,259.9 g.,,® Top(tiKB) Top(TVD)(ftKB) Top not Cl Item Des Com (in) 25.1 25.1 0.29 HANGER McEvoy DP-1-D-S-3(7-1/16"x 3-%"EUE BxP)Tubing 2.995 IIIHanger w/Pup Joint pp 11,715.2 5,819.7 49.40 LOCATOR Baker GBH-22 Locator Sub w/pup(bottom of locator 2.990 II spaced out 3') 11222.3 5,824.4 49.14 SEAL ASSY Baker 80-40 Seal Assembly 2.990 SURFACE;41.05.310.4 l 11,725.1 5,826.2 49.07 PBR Baker 80-40 PBR(40k shear release) 2.980 11,738.1 5,834.7 48.74 PACKER Baker 7"x 3-1/2"FHL Ret.Packer(60k shear release) 2.940 Mandrel;6,116.3 11,791.5 5,870.3 47.38 NIPPLE 3.5"x 2.812"X Nipple with PXX Plug and Prong Tested 2.812 above and below 1. ar 12,107 4 6,092.4 45.00 XO Enlarging 3-1/2",9.3#,L-80 EUE-8rd AB-Mod Box x 4-1/2"STC Pin 2.995 Ported XO illa Mandrel 8348.3 E. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 4 Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) In 8,930.0 4,663.6 69.12 Casing Patch MetalSkin Cased Hole Liner,Drift 5.433",Burst 1/7/2017 5.488 5,000 psi,Collapse 3,300 psi,Grade 60,000 Casing Patch;6,930.0 I 12,139.0 6,114.8 45.08 Whipstock Set 2nd Baker 3.5 x 5.5 Gen II Delta Whipstock,RA 1/14/2017 0.000 tags 7.35 ft below TOWS.0°HS orientation. 12,173.0 6,138.8 45.18 Whipstock Set Baker 3.5 x 5.5 Gen II Delta Whipstock,RA tags 1/13/2017 0.000 7.35 ft below TOWS.0°HS orientation. Mandrel;10,095.9 12,240.0 6,186.0 45.23 Fish-Original 18.63'Tail pipe(Pup jt,D nipple,Pup jt,SOS)from 12/30/2016 2.992 Tall Pipe original FHL packer still in hole,drift with 6.0"Junk Mill to 12,230'w/CTD on 12/31/2016 Mandrel;11,278.2 Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/ Top(ftKB) Bhn(ftKB) (ftKB) (fd(B) Zone Date ft) Type Com 12,132.0 12,152.0 6,109.8 6,124.0 C-4,3M-24 8/30/2001 6.0 APERF EnerjeVPowerjet,0 deg Mandrel;11,657.1 C ph,44-90 orient 12,162.0 12,198.0 6,131.0 6,156.4 A-3,A-2,3M- 8/30/2001 6.0 APERF EnerjeVPowerjet,0 deg 24 ph,+/-90 orient 12,208.0 12230.0 6,163.4 6,178.9 A-1,3M-24 6/30/1994 4.0 IPERF 180 deg.phasing;2 1/2" LOCATOR;11,7152 Titan SEAL ASSY;11,722.3 - 12,230.0 12,244.0 6,178.9 6,188.8 A-1,3M-24 8/28/2001 ' 6.0 APERF EnerjeVPowerjet,0 deg PBR;11,725.1 i ph,+1-90 orient PACKER;11,738.1Mandrel Inserts St an N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com NIPPLE;11,791.5 Mi1 3,502.1 2,592.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/3/2016 2 6,635.2 3,790.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/3/2016 3 8,950.2 4,670.8 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 9/4/2016 4 10,983.6 5,422.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2008 5 11,952.8 5,983.4 CAMCO KBMG 1 GAS LIFT OPEN 11/8/2016 XO Enlarging;12,107.4 a, Notes:General&Safety End Date Annotation APERF;12,132.0-12,162.OL� - 7/28/2010 NOTE'View Schematic w/Alaska Schematic9.0 Whipstaek;12,139.0 1. 11 I Whipstock,12,1730 Ji 1111' APERF,12,162 0-12,196.0 i' iiiii IPERF;12,208.0-12,230.0--• APERF;12,230.0-12,244.0 Fish-Original Tail Pipe;12,240.0 I PRODUCTION;29.5-12,470.2 RECEIVED • • \c)Z- Q1 5 FEB 032017 WELL LOG TRANSMITTAL#903541499 AOGCC To: Alaska Oil and Gas Conservation Comm. February 1, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED i�i2 7Anchora e, Alaska 99501 BENDER % MINED JUN 3 2.01 RE: Leak Detect Log with ACX: 3M-24 Run Date: 14-16 SEP 2016 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 3M-24 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-22432-00 *Re-Deliver due to incomplete digital data,E-Set#27872 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'FIENTION 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:rn FEB 03 2017 S 21g5`� WELL LOG TRANSMITTAL#903735243 AOGCC To: Alaska Oil and Gas Conservation Comm. January 27, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 / BENDG/201ER RE: CAST-M w/FASTCASE: 3M-24 Run Date: 12/20/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3M-24 Data in LAS or DLIS format, Digital Log Image files 1 CD Rom 50-029-22432-00 FASTCACE Log 1 Color Log 50-029-22432-00111NNI CAST-M Field print 1 Color Log 50-029-22432-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ va v / 4/, RECEIVED • --� °�5� FEB 0 3 2017 WELL LOG TRANSMITTAL#903621758 AOGCC To: Alaska Oil and Gas Conservation Comm. January 11, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 Zi G/201-1 M BENDER �Ep .IUC�1 3 �+ 2'i17: RE: EM Pipe Xaminer: 3M-24 Run Date: 10/29/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3M-24 Digital Data(LAS), Digital Log file, Casing Inspection Report 1 CD Rom 50-029-22432-00 EM Pipe Xaminer(Processed Log) 1 color log 50-029-22432-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: vaLa.'W..., / .4.sk; • 1-76"1 WELL LOG TRANSMITTAL#903541499 To: Alaska Oil and Gas Conservation Comm. December 23, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 RECEIVED i203/20 t M.K.BENDER JAN 092017 RE: Leak Detect Log with ACX: 3M-24 AOGCC Run Date: 14-16 SEP 2016 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 3M-24 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-22432-00 Leak Detect Log with ACX(Processed Log) 1 Color Log 50-029-22432-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Pro 113 - 1 7 5-- 0 • Loepp. Victoria T (DOA) From: Herring, Keith E <Keith.E.Herring@conocophillips.com> Sent: Thursday,January 05,2017 3:21 PM To: Loepp,Victoria T(DOA) Subject: KRU 3M-24 (PTD# 193-195) Follow Up Flag: Follow up Flag Status: Flagged Good afternoon Victoria, ConocoPhillips submitted permits to drill a quad lateral out of KRU 3M-24(PTD#193-195)and the permits to drill the 4 laterals were approved on 11/10/16(PTD#'s 216-140,216-141,216-142,&216-143). In the cover letter ConocoPhillips requested a variance from the requirements of 20 ACC25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being to 500'from the original point. I am inquiring to see if the variance was granted? Thanks for your time and I look forward to hearing from you. Keith Herring CTD Engineer 907.263.4321(Office) 907.570.2410(Mobile) 700 G Street,ATO—664 Keith.E.Herring@conocophillips.com 1 ConocoPhillips • • 0,101,7„;4., THE STATE Alaska Oil and Gas Of j\ /\ SKA Conservation Commission .fix _ y 333 West Seventh Avenue i''174.441111;* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O 1.A9�� Fax: 907.276.7542 www.aogcc.alaska.gov Daniel Kane MA �'�}! Senior Wells Engineer s ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-24 Permit to Drill Number: 193-195 Sundry Number: 316-564 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this/U day of November, 2016. RBDMS NO4 1 6 2016 STATE OF ALASKA • r ALASKA OIL AND GAS CONSERVATION COMMISSION tj0U 0 2 2016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGc 1.Type of Request: Abandon H Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0L/ per tions shutdownU Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q , Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Cl Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q• 193-195 , 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22432-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 3M-24 ' Will planned perforations require a spacing exception? Yes ❑ No❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025523;ADL025524 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): .-, Plugs(MD): Junk(MD): ' 12490' • 6361' 0' 2951 none none Casing Length Size MD Burst Collapse Structural Conductor 79' 16" 121' 121' Surface 5265' 9.625" 5309' 3285' Intermediate Production 12439' 7" 12469' 6346' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12132'-12152' 6110'-6124' 3.5" L-80 12048' 12162'-12198' 6131'-6156' 12208'-12230' 6163'-6179' 12230'-12244' $ 6179'-6189' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SSSV: CAMCO DS LANDING NIPPLE SET 1/2/2008 • MD=507 ND=507 PACKER-BAKER FHL RETRIEVABLE PACKER . MD=12023 TVD=6033 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑� , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/15/2016 OIL ❑., . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Daniel Kane©265-6048 Email Daniel.Kane@conocophillips.com Printed Name Daniel Kane 265-6048 Title Sr.Wells Engineer Phone Signature Z, Date m(—ti)OV 2.QSI 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test L1J Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3 0 ^„ d l fes i Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Q' Subsequent Form Required: / G al RBDMS l.k, NOV S 2O 16 APPROVED BY Approved by: (� ISSIONER THE COMMISSION Date: i Ili�!`lO:.ui Four]dl�d Form 10-403 Revi ed 1 2015 O R wv�dli c� valid for 12 month�from the date of approval. � p Attachments in Duplicate Y'Ki 4141 /024 )""`A i.16 • REC .. NOV 0 2 2016 • ConocoPhullips Alaska AtOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 1",2016 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Producer KRU 3M-24(PTD# 193-195). Well 3M-24 was spudded and completed in 1994 as a Kuparuk A-sand single completion producer. In 1999,a tubing leak was discovered&patched. In 2001, additional perforations were shot in the A-& C-sands to make the well a comingled Kuparuk A- &C-sand single completion producer. In 2007/2008, a work-over was performed to pull & replace the upper completion after an additional tubing leak was found beneath the existing tubing patch. 1C."' , In September 2016, while preparing the well for a CTD development project, the well failed a CMIT-TxIA and �t, ' ultimately two leaks were discovered in the IA; one at 12,029' MD(production packer leak)&the second at 8,967' MD (deep 7" production casing leak). The well was added to the rig work-over list to pull & replace the single completion as well as to repair the deep production casing leak prior to performing the CTD development. This Sundry is intended to document the proposed work on KRU 3M-24 because of the intent to repair the well,pull tubing,&alter the casing,as well as to request approval to workover this well. This Sundry request is intended to be independent of the previously-approved Sundry(316-423)for CTD development. If you have any questions or require any further information,please call me at 265-6048 or email me at danny.kane n,conocophillips.com. Sincerely, Danny Kane Wells Engineer CPAI Drilling and Wells • KUP PROD . 3M-24 ConocoPhillips i Well Attributes Max Angle&MD TD Alaska.Inc. • Wellbore API/UWI Field Name Wellbore Status Incl 7) MD(ftKB) Act Btm(ftKB) , Ryy� 500292243200 KUPARUK RIVER UNIT PROD 70.03 9,189.96 12,489.0 ',YAW --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-24,7/27/20165.14.34 PM SSSV:NIPPLE 200 12/11/2015 Last WO: 1/3/2008 41.00 1/26/1994 VerGwlschemalic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,220.0 7/25/2016 Rev Reason:H2S 8 TAG pproven 7/25/2016 Casing Strings HANGER;3021 -17:7 ii_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED • Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len)I...Grade Top Thread SURFACE 95/8 8.921 41.0 5,310.4 3,285.6 47.00 L-80 BTC y 1k -Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade lop Thread PRODUCTION 7 6.276 29.5 12,470.2 6,347.4 26.00 L-80 BTC-MOD Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(7801(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 30.3 12,009.1 6,023.1 9.30 L-80 EUE8rdABMOD Completion Details CONDUCTOR;420-121.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl 7) Item Des Com (in) 30.3 30.2 0.34 HANGER MCEVOY GEN IV HANGER 3.500 NIPPLE;507.4 507.4 507.3 1.47 NIPPLE CAMCO DS LANDING NIPPLE SET 1/2/2008 2.875 12,007.3 6,021.8 45.16 SEAL ASSY BAKER LOCATOR OD 4.18/SEAL ASSEMBLY- 3.000 INSERTED IN ORIGINAL PBR-SET 1/2/2008 WORKOVER Tubing Description String Ma...ID(In) -Top(ftKB) Set Depth(ft..Set Depth(TVD)(..•Wt(IbI11) Grade Top Connection TUBING Original 5 4.000 12,008.5 12,048.0 6,050.5 GAS LIFT:3.502.1 Completion Details Nominal ID Top(ftKB) Top)TVD)(ftKB) Top Incl 7) Item Des Com (in) 12,008.5 6,022.7 45.16 PBR BAKER PBR W/10'STROKE 4.000 12,023.2 6,033.0 45.11'PACKER 'BAKER FHL RETRIEVABLE PACKER 3.000 12,037.5 6,043.1 45.07 NIPPLE CAMCO D NIPPLE NO GO 2.750 12.047.1 6,049.9 45.05 SOS 'BAKER SHEAR OUT SUB 3.500 SURFACE;41.05,3104-4 Perforations&Slots Shot I Dens Top(T1/0) Btm(ND) (shotslt Top(11(6) Btm(ftKB) (0KB) (ftKB) Zone Date t) Type Com GAS LIFT;6,635.2 12,132.0` 12,152.0 6,109.8 6,124.0 C-4,3M-24 8/30/2001 6.0 APERF 'Enerjet/Powerjet,0 deg 'F• ph,+/-90 orent • 12,162.0 12,198.0 6,131.0 6,156.4 A-3,A-2,3M- 8/30/2001 6.0 APERF Enerjet/Powerjet,0 deg • 24 ph,+!-90 orient • 12,208.0' 12,230.0 6,163.4 6,178.9 A-1,3M-24 6/30/1994 4.0 (PERF 180 deg.phasing;21/2" Titan GAS LIFT:6,950.3 = 12,230.0 12,244.0 6,178.9 6,188.8 A-1,3M-24 8/28/2001 6.0 APERF Enerjet/Powerjet,0 deg _„7 ph,+/-90 orient III Mandrel Inserts at L on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com GAS LIFT:10983 Si 1 3,502.1 2,592.7 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.156 1,307.0 1/5/2008 II2 6,635.2 3,790.8 CAMCO KBMG i GAS LIFT GLV BK-5 0.188 1,343.0 1/5/2008 111 3 8,950.3 4,670.8 CAMCO KBMG i GAS LIFT •OV BK-5 0.250 0.0 1/5!2008 4 10,983.7 5.422.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2008 5'. 11,952.8 5,983.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2008 GAS LIFT;11.952.8 Notes:General&Safety ill End Date Annotation 7/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 • I SEAL ASSY:12,00].3 PSR;12,008.5 1/'"7,-4 PACKER;12,023.2 NIPPLE:12,037.5 I SOS:12.047.1 11 ` APERF;12,132.0-12,152.0- _ 4- APERF;12.102.0-12.108.0-) (PERF;12206.412.230.0 APERF;11230.0-11244.0- -4 2 I PRODUCTION;290-12,470 • • KRU 3M-24 Proposed Rig Workover ConocoPhillips CTD Set-Up— P&R Single Completion & Repair Casing Leak Original PTD #:193-195 Alaska CURRENT STATUS: KRU 3M-24,a comingled Kuparuk A-&C-sand single completion producer, is currently shut-in after a production packer leak&deep production casing leak were discovered while performing well work needed prior to proposed CTD development on the well. In order for the CTD project to proceed,a rig work-over will be needed to pull the existing single completion, repair the deep casing leak,&install a new CTD-compatible completion. Please see below for a history of the well&annuli integrity diagnostics: - 1994—KRU 3M-24 was drilled targeting the Kuparuk A-sands along the field perimeter. The well was completed as a Single Completion producer after the Kuparuk A-1 sands were perforated. o Jul—Kuparuk A-1 sands fracture-stimulated. Screened out leaving 30.4 klbs 12/18 proppant in the well& 169 klbs 12/18 proppant in formation. - 1999—Tubing leak found at"'6,228'MD&patched. - 2001—Perforated new Kuparuk A-&C-sand intervals. o Aug—Pulled retrievable patch covering leak at 6,228' MD. Perforated Kuparuk A-1 sand from 12,230'—12,244' MD. Perforated Kuparuk A-2/A-3 sands from 12,162'—12,198' MD. Perforated Kuparuk C-4 sand from 12,132'—12,152' MD. o Sep—Re-installed tubing patch covering leak at 6,228' MD. - 2002—Found TxIA communication beneath tubing patch. Well shut-in. - 2003—Pulled existing patch, replaced leaking OV, &installed new patch. o Nov—Leaking OV check replaced&new patch finally installed. - 2006—Found TxIA communication beneath tubing patch. Well shut-in. o Sep—TxIA communication noted&diagnostics confirmed leak was beneath patch. o Oct—Replaced patch,subsequent TIFL failed. o Unable to set patch &get passing test remainder of year. - 2007—Well added to RWO list. Nordic 3 moves on well &starts RWO#1. o Leak at 6,228'MD confirmed. Additional leak at 11,987'MD identified. Added to RWO list. - 2008—Nordic 3 completes RWO#1 pulling&replacing the upper completion. o Jan—RWO completed. Shallow leak resulted from internal corrosion. Deeper leak(in sump below deepest GLM) resulted from external corrosion. Installed 3-%" upper completion. o Jun—OOA topped off w/RG-2401 sealant. - 2016—MIT-IA failed while preparing well for CTD development. o Aug—Sundry#316-423 approved for CTD development. ■ This work-over Sundry request is intended to be independent of this previously- approved Sundry for CTD development. o Sep—Cat SV set in tubing tail&GLD reconfigured for pending CTD development. CMIT-TxIA fails w/6gpm LLR. Dummy-off all GLMs&perform passing MIT-T to 2,000 psig. MIT-IA fails (same LLR as CMIT-TxIA LLR). Acoustic leak-detect log(ACX)identifies leaks at 8,967'& 12,029'MD. ■ 12,029' MD—Suspected packer leak at the casing wall/packer element interface. ■ 8,967' MD—Suspected internal casing corrosion at gas/water interface(gas lift OV had been at the 8,950' MD GLM since the 2008 RWO). ■ Well added to RWO list. Page 1 of 4 • KRU 3M-24 Proposed Rig Workover ConocoPhillips CTD Set-Up— P&R Single Completion & Repair Casing Leak Original PTD #:193-195 Alaska SCOPE OF WORK: The objectives for the proposed KRU 3M-24 RWO are to pull the existing single completion, install a new lower completion (restore production packer integrity),&repair the deep casing leak—the last of which requires sundry approval.The scope consists of pulling the existing upper completion, pulling the existing lower completion, installing either a straddle liner or expandable casing patch, &running a new upper completion. This will allow the well to be brought back online as a comingled Kuparuk A-&C-sand single completion producer ready for CTD development operations. Well Type: Comingled Kuparuk A-&C-sand Single Completion Producer MPSP: 2,952 psig using MPSP=(PP-(0.1*TVD)), or dry gas gradient • 2,952 psig=(3,566 psig–(0.1 psig/ft*6,149'T iD)) Reservoir Pressure/ND: Kuparuk A-&C-Sand Mid-Perfs–3,566 psig/6,149'T ' (11.2 ppg EMW Using last recorded shut-in tubing pressure&known fluid column. Wellhead Type: McEvoy Gen IV(5M) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams BOP Test Pressure 250/3,500 psig(2,500 psig high for Annular) Integrity Results: MIT-T Passed 04-Sep-2016 (MIT-T to 2,000 psig during IA Leak Diagnostics) MIT-IA Failed 04-Sep-2016 (Last passing TIFL 25-Jun-2016) MIT-OA Passed 25-Jun-2016 (MIT-0A to 1,800 psig) Earliest Start Date: 15-Nov-2016 Production Engineers: Yemeli Yemeli-Gozon 3M DPE/Chris Ruff 3M Development Engineer Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com SUMMARY OF COMPLETED&PROPOSED RWO PROCEDURE: Proposed Pre-Rig Work: 1. Function-test all LDS. Test tubing&I.C. pack-offs(T-POT/T-PPPOT/IC-POT/IC-PPPOT). 2. Install tubing-tail plug in 3-%z"Camco 2.75" D Landing Nipple at 12,037' MD. Pressure-test to confirm set. 3. Swap GLM#1&2 GLVs for DVs. Swap GLM#3 OV for DV. Pull DV from GLM#5. 4. Set 3"Type'H' BPV. Completed Rig Workover Procedure: 1. MIRU Nabors CDR-2 AC. V ' 2. Pull 3"Type'H' BPV. 3. Rock the diesel out of the tubing by reverse circulating 11.6 ppg KW brine. Line-up to pump 11.6 ppg KW brine the long-way to displace/kill the well. Shut-in, obtain SITP & SICP, & if still seeing surface pressure, repeat circulation. Perform 30-minute flow check to verify the well is static. 4. Install 3"Type`HP' BPV. Perform rolling-test against the BPV by pressuring-up on the IA to 1,000 psig. 5. ND existing 3-Y8"vertical tree. Make-up the Sealing HP Plug-Off tool to the BPV. NU BOPE&test to 250/3,500 psig(annular to 2,500 psig). 6. Pull the Sealing HP Plug-Off tool&3"Type`HP' BPV,screw in the landing joint,BOLDS,&unseat tubing hanger. Page 2 of 4 • • . , No---- KRU 3M-24 Proposed Rig Workover ConocoPhillips CTD Set-Up— P&R Single Completion & Repair Casing Leak Original PTD #:193-195 Alaska 7. P/U on the 3%"tubing&pull the tubing hanger to the rig floor. Circulate bottom's up if needed,flow check, &start TOH laying down the 3-YZ" Upper Completion. a. CONTINGENCY: If the seal assembly fails to pull from the PBR, RU E-Line and cut the 3-1/2" tubing at 11,986' MD, pull tubing to tubing cut,&fish remaining tubing stub/seal assembly with coiled tubing. 8. Convert from stick pipe to coiled tubing operations. R/D flow riser, R/U lubricator, spot injector head, & �_ perform E-line slack management as needed. M/U coiled tubing connector and pull-&pressure-test same. coil_ 9. M/U & TIH w/ CT BHA #01 — Casing Logging Assembly. TIH to bottom & perform multi-finger caliper (or coil_ equivalent) logging run from the top of the existing PBR(12,003' MD)to surface. L/D BHA. 10. M/U &TIH w/CT BHA#02—Casing Pressure Test Assembly. TIH to 8,952' MD (adjust as needed by logging ®f5 results),set inflatable test tool,&pressure-test 7"casing above test tool to 2,500 psig. TOH & L/D BHA. Of a. If pressure-test fails,continue TOH chasing leak. 11. M/U & TIH w/ CT BHA#03 — Packer Fishing Assembly. TIH to bottom, engage spear in PBR, apply 30 klbs overpull at depth, & set Welltec Well Stroker as per Welltec representative. Cycle Well Stroker (100 klbs downhole pulling tool)to shear-release the existing 7"x 3-Y2" FHL retrievable packer(pinned to shear release at 35 klbs overpull). TOH&L/D BHA and packer fish. a. CONTINGENCY: If unable to pull packer to surface w/CT BHA#03 (tensile yield of smart tools),TOH & L/D CT BHA#03 and P/U,TIH,&retrieve packer w/dedicated CT fishing BHA. b. CONTINGENCY: If unable to shear-release FHL packer w/CT BHA,TOH & L/D CT BHA and P/U&single- in a conventional fishing BHA on 2%8"drill pipe. Overpull/jar packer free,TOH while laying-down drill pipe,fishing BHA,&packer fish. c. CONTINGENCY—If Lower Completion condition and/or returns suggests significant fill/scale downhole, M/U&TIH w/Casing Clean-Out BHA. Clean-out of production casing to PBTD,TOH,& L/D BHA. 12. M/U & TIH w/ new Lower Completion on CT BHA #04 — Completion Runnia .As emhir_...TIH w/ Lowpr_ �"` A Completion,set new production packer as per planned setting depth,TOH w/CT BHA#04&L/D same.4 P ', '- 13. M/U &TIH w/CT BHA#05—Packer Pressure Test Assembly. TIH to 8,982' MD (adjust as needed by logging results), set inflatable test tool, & pressure-test beneath the test tool to 2,500 psig to confirm the integrity of > the new production packer,tubing tail plug, & production casing beneath the known deep production casing I' dleak(8,967' MD). TOH & L/D BHA. a. CONTINGENCY: If pressure-test fails,TOH to P/U new inflatable test tool&TOH to immediately above 0 V the new production packer&test same. TOH to P/U new inflatable test tool &test once more below suspected bad casing(attempt to find base of damaged casing). () PIGL`' / b CONTINGENCY: If damaged production casing interval is discrete&an expandable casing patch <200' a2 _541-4-- cE MD in length can be installed to repair the damaged casing,proceed ahead with the follow contingency ,,} steps to set,.a WFT MetalSkin MCL ex.andable patch across the leak. 1 OP b.�" i. M/U &TIH w/CT BHA—Dual String Mill Assembly. TIH &dress the production casing to the kr._ tyk Ali�)Ci planned setting depth of the WFT MetalSkin MCL expandable patch. TOH & L/D BHA. L�- ii. M/U 5-Y2"x 7"WFT MetalSkin MCL patch&inner string. TIH w/patch on CT BHA—MCL Setting p� Assembly. Set patch across damaged production casing (across deep production casing leak at 8,967' MD)as per WFT representatives. iii. With patch installed, pressure-test the 7" casing to 2,500 psig to confirm casing / patch / tubing/packer&tubing-tail plug integrity. (41°43 iv. TOH w/CT BHA&L/D same. Proceed ahead to Step#19. 6, 14, MJU&T1H w/5%z"$traddle Liner on CT BHA#06—Straddle Liner Setting Assembly. 15. With seal assembly above the PBR,displace the 7"x 5-Y2"annulus to corrosion-inhibited fluid. Page 3 of 4 • • KRU 3M-24 Proposed Rig Workover ConocoPhillips CTD Set-Up—P&R Single Completion & Repair Casing Leak Original PTD#:193-195 Alaska .,7 16. Slack-off to tag the seal assembly on the PBR,fully-locate,&space-out as per completion design. `? 17. Set the 7"x 5%z" liner hanger&liner-top packer as per Baker representatives. 18. Pressure-test the 7"casing/5-%"liner to 2,500 psig to confirm casing,liner-top packer,5-14"liner,3-%z"tubing, , &tubing-tail plug integrity. TOH & L/D BHA. 19. Convert from coiled tubing to stick pipe operations. Slide back injector head, R/D lubricator, R/U flow riser,& R/U tubing handling equipment. 20. M/U&TIH with the new 3-%z" Upper Completion. 21. Slack-off to tag seal assembly on PBR, space-out seal assembly, mark-pipe at surface, & lay-down two joints. Space-out with tubing pups, M/U tubing hanger,&M/U landing joint. 22. Displace well to C.I.seawater/seawater,stab seals, land hanger,&RILDS. 23. Pressure-test tubing to 3,000 psig&IA to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. Bleed all pressure&perform CDDT-TxIA to confirm barriers in the direction of flow. 24. Freeze protect IA down to 2,000'TVD through sheared SOV. 25. Back-out landing joint&install 3"Type'HP' BPV. 26. ND BOPE, NU new 3-%8"vertical tree, make-up the Sealing HP Plug-Off tool to the BPV, &pressure-test tree to 250/5,000 psig. Pull the Sealing HP Plug-Off tool &3"Type`HP' BPV. 27. Transition from RWO to CTD operations on KRU 3M-24(move to previously-approved Sundry#316-423). r Proposed Post-RWO/Pre-CTD Work 1. RU Slickline. a. Set catcher sub above tubing tail plug. b. Swap the sheared SOV for a DV. c. Pull catcher sub&tubing tail plug. d. RDMO Slickline. 2. Transition from RWO to CTD operations on KRU 3M-24(move to previously-approved Sundry#316-423). Page 4 of 4 I McEvoy Gen KRU 3M-24 7-'/is'x 3'/_"EUE Tbg bg Hgr ConocoPhillips Kuparuk A-Sand Producer Current Status—01-Nov-2016 16"62.58#H-40 WLD,121'MD- - Surface Casing Primary Cement a -0--507'MD,3-%"Camco 2.875"DS Nipple 380 bbls 12.0 ppg Arctic Set III 123 bbls 15.8 ppg Arctic Set I OA Shoe Squeeze —3502'MD,Camco 3-1/2"x 1"KBMG,GLV Est TOC 2108'MD PRE-RIG-Swap GLV for DV. 83 bbls 15.7 ppg Arctic Set I 54 bbls 7.3 ppg Arctic Pack 9-%"Landed on Mandrel Hanger 9-%"47#L-80 BTC,3039'MD--►� 9-%"36#J-55 BTC,5310'MD t 3-%"9.3#L-80 EUE-8RD AB-Mod Drilling Mud/Spacer Lead Cement MIKMILAMitZ0a11100:::!:61er -110+3 6635'MD,Camco 3-1/2"x 1"KBMG,GLV Arctic Pack PRE-RIG-Swap GLV for DV. Diesel Seawater Kill-Weight Brine 8950'MD,Camco 3-1/2"x 1"KBMG,OV Casing Leak at 8967'MD(ACX Log) PRE-RIG-Swap OV for DV. • 10983'MD,Camco 3'/a"x 1"KBMG,DV 11952'MD,Camco 3'//"x 1"KBMG,DV PRE-RIG-Pull DV&leave pocket open. ij 12008'MD,Baker 10'PBR&Seals(Sheared) Packer(IA)Leak at 12,029'MD(ACX Log) 12023'MD. " a 65 klbs ShearBaker Release7x(St3raA ight FHL OverpuPll)orcker Rotation 12037'MD,3'/2"Camco 2.75"D Nipple PRE-RIG-Install tubing tail plug. . 12047'MD,3'/2'Baker Shear-Out Sub Kuparuk A-Sand Perforations C-4,2001-12132'-12152'MD A-3&A-2,2001-12162'-12198'MD A-1,1994-12208'-12230'MD A-1,2001-12230'-12244'MD Production Casing Primary Cement TOC-11400'MD(CBL 10-Feb-1994) 53 bbls 15.8 ppg Premium'G'Tail 7"26#L-80 BTC-M,12470'MD I Date: 01-Nov-2016 I Drawn By: Danny Kane ' • McEvoy Gen IV(5M) •KRU 3M-24 7-1/,fi'x3'/2"EUETbgHgr ConocoPhillips Kuparuk A-Sand Producer Proposed RWO 5-%"Straddle Liner 16"62.58#H-40WLD,121'MD_ . - Surface Casing Primary Cement �i b 380 bbls 12.0 ppg Arctic Set III l 123 bbls 15.8 ppg Arctic Set 1 DAV OA Shoe Squeeze s °_ —3500'MD,Camco 3-1/2"x 1"KBMG,DV Est TOC 2108'MD 83 bb/s 15.7 ppg Arctic Set 1 54 bbls 7.3 ppg Arctic Pack 9-%"Landed on Mandrel Hanger 9-%"47#L-80 BTC,3039'MD--111.--i- 9-%" ►i-9%"36#J-55 BTC,5310'MD Drilling Mud/Spacer Lead Cement ' a'i�: i 6600'MD,Camco 3-1/2"x 1"KBMG,DV Arctic Pack Diesel Seawater 3-'A"9.3#L-80 EUE-8RD AB-Mod Above Liner 3-1/2"9.2#L-80 IBTM SC Through&Below Liner Kill-Weight Brine 8750'MD,Camco 31/:"x 1"KBMG,SOV 8900'MD,Baker 7"x5-W'HRD-E ZXPN Packer Setting Depth TBD by On-Rig Logging �-I 8918'MD,Baker 7"x5'/2"HMC Hanger Casing Leak at 8967'MD(ACX Log) r ---I-10000'MD,Camco 3-1/2"x 1"KBMG,DV -----10800'MD,Camco 3-1/2"x 1"KBMG,DV 10900'MD,Baker 20'80-40 SBE 1• I,•• Top SBE TBD by Liner Hanger Depth 10950'MD,3'/2"HES 2.81"XNipple 't ' 11000'MD,Baker 20'80-40 PBR/Seals i Top PBR TBD by Liner Hanger Depth H--}- 11600'MD,Baker 7"x 3 3W FHL Packer '---' 60 klbs Shear Release(Straight Overpull)or Rotation 11958'MD,3'/2"HES 2.81"X Nipple Packer(IA)Leak at 12029'MD(ACX Log)-0.-- - • - w/Plug Pre-Installed&Tested Both Directions 12109'MD,Top 5'/2"Wearsox Tailpipe Kuparuk A-Sand Perforations •' a C-4,2001-12132'-12152'MD f A-3&A-2,2001-12162'-12198'MD f - A-1,1994-12208'-12230'MD A-1,2001-12230'-12244'MD Production Casing Primary Cement TOC-11400'MD(CBL 10-Feb-1994) 53 bbls 15.8 ppg Premium'G'Tail 7"26#L-80 BTC-M,12470'MD ► I Date: 01-Nov-2012 I Drawn By: Danny Kane • McEvoy Gen IV(5M) •KRU 3M-24 7-1/16'x 3-1/2"EUE Tbg Hgr ConocoPhillips Kuparuk A-Sand Producer Proposed RWO Contingency—Expandable Patch [ , 16"62.58#H-40 WLD,121'MD—Iiiii- Surface Casing Primary Cement r- , 1 '' 380 bbls 12.0 ppg Arctic Set Ill ✓ 41, '&i' 123 bbls 15.8 ppg Arctic Set I OA Shoe Squeeze -- —3500'MD,Camco 3-1/2"x 1"KBMG,DV Est TOC 2108'MD 83 bbls 15.7 ppg Arctic Set 1 54 bbls 7.3 ppg Arctic Pack 9-%"Landed on Mandrel Hanger 9-%"47#L-80 BTC,3039'MD—►L 9-%"36#J-55 BTC,5310'MD Drilling Mud/Spacer Lead Cement i k* 4 6600'MD,Camco 3-1/2"x 1"KBMG,DV 410180.;...4 51digiN;448riWi%i Arctic Pack Diesel Seawater Kill-Weight Brine 3-1/2"9.3#L-80 EUE-8RD AB-Mod Above Patch ii 3-1/2"9.2#L-80 IBTM SC Through&Below Patch t 8750'MD,Camco 31/="x 1"KBMG,SOV Casing Leak at 8967'MD(ACX Log)— "] - WFT MetalSkin Casing Patch(5.433"Drift)`/ Straddle Production Casing Leak,<200'MD OAL : —I 11000'MD,Camco 3-1/2"x 1"KBMG,DV ua 4 I 11810'MD,Camco 3-1/2"x 1"KBMG,DV '[ 4 11870'MD,Baker 20'PBR&Seals(Sheared) 11900'MD.B " 3'/:" 60 klbs Shearaker7 Release x(Straight Overpull)FHLPacker or Rotation - Packer Set Depth Determined by On-Rig Logging t-4111958'MD,3-'/2"Camco 2.75"D Nipple backer(IA)Leak at 12029'MD(ACX Log) I• w/Plug Pre-Installed&Tested Both Directions 12109'MD,Top 5'/"Wearsox Tailpipe Kuparuk A-Sand Perforations C-4,2001-12132'-12152'MD A-3&A-2,2001-12162'-12198'MD A-1,1994-12208'-12230'MD ( I A-1,2001-12230'-12244'MD Production Casing Primary Cement / [ TOC-11400'MD(CBL 10-Feb-1994) 53 bbls 15.8 ppg Premium'G'Tail 7"26#L-80 BTC-M,12470'MD � Dale: 01-Nov-2016 I Drawn By: Danny Kane • I 'Schwartz, Guy L (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday, November 08,2016 7:10 PM To: Schwartz,Guy L(DOA) Cc: Bettis, Patricia K(DOA); Herring, Keith E Subject: RE:3M-24 RWO (pre CTD) PTD 193-195 Guy, I wasn't fully aware of the scope of the previous submitted Sundry by the CTD group. After following-up with Keith Herring(CTD drilling engineer for 3M-24), I've answered your questions below: L 1) Are you still planning on cement squeezing the A and C perfs after the RWU (the new tubing tail has the 5'A" Wearsox)—No. The Wearsox tailpipe will be installed in lieu of the cemented pilot hole exit;doing so allows us to retain the mother bore perforations(having to go to RWO opened up this option). 2) If sundry 316-423 has substantial changes due to the RWO please outline the differences. As I understand, Keith Herring has requested that this Sundry(316-423Iancelled. I was not aware of this when I was putting together the RWO Sundry application. t be c�ti`j a c 0 i - t Cr- I have CC ed Keith to confirm that I have answered your questions accurately. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday, November 08,2016 2:56 PM To: Kane, Danny<Danny.Kane@conocophillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNALj3M-24 RWO(pre CTD) PTD 193-195 Daniel, I am reviewing the sundry to do a pre-CTD RWO on 3M-24 and have a couple of questions: 1) Are you still planning on cement squeezing the A and C perfs after the RWO.. (the new tubing tail has the 51A" Wearsox) 2) If sundry 316-423 has substantial changes due to the RWO please outline the differences. Regards, 1 • Guy Schwartz • 'Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 �'OF Tit' �\\I//7:• •, THE STATE Alaska Oil and Gas 71, ofALAsKA, Conservation Cornrnissi®n fifth333 West Seventh Avenue .".1513"1-1-16*- GOVERNOR BILL WALKER � chorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke SCANNED ,JA?\ 4 7[1; CTD Coordinator ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-24 Permit to Drill Number: 193-195 Sundry Number: 316-423 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, &Zee Cathy . Foerster Chair DATED this / ay of August, 2016. RBDMS L c- A66 L 5 2016 ERI hp • STATE OF ALASKA • C 1 . 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION AUGa APPLICATION FOR SUNDRY APPROVALS0-1-5 gii9 1/� AOGCO 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑✓ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill Q'• Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc • Exploratory ❑ Development ❑✓ • 193-195 . 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510 50-029--22432-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? �rf KRU 3M-24 • Will planned perforations require a spacing exception? Yes ❑ No Ig 9.Property Designation(Lease Number): f( 10.Field/Pool(s): ADL 25524 ` a�5 a3 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12490'MD - 6361'TVD + 12382'MD • 6286'TVD ' 3722 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 121' 16" 121'MD 121'TVD 1640 psi 630 psi Surface 5310' 9-5/8" 5310'MD 3285'TVD 3520 psi 2020 psi Intermediate Production 12470' 7" 12470'MD 6347'TVD 4980 psi 4330 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12132'-12244'MD • 6110'-6189'TVD 3-1/2" L-80 12009'MD Packers and SSSV Type: No SSSV Packers and SSSV MD(ft)and TVD(ft): SSSV:None Baker FHL Retrievable Packer Packer:12023'MD&6033'TVD 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development D , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1-Oct-16 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned I 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email jason.burke@a,cop.com Printed Name Jason Burke Title CTD Coordinator Signature Phone 265-6097 Date l A 4 :2f9 0��" //Y' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: •kLt- Lf22 Plug Integrity ❑ BOP Test I Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOP t-eit prc55 L., �z r.5 4 00 0 p 5 t 4,-hrula✓ preKeeritr /-e5-1- pCc5SUY lS ZS0(-75► /terfic p1v plci< v^t.4")" app rlb r 2 mved per- z m . 5. 112 < / �.,� Post Initial Injection MIT Req'd? Yes [C kir C►' No1...\ C- g1,9I Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /0 —4 07 RBDMS LA-AUG 2 5 2016 i)sie,c,aa.......v APPROVED BY Approved by: .,,./ COMMISSIONER THE COMMISSION Date: 41�/� TZ- /JW 6 A Submit Form and Form 10-403 Revised 11/2015 R10® t t. iIlid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AUG 1 1 2O1 OG August 11, 2016 Commissioner- State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications to abandon the KRU 3M-24 by cementing up the perforation in order to set up to for CTD operations to drill a quad-lateral out of the KRU 3M-24 using the coiled tubing drilling rig, Nabors CDR2-AC. A sundry application is attached to plug the KRU 3M-24 (193-195) perfs to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A/C-sand perfs in 3M-24. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 3M-24 (193-195) — Operations Summary in support of the 10-403 sundry application — Proposed CTD Schematic — Current Well Bore Schematic If you have any questions or require additional information, please contact me at 907-265-6097. Sincerely, Jason Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 3M-24 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 3M-24 is a Kuparuk NC-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize four laterals to target the Al and A2 sands to the east and west of the 3M-24. The laterals will add new resources and improve existing recovery. Prior to CTD operations the nipple at 12037' RKB will be milled out and the existing NC-sand perforations will be squeezed with cement, the 3-1/2" tubing tail will be punched and cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 12210' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 12173' MD. All the laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3- 1/2" tubing tail. Using the maximum formation pressure in the area of 4337 psi in 3M-12, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3722 psi. The BOPE will be tested to 4000 psi. CTD Drill and Complete 3M-24 Laterals: October 2016 Pre-CTD Work 1. RU Slickline: Dummy off gas lift mandrels; obtain a SBHP 2. RU E-line: Punch tubing at 12035' MD. 3. RU Pumping: Swap hole over to diesel and perform injectivity test 4. RU Service Coil: Mill out nipple set at 12037' MD, and lay in cement plug and squeeze off the NC-sand perforations. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3M-24A Sidetrack (Al sand - East) a. Drill 2.80" high-side pilot hole through cement to 12210' MD b. Caliper pilot hole c. Set top of whip-stock at 12173' MD d. Mill 2.80" window at 12173' MD. e. Drill 3" bi-center lateral to TD of 15450' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 14100' MD. 3. 3M-24AL1 Lateral (A2 sand - East) a. Kick off of the aluminum billet at 14100' MD. b. Drill 3" bi-center lateral to TD of 15450' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 12850' MD. L `A �/o�ofrd �att�a� w/// df (0/�1,/Cre' Ui'`j� 57 t t /1114e/ Y -k ►�nFo clirI , ,,acs ar r4,s focUr,tYt weU4on ah°' rdwc CQ/ ' or Co„>inw�Y fee it re f�� Page 1 of 2 'ii 'irr /)0 fe'V( lr'.vi tw �s v ig4514 8/11/2016 • 4. 3M-24ALLateral (A2 sand - East) • a. Kick off of the aluminum billet at 12850' MD. b. Drill 3" bi-center lateral to TD of 14000' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 12270' MD. 5. 3M-24AL3 Lateral (Al sand - West) a. Kick off of the aluminum billet at 12270' MD. b. Drill 3" bi-center lateral to TD of 14300' MD. c. Run 2%" slotted liner with a deployment sleeve from TD up to 12030' MD. 6. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 8/11/2016 • • • 3M-24 Proposed Pre-CTD Schematic 3-1/2"9.3#J-55 EUE 8rd Tubing to surface Camco Landing Nipple @ 507' 16"62#H-40 — — shoe @ 121' 3-1/2"Camco MMG gas lift mandrel @ 3502',6635'8950', MD 10983'&11952' 9-5/8"47#L-80 shoe @ 5310'MD —.01111111 3-1/2"tubing tail @ 12009'MD Baker 3-1/2"PBR @ 12008'MD(4.00"ID) Baker FHL packer @ 12023'MD(3.0"ID) Tubing Punched3-1/2"Camco D landing nipple @ 12037'MD(2.75"min ID,No- 12034'-12036'MD Go) lig C-sand perfs w.. 12132'-12152'MD Squeezed A-sand perfs 12162'-12224'MD Squeezed 7"26#L-80 shoe @ 12470'MD e e, KUP PROD • 3M-24 ConocoPhillips ti Well Attributes Max Angle&MD TD Alaska tic Wellbore API/MI Field Name Wellbore Statusncl0) MD(ftKB) Act Btm(ftKB) co.woFryMpc 500292243200 KUPARUK RIVER UNIT PROD 1 70.03 9,189.96 12,489.0 • ' ., x, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-24,7/27/20165:1434 PM SSSV:NIPPLE 200 12/11/2015 Last WO: 1/3/2008 41.00 1/26/1994 • Vertcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,220.0 7/25/2016 Rev Reason:H2S&TAG pproven 7/25/2016 Casing Strings HANGER 30.2 O Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED Casing Description'''''''''''''''''''''''""""""'"i i - -7 ,, , i OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 41.0 5,310.4 3,285.6 47.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.5 12,470.2 6,347.4 26.00 L-80 BTC-MOD Tubing Strings Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Description ! 31/21 2.9921 30.31 12,009.11 6,023 .11 9.301 L- 80 1EUE8rdABMOD ^^^d,; ,^Completion Details CONDUCTOR 42.0-121.0 Top(ftKB) Top(ND)(ftKB) Tap Incl(°) Item Des Com No minaI ID • 30.3 30.2 0.34 HANGER MCEVOY GEN IV HANGER 3.500 NIPPLE;507.4 . 507.4 507.3 1.47 NIPPLE CAMCO DS LANDING NIPPLE SET 1/2/2008 2.875 12,007.3F 6,021.8 45.16 SEAL ASSY BAKER LOCATOR OD 4.18/SEAL ASSEMBLY- 3.000 INSERTED IN ORIGINAL PBR-SET 1/2/2008 WORKOVER Tubing Description ..ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING Original 1String Ma.51 4.0001 12,008.5 12,048.021 6,050.5] 1 1 GAB LIFT,3,502.1CT Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 12,008.5 6,022.7 45.16 PBR BAKER PBR W/10'STROKE 4.000 12,023.2 6,033.0 45.11 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 € 12,037.5 6,043.1 45.07 NIPPLE CAMCO D NIPPLE NO GO 2.750 12,047.1 6,049.9 45.05 SOS BAKER SHEAR OUT SUB 3.500 SURFACE;41.0-5,310.4-+ A Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT:6,635.2 ' 12,132.0 12,152.0 6,109.8 6,124.0 C-4,3M-24 8/30/2001 6.0 APERF Enetjet/Powerjet,0 deg ph,+/-90 orient 12,162.0 12,198.0 6,131.0 6,156.4 A-3,A-2,3M- 8/30/2001 6.0 APERF Enerjet/Powerjet,0 deg 24 ph,+/-90 orient 12,208.0 12,230.0 6,163.4 6,178.9 A-1,3M-24 6/30/1994 4.0 IPERF 180 deg.phasing;21/2" Titan GAS LIFT;8,950.3 C_ 12,230.0 12,244.0 6,178.9 6,188.8 A-1,3M-24 8/28/2001 6.0 APERF 'Eneget/Powerjet,0 deg ph,+/-90 orient Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Corn GAS UFT;10s83.7 1 3,502.1 2,592.7 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.156 1,307.0 1/5/2008 2 6,635.2 3,790.8 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,343.0 1/5/2008 3 8,950.3 4,670.8 CAMCO KBMG 1 GAS LIFT OV BK-5 0.250 0.0 1/5/2008 4 10,983.7' 5,422.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2008 5 11,952.8 5,983.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 1/2/2008 GAS LIFT;11,952.8 Notes:General&Safety End Date Annotation 7/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY;12,007.3 a PBR;12,008.5 -- PACKER;12,023.2 NIPPLE;12,037.5 SOS;12,047.1 t'-.. _. APERF;12,132.0-12,152.0- APERF:12,162.0-12,196.0 IPERF;12,200.0-12,230.0---. r APERF;12,230.0-12,244.0--- PRODUCTION;29.5-12.470.2- - + • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the"Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist / work)the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July,the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. SI • 4110 Cfai -c .7• _ v a) S6 !.' '42 N a) j U co awow 0 0_ Q L COO❑ -Q a) a) O CO cy Z . a) C L C St)41 LU O C N H ? co Oa) OHY Y_ o- - u co NO 0 -O ro pQ 1 (., m co (o O (o co O s O v F m 2 W Q Q Q Q Q Q E , v, n, aN0 W 0 M N N O_ E m >Z Q) Q 0 Z Q '' O -0 E O ? F 0 C r9 , ❑ ❑ ❑ ❑ ❑ ❑ ❑ ' N u t cr W J J J J J J J = O O O. 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N N N N N N N N IN 0) 01 0) M O) O O E L L 0 N N N 0 N N N O 0 O � O O O CO d O O O O O O O i 00 O U) in U) U) L0 l() IS) V 0 O ens 00 C 4, o. 'CO O d1 pC .-1 •� •O QJUO 2 cri E u en O) r. C '71 . E- co LU X g W _ E E Q rl Q l0 Q 'R Q 00 V V f6 a) C Y Y d i z O r 0 N N F' E cu 0) 0) N. M d Q . O O Vu w iAP h ,c a EE 8 !/A c I R F a s O XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. IC:t~3'' I~"~ 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 ~ianna"~incent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by:~Dianna vincent Nathan Lowell V G® ~ ~ RECD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 2 2008 REPORT OF SUNDRY WELL OPERATI~~ R r~ c~L cnmm~~air~n t. operations Pertormed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ OtherA Alter Casing ^ Pull Tubing Q 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 ^ 193-195 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 ~' 50-029-22432 00 7. KB Elevation (ft): 9. Well Name and LVumber: RKB 68' ~ 3M-24 ' 8. Property Designation: 10. Field/Pool(s): ADL 25524, ALK 2655 ~~ Op~,~$'„2,~+ \Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12490' ~ feet true vertical 6361'- feet Plugs (measured) 12038' Effective Depth measured 12262' feet Junk (measured) true vertical 6201' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 5269' 9-5/8" 5310' 3285' PROD. CASING 12402' 7" 12470' 6347' Perforation depth: Measured depth: 12132'-12152', 12162'-12198', 12208'-12244' .,, ~g~E~ ~~~ ~ ~ ~~jo~ ~~ true vertical depth: 6110'-6124', 6131'-6156', 6163'-6189' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12009' MD. Packers 8 SSSV (type & measured depth) pkr= BAKER'FHL' pkr= 12024' Camco'DS' nipple @ 507' 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 19 127 1087 -- 143 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 N/A if C.O. Exempt: none Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer Signature Phone ~~~,~Z~ Date ~j~`~ f Pr ared b haron Allsu Drake 263-4612 Form 10-404 Revised 04/2006 Submit Original Only _ ~ • ~' Ate. GQ~1r~~caPh~llip~ e4la~ka, Univ. 3M-24 _ T API: 500292243200 Well1 :PROD TUBING -I{ SSSV Type: NIPPLE Orig 1/26/1994 ~o-lzoos, ! Com letion: OD:3.500, ID:zss2) ~~ Annular Fluid: Last W/O: 1/3/2008 Reference L : Ref L Date: Last Ta 12240' SLM TD: 12490 ftK6 LastTa_q Date: 1/10/2008 Max Hole Angle: 70 deg (a) 9190 s' ' ~ ~ Casino 5trina -ALL STRINGS seAL ;12007-12009, OD:4.000) PBR ;12009-12010, OD:3.500) TAIL PUPS ;12009-12050, OD:3.500) PROD. CASING falza7o, oD:7.oo0, wt:zs.oo) NIP 12038-12039, OD:3.500) SOS ;1204&12049, OD:3.500) TTL ;12049-12050, OD:3.500) Pert :12132-12152) - Pert _ :1 216 2-1 2198) KRU 3M-24 An le TS: 45 de 12125 Angle ~a TD: 46 deg aQ 12490 Rev Reason: GLV C/O, PULL CATCHER PLUG Last Update: 1 /27/2008 Descrl Ion Slze To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 SUR. CASING 9.625 0 3039 2418 47.00 L-80 PROD. CASING 7.000 0 12470 6347 26.00 L-80 SUR. CASING Tubing String -TUBING I Slze I Top 9.625 3039 Bottom 5310 _ TVD Y1It 3285 Grade 36.00 J-55 Thread I .3.500 ~ 0 12009 6023 9.30 L-80 MODEUE8rd ~ Perforations Summary Interval TVD Zone Status Ft ' SPF Date T e Comment 12132 - 12152 6110 - 6124 C-4 20 6 8/30/2001 APERF Enerjet/Powerjet, 0 deg Ph, +/- 90 orient 12162 - 12198 6131 - 6156 A-3,A-2 36 6 8/30/2001 APERF Enerjet/Powerjet, 0 deg ph, +/- 90 orient 12208 - 12230 6163 - 6179 A-1 22 4 6/30/1994 IPERF 180 deg. phasing; 2 1/2" Titan 12230 - 12244 6179 - 6189 A-1 14 6 8/28/2001 APERF EnerjeUPowerjet, 0 deg ph, +/- 90 orient Gas Lift MandrelsJVaives St MD TVD Man Mfr Man Type V Mfr v Type V OD Latch Port TRO 'Date Run Vlv Cmnt 1 3502 2593 CAMCO KBMG GLV 1.0 BK-5 0.156 1307 1/5/2008 2 6635 3791 CAMCO KBMG GLV 1.0 BK-5 0.188 1343 1/5/2008 3 8950 4671 CAMCO KBMG OV 1.0 BK-5 0.250 0 1/5/2008 4 10984 5423 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/2/2008 5 11953 5984 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/2/2008 Other lu s equip., etc.) -COMPLETION De h TVD T Descrl tlon ID 507 507 NIP CAMCO 'DS' LANDING NIPPLE set 1 /2/2008 2.875 12007 6022 SEAL BAKER LOCATOR OD 4.18/S EAL ASSEMBLY -INSERTED IN ORIGINAL 3.000 PBR -set 1/2/2008 12009 6023 PBR Baker w/ 10'stroke 3.000 12038 6043 NIP Camco'D' Ni le NO GO 2.750 12048 6051 SOS Baker 2.992 12049 6051 TTL 2.992 Pert - :12208-12230) _ Perf :12230-12244) - • Time Logs Date ,From To__ __ Dur S. Depth E. De th Phase Code Su_bcode T _ COM T~-- - - _- 12/30/2007 18:30 20:00 1.50 0 0 COMPZ WELCT OWFF P #0 psi on tbg. 20 psi on fA. Pump 9.6# brine with 0.6% Safelube down tbg. @ 4 bpm w/ 280 psi on tbg. & 100 psi on choke. 20:00 20:30 0.50 0 0 COMPZ WELC OTHR P Blow down hard lines & kill manifold. 20:30 21:00 0.50 0 0 COMPZ WELCT OTHR P Set BPV. 21:00 22:30 1.50 0 0 COMPZ WELCT NUND P Nipple down tree. 22:30 00:00 1.50 0 0 COMPZ WELCT NUND P Nipple up bope. 12/31/2007 00:00 03:30 3.50 0 0 MIRU WELC NUND P Continue nipple up BOPE. 03:30 04:30 1.00 0 0 MIRU WELCT NUND P Fill Stack, rig up lines & change'0' rin on koome hose. 04:30 09:30 5.00 0 0 MIRU WELCT BOPE P Test BOPE 250-3500 psi. Mud saver valve & HCR valve Failed. BOP test witnessed by Lou Grimaldi - AOGCC Field Ins ector. 09:30 14:00 4.50 0 0 MIRU WELC EORP T Change out Mud saver valve &HCR valve. 14:00 14:30 0.50 0 0 MIRU WELCT BOPE P Test MSV &HCR valve 250-3500 psi OK. BOP test witnessed by Lou Grimaldi -AOGCC Field Ins ector. 14:30 15:30 1.00 0 0 COMPZ WELCT OTHR P Rig down & blow down atl testing equipment. Lay down test jt. & test lu . 15:30 16:30 1.00 0 0 COMPZ RIGMN SVRG P Slip & cut drlg. line. 16:30 17:00 0.50 0 0 COMPZ RPCO OTHR P Pull BPV. 17:00 18:30 1.50 0 0 COMPZ RPCOh RURD P Rig up landing jt. PJSM-unseat hanger & work seal assembly loose w/ 165k u. 18:30 22:30 4.00 0 0 COMPZ RPCOh CIRC P Circ. well clean both ways. Had to pump open SSSV. Circ. @ 4.5 bpm 700 si. 22:30 00:00 1.50 0 0 COMPZ RPCO PULD P PJSM-POH laying down 3.5" com letion. 01/01/2008 00:00 09:30 9.50 0 0 COMPZ RPCOh PULD P Cont POOH w/ LD tbg string & completion equipment f/ 11014' - 4795'. 09:30 13:00 3.50 0 0 COMPZ RPCOh OTHR P Strap pulled tbg & install thread protectors. Rack and tally new 3 1/2" tbg for additional thread protectors to et old tubin out of i e-shed. 13:00 19:00 6.00 0 0 COMPZ RPCOh PULD P Cont POOH w/ LD tbg string & completion equipment f/ 4795' - surface. Last 70 ft of tbg had extensive corrosion ID'd by scaling and pitting w/ 3/4" hole in tbg noted in 't 373 26' above no- o. 19:00 21:00 2.00 0 0 COMPZ RPCO RURD P Clean !clear floor. Finish strap and removal of old pipe from rig. Finish loading new tbg & completion e ui ment, & stra of same. Pay ~ of • ~~ Time Logs _ __ __ _ Date From To Dur S __De tp h E. Depth Phase Code_ Subcode T COM 01/01!2008 21:00 00:00 3.00 0 0 COMPZ RPCO PULD P MU new seal assy, start running in hole w/ new 3 1/2" 9.3# L-80 8rd EUE Mod tbg w/picking up mandrels as s ecified. 01/02/2008 00:00 08:00 8.00 0 COMPZ RPCOh RCST P PU and RIH t/ 11971' w/ new 3 1/2" 9.3# L-80 8rd EUE Mod tbg string & 'ewe! 08:00 10:00 2.00 COMPZ RPCOti HOSO P Locate SBE & space out. PU 100 klbs, SO 70 klbs. 10:00 11:30 1.50 COMPZ RPCOh CIRC T Circ brine @ 2 bpm w/wait on Corr Inhib fluid. Road is blocked by moving ri . 11:30 12:30 1.00 COMPZ RPCOh CIRC P Pump Corr Inhib @ 4 bpm / 500 psi. 12:30 13:00 0.50 COMPZ RPCOh HOSO P Land hanger, RILDS, TBG landed @ 12009' MD. PU 100k1bs, SO 70 klbs, Blk wt 35klbs. 13:00 16:00 3.00 COMPZ RPCO DHEQ P PJSM, RU and P-test tbg U 2500 psi, , Test IA t/ 2500 psi w/ holding tbg ressure, record on chart. Test good. Bleed tb and shear SOV in GLM. 16:00 17:30 1.50 COMPZ RPCO RURD P RD hose and test equipment. LD landing jt, set two-way check. Drain BOP and Blow down choke and kill lines. 17:30 21:00 3.50 COMPZ WELCT NUND P ND BOP, Install adapter spool and tree. 21:00 23:00 2.00 COMPZ RPCO DHEQ P Open surface safety valve, Ptest tbg hanger pack-off t 250/5000 psi, OK. RU, test tree t 250/ 5000 psi on chart, O K. 23:00 00:00 1.00 COMPZ RPCOh RURD P RD test equipment. Pull two way check, RU Hot Oil f/freeze protect rocedure. 01/03/2008 00:00 01:00 1.00 COMPZ RPCOh RURD P RU Hot Oil f/freeze protect procedure. PJSM. 01:00 03:00 2.00 COMPZ RPCOh FRZP P Freeze protect well by pumping 85 bbls diesel down IA. Open valves and let well U-tube to balance out diesel in IA & Tb . 03:00 06:00 3.00 COMPZ RPCOh NUND P Set BPV. Finish draining pits and transfer fluid t/ on-site storage. Rig released this date 03-Jan-08 @ 0600 hrs. Page 3 esf 3 ~ i 3M-24 Well Events Summary DATE Summary 1/5/08 PULLED SOV & REPLACED W/ 1/4" OV @ 8950' RKB. PULLED DV's @ 6635' & 3502' RKB. SET GLV's @ 6635' & 3502' RKB. IN PROGRESS 1/6/08 BAIL DRILLING MUD f/ TOP OF CATCHER SUB @ 12,038' RKB. IN PROGRESS 1/7/08 PULL CATCHER SUB @ 12,038' RKB. BAIL DRILLING MUD f/ TOP OF CA-2 PLUG @ 12,038' RKB. LAY DN FOR NIGHT DUE TO COLD WEATHER. IN PROGRESS 1/10/08 PULLED 2.75" CA-2 PLUG @ 12038' RKB. TAGGED @ 12240' SLM. COMPLETE. • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • October 28, 2007 ocr ~ o zaa~ Alaska llii ~ Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~~~~ NCV ~. ~ 20G7 Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we113M-24 (PTD 1931950). The report records thC'C~mpletion of pulling the tubing patch and running a PDS caliper survey. The condition of the tubing is such that the well will require a Rig Workover to repair and no further non-Rig work is planned. Please call MJ Loveland at 659-7043, Brent Rogers or Perry Klein at 659-7224 if you have any questions. Sincerely, ~~~ Brent Rogers Problem Wells Supervisor ~~~ Attachments ~E1~IED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ (, r ~ ~ 2~~7 REPORT OF SUNDRY WELL OPERATIONS 1.0 erations Performed: Abandon p ^ Repair Well ^ Plug Perforations ^ ~ S Stimulate ^ Other chorage Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development_^ Exploratory ^ 193-195 f 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360 50-029-22432-00 7. KB Elevation (ft): 9. Weil Name and Number: RKB 68' 3M-24 8. Property Designation: 10. Field/Pool(s): ADL 25524 ~ ALK 2655 Kuparuk River Field /Kuparuk Oil Pool ° 11. Present Well Condition Summary: Total Depth measured 12490' ~ feet true vertical 6361' ' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical 6276' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 2971' 9-5/8" 3039' 2418' SUR. CASING 2271' 9-5/8" 5310' 3285' PROD. CASING 12402' 7" 12470' 6347' Perforation depth: Measured depth: 12132-12152, 12162-12198, 12208-12230, 1223 0-12244 true vertical depth: 6110-6124, 6131-6156, 6163-6179, 6179-6189 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12049' MD. Packers &SSSV (type & measured depth) pkr= BAKER'FHL' pkr= 12024' SSSV=Cameo TRDP-4E SSSV= 1949' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A _ ~~~ ~0~~ Q 200 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 N/A N/A N/A N/A N/A Subsequent to operation N!A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed 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 NiA if C.O. Exempt: N/A contact Brent Rogers/ferry Klein Printed Name Brent Rogers Title Problem Wells Supervisor Sign ure Phone 907-659-7224 Date 10/28/2007 s, r t`~~°L'? ~r~ /0-3!.07 t/ `\ ~ 1 Form 10-404 Revised 0412004 p R I G f N A L I _ ` SiOa BJ~~ 1 ~ ~ • 3M-24 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary PULLED UPPER ECLIPSE PKR, SPACER & SNAP LATCH ASS'Y. SNAP LATCH NOT FULLY ENGAGED IN BOTTOM PKR. SET TEST TOOL IN LOWER PKR & CONFIRMED SNAP LATCH FUNCTION /ENGAGEMENT. COMBO MIT NOT POSSIBLE WITH OV @ 10066' RKB. PULLED LOWER PKR. IN PROGRESS. GAUGED TBG TO 2.74". TAGGED @ 12264' RKB, EST. 20' RATHOLE. PULLED OV @ 10066' RKB & REPLACED WITH DV. LOGGED PDS CALIPER SURVEY FROM 12100' TO SURFACE. IN PROGRESS. Summary Pulled tubin atch. Condition of tubin is non re airable and will re uire a RWO. 3M-24 (193-195} Failed TI~ ~ Page 1 0€1 Maunder, Thomas E (QOA) From: NSK Probkem Well Supv [n1617@conocophi0ips.com] Sent: Monday,. September 04, 2006 5:41 AM To: Tam Maunder; James Regg Cc: NSK Problem Weil Supv Subject: 3M-24 (193-195) Faiked TkFL Tom, 3M-24 (193-195) failed a TILF yesterday 913!06. Fluid level shots indicate the tubing patch may have failed. Initial T/!10 pressures were 300/1300/50. The plan forward is to troubkeshoot the TxIA communication with stick line detection methods. If needed, the patch wilt be pulled and reset. Let me know if you have any questions. MJ Loveland ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cek (907} 448-3114 ~ ~,~E 11/1/2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: A03CC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 9951 B Fax: (907) 245-8952 1 Report / EDE 3M - 24 Caliper Report 25-May-07 1) 2) 3) 4) 5) 6) 7) sCANNED JUN 0 6 2007 ¡C?3 -Ie¿ 5- +i: 1:5-/'9<:/ RECEIVED Print Name: ~ C ~l1 d3M I.{ f' JUN 0 1 Z007 Signed: ó\1..a.k Hk.p L.-1 Date : Alaska 011 & Gas COliS. Gornml5sion Anchorage PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _COPY- 00 ]DSANC-2OxxIZ _ WOIdlDisbibution\Transmittal_ Sheets\Transmit _ Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company; Log Date; Log No. ; Run No.; Pipe1 Desc.: Pipe1 Use; ConocoPhillips Alaska, Inc. May 25, 2007 8105 3 3.5" 9.3 lb. L-80 Tubing Well: 3M-24 Field: Kuparuk state: Alaska API No.; 50-029-22432-00 Top Log IntvI1.: Surface Bot. Log Intvl1.: 12,049 Ft. (MD) Inspection Type : COMMENTS: Corrosive & Mechanical Damage Inspection This log is tied into 3.5" Tubing Tail@ 12,049' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the 3.5" tubing is in good to poor condition, with 2 recorded holes, in joint 195 @ 6,228' and joint 373 @ 11,987" respectively. Wall penetrations in excess of 20% are recorded in 42 of the 391 joints logged. The damage appears in the form General Corrosion, Line of Corrosion, and Isolated Pitting. No significant areas of cross-sectional wall loss or LD restrictions are recorded throughout the 3.5" tubing logged. This is the third PDS log of this well. This is the first PDS log of the entire 3.5" tubing in this well. A comparison between this log and the previous log (June 2003) shows no increase in corrosive damage over the interval 4,900' to 5,900', and indicates a slight decrease in corrosive damage over the interval 5,900' - 7,800'. Critical analysis ofthe data in this lower interval points to isolated deeper penetrations falling between the caliper fingers on the most recent run as the cause for the apparent slight decrease in recorded damage. Assessment ofthe data from all three consecutive caliper logs (1999, 2003 & 2007) strongly support very little or no increase in internal corrosive damage to this tubing over the eight year period. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. 3.5" Tubing - MAXIMUM RECORDED WALL PENETRATIONS: HOLE (100%) Jt. 195 HOLE (100%) Jt. 373 Corrosion ( 67%) Jt 193 Line Corrosion ( 65%) Jt. 198 Corrosion ( 58%) Jt. 196 @ @ @ @ @ 6,228 Ft. (MD) 11,987 Ft. (MD) 6,166 Ft. (MD) 6,324 Ft. (MD) 6,260 Ft. (MD) 3.5" Tubing - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall less (> 13%) are recorded throughout the 3.5" tubing. 3.5" Tubing - MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the 3.5" tubing. I Field Engineer: R. Richey Analyst: B. Qi & J. Thompson Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. I P.O. Box 1369{ Stafford{ TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 -~ 10,3 -/'i 5 15(~'-I I I I I Well: Field: Company; Country; I I I I I I I I I I I I I I I 3M-24 Kuparuk ConocoPhííllips Alaska, Inc. USA Overlay Max. !tee. Pen. (mils) o 100 200 154 164 174 224 234 241 Maximum Recorded Penetration Comparison To Previous Survey Date: Prevo Date: Tool; Tubing; -100 -25 May 25, 2007 June 1, 2003 UW MFC 24 No. 211387 3.5" 9.3 Ib L-80 Difference Oiff. in Max. Pen. (mils) ·50 o 50 184 .. .. 194 J <II ¡¡¡ ,¡: :::I § Z ... Z I: 1È 204 ]. ]. 214 -13 0 Appro", Col'l'OSÎon Rate (mpy) 13 I I I I I I I I I I I I I I I I Bottom of I I to 3.5 in Well: Field: 3M-24 Kuparuk Inc. Country: Date: USA 25,2007 Too! Deviation 50 100 150 Profile Borehole Profile GLM 1 25 1580 3188 4798 ... v 200 6387 æ: ..a E ::::¡ .= Z ...., GlM2 c 12, 250 7998 300 Gl.M3 Gl.M4 350 GLM5 GLM6 373.7 0 '" 373.7 50 / Tool Deviation 9584 11209 12049 100 I I I We!!: Field: 3M-24 IOL I USA I Grade & Thread L-80 Nom.OD 3.5 ins Weight 9.3 f I Penetration and Metal loss wall) penetration body metal loss body I 400 300 200 100 0 o to 1% 10 to 20 to 40 to over 20% 40% 85% 85% I 1 to 10% I 2 o I I ( body) 80 I 60 40 I 20 I o isolated general line ring hole I poss pitting corrosion corrosion corrosion ¡ble hole I 2 I I May 25,2007 UW MFC 24 No. 211387 1.69 24 B. NomJD 2.992 ins Nom. Upset 3.5 ins len. 6.0 ins Profile (% wall) penetration body o o metal loss 50 Bottom GLM 1 GLM2 GLM3 GLM4 Analysis Overview page 2 I I Lower len. 6.0 ins 100 I I I I I I I I I I I I I I I I I I I REPORT JOINT LATION SH Wall; Upset Wall: Nominal !.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: 3M-24 Alaska, tne. Date: USA May 25, 2007 Joint jt. Depth Pell f~ Pen. Me!al Min. P Tofile No. ID. Comments wall) (Ins) (Ins.) 0 50 100 .1 20 0.52 . 1 25 () ~I 2.96 Shallow corrosion, 2 58 o 2.96 3 90 1.95 4 122 , ~ 5 154 i 0.02 7 6 185 i 0.02 () , 7 217 fig 2.95 8 249 o 12.% 9 281 o 2.97 10 ±=m= ' 2.97 11 i 0.02 2.96 12 I 002 7 2.96 13 409 ( 0.02 r 2.96 14 440 I 0.02 ~ 15 472 ( 0.02 ±Jti:=i 16 504 C 0.Q2 2.97 17 '136 ( 0.02 () 2.97 18 568 i ~ B ( I 19 598 i () 20 629 ( 0.02 21 662 I =! 4 22 693 I 23 724 ( 24 7"') 0.02 2,c1) 25 787 0.02 2.96 26 819 0.01 ( 2.95 27 850 0.Q2 5 2.97 28 882 0.01 2.97 29 914 0.03 J 2.94 30 945 0.02 2.95 31 976 0 0.02 2.95 32 1008 I 0.03 ~ 33 1040 I !: 34 1071 ( Shallow oittioo. 35 n04 I 4 2.96 36 1135 ( 0.02 2.97 37 1166 0 0.03 till 38 1198 0 39 1230 0 2.96 40 12h1 2.% 41 1292 1 2.96 42 1324 P 2.97 43 1356 t 4 2.95 44 1388 0 0 13 I ø, Shallow IJÌtUIlI:/:. 45 1421 ¡ I .95 46 1452 I .94 47 1484 I 48 1516 ( 113 ( Shallow corrosion. 49 1548 ( 0.03 113 I 2.96 Shallow corrosion. Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I JOINT 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: 3M-24 Alaska, inc. USA 25, 2007 Joint Jt. Depth Pen Pen. Pen~ ¡\/le!al Min. -0' Profile No. Upset Loss I.D. Comments (Ins) (Ins.) (Ins.) 0 50 100 50 15M ()~. .51 1611 0 52 164 1i 0.02 2.95 53 1£;: +f 17 ~~ 17' 17: 57 1803 i 58 1835 ( 59 1866 (iõ2 60 1897 0.02 PiHina. 60.1 1929 PIIP 60.2 1935 0 ! ! 603 194'i C ± 1981 0.02 2013 0.02 t" 64 7045 íI 03 n 6" 7076 0.02 Ii 2. 66 2108 0 0.03 4 2.95 67 2140 0 0.02 "; 2.96 68 2172 n 0.03 Ii 2.97 69 2204 n 004 j 2.95 ¡ Shallow corrosion. 70 2236 0 0.02 ¿j 2.95 71 ),)F.7 I m 72 2299 q 73 2331 Shallow corrosion 74 2364 ( 75 2396 0 0.03 1;':>.96 76 2428 OJ)£¡ PittinlZ. 77 2460 0 .04 Shallow corrosion. 78 2491 .02 3 79 )5)] 0 80 1554 0 0 81 2'iH6 0 Sh"lIow corrosion. 82 2618 0 2.95 à1 2650 0 295 84 2681= I 0.03 Ff:= 2.96 85 2713 ~ -tm 86 2745 ~1 87 ')777 2.95 88 2808 ~ I 2.95 89 2 ALl{) 0.02 ¡ 2.93 90 2872 0.02 I 2.95 91 2904 ) . 2.'15 Shallow corrosion. 92 2935 0 0.03 11Jm 93 2967 0 0.03 I 2.95 Shallow rnrrosio!1. 94 2999 0 95 lO3D n I 2.95 96 3061 n ( I 2.96 Shallow corrosion. 2 I I I I I I I I I I I I I I I I I I I 3.5 În 9.3 0.254 in 0.254 in 2.992 in L-BO WeH: Field: 3M-24 Inc. USA May 25, 2007 Joint Jt Depth Pen. PerL ¡Mel;c!! Min. P rofile 1~7" '" No. W. Comments \ YO IN""} (Ins.) (Ins.) ( ) 0 50 100 97 3093 ) 0.03 -¡ /:; 9R 3125 ¡ 0.02 -4 99 3t<;7 c¡ corrosion. 100 3188 00<1. ! c cX}Hosiol1. 101 3220 0 101 3252 0 =ffit ~ 9 11 2 105 Sha!low corro;;;ion. 106 3,79 0 si1;líow oittinª. 107 3410 n rrosion. WfI 3442 109 3474 .2 110 3507 .2 Shaik,w "iHin"'. 111 353R 2 Shallow corrosion. 112 3569 8 1n 3ffiO 114 1/;,1 :¡ 1f~ 3665 n 0.04 6 ¡-:¡ .96 Shallow rnrrn"ion. 116 3699 ) 0.03 0 6 296 116.1 3731 0 1l1l3 PUP It nenn"it<:. 116.2 3740 0 GLM 1 ( atm @ 7:001 116.3 3747 0 PUP line ;;;hallow oiffint:l'_ It Oeoosits. 117~ 9 118 n ¡Ii 119 3814 0 Shallow corrosion 120 3845 2:: Corrosion. 121 3877 8 2.93 122 "1909 0.04 I . Shallow corro"ion. 123 3941 0.£'14 ¡ 2 Shallow corrosion 174 3973 0.03 1 \94 Shallow oitlinlÆ. 115 4004 I~ 1 .93 Shallow corrosion. 126 4036 II I ¡ 2.% Shallow corrosion. 127 4067 .ì 0.02 2.95 128 4099 ì 0.03 I 195 Shallow rmro"ÎOh 129 4130 0 0.02 2.94 130 4163 0.02 8 131 4194 &m 132 4176 3 Shallow corrosion. ~ 133 4257 0 3 Corrosion. 134~ 1[~ 2 135 5 136 4353 ') 2.94 137 4385 0.02 2.94 Pittinu . 138 4417 7.94 =HR 4449 12 2.93 1 4481 2.95 141 4512 t= 2.94 14.2 4.544 1.94 143 4575 0.Q2 8 2.93 3 I PDS REPORT JOINT ULATION SHEET I Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3M-24 Kuparuk ConoroPhiiilips Alaska, Inc. USA May 25, 2007 I I Joint Jt. Depth Pen. Pen. Pen. 1¡\I\('I:11 Min. Damag e Profile No. (Ft.) Body !.D. Comments (% wall) (Ins.) (Ins.) (Ins.) 0 50 100 m 0.02 R 1 2.93 '" i45 0.03 11 2.91 Shallow corrosion. I 0.02 I 2.93 147 4702 0.02 t1 2.95 I 148 4734 0.02 2.93 149 4767 0.02 I 2.95 Pittirn!. 150 479R I 0.03 ¡In ' , 2.94 """ 151 4829 0 0.01 11 2.91 152 4862 0.03 11 ! 2.94 153 4893 I 2q4 I Shallow rorrosion. 154 4925 ) 2.94 155 4957 2.94 156 4988 "1 2.94 Shallow rorrosion. 157 5021 1 2.92 Shallow rorrosion 158 5057 I) 0.D2 2.93 159 5084 I) 0.02 2.94 160 5115 11 O.O? 1 2.94 161 5147 11 0.02 2.95 162 5179 I) 0.03 2.95 Shallow nitlin<>. 163 5211 n 0.03 2.94 Shallow rorrosion. 164 5242 I) 0.D2 2.92 165 5273 0 ; 7.94 Shallow rorrosion. 166 5305 n I: 7.93 PiWnº. 167 5338 0 I 2.93 Shallow oitlinQ. 168 5170 Oln 0.04 2.94 Shallow nitlinC>'. 169 5401 Pi 0.05 ::¡ 2.95 Shallow nitlina. 170 5433 0.12 7.Q2 Corrosion. 171 5465 I 0.08 2.90 Isolated nittin<> 177 5497 I 0.06 2.93 Isolated niWn<> 173 5528 I 0.08 i:¡, 2.93 Corrosion. 174 5560 I 0.08 fi, 2.94 Corrosion. 175 5592 I 0.09 2.93 Isolated ,,¡Wna 176 5624 I ! 2.93 Isolated "ittino 177 5656 I I 2.94 Isolated niWr¡o 178 5687 7.95 Corrosion. 179 5719 11 nil 0.09 2.93 Corrosion. 180 5751 0 0.08 2.93 Cormsion. Î 81 5782 0.05 'if 2.94 I';;';¡~i':;::¡ nittioQ 182 5814 0.06 ;;7 2.94 Isolated nittin<> 183 5846 0.08 5 2.94 Corrosion. 184 5878 0.13 ti 2.93 Isolated "inino 185 5909 (] ¡I; 0.11 0 2.92 Corrosioll. 186 5941 0.07 2.93 Isolated nittin<> 187 5972 0 ~~ 2.93 Isolated nìttinQ 188 6004 om 2.93 Isolated nìttinQ 189 6036 I 0.04 2.93 Shallow rorrosion. 190 6069 ¡ 0.09 2.93 Corrosion. De"osits. 191 6100 0 'r; 0.04 10 2.91 Shallow corrosion. 192 6133 I 0.06 2R9 Isolated n¡ttino 193 6165 (¡OR 0.17 ¡ 2.94 Corrosion. I I I I I I I I I I I I I Body MeJaI Loss Body Page 4 I I I I I I I I Wall: Upset Waft: Nominal 1.0.: Joint No. 194 195 196 197 1% 199 200 201 I I I I I I 209 211 212 213 214 215 216 I 217 218 219 220 221 )22 223 224 225 226 227 ?28 229 230 231 232 233 234 235 36 1'17 nR 239 239.1 239.2 239.3 240 I I I I Jt. Depth Pel 'I (Ins) (Ins.) I··~ 0.07 In "0 ji'; 0.15 O. O. 6228 6259 6291 6322 1'.354 6387 6421 6545 6577 6¡;Oq 6641 1'.674 1)738 6769 6000 6R32 6864 6896 6928 fi961 6992 7024 7055 7088 7119 7151 7183 7215 7247 7279 7309 7341 7372 7.405 7436 711'::7 7499 7530 7562 7594 7624 7657 7667 7671 7678 3.5 in 9.3 ppf l-OO 0.254 in 0.254 in 2.992 in Pen. Pen. : {\flelal Min. 1.0. (Ins.) Ii II 2.93 2.93 2.95 7.9'1 ? 93 2.93 2.94 2.92 VB 2.91 J.92 2.Q3 0.09 ¡ 2.91 O,\S ~ ~ () :Mtìjt¡ ~ o OOA 1 ~ ~;~: 2.93 o J1QL --4 2.93 o g" 0.02 +i ¡ ;.~~ "'ie i ' ;;~ 0.07 ~ IIIK+2.94 0.03 2.95 n 17 004 ¡ë, j :: n II. O.¡j~ 2.93 0.03 2.94 ~O'n? '7 ~:~j .~J.I 2.94 ~93 . , 1 2.95 0.03! n ±H1 in) :f§t±1 2.94 0])2 2.% B~::: )ni 0.02 ¡ o , O.01¡ 2JíO O. ï4 0.04 ¡ 1 2.92 . o ° I () 0.06 O.oq 0])6 ;:¡- 0.13 I t) 0.ü2 I I Lt ¡ i TABU Well: Field: 3M-24 Alaska, Inc. USA May 2007 Comments Corrosion. HOlE! Corrosion. Corrosion. line OJrrnsion. line of niWm,. line of ..·;¡ttina. !<:o!ated nittim:r i <;n!aterl niHioa Isolated nittina Shallow niUna. !so!"tpd oittin<> Corrosion. Isolated nittinu Shallow OJHn<:.iop. Shallow niUi!1"'. Denos~ Del'l<1<;its. 'tlinc 11. Shallow nittincr Isolated niUin<> Iso!ater! nittincr Shallow nittincr. Shallow nitti....cr Shallow OJHosion. Isolated nittincr Isolated '::';itina PUP GLM 2 ¡¡atÒl @ 1O:3Oì PUP It De.........;t". Shallow nittina. 5 w o Profile wall) 50 100 I!II III JOINT U I I I I I I I I I I I I Pipe: Body Wall: UpsetWaß: NominaILD.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: joint Jt. Depth Pe Pen. ¡)~~¡l.· :\1e:al Min. No.': ¡.D. C (Ins.) (Ins.) 241 7712 n nt, 0.04 17: 2.94 lin.... 2Ll7 774 3 illli7 7.93 Isolated nittin... 243 7774 7.93 244 ~ 2.92 Shallow nWinº'. ~~ O.Q3f Shal!ownit!inn. 247 7902 OO? ¡ 248 . 7932 U1QL. : 2.91 749 796'> ±±:..JWL .91 250 7q98 0.02'1 .95 2'>1 8029 0.02 .90 252 8061 0J13 :....- 253 8092 On3 2-- 254 7'>S 8156 256 187 . 2.93 257 220 ) ',1.93 2"R 1750 14 7.91 ShalJow nit!Îna. 259 287 0 i h 2.92 Shallow mrfro;;nn. 760 8314 0 0.ü311 S 2.92 it. De"""¡t<;. 261 834"i 0 O.ü3Ùi 0 2.91 262 8378 0 O.O? I :' 2.91 263 8410 0 ~ 2.91 It De""""it". 264 8441 0 2.92 765 RLl7, 0 0 7.93 "hallow mrrnSÎon. 266 8506 0 0.ü2 2.92 267 8537 0 0.02 7 2.97 266 856q 0 0.02 2.94 ~~6 8600 ~ : =tlt 271 8664 jj1Qì, 291 Sha!!ow"'it!inO'. 272 8695 0.04' r:; 2.94 Shallow nitlÎn<>. 771 8776 0.02 7.93 274 8759 0 m 2.93 275 8791 2.94 276 8822 2.93 Shallow "itinO'. 277 8854 0.06 -;:;"¡ 2.93 Isolated nittinu 278 8886 0.02 2.93 779 8917 0 0.ü2 ±Ii ~~ = 0 gO' ' , 294 283 9045 0 m Sh"IIM\Af ..itÛnu. 284 9077 01.:' Shallow ..iUnO'. 2~ 10 286 9141 2.92 2R7 9173 003 2.91 288 9204 0 ~ 2.90 U. De~ts. 289 q7i5 0 2 Q? Shal!ow,·;¡;;;;;;. 290 9267 0 2.93 I I I I I ¡tiill<1. 6 3M-24 USA May 25, 2007 Comments Alaska, Inc. "0 Profile ,-; '" \70 WillI} m ~ 100 iii iii III iii ~ II! ~ I I Body Meta! Loss Body I I I I I I I I I I I I I I I I I I I REPORT JOINT Wall: Upset Wali: NominaILD.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Weli: Field: 3M-24 Kuparuk ConocoPhiiBips Alaska, Ine. USA May 25, 2007 Survey Date: Joint Jt Depth Pen. Pen. Pen, I,'vlelal Min. "'V Profile No. 1.0. Comments wall) (Ins.) (ins.) (Ins. ) 0 50 100 )91 9298 ~03 '{ 2.92 292 9330 04 1 2.92 Shallow nitltno. 293 9363 0.03 :> =ffi 294 9394 °1 295 9425 )96 9457 q ?93 isolated niUirw 297 i 9489 2.93 298 9520 2.91 299 9552 '{ 2.92 300 9584 n 11i ~06 '11 ¡ s 2.93 ! Isolated niWno 301 %16 :!ili 2.9? 30? %L!.7 ? 92 303 9679 () 2.91 I t. Denn<;it~~ 3M 9710 0:03 1 , 2.91 305 9742 i 1 "" 2.91 It Denr.sit". 306 9775 ¡: 2.93 307 9807 ) 2.92 308 9838 ) 2.91 Shallow mrrosion. 309 9870 n O.Õ? 2.93 310 9qo2 31 : 93 311 9934 ' 93 It. Denn<;its. 31/ 996'> - , 9:> ~I 313 £1' 2.91 Lt. Denn<;j¡':';: 314 10029 I 2.93 Shallow nittino. 314.1 100<;9 'J.91 PUP Sh"llo\M njtlinO'. 314.2 10068 I 0 N/A GlM 3 Hatch @ 11 :3Oì 314.3 10071'. I OJ)3 2.89 PUP U. Denn<;its. pII! 315 10080 0.01 2.90 pII! 316jj0112 O~ 2.87 U. Denn<;its. pII! 317 0143 0.03 2.90 It Deoosits. pII! 318 10176 Ofl? 2.91 319 10208 111 : 2.93 It Denosits. 3)0 10240 I ).c¡1 321 10272 2.92 Shallow corrosion. 321 10303 n 2.<12 323 10334 4 2.92 324 10365 4 ~.93 ~ '",",low ~nOOon. 325 10397 I 0.03) 326 10430 ( 0.02 2 U. n"''"''"'''íts. ~ 10462 0 0.02 2.92 Pittiml. 2 1 Men () 0.02 2.QO 329 1 œ¡? A- n 0.02 ~ Sh;¡ljnw nittio<>. 330 10'>55 0.03 331 10587 n )7 0.02 2.94 Pittin2.. 332 10619 0.03 2.90 It. Denn<;it$. 333 10650 0.03 CJ +m I 334 10682 ~ ~:I O.Õ? Shallow rnrrosíon. 335 10714 336 10747 ( n ¡ 2.9? 337 10778 or 0.03 :¡ 2 ¡ 2.92 Shallow nit!Înº. 7 I I I I I I I I I I I I I I I 3.5 in 9.3 ppf l-OO 0.254 in 0.254 in 2.992 in Well: Field: 3M-24 inc. Date: USA 25,2007 Joint Jt Depth Pen. Pen. Pen. ¡yinial Min. ! Profile No. \:;:~(;¡ ;; !.D. Comments (Ins.) (Ins.) 0 50 100 I om 11 ) 7.91 Shallow nitlinq. II 339 1084tl= 7.97 340 10873 2.93 341 10905 I 2.9? 341 10936 I 343 10%9 I om ~hallow rt1nosion. ~ I 0.05 PUP Shallow nitlirnz. Lt. Denn"its. 3432 CLM 4 flatch @ 8:151 343.3 ~\ pi ¡P Shallow corrosion. Lt Deoosits. 344 1102 1 345 11052 0 0.02 346 11082 0 347 11114 n 348 11146 n ~"177 0 11209 n 0.02 ¡g 2.92 3 2 11273 7.9f.. 353 11305 I 2.95 354 11336 0 I 2.94 35<; 11"168 0.02 2.94 356 11400 om 'I ?q~- 357 11431 om 2.94- 358 11462 om 2.97 ~5q 11493 797 360 11524 0 2.94 31'.1 11557 0 . 0.02 7 2.94 361.1.0.18 0.04 14 ¡y 2.86 PUP Shallow corrosion. Lt. Demsits. !I 361.2 1597 0 0 -0 m GlM 5 (latch @ 3:OOi 361.3 1604 00: I :~ PUP U. Deno<;its. 362 363 11 2.94 3f..4 11673 1 2.94 365 11705 J 2.93 366 11737 ¿j 2.94 367 11767 ~9 i 2.94 368 11797 10 'i 2.lf1 ~ 11829 = 4 2.93 11860 0.02 1 7.93 Lt. l1enŒåt;;. 371 11892 ( 0.02 372 11924 ( 8 372.1 11955 o 0.03 13 '* PUP Shallow"i"'~. 372.2 11960 n 0 NIA r.¡ M 6lbtrh @ ':4<;\ 372.3 11966 0 0 if PUP 373 11972 0 0.2'1 l ìO HOLE! 373.1 12004 n ~ O~ I PUP Lt. Denosit<¡. 37~.2 12010 0 PRR 373.3 12022 I PACKER 37'1.4 170<1 n PUP l<:nlaœd "'flinG. It . . HOLE' 173.5 12038 n D NIPPLE I I I 8 I I I 3.5 in 9.3 L-80 WeD: 3M-24 Wail: 0.254 in Field: Upset WaH: 0.254 in Inc. Nominal 1.0.: 2.992 in USA Survey Date: 25, 2007 Joint No. Comments It. TAIL I I I I I I I I I I I 9 I I ------ ------------ PDS Rep rt Cross Sections We!!: Field: Company: Country: Tubin : 3M-24 Kuparuk ConocoPhiillips Alaska, Inc. USA 3.5 ins 9.3 f L-BO Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: May 25, 2007 UW MFC 24 No. 211387 1.69 24 B. i Cross Section for Joint 373 at depth 11986.98 ft Tool "" 44 Nominal 10 "" 2.992 Nominal 00 = 3.5 Tool deviation"" 43 0 HOLE .25 ins"" 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ------ ------- - - -- - - s art s Well: Field: Company: Country: Tubin : 3M·24 Survey Date: Tool Tool Size: No. of Anal st: May 25,2007 UW MFC 24 No. 211387 1.69 24 R i ConocoPhimips Alaska, Inc' USA 3.5 ins 9.3 f L·BO ft Tool '" 43 Nominal to'" 2.992 Nominal 00 '" 3.5 Tool deviation'" 89' HOLE .25 ins'" 100% Wall Penetration HIGH SIDE'" UP Cross Sections page 2 I I I I TUBING (0.12049, OD:3.5OO, I 1D:2.992) I 36 I GasLiJ! 22 Mandre!IVa!\Ie 2 (7669-7670. OD:5.300) I I I I I I I I 50S (12048-12049, 00:3.5(0) I Perf (12132-12152) Perf I (12162-12198) I Perf (12230-12244) I KRU 3M..24 (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Variance 0 Annular Disp. 0 Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development_B Exploratory 0 193-195/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-029-22432-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' 3M-24 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12490' feet true vertical 6361' feet Plugs (measured) Effective Depth measured 12262 feet Junk (measured) true vertical 6202 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 2971' 9-5/8" 3039' 2418' 6870' 4750 SUR. CASING 22711 9-5/8" 5310' 634T 5120' 2370 PROD. CASING 12402' T' 12470' 634T 4980' 5410 Perforation depth: Measured depth: 12132-12152',12162-12198',12208-12244' true vertical depth: 6110-6124', 6131-6156', 6163-6189' RE Tubing (size, grade, and measured depth) 3-1/2', L-80, 12049' MD. CEIVED Ute "/ {" 21ìi\'l Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' pkr= 12024' ".: U ''JU\J SSSV= Cameo TRDP -4E SSSV= 1949' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 0 0 0 1000 1450 Subsequent to operation 214 205 375 766 140 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~ Contact MJ Loveland/Nina W 0 ds 659-7224 Printed Name MJ L ela Title Signature Phone & s-Tf 7;;' ;;... Form 10-404 Revised 2/2003. fIIIIS BFl DEe 8 0 II! SUBMIT IN DUPLICATE \SCAf~(.~ED! JANI 2 @ 2004. WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey But'con / Jeni Thompson ProActive Diagnostic Services, Inc. P. 0. Box 13S9 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR CD-ROM FILM BLUE LINE Open Hole I 1 1 Res. Eval. CH 1 1 1 Mech. CH 3M-24 6-01-03 Caliper Survey I Flpt or 2 Color -- , Signed ' Print Name: Date ' ProActive Diagnostic Services, Inc., Po Box 1369 Stafford Tx 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog, com Website: www.memorylog.com Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3M-24 Log Date: June 1, 2003 Field: Kuparuk Log No.: 5092 State: Alaska Run No.: 2 APl No.: 50-029-22432-00 Pipe1 Desc.: 3.5" 9.3 lb. L-80 Top Log Intvll.: 4,928 Ft. (MD) Pipe1 Use: Tubing Bot. Log Intvll.: 7,774 Ft. (MD) Inspection Type · Patch Candidate Inspection COMMENTS · This log is tied into GLM 2 @ 7,669' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages to determine potential patch candidacy. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition with respect to corrosive penetrations. A hole in an area of corrosion just below the collar is recorded in joint 195 @ 6,230'. Wall penetrations from 20% to 73% are recorded throughout the interval of most severe corrosive damage from 5,400' - 6,650'. The damage appears in the form General Corrosion with deeper Line Corrosion. No other significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. The joint numbering used in this report is an estimation based on average joint length. MAXIMUM RECORDED WALL PENETRATIONS · Hole in Line of Corrosion (100%) Jt. 195 @ 6,230 Ft. (MD) Line Corrosion (73%) Jr. 191 @ 6,103 Ft. (MD) Line Corrosion (72%) Jt. 199 @ 6,358 Ft. (MD) Line Corrosion (63%) Jr. 198 @ 6,326 Ft. (MD) Line Corrosion (61%) Jr. 204 @ 6,540 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No other areas of significant cross-sectional wall loss (> 13%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS · ~::o~ ~!::~ ,,¢~'~, ~:'" ~, ~l~i!i":.":: i;~:"'",~;~, No significant I.D. restrictions are recorded throughout the inte~al logged. , [, ~ ,,;:.. ,,~, ....,,..,.,. Field Engineer: D. Cain Analyst: J. Thompson Witness: T. Johns ProAc'i~ive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 774.97 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS(~memorylog.com Prudhoe Bay Field Office. Phone: (907) 659-2307 Fax: (907) 659.-2314. PDS Report Overview Body Region Analysis We]h 3M24 Field: KUPARUK Company: BP EXPLORAiION ALASKA Counlry: USA Tubii/g: Nora.OD Weight Grade & Thread 3.5 ins 9.3 ppf L-80 Survey Date: June 1, 2003 Tool Type: MFC 24 No. 00387 [oo} Size: 1.69 No. of Fingers: 24 Perpetration and Metal Loss (% wall) ! Damage Configuration ( body ) () Damage Profile (% wall) 0 50 154, 194 214 Gl M 1 A~lalysis Overview page 2 PDS REPORT JOINT TABULATION Pipe: 3.5 in 9.3 ppf L-80 Well: 3M-24 Body Walk 0.254 in Field: KU?ARUK Up,et Wa[h 0.254 in Company: BP EXPLORATION ALASKA Nominal I.D.: 2.992 in Countrv: USA Survey Date: June 1, 2003 joint i Depth , No. i (Ft.) I !~ [ 4928 185 [ 4959 [ !56 ] 499l [57 5023 I58 5054 159 5086 I60 5118 [6t 5150 162 5181 __163 5214 i 164 5245 ~ 165 5277 5309 ~ [ 5341 168 [ 5372 169 i 5404 170 5435 17 [ 5467 172 5499 t73 5531 174 5563 175 ~59, 176 177 [78 179 180 181 182 183 184 185 186 187 188 189 190 5626 5658 569O 5721 5753 5785 5817 5849 5880 5912 5944 5976 6007 6039 6071 FPen. Pen. I Pen. Upset ~ o i I i Body ~ Loss I.D. I Comments 0.03 It 4 [ 2.96 [ Pittin& ~ t 0.03 I1 ] 7 I ~,95 I 0.02 8 [ 2 ] 2.95 ' o.02 0.04 ~5 9 [ 2_,.~5 l 10 3 O.02 8 2.95 0 [ 0 02 8 I 0 I 0.04 [7 ~ 4 [ 2.95 Shallow pitgjng. 0 [ 0.03 13 [ 5 2.94 0.0~ 13 I 6 i 2.92 0 [ 0.05 20 [ 9 [ Sha[]ow corrosion. 0 [ 005 ] 8 [ 6 ] 2.95 Shaik~w corrosion. 0.06 23 I 4 2.94 [so[ated 0.04 [6 [ 3 2.95 0.06 23 i 4 2.95 Isolated 0.11 [ 43 8 2.94 Isolated 0.06 24 [ 9 ~ 2.91 , ~solatqd pitting. 0.05 20 6 j 2.92 [ Shallow corrosion. 0.09 [ 36 5 j 2.93 i Corrosion. ~,g9 )6 9 2.94 Corrosion. 0.08 31 9 2.93 [ Conosion. Q [ 0.10 [ 39 7 2.94 Corrosion. 0 ] 0.09 ~0 2.95 Corrosion. 0 0.09 . 36 7 2.94 Corrosion. 0. [0 40 8 j 2.94 Corrosion. 0 [ 0.08 30 5 ] 2.92 Corrosion. 0 ] 0.07 26 6 2.95 Corrosion. ,) ~ 0.06 25 2 2.95 Corrosion. 0 ] 0.07 29 7 2.94 Corrosion. 0 ~ O. If ~ 53 7 . 2.93 . Corrosion 0 ().10 12 2.92 Corrosion. 0. l I 41 Corrosion. 0.10 39 [ 4 2.93 Corrosion. 9 2.94 isolated pitting. 0.05 19 ~ ~ [ 2.93 Shallow kine Conosion. ~ j ~ ~ 43 , G j 2.94 Line Corrosion 19[ 6[03 192 6134 0 193 6166 194 6198 195 6230 196 6261 197 6293 I98 ~ 6325 !99 ] 6357 200 [ 6388 20~ ] 6420 202 [ 6452 203 i (,484 0. I9 [ 73 12 i/.06 [ 23 I 7 0.15 ] 58 0.14 54[ I1 100 [ 13 0.15 i 59 I 6 0.15 j 57 5 0.16 7 0.18 ] 72 ] 7 4 2.92 Line Corrosion. 2.92 Line Con'osion. 2.94 i Lille Corrosion. 2.88 [ Line Corrosion. Lt. Deposits. 2.93 )]e I IOLES 2.92~. j Line Corrosion 2.94 Line Corrosion. 2.94 Line Corrosk)n. 0.07 i 27 2.93 [ Line Corrosion. 2.95 Line Corrosion. 6 2.94 Line Cprroskm. 2 2.93 Corrosion. 4 [ 2.94 Line Corrosion. Damage Profile (% wall) [0 50 100 ii Penetration Body Metal Loss Body Page I JOINT TABULATION Pipe: 3.5 in 9.3 ppf b80 Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in We[h Field: Company: SLirve¥ Date: 3M-24 KUPARUK BP EXPLORATION ALASKA USA june l, 2003 Joint [ Depth Pen, Pen, Pen, No. j (Ft.) Upset Body % i (ms.) (Ins.) 204 65J5 0 0.15 61 J 7 205 6547 0 0.05 21 j 6 206 6579 0 23 5 207 6611 0 0~0 j41 7 208 6642 0 i 0.O4 [15 7 2.9~2 209 6674 0 0.04 I 17 6 [ 2.95 213 680[ 0 0.05 20 4 2.92 214 6833 0 0X)4 I 16 4 2.93 215 6865 0 0.07 10 216 ~ 6896 [ 0 0.05 21 9 217 j 6928 0 [ 0.04 15 9 218 [ 6960 0 ~, 0.06 24 8 Metal Mia. Loss I.D. % (ins.) 2.92 2.93 2.94 293 Line Corrosion. Shallow 5hallow Corrosion. Line Corrosion. IsoJated Corrosion. 220 J 22I 222 223 ~224 225 Shallow pitting. Corrosion. 2.93 Co:rosian. ~,94 · 2.95 Co(rosjon: 6992 0 i 0 06 24 ~ 7 2.95 Corrosion. 7023 0 0.05 ~(-) J 8 2.9l Shallow corrosion. 7055 0 007 27 i 6 2.89 Conosion. 7087 0 . 0.08 ~0 ] 4 2.90 Corrosion 71[9 0 0.03 13 j ~ 2.9~ 2{3 [ 7436 ~ 234 [ 7468 2~5 7~00 236 [ 7532 237 756] 2{8 i 7595 239 ~ 7627 7150 0 0.05 7182 0 0.05 226 7214 0 0.05 230 j 7341 0 0.04 231 I 7373 0 0.05 232 7405 0 0.04 () i 0.05 o I o.o4 0 i 0.07 B 0,04 20 i 8 19 j 5 r9 i 6 16 19 [4 15 2.93 Sharrow corrosion. 2.93 Shallow corrosion, 2.93 Sha[k)w Corrosion. Corrosion. Shar[ow corrosion, 6 2.9! Shallow Corrosion. 3 2.90 Sharlow Corrosion. 5 2.93 6 Shallow corrosion. 2.92 Corrosion. 2.94 0 0,04 [ 5 9 2. ~4 0 % [ ~ ' 2 i 2S~ 0.05 18 ~ 2 _.91 j 239.[ 7658 0 [ 0.0! . 4 , I [ 2.91 1 239,2 7668 . 0 I 0 0 0 j N/A ' 239.~ 7674 0 240 7680 241 [ 771l 242 ] 7743 243 7774 Isolated pitting, Shallow PUP Latch @ 1:00 0.02 [ 9~. ~ 3 2.90 PUP 0 0,08 ] 32 i 9 i 2,92 [ CoErosion. 0 0.06 I 22 I !1 2.92 i Corrosion. 0 007 [ 29 [ 8 Corrosion. 0 [ 002 ] 8 4 ] 2.94 I Damage Profile (% wall) lO 50 I )0 Page 2 PDS Report Cross Sections Well: 3M-24 Survey Date: lune 1, 2003 Field: I(UPARUK Tooi Fype: MFC 24 No. 00387 Company: BP EXPLORATION ALASKA 1'oo[ Size: 1.69 Country: USA No. of Fingers: 24 Z!iubin~i 3:5 !ns 9:3~pf b80 Analyst: I.Thom~son Cross Section for Joint 195 at depth 6230.14 ft Too] speed - 54 Nominal ID - 2,992 Nominal OD - 3.500 Remaiqing wall ~rea - 87 % ¥ool deviatkm - 78 ° Finger 8 Penetration = 0.278 ins Multiple I tOles 0.28 ins = 100% Wall Penetration bi[Gl t SIDE = UP Cross Sections page 1 PDS Report Cross Sections WEN!: 3M-24 Survey Date: june 1, 2003 FieNd: KUPARUK Tool Type: MFC 24 No. 00387 Company: BP EXPLORATION ALASKA Fool Size: 1.69 Country: USA No. of Fingers: 24 Tu bin~- 3.5 ins 9:3 pp~ L-~ Anajys!~_ 1: rhom1~son Cross Section for Joint 191 at depth 6103.12 ft Too[ speed - 56 Nominal ID - 2.992 Nominal OD - 3.500 Remainil~g ~,a][ are~ = 89 % Tool deviation = 78 ° Finger7 Penetration = 0.186 ins 0.19 ins = 73% \,¥aJ[ Penetration HIGII SIDE= UP Cross Sections page 2 PDS Muldfinser Caliper 3D Lo~ PJol Company: Co~oco?'~ ti p;~ A~a~a, ~nr~. Field: Kuparuk Weli 1Y-t4 Date March 29, 2883 Description: Oefa~ of Ca~pe¢ Record~rigs Over Jewelry From 6, 7~0' ~, 6,970 Joi~t 224 X Nipple Joint 225 lnjectioi~ Joliet 226 Joint 227 PDS Multifinder Caliper 3D Lo~ Company: Co~oso?hiilips Alaska, Ins, Field: Kuparuk Well: 3~'~1-24 Date: June I, 2~83 Descri ption: Derai~ o~' Cad,per Recordings Over' Proposed Pa~ch &oca~ion Joint 193 Joint 194 Joint 195 Multiple Holes near Collar Joint t96 ~a~ 3! 03 02:59p PHI WELLS GROUP 90? 659 7314 p.2 KRU 3M-24 Fluid: Refemnoe last WIG Rev Reason: Set retrievable CONDUGTO~ SUR. CAS~IG PROD. CA,9 lNG SUR. CASING Size 3,500 TD: 12490 flKB Thread Thread 18RD AB MOD TUBIF §11B-61Z4 I2162-12198 615t. 6156 t2208-12230 6f6~.6179 12230-12244 6t79- 6189 Lift Rlandrolr. Nalves Conatte~t Enedet/Powerjet. 0 deg 90 e~ent Enerjel/Power~et 0 deg +f- 90 ~'lgnt cle9. i~slng; 2 7/2° Descrlplion ID 2.812 HALLIBURTON RETRIEVABLE PATCIL TOTAL LENGTH 23.12', SET 1.310 Baiter w/10' stroke 3.000 Baker 'FHL' 3.Doe , NO GO 2.750 Bake~ 2.992 2,992 ..: :!.. ::.. IN TUBING RKE ~e-calculated depths off mandrels & Jewelry .... located hole [r 6231' MO. 6231' MD PH,,.LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 1, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3M-24 (193-195) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU well 3M-24. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED OCT 0 ~ 2001 Alaska Oil 8, Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 983' FNL, 1609' FEL, Sec. 25, T13N, RSE, UM At top of productive interval 3844' FNL, 279' FEL, Sec. 27, T13N, RSE, UM At effective depth At total depth 3906' FNL, 532' FEL, Sec. 27, T13N, R8E, UM 5. Type of Well: Development __X Exploratory _ Stratig raph ic __ Service__ (asp's 506256, 6016515) (asp's 497032, 6013654) (asp's 496779, 6013587) 6. Datum elevation (DF or KB feet) RKB 68 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3M-24 9. Permit number / approval number 193-1 95 / 10. APl number 50-029-22432 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 12490 6361 feet feet Plugs (measured) Effective depth: measured true vertical 12262 feet 6202 feet Junk (measured) Casing CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Length 121' 5242' 12402' Size Cemented 16" 452 sx AS 1 9-5/8" 1100 sx AS III & 600 sx Class G 7" 250 sx Class G Perforation depth: measured 12132'-12152', 12162'-12198', 12208'-12244' true vertical 6110'-6124', 6131'-6156', 6163'-6189' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 12049' MD. Packers & SSSV (type & measured depth) BAKER 'FHL' @ 12024' MD. CAMCO 'TRDP-4E' @ 1949' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure Measured Depth 121' 5310' 12470' True verticalDepth 121' 3285' 6347' RECEIVED OCT 0 2, 2001 A!sska 0il & Anchorage 14. Prior to well operation Subsequent to operation OiI-Bbl 162 Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 303 537 174 30 456 Casing Pressure Tubing Pressure 165 173 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas__ Suspended_ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~l 4~ Title Staff Engineer Michael Moonay Form 10-404 Rev 06/15/88 · Questions? Call Mike Mooney 263-4574 Oa, Prepared by Sharon Al/sup-Drake 263- SUBMIT IN DUPLICATE 3M-24 Event History Date Comment 08/28/01 RAN STATIC BHPT LOG, SBHP=3662.5, BHT=157.7 F @ 12250'., TD @ 12255', PERFORATED A1 SAND (12230'-12244') / ATTEMPTED TO PERF. OTHER ZONES, GUN #2 MISRUN, POOH RDFN, LEFT WELL SI. JOB IN PROGRESS. [PRESSURE DATA, PERF] "~5'§?'§i5~5'i ................ j~.'~.j~;~:f:i~biq5.~§.`~.5~..~:~..~.'.q.~.{~.~.~:~.~.§.~.~.~.~ ?~?~'~ ?~ ?~'§~i"O §'1'~ ~"~':'{~§~" ........................................ ENERJET/POWERJET, 6 SPF, 0 DEG PHASING, +/- 90 DEG ORIENT. NO PRESSURE CHANGES DURING ANY OF THE PERF RUNS. LEFT WELL BORE FREEZE PROTECTED W/DIESEL [PERF] Page I of I 9/28/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ X Patch 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 68 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 983' FNL, 1609' FEL, Sec. 25, T13N, R8E, UM (asp's 506256, 6016515) 3M-24 At top of productive interval 9. Permit number / approval number 3844' FNL, 279' FEL, Sec. 27, T13N, R8E, UM (asp's 497032, 6013654) 193-195 / At effective depth 10. APl number 50-029-22432 At total depth 11. Field / Pool 3906' FNL, 532' FEL, Sec. 27, T13N, R8E, UM (asp's 496779, 6013587) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12490 feet Plugs (measured) true vertical 6361 feet Effective depth: measured 12262 feet Junk (measured) true vertical 6202 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 1 6" 452 sx AS 1 121' 121' SUR. CASING 5242' 9-5/8" 1100 sx AS III & 5310' 3285' 600 sx Class G PROD. CASING 12402' 7" 250 sx Class G 12470' 6347' PROD. CASING Perforation depth: measured 12132'-12152', 12162'-12198', 12208'-12244' RECEIVED true vertica16110'-6124', 6131'-6156', 6163'-6189' OCT ~_ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 12049' MD. ,,~laska 0il & Gas Cons. Commission, Anch0racle Packers & SSSV (type & measured depth) BAKER 'FHL' @ 12024' MD. CAMCO 'TRDP-4E' @ 1949' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Set 20-foot 3-1/2" tubing patch 6223-6241' across leak @ 6230' mc Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 162 137 537 1221 165 Subsequent to operation 144 196 623 1314 187 . 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ___X Oil __ X Gas __ Suspended __ Service _ 17. I hereby certify that the foregoing is t~ best of my knowledge. Questions? Call Jerry Dethlefs 659-7224 Signed ~~-'¢-'~~~ Title Problem Well Supervisor Date Jerry Dethlef. Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc - .KUPARUK RIVER UNIT ELL SERVICE REPORT 3M-24(4-1)) WELL 3M-24 DATE 09/04/01 DAY 9 FIELD ESTIMATE JOB SCOPE PERFORATIONS-E-LINE(260) DALLY WORK SBHP, SET HALIB. PATCH OPERATION COMPLETE SUCCESSFUL ~ Yes 0 No ~ Yes 0 NO AFC# ICC# I DAILY COST K85328 230DS36ML $17,986 Initial Tbg I Final Tbg I Initial IA I 1345PSlI 1600PSII 1800PSl I IKEY PERSON SWS-JOHNSON ACCUM COST $127,955 Final IA I Initial OA IFinal OA ITTL Size 1800PSll 100PSll 100PSII 3.500" JOB NUMBER 0516010452.1 UNIT NUMBER 2128 SUPERVISOR CHANEY Signed IMin ID Depth 2.750" 12038 FT DALLY SUMMARY OBTAINED SBHP OF 3739.9 PSIA AT 12250' ELM, SET HES RCP TBG PATCH WITH TOP ELEMENT AT 6223' - BTM ELEMENT AT 6242' COVERS LEAKING COLLAR @ 6230' (TOP PATCH BODY AT 6221') [Pressure Data, Leak Detect-Patch] TIME LOG ENTRY 08:00 ARRIVE WELL SWS UNIT 2128, ENG JOHNSON 09:00 HOLD SAFTEY MEETING 09:10 PRESSURE TEST BOP/RISER TO 3000# 09:20 RIH W/HEAD/SWIVEL/WT BAR/ROLLERS/WT BAR/PBMS/ROLLERS (25.5') 10:15 TIE IN TO CBL DATED 1/29/94 10:32 RUN GR/CCL/PRESS/TEMP PASS FROM 12250' TO 12000' 10:46 TAKE PRESSURE STOP AT 12250', PRESS=3740 PSIA, TEMP= 158.1 (SAME DEPTH AS PRESSURE STOP MADE PRE ADD PERF) 10:53 POOH 12:00 AT SURFACE, RIG DOWN PSP AND RIG UP FOR PATCH 13:15 RIH W/HEAD/SWIVEL/CCL/GO ADP/HALIB. SETTING TOOL/PATCH (34.5') 14:10 STOPPED AT 3460' - BEGIN PUMPING AT DIESEL AT 0.5 BPM - CONT. IN HOLE 14:35 STOPPED AT 6220' - RAISE PUMP RATE TO 1.0 BPM THEN TO 1.5 BPM THEN 2.0 BPM, GO THRU THEN REDUCE RATE TO 1.0 BPM 15:12 STOPPED AT 7350 - RAISE RATE TO 1.5 BPM - WORK THRU 15:18 STOP PUMPING 15:20 TIE IN TO GLM AT 7669' WITH PATCH SETTING RECORD DATED 10/11/99 15:25 LOG UP FROM 7718' TO SET DEPTH OF 6213.5' - COUNT COLLARS UP FROM GLM - OK WITH PATCH SETTING RECORD 11/21/99 16:00 SET PATCH WITH TOP ELEMENT AT 6223', BTM ELEMENT AT 6242' ( TOP OF PATCH AT 6221') Fluid Summary 55 BBLS DIESEL INTO TBG SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $854.00 APC $2,350.00 $19,780.00 COBURN $0.00 $1,599.00 DOWELL $0.00 $14,218.00 FAIRWEATHER $0.00 $150.00 HALLIBURTON $4,743.00 $14,363.00 LITTLE RED $0.00 $7,500.00 ORBIS $0.00 $965.00 PH I LLI PS $250.00 $2,293.00 SCHLUMBERGER $10,643.00 $61,318.00 WEATHERFORD $0.00 $4,916.00 TOTAL FIELD ESTIMATE $17,986.00 $127,956.00 TIME 16:18 16:20 16:55 17:30 LOG ENTRY ~-- -~-' HAN TO WORK TOOL UP/,. ,~/N TO GET FREE - 600# OVER NORMAL TL. JLL STEM FREE FROM PATCH POOH AT SURFACE, RIG DOWN LEAVE LOCATION PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY SSSV -- (1949-1950, 0D:3.500) Gas Lift -- MandrelNalve 1 (37'47-3748, 0D:5.390) PATCH (6221-6241, 0D:3.500) Gas Lift MandrelNalve 2 (7669-7670, 00:5.390) TUBING (0-12049, 0D:3.500, ID:2.992) SOS (12o48-12049, 0D:3.500) Pad (12132-12152) Perf (12162-12198) Perf (12230-12244) KRU 3M-24 3M-24 SSSV Type: Annular Fluid: APl: 500292243200 Reference Log: TRDP Last Tag: 12262 Last Tag Date: 8/15/2001 Casing String - ALL STRINGS Description CONDUCTOR sun. CASING PROD. CASING sun. CASING Tubing String - TUBING Size Top 3.500 0 Perforations Summary Interval TVD 12132-12152 6110-6124 12162-12198 6131-6156 12208-12230 6163-6179 12230-12244 6179-6189 Gas:Lift Mandrels/Valves: Well Type: PROD Angle @ TS: 145 deg @ 12125 Odg Completion: 1/26/1994 Angle @ TD:I46 deg @ 12490 Last W/O: Rev Reason: Reset Patch by ImO Ref Log Date:TD: 12490 ftKB Last Update: 915/2001 Max Hole Angle: 70 deg @ 9190 Size Top Bottom I TVD I Wt I Grade I Thread 16.000 0 121 121 62.50 H-40 9.625 0 3039 2418 47.00 L-80 7.000 0 12470 6347 26.00 L-80 9.625 3039 5310 3285 36.00 J-55 Bottom TVD Wt Grade Thread 12049 6051 9.30 L-80 EUE 8RD AB MOD. Zone I Status I Ft ISPFI Date J Type J Comment C-4 20 6 8/30/2001 APERF Enerjet/Powerjet, 0 deg ph, I +/- 90 orient A-3,A-2 36 6 8/30/2001 APERF Enerjet/Powerjet, 0 deg ph, ] I I I+/- 90 orient A-1 I I 22 I 4 I 6/30/1994 I IPERF 1180 deg. phasing; 2 1/2" Titan A-1 14 6 8/28/2001 APERF Enerjet/Powerjet, 0 deg ph, I I I I I I+/- 90 orient Vlv Cmnt Other ,; ~: J EW:ELRY . Depth TVD Type Description ID '1949 1824 SSSV Camco 'TRDP-4E' 2.812 6221 3633 PATCH HES RCP Retrievable patch from 6221'-6241' RESET 9/4/01 1.310 12009 6023 PBR Baker w/10' stroke 3.000 12024 6034 PKR Baker'FHL' 3.000 12038 6043 NIP Camco 'D' Nipple NO GO 2.750 !12048 6051 SOS Baker 2.992 12049 6051 TTL 2.992 Date I Note 3/11/1999 LOCATED LEAK IN TUBING (~ 6183' WLM (approx. 6224 RKB) 3/14/1999140' joint of tubing missing, re-calculated depths on mandrels & jewelry 9/25/19991PDS caliper log located hole in tubing (~ 6231' MD. 10/25/1999~ PDS caliper log located hole (~ 6231' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 983' FNL, 1609' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 3844' FNL, 279' FEL, Sec. 27, T13N, R8E, UM At effective depth At total depth 3906' FNL, 532' FEL, Sec. 27, T13N, R8E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 506256, 6016515) (asp's 497032, 6013654) (asp's 496779, 6013587) 6. Datum elevation (DF or KB feet) RKB 68 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3M-24 9. Permit number / approval number 193-195 10. APl number 50-029-22432 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 12490 feet 6361 feet Effective depth: measured 12274 feet true vertical 6210 feet Plugs (measured) Casing CONDUCTOR SURF CASING PROD CASING Junk (measured) Length Size Cemented 121' 16" 452 Sx AS I 5242' 9-5/8" 1100 Sx AS 111 & 600 Sx Class G 12402' 7" 250 Sx Class G Tagged PBTD (4/22/99) @ 12274' MD. Measured Depth TrueverticalDepth 121' 121' 5310' 3285' 12470' 6347' Perforation depth: measured 12208' - 12230' true vertical 6163 - 6179' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tbg @ 12049' MD. BAKER 'FHL' Packer @ 12024' MD. CAMCO 'TRDP-4E' @ 1949' MD. RECEIVED t- _B ,5 2001 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation OiFBbl 270 Representative Daily Avera,qe Production or Injection Data Gas-Mci Water-Bbl 365 553 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 181 163 462 16. Status of well classification as: Oil __X Gas __ Suspended __ Casing Pressure Tubing Pressure - 196 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Service 189 Prepared by John Peirce 265-6471 SUBMIT IN DUPLICATE 3M-24 DESCRIPTION OF WORK COMPLETED TUBING PATCH INSTALLATION & CEMENT OUTER ANNULUS 4/22/99: RIH & tagged PBTD at 12274' MD. 10/21/99: MIRU & PT equipment. RIH & set an HES RCP Retrievable Tubing Patch over tubing leak at 6223 - 6242' (seal to seal). POOH. RD. 6/7/00: MIRU & PT equipment. Ran in the 9-5/8 x 16" annulus w/hose & pumped I bbl of 12# Litecrete cement. Returned the well to production w/gas lift & obtained a valid well test. RECEIVED FEB 2001 Al~k~ Oil & Gas C,~')ns. (;omnlis-¢,ior Anchorage P E R H I T ., .. AOGCC Ina1 v'i'dt.iai V,/:c~i i .ao'iogi:cai Hater"'i'a'is Invan,..~,"y DATA T DATA__F'LUS L.~ as..~'195,~,.., II:SIT... (C&C). L 10600 ...... 1°356~. 93'-195 ~T L 10600~-1'2327 3 .... ~'1 R 0 '12~-90~ :, 't 95 .... R V E Y .~ G C T . ...ag .... '19~,.; ~13 T 5330'-1°z[90~~. 93"'195 ~DR LWD/DC L. 5200- 'i 2~-~90 93'-195 /./C~.~ D N '-' L WD / D C L 5170-.' i2/~. 80 0 I-'1 ~- C D R /,3 D 1'4 g3'--195 C~.JDR VER/LWD/DC L i 'i600"-12z,~80 93 i95 ~ F.: COHP DATE:O6/30/'ga. 93"-195 ~LY WELL OP R 01/17/9/~'--C) 7/01/'9z~ ,S I',I F' S (:; H I.:' 5; C: i'.t F" 0/,~/ IO/96 D A '1' L: ...... 14: E ,:.': V D Ar'e dr'y di:tch samples r'equi'r'ect? yes ~___.~ct Was the ¥/ei'i cor'ed? yes Ar'e we i i tests r'equi'r'eci? e.y~.~ Znff ti' a'i C: 0 H H E F.! T S ~___.~A1na'l ysi's & ctescr'i'p~on ~___~Rec~- yes r',o r' e c e i' v e d 2 ~-, o r'e c: e i' ',,/e <:l 2 y e} S FI O ~,RCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 October 3, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. FORM WELL ACTION 10-404 3H-23 FRAC 10-404 3H-23 PERF 10-404 3M-24 FRAC 10-404 3M-28 FRAC ORIGIN. AL If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Wells Superintendent Kuparuk Production Engineering Attachments Well Files (atch only) RECEIVED 0CT '- 6 t994 Aiaska 0ii & Gas Cons. Commission Anchora:je ARCO Alaska. inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate X Plugging Perforate Repair well __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Po O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development . X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 985' FNL, 1612' FEL, SEC.25, T13N, RSE, UM At top of productive interval 1440' FNL, 282' FEL, SEC.27', '1'13N, RSE, UM At effective depth 1405' FNL, 447' FEL, SEC.27, T13N, RSE, UM At total depth 1375' FSL, 532' FEL, SEC.27, T13N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-24 feet 12490' feet Plugs (measured) 6361' feet 9. Permit number/approval number 93-195 10. APl number 50-029-22432 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 12382' feet Junk (measured) true vertical 6286' feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 452 SX ASI Surface 5269' 9-5/8" 1100 SX AS III & Intermediate 600 SX CLASS G Production 1 2 4 2 9' 7" 250 SX CLASS G Liner Perforation depth: measured 12208'-12230' true vertical 6164'-6179' Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80@ 12049' Packers and SSSV (type and measured depth) PKR: BAKER FHL PKR @ 12024' SSSV: Camco TRDP-4E @ 1949' Measured depth True vertical depth 121' 121' 5310' 3285' 12470' 6350' RECEIVED 13. Stimulation or cement squeeze summary A Sand Fmc intervals treated (measured) 12208'-12230' Treatment description including volumes used and final pressure Pumped 194.4 Mlbs 12/18 Propant@ perfs. Max Press of 8400psi. 14. Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 0 ,;' 0 0 500 Subsequent to operation 731 322 457 10 Gas Cons. Commission Anchora'~o Tubing Pressure 150 185 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. " ~ Signeg," --- Title Wells Superintendent Form 10-404 Rev 06/15/88 Date ///'~ ,~J~/ SUBMIT IN DUPLICATE ARCO Alaska, Inc.~, Subsidiary of Atlantic Richfield Company WELL DATE ,-/- ~.~._ ?J DAY DESCRiRTION OF WORK cos~c~o~ ~ ~ ~os PB~ (R~) ~T TAG (~} - DATE KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC~ - SCA# IFIE~ COST EST. I,,,CCU~UL~','a COST TIME OSCO IOL~ ~0~'7 ~8 II~$ II$I IIqO / /~/q 115B i LOG ENTRY TP - ~Iq4 0,153 00 TP- 54130/5730 T°- 571o8/~cl,5'0 ~P- (~0~,o/ qq50 7 "- suu4/$~'lcf. q"-3u¢/.Jas/o. . q'-ss/o/ss~9. , '7 "- 3*1'I8 /3¢oq , 7"- ~$~ /s~ .OUT o78~ BSh. x~rO 3~086/. /Oppn ~h8 ~eT'nGE. ff)nx.n/~ss, o8$£~vEb ~z/OO.=lb Pt~l$14 Pl. lff~PS RMb ,.,CLIflF.'qCE LI,UES ~ ~D.b. ,E'.~,~C E~UIDmEMT. IO PPA ~T~E ~a,/z8 P,~oP. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~c,$1ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1' Status of Well Classification of Service Well OIL ~] GAS [-~ SUSPENDED [---'] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 93-195 3 Address 8 APINumber P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22432 4 LocaUon of well at surface ~- ................. '~ 9 Unit or Lease Name 985' FNL' 1612' FEL' SEC 25' T 13' R SE' UM i''-~--- --'~"'- "(::~/' ~"~ .... }'~i ~ 10 WelIKU PARUK RIVERNumber At Top Producing Interval At Total Depth '~, '~.~. ~ 11 Field and Pool 1375' FSL, 532' FEL, SEC 27, T 13, R 8E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. RKB 68', PAD 27' GLI ADL 25524 ALK 2655 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 16 No. of Completions 17-Jan-94 25-Jan-94 04/23/94(RR)Perfed 06/30/94.I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set J 21 Thickness of permafrost 12490' MD, 6361' TVD 12382' MD, 6286' TVD YES LX] NO ] J 1949' feet MDJ 1800' APPROX 22 Type Electdc or Other Logs Run LWD LOGS, CBT, USIT, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16. 62.5# H-40 SURF 121' 24" 452 SX ASI CMT 9.625 47#/36# L-80/J-55 SURF 5310' 12.25" 1100 SX ASIII CMT, 600 SX G CMT 7. 26# L-80 SURF 12470' 8.5" 250 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) 3-1/2" 9.3# L-80 12049' 12024' 12208'-12230' @ 4 spf md 6164'-6179' tvd 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC *Perfed w/2-1/2" ~tan gun O6/30/94. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 15 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA RECEIVED jul_ -'6 'i99q. ~_~..~k~ Oi! & Gas Cons, Commission Anchorage Form 10-407 Submit In duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 12127' 6106' BASE KUPARUK C 12158' 6128' NA TOP KUPARUK A 12158' 6128' BASE KUPARUK A 12264' 6203' .......,. ., · - 31. LIST OF ATTACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed,.. :~~'~. Title ~.,~ ~p,_~ C~l DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIO PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3M-24 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25524 ALK 2655 50-029-22432 93-195 ACCEPT: 01/17/94 12:00 SPUD: 01/17/94 12:30 RELEASE: 04/23/94 03:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 01/17/94 ( 1) PARKER 245 TD: 121' ( 121) MOVE RIG OVER 3M-24 MOVE RIG F/3M-26 TO 3M-24 MW: 0.0 VIS: 0 01/18/94 ( 2) PARKER 245 TD- 3060' ( 2939) 01/19/94 ( 3) PARKER 245 TD: 4850' (1790) 01/20/94 ( 4) PARKER 245 TD: 5330' ( 480) 01/21/94 ( 5) PARKER 245 TD- 5330'( o) DRILL 12.25" HOLE 16"@ 121' MW: 9.9 VIS: 60 NU DIVERTER & DIVERTER LINES. ACCEPT RIG @ 0600 HRS 01/17/94. FUNCITON TEST DIVERTER & ACCUM. JERRY HERRING W/AOGCC WAIVED WITNESSING TEST. MU BHA #1. ORIENT TOOLS & CLEAN OUT COND. SPUD & DRILL 12.25" HOLE F/121'-283' SERV RIG & TOP DRIVE. DRILL 12.25" HOLE F/283'-3060' RUN GYRO SURV AS NEEDED. DRILL 12.25" HOLE 9-5/8"@ 5310' MW:10.1 VIS: 49 CBU & PMP PILL. SHORT TRIP 20 STDS. TIH, FILL PIPE. DRILL 12.25" HOLE F/3060'-3766' SERVICE RIG & TOP DRIVE. DRILL 12.25" HOLE F/3766'-4726' CBU @ 4726'-MOTOR FAILED. POOH-TIGHT IN SPOTS. LD NAVIDRILL. PU NAVIDRILL & ORIENT TOOLS. TIH-TIGHT F/2687'-3344' DRILL 12.25" HOLE F/4726'-4850' RUN 9-5/8" CSG-CIRC 9-5/8"@ 5310' MW:10.1 VIS- 42 DRILL 12.25" HOLE F/4850'-5330' CBU. MONITOR-PMP SLUG. SHORT TRIP-HOLE TIGHT IN SPOTS. TIH. CIRC & COND MUD-PMP PILL. POOH-TIGHT. LD JARS-PU JARS. LD BHA & CLEAR ALL SUBS OFF FLOOR. RU TO RUN 9-5/8" CSG. HOLD SAFETY MEETING. RUN 9-5/8" CSG. CIRC & COND MUD W/9-5/8" @ 2500' WORK & WASHED F/2790'-2950' RUN 9-5/8" CSG. LD HGR. NU CMT HEAD. CIRC & COND HOLE. TIH 9-5/8"@ 5310' MW: 8.4 VIS' 28 CMT 9-5/8" CSG-CIP @ 0912 HRS 01/20/94. FLUSHED & ND DIVERTER-MU SPD HD 20K FT LB. NU BOPE. RU TEST EQUIP. TEST BOPE. RD TEST EQUIP. INSTALL WEAR BUSHING. PU BHA-ORIENT & PROGRAM TOOL. TIH & CHECK TOOLS-LWD NOT WORKING. POOH-RETRIEVE SOURCE-LD LWD-PU LWD. PU & ORIENT BHA-TEST LWD-PLACED RA SOURCE IN LWD. TIH. TEST MWD @ HWDP. ECFIVE,r) WELL: 3M-24 API: 50-029-22432 PERMIT: 93-195 PAGE: 2 01/22/94 ( 6) PARKER 245 TD: 9500' (4170) 01/23/94 ( 7) PARKER 245 TD: 9500'( o) 01/24/94 ( 8) PARKER 245 TD:12136' (2636) 01/25/94 ( 9) PARKER 245 TD:12490' ( 354) 01/26/94 (10) PARKER 245 TD:12490' ( o) 01/27/94 (11) PARKER 245 TD:12490' ( o) DRILL 8.5" HOLE 9-5/8"@ 5310' MW: 9.0 VIS: 32 WASHED F/5179'-5288' TAG PLUG. CBU. PEFORM CSG TEST TO 2000#-NO PRESS LOSS. DRILL PLUGS, FLOATS, CTM & 10' NEW HOLE TO 5340' CBU. PERFORM EMW 8.8 PPG W/675 PSI=12.7 PG. DRILL 8.~" HOLE F/5340'-6250' SERV RIG. DRILL 8.5" HOLE F/6250'-9500' 9-5/8"@ 5310' MW:ll.0 VIS: 39 DRILL F/9500 TO 10533', SERVICE RIG, DRILL F/10533 TO 11570', LOST POWER F/ARCO FACILITY-SWITCH TO RIG POWER, DRILL F/11570 TO 11980' DRLG 8-1/2" HOLE 9-5/8"@ 5310' MW:ll.3 VIS: 43 DRILL 8.5" HOLE F/11980'-11988'. CBU-MONITOR HOLE. TOH TO 9-5/8" SHOE-NO TIGHT SPOTS. CUT DRILL LINE. RESET DUO-MATIC. SERV TOP DRIVE. TIH-FILL PIPE @ 8647'-FIN TIH T/ll917'-FILL PIPE-TIGHT @ ll917'-BROKE STD BUT UNABLE TO STD BACK-GRABS FROZEN-LAYED BACK ONE JT DP. THAW ACTUATOR ON TOP DRIVE. DRILL 8.5" HOLE F/11988'-12136' SLOW PENETRATION RATE. MONITOR HOLE-PMP PILL. TOH-RETRIEVE RA SOURCE-LD LWD & MWD. COND MUD & HOLE 9-5/8"@ 5310' MW:ll.3 VIS: 40 PU LWD, MWD, TEST-SET RA SOURCE, TEST @ HWDP, TIH, FILL PIPE @ 9-5/8" SHOE AT 8700', FILL PIPE AND REAM F/12061-12136 @ 200-250'/HR F/LOGS, DRLG 8-1/2" HOLE F/12136-12162'-CK FOR FLOW, NO FLOW, DRLG F/12162-12490'-CK FLOW, NO FLOW, CIRC & MONITOR HOLE, PUMP PILL, SHORT TRIP TO 8000'-MONITOR HOLE-TIH, FILL PIPE @ 10200', CIRC & MONITOR HOLE CIRC HOLE CLEAN & COND MUD 9-5/8"@ 5310' MW:ll.4 VIS: 42 CIRC & COND MUD, MUD CUT TO 9.9 PPG, INCREASE WT TO 11.5 PPG, POOH, LD BHA & RETRIEVE SOURCE. PULL WEAR RING, RU CSG TOOLS & HOLD SAFETY MTG, RUN 7" 26#, L-80, BTC-MOD CASING, REPAIR HYDRAULIC LINE ON LAY DOWN MACHINE, CONTINUE TO RUN 7", 26#, L-80 CSG, CBU @ 9-5/8" SHOE & @ 8900', CIRC @ 7 BPM W/NO LOSSES. RUN TOTAL OF 290 JTS & MARKER JT. SET SHOE @ 12470', CIRC HOLE CLEAN & COND MUD FOR CMT JOB. FINAL REPORT 7"@12470' MW:ll.4 VIS: 0 CIRC & COND MUD @ 6 BPM W/1200 PSI. PMP A TOTAL OF 840 BBLS. RU DOWELL. CMT W/250 SX CLASS G CMT. BMP PLUG. FLOATS HELD. CIP @ 1005 HRS. FULL RETURNS. PIPE STUCK ON BTM & COULD NOT RECIP-PULLED 500K. PU BOPE & ATTEMPT TO SET SLIPS-WOULD NOT HOLD CSG. WAIT ON NEW SET & INSTALL SAME W/280,000# ON WEIGHT INDICATOR. MAKE ROUGH CUT ON 7" CSG. ND BOPE & SET BACK ON STUMP. MAKE FINAL CUT ON 7" CSG, NU TBG HEAD. TEST TO 3000 PSI-OK. FREEZE PROTECT W/100 BBLS WATER & 70 BBLS DIESEL. RELEASE RIG @ 2100 HRS 01/26/94. WELL: 3M-24 API: 50-029-22432 PERMIT: 93-195 PAGE: 3 02/10/94 (12) DOWELL TD:12490 PERFORM ARCTIC PACK ON 3M-24. 7"@12470' 04/22/94 (13) NORDIC 1 TD:12490 PB:12382 04/23/94 (14) NORDIC 1 TD:12490 PB:12382 RIH W/PERF GUN 7"@12470' MW: 0.0 MOVED RIG F/3M-28 TO 3M-24. ACCEPTED RIG @ 1930 HRS 04/21/94. LEVEL RIG, ND DRY HOLE TREE. SET TEST PLUG. NU BOP, TEST ALL TO 3500 PSI. TESTED 7" CSG TO 3500 PSI F/30 MIN. LOST 50 PSI IN 30 MIN. RU SWS. TEST LUB TO 1000 PSI. PU 4-1/2" CSG GUN & RIH. SET DOWN @ 8100' WORKED PERF GUN F/8100'-9615' RIG RELEASED 7"@12470' MW: 0.0 CONT ATTEMPT TO RIH W/PERF GUNS. WORK GUN F/9615'-9764' POOH & DISARM GUNS. RD SCHLUMBERGER. RU FLOW RISER & TONGS TO RUN COMP ASSY. RUN A TOTAL OF 373 JTS 3-1/2" 9.3# L-80 MOD 8RD TBG. TEST ANN & TBG. TEST TREE TO 250/5000 PSI. RELEASE RIG @ 0330 HRS 04/23/94. * WELL WILL BE PERF THROUGH TBG AT A LATER DATE. SIGNATURE: DATE: Date: 07/01/94 Page: 1 ARCO ALASKA INC. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL:3M-24 TYPE:DEV AFENO:AK7698 DESC:DC+P AFENO:998231 DESC:FRACTURE ACCEPT: CODE:3 07/01/94 (15) TD:12490 PB:12382 SUPV:TA RD & SECURE WELL 7"@12470 MW: 0.0 RU E-LINE. TEST BOP & LUB TO 1500 PSI-OK. RIH W/2-1/2" TITAN GUN, 4 SPF 180 DEG BIG HOLE. TIE INTO SCHLUMBERGER CET DATED 01/29/94. PRESS TBG TO 250 PSI FOR 1000 PSI UNDERBALANCE. PERF A-1 SAND F/12208'-12230'. NO PRESS CHANGE ON TBG. POOH. ASF. RD & SECURE WELL. SUB. SURFACE DIRECTIONAL I~UIDANCE SURVEY [~]ONTINUOUS 1'TJooL Company ARCO ALASKA, INC. . Well Name 3~-z4 (985'FNL, 1612'FEL, SEC 25, T:].3N, R8E, IJH)_ FieldlLocation KUPARUK, NORTi] SLOPE, ALASKA Job Reference No. Date 94044 30-JAN- 1994 Lo~3ged By: Computed By.' FORMICA SINES ~ SCHLLJIvlBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 30-JAN-1994 ENGINEER FORMICA METHODS OF COMPUTATION TOOL LOCATION MINIMUM CURVATURE INTERPOLATION. LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 72 DEG 42 MIN WEST COMPUTATION DATE' 17-FEB-94 PAGE I ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 30-JAN-1994 KELLY BUSHING ELEVATION' 68.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET Of MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOLFFH EAST/WEST DIST. AZIMLrTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 99 91 199 89 299 87 399 84 499 80 599 77 699 41 798 36 896 11 -68 O0 31 91 131 89 231 87 331 84 431 80 S31 77 631 41 730 828 0 0 N 0 0 E 0 50 N 49 9 E 1 3 N 40 35 E 1 15 N 34 2 E I 32 N 31 30 E 1 31 N 29 42 E 2 22 N 68 44 W 6 31 S 83 30 W 36 10 12 S 73 55 W 11 14 16 S 72 15 W 0 O0 -0 5O -1 95 -3 61 -5 50 -7 50 -7 94 '-0 18 14 06 35 07 0 O0 0 01 0 O0 0 O0 0 O0 0 O0 0 O3 0 O5 0 O4 0 O2 0 O0 N 0 46 N 1 63 N 3 28 N 5 33 N 7 65 N 9 63 N 9 71N 6 71N 0 49 N 0 O0 E 0 38 E 1 53 E 2 76 E 4 10 E 5 47 E 5 32 E 2 84W 16 82 W 36 89 W 000 N 0 0 E 0 2 4 6 9 11 10 18 36 59 N 39 24 E 24 N 43 20 E 29 N 4O 6 E 72 N 37 33 E 40 N 35 36 E O0 N 28 55 E 12 N 16 18 W 11 N 68 14 W 89 N 89 15 W 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 992 26 O0 1087 O0 1181 O0 1274 O0 1365 O0 1453 O0 1538 O0 1622 O0 1705 O0 1786.26 1718 924.26 17 10 30 1019 30 18 42 55 1113 39 1206 23 1297 53 1385 96 1470 80 1554 79 1637 S 72 4 W S 71 49 W 55 20 41 S 74 22 W 39 23 0 S 76 38 W 23 26 22 S 77 9 W 53 29 48 S 74 55 W 96 32 41 S 75 18 W 80 33 22 S 75 6 W 79 34 41 S 74 17 W 26 38 11 S 73 25 W 62.48 93.58 126.98 164 08 205 72 252 52 304 43 358 88 414 64 473 96 0 04 0 02 0 02 0 02 0 03 0 03 0 03 0 03 0 02 0 02 7.93 S 62 98 W 52 W 94 44 W 127 39 W 164 17 W 206 65 W 253 84 W 305 55 W 359 17.63 S 92 27.47 S 124 36 78 S 160 45 89 S 201 57 25 S 246 70 68 S 296 84 55 S 349 99 26 S 403 115 90 S 460 63 47 S 82 49 W 19 S 79 13 W 44 S 77 33 W 56 S 77 5 W 34 S 77 9 W 21 S 76 56 W 14 S 76 36 W 63 S 76 24 W 37 W 415.41 S 76 10 W 32 W 474.68 S 75 52 W 2000 O0 1862 85 1794 85 41 48 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1934 O0 2002 O0 2065 O0 2124 O0 2180 O0 2233 O0 228O O0 2323 O0 2362 90 1866 42 1934 27 1997 55 2056 90 2112 37 2165 51 2212 29 2255 61 2294 90 45 35 42 49 16 27 52 29 55 54 33 90 56 56 37 59 59 51 63 29 29 66 9 61 66 57 S 72 47 W 538 21 S 72 48 W 607 53 S 73 59 W 681 25 S 74 34 W 758 98 S 74 33 W 839 45 S 72 55 W 922 03 S 71 35 W 1007 14 S 71 54 W 1095.29 S 72 2 W 1185.66 S 72 4 W 1277.59 0 O3 0 O4 0 O4 0 O4 0 O3 0 0 0 0 0 O1 02 03 03 03 134 62 S 521 78 W 538.87 S 75 32 W 155 176 197 218 241 267 295 323 351 23 S 587 34 S 658 28 S 733 52 S 811 51S 890 72 S 971 61S 1055 42 S 1141 83 S 1228 97 W 608 11 S 75 13 W 60 W 681 49 W 759 17 W 840 50 W 922 47 W 1007 11W 1095 11W 1186 55 W 1277 80 S 75 I W 56 S 74 57 W 08 S 74 55 W 67 S 74 50 W 69 S 74 36 W 74 S 74 21W 05 S 74 11W 93 S 74 I W 3000 O0 2401 97 2333 97 66 40 3100 O0 2441 3200 O0 2478 3300 O0 2515 3400 O0 2553 3500 O0 2591 3600 O0 2630 3700.00 2670 3800.00 2707 3900.00 2742 29 2373 37 2410 54 2447 17 2485 82 2523 89 2562 22 2602 11 2639 85 2674 29 67 42 37 68 15 54 67 57 17 67 27 82 67 21 89 66 48 22 66 55 11 69 19 85 68 44 S 72 15 W 1369 52 S 71 40 W 1461 45 S 71 8 W 1554 30 S 71 3 W 1647 10 S 71 4 W 1739 70 S 70 53 W 1831 89 S 70 46 W 1923 89 S 70 45 W 2015.78 S 71 14 W 2108.68 S 71 10 W 2202.04 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O0 0 O1 0 O1 380 02 S 1316 05 W 1369 82 S 73 54 W 408 31 S 1403 53 W 1461 438 10 S 1491 49 W 1554 468 16 S 1579 33 W 1647 498 28 S 1666 94 W 1739 528 35 S 1754 13 W 1831 558 57 S 1841 08 W 1923 588 93 S 1927.86 W 2015 619.18 S 2015.74 W 2108 649.22 S 2104.17 W 2202 71 S 73 47 W 50 S 73 38 W 25 S 73 29 W 82 S 73 21W 97 S 73 14 W 95 S 73 7 W 81 S 73 1W 69 S 72 55 W 05 S 72 51W COMPUTATION DATE' 17-FEB-94 PAGE 2 ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY- 30-JAN-1994 KELLY BUSHING ELEVATION' 68.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 2779 47 2711.47 68 15 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 2817 O0 2856 O0 2896 O0 2935 O0 2974 O0 3011 O0 3050 O0 3089 O0 3128 04 2749.04 67 31 20 2788.20 66 32 42 2828.42 66 37 28 2867 28 67 9 11 2906 11 67 39 98 2943 98 67 27 56 2982 56 67 8 60 3021 60 66 57 36 3060 36 67 39 S 71 5 W 2295.06 S 70 48 W 2387 68 S 70 28 W 2479 S 70 43 W 2571 S 71 7 W 2663 S 71 19 W 2755 S 71 34 W 2847 S 71 30 W 2940 S 71 10 W 3032 S 71 27 W 3124 63 12 22 33 87 11 14 29 0 01 0 O0 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O0 0 O1 679 39 S 2192 20 W 2295 06 S 72 47 W 7O9 740 770 800 830 860 889 918 948 71S 2279 28 S 2366 80 S 2452 90 S 2539 66 S 2627 05 S 2714 31S 2802 77 S 2889 46 S 2976 77 W 2387 55 W 2479 87 W 2571 96 W 2663 17 W 2755 93 W 2847 43 W 2940 65 W 3032 92 W 3124 68 S 72 42 W 64 S 72 38 W 13 S 72 33 W 23 S 72 30 W 36 S 72 27 W 90 S 72 25 W 15 S 72 24 W 20 S 72 22 W 36 S 72 20 W 5000 O0 3166 31 3098 31 67 26 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3205 O0 3243 O0 3281 O0 3319 O0 3358 O0 3396 O0 3434 O0 3472 O0 3509 10 3137 67 3175 53 3213 98 3251 27 3290 58 3328 73 3366 48 3404 91 3441 10 66 58 67 67 51 53 67 21 98 67 29 27 67 28 58 67 31 73 67 42 48 68 8 91 67 48 S 71 14 W 3216 79 S 71 22 W 3308 S 72 16 W 3401 S 71 46 W 3493 S 71 24 W 3586 S 72 24 W 3678 S 72 45 W 3770 S 72 24 W 3863 S 73 50 W 3955 S 74 3 W 4048 93 18 72 O2 38 75 18 78 48 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O0 0 O1 0 O1 978 03 S 3064 58 W 3216 86 S 72 18 W 1007 1036 1065 1094 1123 1150 1178 1205 1231 64 S 3151 57 S 3239 05 S 3327 41S 3415 46 S 35O2 92 S 3590 71S 3679 92 S 3767 32 S 3856 87 W 3309 48 W 3401 54 W 3493 06 W 3586 75 W 3678 95 W 3770 10 W 3863 62 W 3955 80 W 4048 02 S 72 16 W 28 S 72 15 W 83 S 72 15 W 14 S 72 14 W 51 S 72 13 W 88 S 72 14 W 31 S 72 14 W 90 S 72 15 W 59 S 72 18 W 6000 O0 3548 06 3480 06 67 24 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 3586 O0 3624 O0 3663 O0 3700 O0 3737 O0 3776 O0 3816 O0 3857 O0 3898 59 3518 64 3556 15 3595 62 3632 81 3669 68 3708 76 3748 49 3789 27 3830 59 67 35 64 67 30 15 67 18 62 68 27 81 67 42 68 66 39 76 66 6 49 65 51 27 66 22 S 73 45 W 4140 90 S 75 55 W 4233 S 75 56 W 4325 S 75 39 W 4417 S 76 27 W 4510 S 75 28 W 4602 S 74 35 W 4694 S 73 38 W 4786 S 72 54 W 4877 S 74 8 W 4969 11 43 59 13 80 86 45 77 07 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 1256 gg S 3945 60 W 4140 99 S 72 20 W 1281 1303 1326 1348 1370 1394 1419 1446 1472 27 S 4034 55 S 4124 29 S 4213 38 S 43O3 91S 4393 72 S 4482 84 S 4571 20 S 4658 48 S 4745 62 W 4233 37 W 4325 81W 4417 86 W 4510 90 W 4602 91W 4694 01W 4786 45 W 4877 89 W 4969 18 S 72 23 W 47 S 72 28 W 61 S 72 32 W 13 S 72 36 W 80 S 72 40 W 86 S 72 43 W 45 S 72 45 W 78 S 72 45 W 07 S 72 46 W 7000.00 3937 89 3869 89 66 48 7100.00 3977 43 3909 7200.00 4016 16 3948 7300.00 4053 23 3985 7400.00 4091 58 4023 7500.00 4130 37 4062 7600.00 4168 88 4100 7700.00 4206 74 4138 7800.00 4243.35 4175 7900.00 4279.87 4211 43 66 41 16 68 4 23 67 58 58 66 58 37 67 15 88 67 30 74 68 4 35 68 39 87 68 32 S 74 33 W 5060 84 S 74 22 W 5152 S 75 13 W 5244 S 75 17 W 5337 S 74 25 W 5429 S 75 38 W 5521 S 75 23 W 5614 S 75 3 W 5706 S 74 50 W 5799 S 74 54 W 5892 65 79 56 84 95 13 59 58 61 0 O1 0 O1 0 O1 0 O1 0 O1 00l 0 O1 0 O1 0 O1 0 O1 1496 98 S 4834 38 W 5060 85 S 72 48 W 1521 1546 1569 1593 1617 1640 1664 1688 1713 67 S 4922 09 S 5011 52 S 5101 63 S 5190 84 S 5279 86 S 5369 51S 5458 66 S 5548 02 S 5638 85 W 5152 75 W 5244 62 W 5337 77 W 5429 70 W 5522 07 W 5614 55 W 5706 42 W 5799 27 W 5892 66 S 72 49 W 81 S 72 51W 59 S 72 54 W 89 S 72 56 W O1 S 72 58 W 21 S 73 0 W 69 S 73 2 W 70 S 73 4 W 75 S 73 6 W COMPUTATION DATE' 1?-FEB-94 PAGE 3 ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 30-JAN-1994 KELLY BUSHING ELEVATION- 68.00 FT ENGINEER' FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOO FEET FEET FEET DEG MIN 8000 O0 4316 73 4248 73 68 22 8100 8200 8300 8400 8500 86OO 8700 8800 8900 O0 4353 O0 4390 O0 4427 O0 4465 O0 4503 O0 4541 O0 4579 O0 4617 O0 4652 45 4285 41 4322 59 4359 68 4397 84 4435 66 4473 91 4511 17 4549 88 4584 45 68 30 41 68 18 59 67 47 68 67 32 84 67 44 66 67 43 91 67 38 17 68 48 88 69 9 S 74 51W 5985 50 S 74 43 W 6078 S 74 24 W 6171 S 74 37 W 6264 S 75 2 W 6356 S 75 17 W 6448 S 75 23 W 6541 S 75 20 W 6633 S 75 4 W 6726 S 74 50 W 6819 45 32 11 5O 85 33 63 33 67 0 O0 0 O0 0 O0 0 O0 0 O1 0 01 0 O0 0 O0 0 O1 0 O1 1737.23 S 5728 02 W 5985 66 S 73 8 W 1761.67 S 5817 1786.41 S 5907 1811.40 S 5996 1835.39 S 6086 1859.18 S 6175 1882.64 S 6264 1905.99 S 6354 1929.66 S 6444 1953.96 S 6534 77 W 6078 33 W 6171 73 W 6264 03 W 6356 35 W 6449 90 W 6541 30 W 6633 02 W 6726 21W 6820 64 S 73 9 W 53 S 73 10 W 34 S 73 12 W' 76 S 73 13 W 15 S 73 15 W 66 S 73 16 W 99 S 73 18 W 74 S 73 20 W 11 S 73 21W go00 O0 4688 49 4620 49 69 4 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 4723 O0 4757 O0 4792 O0 4826 O0 4862 O0 4897 O0 4932 O0 4967 O0 5004 40 4655 64 4689 04 4724 86 4758 36 4794 75 4829 94 4864 98 4899 76 4936 40 69 54 64 70 1 04 69 41 86 69 36 36 69 13 75 69 19 94 69 36 98 69 28 76 67 33 S 74 29 W 6913.06 S 72 41W 7006.75 S 72 21W 7100.70 S 71 53 W 7194.60 S 71 41W 7288.32 S 71 26 W 7381.79 S 71 14 W 7475.29 S 70 57 W 7568.86 S 70 34 W 7662.46 S 71 36 W 7755.40 0 O1 0 O1 0 O1 0 O1 0 O0 0 O1 0 O1 0 O0 0 O0 0 O1 1978 60 S 6624.35 W 6913 53 S 73 22 W 2005 2033 2062 2091 2121 2151 2181 2212 2242 17 S 6714.21 W 7007 45 S 6803.80 W 7101 25 S 6893 18 W 7195 54 S 6982 22 W 7288 13 S 7070 90 W 7382 08 S 7159 50 W 7475 41 S 7248 06 W 7569 36 S 7336 46 W 7662 54 S 7424 40 W 7755 23 S 73 22 W 17 S 73 22 W 05 S 73 21W 76 S 73 19 W 20 S 73 18 W 67 S 73 17 W 21 S 73 15 W 78 S 73 13 W 69 S 73 12 W 10000 O0 5042 67 4974 67 67 46 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 5080 O0 5118 O0 5156 O0 5194 O0 5232 O0 5271 O0 5311 O0 5350 O0 5389 43 5012 13 5050 20 5088 05 5126 64 5164 96 5203 23 5243 38 5282 57 5321 43 67 53 13 67 37 20 67 41 05 67 52 64 66 48 96 66 48 23 67 7 38 66 59 57 66 50 S 71 21W 7847 92 S 70 57 W 7940 S 7O 48 W 8O33 S 7O 45 W 8125 S 70 29 W 8217 S 71 18 W 8310 S 71 8 W 8402 S 70 52 W 8494 S 70 36 W 8585 S 70 24 W 8677 48 06 47 97 18 09 02 98 91 0 O1 0 O0 0 O1 0 O1 0 O0 0 O1 0 O1 0 O0 0 O0 0 O1 2271.96 S 7512 14 W 7848 19 S 73 10 W 2301.89 S 7599 2332.23 S 7687 2362 67 S 7774 2393 39 S 7861 2423 54 S 7949 2453 21S 8036 2483 09 S 8123 2513 47 S 8209 2544 23 S 8296 76 W 7940 28 W 8033 59 W 8125 90 W 8218 09 W 8310 11W 8402 09 W 8494 95 W 8586 65 W 8677 73 S 73 9 W 28 S 73 7 W 67 S 73 6 W 14 S 73 4 W 33 S 73 3 W 22 S 73 I W 14 S 73 0 W 08 S 72 59 W 99 S 72 57 W 11000.00 5429 17 5361 17 65 43 11100.00 5472 11 5404 11200.00 5519 78 5451 11300.00 5572 70 5504 11400.00 5629 28 5561 11500.00 5687 92 5619 11600.00 5747 57 5679 11700.00 5809 96 5741 11800.00 5876.20 5808 11900.00 5946.11 5878 11 63 14 78 59 51 70 56 38 28 54 35 92 53 59 57 52 24 96 50 11 20 46 56 11 45 12 S 70 2 W 8769 65 S 69 40 W 8859 85 S 70 13 W 8947 63 S 70 51W 9032 42 S 71 4 W 9114 82 S 70 59 W 9195 78 S 71 I W 9276.00 S 72 0 W 9354.12 S 73 31 W 9429.01 S 73 51 W 9500.49 0 O1 0 02 0 03 0 03 0 03 0 02 00l 0 O1 0 O2 0 O3 2575 32 S 8383 05 W 8769 71 S 72 55 W 26O6 2636 2664 2691 2717 2744 2769 2790 2810 29 S 8467 88 W 8859 51 S 8550 41 W 8947 37 S 8630 54 W 9032 53 S 8708 39 W 9114 81S 8785 O0 W 9195 05 S 8860.85 W 9276 03 S 8934.89 W 9354 94 S 9006.51 W 9429 9O S 72 54 W 67 S 72 52 W 45 S 72 51W 84 S 72 49 W 8O S 72 49 W O1 S 72 48 W 13 S 72 47 W 02 S 72 47 W 96 S 9075.13 W 9500.50 S 72 47 W COMPUTATION DATE: 1T-FEB-94 PAGE 4 ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA · DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000 O0 6016.59 5948.59 45 11 S 74 0 W 9571 42 12100 O0 6087.18 6019.18 45 2 S 74 54 W 9642 22 12200 O0 6157.75 6089.75 45 15 S 75 13 W 9713 O1 12300 O0 6228.11 6160.11 45 25 S 75 25 W 9784 O0 12400 O0 6298.29 6230.29 45 30 S 75 41 W 9855 19 12490 O0 6361.37 6293.37 45 30 S 75 41 W 9919 31 0.02 2830.69 S 9143 27 W 9571 43 S 72 48 W 0.01 2849.82 S 9211 47 W 9642 23 S 72 49 W 0.00 2867.93 S 9279 98 W 9713 03 S 72 50 W 0.01 2886.18 S 9348 65 W 9784 03 S 72 51W 0.00 2903.75 S 9417 74 W 9855 23 S 72 52 W 0.00 2919.63 S 9479 95 W 9919 36 S 72 53 W ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 0 O0 -68.00 0 0 1000 O0 992 26 924.26 17 10 2000 O0 1862 85 1794.85 41 48 COMPUTATION DATE: 17-FEB-94 PAGE 5 DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0 O0 0 O0 0 O0 N 0 O0 E 0 O0 N 0 0 E S 72 4 W 62 48 0 04 7 93 S 62 98 W 63 47 S 82 49 W S 72 47 W 538 21 0 03 134 62 S 521 78 W 538 87 S 75 32 W 3000 4000 5000 6000 7000 8000 9000 O0 2401 O0 2779 O0 3166 O0 3548 O0 3937 O0 4316 O0 4688 97 2333.97 66 40 47 2711.47 68 15 31 3098.31 67 26 06 3480.06 67 24 89 3869.89 66 48 73 4248.73 68 22 49 4620.49 69 4 S 72 15 W 1369 S 71 5 W 2295 S 71 14 W 3216 S 73 45 W 4140 S 74 33 W 5060 S 74 51W 5985 S 74 29 W 6913 52 0 06 0 79 0 9O 0 84 0 50 0 06 0 01 380 O1 679 O1 978 O1 1256 O1 1496 O0 1737 O1 1978 02 S 1316 39 S 2192 03 S 3064 99 S 3945 98 S 4834 23 S 5728 60 S 6624 05 W 1359 2O W 2295 58 W 3216 60 W 4140 38 W 5060 02 W 5985 35 W 6913 82 S 73 54 W 06 S 72 47 W 86 S 72 18 W 99 S 72 2O W 85 S 72 48 W 66 S 73 8 W 53 S 73 22 W 10000.00 5042.67 4974.67 67 46 11000.00 5429.17 5361.17 65 43 12000.00 6016.59 5948.59 45 11 12490.00 6361.37 6293.37 45 30 S 71 21 W 7847.92 S 70 2 W 8769.65 S 74 0 W 9571.42 S 75 41 W 9919.31 0.01 0.01 0.02 0. O0 2271.96 S 7512.14 W 7848.19 S 73 10 W 2575.32 S 8383.05 W 8769.71 S 72 55 W 2830.69 S 9143.27 W 9571.43 S 72 48 W 2919.63 S 9479.95 W 9919.36 S 72 53 W COMPUTATION DATE' 17-FEB-94 PAGE 6 ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 30-JAN-1994 KELLY BUSHING ELEVATION' 68.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN -68 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 80O 0 0 N 0 0 E 0 26 N 44 47 E 0 58 N 43 43 E 1 15 N 34 53 E 1 27 N 32 16 E I 32 N 30 32 E I 9 N 14 38 W 5 37 S 86 31W 8 58 S 75 57 W O0 12 51 S 72 25 W 0 O0 68 09 168 10 268 12 368 15 468 18 568 21 668 41 769 21 871 07 0 O0 68 O0 168 O0 268 O0 368 O0 468 O0 568 O0 668 O0 768.00 868.00 968.00 63 1068 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 16 47 O0 18 35 O0 20 19 O0 22 46 O0 26 28 O0 30 16 O0 32 55 O0 33 54 O0 37 28 O0 42 4 S 72 3 W S 71 41W S 73 55 W S 76 26 W S 77 5 W S 74 50 W S 75 21W S 74 42 W S 73 29 W S 72 45 W ENGINEER' FORMICA 53 1168 06 1268 10 1368 70 1468 54 1568 26 1668 90 1768 93 1868 974 63 1079 1185 1293 1403 1516 1634 1754 1876 2006 2148 11 1968 O0 1900 O0 47 36 O0 2OOO O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 OO 2700 O0 2800 O0 52 38 O0 56 16 O0 62 38 O0 66 54 O0 68 23 O0 67 7 O0 66 54 O0 68 26 O0 66 16 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 2304 2476 2672 2913 3171 3438 3694 3968 4229 50 2068 55 2168 38 2268 77 2368 95 2468 39 2568 33 2668 94 2768 48 2868 4483 98 2968 O0 2900 O0 67 22 O0 3OOO O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 67 2 O0 67 25 O0 67 45 O0 67 30 O0 68 2 O0 67 14 O0 67 27 O0 66 47 O0 65 47 0. O0 -0.12 -1.47 -3 O7 -4 86 -6 87 -8 41 '-3 44 8 96 28 23 55 O8 87 07 121 91 161 38 207 10 260 85 323 12 388 88 459 81 542 85 S 73 20 W 642.44 S 74 35 W 762.56 S 73 31W 902.45 S 71 36 W 1070.67 S 72 5 W 1290.27 S 71 10 W 1528.24 S 70 59 W 1775.10 S 70 45 W 2010.57 S 71 2 W 2266.20 S 70 29 W 2506.63 4744 5004 5264 5525 5788 6051 6312 6578 6825 S 71 13 W 2740 53 79 3068 39 3168 53 3268 42 3368 03 3468 59 3568 65 3668 05 3768 66 3868 35 84 94 86 68 47 26 71 18 S 71 23 W 2981 S 71 14 W 3220 S 72 2 W 346O S 72 40 W 3701 S 73 35 W 3944 S 74 43 W 4188 S 75 48 W 4429 S 74 46 W 4674 S 72 52 W 4901 0 O0 0 01 0 01 0 O0 0 O0 0 01 0 01 0 06 0 04 0 03 0.00 N 0 18 N 1 21 N 2 71 N 4 62 N 6 91 N 9 09 N 10 O0 N 804 N 2 57 N 0 O0 E 007 E 1 16 E 2 37 E 3 65 E 504 E 5 98 E 049 E 11 89 W 30 37 W 0.00 N 0 0 E 0.19 N 22 44 E 1.68 N 43 39 E 3.60 N 41 13 E 5 89 N 38 18 E 8 55 N 36 8 E 10 88 N 33 21E 10 02 N 2 49 E 14 36 N 55 55 W 30 48 N 85 10 W 0 O3 0 O2 0 O2 0 O2 0 03 0 O3 0 O3 0 O2 0 02 0 03 5 65 S 15 26 36 46 59 75 92 111 135 55 93 W 59 S 86 08 S 119 15 S 157 20 S 202 42 S 254 43 S 314 36 S 378 86 S 446 99 S 526 56 22 S 84 14 W 34 W 87 57 W 122 77 W 161 52 W 207 71W 261 94 W 323 53 W 389 75 W 460 22 W 543 74 S 79 46 W 38 S 77 42 W 86 S 77 6 W 72 S 77 9 W 55 S 76 52 W 85 S 76 32 W 64 S 76 17 W 54 S 75 57 W 51 S 75 31W 0 04 0 04 0 O1 0 03 0 03 0 O1 0 O1 0 O0 0 01 0 O1 165.42 S 621.36 W 643 O0 S 75 6 W 198 23 S 736.95 W 763 235 287 355 429 509 587 670 749 84 S 871.75 W 903 90 S 1031.73 W 1071 74 S 1240.61 W 1290 67 S 1466.83 W 1528 78 S 1700.43 W 1775 21 S 1922.94 W 2010 02 S 2164.89 W 2266 31S 2392.01W 2506 14 S 74 57 W 09 S 74 52 W 14 S 74 25 W 60 S 74 0 W 46 S 73 4O W 20 S 73 19 W 60 S 73 1W 21 S 72 48 W 63 S 72 36 W 0 01 0 O1 0 O1 0 01 0 O1 0 O1 0 01 0 O1 0 O1 0 O1 825.91 S 2613 14 W 2740 55 S 72 28 W 902.44 S 2841 54 W 2981 979 34 S 3068 42 W 3220 1054 87 S 3296 37 W 3461 1130 51S 3525 15 W 3701 1202 79 S 3756 97 W 3944 1270 O0 S 3991.37 W 4188 1329 16 S 4225.14 W 4429 1389 39 S 4463.46 W 4674 1453 09 S 4680.82 W 4901 40 S 72 23 W 92 S 72 18 W 04 S 72 15 W 99 S 72 13 W 81 S 72 15 W 55 S 72 21W 28 S 72 32 W 71 S 72 43 W 18 S 72 45 W COMPUTATION DATE: 17-FB-94 PAGE 7 ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEQ VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 7076 18 3968.00 3900 O0 66 40 7339 11 4068.00 4000 7597 71 4168.00 4100 7867 54 4268.00 4200 8139 50 4368.00 4300 8406 06 4468.00 4400 8668 85 4568.00 4500 8942.46 4668.00 4600 9230.27 4768.00 4700 9515.91 4868.00 4800 O0 67 38 O0 67 29 O0 68 34 O0 68 12 O0 67 32 O0 67 26 O0 69 10 O0 69 56 O0 69 14 S 74 21W 5130 79 S 75 2 W 5373 S 75 23 W 5612 S 74 51W 5862 S 74 37 W 6115 S 75 1W 6362 S 75 22 W 6604 S 74 45 W 6859 S 72 17 W 7129 S 71 24 W 7396 74 O1 42 15 10 87 32 14 66 0 O1 0 O1 0 O1 0 01 0 O0 0 O1 0 O0 0 O1 0 O1 0 O1 1515 77 S 4901 79 W 5130 80 S 72 49 W 1578 1640 1705 1771 1836 1898 1964 2042 2125 79 S 5136 62 W 5373 32 S 5367 02 W 5612 13 S 5609 10 W 5862 37 S 5853 19 W 6115 83 S 6091 44 W 6362 71 S 6326.45 W 6605 37 S 6572.50 W 6859 09 S 6830.90 W 7129 87 S 7085.00 W 7397 77 S 72 55 W O9 S 73 0 W 55 S 73 5 W 35 S 73 10 W 36 S 73 13 W 23 S 73 18 W 78 S 73 22 W 61 S 73 21W 07 S 73 18 W 9800 06 4968.00 4900.00 69 28 10067 10331 10589 10844 11090 11291 11466 11633.20 5768 11788.00 5868 02 5068 O0 5000.00 67 49 10 5168 95 5268 95 5368 79 5468 52 5568 14 5668 O0 5100.00 67 44 O0 5200.00 66 47 O0 5300 O0 66 56 O0 5400 O0 63 41 O0 5500 O0 56 55 O0 5600 O0 53 56 O0 5700 O0 51 40 O0 5800 O0 47 34 S 70 34 W 7662 52 S 71 5 W 7909 S 70 40 W 8154 S 71 9 W 8392 S 7O 3O W 8627 S 69 45 W 8851 S 70 56 W 9025 S 71 3 W 9168 S 71 12 W 9302 S 73 27 W 9420 94 24 86 3O 62 36 42 16 25 0 O0 0 O1 0 O0 0 O1 0 O1 0 O1 0 O3 0 o3 0 O1 0 O2 2212.38 S 7336 51W 7662.83 S 73 13 W 2291.95 S 7570 2372.18 S 7801 2450.23 S 8027 2527.26 S 8248 2603.43 S 8460 2662.05 S 8623 2708.90 S 8759 2752.52 S 8885 2788.45 S 8998 88 W 7910.20 S 73 9 W 75 W 8154.42 S 73 5 W 38 W 8393.00 S 73 2 W 93 W 8627.39 S 72 58 W 15 W 8851.67 S 72 54 W 87 W 9025.39 S 72 51W 11 W 9168.43 S 72 49 W 61 W 9302.17 S 72 47 W 10 W 9420.26 S 72 47 W 11931.04 5968.00 5900.00 45 8 12072.84 6068.00 6000.00 45 7 '12214.56 6168.00 6100.00 45 15 12356.77 6268.00 6200.00 45 30 12490.00 6361.37 6293.37 45 30 S 73 50 W 9522.50 S 74 28 W 9623.00 S 75 8 W 9723.34 S 75 41 W 9824.40 S 75 41 W 9919.31 O. 02 0.01 O. O0 O. O0 O. O0 2817.09 S 9096.28 W 9522.51 S 72 48 W 2844.75 S 9192.93 W 9623.02 S 72 48 W 2870.58 S 9289.97 W 9723.36 S 72 50 W 2896.13 S 9387.86 W 9824.44 S 72 51 W 2919.63 S 9479.95 W 9919.36 S 72 53 W COMPUTATION DATE: 17-FEB-94 PAGE 8 ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD 7" CASING DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : 985' FNL & 1612' FEL, SEC25 T13N RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 5310.00 12127.00 12158.00 12158.00 12264.00 12350.00 12382.00 12470.00 12490.00 3285 38 6106 26 6128 15 6128 15 6202 81 6263 17 6285 68 6347 35 6361 37 3217 38 6038 26 6060 15 6060 15 6134 81 6195 17 6217 68 6279 35 6293 37 1067 96 S 2854 75 S 2860 34 S 2860 34 S 2879 65 S 2895 08 S 2900 58 S 2916 10 S 2919 63 S 3336 30 W 9229 93 W 9251 16 W 9251 16 W 9323 89 W 9383 17 W 9405 3O W 9466 13 W 9479 95 W ARCO ALASKA, INC. 3M-24 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a COMPUTATION DATE: 17-FEB-94 PAGE 9 DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 ET ENGINEER: FORMICA ****~****** STRATIGRAPHIC SUMMARY ***~.~ SURFACE LOCATION = 985' FNL & 1612' FEL, SEC25 T13N R8E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 12127.00 6106.26 6038.26 2854,75 S 9229.93 W 12158.00 6128.15 6060.15 2860.34 S 9251.16 W 12158.00 6128.15 6060.15 2860,34 S 9251.16 W 12264.00 6202.81 6134.81 2879.65 S 9323.89 W 12490.00 6361.37 6293.37 2919.63 S 9479.95 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 12490.00 6361.37 6293.37 9919.36 S 72 53 W COMPANY ARCO ALASKA, INC. FIELD 3M-24 WELL KUPARUK RIVER COUNTRY USA RUN I DATE LOGGED 30-JAN-1994 REFERENCE 94044 All interpretations are opinions based on inferen, ces from ,electrical,or oth, er,,mea, sureme.n.ts .a, nd we ca?not, and d?, guarantee 1he accuracy or correctness of anylnterpretations, ana we sna~ nOT. except ~n tqe. case ,or gross, o.r negligence o? our pa~ I~. liable or .r. esponsi, bl,e for any,loss, .c..osts, damages or expenses ~curreg.~__s_u_s,~?_~o- a~rVe anyone resulti?g fro,m, any ,nterpr~eta~oq _maoe Dy a.n.,V or .o..u. r omcers, ~ge, n..? _o.r._e_m..~_l_o_y,e_e?:;. I_n~e_,s?~4n.~? ......... also suoject to our uenera~/erms ano ~,OnOloons as se[ out In ~uf cul/elll. [[JHu~ ~ELL: 3~_. -24 (985'FNL~ 16127FEL, SEC 25.. ..... '.3N, R8E, UM) HORIZONTAL PROJECTION 8000 6OOO 4OOO 2OOO -2000 -4000 -6000 SOUTH -8000 REF 94044 SCALE = I / 2000 ~N/~ ..... i .j ..i i..}.i-.i i .-.i...~.i-.i...i.i..~ ..... } .... i ...... }...i.~.~ ~..i ~..i ~ ~ i } .~ .i i i..i ~..L : !. ~ : : - : i .............. i..-~..t.--i-.i..i .... ;.-.~.-.~-.: ....... ~.--~-..~ ............ ~ ...... ~ ........ i ......... ~ ........ ~..~ ....... ~ ....... i..l ..... ;.;.;..~.:~;.;;. ........................................... ~:~- :~-~:, ---~-~ ~.}~.~ . . !:'!! !'!!'!"j'i'!"!"!'~'~'~'l'~'~"~"~ .... E'~'!"~ .... ~";~!'~!'~!''~i~ 'F"!i'!l'!':~"~'":'~:: }~ ' -. · ''' i '- -.-, !ii -i .... i-!',i · ii' -~i' · i ~i ~ ~ ' !...,..,..~..., ..... !...!...!...! . _ ........... ~.. ~i--'i"i ~'!"!'"!.:::: .:. !'"!"'!'! .... !"!'"i'"!":'"i"!"!! '!'!'"!'"! .... !"!'!! 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' ~' : ..... ! .... ~ ...... : -!:-t':j!--~---!--~l-.-~---~---~---! .... ~--:--?---? ....... ~---~-'-~--I---:--~--':--~ -:'--~--~ .... :'-r-.r~ .... ~":':--r-'-:-''~ ~:~'' ' · ' · !!-ii-.~i-,i--i-!--i--i--i-i-i-i.-!---!-.!---!--i--i--~.-i-i--.!-i .... ii--.i--i !-!.!!-.,ii-!i !i~.i~;~ ;-: ................................ :...:...:...: ...... :...:...:.:..;..:~.:..:...:...:..:.;..:..,:.:..:: ........... -i-i !-!- ¥':. :-- : :-: : - .... - ......... - .... ': : ' .... - · - !'~!'!"'!"!"!!'i!!"!"! ..... ~"??'"! .... ??~"~"'?'"?'?'"? ~'i"}? ...... .......... ! ........ ~'-q ..... ~ .......... i .... ~ ....... ~'-'~--')'~) ....... ~--~.--i .... ~,-i--i~-.-;-.-i.-:~..i-:-.i .i: ........ ~:~ !~;: i~i! ~i~'!!~i ~i~i !!': ': ...... :..:::...:...:...:.: ..... :.:..:.: .... ::..:...~..,:..::.:.. ;..:..:.: ..:.::: :.::: ..::-,:.:: . ....... :.:: :.-: ::: : : '::: :::: :::: :::: :;:: :::: ::: .' :' -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 EAST WELL' 3,M- 24 (985'FNL~ 1612"FEL, SEC 25:-"',3N, R8E, UN) VERTICAL PROJECTION 73.0 -4000 -2000 0 0 2000 4000 6000 8000 10000 ":,'::"} i'/'i"i i'i"':'~ .... i i'"!'i' 'igd~6'" ':!'"ii ~':~'~ .... ~'~' ~'~":' ~ ~: ' . 124901 ~ :: :~ L )..::.:,..:, . ~.; ~...~ .... ~.;...; +. ~.;. ~. ~ .~-.~..~...~ ..~.~ ~ ~...~-~--~ ~ .~ ~ ~ ~ ~ ~ ~. ~ ~ ~-~-~ ~-~-~ 'F : ~ ~ ' ' : ~ : ~ ~ ~ ~ ~ ~ ::'- ~ : ~.;-~ : .... ;.; ;' .; ~'~ ~ ~ .~ ~... ~ :: .... :: ~ ~..~-..~..~. ?..~ .... ~...~ ............ ~ .................. ~ ;:.--~.~ ~ ~ ~.: .... ;..;.;.; ;-; ............. ; ; ; : : .............. ~ ...... ; ~ ~ ~ .~ ~-j ~ ~ . ~ ~ .... ~ ~ ~ . ~ ~ ~ ~ '~ ~ ~. ~ ~ ~-~ : ~ ~ : : : -. : · : . : ~ : ~ ~ i :. :: ~ ~'~ :800~ ' ~ :. ~. :, ' ~ :. : ~ ; :. ~. : ' ' : ' ' ................. ....... ~.~.:~..~; ...~.~:...~ .~. ~.~...~ ........................ ~. ~..~..~ .... ~ ~ ~.~ ~. ~ ~ .:: -:,:: :::, . .. :, :,.:, :, . ~ .i..-:,..:, ·-i..J. :,--:, .... ;-:,--~- ~; ~; .~ ~...;..~ .~..~ ~?..~..~..~.'::?~: ~: ::::::::::::::::::::::::::::: ~::'::: ::~::::;~::~::::':~:~ ::~::' .~':~::::~ '::'~; :~ ~: :.: · : ~-~ ~-~": ~--~---~--~ ..... ~-'~ ..... ~"~--/~' -'~a~' ~--~"~"-~" ';"-~'"~"~""~'"~'?'~ '~ '~"?~ ..... ~ ~'~"? ;'~'"~; "~': :'~' ~"':: ~ ~. ~. :: ~ .;. ~, ~ ~ ~...;; .:~ ~ ..-:,-~-.-;...~ . ~...~..~..;.. ~..~...~. ~ ~. ~.-~..~. ~.. ~.. ~. ~ .-. ~.~ ~-.~ .~..~ ~ ~- . ~ ~ ~; ~ ~; .~ ; ..... :.~: ~; ..... · ~-.~--.~; ..... ~ ;.--::---~ ..... ::---~-~--~ ...... ~---~---~---:: .... ~---F.~---~ .--~---~---~---~ ..... ~.-~--~.--~ ...... ~---~---~.--~ ...... ::.-~--!--i- -?-..~-~-..? ~ ~-~ ~ '~ ........ ~"~' ' ;': ....... ~ :.-~ ~ ~'~ ~'"~ I ~' ~'~ ~ ..... ~"~ .................. F"F'F'; .... f ~"~"~' T:: ;"F' :: ...... f .... ~ ~';'~ ~ ...... ................ :~...~ ..... ~...~...:?.:~ ..... ~...~...?..~ ..... ??..?..~ ...... ~ ......................... ~..-~-..~..~ .... ~..¢..~-..~ ...... ; ........... ~. ~ ~' ;- ; : · ..: . ~ . ~ -:- .?. T--;- -;- , '-T"F'¥-'-~ ..... : --T--;---:-- : .... _ ' ..;. ;-.~..:. :-.::.-:.- :~ - ~-~;---~ ..... ~---~--+--~ --~---F-~--~- .-~--~ ~---~--: ...... ~ .... ~-'~"~ '~ '::'~'~ ~ "~: ~'~ '~' ' · - ~ ~ ~ ~ ~ ~ ~ ~ : : : : : ; ...... . . _ :~;~:~ .-~ ~.;~ ~.;.~-.~ ...... ~.;.;.;.:;.~-F;- -L~--;; ~--~-~-~- ~ ~:.. ; :~ ~.: · ....~.. ' ~:.~ '~"??-~ .... ?'?-'?"~ '"~'";'"F'F'~'~'~Ab'b~'"~"~"~'~" '~''::' ;''~' ~";";~ ~: ~ : :. : _1 .... ~ ...... -~:-:~:, ~-:~--;-~ --~--~ ..... ;'~---~-'~ '~S~6~ "~'-~'"~"~ -i-+-~-~ --~-~ --?-~ '~"¢ "~:.: -~: ~ ' ____[ PROJECTION ON VERTICAL PLANE 73.0 - 253.0 SCALED IN VERTICAL DEPTHS HORIZ SCALE ~ 1 / 2000 IN/FT 12000 2530 ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9079 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of th!~ transmittal. ~d,~..~¢~ 3H-31 ,J_IS Tape and Listing: 04-25-94 · ~' LWD CDR/CDN 1 Bit Run ¢)~.~iG 3H-25 LIS Tape and Listing: .- 04-27-94 ¢'LWD CDR/CDN 1 Bit Run C},L~l~ 3H-23 LIS Tape and Listing: 04-25-94 ¢" LWD CDR/CDN 1 Bit Run ,~ Tape 04-22-94 c~...!%~ 3M-23 LIS and Listing: · " CDR/CDN-4 Bit Run with QRO Processing ~r~...-lc~..~ 3M-26 ,LIS Tape and Listing: 04-27-94 ¢'CDR/CDN-4 Bit Run with QRO Processing ~,~ 1'~2E-17 LIS Tape and Listing: 05-03-94 ¢"-2 Pass CNTG Cased Hole Edit ~--~'~f¢ 3M-25 ..,,[.IS Tape and Listing: ~--' "Run with QRO Processina Receipt Acknowledged: Please acknowledge receipt 94066 94083 94075 94018 94O23 94102 05-02-94 94027 Date: ~' DISTRIBUTION: Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: March 04, 1994 Transmittal #: 9020 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed copy of this transmittal. Please acknowledge receipt and 3M-23 3M-26 3M-25A 3M-24 Receipt Acknowledged: Directional SurveyO'" ~.-~c 01-30-94 Directional Survey o- ~'zs 01-30-94 Directional Survey o- ~ t~ 01-29-94 Directional Survey o-i~-~,~ 01-30-94 _~~_.Z~ ~ Date: DISTRIBUTION: D&M State of Alaska (2 copies) 94045 94O43 94042 94044 ARCO Alaska, Inc. Date: January 11, 1994 Transmittal #: 9000 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 3M-25A 3M-26 3M-23 3M-24 3M-26 3M-25A 3M-23 3M-24 ¢'Ultrasonic Imager-USIT Cement & Corrosion /Ultrasonic Imager-USIT Cement & Corrosion ,./Ultrasonic Imager-USIT Cement & Corrosion ~,-Ultrasonic Imager-USIT Cement & Corrosion ,,'Cement Bond Log (CBT) ,-Cement Bond Log (CBT) .'Cement Bond Log (CBT) ,,"Cement Bond Log (CBT) Please .acknowledge 01-29-94 ~t 78~e-9~50 01-29-94 ~,~, 6900-8785 5 01-29-94 ¢3. 01-29-94 ~,~ 7300-12606 5" 10600-1 2356 12-20-93 P,~ 7800-9421 5" 12-20-93 ~,t 6900-8756 .5 ~ 12-20-93 ~,~ 7300-12577 .5" 12-20-93 ~ 10600-12327 .5 Receipt Acknowledge: Drilling State of Alaska(+sepia) NSK Date: -u~ i.J L, Ct~ tJ - ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 13, 1994 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 3M-24 ARCO Alaska, Inc. Permit No. 93-195 Sur Loc 985'FNL, 1612'FEL, Sec. 25, T13N, R8E, UM Btmhole Loc 1364'FSL, 465'FEL, Sec. 27, T13N, R8E, UM Dear Mr McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated December 22, 1993 are in effect for this revision. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section W/o encl Department of Environlnental Conservation w/o encl ,STATE OF ALASKA " ~ ,~KA OIL AND GAS CONSERVATION COMM, ~ ,~ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r-I lb Type of Well Exploratory [~] Stratigraphic r~ Development Oil X Test Re-Entry r"] Deepen [~] Service E~] Development Gas r'"] Single Zone X Multiple Zone 2,. Name of Operator ' 5. Datum Elevation (DF or KB) 10.' Field an'd Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3, Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorac.:je, AK 99510-0360 ADL 25524, ALK 2655 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25,025) 985' FNL, 1612' FEL, SEC. 25, T13N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1428' FSL, 258' FEL, Sec. 27, T13N, RSE, UM 3M-24 #U-630610 At total depth 9. Approximate spud date Amount 1364' FSL, 465' FEL, Sec. 27, T13N, RSE, UM 1/1 5/94 $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 3M-12 12421' MD 465' @ TD feet 12.1' @ 100' MD feet 1920 6284' TVD feet , 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 600 feet Maximum hole angle 67.75° Maximum surlace 1954 psig At total depth (TVD) 3475 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length ME) TVD MD TVD (include sta~e data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 47.0# L-80 BTC 2817' 41' 41' 2858' 2368' 680 Sx Arcticset III & , , HF-ERW 550 Sx Class G , 12.25" 9.625" 36.0# J-55 BTC 2462' 2858' 2368' 5320' 3300' HF-ERW 8.5" 7" 26.0# L-80 BTCMOE 12380 41' 41' 12421' 6284' 150 SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth ~tornUdCutcUtroar' R E C E IV E O Surface Intermediate Production .,.j~[~r '] -j ]994 Liner · Perloration depth: measured ~.v~c,::~,,~ 0JJ & G~S C0rlS. C0~rllJSS[orl true vertical Anch0ra_q~ 20. Attachments Filing fee X Property plat r-] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis r'~ Seabed report ["] 20' AAC 25,050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/Tf/~/~~ Title Area OrillJn, En,ineer Date l//,/f¢ . ! "' - Commission Use Only Permit Number [APl number ~ ..~ [Approval date/c.,~ ~¢.,,~,,_~ J ~ ~ -~ ~:..7 See cover letter for ~.~...~- ~///'~.,. c~. 50- c'~ ~?~. ._'-~ ~ ~ ~ ~,~" ~. -~ .. ."~.?~_ ,) other requirements Conditions of approval Samples required .[-'l Yes J~ No Mud log required [-'! Yes ;r~l No Hydrogen sul. fide [--I Yes ~] No Directional survey required ~ Yes ri No measures Required working pressure for BOPE [~] 2M ~i~ 3M [--~ 5M ["] 10M [-~ 15M Other: Original Signed By by order of Approved by David W, Johr t0n Commissioner the commission Date ,/'y//'~/~ Form 10-401 Rev. 7-24-89 ~ubr~it in tr plicate KRU 3M-24 Permit to Drill Kuparuk River Unit Well 3M-24 was approved to drill by the AOGCC on 12/22/93 (Permit #93-195, API #50-029-22432). As a result of geologic information obtained while drilling offset Wells 3M-23 and 3M-25, the original planned Kuparuk target for 3M-24 will not be drilled. By submittal of this Permit to Drill, ARCO Alaska, Inc. requests approval to drill Well 3M-24 to an alternate Kuparuk target (1428' FSL, 258' FEL, Sec. 27, T13N, R8E, UM). Drilling of Well 3M-24 will begin on 1/15/94. Approval of this Permit to Drill is requested by 1/14/94 (Friday) so as not to incur significant stand by rig charges. If you have any questions or comments regarding the attached procedure, please contact Wayne McBride at 263-4962 or the Drilling Engineer working on the project (Steve Bradley) at 263-4243. Thank you for your expedient response to this request. RECEIVED JAN 3'1 1994 ?._.!~;si~a Oii& Gas Cons. Commissior~ Anchorage o , , , , o . . o 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M-24 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5320')according to directional plan. Run and cement 9-5/8" casing (cement to surface). No cement bond logs to be run in 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (12421') according to directional plan. Run open hole evaluation logs or 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 logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED jail '1'i 199q, Oil & Gas C0r~s. C0~f~rnissi0n Anch0rag~:; DRILLING FLUID PROGRAM Well 3M-24 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.5 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% 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 Notes: Weight up to TD 11.3 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% 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 1954 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-24 is 3M-12. As designed, the minimum distance between the two wells would be 12.1' @ 100' MD. 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 the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. Oar.. 00r~s. t;01¥~rnissi0r~ Anchoragn iCreated by ' jones ¥or: $ BRADLEY iDate plotted : lO-Jan-94 !Plot Reference is 2(Y) Version #5. iCoordinates ore in feet reference slot //24-. ITrue Vertical Depths are reference wellhead. --- Baker Hughes INTEQ 'ARCO ALASKA, Inc. Structure : Pad SM Well : 24(Y) : Field : Kuparuk River Unit Location : North Slope, Alaska] < = - W e s f Scale 1 : 250.00 10000 9500 9000 8500 80,00750.07000 6500 600.05500 5000 450.0400.05500 30.002500 2000 1500 1000 500 0 500 Illlllllllllllllllllllllllllllllllllllllll s 72.7 DEG W 9642' (TO TARGET) TD LOCATION: 1364' FSL, 465' FEL SEC. 27, T13N, RBE ~ SURFACE LOCATIOF:I [ I J 985' FNL, 1612' FEL SEC. 25, TISN, RBE TARGET LOCATION: 1428' FSL, 258' FEL SEC. 27, T15N, RBE TARGET TVD=606B TMD=12115 DEP=9642 SOUTH 2867 WEST 9206 500 .. o - 0 I I - _250(I V · -I-- 30OO_ ~ 3500_ _ I 5000_ 6500_ RKB ELEVATION: 68' KOP TVD=600 TMD=600 DEP=O 6.00 12.00 18.00 BUILD $ OEO / 100' '~ 24.00 \ 3o.oo k ,58.00 B/ PERMAFROST WD=1718 TMD=1794 DEP=561 MAXIMUM ANGLE ~ ¢2.00 ' ~ ~ DEG ~ 48~%?00 T/ UGNU SNDS ~=2098 TMD:2522 DEP:725 ~0¢~00' EOC WD=2568 TMD=2858 DEP=1187 ~ _ ECEIVE T/ W SAK SNDS ~D=2868 TMD=4180 DEP=2410 ~ B/ W SAK SNDS ~D=5168 TMD=4972 DEP=3 5 ~ 9 5/8 CSG PT ~D ~ TMD O0 DEP 3632 ~ ~ ~ t ~ 0 ~ Ai?,sj<a Oil & 6as Cons. Commission Anchorage K-5 ~D=4868 TMD=9461 DEP=7298 BEGIN ANGLE DROP ~D=5442 TMD=10978 DEP=87~ 66~0 5o.oo TABGET ANGLE T~T - .~ ~ T/ ZONE A ~D=6078 TMD=12129 DEP=g652.~ ~ ~ B/ KUP SNDS ~D=6143 TMD=12221 DEP=9717 TD / 7" CSG ~ ~=6284 TMD=I2421 DEP=985B i i i i i i i i i i i i i i i i i I i i i i i i i i i i i i i i i i i i i i i i i i i i 500 0 500 1000 1500 2000 2500 5000 3500 4000 4500 mOO 55O0 6OOO 65OO 7000 7500 80OO 8500 9OO0 95OO m000 ~0500 Scole 1: 250.00 Vertical Section on 252.70 azimuth with reference 0.00 N, 0.00 E from slot #24 West Scale 1 · 20.00 220 200 180 160 140 120 100 80 60 40 20 0 20 40 ARCO ALASKA, 11112. S~ructure : Pad 3M Field : Kuparuk River Unit Location : North Slope, Alaska 900 / 800 -- 4O 700 ' oo _ 0 Casing Design / Cement Calculations 11 -Ja n-94 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TM D: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3M-24 5,320 ft 3,30O ft 12,421 ft 6,284 ft 4,18O ft 12,115 ft 6,068 ft 3400 psi 3,500 psi Maximum anticipated surface pressure TVD surface shoe - 3,300 ft {(13.5'0.052)-0.11}*TVDshoe :1 1,954 psiI Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 3,4O0.0 ppg 6,068 ft 150 psi 11.3 ppgJ Surface lead: Surface tail' Top West Sak, TMD = 4,180 ft Design lead bottom 500 ft above the Top of West Sak = 3,680 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,153 cf Excess factor = 15% Cement volume required = 1,325 cf Yield for Permafrost Cmt = 1.94 Cement volume required =1 680 sxJ TMD shoe = 5,320 ft (surface TD- 500' above West Sak) * (Annulus area) = 514 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4110 cf/If Cmt required in casing = 33 cf Total cmt = 547 cf Excess factor = 15% Cement volume required = 629 cf Yield for Class G cmt = 1.15 Cement volume required =1 550 sxJ Casing Design / Cement Calculations 11 -Ja n-94 Production tail: TMD = 12,421 ft Top of Target, TMD = 12,115 ft Want TOC 500' above top of target = 11,615 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area -- 141 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing - 17 cf Total cmt = 158 cf Excess factor - 15% Cement volume required = 182 cf Yield for Class G cmt = 1.23 Cement volume required =[ 150 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.$ Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) -- Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy Tension (Pipe Body) Design Factor 1086000 lb 5,320 ft 47.00 Ib/ft 250040.0 lb 42197.4 lb 207842.6 lb 5.2] Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 1161000 lb 5,320 ft 47.00 Ib/ft 250040.0 lb 42197.4 lb 207842.6 lb 5 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (ib/ft) -- Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =l 604000 lb 12,421 ft 26.00 Ib/ft 322946.0 lb 54798.8 lb 268147.2 lb 2.31 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy -- Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) -- Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Cons. An.c!,,orag,--~. 667000 lb 12,421 ft 26.00 Ib/ft 322946.0 lb 54798.8 lb 268147.2 lb :2.5] Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressur(~ Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' 'I-VD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*'FVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient- Ext. Pres. @ Bottom = Design Factor =[ 11 -Jan-94 6870 psi 1953.6 psi 3.51 7240 psi 7176 psi 2908 psi 4268 psi 1.7] 4750 psi 0.585 Ib/ft 995 psi 4.8] 5410 psi 0.585 Ib/ft 3676 psi 1.5] Casing Design / cement Calculations 11-Jan-94 Surface Casing Choices oD ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices oD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi K- PARUK RIVER UNIT 20" DIVERTER SCHEMATIC 3 2 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) . 2. 3. 4. 5. . 16" CONDUCTOR SLIP-ON WELD STARTING HEAD DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTRO//FD TO ACHIEVE DOWNWIND DIVERSION ED F 3/10/92 13 5/8" 5000 t-,41 BOP STACK 7 6 5 J I . 3 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 REMAIMNG PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 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/kND 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'FI'OM PIPE FINVIS. TEST Bo'FrOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10MINUTES. 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. 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 N~ID FUNCTIONALLY OPERATE BOPE DAILY. 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 ' ,..t i'",, 'i 'f ~ r ,J ,.I !' ...... {J01iS. ITEM [2 thru 8] ** CHECK LIST FOR NEW WELL PERMITS :::: APPROVE DATE [9 t?/ru i33 _ [10 & 13] (4) Casg [14 thru [23 thru 2 (5) BOPE (6) Other I]29 thru 31} (7) Contact ~.,:~2~'__ '/"'""'"'' //..///? ~? [32] (8) Addl 5 5. 6. 7. 8. e 10. 11. 12. 13. 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undndicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s admi n i st rat ive approval needed .................................... Is lease ncrnber appropriate ........................................... Does well have a unique name & ntrnber ................................ Is conductor string provided ......................................... Wil 1 surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover al 1 known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel lbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to .~C~Z) psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STP~ATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ncrnber of contact to supply weekly progress data ...... Lease & Well ~ ~.~' NO 33. Additional requirements ............................................. 0 geology: engineering: rev 6~93 jo/6.011 INITIAL GEOL [ UNIT oN'/OFF POOL CLASS STATUS AREA[ ~ SHORE ,,'-.., .-'.-o ,, ... ',:/© ///~': c~ : b Additional remarks' MERIDIAN' UM ~ SM WELL TYPE' Exp~D-e~ Redrill Inj~ Rev ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 10, 1994 Phyllis Billingsley ARCO Alaska inc P O Box 100360 Anchorage, AK 99510-0360 · Dear Ms Billingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were ddlled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were drilling as of I2/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project, if ! may be of any assistance, please call me at 279-1433. Yours very truly, Robed P Crandall Sr Petr Geologist encl jo/A:RPC:~drlstats .1/o4/94 OPERATOR ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA INC ARCO ALAS If3% ARCO ALAS ff. A INC ARCO ALASKA ARCO ALAS~tA INC ARCO ALASKA INC ARCO ALAS~A ARCO ALASKA ARCO ALASKA ARCO ALAS~(A ARCO ALASKA ARCO ALASKA INC ARCO ALASKA ALASKA WELLS BY ARCO PERMIT 93-0166-0 93-0152-0 93-0151-0 · 93-0163-0 93-0144-0 93-0188-0 93-0179-0 93-0169-0 93-0104-0 93-0189-0 93-0174-0 93-0175-0 93-0187-0 93-0195-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV U~IT KUPARUK RIV UI~IT KUPARUK RIV UI~IT KUPARUK RIV LTNIT K~PARUK RIV UNIT 2A-18 2A-19 2A-20 2A-22 2A-24 2E- 04 2E-05 2E-06 2E-07 2E-08 2E-17 2E-18 3M-23 3M-24 3M- 25 3M-26 3R-16 ALASKA OIL AND GAS CONSERVATION COMMISSION December 22, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3M-24 ARCO Alaska, Inc. Permit No: 93-195 Sur. Loc. 984'FNL, 1612'FEL, Sec. 25, T13N, R8E, UM Btmhole Loc. 1077'FSL, 869'FEL, Sec. 23, T13N, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. ' 'The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · , ~; 'c~ l)ru~Im;l on recych?cl papc,r b v ¢". Pt STATE OF ALASKA AL~oKA OIL AND GAS CONSERVATION COMMIS~,,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic [] Development Oil X Test Re-Entry ~ Deepen I~ Service [] Development Gas C] Single Zone X Multiple Zone FI 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25522, ALK 2558 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.025) 984' FNL, 1612' FEL, SEC. 25, T13N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1000' FSL, 700' FEL, Sec. 23, T13N, R8E, UM 3M-24 #U-630610 At total depth 9. Approximate spud date Amount 1077' FSL, 869' FEL, Sec. 23, T13N, R8E, UM 12/29/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) property line 3M- 1 3 8356' MD 1077' @ TD feet 12.3' @ 420' MD feet 2560 6412' TVD leet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500 feet Maximum hole angle 44.4° Maximum sudace 2029 psig At total depth (TVD) 3277 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 4167' 41' 41' 4208' 3428' 490 Sx Arcticset III & HF-ERW 430 Sx Class G 8.5" 7" 26.0# L-80 BTCMOB 8315' 41' 41' 8356' 6412' 140 Sx Class G HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M e asu re d..,.de p.~t h.~., ,,,,,-~ r~ el ~.~ r~al depth Structural bL lVl::u Conductor Surface Intermediate Production DEC 1 6 99b Liner Perforation depth: measured A~tSk~. uli & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis Fl Seabed report El 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~/'~~~,~ Title Area Drilling Engineer Date Commission Use Only Permit. Number IAPI(,~ r'.4 ~number j App~..v~l ~d~_~e j see cover loller for 4-k.~. _ /~ ~ 50 ..... / ~ ~ ~'"? ~-- r~ f~' ~ other requirements /, ~ /Z-.~' _ Conditi~-ns of approval Samples required [] Yes ~ No Mud log required E] Yes ~[] No Hydrogen sulfide E] Yes [~ No Directional survey required '~ Yes E] No measures Required working pressure for DOPE Fl 2M '~ 3M Fl 5M Fl 10M E~] 15M 3avid W. Johnston by order of Approved by Commissioner the commission Date /C;'~.-~-"~ Form 10-401 Rev. 7-24-89 Submit in ! , , , 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M-24 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4208')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8356') according to directional plan. Run open hole evaluation logs or 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 logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED Alaska 0il & 8as Cons. ComBission Anchorage DRILLING FLUID PROGRAM Well 3M-24 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.5 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% 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 Notes: Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% 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 2029 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-24 is 3M-13. As designed, the minimum distance between the two wells would be 12.3' @ 420' MD. 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 the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED DEC 1 6 199,3 ", o Alaska 0ii & Gas Cons. C0mrniss~on Anchorage ALASKA, Structure : Pod SM Well: 24 750 _ 10043_ _ 1250_ 1780_ _ 20-,90 _ 2250_ _ 2500_ 275o_ _ 3000_ 3250_ 3750t _ 42~0_ _ 450'0 _ - 4750_ _ - 52~O_ _ 55~3_ 5750t 6250] 65001 RKB ELEVATION: Field : Kuparuk River" Unit TD LOCATION: 1077' FSL, 869' FEL SEC. 26, T16N, RBE KOP TVD=500 TMD=500 DEP=O TARGET LOCATION: 1000' FSL. 700' FEL SEC. 23, TlSN, RBE Location : North Slope, Alaska _. ,Created by jones For: S BRAI)LEY iDote plotted' 7-Dec-93 iPlot Reference is 24 Version #2. Coordinotes ore in feet reference slot #24. iTrue Verticol Dentils ore reference wellhead. Baker Hughes INTEO .... 6,00 4550 4200 3850 350'3 ,5150 2800 2450 I 2.00 (~ TARGET 1VD=6191 TMD=8067 18 O0 BUILD 6 BEG / iCe' 0EP=4798 · NORTH 1985 WEST 4568 k 24.00 ,~ 30.00 "X 36.00 B/ PERMAFROST x, 42.00 TVD=1673 TMD=1763 OEP=403 EOC TVD=185S TMD=19SO DEP=545 ~ T/ UGNU SNDS WD=2188 TM0=2472 OEP=890 ". T/ W SAN ~HDS TVD=2895 TMD=3459 DEP=1580 -... .. West sco, 1: 2100 1750 1400 1050 7005~M} 0 550 N 65.57 DEG W 4798' (TO TARGET) -, '"", B/ W SAK SND$ TVD=5228 TMD=3928 DEP=1908 :'~,~9 5/8" CSO PT R/D=3428 TMD=4208 DEP=2104 K-lO i'VD=3538 TL(D=4362 DEP=2212 ",,,% TARGET ANGLE 40 DEG MAXIMUM ANGLE 44.4 DEG 1400 - 1050 _ _ 700 350 0 350 A I I ESTIMATED SURFACE LOCATION: 984.5' FIIL, 16 I 2' FEL SEC. 25, T13H. R;SE '"""-..., RECEIVED x, '""-,,., DEC 1 6 199~ l<-5 TVD=4978 TLtD=6577 DEP=3622 ""-%.. Alaska 011 & I~as Cons. Ootllmission '"'"""x. Anchorage '%, -.. ,. ',.. , BEGIN ANGLE DROPTVD=6028 TMD=7847 DEP=4650 . 44.00 DROP 2 OEO, 'N 42.00 ., TARGET - T/ ZONE C (EOD) TVD=6191 TMD=8067 DEP=4798 "-. T/ ZONE A TVD=6210 TMD=8092 0EP=4814 '" "~'"" B/ KUP SNDS TVD=6259 TMD=8156 DEP=4855 '"" ,, TD / 7" CSG PT TVD=641g TMD=8356 DEP=4983 .~x),X¢ I I ! I I I I I I I I i i I i I I I I ) I t t I I O 250 500750 1000 1250 1500 1750 200a3 2250 2500 2750 3000 Cocale 1 : 12,5.00 Vedicol Section on 294.43 ozimufh with reference 0.00 I,I, 0.00 E from slot #24 I I I I I i I i I I I i I t i 3250 35D3 3750 4 C/'uO 4250 4500 4750 5000 West ARC0 ALASKA, Inc Structure · Pad 3M Well · 23-24-25-26 Field · Kuparuk River Unit Location · North Slope, Alaska 2100 2050 2000 1950 1900 1850 1800 1750 1700 1650 1700 % 1300 1500 15OO 1500 1300 13OO 1300 1100 1100 2900 1100 900 1600 1550 700 27OO ' 650 _ ~ _ 700 " _ 750 800 0 I 85O I 900 ] V 950 PROPOSED ,5O0 e ~00 1000 1 Casing Design / Cement Calculations 14-Dec-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TM D: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3M-24 4,208 ft 3,428 ft 8,356 ft 6,412 ft 3,459 ft 8,067 ft 6,191 ft 3200 psi ** See Page 4 For Casing Choices 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,428 ft {(13.5*0.052)-0.11}*TVDshoe =[ 2,029 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD -- Overbalance, psi-- Anticipated Mud Weight =L 3,200.0 ppg 6,191 ft 150 psi 10.4 ppgJ Surface lead: Surface tail: Top West Sak, TMD = 3,459 ft Design lead bottom 500 ft above the Top of West Sak = 2,959 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 927 cf Excess factor -- 15% Cement volume required = 1,066 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 490 sxJ TMD shoe = 4,208 ft (surface TD - 500' above West Sak) * (Annulus area) = 391 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 426 cf Excess factor = 15% Cement volume required = 490 cf Yield for Class G cmt = 1.15 Cement volume required =J 430 sxI RECEIVED DEC 1 6 199~ ,~i~ska Uil & (}as Cons. Commission Anchorage Casing Design / Cement Calculations 14-Dec-93 Production tail: TMD - 8,356 ft Top of Target, TMD = 8,067 ft Want TOC 500' above top of target = 7,567 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 138 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 155 cf Excess factor = 15% Cement volume required = 178 cf Yield for Class G cmt -- 1.23 Cement volume required =l 140 sxI TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy Tension (Pipe Body) Design Factor 564000 lb 4,208 ft 36.00 Ib/ft 151488.0 lb 23324.3 lb 128163.7 lb 4,41 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy - Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 639000 lb 4,2O8 ft 36.OO Ib/ft 151488.0 lb 23324.3 lb 128163.7 lb 5.0J Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Pipe Body)- Design Factor =1 604000 lb 8,356 ft 26.OO Ib/ft 217256.0 lb 34096.8 lb 183159.2 lb 3,31 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud RECEIVED Casing Rated For: Length = Casing Wt (ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ DEC 1 6 199~ 0ti & Gas Cons. Commission Anchorage 667000 lb 8,356 ft 26.00 Ib/ft 217256.0 lb 34O96.8 lb 183159.2 lb Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres: Design Factor :[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =1 COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' 'I-VD with 9.0 # Mud 2. Ext, Pres=Mud Wt*0,052*'I'VD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 14-Dec-93 3520 psi 2029.4 psi 1.7J 7240 psi 6970 psi 2967 psi 4002 psi 1.81 2020 psi 0.541 Ib/ft 919 psi 2.21 5410 psi 0.541 Ib/ft 3470 psi 1.6J RECEIVED DEC 1 6 199;~ ~!~ska 0il & Gas Cons, Commission Anchorage Casing Design / Cement Calculations 14-Dec-93 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi Burst 7240 psi 4980 psi RECEIVED DEC 1 6 I99~ Ai~sk~ Oil & Gas Cons. Commission Anchorage KJPARUK RIVER UNI'I 20" DIVERTER SCHEMATIC I 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) RECEIVED DEC 1 G 199~ Alaska Oil & Gas Cons. Commission 1. 16" CONDUCTOR Anchorage 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"-2000 PSI DRILLING SPOOLWITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 I 7 13 5/8" 5000 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STA(.3K 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 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 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~-FOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 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. 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. 1. 16" - 2000 PSI STARTING HEAD P_ 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 DEC 6 git & Gas Cons. Commission Anchorage ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE ( 1 ) Fee ,.,~D4'"/.~ ,/ (2) Loc '~ ' [2 thru 8] (3) Admi n ~% (4) Casg (5) BOPE [9 t~ru 13'] '/ [10r~& 13] [14 ~hru 22] [23 thru 28 . 10. 11. 12. 13 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26 27 28. Lease & Wel 1 Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate ............................................ Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BO__PE attached .... Does BOPE have sufficient pressure rating -- test to ~ ps ig ..... Does choke manifold comply w/API RP-53 (May 84) ...... ~ ......... Is presence of H2S gas probable ...................................... NO YES 1. Is permit fee attached ............................................... ~. 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undndicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... °~/¢~ 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait .............................. £., REMARKS (6) Other ~/~(, - /'~'-' ×;~ ,,/ -% /..,~,.,~-/ ,)?- _% E29 thru 31] (7) E32] (8) Addl 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional reauirements ............................................. y rev 6/93 jo/6.011 INITIAL GEOL j UNIT ON/OFF POOL CLASS STATUS AREAJ ~ SHORE Additional remarks' UM X MERIDIAN' ' ' SM WELL TYPE' Exp/(~_e,~'~ Red r il 1 Inj Rev O ~O om m z 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. CLP~PANY NA~E : ARC[] A[,ASKA, INC, WELL N~S~ : 3M-24, FIELD MA~ : KUDARUK RIVER ROROUGH : NORTH SLOPE STAT~ ! ALASKA APT NU~R ! 50-029-22412-00 REFF~RENC~ N[) ! 94028 RECEIVED MAY 0 9 ;994 Oil & ~ Cons, Commission Anchoralle IS Tape Verification Listinq cblumbergar AlasKa ComputID0 Center !-~AY-!994 !7:57 DATE : 94105/ 1 [)PI~I~ : FLIC R~E!~ ~A~E : ~402~ CONTiMU~TIOM ~ : COM~E~:!T : nRC0 ALASKA, !NC.,KUPARUK PiVER UNIT, 3M-24,50-029-22432-00 **** TAPE ~!Ei~DER **** $~RVICE ahM~ : EDIT DAT~ : 94105/ 1 T~,P~ ~AME : q402~ PPEVIOUS TA~E : CO~E~T : ARC(,} ALASKA, I~C,,KUPAROK RtVEP UNIT, 3M-24,50-029-22432-00 NWD/P!hD OPE~ATO~: LOGGING cn~PANY TAPF CREA, TInN JOB 40.. NICOGS ~ ST STRIK~G 34-24 500292243200 ~RCD AI,ASK~, INC. SCHLUMBERGER WELL SERVICES 30-APR-94 BlT RUN ? NiCOL$ BIT RUN 3 25 13N 8E 985 1612 6~.00 68 00 27:00 OPE~ HOLE CA$1DJG DRILLERS BIT SIZE ¢IN) SIZE (I~) DFPTH (FT) ~,500 ,, 5 5310,0 ?ape Verification ListJ. na 1-'~AY-1994 17:57 ~chlumbergeI~ AlasKa Co~put~r~O Center P~9[)UC'CIO~ STRING REM~.~rS: ************** RUN ! *************** RCS ~P B! : 69 03 FT ~bS RP TO ~IT: 12~,98 FT M~.TS TO ~IT: 6~.~6 FT G~ TO ~IT: V6 2V FT OFN TO aim: 1~9.35'"FT NMOT TO BIT: 136.33 FT D~II,,L, ED I,~,~TERVAL: 5330-12~36 FT ~************* RU~'~ P *************** NPS RP mt) BIT~ 78,45 FT G~ TO biT: ~6,45 FT QE~:4 TO BiT: 79,76 FT ~,~EUT T[~ BIT: 86.74 FT D~ILL~[) I~,~TERVA[.~: i~136 - 12490 FT '~,~SMDO;~M' !NTEPVAL: !2080 - ~2~36 FT .... . , ~,GIJM AT D - 45 68 DEG, 12490 FT, t,~XTMU?~ }'.{OL,~ Aa~.D~ = ~9,36 D~;G.~ 0402,4P FT. TP ~EI.,L (~ 00:15 ~iA~,! 25,1994 VISCOSITY = 40.0 = ~ 0.0 ~.TER bOSS = .4.0 LIS F'OR~A'P !~ATA **** FTLE NEBDMR **** FILF ~3A~'E : EDIT ,001 $~RVICE : ~LTC V~RMION ! O01COI D!T~ : 94/05/ 1 M~X RFC SIZ~ L~ST FILE FIbF FTLF ~,IU a ~]wR: ~e~th shi~te,~ aha clipped ~urves: all hit runs mercled, DEPTH 1 ~JC~E~ENT: 0,50nO IS Waoe Verification t, istf. nn chlumberoer AlasKa Compu. tinC Center ~ -~A..Y- ~. 994 17:57 PAGE, t~DWG TOOL CODE START DE'~TH ~ . COl~ 533n, 0 SIOF DF. PTI! 12111,0 ...... - - - - F {~ !.l I V a b E M T C!!RV~; $~4iFT DhT~, CAS~;15I~E DEPT[i ~8~188.0 ~8883.5 1.2~95,0 !2~90,5 2~46,0 12240,5 .2167,5 1216~,5 ~21570 ~. 21.3~ ~0 12132,0 12!.20 5 !2125.5 12060'5 1205& 1204~,5 ~2046.5 ! 2023.0 ~ 2021. ,0 ~1974.5 11971,5 11841,5 ~1838.5 1 179:~,0 11791.0 ! 174~.t~ 11739.5 11687 5 11685 5 ll60~,S 11606,5 11538.5 11534.0 11410,5 11417,5 ! 1300,5 11297.5 !1231,0 11227,0 111~8.0 ! 1~..85.0 ! 1166'0 11164,5 ! 1149.0 ~.1~45,5 10qO0. ~ 10R9~. ~ 0741 .5 10~5~,a 10654.5 100,0 9a.5 MWRCE~ nATA 50UPCE LDWG T~Of COreC ~IT R~JN NO. ~ERGE TOP ;~[. ........................ 1 5 C~ 2 12136,0 CD~ ! 5330,0 CDr.' tlNSHIFTED DEPTH-- .... ---- UE~GE ~ASE 12473.0 12136.0 !.2411,0 ,:IS Tane 'Verification Listino ;chl'~,,mber(.~er Al, as~a Co~putfna Center l ~,~4hY-! 994 17:57 PAGE: TO ~H[c CE~/~-~ [)~" ~' ,~-d~~ , ~F,I~ ~ I994 ALL OTHER CI, tRVE~ CaR~IFD W!T~,~ YblF (;[~ SHIFT. T~IS FILE CONTAINS THE VERy E~'HANCED ORO P~OCESSED ~hMISTIV!TY DATA WITH 2' AVERAGE Tt.~E GI~C~'~,CET I'M iNCLi..JDED IN T[~IS LTS FORNAT f)ATA DATA FORMAT SPECIFICATION RECO~D ** ** SET TYPE - 64ER ** TYPE; O. 1 66 2 66 0 3 73 68 4 66 5 66 6 73 7 65 8 6~ 0,5 9 65 FT ~! 66 1,5 1~ 68 13 66 O la ~5 !5 66 68 !6 66 ';'~;~. ..... SER~''~;~;'~;;~''';~'';;''';~i'';~';i~E''~;;~A ~ I ........... NUMB SIZ['';EPR ...... ~''''''''OCESS ID ORDER # bOG TYPE CheSS ~Of) ~U~B SAMP MbEM CODE (HEX) '5;';P ............. FT ;;'';;qb.., .... 0; .... 0_;;''';0 .... 5'''; ............1 t ' ........... 4 68' .... 05;5'5;5;5'0 G/C3 599589 O0 000 O0 ~ ! ! I 4 68 G/C3 59°5~9 O0 OO0 O0 0 1 1 ! 4 68 BN/E 5995~9 O0 000 O0 0 1. 1 ! 4 68 PU-S 5995R9 OO 000 O0 0 1 1 I 4 68 O~a. 59~5~9 Oo 000 OO 0 1 1 I 4 68 O~M 5995~9 O0 000 O0 0 1 I 1 4 68 OM~ 59~5~9 O0 000 O0 0 1 1 ! 4 68 C3~Nu 599b~9 Oo OOO O0 0 1 1 1 4 68 O[~?~ 5995~9 O0 OOO O0 0 I I I 4 68 FPHR 5905~9 OO 000 O0 0 1 ~ 1 4 68 GAPI 5905R9 OO 000 oO 0 1 I I 4 68 0000000000 0000000000 0000000000 00~0000000 000000'0000 O00OO00000 0000000000 0000000000 0000000000 O00OO00000 0000000000 OOO0000000 ~IS Tame Verification ListJno 1-~aAY-1994 17:57 ~chlufnberger Alaska ComputinO Center PAGE: 0 .,~, I T S E ~ V ? C ~,~ ~ F I L E N 0 ~ 8 N U M B S I Z E RE R PROCESS ID ~RDER ~ bOG TYPE CbASS MOD NUmB SA~P ELEM CODE (HEX) ... ..... .. ......... .... ..... ...........-.- ................ ~CNm M~D CPS 599589 O0 000 O0 0 I I t 4 680000000000 FCNw ~D CPS 59~589 00 ()00 00 0 1 1 1 4 68 0000000000 F~T ~P ~P 5905~9 OD OOO 00 O ! 1 1 4 68 0000000000 GPCH CET GAPI 599589 oo 00© O0 0 i ~. 1 4 68 0000000000 12484,000 R~OB.Mwp -999,250 DRHO,MWD -999.250 PEF.MND -9q9,25t) NPHI*MWD -990,250 RA,MWD -999 ~50 RP.MWD -9q9,250 V~P.MWD -999.~50 VR~.MWb -999~50 ROP.~WD ~, .... '~' ~WD -999 ~50 FCNT,MWD -999 250 FET.~WD '909,250 ~<'~u~., .~ · .... · ..... -9~9,250 D~PT. 12000.000 PHOB.MwD 2,402 ORHO.MWD 0.006 PEF.~WD C~LM,MWD 9.000 NPH.I,~WD ~2,547 RA,MWD 2.150 RP.MWD DEP.~WD 2.255 VRP.MWD 2,29'8 V~A,MWD 2.~57 ROP.~WD G~ ~w~ ID5 36'7 ~:~CNT MW[) 283 ~23 FCNT,MWD 5,645 FET ~WD . · , . ' , . .. GPCN,C~T 73.473 D~PT. llO00.O00 RHOB.MWD 2.4~0 DRHO,MWD -0.022 PEF.MWD C~LN,M~D 8.500 NPNi. MWD 34,554 RA.MWD 3,990 RP.~WD DE~.'~WP 4'235 V~p. MWD -999,250 VRA.MWD -999.250 ROP,~WD GP,~WD IO8.930 NCNT.MWD 2S2.000 FCNT.MWD ~,390 FET,~WD GPC~,CET 64.7~2 DFpT. lnOO0.O0(> RIiOB.NWD 2.494 DRHO.MWD 0.00) PEF.MWD CaLN.~D 8.702 NP~i. MWD 29,000 RA.MWD 4.~44 RP.~WD DE~ ~WD ~.447 VRp. MwD -~99.250 V~A.MW~ -999 250 ~OP,MWD G~[~p ~5.b20 NCNT,MWD 300.750 FC~T,MWD 7:688 FET.UWD GPC~.C~m -909,250 PFipw. o0n0.unu PH~B.MND 2 568 r)RMO.MWD 0.005 PEF.MWD ~LN ~WT~ ~,907 ~PWI,MWD 3J:~00 RA.MWD 3 ~12 RP.~WD CD~Wn 3'9~1 VPP.MWD -999. 250 VPA.MWD -999~250 ROP.MWD GP,~[) q6.373 NCNT.MWD 300.~0 WCNT.MWD 7,280 FET.~WD GPC~.CET -~o9.250 DFPT. 80Ou. OoO R,.iOB.NWD 2.455 DRHO.MWD 0.006 PEW.MWD CaL~'.vWD 8.b58 NPHI.~WD 38.500 RA.MWD 4.420 RP.MWD mEP.~wn 5,218 VPP.MW!) -999.250 VPA MWD -99q,250 ROP.MWD G~.MWD 132.8K2 ~CNT.~WD 2~7.617 FCNT[MWD 5.626 FET.MWD GP~N.CET -9~9.250 DMPW, 7000.000 PHOU.MWD ?.306 D~MO.MWD -0.016 PEF.MWD C~LN.~wt~ ~.569 ~iP~I.YWD ~0.lgg FA.MWD 3.044 RP.MwD DE~.uWD ~.qlb VPP.MWD -99q.250 VPA.MWD I999,~50 ROP.~WD G~.MW~'~ I()7,77~ NCN~.~q~D 265.264 ~CNT.~!W[) 5.417 FET.~WD GPC~.CEW -9q9,250 99~ 250 25O 2 851 ~,224 2,329 1,5,264 3,040 3 422 4!378 326 688 0,863 3.130 4.558 385.487 0,406 3.196 3 996 ,o:s4o 0.485 2,842 5,487 281.733 0,193 3.044 3.707 330,477 0.350 ,IS Ta~e verification l, istino ~chlumberqer Alaska ComputJnq Center t-~AY-1994 !7:57 PAGES C~bN'~,~W~ ' 8.662 PEP, ~P 5. i 3b V~P. MWD GP.~W'n ~0.983 NCNT,MW[) gttc~. CE'r -909.250 2.233 DRHO,MWD 33.500 'g99,250 V,.A,MWD 273,891 FCNT.~WD 0.014 4.o41 -9 9: 6.320 PEF MmD RPiM~D ROPM'WD DEPT, 5167,000 RiiOB.MWD -999,250 DRHO.MWD -999.250 PEF,~1ND C A L~,! ~,~WD -999.250 t,JPH I. MWD -qgg,~50 RA.MWD -99g.~50 RP, N~D DED'~"k,~n 909,2~0 vPP ~4WP 999 250 V~A MWD -999, - . _ - . 250 ROP MWD ..... '~VD -9Og 250 NC~JT MWD -999,250 FCNT' ' GR,, .... , . G~CM.CE7 -909.250 2.743 O16 0,422 -999' 250 -999'250 ..999'250 -999' 250 ** END OF DATA ** **** FILE TRAILER **** F'TL~ MANE : EDIT .001 $~RViCE : WLIC YFRSION : 001C0i D~TF : o4105/ 1 FILE TYPE : LO LAST FIbE : FIL~ NA~E : EDIT .002 SERVICE : FLIC V~RSION : O0~COl D~T~? : q4105/ 1 ~AX REC $IZ? : 1024 FTL? TYPE LAST FILE : Ctlrves and f3TT RI!Ft NUMBER; !,D~,G TOt)l, CODE ........... CDM header data 1 O.50OU for 5168.5 each bit run in separate STOP bFPTH 1213 5 !2134,5 files. .,IS Tape VerificatioD ;cblumherger AlasKa Comput]nq Center i7:57 PAGE: DATE LDGGED: SE)FTWARE: DOWNHF]b~ S(,)VTWARE; V~RSI~]N ~ATA TYPF (HEHORY or R~AL-T!~'~E): TD DRILLFR (FT): TOP I..,,OG INTERVAL P.(.]TTD~ LOG I~TF, RVAL (FT): nit ROTATING ~DE:~[) HOL~ i~:~CLINAT!ON (DEG) STRING (~'()P TO BOT~OH) V~NDOR TOOL COD~ TOOI~ TYDW 25-dAN-94 FAST 2.4 12490.0 53i0,0 12490°0 69.4 P, UREHO!.,g AND CASI!'~G DATA OPEN HOLE LST,.T STZE (IN): DR!bLED5 CASING DEPTH (FT): TOOL NUMBER RGS035 NDS049 MIlD TYPE: MI!D DgNSiT'Y (LB/G) ?,~UD PH: FLUID bOSS (C3) aAXIMI.!D~ R~CORDED TEaP~RAT!~RE (D~GK): R~SISTIVI'rY (Oi-.i~) AT TEMPERATURE (DEGE): MUD AT ~iFASURE;D ~Un AT NAX CIRCLJLATIMG TENPERATURE ~UD FII,TPATE ~,~UD CAKE ~ EI~T P []K~ Tong HDL~ .~.ODR~CTION (IN): 500 !1,3{) 40,00 10,00 150.0 i.640 2.240 RFH~RK$: TOOL STANDOFF 2.65 1.000 ******* R!IN 1 ********** OR!l, bgP INTERVAL 5330 - 12136 ET ******* RU~ 2 ********** ~A~HDO~N !NT~PVAb 120~0 - l~13b FT DDiI, LVD INTERVAL 12136 - 12490 FT H~bE A~CLE aT TD = 45.6~ DEG m ~2490 FT ~AXli4LJr~ H~LK A~(;LF = 69,36 DEG ~ 9402.4? FT TD WEl,b AT O0:!5 ,]AN ~5, t994 $ 80.0 ,IS TaP. e Ver.i~icatior, Listln~ :chlumberq~r Alaska Computln¢-] Center. 17:57 LTS FOR~JA? DATA ** DATA FORMAT SF~ClFIC~?ION RECORD ** 2 66 3 73 64 5 66 6 73 7 65 8 68 0,5 9 65 12 68 13 66 0 !~ 65 PT 15 66 68 16 66 0 66 D~Pn~ F~ 599589 O0 000 OO 0 2 1 1 4 68 RHOP Lwl G/C3 5995~9 O0 OOU O0 e 2 1 I 4 68 DPH~ [,~ PI] 599589 O0 000 O0 0 2 1 1 4 68 D~H~ L~ G/C3 599589 O0 0(:0 O0 0 ~ 1 1 4 68 PPF LW~ BN/E 59~5~9 O0 000 ~0 O ~ 1 I 4 68 DCA;. L~! 1~ 599589 00 000 O0 O 2 1 I 4 68 TNP~ I,W~ P!; 59~589 O0 000 O0 0 ~ I I 4 68 PSR LW! OM~~' 59~589 O0 OOu O0 O 9 1 i 4 68 DFR I~W~ (jMM~ 599589 OO 000 O0 0 ~ 1 1 4 68 RnP~ Lw1 F/H~ 5995~9 Ou 000 O0 0 ~ 1 i 4 68 GP [,~ GAPI 5995~9 OO 0o0 O0 0 ~ 1 1 4 68 HFN5 ~,:~ CPS 599589 O0 000 O0 0 ~ 1 1 4 68 HFF~ 1,~ CPS 59qb~9 O0 000 OO 0 ~ 1 I 4 68 T~B !.,~ H~ 59~5~9 O0 000 O0 0 ~ 1 i 4 68 TaBn l,~!. HP 599589 00 000 O0 0 9 1 I 4 68 OOO0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000UO0000 0000000000 ~m~mm~m~~~m~mmmmmI~m~mm~mm~m~m~mmmm~m~mm#~m~m~m~m~~m~m~mmm~I! ElS Tape Veritication Listlsrl ;chlumberqer AlasKa Computino Center ** DaTA -999. -099. -999. -999. D~PT. R000.000 RH~B.LW1 DEw. LNI 2.854 DC~L.LWl PS~ Lv~l 5.354 D~a.bWl H~N~iL~ 266.250 ~!EFA.LW1 DFPW. 7000.000 PHO¢.LWl D$~,L~I 3.6al DFR.LW1 HFN~.LW! 266,750 UEFA.LW1 DEPT. 6000.000 RiiOS.LWl PEF.LNI 2.6~8 DCAB.bWl PSPo[~W1 4.9!.1 DER,LW1 H~Na,LW1 273.437 HE~A.LW1 !-MAY-!994 17:57 , . O. 5. 5. . O. 3. 5. o O. 4. 6. DFpT, 5168,500 :HO6.LW1 -g99, OEF.LW1. -999,250 OCaL.LW1 -099, DS~.LW1 -999.250 DER.LW1 -ggo. HFN~.LW~ -909.250 ~E~A.LW1 ** E~,~D UF .DATA 250 DPMI..LW! ~50 TNPB,.LW1 ~50 ROPE,LWl 250 TAB.LW! 4't6 DPHI.bWl 485 TNPH.LwI 179 RQPE'LWl 250 TAB.~LWl 400 DPHI.LWI 000 TNPH,LWI 351 ?OPE.bWl 258 TAB'L~I 475 DPHI.LWi 206 TNPH bWl 599 "~, .... l~Wl 405 DPHi 310 T~PH:bW1 839 ROPE,bWI 615 TAB.LWI 451 OP~I.LWl 352 TNPH.bWl 106 ROPE.bW1 563 T~B.LW! 312 DPHI.LWl 098 TNPH.LWl 387 ROPE.LWl 3°3 TAB.bWl ~b8 DPHI.LWl 188 TNPM.LWl ~73 ROPE.bWl 009 TAB.bWl 250 OPHI, bWl ?.,50 TNPh:LWI 250 ROPE.LW1 0.20 TINB.LWI -999..250 -999.250 14.470 -999.250 10.600 -999.250 17.341 3.1.23 15 2OO 351550 305 260 0 881 10.600 29.850 369.411 0.407 0 275.773 O. 480 12 050 3Bi85o 286'228 0 1.93 20 450 41.250 333.041 0.350 23,800 35 450 450.423 :999.250 999.25o -999.250 -~99.250 D a H 0 b W 1 tAB.,,. DRMO.LWl ITR,LWl GR.LWl TABD'LW1 TABD.LW! DR}'{O LW ! GR.L~I TABD.LWl DRHO.LW1 ATR.LWl GR.L~I, TABD.LW1 DRHO.LW! ATR.Lw~, GR.LWl TABD.LWl DRHO.LW~ ATR.LWl GR.Lwl TABO.L~I DRHO.Lwl. GP.LWl TABD.lwI DRHO.I.,Wl GR.Lw! TABD.LW! PAGE: '999,250 '999,250 '999.250 '999.250 0,024 2,140 10'2,596 5,772 '0,032 3 ~89 111~ 07 1'; 986 '0,005 - 0.022 10 981 766 0,005 4,366 122.559 0,427 -0 016 3;051 04 -0.004 4,791 77.440 0,668 -999.250 '999,250 '999.250 '999.250 Tame Verification Listinq cblumberger AlasKa ComputJ. nq Center 1-~hY-!994 I7:57 10 **** FILE TRAILEP **** SFRViCE t ~LIC VERSIOn! : 00!C01, [)ATE : 94/05/ I ~X BEC $]:Z~ : I024 Fib? TYPE : LO LaST FI[,E : **** FILE HEADER **** F!LF NA~E : EDIT .003 SERVICE : FLIC VFR$IO~ : o01C0! D~TF : ~4195/ ! MA× R~C $iZ~ : lo24 F~LE ~YnE : LO L~S~ FIbE : FTL~ ~E~DER Fib? N[3uBER 3 R~w MAD Curves and ].c~ header data for each bit run in separate BIT RUN ~iUMBER: 2 DFPmH IMC~E~E~T: 0.5000 FIL~ LDWG TOOL CODE START DEPT}{ STOP DEPTH .... ' ......... ..... CON 12080,o 124~4,0 LOG HEAD~:R DA~A DATE LOGGED: SOFTWARE: SURFACE SOFT~ARE VERSIOn!: FAST 2,4 DATA TYPE (N~qORY or R~AL-TI2E): ~E~OPY BOTTOm! bOG INTERVAL (PT): ~2490.0 nit ROTAmlNG SPEED MTNTM!!M ~XIMU~ ANGLE: 69,4 TOOb STPlNG (Ti3P TO BO'rTO~) V~r'~DO~ TOOL COiPE TOOL TYPE ................ UlTY NEUTR~/POROSTTY 25-JAN-94 TOnb NtlF:%BER NOS049 IS Tame Ver.if:[catton chlumberger hlasKa ComputiD. d Center I-MAY-~99~ !7:57 PAGE: 11 ~OREHOLE CONDITIOi~{S ~qUO TYPE: ,~¢!JD DENSITY (Li~/G): ~UD VISCOSITY (S): ~4UD MUD CHI~ORI[)E2 (PP~'~): FLUID b088 (C3): M~X, IMU?~t RECORDED TE~-~PERhTURE (DEGF): RESISTIVITY (OHMM) ~T TEMPERATURE (DEGF): MUD AT M~X CIRCULATING TEMPERATURE ; ~UD FILTPATfj AT (MT)~ ~UD CAKE AT (FIT): 6.500 5310,0 i~ATP:IX: HObK CO~R~CTIOM (IN): 11,30 40'00 10,00 1.50.0 1,640 2,24'0 # RKMaRK:S .'. SANDSTOmE 2.65 STANDOFF fiN): FREQUENCY (HZ): 1,000 ******* RUN 1 ********** D~iLbED INTERVAl, 5330 - 1213b FT ******* RUN 2 ********** WASHDOW~ TNTEPV~h 120~O - i~136 FT DPlLLED INTERVAI, 1.2136 - 12490 FT HOb£ ANGLE &T TD : 45,6~ DEG g 12490 FT HaXIMI.!N HOLE ~NGLE : 69,36 DEG 0 9402.42 PT TD wEI,b AT 00:15 JAM 25, ~994 S bls FOR"AW DATA 80.0 82.0 ** hA'fA F~R~.~A"r' SFECIFTCATIGh; RECORD ** ** SET TYPE - ~4EB ** TYPt~ REPP CODE VAbUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 ~ 73 ~I$ Waoe verif.tcati, on Listinq ;¢hlumberqer AlasKa ComputinO Center 1994 17:57 PAGE: 12 68 0~,5 12 68 13 66 0 14 65 15 66 68 !6 66 0 66 NANtF SW. RV !JFJ I T SF:RV ] A. ID O~DEP ~ LOG DFpT FT 599589 O0 RNO~ LW~ G/C3 59~5B9 O0 DPH© [~W~ G/CB 5995~9 O0 PFF L~2 BN!E 59~589 O0 DCAL L~ I5! 5995~9 TNp~ L~ PU 5995S9 O0 ATR !~ OMa~ 5995~9 00 PSR l~W~ []~ 599589 00 DFR [.,~ f)M~ 59q599 O0 RDp~ Lw~ F/HP 5995~9 O0 GP T,~2 GAP! 59~5~q HFN~ LW~ CPS 599589 O0 H~F5 Lw? CPS 590589 O0 TAB L~ ~ K995~9 TaBD L~ }"{P 59q5~9 O0 TYPE 000 O0 0 000 O0 000 O0 000 O0 0 000 O0 0 000 O0 0 O00 O0 0 00'0 O0 000 O0 0 000 O0 0 000 O0 0 000 O0 n o 00 00 0 000 O0 0 000 00 0 0o0 O0 0 OD .NU~'~B SAMp ELEM CODE (HEX) 3 I i 4 68 0000000000 3 i I 4 68 0000000000 3 I I 4 68 0000000000 3 1 I 4 68 0000000000 3 1 I 4 68 0000000000 3 I i 4 68 0000000000 3 1 1 4 68 0000000000 3 I I 4 68 0000000000 3 1 I 4 68 0000000000 3 1 1 4 6~ 0000000000 3 1 1 4 6~ 0000000000 3 ! I 4 O~ 0000000000 3 I 1 4 6~ 0000000000 3 1 I 4 6~ 0000000000 3 1 1 4 68 0000000000 3 I 1 4 68 O0000000OO ~mmm.mmmmmmmImmmmmmmmmmmmmmmmmmmmmmmMimmmmm! ** DITh ** DWPT. 170~0.000 PHOO.LW2 PEW.L~2 !5.472 DCaL,LW2 DSP.Lw2 2.259 DER.I.,W2 H~N~.I,~ 258.95~ HEFA.LW2 ** Ei~D OW DATA ** DPHI.LW2 -999,250 DRHO.LW2 TNPH.LN2 -99~.250 A]'R.I, w2 ~OPE.hW2 29,851 GP,LW2 T~B.LW2 -999.250 'rABD.LW~ ~.!4!. DPNi.LW2 30.850 DRHO.T,W2 0.337 TNOH.bW2 49.200 ATR.Lw2 ~.201, ROPE,I, W2 3~.924 GR.T,W2 4,556 T~.LW2 0,083 TABg,LW2 -999 250 -g gl so : 99 2so 9o92 so 0.029 2.120 90.587 1,062 tis Ta~.e Verfftcat~on ;chlt~mberger AlasKa Comput~,nQ Center 1-~AY-!994 !7:57 PAGEX **** TAPE TRAI~E~ **** SFiRVICE tq~M~ : EDIT D~T~ : 94/05/ ORIGIN : FbJC T~PM ~A~E : 94028 CONTiMUAT!O~i # : ~ PPEVIOUS TAPE COMmEnT : ~RCO ALASKa, !NC.,~liPAR0~ RIVER UNIT, **** REEL TRAI!.,EP **$* 6ERVlCE N~MM : EDIT DATE : 04/05/ ~ ORIGIN : FLIC CONTINtJATIO~ # : P~EVIOUS REEL : C~M~EWT : :~C0 ALASK~o iMC.,KUPARUR RIVER UNIT, 3M-24,50-0~9-224B2-00
