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184-174
TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 2V-11 50-029-21311-00 185049_2V-11_Patch_13Jul2022 185049_2V-11_PPROF_28Jun2023 2W-14 50-029-21253-00 184237_2W-14_Patch_21Jun22 2W-16 50-029-21255-00 184239_2W-16_IPROF_12May2023 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 3B-12 50-029-21370-00 185116_3B-12_WFL_30Mar2023 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 8 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38383 T38384 T38385 T38386 T38387 T38388 T38389 T38390 T38391 T38392 T38393 T38394 2/29/2024 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' • • I- >s r V co - - X 0 �9 > E '2 3 r (:) ,_ - ; 2 _0 . `� to Y 4 D 0,3 ft p` N E Q) , W W .� r .- r r �- . . . . . . . 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JO n Q O) O O T M M O) O O 0) a) w O N N N N 0 0 N N N N •� 01 O o O O V' O O O O `'. 0 0 0 0 0 0 0 0 0 0 a+ 0• a) L 4C N in in (n n u) u) v) 1.0 in a U G3 w Lt.) .givm Cu C. y) Y cc C C Wil- OJ j ,e4 < N Na- (0 r t0 V) C., 1- r a.. a+ V1 Z b op 4' Z O O N 0 N e- N N ++ E a1 H EN gN :w J J W a- Y Y X CL a N N N N N rof Z H Y s S= i , i ^ W N C 0 vi v r 'C . p ro G) a O VA o1 ( O1 H ri aQ sit OF ALASKA KRU 2X-13 ALA OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing F Operations Shutdown fl Performed: Suspend E Perforate E Other Stimulate fl Alter Casing Change Approved Program Plug for Redrill 1 Perforate New Pool F Repair Well F Re-enter Susp Well r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 184-174 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21197-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25645 KRU 2X-13 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8543 feet Plugs(measured) None true vertical 6191 feet Junk(measured) 8290, 8355 Effective Depth measured 8290 feet Packer(measured) 7779,8121 true vertical 6010 feet (true vertical) 5638,5889 Casing Length Size MD TVD Burst Collapse CONDUCTOR 66 16 103 1.5-3-"'''" SURFACE 3711 9 5/8 3747 3030 PRODUCTION 8476 7 8510 6168 SCANNED FE 1 3 2017- RECEIVED Perforation depth: Measured depth: 7970, 8014,8214,8248 SEP 2 7 2016 True Vertical Depth: 5779, 5811, 5956, 5981 AG Tubing(size,grade,MD,and TVD) 3.5, L-80, 8180 MD, 5932 TVD Packers&SSSV(type,MD,and ND) PACKER-PACKER, BAKER,4762 FHL @ 7779 MD and 5638 ND PACKER-PACKER Baker F Production Pack©8121 MD and 5889 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 145 945 2327 552 119 Subsequent to operation 177 1082 2967 1200 120 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service E Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas E WDSPL Printed and Electronic Fracture Stimulation Data E GSTOR E WINJ E WAG r GINJ E SUSP 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: N/A Contact Sara Heskin @ 265-1027 Email Sara.Heskina.conocophillips.com Printed Name Sm Sara Heskin Title Associate Wells Engineer Signature R., kk — Phone:265 1027 Date 9 fL/I Form 10-404 Revised 5/2015 �/[ ` l4/� t0(4//// RBDMS V`/ SEP 2 8 ZOlbmit Original Only MEM tii 0 Operations Summary (with Timelog Depths) 2X-13 ConacoMiliprs Rig: DOYON 141 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) 8/28/2016 8/28/2016 6.00 MIRU MOVE RURD P Dissconect AIR Steam and Water 0.0 0.0 00:00 06:00 Interconnects,Move @ 0045 hrs Shop,Satellite camp,Boiler,Motor, Pump and Pit Complexes t/2X Pad on location with complexes 0300 hrs, Spot camp and shop.Disconnect Trucks f/sows. 8/28/2016 8/28/2016 6.00 MIRU MOVE MOB P Move Pipe Sheds away from Sub,Pull 0.0 0.0 06:00 12:00 Sub off Well 1A-27,Move Sub Rock Washer and Pipe Sheds to 2X Pad on location @ 1000 hrs. 8/28/2016 8/28/2016 6.00 MIRU MOVE MOB P Spot Sub Over Well,Move Pit 0.0 0.0 12:00 18:00 Complex into Position. 8/28/2016 8/29/2016 6.00 MIRU MOVE MOB P Finish Spotting Complexes Pump 0.0 0.0 18:00 00:00 Room,motor,Boiler and pipe sheds, Spot Rock Washer,2315 hrs. Begin Hooking up interconnects. 8/29/2016 8/29/2016 4.50 MIRU MOVE RURD P Hook up interconnects,M/U Cattle 0.0 0.0 00:00 04:30 chute,Put up berming around rig and rock washer.Work on Rig Acceptance Checklist Rig Accepted @ 0430 hrs 8/29/2016 8/29/2016 1.50 MIRU WELCTL RURD P R/U Hard Lines t/tubing and IA 0.0 0.0 04:30 06:00 Pressure Test Lines to tiger tank 2500 psi. 8/29/2016 8/29/2016 1.00 MIRU WELCTL SFTY P Hold Pre Workover Meeting w/crews 0.0 0.0 06:00 07:00 8/29/2016 8/29/2016 0.50 MIRU WELCTL KLWL P Bleed gas off IA 600 psi t/0 psi 0.0 0.0 07:00 07:30 8/29/2016 8/29/2016 2.50 MIRU WELCTL MPSP P R/U Lubricator&test t/1000 psi,Pull 0.0 0.0 07:30 10:00 BPV R/D Lubricator 8/29/2016 8/29/2016 0.25 MIRU WELCTL KLWL P Bleed gas off tubing f/250 psi t/0 psi 0.0 0.0 10:00 10:15 8/29/2016 8/29/2016 0.50 MIRU WELCTL OWFF P Observe well for flow open to 0.0 0.0 10:15 10:45 atmosphere well static. 8/29/2016 8/29/2016 3.25 MIRU WELCTL KLWL P Pump down tubing taking returns to 0.0 0.0 10:45 14:00 tiger tank 300 bbls 4 bpm 300 psi, Shut down observe well f/30 min well static 8/29/2016 8/29/2016 1.00 MIRU WHDBOP MPSP P Set BPV as per Cameron test BPV in 0.0 0.0 14:00 15:00 direction of flow f/30 min 8/29/2016 8/29/2016 5.50 MIRU WHDBOP NUND P N/D Tree and adaptor flange function 0.0 0.0 15:00 20:30 lock down screws.Add Section to riser,Instal Riser and turn Buckles 8/29/2016 8/29/2016 1.00 MIRU WHDBOP RURD P R/U U test BOP 0.0 0.0 20:30 21:30 8/29/2016 8/30/2016 2.50 MIRU WHDBOP BOPE P Test BOPE w/4"Test Jt 250/3000 psi 0.0 0.0 21:30 00:00 State Inspector Guy Cook Witnessed, Test Gas Alarms and PVT Sensors, Shell Test stack. Page 1/12 Report Printed: 9/9/2016 • • Operations Summary (with Timelog Depths) 2X-13 ConacoPhitiiEss Rig: DOYON 141 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(itKE) 8/30/2016 8/30/2016 7.50 MIRU WHDBOP BOPE P PJSM-Continue to conduct initial 0.0 0.0 00:00 07:30 BOPE test w/4"test jt.Test#5-CV 5, 8,10,manual kill valve and dart valve. Test#6-CV 4,6 and 7.Test#7-CV 2. Test#8-.CV 1 and 3.Test#9-HCR choke.Test#10-Manual choke.Test #11-Lower pipe rams w/3 1/2"test jt. Test#12-Upper pipe rams w/3 1/2" test jt.Test#13 Annular preventer w/3 1/2"test jt. Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3000 psi Accumulator Pressure After Closer= 1800 psi Pressure Gain of 200 psi=47 seconds Full System=190 Seconds Average N2(5 Bottles)=1975 psi 8/30/2016 8/30/2016 0.50 MIRU WHDBOP RURD P Rig down test equipment. 0.0 0.0 07:30 08:00 8/30/2016 8/30/2016 2.75 MIRU WHDBOP RGRP T PJSM-Change out lower IBOP 0.0 0.0 08:00 10:45 8/30/2016 8/30/2016 0.50 MIRU WHDBOP BOPE T PJSM-Rig up and test lower IBOP to 0.0 0.0 10:45 11:15 250/3000 psi for 5 min each. 8/30/2016 8/30/2016 0.75 MIRU WHDBOP RURD T Rig down test equipment.Sim-ops/ 0.0 0.0 11:15 12:00 Mobilize control line spooler and tools to rig floor. 8/30/2016 8/30/2016 1.00 MIRU WHDBOP MPSP P Pull blanking plug.Check for pressure 0.0 0.0 12:00 13:00 under BPV.Static.Pull BPV with dry rod. 8/30/2016 8/30/2016 1.75 COMPZN RPCOMP PULL P Make up spear assy.RIH 31'MD and 7,807.0 7,782.0 13:00 14:45 engage fish.BOLDS.Unseat hanger w/40K and pull tubing free w/100K up weight. Pull hanger to rig floor. PU=95K.Release and lay down spear.Lay down hanger. 8/30/2016 8/30/2016 0.25 COMPZN RPCOMP OWFF P Monitor well.Static. 7,782.0 7,782.0 14:45 15:00 8/30/2016 8/30/2016 1.00 COMPZN RPCOMP CIRC P Rig up circ equip.CBU at 6 bpm,910 7,782.0 7,782.0 15:00 16:00 psi.Rig down circ equip.Make up floor safety valve. 8/30/2016 8/30/2016 7.00 COMPZN RPCOMP PULL P POOH laying down 3 1/2"9.3#tubing 7,782.0 0.0 16:00 23:00 f/7782'to surface.Recover hanger, 31 SS bands,all control line,3 space out pup jts,SSSV,five 3 1/2"x 1" KBUG GLM's and one 3 1/2"x 1 1/2" MMG-2 GLM for a total of 6 GLM's, 243 jts of 3 1/2"tbg,and cut jt=13.69'. Corrosion on collars of joints#136 to #156 and#208,Pin end of jt #212 and collar of jt #213 also had corrosion. Calc disp=27.25 bbls Act disp=24.4 bbls. 8/30/2016 8/30/2016 0.50 COMPZN RPCOMP RURD P Rig down Weatherford power tubing 0.0 0.0 23:00 23:30 tongs.Clean and clear rig floor. 8/30/2016 8/31/2016 0.50 COMPZN WELLPR MPSP P MU 7"G Lock-Set RBP.RIH and set 0.0 107.0 23:30 00:00 RBP @ 107'RKB(center of element) Page 2/12 Report Printed: 9/9/2016 0 • Operations Summary (with Timelog Depths) . = 2X-13 ccf'hfips Rig: DOYON 141 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) 8/31/2016 8/31/2016 0.50 COMPZN WELLPR MPSP P PJSM-Release from G-Lock RBP. 107.0 0.0 00:00 00:30 8/31/2016 8/31/2016 0.50 COMPZN WELLPR MPSP P PJSM-Rig up and test RBP to 1000 0.0 0.0 00:30 01:00 psi/10 min. 8/31/2016 8/31/2016 0.50 COMPZN WELLPR OWFF P Monitor well.Static.Sim-ops/Blow 0.0 0.0 01:00 01:30 down lines. 8/31/2016 8/31/2016 0.75 COMPZN WELLPR NUND P ND and set back on stump BOPE.ND 0.0 0.0 01:30 02:15 7 1/16"x 13 5/8"DSA. 8/31/2016 8/31/2016 1.75 COMPZN WELLPR NUND P ND annulus valve and IA flange from 0.0 0.0 02:15 04:00 tubing spool.Remove every other bolt from the tubing spool lower flange. 8/31/2016 8/31/2016 4.00 COMPZN WELLPR NUND P RU Hydratight and ND the tubing 0.0 0.0 04:00 08:00 spool using Hydratight to control the casing growth. Initial Hydratight pressure=20,000 psi.Final casing growth=28.5".RD Hydratight. 8/31/2016 8/31/2016 1.50 COMPZN WELLPR NUND P Remove remaing bolts from casing 0.0 0.0 08:00 09:30 head flange and remove tubing spool from 7"casing. 8/31/2016 8/31/2016 0.50 COMPZN WELLPR WWSP P Pull 7"casing packoff and slips. 0.0 0.0 09:30 10:00 8/31/2016 8/31/2016 1.50 COMPZN WELLPR CUTP P PJSM-Spear 7"casing.PU to 75K 0.0 0.0 10:00 11:30 over neutral weight to 290K.Stretch casing 32".Set 7"emergency slips. 8/31/2016 8/31/2016 1.50 COMPZN WELLPR CUTP P PJSM-Rig up Wachs cutter.Cut 59.5" 0.0 0.0 11:30 13:00 off 7"casing.Rig down Wachs cutter. 8/31/2016 8/31/2016 1.00 COMPZN WELLPR BHAH P Clear cellar. Back out and lay down 0.0 0.0 13:00 14:00 spear assy. 8/31/2016 8/31/2016 1.00 COMPZN WELLPR WWSP P Prep 7"casing stub and install packoff 0.0 0.0 14:00 15:00 8/31/2016 8/31/2016 2.00 COMPZN WELLPR NUND P Install Cameron C-bowl 11"3K x 7 0.0 0.0 15:00 17:00 1/6"5K tubing spool.Verify orientation with DSO. 8/31/2016 8/31/2016 1.00 COMPZN WELLPR WWSP P PT packoff to 250/3450 psi for 10 min 0.0 0.0 17:00 18:00 each.Witnessed by company rep. 8/31/2016 8/31/2016 2.50 COMPZN WELLPR NUND P NU 7 1/16" x 13 5/8"DSA and BOPE. 0.0 0.0 18:00 20:30 8/31/2016 8/31/2016 1.00 COMPZN WELLPR BOPE P Set test plug.Rig up and shell test 0.0 0.0 20:30 21:30 BOPE to 250/3000 psi for 5 min ea. Blow down lines 8/31/2016 8/31/2016 0.50 COMPZN WELLPR RURD P Pull test plug and set 6 3/8"ID wear 0.0 0.0 21:30 22:00 ring 8/31/2016 8/31/2016 1.00 COMPZN WELLPR MPSP P RIH and latch and release G-Lock 0.0 0.0 22:00 23:00 RBP.POOH and lay down plug assy. 8/31/2016 9/1/2016 1.00 COMPZN RPCOMP BHAH P Mobilize and make up Baker Fishing 0.0 0.0 23:00 00:00 BHA#3.(Overshot assy) 9/1/2016 9/1/2016 2.00 COMPZN RPCOMP BHAH P Continue to make up BHA#3 0.0 312.0 00:00 02:00 9/1/2016 9/1/2016 4.75 COMPZN RPCOMP PULD P Pick up and single in hole w/4"XT39 312.0 7,786.0 02:00 06:45 DP.Pick up 238 jts.to 7786'MD. 9/1/2016 9/1/2016 0.25 COMPZN RPCOMP CIRC P Make up top drive and circulate DP 7,786.0 7,786.0 06:45 07:00 volume.8 bpm=1150 psi. Page 3/12 Report Printed: 9/9/2016 • Operations Summary (with Timelog Depths) 2X-13 ConocaPhillips y, Rig: DOYON 141 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) 9/1/2016 9/1/2016 0.50 COMPZN RPCOMP FISH P Establish parameters.PU=150K 7,786.0 7,796.0 07:00 07:30 50=93K. Rot=115K.Slack off to top of fish @ 7792'MD and swallow 4'to 7796'MD.Jar on fish with 20K overpull working up to 50K overpull. After 4 jarring cycles fish came free. 9/1/2016 9/1/2016 1.00 COMPZN RPCOMP CIRC P Lay down single DP. Make up top 7,796.0 7,796.0 07:30 08:30 drive and CBU.6 bpm=650 psi. 9/1/2016 9/1/2016 1.00 COMPZN RPCOMP SLPC P PJSM-Slip and cut 65'drilling line.Sim 7,796.0 7,796.0 08:30 09:30 -ops/Monitor well.Static. 9/1/2016 9/1/2016 1.00 COMPZN RPCOMP SVRG P Service top drive. 7,796.0 7,796.0 09:30 10:30 9/1/2016 9/1/2016 3.00 COMPZN RPCOMP TRIP P PJSM-POOH on elevators f/7796'MD 7,796.0 312.0 10:30 13:30 to 312'MD. 9/1/2016 9/1/2016 1.50 COMPZN RPCOMP BHAH P Stand back DC's.Back out and lay 312.0 0.0 13:30 15:00 down fish.Recover cut joint,pup joint and seal assy.Total length=36.59'. Lay down overshot assy. 9/1/2016 9/1/2016 2.00 COMPZN RPCOMP BHAH P Mobilize BHA#4 eqipment to rig floor 0.0 337.0 15:00 17:00 and make up spear assy.to 337'MD 9/1/2016 9/1/2016 2.50 COMPZN RPCOMP TRIP P RIH from 337'MD to 7717'MD. 337.0 7,717.0 17:00 19:30 Calc disp=46.98 bbls Act disp=49.69 bbls 9/1/2016 9/2/2016 4.50 COMPZN RPCOMP FISH P Make up TD and establish 7,717.0 7,818.0 19:30 00:00 parameters.PU=150K,SO=92K,3 bpm=1480 psi.RIH and engage PBR, swallow to 7821'MD.Stage up jar operations to jar at 90K overpull and straight pull to 150K over. Rattle at 2.5 bpm, 1350 psi.Move fish uphole 3'. Attempt to bullhead but unable to. Observed gas breaking out at surface at bottoms up strokes indicating that packer is released. 9/2/2016 9/2/2016 0.75 COMPZN RPCOMP FISH P PJSM-Con't to jar fish from 7818'MD 7,818.0 7,806.0 00:00 00:45 to 7806'MD at 90K overpull and straight pull to 150K over. 9/2/2016 9/2/2016 0.25 COMPZN RPCOMP SFTY P Perform post jar derrick inspection. 7,806.0 7,806.0 00:45 01:00 9/2/2016 9/2/2016 1.75 COMPZN RPCOMP FISH P Fire jar 2 times with same parameters. 7,806.0 7,675.0 01:00 02:45 Fire jar third time and hold 50K overpull.Pump at 2.5 bpm and rattle fish from 7806'MD to 7773'MD.Jar 5 more times.Lay down working single DP.Jar up at 90K overpull.Weight dropped off to 25K over.Drag fish up hole with 25K to 50K overpull to 7675' MD placing seal assy above upper pert. 9/2/2016 9/2/2016 0.50 COMPZN RPCOMP CIRC P Attempt to bullhead down annulus. 7,675.0 7,675.0 02:45 03:15 Pressure up to 2000 psi.Unable to bullhead.Bleed off pressure. Drop dart and open circ sub. 9/2/2016 9/2/2016 1.00 COMPZN RPCOMP CIRC P CBU at 6 bpm=900 psi.No gas 7,675.0 7,675.0 03:15 04:15 observed at surface on bottoms up strokes.No gains or losses. 9/2/2016 9/2/2016 0.50 COMPZN RPCOMP OWFF P Monitor well.Fluid level slowly 7,675.0 7,675.0 04:15 04:45 dropping in stack. Page 4/12 Report Printed: 9/9/2016 • • • `,-4Operations Summary (with Timelog Depths) 4� 2X-13 Cono t'hitllps Rig: DOYON 141 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(MKS)', 9/2/2016 9/2/2016 1.25 COMPZN RPCOMP TRIP P Slowly POOH f/7675'MD to 7528'MD 7,675.0 7,528.0 04:45 06:00 with 25K to 50K overpull.Well swabbing while pulling pipe and taking fluid while stationary. 9/2/2016 9/2/2016 0.25 COMPZN RPCOMP CIRC P Attempt to bullhead down annulus. 7,528.0 7,528.0 06:00 06:15 Pressure up to 1800 psi.Unable to bullhead.Bleed off pressure. 9/2/2016 9/2/2016 0.75 COMPZN RPCOMP TRIP P Slowly POOH f/7528'MD to 7330'MD 7,528.0 7,330.0 06:15 07:00 with 25K to 50K overpull.Well swabbing while pulling pipe and taking fluid while stationary. 9/2/2016 9/2/2016 0.25 COMPZN RPCOMP CIRC P Bullhead 30 bbls at 6 bpm=600 psi. 7,330.0 7,330.0 07:00 07:15 9/2/2016 9/2/2016 4.25 COMPZN RPCOMP CIRC P 100 bph losses after bullhead 7,330.0 7,330.0 07:15 11:30 operation.Pump three 30 bbls hi-vis pills at 3 bpm= 100 psi slowing pump to 1.5 bpm and simultaneously filling from top with trip tank. 100 bph loss rate continued. 9/2/2016 9/2/2016 1.00 COMPZN RPCOMP TRIP P PJSM-POOH from 7330'MD to to 7,330.0 6,203.0 11:30 12:30 6203'MD filling hole with 50 bph. 9/2/2016 9/2/2016 0.25 COMPZN RPCOMP OTHR P Rig up DHD echo meter and shoot 6,203.0 6,203.0 12:30 12:45 fluid level.Fluid level at 270'filling at 50 bph. 9/2/2016 9/2/2016 0.50 COMPZN RPCOMP TRIP P POOH from 6203'MD to 5572'MD 6,203.0 5,572.0 12:45 13:15 filling at 40 bph. 9/2/2016 9/2/2016 0.25 COMPZN 'RPCOMP OTHR P Rig up DHD echo meter and shoot 5,572.0 5,572.0 13:15 13:30 fluid level.Fluid level at 650'filling at 40 bph. 9/2/2016 9/2/2016 3.75 COMPZN RPCOMP TRIP P POOH from 5572'MD to 310'MD. 5,572.0 310.0 13:30 17:15 Shoot fluid level at 4305'(fluid at 810'),2493'(fluid at 810'),801'(fluid at 950').Increase hole fill to 48 bph plus pipe disp. 9/2/2016 9/2/2016 1.50 COMPZN RPCOMP BHAH P Lay down Baker spear BHA and 310.0 0.0 17:15 18:45 PBR/packer assy. Calc disp=52.17 bbls Act disp=548.94 bbls. 9/2/2016 9/2/2016 0.25 COMPZN RPCOMP RURD P Rig up tubing power tongs.PU false 0.0 0.0 18:45 19:00 table and tool box for blast rings. 9/2/2016 9/2/2016 1.00 COMPZN RPCOMP PULL P PJSM-Lay down one jt.3 1/2"tbg, 0.0 0.0 19:00 20:00 GLM,one jt 3 1/2"tbg,GLM and pup jt. 9/2/2016 9/2/2016 2.50 COMPZN RPCOMP PULL P Lay down 4 blast ring jts,GLM and 0.0 0.0 20:00 22:30 seal assy.Recover 261'of fish. 9/2/2016 9/2/2016 0.75 COMPZN RPCOMP BHAH P PU PBR,packer assy and attempt to 0.0 0.0 22:30 23:15 back out spear from PBR.Unable to release spear. Lay down in shed in one piece. 9/2/2016 9/3/2016 0.75 COMPZN RPCOMP BHAH P Clean and clear rig floor. Mobilize 0.0 0.0 23:15 00:00 milling BHA tools to rig floor. Total daily losses=1105 bbls. 9/3/2016 9/3/2016 1.25 COMPZN RPCOMP BHAH P Make up 6 1/8"Milling assy. 0.0 0.0 00:00 01:15 Page 5/12 Report Printed: 9/9/2016 • Operations Summary (with Timelog Depths) 2X-13 conocophops Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKS) End,Depth(5KB), 9/3/2016 9/3/2016 1.75 COMPZN RPCOMP BHAH T RIH and tag up in wellhead.Pull wear 0.0 0.0 01:15 03:00 ring and inspect.OK.Confirm that mill will pass through wear ring.Set wearring.Attempt to work mill through well head. Mill stacking up on top of 7" casing at 27.55'.Consult with WO engineer. Decision made to wash wellhead. Lay down mill BHA. 9/3/2016 9/3/2016 0.50 COMPZN RPCOMP WWWH T Make up stack washer to one jt.of DP. 0.0 0.0 03:00 03:30 Make up to top drive.Lower stack washer into well.Bullnose on stack washer contacted wear ring and damaged top of wear ring. 9/3/2016 9/3/2016 3.00 COMPZN RPCOMP FISH T Attempt to fish wear ring.Confirm that 0.0 0.0 03:30 06:30 wear ring puller would not engage wear ring.Make up 4 1/2"XO and attempt to screw into wear ring where it is lipped over.Unsuccessful.Force XT 39 tool joint past lip and attempt to pull wear ring.Unsuccessful. 9/3/2016 9/3/2016 2.00 COMPZN RPCOMP WAIT T Wait on retrieval tool.Perform fluid 0.0 0.0 06:30 08:30 level shot. Fluid level at 825'. 9/3/2016 9/3/2016 0.50 COMPZN RPCOMP FISH T Make up retrieval tool. Pull wear ring. 0.0 0.0 08:30 09:00 9/3/2016 9/3/2016 0.75 COMPZN RPCOMP WWWH T Make up stack washer and wash 0.0 0.0 09:00 09:45 wellhead.Lay down stack washer. 9/3/2016 9/3/2016 0.75 COMPZN RPCOMP RURD T Rig up and set 6 3/8"ID wear ring. 0.0 0.0 09:45 10:30 9/3/2016 9/3/2016 0.75 COMPZN RPCOMP BHAH T PJSM-Pick up 6 1/8"mill BHA and 0.0 310.0 10:30 11:15 attempt to RIH.Mill stacking up on top of 7"casing at 27.55'.Change out 6 1/8"packer mill with 6.0"packer mill 9/3/2016 9/3/2016 3.00 COMPZN RPCOMP TRIP P PJSM-RIH w/6"packer mill to 7781' 310.0 7,781.0 11:15 14:15 MD. 9/3/2016 9/3/2016 0.25 COMPZN RPCOMP PULD P PU 4"DP from pipe shed from 7781' 7,781.0 8,068.0 14:15 14:30 MD to 8068'MD.Filling hole at 50 bph.PU=155K SO=95K Rot=120K. Calc disp=54.78 bbls Act disp=137.20 bbls. 9/3/2016 9/3/2016 0.50 COMPZN RPCOMP REAM P Make up TD on jt#247, PU=155K 8,068.0 8,081.0 14:30 15:00 50=95K Rot=120K,60 rpm,8K tq. Wash and ream down from 8068'MD to 8081'MD.Tag lower packer and set down 10K wt.Verofy packer depth at 8081'MD. 9/3/2016 9/3/2016 1.00 COMPZN RPCOMP MILL P Mill up packer from 8081'MD to 8084' 8,081.0 8,096.0 15:00 16:00 MD. 1.5 bpm,50 psi,60 rpm,8-10 tq, 5-13K WOM. PU=155K SO=95K Rot=120K.Push packer down to 8096' MD. 9/3/2016 9/3/2016 0.75 COMPZN RPCOMP PULD P PU 4"DP from pipe shed and RIH 8,096.0 8,200.0 16:00 16:45 pushing packer down from 8096'MD to 8200'MD. 9/3/2016 9/3/2016 0.25 COMPZN RPCOMP CIRC P Pump 50 bbls seawater at 6 bpm,400 8,200.0 8,160.0 16:45 17:00 psi to clean up around packer.No returns.POOH to 8160'MD.Obtain fluid shot.Fluid level at 900'. Page 6/12 Report Printed: 9/9/2016 • • Operations Summary (with Timelog Depths) 2X-13 ConocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr)y Phase Op Code Activity Code Time P-T-X Operation (ftKB)', End Depth(ftKB) 9/3/2016 9/3/2016 2.50 COMPZN RPCOMP TRIP P POOH from 8160'MD to 310'MD. 8,160.0 310.0 17:00 19:30 Continue to fill hole at 50 bph=pipe displacement.Take fluid shot at 6839' MD.Fluid level at 900'. 9/3/2016 9/3/2016 0.50 COMPZN RPCOMP BHAH P Lay down packer mill BHA.Recover 310.0 0.0 19:30 20:00 24#of metal from boot baskets. Calc disp=49.42 bbls Act disp=175.35 bbls 9/3/2016 9/3/2016 0.50 COMPZN RPCOMP BHAH P Clean and clear floor.Mobilize smooth 0.0 0.0 20:00 20:30 OD mill assy tools to rig floor. 9/3/2016 9/3/2016 0.75 COMPZN RPCOMP BHAH T Make up smooth OD mill BHA. 0.0 98.0 20:30 21:15 9/3/2016 9/3/2016 1.00 COMPZN RPCOMP MILL T RIH w/mill assy.Tag up on casing 98.0 119.0 21:15 22:15 restriction at 27.5'MD.Mill through restriction w16.151"mill. 15-20 rpm, 1- 3K tq, 1-2K WOM.Work through restriction x 3.9K slack off weight to push through restriction.Slight bobble seen when pulling up through restriction. 9/3/2016 9/3/2016 0.50 COMPZN RPCOMP BHAH T POOH and lay down mill assy. 119.0 0.0 22:15 22:45 9/3/2016 9/3/2016 0.75 COMPZN RPCOMP BHAH P Clean and clear rig floor.Make up 0.0 312.0 22:45 23:30 packer spear BHA 9/3/2016 9/4/2016 0.50 COMPZN RPCOMP TRIP P RIH w/packer spear assy to 879'MD. 312.0 879.0 23:30 00:00 Continue to fill hole w/seawater at 50 bph.Total daily losses= 1400 bbls. 9/4/2016 9/4/2016 2.00 COMPZN RPCOMP TRIP P RIH w/spear assy.from 879'MD to 879.0 8,169.0 00:00 02:00 8169'MD.Filling hole with seawater at 50 bph. 9/4/2016 9/4/2016 0.50 COMPZN RPCOMP FISH P PU 2 jts DP.Wash down from 8169' 8,169.0 8,169.0 02:00 02:30 MD to 8200'MD.PU=155K SO=97K, 4 bpm,300 psi.Wash down from 8200'MD to 8204'MD.Set down 10K. Pick up to 175K.Observed weight drop off to 160K.Pull up 10'.Set back down and tag up 1'high.Set down 10K.Pick up 20'.Set down and tag up 7'high.Set down 10K.Pull up and observe 5-10K overpull. 9/4/2016 9/4/2016 3.75 COMPZN RPCOMP TRIP P PJSM-POOH from 8169'MD to 300' 8,169.0 300.0 02:30 06:15 MD. Filling hole with seawater at 50 bph+pipe displacement.Take fluid shot at 300'.Fluid level at 830'. 9/4/2016 9/4/2016 1.50 COMPZN RPCOMP BHAH P Stand back DC's.Lay down BHA. 300.0 0.0 06:15 07:45 Attempt to remove spear from fish. Unable to release spear.Lay down spear and fish. 9/4/2016 9/4/2016 0.50 COMPZN WELLPR BHAH P Mobilize clean out BHA tools to rig 0.0 0.0 07:45 08:15 floor. 9/4/2016 9/4/2016 1.50 COMPZN WELLPR BHAH P Make up clean out BHA w/6 1/8" 0.0 342.0 08:15 09:45 string mill. 9/4/2016 9/4/2016 2.75 COMPZN WELLPR TRIP P RIH from 342'MD to 7990'MD. 342.0 7,990.0 09:45 12:30 Encounter tight spot with string mill at top fo upper perfs. PU=160K 50=95K Rot=115K 8K tq,60rpm. Continue filling hole at 50 bph. Page 7/12 Report Printed: 9/9/2016 0 0 g 3 -. Operations Summary (with Timelog Depths) i Y 4 Y1 4. 2X-13 Cillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation {EKE)I End Depth(EKE)', 9/4/2016 9/4/2016 3.00 COMPZN WELLPR MILL P Ream down through perfs from 7990' 7,990.0 8,290.0 12:30 15:30 MD to 8000'MD. 60 rpm,9-10K tq, 1- 2K WOB.Continue to RIH to 8066' MD.Tight at 8066'MD.Ream from 8066'to 8070'MD.RIH to 8195'MD. Make up to top drive.Wash down to 8214'MD at 5 bpm,350 psi.No returns.Tight at 8214'MD.Ream from 8214'MD to 8290'MD. 9/4/2016 9/4/2016 5.00 COMPZN WELLPR TRIP P Pump OOH from 8290'MD to 7908' 8,290.0 342.0 15:30 20:30 MD.4.5 bpm,320 psi.Pull on elevators from 7908'MD to 342'MD. Fill at 50 bph+pipe disp.Take fluid shot at 5930'MD.Fluid level at 810' on first shot and 858'second shot. Calc disp=48 bbls Act disp=253 bbls. 9/4/2016 9/4/2016 2.25 COMPZN WELLPR BHAH P PJSM-Lay down BHA filling at 50 bph. 342.0 0.0 20:30 22:45 Recover 25#metal on magnets and 25#metal in boot baskets. 9/4/2016 9/4/2016 0.50 COMPZN WELLPR BHAH P Clean and clear rig floor of BHA tools. 0.0 0.0 22:45 23:15 9/4/2016 9/4/2016 0.50 COMPZN WELLPR ELNE P Rig up Dutch riser. 0.0 0.0 23:15 23:45 9/4/2016 9/5/2016 0.25 COMPZN WELLPR ELNE P Spot SLB E-line truck. Rig up wireline. 0.0 0.0 23:45 00:00 Daily losses=1619 bbls 9/5/2016 9/5/2016 0.75 COMPZN WELLPR ELNE P PJSM-Continue to rig up SLB wireline. 0.0 0.0 00:00 00:45 9/5/2016 9/5/2016 2.75 COMPZN WELLPR ELNE P RIH w/6.02"gauge ring/junk basket to 0.0 0.0 00:45 03:30 8338'WLM.POOH w/e-line. 9/5/2016 9/5/2016 0.50 COMPZN WELLPR ELNE P PJSM-Rig down wireline. 0.0 0.0 03:30 04:00 9/5/2016 9/5/2016 1.25 COMPZN RPCOMP PUTB P PJSM-Rig up tubing power tongs and 0.0 0.0 04:00 05:15 pick up tandem wedge/packer assy as per detail.(WLEG 4.57"OD x 3"ID, GX nipple w/PXX plug and prong, tandem wedge assy,SBE, Baker Type F packer) 9/5/2016 9/5/2016 2.00 COMPZN RPCOMP ELNE P PJSM-Rig up e-line and make up to 0.0 0.0 05:15 07:15 tandem wedge/packer assy. 9/5/2016 9/5/2016 4.00 COMPZN RPCOMP ELNE P RIH w/tandem wedge assy.Log on 0.0 0.0 07:15 11:15 depth w/top of wedge assembly at 8138'original KB.Top of packer at 8120'original KB.Set packer.POOH with wireline. Take fluid shot.Fluid level at 830'. 9/5/2016 9/5/2016 0.75 COMPZN RPCOMP ELNE P PJSM-Rig down SLB wireline. 0.0 0.0 11:15 12:00 OA=75 psi 9/5/2016 9/5/2016 1.00 COMPZN RPCOMP ELNE P Rig down Dutch riser.Clean and clear 0.0 0.0 12:00 13:00 rig floor of Baker lower completion running equip. 9/5/2016 9/5/2016 0.50 COMPZN RPCOMP BHAH P Make up Baker test packer BHA to 0.0 287.0 13:00 13:30 287'MD. 9/5/2016 9/5/2016 1.00 COMPZN RPCOMP TRIP P RIH from 287'MD to 1986'MD. 287.0 1,986.0 13:30 14:30 Page 8/12 Report Printed: 9/9/2016 • • Operations Summary (with Timelog Depths) 2X-13 conaccittoups Rig: DOYON 141 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) 9/5/2016 9/5/2016 0.75 COMPZN RPCOMP MPSP P Pump 40 bbls seawater down DP at 2 1,986.0 1,986.0 14:30 15:15 bpm,50 psi.No returns.Set test packer. Establish circulation through kill line.Test Baker test packer to 2500 psi/5 min.charted.Unseat test packer.Pump 10 bbls seawater down DP,2 bpm,50 psi.No returns 9/5/2016 9/5/2016 1.25 COMPZN RPCOMP TRIP P RIH from 1986'MD to 5109'MD. 1,986.0 5,109.0 15:15 16:30 Filling hole w/50 bbls/hr seawater. 9/5/2016 9/5/2016 0.50 COMPZN RPCOMP SVRG P Service dynamatic,TD and traveling 5,109.0 5,109.0 16:30 17:00 blocks. 9/5/2016 9/5/2016 2.25 COMPZN RPCOMP TRIP P RIH from 5109'MD to 8071'MD. 5,109.0 8,071.0 17:00 19:15 Filling hole w/50 bbls/hr seawater. 9/5/2016 9/5/2016 2.25 COMPZN RPCOMP PRTS P Set Baker test packer w/center of 8,071.0 8,104.0 19:15 21:30 element at 8066'MD.Fill DP and bleed air.Test permanent packer to 2500 psi.Would not test.Bleed off pressure,rig down test equipment and RIH to 8104'MD.Set test packer center of element at 8099'MD.Test permanent packer to 2500 psi/10 mins charted.Good test.Rig down test equipment. 9/5/2016 9/5/2016 0.50 COMPZN RPCOMP PULD P POOH laying down DP to 7916'MD. 8,104.0 7,916.0 21:30 22:00 9/5/2016 9/5/2016 0.75 COMPZN RPCOMP PRTS P Set test packer center of element at 7,916.0 7,916.0 22:00 22:45 7911'MD. Pump through kill line to purge air from system.Test casing to 2500 psi/10 min charted.Rig down test equip.Blow down kill line and release test packer. 9/5/2016 9/6/2016 1.25 COMPZN RPCOMP SLPC P PJSM-Slip and cut 48'drilling line. 7,916.0 7,916.0 22:45 00:00 Service drawworks. Daily losses=1228 bbls 9/6/2016 9/6/2016 5.25 COMPZN RPCOMP PULD P PJSM-POOH laying down DP.Lay 7,916.0 276.0 00:00 05:15 down total of 252 jts 4"DP. 9/6/2016 9/6/2016 1.00 COMPZN RPCOMP BHAH P Lay down 9 ea 4 3/4"DC's and test 276.0 0.0 05:15 06:15 packer. 9/6/2016 9/6/2016 0.25 COMPZN RPCOMP RURD P PJSM-Pull wear ring. 0.0 0.0 06:15 06:30 9/6/2016 9/6/2016 1.75 COMPZN RPCOMP RURD P PJSM-Pick up completion tools and rig 0.0 0.0 06:30 08:15 up to run upper completion 9/6/2016 9/6/2016 3.75 COMPZN RPCOMP PUTB P PJSM-Run upper completion.PU seal 0.0 2,444.0 08:15 12:00 assy,locator sub,4 blast joints GLM, X nipple,FHL Packer,seal assy,4 GLM's and 67 jts 3 1/2"EUE 8rd Mod 9.3#L-80 tubing to 2444'MD.Fill hole at 50 bph. OA=60 psi. 9/6/2016 9/6/2016 3.00 COMPZN RPCOMP PUTB P PJSM-Run upper completion. PU seal 2,444.0 4,630.0 12:00 15:00 assy, 2 GLM's,Baker Orbit valve and 68jts 3 1/2"EUE 8rd Mod 9.3# L-80 tubing to 4630'MD.Fill hole at 50 bph. 9/6/2016 9/6/2016 3.00 COMPZN RPCOMP OTHR P PJSM-Rig up control line spooler.Tie 4,630.0 4,630.0 15:00 18:00 in control lines to Baker Orbit valve. Test open and close side of control line to 5000 psi/10 mins. Page 9/12 Report Printed: 9/9/2016 • • • Operations Summary (with Timelog Depths) 2X-13 5`a Conactx- niiii Rig: DOYON 141 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)', 9/6/2016 9/6/2016 4.50 COMPZN RPCOMP PUTB P PJSM-Run upper completion.PU, 1 4,630.0 8,091.0 18:00 22:30 GLM. 110jts 3 1/2"EUE 8rd Mod 9.3# L-80 tubing to 8091'MD.Install cannon clamps on each joint.Fill hole at 50 bph. 9/6/2016 9/6/2016 1.00 COMPZN RPCOMP HOSO P Rig up head pin and circ equip on jt 8,091.0 8,124.0 22:30 23:30 #245.RIH to 8115'MD while pumping at 1 bpm,50 psi.Observe seal entry at 8111'MD with pressure increase to 200 psi.Shut down pump and bleed pressure.RIH to No-go at 8124'MD. 9/6/2016 9/7/2016 0.50 COMPZN RPCOMP CRIH P Pick up to 8109'MD.Confirm 8,124.0 8,109.0 23:30 00:00 circulation.Pump 20 bbls Conqor 303A inhibited seawater followed by 65 bbls uninhibited seawater to spot between packers.3 bpm,60 psi. Daily losses=1136 bbls 9/7/2016 9/7/2016 0.25 COMPZN RPCOMP CRIH P Continue to spot Conqor 303A 8,109.0 8,109.0 00:00 00:15 inhibited seawater. 9/7/2016 9/7/2016 0.50 COMPZN RPCOMP PACK P Shut down pump and open bleeder. 8,109.0 7,777.0 00:15 00:45 Sting seals and space out 1'from fully located at 8115'MD.PU=100K 50=65K. Pressure up on tbg to 2500 psi and hold for 10 min to set FHL packer.Bleed down to 1800 psi.and shear out of PBR w/116K up weight. PU 5'and RIH to confirm no-go. 9/7/2016 9/7/2016 1.75 COMPZN RPCOMP HOSO P Lay down jts#245,244 and 243 for 7,777.0 7,726.0 00:45 02:30 space out. PU 3 space out pup jts (6.17', 10.22'and 10.31'). PU jt#243, hanger and landing jt. 9/7/2016 9/7/2016 1.00 COMPZN RPCOMP THGR P Tie in orbit valve control lines to 7,726.0 7,726.0 02:30 03:30 hanger.Test both lines to 5000 psi/10 min. 9/7/2016 9/7/2016 0.25 COMPZN RPCOMP HOSO P Pump down tbg at 1 bpm,50 psi. 7,726.0 7,763.0 03:30 03:45 Slack off and locate top of PBR at 7765'MD.Observe pressure increase to 100 psi.Shut down pump,bleed off pressure and pick up 2'. 9/7/2016 9/7/2016 1.00 COMPZN RPCOMP CRIH P PJSM-Pump 270 bbls of Conqor 303A 7,763.0 7,763.0 03:45 04:45 inhibited seawater down followed by 15 bbls seawater down tubing.5 bpm at 475 psi. 9/7/2016 9/7/2016 0.50 COMPZN RPCOMP RURD P Drain BOPE and blow down all lines. 7,763.0 7,763.0 04:45 05:15 9/7/2016 9/7/2016 0.25 COMPZN RPCOMP TRIP P Land hanger and RILDS.Spaced out 7,763.0 7,775.0 05:15 05:30 2'from fully located. Ran 243 jts 3 1/2"L-80 EUE 8rd Mod 9.3#tubing.No remakes/No rejects. Ran total of 111 SlingCo 3 1/2"x 25.25 cross coupling clamps. 9/7/2016 9/7/2016 1.00 COMPZN RPCOMP PRTS P Test tubing to 3000 psi/10 mins 7,775.0 7,775.0 05:30 06:30 charted.Bleed pressure to 2000 psi and test IA to 2500 psi/30 mins charted.Dump tbg pressure and shear out SOV.Pressure equalized and bled off confirming shear out. Page 10/12 Report Printed: 9/9/2016 • • 0 Operations Summary (with Timelog Depths) 2X-13 Con000PhiiHps Rig: DOYON 141 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(EKE)', 9/7/2016 9/7/2016 0.50 COMPZN RPCOMP PRTS P Rig up and confirm circulation through 7,775.0 7,775.0 06:30 07:00 SOV in both directions.Close orbit valve test from below to 1000 psi/10 min and from above 1000 psi/10 min charted. 9/7/2016 9/7/2016 0.50 COMPZN RPCOMP RURD P Rig down test equipment.Lay down 7,775.0 0.0 07:00 07:30 landing jt. 9/7/2016 9/7/2016 0.50 COMPZN WHDBOP MPSP P Set BPV.Test in direction of flow 1000 0.0 0.0 07:30 08:00 psi/5 min.charted. 9/7/2016 9/7/2016 0.75 COMPZN WHDBOP RURD P Rig down tubing equipment on rig floor 0.0 0.0 08:00 08:45 and lay down beaver slide. 9/7/2016 9/7/2016 1.25 COMPZN WHDBOP NUND P PJSM-Nipple down BOPE. 0.0 0.0 08:45 10:00 9/7/2016 9/7/2016 3.00 COMPZN WHDBOP NUND P Nipple up adaper flange and tree.Test 0.0 0.0 10:00 13:00 hanger seals to 250/5000 psi for 5/10 min. 9/7/2016 9/7/2016 1.00 COMPZN WHDBOP NUND P Rotate swab valve on tree 180°. 0.0 0.0 13:00 14:00 Continue to nipple up tree.Sim- ops/Rig up to test tree and freeze protect. 9/7/2016 9/7/2016 1.00 COMPZN WHDBOP NUND P Build,install and test orbit valve 0.0 0.0 14:00 15:00 manifold.Open orbit valve. 9/7/2016 9/7/2016 2.50 COMPZN WHDBOP PRTS P PJSM-Test surface lines to 5000 psi. 0.0 0.0 15:00 17:30 Fluid pack tree.Bleed air and test tree to 250/5000 psi for 5 min each.Bleed off pressure.Open IA valve to confirm no pressure. 9/7/2016 9/7/2016 0.25 COMPZN WHDBOP MPSP P Dry rod out BPV 0.0 0.0 17:30 17:45 9/7/2016 9/7/2016 1.25 COMPZN WHDBOP FRZP P Pump 80 bbls diesel freeze protect 0.0 0.0 17:45 19:00 down IA taking returns up tbg to rock washer. ICP=800 psi FCP=1000 psi. Open communication from IA to tubing and allow to u-tube for 30 min. IA=0 psi Tbg=0 psi. 9/7/2016 9/7/2016 0.25 COMPZN WHDBOP MPSP P Set 3 1/2"Type H BPV with dry rod. 0.0 0.0 19:00 19:15 9/7/2016 9/7/2016 0.75 DEMOB MOVE RURD P Blow down and rig down circ lines. 0.0 0.0 19:15 20:00 Install flanges and gauges and secure well. 9/7/2016 9/8/2016 4.00 DEMOB MOVE RURD P Prep rig for move and annual rig 0.0 0.0 20:00 00:00 maintenance.Clean rig floor.Remove rotary table cover and clean rotary table.Clean drawworks drip pan. Drain oil,remove suction dampners, open up fluid ends,pull valves from both mud pumps.Remove plugs from charge pumps.Disconnect high pressure and suction lines.Remove agitator from pit room. Daily losses=361 bbls Page 11/12 Report Printed: 9/9/2016 • • Operations Summary (with Timelog Depths) '.1:l'L':''''' l'''''''7-- '', ,0 2X-13 Conoc.oPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKEi)', End Depth(ftKB) 9/8/2016 9/8/2016 12.00 DEMOB MOVE RURD P PJSM-Prep rig for move and annual 0.0 0.0 00:00 12:00 maintenance.Clean drip pan.Install floor plate.Clean out cellar w/super sucker.Clean grating and trough on drag chain.Clean pit#6. Remove liners from mud pumps. Remove drawworks covers and clean brake linkage and around drawworks.Clean out pipe racks.Clean radiator on pump room cold start.Remove bolts on blind rams.Lay down all subs from rig floor and sub rack.lnstall pressure washer in pit room.Remove lower rams.Rack back BOPE. Rig released @ 12:00 hrs 9/8/16 Page 12/12 Report Printed: 9/9/2016 KUP P D 2X-13 ConocoPhillips Well Attribute Max Angle It TD Alaska.Inc.. Wellbore API/UWI Field Name Wellbore Status ncl(^) MD(ftKB) Act Btm(ftKB) gft, 500292119700 KUPARUK RIVER UNIT PROD 52.57 5,400.00 8,543.0 `- .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2x-13,9/26/201611:34:06 AM SSSV:NONE 150 10/29/2014 Last WO: 9/8/2016 39.00 11/13/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,357.0 9/14/2016 Rev Reason:PULLED PLUG 8 GLV C/O pproven 9/21/2016 HANGER;30.5 l -'.!id" Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len II...Grade Top Thread CONDUCTOR 16 15.062 37.0 103.0 103.0 62.58 H-40 WELDED i�, . ,fir _,.Casing Description OD(in) ID(in) Top(ORB) -Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread s SURFACE 95/8 8.921 35.9 3,747.2 3,029.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread al PRODUCTION 7 6.276 33.6 8,509.7 6,167.1 26.00 J-55 BTC Lev....CONDUCTOR,37.0-1030 • ., a.-.Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(TVD)(...Wt(113/ft) Grade Top Connection 3.5"Selective 3 1/2 2.992 30.5 8,131 4 5,896.8 9.30 L-80 EUE 8rd Mod Completion 2016 RWO Completion Details GAS LIFT;2,932.3 Nominal ID 1111.Allik Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 1 m_ 30.5 30.5 0.05 HANGER Tubing Hanger,Cameron,CSX,7-1/16"x 3-1/2"EUE 8rd 2.950 ORBIT VALVE;3,498.0 F Boo x Boo 11 3,498.0 2,866.6 48.97 ORBIT Baker Orbit Valve SN:1169183 2.880 IVALVE SURFACE,35.9.3,7472--.1 t 7,763.0 5,626.2 42.50 LOCATOR Locator Sub,Baker,GBH-22 3.000 01 7,763.4 5,626.4 42.50 SEAL ASSY Seal Assembly,Baker,80-00 located 2'up.(total seal 3.000 length=12.45') GAS LIFT;4,781.9 2: 7,765.4 5,627.9 42.50 PBR PBR,Baker,80-00 4.000 7,778.8 5,637.8 42.49 PACKER Packer,Baker,4782 FHL(shear release pinned at 60k) 3.000 7,832.3 5,677.2 42.43 NIPPLE X Nipple,Camco,2.813", SN:C-3572208 2.813 GAS LIFT;6,227.6 II 7,940.9 5,757.5 42.43 BLAST Blast Joint.9.38 L-80 3%EUEM box x 3%HYD 511 pin 2.992 RINGS 7,972.3 5,780.7 42.50 BLAST Blast joint 3%9.38 L-80 HYD 511 box x pin 2.992 RINGS GAS LIFT,7.140.2 8,119.8 5,888.3 43.73 LOCATOR Locator Sub,Baker,GBH-22 3.000 8,120.2 5,888.7 43.73 SEAL ASSY Seal Assembly,Baker,80-40 located one foot up.(total 3.000 seal length=12.19') GAS LIFT;7.708.0 -"- - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(ID/ft) Grade Top Connection 2016 RWO WEDGE 5.935 2.992 8,120.4 8,180.5 5,932.2 na EUE ASSY LOCATOR;7,763.0 'kill Com letion Details SEAL ASSY;7,763.3 PBR;7,765.3 Nominal ID l� Completion (ftKB) Top(TVD)(ftKB) Top Incl(3 Item Des Com (in) PACKER;7,778.8 8,120.4 5,888.8 43.73 LOCATOR NO GO collar.4.40"Drifted 3.98 4.400 8,121.3 5,889.4 43.74 PACKER Baker"F"Production Packer 4.000 • : : . . .. .. 8,123.7 5,891.2 43.74 SBE Baker 80-40 12.26'SBE 4.000 8,143.0 5,905.1 43.80 WEDGE Upper Wedge Assembly#2 2.992 .. :,,! ti I 8,157.0 5,915.2 43.85 NIPPLE GX Nipple,HES,2.813",SN:7256 2.813 8,162.8 5,919.4 43.86 WEDGE Lower Wedge Assembly#1 2.992 8,176.8 5,929.5 43.91 NIPPLE GX Nipple 2.813 8,180.0 5,931.8 43.92 WLEG WLEG 4.57"OD x 3"ID.Drifted 2.91". 3.000 GAS LIFT;7,8860 iOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (3 Des Com Run Date ID(in) 8,290.0 6,010.8 44.36 FISH 1 1/2"CV 8 RKP Latch Dropped downhole. 4/3/1992 0.000 9/4/2016.D 141 Cleaned down to 8290.6.125 bit. I BLAST RINGS;7910.9 8,355.0 6,057.2 44.55 FISH NIP Reducer 6"Shear Out Sub Mechanically 12/1/1993 0.000 _ fill sheared;dropped to rathole APERF;7,970.0$,014.0 p I BLAST RINGS;7,972.3_. - g. Perforations&Slots (PERF,8,014.0-8,060.0 [fl6 '.I Shot Dens Ili: Top(Tool Btm(TVD) (shots/ ME Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn GAS LIFT;8,073.1 ;' 7,970.0 8,014.0 5,779.0 5,811.4 UNIT D,C-4, 11/18/1990 12.0 APERF 90 deg.ph;5"HSC 2X-13 8,014.0 8.060.0 5,811.4 5,845.0 C-4,C-2,C-1, 12/5/1984 12.0 IPERF 120 deg.ph;DA 5" 2X-13 Jumbo Jet Csg 8,214.0 8,240.(1 5.956.3 5,974.9 A-4,2X-13 12/5/1984 4.0 IPERF 120 deg.ph;0.31-0.35 diar holes;DA 4"Jumbo Jet Csg 8,248.0 8,288.0 5,980.7 6,009.3 A-3,2X-13 12/5/1984 4.0 IPERF 120 deg.ph;0.31-0.35 LOCATOR;8,719.8 diA holes;DA 4"Jumbo LOCATOR;8,720.4 i Jet Csg PACKER;8,121.2 8,248.0 8,288.0 5,980.7 6,009.3 A-3,2X-13 11/22/1993 4.0 RPERF 180 deg.ph;2.5"Titan SEAL ASSY;8,120.2 r. c -qa BBE;8,123.7 r prz--.Pup;8.133.2 Mandrel Inserts 8.133.8 �I `� St Tubing- E;8,143.0 i WEDGE;8,743.0 atii Tubing-Pup;8,153.6 H c Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com Tubing-Pup;8,167.9 WEDGE;8,162.8 r 1� 2,932.3 2,486.7 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,277.0 9/14/2016 Tubing-Pup;8,173.4 1 2 4,781.9 3,700.3 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,275.0 9/14/2016 Tubing-Pup,8,177.8 `< .. 3 6,227.6 4,5972 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,277.0 9/13/2016 WLEG;8,105.0 - 4 7,140.2 5,1863 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,273.0 9/13/2016 IPERF;8,214.0-8,240.0-, 5 7,706.0 5,584.1 Camco MMG 1 1/2 GAS LIFT OV RKP 0.250 0.0 9/13/2016 RPERF;8,248 0-8,288.0 6 7,886.0 5,716.9 Camco MMG 1 1/2 PROD HFCV RKP 0.000 0.0 9/15/2016 IPERF;8,248.0-8,288.01 7 8,073.1 5,854.6 Camco MMG 11/2 PROD HFCV RKP 0.000 0.0 905/2016 FISH;6,290.0 Notes:General&Safety End Date Annotation FISH;8,355.0 9/14/2016 NOTE:Orbit valve control lines/system at wellhead marked open/close. 9/14/2016 NOTE:Orbit valve is not a safety valve:it does not fail to closed position. PRODUCTION;33.6-8,509.7 KUP POD 2X-13 Conc caPhillips 1 • • Alaska Inc. c0Noc anawps ,,, H2S(ppm) Date 2X-13,9262018 11:34:06 AM 135 11/19/2015 Vertical schema..actual) HANGER.30.5 I": I It M CONDUCTOR,37.0.103.0• -A. GAS LIFT,2,932.3 ' AR ORBIT VALVE;3,498 0 I- AK SURFACE;35.9.3,747.21 ti; 1 GAS LIFT,4,781.9 GAS LIFT;6,227.6 GAS LIFT,7,140.2 fni 111 GAS LIFT;7,706.0 WEB LOCATOR;7,763.0 SEAL ASSY;7,763.3 PBR;7,765.3 PACKER;7,778.8 yGAS LIFT',7,886.0 BLAST RINGS;7,940.9 _�$_.. __ APERF;7,970.08,014.0----. 4.14 BLAST RINGS;7,972.3.. y— - ,-- !PERE;8,014.08,060.0—• re- Ng GAS LIFT;8,073.1 aR; LOCATOR;8,119.8 LOCATOR;8,120.4 PACKER;8,121.2 SEAL ASSY;8,120 2N SBE;8,123.7 ;` s X0 Threads;8,133.2 $.. Tubing-Pup;8,133.8- g, Tubing-Pup;8,138.0 fit - WEDGE 8143.0 Tubing-Pup,8,153.8 WE TubiPup 8,157.9 & WEDGE 8,162.8 f Tubing-PuP 8,173.4 Tubing-Pup;8,177.8 WLEG;8,180.0 / IPERF;8,214.04245.0—j I RPERF;8,248.08,288.01 T IPERF;6,248.0-8,288.0 FISH;8,290.0 FISH;8,355.0 PRODUCTION;33.6-8,509.7 qq w • r d O C' x c>" " 3 V 1. `� (O dO +, r6 T t0 NO � CO o U O > co +.. ° N O .-- c.) a, a C C p 10 V '13 .0 aW Jw 0 -o =5CO O v > coQhQ a o z o O U E a R. O Q CO CO CO cc cc CO CD CO CO v m -+ +. O to 1 Q H Y p a a a a a a u m m 'o +' v) 0 J m CO d 0 v d ;«- C t '3 v, N to 0 � N co !n L C u aJ 2 N N M ,A 6 r OO O c' '.-• '- .,-. v- ,-. 0 +' i C u 73 r0 O .-u cc ~ C O O O O O O O O O ,_ a) p i C w U 0aW W W W W W W W W .J) N OA I- LL LL LL LL LL LL LL LL LL +-' a) v v -0 O Q J J J J J J J J J a > C N C c = C, 4 Z Z Z Z Z Z Z Z Z a s a) 0 v 0) LL LL LL LL LL LL LL LL LL CC . - CID-- C > ( pp _ C m co .uJ > + a1 O y v a o 4V 5 y c ai u v .. t+ v V 2 z0 c a m = > V In C 0 0 0 O Q Ce O ° N 0 ga a, Q w J N J 16 J f6 N \ Z m LL U a U m a w I� u c cr E . v V 0 113 2 13 gcxpg, Ly i� ,o LL, o Cx0 V a J J J J J J J J J cu 4 0.0 W W W W W W W W W = E w > > > > > > > > > r "�. in z Y Y Y Y Y Y Y Y Y o r4 2 rt d' W d' C4 Q' CC Av › w Q Q Q Q Q Q Q Q Q ,� a a a a a a LL a a Y o Y Y Y Y Y Y Y Y Y 0 on co Na — CU OC NO ( 0NX (7)0 O (41 , v) I) CD CD CD LO CO N V 0 0 0 0 0 O o 0 0 0 O O o 0 0 o O O o 0 0 0 0 0 O o 0 v LAMM to CV LL LL LL LL LL LL LL lL LL lli�Afel O O O H O F F FO- H as ` c-W1 0. w> InCICLC1O0OCICC CO k VI U hi cr) < 2 o 0 0 0 0 o C �L W 0 O o 0 0 0 0 0 0 40 i �"�L tG O, CO O _M CO N h O in O {n f0 LO O O T LO O U Ii�� N - N N N O O O N N y. N N N N N N N N N , __ R N N N N N N N N N •, N C1 0 O 0 0 O O 0 O O - `•'� 0 0 0 0 0 0 0 0 0 a+ O v tw., as C ,n ,n ,n o o 0 U) U) Ln a u -' az ,m�, ^,n a, m v �i E ar > c aa uWLis — ` i E z b 00 m z N T. N n- 0 0 = E H 6. Q 0 N J _IL,- N N N a a .IL N N E Z N 11 _ N v CS Q pl-k I 11 ( 1 I I Ca QJ ra it a a Q T4sq -\�t-t • • 2—(0—t,t) WELL LOG TRANSMITTAL#902996305 DATA LOGGED L i t /201( K BENDER To: Alaska Oil and Gas Conservation Comm. January 21, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED I JAN 26 RE: Production Profile: 2X-13 AOGCC Run Date: 12/17/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2X-13 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21197-00 Production Profile Log 1 Color Log 50-029-21197-00 SCANNED r� 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: MALe4za,d6t Imai~2roject Well History File' Cover~,ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .J ~2 ~- _1-]_ L~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] [] Grayscale items: [] [] Poor Quality Originals: Other: ~ NOTES' Diskettes, No. Other. No/Type OVERSIZED (Scannable) [3 Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [::3 : Logs of various kinds Other DATE: '¢~'"~ ~-,-,-,-,-,-,-,-,-~-~ / S/ BY: B~ BREN VINCENT SHERYL MARIA LOWELL Project Proofing BY: BEVERLY BREN VI~IT SHERYL MARIA LOWELl. DATE: Scanning Preparation ._.~ x 30 = ~(~ + {~' BY: BEVERLY [~ VINCENT SHERYL MARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE' PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ NO BY: BEVERLY BREN VINCE~ARIA LOWELL DATE:/¢3/~/~S/~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL , General Notes or Comments about this file: DATE: IS~ Quality Checked 10125/02Rev3NOTScanned.wpd WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 `~ 4 4 ~ ~: RE: Production Profile: 2X-13 Run Date: 7/30/2010 August 31, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2X-13 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21197-00 Production Profile Log 1 Color Log 50-029-21197-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton com r ° '~ ~ f ~ ~ ./ z .~~,. Date: _ , .) ~~ ~ JT--i~.j~~ e /'~~~ ~~~ I ~~~ Signed: • =~~a~d~~ac~r' S ~l~~.at~a• ~. COr1000P~'llll! S p Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~~~3 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25, 2008 and the corrosion inhibitor/sealant was pumped December 3, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, a Perry Kl ' ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2X-10 184-163 14' 1.75 29" 11/25/2008 9.77 12/3/2008 2X-13 184-174 7' 1.15 23" 11/25/2008 3.83 12/3/2008 2X-14 184-175 17' 3.40 28" 11/25/2008 6.80 12/3/2008 2X-15 184-176 24" NA 24" NA 3.25 12/3/2008 2X-16 184-172 7' 0.95 21" 11/25/2008 3.40 12/3/2008 c~ 04/20/07 -- Schlumberger NO. 4239 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NAY 0 4 2007 t~L{-I~( sGANNED MAY ()' 7 2007 Field: Kuparuk Oil If, Con"'. Cnmmi¡~$inn Well Job# Log Description BL Color CD Date 2F-17 11632699 INJECTION PROFILE 04/30/07 1 1G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L 1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04/24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. rO . . Schlumberger RECEIVED NO. 3638 Schlumberger -DCS ,jAN 0 9 2006 2525 Gambell Street, Suite 400 Company: Anchorage, AK 99503-2838 A TTN: Beth ~!aS,\3 CH & G;s CünS. Commissjon And1crage Field: Well Job # Log Description Date BL 20-02 N/A SHUT IN BOTTOM PRESSURE 12/03/05 1 1 A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE WIDEFT 12/27/05 1 2U-08 11166750 PROD PROFILE WIDEFT 12/28/05 1 2X-13/PA-/74- 11144057 GLS 12/25/05 1 2V -11 11166736 PROD PROFILE W/DEFT 12/16/05 1 3Q-09 11166737 LDL 12/17/05 1 3S-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15 11144058 PROD PROFILE W/DEFT 12/26/05 1 3Q-09 11144055 LDL 12/23/05 1 2V -01 11144056 INJECTION PROFILE 12/24/05 1 SIGNE&è1!.lQOO1-¡ SCANNED .JAN 3 1 2006 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 12/30/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color - CD ~' (':"".? IL, ! i,:::JJ Lb ) / .I / ALASKA OIL AND GAS/ CONSERVATION COMMISSION / November 9, 2005 ) a-\ "....<J ,''''''''' .... ¡ I,' "~, 'I' : ;,"". ' ,'..:', "., I,f I ~J! i :Ul p / ß\ i ¡ I~,:::,) ! [ D-1J L~ '1~'7' ffi· -, ì i ¡,'/ .i ,'I \ j I ~ .:' /\~ 'U' 01') ,JJ I , i,' \ .' I' ~ Î !, i \ i: !..~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 .If" \.... V \~Ù(-~_\:? ~ Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2X ("KRU 2X") pad on October 7, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction with Conservation Order 348 requires all wells in the Kuparuk River field to be equipped with a Comn1Ìssion approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a failure rate exceeds 10 percent. Effective October 7, 2005 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SVS test. Sincerely, : - '-; TJ \~{ ð1l,iß.j b ' 1\ t-if James B. Regg Petroleum Inspection Supervisor .-....;.,.~' ~'_..--.-..- Attachment cc: AOGCC Inspectors 5tA.NNEL NOV 1 ? 2005 Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv Comm Pad: KfW_2X Insp Dt 10/7/2005 Inspected by John Spaulding Interval 90 Days InspNo svsJS051007213641 Field Name KUPARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Noble Well Nllmbe," 1_ . ~~.~O~_ _ 2X-10 2X-11 2X-13 2X-14 2X-IS - -- .- - --- 2X-16 2X-17 I,~- _~~~~- _--- I j- Comments Related Insp: Reason 180-Day Src: Inspector - --- - - -- --- ----- Performance ,--~~---- -~.~--- _~_____u _~'·_'__"~'_I Failures Failure Rate ! 2 11.11% I __~___~-===~_-____J Permit Separ Set UP Test Test Test Date SI Oil,WAG,GfNJ, Inner Outer Tubing Number PSI PSI Trip Code Code Code GAS,CYCLE, SI PSI PSI PSI Yes/No Yes/No - -18-41620 96 70 60 H--P------4,- --------I-OII~---¡-UOO-·-~900------200----- ·Ye~~- -~--------- -- ..__________n_ _ _n __ _, 'un ,__~__. ____ _ _ __ _ ____,_+______ ,______ 1841630 96 70 60 P P I-OIL 1]50 600 150 Yes No Ï"s4i640' -¡ 96 u -70 --:10 P ~_-=p-~-=_- __1_ 1 ~?~=~ -- ~J"~SO-~___-I200=- 150 u-~-=-~~_--~~_~-Y~~---- ,- 1841740 96 70 55 P P I-OIL 1050 700 150 Yes No 1841750 96 70 50 P P ¡ I-OIL 1300 930 180 Yes I No ·~~84-Ci~() -~-~ 9~_ t:- 70 10 ,_¡___n_p__ ¡---I ~oïL- -, -1000-- . -900------200 --- ~~y~~ ----1- N~--- ;~test~d tripped at65psi ok 841720 96 70 ·6'0'- --p·----I;· I -]---)·~ÕIL '-n----1350- 1000" ~200'---y~~--¡I' --"No ___m___ ---- nn.________n___ "Y5Ï710 - 96 -I 70 65 P - ---p -- n_ --1 -1- --~OIl.~ ---- --1000-- -- 600 ..---20Õ-----y~~" ---N~--- --~ ---- -1951600 - 96-1 70-·- -60-' _p___np__u_"_.. r-----~-î---l-=ÒIL---12i5---Wõ----200---- Yes----r-N~----- ___Hn n____u__ '1 __.. _______.__, _. .1_____,., .__u____..__· ____'..~_n__,_Lu,___._ ___._____~____ __.,_~____,,___----.L......,.___,_.u_ _ __..,______________. _, .J 2- I 2a wing leaked -unable Lo Lest, requested repairs prior to testing again 18 Wells Components 9 -------- - - --- -- L_ -------. - ---- i!$$ \. o p y Wedncsday, November 09, 2005 I -~~~.=-j ! -.-/ ~ \ ) ') @~ ~ ~-e ~;;1: !fJ\ ~ fE\ @ ;~~ @ .. -fL, - J: ~ J W ~10j r5f)_UIfU / / AT,ASIiAOILAND GAS / CONSERVATION COMMISSION / . October 25,2004 c¡¥',1~ FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 l\nchorage,AIC 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed. an inspection of your well safety valve system (8YS) at&t!~~~\RiV'ergnit2X("KRU 2X") pad on October15, 2004. Attached is a copy of the Inspecflon:Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SYS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a. subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Also noted during the Commission's inspection were unsupported flow piping and pilots on KRU 2X pad, specifically Wells 2X-03 and 2X-09. These were not included in the failure rate calculation but clearly are deficiencies in the SVS that must be corrected. Effective October 15, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on }(RU 2X must be tested every 90 days. When testing is sched ed, you must notify the Commission Field Inspector at 907-659-2714 to provide ~ortu' 0 witness the SVS test. ~ : 1. Norman Sincerely, 0Á1 ¿/ 0 ~ -~~ Daniel T. Seamount, Jr. Chairman Commissioner Attach. copy by email: Bob Fleckenstein; AOGCC Inspectors 5~:r{\~;~Ntr) NI)V 04 2.0Û¿~ Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv~ \D\zSlû4- Comm Pad: KRU_2X Insp Dt 10/15/200 Inspected by JefIJones Interval 90 Days InspNo svsJJ041019163228 Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason ISO-Day Src: Inspector "'''-J, Well Permit Separ Set UP Test Test Test Date SI Oil, W AG,GINJ, Inner Number Number PSI PSI Trip Code Code Code GAS,CYCLE, SI PSI YeslNo Y eslNo 2X-03 1831090 I 2700 I 2000 1900 I P I P I W AGIN Flow piping & pilot not supported properly; loose & wobbly. 2X -08 1831140 2700 2000 1750 P P W AGIN 2X-09 1841620 98 70 50 P P I-OIL Flow piping & pilot not supported properly; loose & wobbly. ~ 2X-IO 1841630 98 70 60 P P I-OIL 2X-ll 1841640 98 70 65 P 4 I-OIL 750 900 175 No Yes IA x OA communication 2X-12A 1951760 98 70 65 P P I-OIL wing valve leaks. 2X-13 1841740 98 70 44 3 P I-OIL 2X-14 1841750 98 70 75 P P I-OIL 2X-15 1841760 98 70 55 P 7 l-OIL wing & pit valves leak. 2X-16 1841720 98 70 52 P P I-OIL 2X-17 1951710 98 70 50 P P l-OIL 2X-18 1951600 98 70 55 P P I-OIL Comments Performance The SSV on well2X-ll failed the pressure test & will require repair. The pilot on we1l2X-13 tripped Wells Components Failures Failure Rate low & was cycled & passed a re-test. Both the wing and pit valves leaked on we1l2X-15 and the SSV could not be tested. I inspected 12 well houses. 12 24 3 12.5% ---~< Monday, October 25,2004 tt MEMORANDUM TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: FROM: Chuck Scheve; SUBJECT: Petroleum Inspector January 25, 2001 Safety Valve Tests Kuparuk River Unit 2X Pad Thursday, January 25, 2001: I traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 2X Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on Well 2X-14 had a slow leak when pressure tested. This valve was serviced and I witnessed a successful retest on 1-26-01. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good condition. Summary: Field. I witnessed the 90-day SVS testing at 2X Pad in the Kuparuk River KRU 2X Pad, 12 wells, 24 components, 1 failure 4.1% failure rate 15 wellhouse inspections Attachment: SVS KRU 2X Pad 1-25-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2X Pad 1-25-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Bamdt AOGCC Rep:, Chuck,Scheve Submitted By: - ~huck SCheve Date: FieldftJnk/Pad:. Kup. ,aruk / KRU / 2X Pad Separator psi: LPS 99 HPS 1/25/01 I II . . . -. I I . Iii I I I I I I ' I '1 ' II i' i i ' ' i ' il' ' '1 'i' l'lJ, ii` '' '' i"i '"1; ' 'l '"l:" i'' '~ '' i "'"' ' i ' '; ;h'[: ;; i'" :'/',' · Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number ,. psi PSI Trip Co, de Code Code Passed GAS orCYCLE 2X-01 1830840 2X-02 '1831030 ' '~750 " 2000 18'00 P 'P " WAG ~X-03 1831090 ....... 2x-04 1831180 3750 2000 2000 P P WAG 2X-05 1831070 ............. 2X-06 1831100 , , , 2X-07 ..... 183i130 "37~0 '2000 '2000 p P WAG 2x-08 1831140 2xi09 18'41620!' 99 '60 60 P P ...... OIL 2X-10 1841630: .......... 2X-11 184'i640 99 .... 60 . "50 .... P ' P ...... 0IL 2X-12A 1951760 99 60 55 P P OIL 2X-13 "1841740 99 60 55 P P OIL 2X-14 ' 1841750 99 60 55 P 4 1/26/Ol '' 2x-15 '184'176o ' ' 99 60 .... 55 P P ..... OIL 2X-16 "1841720 99 60 '~5 p " p .......... 0iL ~x-17' 195i~10 99 60 ' '6o ' P P ..... OIL 2X-18 1951600 99 60 60 P P OIL 2X. 1'9 ,, '19~51750 ............. Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% [] 90 oar Remarks: Surface Safety on well 2X-14 had very slow leak when pres'.st)re, tested, valve to be serviced and retested by operator. 1L1F 1/16/01 Page 1 ofl SVS KRU 2XPad 1-25-01 CS.xls ARCO Alaska. Inc. ;~ ?est OIfic¢= Sc{ .0350 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 17, 1993 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. WELL ACTION e:.--_.%',t 1 F-02 Perforate ~q.-. F:E3 1L-01 Perforate gq---r~'~" 2X-13 Perforate '¢~,-1~l,, 2X-15 Perforate ,/3A-03 Stimulate 'gC'~' ",- 3A-03 Perforate ~r_>-~.5~-- 3A- 10 Perforate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfleldCompany · ' STATE OF ALASKA ~' " ~,, Al, ,(A OILAND GAS CONSERVATION COM~ ~ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate Plugging Pull tubing ~ Alter casing Repair well Perforate X ' Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4,, 1 At top of productive interval 1216' FNL, 1368' FEL, Sec. 3, T11N, At effective depth 1064' FNL, 1097' FEL, Sec. 3, T11N, At total depth 1025' FNL, 1027' FEL, Sec. 3, T11N, Location of well at surface 229' FSL, 238' FEL, Sec. 4, T11N, R9E, UM R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 8 5 3 9' true vertical 61 87 feet feet Plugs (measured) None Effective depth: measured 8 4 2 8' true vertical 61 08' feet feet Junk (measured) None Casing Length Size Structural Conductor 7 2' 1 6" Surface 3 70 6' 9- 5 / 8" Intermediate Production 8478' 7" Liner Perforation depth: measured 7970'-7992' true vertical 5778'-5794' Cemented 260 Sx AS II 900 Sx CS III & 650 Sx CS II 315 Sx CS II 6. Datum elevation (DF or KB) 112' RKB, 77' PAD feet 7, Unit or Property na ~r~e?/ Kuparuk River 8' 2~e. II ~umber 9. Permit number/approval ~4-174 ' ,//".,~ 10. APl number 50-029-211~)7 11. Field/Pool Kuparuk River Oil Pool RECEIVED DEC 2 1 1993 Ataska 0il & Gas Cons. Commission Anchorage Measured depth True vertical depth 103' 103' 3747' 3030' 8510' 6163' , 7992'-8014', 8014'-8060', 8214'-8240', 8248'-8285' , 5794'-5811', 5811'-5845', 5963'-5975', 5981'-6007' Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft, J-55 AB MOD set at 8124' MD Packers and SSSV (type and measured depth) Baker "HB" @ 7845', Baker "FB-I" @ 8095'; "TRDP-1A-SSA" SSSV @ 1912' 13. Stimulation or cement squeeze summary Reperforate A Sands @ 4 SPF @ 180° phasing, add perforations in A Sands @ 4 SPF & 180° phasing Intervals treated (measured) Reperforated 8248'-8285', MD RKB , Added perforations 8285'-8288' , MD RKB Treatment description including volumes used and final pressure 14. Prior to well operation Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1869 4079 2804 1550 psi Tubing Pressure 221 psi Subsequent to operation 2000 2841 2762 1000 psi 204 psi 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations , X 16. Status of well classification as: Water Injector__ Oil ~ Gas Suspended __ Service 17. I.hereby certify that the foregoing is true and correct to the best of my knowledge. i Signed Title Senior Operations En~]ineer Form 10-404 Rev 09/12/90 Date f Z- ! 7" 4.3 SUBMIT IN DUPLICATE ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company i! WELL 2X-13 DATE 11/22/93 DAY 1 TIME DESCRIPTION OF WORK RE-PERFORATE A3 SAND CONTRACTOR I KEY PERSON SCHLUMBERGER/JACK RATHERT PBTD (RI(B) ]LAST TAG (RKB) - DATE 8428 I 8355 - I 1/11/93 LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT I AFC/CC# . SCA# 230DS28XL - 10223 IFIELD COST E~T. ACCUMULATED COST $7,039 ,[ $7,039 SSSV TYPE / STATUS ' [CAMCO 1A-SSA 0730 0845 , ,, , 0930 1015 1035 1105 1145 1215 MIRU SCHLUMBERGER, SAFETY lV[EETING, PSI TEST TO 3000 ! RIH W/1 11/16" TOOL STRING, HE~, 6' WT. BAR, CCL, MPD, 20' 2.5" TITAN, 4 SPF, ,, 180 DEGREE PHASING, ALTERNATING BH (DOWN) and DP (UP), ORIENTED 17 DEGREES CCW FROM THE HIGH SIDE. 4.5' FROM CCL TO TOP SHOT , .TIE IN TO CBL DATED 11/17/84, PULL UP TO 8263.5 W/CCL, SHOOT 8268' TO 8288', FLAG LINE AT 8200', POOH, HUNG UP IN D NIPPLE AT 8071', PULL UP TO 2600 PSI BINDS, ABLE TO COIV[E FREE, POOH OOH, ALL SHOTS FIRED R.[H W/20' SAME TYPE GUN, SAME ORIENTATION CHECK TIE IN, PULL UP TO 8243.5 W/CCL, SHOOT 8248' TO 8268', POOH OOH, ALL SHOTS FIRED , RDMO SUMMARY: RE-PERFORATED A3 SAND FROM 8248' TO 8288' W/4 SPF I [CIIECK THIS BLOCK IF SUMMARY, IS CONTINUED, , ON BACK R,~o. ,, .... mU,si, mphI , bnehnraoe ,,, INCOMPLgTg STATE OF ALASKA ALASKA OIL AND G/~ CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate _ Plugging __ Perforate Alter casing __ Repair well Other __ Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1229' FSL, 238' FEL, SEC 4, T11N, RgE, UM At top of productive interval 1216' FNL, 1368' FEL, SEC 3, T11N, RgE, UM At effective depth 1064' FNL, 1097' FEL, SEC 3, T11N, R9E, UM At total depth 1025' FNL~ 1027' FEL~ SEC 3~ T11N~ RgE, UM 12. Present well condition summary Total Depth: measured 8539' true vertical 61 87' feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 112'. PAD 77' 7. Unit or Property name Kuparuk River Unit mbor feet ~~3a't/n u m ber/~pproval number 84-1 74 10. APl number 50-029-21197 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8428' true vertical 61 08' feet feet Junk (measured) Casing Length Size Structural 72' 1 6" Conductor Surface 3 7 0 6' 9 - 5 / 8" Intermediate Production 8478' 7" Liner Perforation depth: measured 7970'-7992', true vertical 5778'-5794', Cemented 260 sx CS II 900 sx CS III 650 sx CS II 315 sx CS II Measured depth 103' md 3747' 8510' md 7992'-8014', 8014'-8060', 8214'-8240'. 5794'-5811', 5811'-5845', 5963'-5975', True vertical depth 103' tvd 1030' 61 63' 8248'-8285' md 5981'-6007' tvd Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 AB MOD @ 8126' MD Packers and SSSV (type and measured depth) BAKER "HB" ~ 7845'r BAKER FB-1 PERM ~ 8095'~ CAMCO TDRP-1A-SSA SSSV ~ 1912' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED J U L - 1991 Alaska 0ii & Gas Cons. C0mn nch0rage 14. Reoresentative Daily Averaae Production or Iniection Data - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecluent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Water Injector __ Daily Report of Well Operations ~ Oil :x Gas __ Suspended 17. I~by certify th~ foregoing is true and correct to the best of my knowledge. Sicjned ~ ~ '/~ ~ ~[' ~Title Area Drillincj Engineer Form 10-404 Rev 05/17/89 Service S~ .'~MIT IN DUPLICATE ,iss[o ALASKA INC. WELL: 2X-13 DAILY OPERATIONS PAGE: 1 BOROUGH: FIELD: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: NORTH SLOPE KUPARUK RIVER FIELD KUPARUK RIVER UNIT ADL 25645 ALK 2576 50-029-21197 84-174 AK5393 55.252072 ACCEPT: 11/16/90 SPUD: RELEASE: 11/20/90 OPERATION: WORKOVER RIG: NORDIC NORDIC 1 11/15/90 (1) TD: 0 PB: 8428 SUPV:GB SPOTTING RIG 7"@ 8510' MW: 0.0 MOVING RIG FROM 1L TO 2X PAD, SPOTTING RIG OVER WELLHEAD. DAILY:S27,999 CUM:$27,999 ETD:S27,999 EFC:$680,000 11/16/90 (2) TD: 0 PB: 8428 SUPV:GB RU TO PULL TUBING 7"@ 8510' MW:ll.6 NaC1/Br RU HARD LINE, PULL BPV, RD LUBE, RU OTIS SLICK LINE, RIH W/ 2.75" SWEDGE TO 8114' AT THE 'D' NIPPLE, POOH RIH AND PULL GLV A 7770', RD OTIS, RU CIR HEAD, DISPLACE WELL WITH SEA WATER, RU HLS E-LINE, RIH WITH CHEM DUTTER AND CUT TUBING ABOVE BLAST RINGS AT 7955', POOH, KILL WELL W/ 11.6 PPG THIXSAL, ND TREE, NU BOPE, PULL BPV, SET TEST PLUG, TEST BOPE, ALL OK, RU TO PULL TUBING DAILY:S171,804 CUM:$199,803 ETD:S199,803 EFC:$680,000 11/17/90 (3) TD: 0 PB: 8428 SUPV:GB RIH W/3-1/2" DP 7"@ 8510' MW:ll.4 NaCl/Br RU TO POOH W/3-1/2" TBG, LD TBF HNGR, POOH CHANGING NON A-B MOD COLLARS TO A-B MOD, STRAP & TALLY, MU BHA & RIH W/PKR RETREIVING TOOL, SLIP & CUT DRILL LINE, RIH W/3-1/2" DP. DAILY:S30,352 CUM:$230,155 ETD:S230,155 EFC:$680,000 11/18/90 ( 4) TD: 0 PB: 8428 SUPV:GB POOH W/3-1/2" TBG 7"@ 8510' MW:ll.4 NaC1/Br RIG SERVICE, FUNCTION BOP, CONT RIH W/3-1/2" DP & PKR RETREIVING TOOL, BREAK CIRC, TAG PKR @ 7804', RELEASE PKR, REV CIRC GAS CUT MUD, POOH W/DP & PKR, LD RET TOOL, PKR, 3 JTS TBG, 2 GLM, RU TO RUN TBG, MU OVERSHOT, RIH W/TBG & DRIFT W/2.860, FISH TAGGED @ 7951', RU CIRC HOSE, PUMP & LATCH ON FISH, RU FLOOR TO POOH W/FISH, RU TO POOH. DAILY:S34,166 CUM:$264,321 ETD:S264,321 EFC:$680,000 11/19/90 (5) TD: 0 PB: 8428 SUPV:GB RIH W/PROD STRING 7"@ 8510' MW:ll.4 NaC1/Br FIN POOH W/FISH, LD FHA, RECOVER FISH, PULL BOWL PROTECTOR, ND FLOW NIPPLE & FLOWLINE, CUT & SLIP DRILL LINE, RU HLS F/5" CSG GUN, RIH & PERF F/7992'- 8014 W/12 SPF 90 PHASE NO ORIENTATION, RUN ~2 PERF F/7970'-7992' SAME, RD HLS RU TO RUN COMP STRING, RIH W/ COMP STRING DAILY:S58,129 CUM:$322,450 ETD:S322,450 EFC:$680,00 11/20/90 (6) TD: 0 PB: 8428 SUPV:GB SIGNATURE: RIG RELEASE 7"@ 8510' MW:ll.4 Diesel BREAK CIRC, STAB INTO SEAL ASSEMBLY, PRESS TO 300 PSI, SPACE OUT~ PU TBG HNGR PRESS TO 5000 PSI, LAND TBG, PRESS TBG TO 2500 TO SET PKR, PU & SHEAR PBR @ 88K, RILDS, PRESS TEST ANNULUS TO 2500 PSI, ND BOPS, RU TREE, PT TREE, OPEN SSSV, RU TO DISPLACE W/DIESEL, CHECK VALVE PLUGGING OFF, RU oTIS PULL CHECK VALVE @ 7785', CONT DISPLACE W/DIESEL, SET DUMMY VALVE @ 7785' SECURE WELL, RIG RELEASE @ 11/19/90 24:00 DAILY:S32,075 CUM:$354,525 ETD:S354,525 EFC:$680,000 DATE: ~/ ~aska Oil & Gas Cons. Com~s~og ~nchorage 'fO: THRU: FROM: State of Alaska ALASKA OIL AND GAS CONSERVATION CO}@IISSION '" ~i ~ ,~,~~~ DATE: Lonnie .C. Sm" November ..6, ° 1990 Commis s zoner / FILE NO: JT.DA. 1126.2 TELEPHONE NO: SUBJECT: RIG/BOP Inspection AAI KRU 2X-!3 Nordic Rig ~ Kuparuk Rv Field Doug Amos Petroleum Inspector ~%ursday Nov 15, 1990: I traveled this date from Prudhoe Bay to AAI's KRU 2X~3 well to conduct a RIG/BOP Inspection. I was unable to attend the BOP test conducted earlier this date. I inspected the BOP stack choke and kill lines, the mud pits, rig floor, choke manifold, all lines downstream of the manifold and the gas buster, and the AIDC record book. I found all items inspected to be in compliance with the exception of the blow down lines to the upright waste oil tanks outside the rig. These lines which run from the choke manifold were chic san lines with hammer unions. I was unable to talk to AAI rep. George Bean. about this problem so I confronted the contract toolpusher, Paul Hines. He in turn contacted the AAI too!pusher warehouse at my request and was told that the clamps needed to bring t'hese lines into compliance,.would be shipped on the 31st of November and arrive in Kuparuk the 5th of Dec.. I had brought this same non-compliance to AAI rep, Don Breeden's attention on' 8/22/90 and was told that the clamps to correct this problem wou!.d be ordered.-)~I suggested that we increase our inspections of this rig until it is brought into. compliance. Also a letter from the commission to the operator may expedite this non-compliance. In summary: I conducted a RIG/BOPE inspection on Nordic Rig No. 1 at AAI's 'KRU 2X-13 well and found hammer unions in the blow down lines downstream of the choke manifold. 02-001.A (Rev. 6/89) 20/1. I/MEMOI.I M3 DEC-07-'90 1~55 ID~NO~DIC ~IG 1 TEL N0:90765~710~ i.~. ~166 General Purpose Worksheet lSubJeot IFile IPege O! RECI IVi i) DEC 1 ~)1990 Oil & Ga8 Cons. Commission Anchorage COM~" "~ ': :' .... A~ ~ OIL AND GAS CONSERVATION .)N APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Pull tubing 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Variance_ Perforate ~X Other_ 6. Datum elevation (DF or KB) RKB 112' 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 1229' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1216' FNL, 1368' FEL, Sec. 3, T11N, R9E, UM At effective depth 1064' FNL, 1097' FEL, Sec. 3, T11N, R9E, UM At total depth 1025' FNL~ 1027' FEL~ Sec. 3~ T11N~ R9E~ UM 12. Present well condition summary Total Depth: measured 8 5 3 9' true vertical 61 8 7' feet Plugs (measured) feet 8. Well number 2X-13 9. Permit number 84-174 10. APl number 5o-029-21 1 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 8 4 2 8' true vertical 61 0 8' Length Size 72' 16" 3706' 9 5/8" 8478' 7" measured 8014'-8060', true vertical 5811 '-5845', Tubing (size, grade, and measured depth) 3-1/2" J-55 9.3 #/FT @ 8126' feet Junk (measured) feet Cemented Measured depth True vertical depth 260 Sx CS II 1 03' 1 03' 900 Sx CS III& 3747' 3030' 650 Sx CS II 315 Sx CS II 8510' 61 63' 8214'-8240', 5963'-5975', 8248'-8285' 5981'-6007' Packers and SSSV (type and measured depth) Baker FB-1 ~ 8097', Baker FHL @ 7833'~ Baker FVL SSSV ~ 1896' 13. Attachments Description summary of proposal _ Detailed operation program Add "C" perforations and change couplings to AB-modified. 14. Estimated date for commencing operation November 2. 1990 16, If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ;~ Gas Service P r o d u ¢ e r BOP sketch X Suspended _ 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ON(..Y Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10- ~"~ ~' Approved by the order of the Commission Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned IAppj'o~val No. SUBMIT IN "rRIF~LICATE Kuparuk River Unit Well 2X-13 Preliminary Workover Procedure "B" Add "C" Sand Perfs Pre-Rig Operations 1. Obtain surface pressure build-up to confirm BHP. J RU slickline and pull dummy at 7770'. Pull CV across "C" sand at 7868' and 8078'. Confirm dummies above 7770' are in place. 3. RU E-line and cut tubing below retrievable pkr and below blast rings. Rig Operations 1. MIRU Nordic #1. 2. Pump kill pill and circulate 10.0 ppg brine. 3. Set BPV, ND tree, NU BOPs. Pull BPV and test BOPs. 4, POOH with 3-1/2" tubing above upper packer (PBR was sheared on initial completion). Replace couplings with AB modified. Inspect GLMs. 5. RIH with drill pipe and retrieve Baker FHL packer at 7831'. J Retrieve tailpipe with carbide blast rings and FL4S connections. Inspect blast ~'ings and GLMs. 1 Sm 10. Retrieve stub above lower packer. Add "C" sand perfs with 5" casing guns: 7970'-8014' 44' @ 12 spf, 90° phasing Pump kill pill if necessary. Rerun selective single completion with new retrievable packer, new SSSV, and tubing as necessary. New "C" sand perfs will require 44' of additional carbide blast rings. Stab tailpipe into original Baker FB-1 lower packer at 8095'. 11. Set standing valve, set upper packer. Pressure test tubing and annulus. Displace annulus with diesel. Pull SV. 1 2. Set BPV, ND BOPs, NU tree. 13. RD, release rig. Pull BPV. KUPARUK WELL 2X-13 APl #: SPUD DATE: ORIGINAL RKB: 500292119700 ADL LEASE: 25845 PERMIT #: 11/04/84 COMPLETION DATE: 12/06/84 WORKOVER DATE: SURFACE LOCATION: 1240'FSL,241'FEL,SEC4,T11 N,RgE TOP OF KUPARUK: 1216'FNL,1368'FEI.,SEC3,T11 N,RgE TD LOCATION: 1025'FNL,1027'FEL, SEC3,T11N,RgE All depths are MD-RKB to top of equipment unless otherwise norad 112 TUBING SPOOL: 31 PAD ELEVATION: WELLTYPE: PRODUCER CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5# H-40 103 9.625' 36# J-55 3747 7' 26# J-55 8510 3.5' 9.3# J-55 8124 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV BAKER F'Vt. 2.81' 1896 SBR BAKER PBR 7816 PKR BAKER FH 7831 PKR BAKER FB 8O95 NOGO CAMCO 'D 2.75' 8112 SHROUT BAKER 8123 MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 550 MAX HOLE ANGLE: 53 deg 5400 HOLE ANCd. E THRU KUP: 44 deg LAST TAG DATE: 09/30/88 8094 RATHOI. E: -191 ft FISH/OBSTRUCTION: PBTD: 8428 PBTDSS: 5996 INTERVAL 8014.8060 8214-8240 8248-8285 84-174 GAS UFT and FLOW INFORMATION VALVE STN DEPTH 1 2078 2 4269 3 5983 4 6621 5 7227 6 777o 7 7868 8 7938 9 8078 PORT MANDREL SIZE SIZE MCMURRAY HUGHES 1' .DV MCMURRAY HUGHES 1' .DV MCMURRAY HUGHES 1' .DY MCMURRAY HUGHES 1' .DV MCMURRAY HUGHES 1' .DY MCMURRAY HUGHES 1' DV MCMURRAY HUGHES 1' .CV MCMURRAY HUGHES 1' .CV MCMURRAY HUGHES 1' .CV PERFORATION DATA ZONE FT SPF PHASE COMMENTS C134 46 12 120 DA 5' JUMBO JET A4 26 4 120 DA 4' JUMBO JET A3 37 4 120 DA 4' JUMBO JET REVISION DATE: 09/30/88 REASON: TAG FILL 5000 (. PSI BOP STACK I I I I 5 3 1. 9-5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" - 5000 PSI CROSS-OVER SPOOl_ 4. 11" -5000 PSI BLIND RAMS 5. 11" -5000 PSI PIPE RAMS 6. 11" -5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1 . FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. 2. 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. 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 PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BAOKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. 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 BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . 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. 14. SIGN AND SEND TO DRILLING SUPERVISOR. 1 5. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORDD SRE 9/8g i"' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1229' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1216' FNL, 1368' FEL, Sec. 3, T11N, R9E, UM At effective depth 1064' FNL, 1097' FEL, Sec.3, T11N, R9E, UM At total depth 1025' FNL~ 1027' FEL, Sec. 3, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 8 53 9' true vertical 6187' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 112' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well numbe~ 2X-13 J ~-~ ~/~,ce~.-~-~ 9. Permit number/approval number 84-174 / verbal bv L. Smith 10. APl number 5o-029-21 1 cj7 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 4 2 8' feet Junk (measured) true vertical 6108' feet 13. Casing Length Size Cemented Structural Conductor 7 2' 1 6" 260 Sx CS II Surface 3706' 9 5/8" 900 Sx CS III & Intermediate 650 Sx CS II Production 84 78' 7" 315 Sx Class G Liner Perforation depth: measured 8014'-8060', 8224'-8240', 8248'-8285" true vertical 5811'-5845', 5963'-5975', 5981 '-6007' Tubing (size, grade, and measured depth) Measured depth 103' 3747' 8510' True vertical depth 103' 3030' 6163' 3 1/2" 9.3 Ib/ft, J-55, 8126' MD RKB Packers and SSSV (type and measured depth) ,~8.SkS. Oil & Gas Cons. Commissio~ Baker FVL SSSV @ 1896', Baker FB-1 ~ 8097'I Baker FHL @ 7833' Anchcra~ Stimulation or cement squeeze summary Hydraulic line to SSSV failed. Locked out SSSV and ran Flopetrol PB valve. Dome pressure set to close valve if pressure at depth falls below 625 psi. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re_~resentative Daily Average Produqtion or In!action Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2780 1885 1290 1600 155 Subsequent to operation 2110 1585 1130 1600 345 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./~'~-t ,,-~ ~ ,'Z'Z~~4,'''u~ :,.-c~,2Title Senior Operations Engineer Form 10-4~t Re~ ~/'~ 5/88" Date ~,,/~/~ ~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL JONTRACTOR REMARKS ~..X_/J {PBDT d' 7'/J' -/~/./L,~,,~, JFIELD- DISTRICT- STATE /f~pa A u/~ OPERATION AT REPORT TIME WELL SERVICE REPOR'[ DAYS [ DATE i / Yo~ ~.,~. ~' {--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemP'Report OF Chill Fact°r I VislbilltY°F miles Iwind Vel' I Signed ~ knots - ,,~ ~ _~-/V STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well 3ull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4, 1064' FNL, 1097' FEL, Sec. 03, T11N, At total depth 1025' FNL, 1027' FEL, Sec. 30, T11N, Location of well at surface 229' FSL, 238' FEL, Sec. 04, T11N, R9E, UM At top of productive interval 216' FNL, 1368' FEL, Sec. 03, T11N, R9E, UM At effective depth R9E, UM R9E, UM i12. Present well condition summary Total Depth: measured 8539' true vertical 6187' feet Plugs (measured) feet Other 6. Datum elevation (DF or KB) RKB 112' 7. Unit or Property name Kuparuk River Unit feet Effective depth: measured 8428' true vertical 6108' feet Junk (measured) feet Casing Length Structural Conductor 1 0 3' Surface 3 7 4 7' Intermediate 8510' Liner Perforation depth: measured Size Cemented Measured depth 8. Well number 2X-13 .~-.~ ~/_ 9. Permit ~ p~p~l~U m ber number/a 84-174 10. APl number 50-02921197 11. Field/Pool Kuparuk River Oil Pool True vertical depth 103' 3O30' 6163' MD true vertical 1 6" 260 Sx CS II 1 0 3' 9 5/8" 900 Sx CS III & 3747' 650 SxCS II 7" 315 Sx Class "G" 851 0' 8014'-8060', 8224'-8240', 8248'-8285' 5811' -5845', 5963' -5975', 5981' -6007' TVD Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55, 8126' Packers and SSSV (type and measured depth) Baker FHL @ 7833' and Baker FB-1 @ 8097' 13. Stimulation or cement squeeze summary Intervals treated (measured) 8224-40', 8248-85' ,~.~la~ka Oil.& ~as Co~ ~ ' Treatment description including volumes used and final pressure Pumped 364 bbl gelled diesel and slurry, 20,500 ~ Proppant~ see attached Representative Daily Average Production or In~ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsec~uent to operation 1 195 623 0 750 138 2080 955 1 1350 171 14. 16. Status of well classification as: Oil X Gas Suspended Service 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~--~"L Date ~t~.~ ~, ~/r O SUBMIT IN DUPLI~,ATE Form 10-404 I~ 0'6/15/88 ..... :~ ARCO Alaska, Inq Subsiclian/of Atlantic Richfield Company WELL ,~ ,Y- I Z CONTRACTOR ,,6:'J R~:MARKS tFIELD - DISTRICT- STATE N,,.,"'K OPERATION AT REPORT TIME WELL SERVICE REPORT I DAYS 1 DATE / I ~-.~/-?~ , [-~ CHECK THIS BLOCK If SUMMARY CONTINUED ON BACK Weather 1 Temp' Chill Fact°rVisibilityIRepOrt OF OF / miles Wind Vel. I Signed knots ARCO Alaska, Inc. Post Office~Bo,~' '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 2, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well ..... 3A-15 Action Fracture Failed MIT If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 Anticipated Start Date September, 1988 September, 1 988 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany A ''''Sk STATE OF ALASKA '~M AL ~ OIL AND GAS CONSERVATION COM ~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: T~me extension Change approved program Plugging "] Stimulate'~,. Pull tubing Abandon Suspend .' 2 Name of Operator AP. 00 /1!a$1~_~_. Tnt'. 3 Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1229' FSL, 238' FEL, Sec. 04, T11N, R9E, UN At top of productive ~nterval 1216' FNL, 1368' FEL, Sec. 03 T11N R9E UM At effective depth ' ' ~ 1064' FNL, 1097' FEL, Sec 03, T11N, R9E, UN At total depth 1025' FNL, 1027' FEL, Sec. 30, T11N, RgE, UM Operation Shutdown ~ ~ Re-enter suspended well .% Alter casing £I Amend order ,r Perforate ~' Other .] 5. Datum elevation (DF or KB) RKB 112' 6. unit or Property name Kuparuk River Unit 7. Well number 2X-13 8. Permit number 84-174 feet 10..PoolKuparuk River Oil Pool 11. Present well condition summary 8539' Total depth: measured 6187 ' feet true vertical feet Plugs (measured) 8428' Effective depth: measured 6108' feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural 103' 16" 260 Sx CS II 103' Conductor Surface 3747' 9 5/8" 900 SX CS III & 3747' Intermediate 650 Sx CS II 8510' 7" 315 Sx Class G 8510' Production Liner 8014'-8060', 8224'-8240', 8248'-8285' MD Perforation depth: measured True Vertical depth 103' 3030' 6163' truevertica, 5811'-5845', CEIVED Tubing (size, grade and measured depth) 3 1/2", 9.3 lb/ft, J-55, 8126' ,~]P O ~' ]988 Packers and SSSV (type and measured depth) Baker FHL ~ 7833' and Baker FB-1 ~ 8097' Alas~0il&Gas cons. commissi°n 12,Attachments Description summary of proposal ~ Detailed operations program ~ 'BO~I~~ Fracture A Sand with gelled diesel sand frac. 13.,.Estimated da,tc.,.(c,r commencing operation bep~:emDer 0 ~ ~ ~ -ii ' n '-'f',:- ':':" ;i'",.';"~,',.",,: '¢, ~'~ k.',. ~,,, 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the for,.egoing is true and correct to the{-Ipest of. my knowledge Signed../'~g-~ /~' ~~~~it le ;~/:,. ~j'~,..~' ~ j_..-¢.~/~ / ~.-';-~)z Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. F__J Plug integrity r-! BOP, Test E] Location clearanceI &Pproved Copy ORIGINAL SIGNED BY LONNIE C, SMITH by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 8~26~88 Kuparuk Well 2X-13 'A' Sand Fracture Procedure Cost Tracking AFE # K89248 . . . . . . . . Obtain a combined zone 24 hour well test. Reduce choke setting to increase flowing tubing pressure by at least 50 psi. Produce well for at least 12 hrs to stabilize. Obtain a combined zone 24 hour well test. MIRU Slickline unit. Pull WRDP @1896' RKB. Pull C Sand CV's at 8078', 7938', and 7868' RKB. Run DV's at 8078', 7938', and 7868' RKB, to shut in C Sand. Rerun WRDP. RDMO. NOTE: The cost of this step should be charged to 230DS28XL, not the frac cost tracking AFE. Obtain an A Sand 24 hour well test. Reduce choke setting to increase flowing tubing pressure by at least 50 psi. Produce well for at least 12 hrs to stabilize. Obtain an A Sand 24 hour well test. MIRU Slickline unit. Pull WRDP @1896' RKB. Tag bottom. Pull GLV's and OV @ 2078', 4269', 6621', and 7770' RKB. Run DV's. Set blanking plug in Camco 'D' nipple at 8112' MD-RKB. Pressure test the tubing. Pull blanking plug. Pump Diesel/10% Musol per the attached schedule. Shut down overnight to soak. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. Check diesel for contamination prior to gelling for frac. Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After frac, verify and record weight of remaining proppant. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 3110 psig Fracture Gradient = 0.69 psi/ft (5870' TVD) Tubing Friction = 140 psi/1000 ft (8250' MD) confer with engineering. 9. Rig down frac equipment. 10. MIRU slick line. Rerun WRDP. RDMO slick line. 1 1. Follow attached flowback procedure. If treating pressure during the job exceeds 6500 psi, shut down job and 12. After A Sand has stabilized and two well tests have been obtained at header pressure, reopen C Sand with three CV's. 8~26~88 Kuparuk Well 2X-13 Post-Frac Flowback Schedule , , , . , Gl Obtain representative fluid samples from the pad, slurry, and flush stages during the fracture treatment. Kuparuk onsite Operations Engineer will place samples in hot water bath at 140° F to observe break time (the fracture treatment will have cooled the Kuparuk formation slightly). For 2X-13, the anticipated break time is 8 hours. After verifying that the gel has broken in the water bath, Operations Engineer at NSK will phone Drill Site Operator to authorize start of flowback. If gel has not broken, DO NOT ATTEMPT FLOWBACK. Flow at 5 to 10 BPH until bottoms up. Verify that gel is broken and proppant is not being produced. After one day of flowing at the above rate, decrease wellhead pressure in 50 psi increments until the well is producing at header pressure. LIMIT THE PRESSURE DECREASE TO NO MORE THAN 100 PSI/DAY AND THE FLOWRATE INCREASE TO NO MORE THAN 250 BOPD/DAY. Record tank straps (rates), choke settings, and WHP's during the flowback period. Take BS&W samples every 8 hrs. Inspect samples for Carbo-Lite. If Carbo-Lite is found, increase WHP by 100 psi and contact Operations Engineering (Currier/O'Dell). Well can be turned to CPF when BS&W is less than 2%. As soon as practical, obtain a 24 hr well test. Sundry Notice - Well 2X-13 A Sand Fracture Treatment No BOP's are used during the fracture. The frac will be pumped through a manifold on the surface A Sand pressure (6200' SS) = 2345 psi 10/1/87 PBU No workover fluid will be used during this process. ARCO Alaska, Inc. .,. Post Offic,t~ 0360 Anchorage, ,~lasKa 99510-0360 Telephone 907 276 1215 Date: November 25, 1987 Transmittal #: 7019 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2X-15 Kuparuk Well Pressure Report(Otis) 10-1-87 2V-4 Kupaurk Well Pressure Report(Otis) 11-16-87 2X-13 Kuparuk Well Pressure Report(Otis) 10-1-87 2X-16 Kuparuk Well Pressure Report(Otis) 10-3-87 Static 'A' Sand 'C' Sand PBU 'A' Sand PBU 'A' Sand ARCO Alaska, Inc. is a Subsidiary of AflantlcRIchfleldCompany ARCO Alaska, Inc. t~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 25, 1987 Transmittal # 5920 RETURN TO: ARCOAlaska, Inc. Attn: Kuparuk Records' Clerk' ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith 'are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '"'"~2X-12 '"~2X-13 ~2X-14 OH LIS Tape & Lis~i_~n~ ~ OH Tape Lis~ing Printout OH Tape Listing Printout Receipt Acknowledged: DISTRIBUTION: State of Alaska ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany ARCO Alaska, Inc. Post Office'~'1~' . ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 19, 1987 Transmittal # 5883 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2X-13 OH LIS Tape 2X-14 OH LIS Tape OLJ-' i Receipt Acknowledged: DISTRIBUTION: State of Alaska ARCO Alaska, Inc. is a Subsidiary o! AtlanticRIchfieldCompany GEARHART INDUSTRIES, INC. November 8, 1985 To Whom It May Concern: Please disregard previously delivered Compensated Density Compensated Neutron Raw Data and Compensated Density Compensated Neutron Porosity Logs for Arco Alaska Inc., 2X-13, dated 11-10-84. This concerns only the 2"/100' Logs that have not been marked "CORRECTED". ~/e inadvertently presented the Repeat Section on these 2"/100' Logs in- stead of the Main Pass. The 5"/100' copies on the above mentioned Logs are correct. Enclosed are the corrected copies of these logs. We apologize for any inconvenience. David Douglas - C/-~ "' Anchorage Computing Center 139 East 515t St., Suite 102 P.O. Box 102436 Anchorage, AK 99510 Telephone (907) 562-2538 ARCO Alaska, Inc. Post Office BoA J60 Anchorage, Alaska 99510 Telephone 907 277 563.7 Date:Il-20-85 Transmittal No:5455 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ CORRECTION/ G. H./ One * of each 2X-13 2" CNL/log (Raw) 11-10-84 2" CNL/log 11-10-84 run #1 7440-8540 run #1 7440.-8540 Receipt Acknowledged: B. Currier BPAE,BL/SE Chevron *BL/SE D & M *BL DISTRIBUTION Drilling,BL W. Pasher State of AK, BL/SE Geolog~L.Johnston Exxon Sohio*BL/SE Mobil*BL/SE Phillips Oil*BL/SE Union*BL/SE NSK Drill Clerk,BL j. Rathmell, BL ...... /Vault *Films ARCO ~ln.~ka, Inc. is ,~ $.b~;idtn~'y of AllanltcRIchfleldCompany ARCO Alaska, Inc~ ' Post Offic~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT~: 10-22-85 TRANSMITTAL ~O: 5410 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEEP, ING RECORDS CLEkK ATO-1115B , P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED hEI{h%4ITH AKa: Tr~}i FOLLOWING I'£E~iS. RECEIPT AND RETURN ON~ SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE * OF EACH CEMENT. BOND LOG/ '~3B-8 ~ q2X- 15 '~2X-13 ~ 2X- 12 '~2X-ll -~X-10 w2X-9 ~ 2W-6 '~ 2V-16 '~ 2V- 15 ~2V-13 '~"~2U- 7' .: . u- "~" 2 U- 4 ?' :.!:'::' "~ 2D- 16 2D- 15 :'. :"~2D-1 :':: '~ 1R-8 ' ~lR-7 .. :',-,IR- 5 "~ 1L- 15 . ' "~ lQ- 15 ' %CPF- lA VARIABLE 06-06-85 RUN #1 11-07-.84 RUN 11-17-84 i{UN 12-08-84 RUN 12-08-84 kUN 12-21-84 kUN #1 12-20-84 RUN 11-25-85 t{UN 06-06-85 .' kUN 06-07-85 . RUN 06-03-85 ' RUN 04-02-85 1{UN ~1. 04-01-~5 RUN ~1' .. 03-31-85 }(UN 04-01-85 :.,. I~UN 03-02-85~< liUN 12-19-84' kUN 12-18-84 RUN 11-0~3-84 RUN 06-17-85 kUN 06-08-~5 . ~UN 06-08-85 t{UN 11-05-84 RUN 05-27-85 RUN 04-17-85 kUN 12-21-84~ ~UN LuGS / CEMENT EVALUATION TOOL '~ 1F-'16 .03-12-85 RUN · ~lR- 5 06-26-85 RUN "~,IR-5' '-:".~ 06-27-85"... "' ~'2U-2"'""::" 03-25-85 '~'2U',15' 03-07-85 "~3B-9 .:::.' 06-30-85 '~3C-11 06-29-. 85 ~'~3C~12' 06-29-85. %1 RUN _JJ:2 kUN ~1 i~UN ~1 RUN %1 RUN #1 RUN ~1 RECEIPT ACKNOWLEDGED: .. . BPAE ' . B, CURRIER' CHEVRON. D & M .. .. PLEAS~ ACKNOWL~.'DG~ DENSITY 5850-8369 5900-8258 5896-8410 3050-7215 310U-6370 3350-6973 5100-8338 5700-7290 4550-710~ 4650-6428 6590-8553 4970-6938 0070-~122 5600-8107 .... 5994-9161 6284-7850 52~0-7459 3285-6454' 5693-6652 5987-~324 4302-7028 6950-8628 4883-6600 6490-7566 ~97~-10744 2200-3856 Ck~MENT ~VALUATI~N LOGS 8269-8712 6974-8644 8254-8532 5790-9450 6400-7002 6000-8246 6500-8726 5400-7457 · DRILLIN~*BL W. PASH~t{ L. JOHNSTON_ EXXON ulOBI L PHILLIPS OIL .. "NSK CLE~K*~L J. RATHmELL com~Ssion SOHIO '".' ................ '" '-' '?/S ~'~',',.. UNION VAUL~ / ~0' FIL~ ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany 3 ~'/ ALASKA OIL ~, ~%~~ ,/./~~ .. -.- .... :;. , -;.: ., '. We ~L~h to b~L~ to ~ou~ ~en~Lon tha~ ehe Go~La~on ha8 noff~ 'fiat ~eee~ved ~he Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. .. Chairman le~C.024 ARCO Alaska, Inc. '~ Post Office Bo,, ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 25, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2X-13 Dear Mr. Chatterton. Enclosed is a copy of the 2X-13 Well History (completion details) to include' with the Well Completion Report dated 12/26/84. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUIO/L04 Enclosure cc' 2X-13 Well File RECEIVED J U L 0:3 19B5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inci' Post Office Dox 100360 Anchorage, A]aska 99.510-0350 Te!ephone 907 276 1215 DATE: 05-2 9-8 5 TRANS.~I.zA~ NO: 5?03 RET URN TO' ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-11!5B P.O. BOX 100360 AI~2HORACE, AK 99510 ENGINEERING TIQINSMITTED HEEEWI'T}[ ARE Tile FOLLOWING ITEHS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS PLEASE ACKNOWLEDGE TFJ~.NSMI TTAL. SEQUENCE OF ..., EVENTS PRESSURE DATA · -~2A-3 PBU- '~' SAND 03-16-85 2A-5 SBHP 11-2 1-84 2B-i PBU 04-01-85 .2B-2 PBU 04-0 2-85 2B-15 PBU- POST FRAC 04-09-85 -2B-16 PBU 04-10-85 2..F..,.-. 7,, PBU- STATE 04-14-85 2F-8 '" PBU- 'A' SAND 04-20-85 ~ ~._-D_~./PB U- STATE 04-13-85 ~ PBU 04-11-8 5 2G-!2 PBU- 'A' SAND POST FRAC 03-23-85 2H-15 ISBHP 04-10-85 2W-13 ,PBU- 'C' SAND 04-21-85 2X-13 PBU 03-30-85 BAKER/ LYNES PRESSURE ~ ~x~ PORTS (ONE COPY OF EACH) SET DEPTH I'A-1 PBU 04-23-85 7187" lA-2 PBU 04-23-85 7476' lA-2 PBU 04-23-85 7476 ' lA-5 BUILD-UP 04-23-85 6957 ' lA-6 PBU 04-23-85 8300 ' lA-6 BUiLD-UP 04-23-05 8300 ' iA-10 BUiLD-UP 04-23-85 8415 ' lA-10 BUILD-UP 04-23-85 8415' TOOL NO. 1722 1302 1512 1734 1719 2062 1508 1299 RECEIPT ACKNOWLEDGED: 3PAE * '.3. CURRIER* 'IIE VROi~* .3 & M* DRILLING L. 0'0 IINSTON MOBIL * NSK CLERK DISTRIBUTION: W. PASHER E X XO PHILLIPS OIL* J. RATHMELL* DA~a u,& ~s Cor~s. Commissio~ Anchorage STATE OF ALASKA* SOHIO* UNION* K.TULIN/VAULT ,. ARCO Alaska, Inc.'"~' Post O;lice [;ox 100360 Anchorage, Alaska 90.510-0350 Telephone 907 276 1215 DATE:05-29-$5 TRANSHITTAL NO: 5199 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-!llSB P.O. BOX 100360 AI';CHORAGE, Al'{ 99510 TRANSMITTED IIERE%~ITIi ARE TIlE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. KUPARUK I~ELL PRESSURE REPORT ENVELOPE DATA: (ONE COPY OF EACH) 2A-4 04-22-8 2A-7 04 -23-8 2F-6 03-21-8 2G-8 03 -21-8 2G-!2 03-23-8 2t!-13 04-26-8 21i-14 04-28-8 2H-!5 04-29-8 2U-1 04-11-8 2U-2 04-11-8 2U-3 04-11-8 2U-4 04 -11-8 2U-5 05-02-8 2U-6 05 -03-8 2U-7 05-04-8 2U-8 05 -04 -8 2U-13 03-09-8 2U-14 03-21-8 2U-!5 ~ 03-20-8 2U-!6 03-15-8 2V-2 03-23-8 2V-SA 03-17 -8 2V-SA 01-24-8 2W-4 04 -13-8 2X-1 04-14-8 ?X 3 04 13-8 2X-13 03-30-8 5 STATIC-'C' SAND 5 STATIC-'A' & 'C' SAND 5 STATIC-PBU-'A' SAND 5 PBU-'A' SAND 5 STATIC-PBU-'A' SAND 5 STATIC-'A' SAND 5 STATIC-'A' SAND 5 STATIC-'A' SAND 5 PBU-'A' SAND 5 PBU-'A' SAND 5 STATIC-'A' SAND 5 STATIC-'A' SAND 5 STATIC-'A' SAND 5 STATIC-'A' SAND 5 ST~,'"TC-'A' SAND 5 STATIC-"A' SAND 5 $ TAT iC 5 STATIC-'A' &"C' SAND 5 STATIC-'A' &'C ' SAND 5 STATIC-'A' &'C' SAND 5 STATiC-'C' SAND 5 STATIC-'C' SAND 5 STATIC-'A' &'C ' SAND 5 STATIC-'A' SAND 5 STAT!C-'A' &'C ' SAND 5 STATIC-'A' &'C' SAND 5 PBU-'A' SAND RECEIPT ACKNOWLEDGED: PAE* CURRIER* ~ Ii.".V~O * M* DRILLING L. JOIINSTON NSK CLERK DISTRIBUTION: W. PAS!IER EXXON PUiLLIPS OIL* J. RATHMELL* DAT~,I[s~ Oil & G~s L;ons. L;u~;~mtssion STATE OF ALASKA* SO]IiO* U N I O N * K. TULiN/VAULT ye~ received the ~ollo~lug required 1berne on the eubJe~t. ~ell ~l)Lch ou~ reeorde. 1,die, Ced ,~e completed. /A-~~~ , Article 536(b) of Title 20, Chapter 25~ Alaska Administrative Code, stipulates that this material shall be filed ~tthin 30 days after complettou of a drtlled.~ell. Please submit the above missing material. · C. V. Chattert/on/ Cl~atrman lc~C.024 ARCO Alaska, Inc. Post Offi( ' 100360 Anchoragt, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO' ARCO ALASKA, II'~.C. ..r,,TTN- REC[)RI)S CLERI{ AT[)-..~ ~ ~SB F'.0. BOX 'l Ah~CHORA(]IE, Al{ ?75i .. · --,.~ x~,, TTED ..... ~l"~..~.:nI I"IEP, EhlITH ARE THE FkECIEIF'T AND RETURN ONE SI~NED COF'Y OF DATE' AF'RIL i9, t985 TRAN.S'MITTAL N.O' 5i47 OF' "2' · I T I::. H,:~. F t.. ,::. ~-.~..~ E A C I< N 0 W/.. E D 6 E THI3' 'FRANSMI'FTAL. EVENTS' 'A' SAND ,"R~C-L, ELt. E.D WATEF~ ,~TATIC BHr-' F'BU . F'BU F'BU F' B LI .r,E~ I..-FD HMTEF.. FRAC I-.IYDR~UI.I C FRAC POST FRAC TEMF' LOSS F'BU F'r~u .STATIC _r.;I-tP F'BU F'BU GELLED WATER BATCH I'"RAC POST FRAC TEHF' LOG STATIC BHF' STATIC BI'iF' INJ:ECT-T. VITY TEST I$IF' STATZC BHF' BHF'. B I"l P ~i'-II::' F'BU F'O£T FRAC TEMF' LOG F.: I"l F" POST r'r',r,u T1EHF' I__P.C~ I"IYD ~ FRACTURE F'RU F'BU · 4/5185 4/7/85 .4/2/8.5 4/t -2/85 '~17, i /85 3/~i/85 4/i/85 4/i/85. 4/2/8~ 4/~- i ~/85 4/7-8/85 4/8/85 4/t~-i2/85 41t i-i 2185 41 i..~,/85., 4Ii2/85 4/i 3/85 4Ii ~/85 4ITS/85 4!t t 185 4/i2/85 4/i 2/85 4/i 2/85 ' 4/t0-'t i 1'85 411,1--i 5185 4/i 4/85 4/I5/85 4/i5/85 4/i4-i~_/85 r.:~_,., ~_ I F'T ACI< i,!O[.]LEDr.. ED BF'AE B,~ CURRIER CHEVRON 0 ._"., H DI,TRIBUTION' DRII_[.IN[i W, F'ASFIER I ....!OI-tNSTON EXXON MOBIL. F'HILL I F',~' OIL NSK CLERK ,J, RAI'HMELL ARCO Alaska, Inc. I~ a Subsidiary of AllantlcRIchfleldCompany RECEIVED Alaska Oil & Gas Cons. P A T E: -~'~Tor~--:,-"7~' · ~-..ATE OF AL/~ -s 0 H I 0 - ' UN'IOW K ,~UL I N/VAUI_T ARcO Alaska, Inc.(" Post '(Jfti'ce '~..,x '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I':; !.-.' ]," L iF; i ! 'T' O' ' ,.o F:: 17 C E i F:"T' /'i i'.! D ,, O ~.~....'(.) t -.-E: 5 0 ''~ .... ")-" :'~ .,,'., ~.:. i~ .... ..,~ ,) ,.> ,.> .... 7 ,,,'.. "" ,,.'. '~ C) 0 7 .-. I ..'!~ .... ~:~'::' O 4-- (.) i .... f::: 5 t.).4 .... 04 .... ~! .-, ..,~ ,,., ~", ,.') ....... ,, 'i .... <,~ '.::;' O '1 -" ¢) '~ .... <:> ':~' OS-'. I '" '"'"" f' "C.,..? 03 .... '" .... ':"::' ^~: 'i ;.) ..; (~ ~ .-. ,-) .-~ .... <:~ ,:.-. · ')..~ ,~.'.. ',... t.? ../ 0 3 .... 0 .' .... ~..,.;>. .r #" ' C.~ .3 ..... ..: (", ::' '., .,... ~,'.. ',.) .... C? .. ~ "."'., '" ".? ¢?'~ I :' 0 ,...) l..J ~. "" (2' ..? "~' .... I' 0 :~ '- 0 ,'; <:! .) 0 3 '- 0 4 .... E)'.5 ~,"), ~ "' I I~ "" E)...~ O ~ .... '~ G ")'::' ~.) .... C; ..) I.-2 / .,, - .; ARCO. Alaska, Inc. Post Office Bq~ 00360 Anc.horage, Alaska 99510-0360 Telephone 907 276 1215 · , ¢"i ":" "l' '"" ' ::) 'f' .I: ("~ 'T' '" ~'' .L E:. (:'? T :1: ,:"7... !:) '1 ..... .r.) ~" :!: ,? ""i!'?~ '; I"I:E.{/R ,..'! i_..'./ FI "" .... ... · . d: ""i 'T' 'r .-', r, T .1; .!," ,,..' O'T' ]'2. · ~':) T 'r · M, (.') t .,.,~ 0 '~' :1: ,:'? "P.., T'.T ,:::'7 ..... ,,.'.) -,-T ~ "' ~ .~. ,,,... . , !3 '!" :[: ,!? .. ,"', "~' T .~' '...' ! .~. ~... ,'~ "(' T ~' · ... ~ .,. ~... C~ T 'r .-'.' ., .i, ~.:. .""t-'r 'r .,', .... ~. /": C. ~''' ~.: ;'3 [,.~ r.- r; ~ E D ' i% , ,.., ~...,.- T", ;' :ii:'i" I';: ]i ..?.i,'~ ~'"' T "~ "' , , . 'r',....., ...:I? 'r [_ L. .,.'" K', r:. !.,.~ ,. ,I::' ~..:~ .... ~, ~::. ~';... ,, :,-', u i'.!,?. 'T' q ~'~' ,::' :,' v,"; :..r :,.. ...",".,.' ,,,,~ ~ I .... {,,..-",.. /% %.' 1% -% .... "'~ '.,.T. F'2..:. i'i 0 :D ]:1 ~¢ t" ,"~ 'r I... t .... f.:i T l... '.¥':' f:,! .~ I'( . C I_ E: F: t'( ,.!~I',, ,.."' '" '"", I'l!v .... r:' L. L: "":' ARCO Alaska, Inc. is a Subsidiary of AllanlicRichtieldCompany ARCO Alaska, Inc.~r' Post Office Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2X-13, 2X-14 Dear Mr. Chatterton' Enclosed are the Well History Addendums to include with the Well Completion Reports for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, nj. Gruber Associate [ngineer JG/tw GRU3/L73 Encl osures xc' Well Files RECEIVED jAN 2 9 19B5 t,~ ~ Gas Gens. Gommissio" ~.,..nchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B<j )0360 Anchorage,A~...,a 99510 Telephone 907 276 1215 January 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-13, 2X-14:~ Dear Mr. Chatterton: Enclosed are the Well History Addendums to include with the Well Completion Reports for the subject wells. If you have any , questions, please call me at 263-4944. Sincerely, uj. Gruber Associate Engineer jG/tw GRU3/L73 Enclosures xc' Well Files. RECEIVED J AN 2 9 1985 b~l & Gas Cons, commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany ARCO Alaska, In~' Post Office. _ ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-lW> 10/16/84' 2B-i~ .... 10/17/84 2B-2~ ..... 10/17/84 2B-6X~ .... 6/02/84 2B-10z-~' 6/02/84 2B-11~- 6/03/84 2B-12N*-- 6/02/84 2B-14~ ..... 10/28/84 2B-13y .... 10/28/84 2D-5,~" 10/05/84~ 2G-l~. 9/21/84 2G-2,.-' 9/22/84 2G-3., 9/23/84 2G-4~ 9/23'/84 2G-8 %~- 9/30/84 2F-15~ 4/13/84 2X-13~."12/18/84 2X-14..~-' 12/21/84 2X-15~ ......12/23/84 2X-16) .... 12/21/84 Receipt Acknowledged: B. Currier BPAE Chevron D&M "Static" SBHP lB-3 ~ :?' 6/26/84 SBHP " " 1B-4~ '" ,~6/26/84 " " " lB-6 Y' ,,, 7 / 01/84 " " 1E-2 ~ 6/22/84 " " 1E-7 ~,>~'~/14/84 " " 1E-4 ~-- 10/15/84 " " 1E-12F~ 6/24/84 ~' " " " 1E-20~-'- 6/23,22/84 " " " 1E-22~? 4/23/84 " " "' 1E-25~ ..... 6/23/84 " "Static/G. Ring" 1E-25¥ 11/09/84 " " " 1E-29'~ 6/23/84 " " " 1E-29} 10/14/84 " " " 1F-4 * .... 9/14/84 " 1F-4 ~ ..... 9/14/84 " "Static/G. Ring/Tagh 1F-7'~ .... 7/05/84 " SBHP 1F-11 ~'~ 4/25/84 " 1F-14~ ...... 2/07/84 " 1F-15%-- 2/14/84 " 10-1, .... 6/29/84 " VlG-i~ ~ 9/13/84 " /1G-3'......" 5/16/84 " v lC-5." 6/29/84 " .-' 1H-4 ~-' 6/24/84 " 1Y-3 ~- 1/21/84 " 1Y-51~' 5/06/84 " 1Y-9~- 5/06/84 " 1G-14.--" 1/12/84 " 1L-2 e-~ 10/21/84 iL-3 '~'~- Date: DISTRIBUTION Drilling W, Pasher Geology G. Phillips Mobil Phillips Oil NSK Ops. J. Rathmell "Static" "Static" "Static" ~./;.cat State of.. A~.,., Sohio ':'"' , Union Well Files ARCO Alaska. Inc. ,$ a subsidiary o! AtlanticRich~leldComDanv z' ARCO Alaska, Inc. ~' Post Office Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 26, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-13 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2X-13 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L22 Enclosures RECEIVED DEC 2 8 Alaska Oil & Gas Oons. Cornmissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany - /,, STATE OF ALASKA ALASKA~ ,AND GAS CONSERVATION CC1 41SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-174 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21197 4. Location of well at surface 9. Unit or Lease Name 1229' FSL, 2:~8' FEL, Sec.4, TllN, R9E, UM ' L~C-;,7'[c":,i',;i~'.~' Kuparuk River Unit At Top Producing Interval. VF[~IFiED .*. 10. Well Number 1216' FNL, 1368' FEL, Sec.3, T11N, R9E, UM ISurf' ~"_ --Ii 2X-13 At Total Depth B.H._ (;P'~__~ 11. Field and Pool 1025' FNL, 1027' FEL, Sec.3, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 112' RKB ADL 25645, ALK 2576 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116. No. of Completions 11/04/84 11/11/84 1 2/06/84 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 8539'MD,6187'TVD 8428'MD,6108'TVD YES)~] NO []I 1898 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D I L/CNL/CNS/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 10:~' 24" 260 sx Cold Set II (Ap fox) 9-5/8" 36.0# L-80 Surf :~747' 12-1/4" 900 sx CS Ill & 650 sx CS II 7" 26.0# J-55 Surf 8510' 8-1/2" 315 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8278' - 8285' :~-1/2" 8126' 8097' & 8268' - 8278' w/4 spf, 120° phasing 8248' - 8268' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8224' - 8240' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 8014' - 8060' w/12 spf, 120° phasing 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.i~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None REC ' VED DEC 2 8 Alaska Oij &. Gas Cons. Con'Imiss!o~ Ar, ct~,orage - Form 10-407 GRU3/WC20 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 Upper Sand 7978' 5784' N/A Base Upper Sand 8061' 5845' Top Lower Sand 8190' 5938' · Base Lower Sand 8371' 6068' 31. LIST OF ATTACHMENTS _ I~/~11 H~r¥ 'Cvrn~nn~r .~,~rv~v (2 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed. ~j. :j.."~,l ~f~) ~.~'~c~. ~,~ ~L _, Title Associate Engineer Date .~, i" 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 ADDENDUM WELL: 11/15/84 11/18/84 2X-13 Arctic Pak w/42 bbls CS I, followed by 58 bbls Arctic Pak. 8428' PBTD RU SOS, log CBL/VDL/JB/GR f/8410' WLTD to 5896'. Rn GCT gyro f/8375' WLM to surf. D ECE!VED .L;~F,,,i 2 9 J985 ~'1 ~.., "' ..... :~: ,b,,',; d 6'as COns. Corn~issio, Dr il 1 ing ~up-er int end ent ' ~ate rcc'a '1~ AtlanticRichfieldCompany '~ Daily Well History-Initial Report Inllrtlctione: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District 1 County or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE 304328 North Slope Borough ADL 25645 IState Alaska Well no. 2X-13 Completion Roll'n #4 API 50-029-21197 Operator ARCO Alaska, Inc. Spudded or W.O. begun [Data I Complete Date and depth aa of 8:00 a.m, 11/13/84 11/16/84 12/01/84 thru 12/03/84 12/04/84 12/05/84 Complete record for each day reported I Hour 12/03/84 2300 hfs A.R.Co's W.I. 56.24% IPror status f a W.O. Run CBL/VDL/JB/GR f/8410' WLM - 5896' WLM. Rn GCT gyro f/ 8375' WLM - surf. Arctic Pak w/250 sx CS I, followed by 58 bbls Arctic Pak. 7" @ 8510' 8428' PBTD, 8539' TD Wait on weather. 7" @ 8510' 8428' PBTD, 8539' TD, Prep to perf 10.0 NaC1/NaBr Accept ri$ @ 2300 hrs, 12/03/84. ND tree, NU & tst BOPE to 5000 psi. 7" @ 8510' ,' 8428' PBTD, 853~' TD, Rn'g 3½" compl string 10.0 NaC1/NaBr Perf 8278'-8285', 8268'-8278', 8258'-8268', 8248'-8258', 8230'-8240', 8224'-8230', 8230'-8233', 8214'-8224' w/4" JJ, 4 SPF, 120° phasing. Perf 8014'-8060' w/5" JJ, 12 SPF, 120° phasing. Perf 8214'-8218' & 8230'-8233' w/4" JJ, 4 SPF, 120° phasing. PU 6.125" gage ring/JB, RIH to 8200'. PU Bkr FB-1WL pkr & tailpipe assy, set pkr @ 8095'. PU 3½" compl string & begin RIH. RECEIVED J L] £ 0 ?: 1985' Ataska Oil & Gas Cons. ~Jormn~ss~or~" ' The above is correct Signature For form proparatlon and distribution, ~' see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 1/18/85 ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be shbmitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, Accounting cost center code District Alaska Field County or Parish Lease or Unit Tte North Slope Borough State Alaska Well no. 2X-13 ADL 25645 Completion API 50-029-21197 Kuparuk River Auth. or W.O. no. AFE 304328 Roll' n #4 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W,O. begun I Date Complete I 12/03/84 Date and depth Complete record for each day reported as of 8:00 a.m, 12106184 12/07/85 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our I Prtor status if a W.O. I 2300 hrs 7" @ 8510' 8428' PBTD, 8539' TD, RU BPV 7.2 Kuparuk crude oil Rn 248 jts, 3½", 9.3#, J-55 8RD EUE tbg. Instl Bkr FVL vlv, tst to 5000 psi f/15 min; OK. Lnd tbg. Set pkr, sheared off PBR. Tst tbg to 2000 psi; OK. Tst ann to 2500 psi; OK. Tst 3½" tbg to 2500 psi. Instl BPV. ND stack, NU tree, pull BPV. Tst tree to 300/5000 psi; OK. Tst pack-off to 5000 psi; OK. Displ well w/30 bbls diesel, followed by crude oil. Shut SSSV, bled tbg to 0 psi; OK. Bkr FB-1 perm pkr @ 8097.03' - TT @ 8126.45' Bkr FVL SSSV @ 1897.87' - Bkr FHL @ 7832.95' 7" @ 8510' 8428' PBTD, 8539' TD, RR 7.2 Kuparuk crude oil Set BPV. RR @ 0700 hrs, 12/06/84. Old TD New TD Released rig Date 0700 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data . PB Depth 8539 ' IKind of rig I 12/06/84 Type completion (single, dual, etc.) Single 8428' PBTD Rotary Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval 0,, or gas Test time Production '~ ~'' %~'' ~- ~ V ~ U Oil on test Gas per day ,.t i.. L 0 .7 ]985 Pump size, SPM X length Choke size T,P. C.P. 'Water % GOR Gravity Al~Na OlJ ~ E4[~tiv~ date corrected was (.;ohs. Cor~lr Jssior~ The above is correct For form preparation and~is~ribution,~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Well History - Initial Report- Daily Inetructlone: Prepare and submit the "Initial RelN3rt" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving Inclusive dates only. District Field Alaska County. parish or borough North Slope Borough Lease or Unit ADL 25645 ALK 2576 ~Title Drilled IState Kuparuk River Alaska IWell no. 2X-13 Auth. or W.O. no. AFE 304328 NABORS 26-E API: 50-029-21197 Operator ARCO W.L ARCO Alaska, Inc. Spudded or W.O. begUnspud IDate 11/4/84 IH°ur 0600 Hrs IP tatusifaW.O. .... Date and depth as of 8:00 a.m. 11/04/84 thru 11/05/84 11/06/84 11/07/84 11/08/84 Complete record for each day reported 56.24% 16" @ 103' 1994', (1891'), TIH Wt. 9.1, PV 17, YP 26, PH 10, WL 15.2, Sol 6 Move rig to 2X-13. NU diverter & tst; OK. Accept ri~ @ 2230 hfs, 11/3/84. PU BHA & GIH. Spud well @ 0600 hfs, 11/4/84. Drl 103'-1994', trip f/new BHA. : 540', 2°, N43.5E, 539.99 TVD, .68 VS, .51N, .48E' 932', 13°, N56.5E, 928.55 TVD, 48.04 VS, 26.06N, 40.36E 1418', 27°, N53.5E, 1384.45 TVD, 213.14 VS, 123.13N, 174.19E 1893', 43.4°, N52.5E, 1768.65 TVD, 489.17 VS, 289.21N, 395.49E 16" @ 103' 3770', (1776'), Prep to rn 9-5/8" j Wt. 9.8, PV 24, YP 25, PH 8.5, WL 10, Sol 13 FIH. Drl 1994'-3770', 28 std short trip, C&C, POH & LD BHA. 2025', 47.2°, N55.SE, 1861.50 TVD, 582.86 VS, 344.36N, 471.40E 2561', 47.4°, N52.5E, 2223.55 TVD, 977.34 VS, 578.76N, 789.58E 3376', 48.7°, N47.5E, 2772.09 TVD, 1573.91VS, 971.91N, 1245.70E 3698', 49.7°, N46.5E, 2982.69 TVD, 1813.54 VS, 1138.82N, 1423.10E 9-5/8" @ 3747' 3770', (0'), Drlg cmt Wt. 9.2, PV 9, YP 2, PH 9.5, WL 10.8, Sol 10 Rn'93 its, 9-5/8", 36#, J-55, HF-ERW BTC csg w/FC @ 3664' & FS @ 3747'. C&C. Cmt w/900 sx CS III @ 12.2 ppg, followed by 650 sx CS II @ 15.3 ppg. Displ w/mud, bump plug w/1500 psi; OK. CIP @ 1355 hrs, 11/6/84. ND diverter. NU csg spool & BOPE. Tst BOP's. PU BHA & GIH, tag FC @ 3664', tst csg to 1500 psi; OK. Drl FC & cmt. 9-5/8" @ 3747' 6215', (2445'), DRL6 Wt. 9.7, PV 19, YP 9, PH 9.0, W-L 10.0, Sol. 11 Drld FS & form to 3780' Perform LOT = 12.5 ppg EMW. Drld 3780'-3847'. Trip for BHA &Navi Drill. Drld & ND 3847'-6215' 4140', 49.8°, N60.5E, 3270.10TVD, 2146.29VS, 1352.98N, 1680.85E 4797', 51.0°, N56.5E, 3692.28TVD, 2649.31VS, 1623.55N, 2104.90E 5143', 51.1°, H55.5E, 3909.79TVD, 2918.34VS, 1774.02H, 2327.98E 5772', 52.0°, H60.5E, 4295.85TVD, 3414.24VS, 2023.21H, 2757.41E The above is correct Signature For form preparation and d~strlbution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date 11/21/84 Title AR3B-459-1-D A~aska OiJ & Gas Cons. Commiss!on Number all daily weir I~l{~(~f~;f~onsecuttvely as they are prepared for each wall. Pa~e no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations If testing, coring, or perforaling, show Iormalion name in ctescribinq work performed, Number all drill stem tests sequentially. Attach description of ail cores. Work performed by Producing Section will be reported on '*Interim" sheets until final completion. Report official or representative test on "Final" form. 11 Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting el oil string until completion. District Ico,nt, orPar,sh Alaska North Slope Borough Field Lease or Unit Kuparuk River ADL 25645 Date and depth as of 8:00 a.m. 11/09/84 Complete record for each day while drilling or workover in progress 9-5/8" @ 3747' 7706', (1491'), Survey Wt. 10.0, PV 21, YP i0, PH 9.0, WL 6.0, Sol 14 Drld & ND 6215' - 7706' 6587' 49.9° N62.SE 4805.90TVD 4049.07VS 2341.78N 3307.42E 7221' 48.0° N58.SE 5209.12TVD 4525.18VS 2573.00N 3724.89E 7621' 43.2° N61.SE 5500.23TVD 4811.54VS 2710.93N 3976.73E Alaska WeE no. 2X-13 The above is correct Signature For form preparation ancl~distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Date ITitle 11/21/8~ Drilling Superintendent RECEIVED DEC 2 8 Alaska Oil & Gas Cons. Cor;'~rniss!er~ as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Preoare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abanctoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefimte Or appreciable length of ~ime. On workovers when an official test ;s not required upon completion, report completion and representative test c~ata in blocks prov~c~ecL The "Final Report" form may be useo Ior reporting the entire operahon ,t space ,s avadable. I Accounting cost center Dislrict ICounty or Parish ~State Alaska I North Slope Borough / Alaska Field Lease or Und [Well no. Kuparuk River ADL 25645 I 2X-13 Auth. or W.O. no. ~ Title AFE 304328 I Drilled NABORS 26-E Operator ARCO Alaska, Inc. API50-029-21197 A.R.Co. W.I 56.24% Spudded or W.O. begun Date Spud 11/4/84 Dale and depth Complete record for each day reported as of 8:00 a,m, 11/10/84 Iotal number of wells (active or inactive) on this est center prior to plugging anti bandonment of this well our I Prior status if a W.O. I 0600 hrs 8428', (0'), RR @ 0600 11/13/84 thru Wt. 10.0, Vis NALL/NABR 11/13/84 Navi-DRLG f/7706' to 7894'. POH. CO BHA. RIH. DRLG f/7894' to 8539'. CIRC &cond mud. POH. RU Loggers. RIH w/triple ~ stack run# 1- DIL/CDL/CNS/GR. Tool lost power @ 1000' (POH). RIH w/DIL/CDL/CHS/GR/-RUN#2. LOG f/8543 to 3753 for caliper & dual. Make 3 passes w/DIL/CDL/CN F/8543 to 7750. Finish POH. PU SFT tool RIH. Could not get DN below 4490'. POH RD gearhart. RIH f/wiper trip. PU to make connection, became stuck @ 8306'. Work pipe could not.go up or DN or rotate, CIRC. OK. Broke free. Wash & ream to BTM, no fill. CIRC & cond mud. Short trip. CIRC &cond mud & hole. POH, LDDP. Change top rams to 7" RU & RUN 213 jts. 7" 26# J-55/HFERW BTC CSG +2, Marker JTS, CIRC & cond mud. Rig pumped 80 bbls 11.0 PPG BJ sweep. Mix & pump .315 sx 'G' @ 15.9-16.3 PPG w/3% KCL, .7%, D-19, .3%, D-31, 1%. D-6. Displace w/322' bbls 10.0 ppg NACL/NABR. Bump w/3000#. Test CSG @ 3000#. OK. CIP @ 15:00 11/12/84. Check floats, held, OK. PU stack. SET slips. ND Bope. Install pack-off & TBG head. Test to 3000# OK. Clean pits RD cellar ri~ release @ 0600 11/13/84. 7809 42.2 NGO.5E 5638.17 4938.98 2772.86 4088.45 Old TD New TD Released rig Date 0600 hfs Classifications (oil, gas, etc,) Oil Producing method Flowin~ Potential test data PB Depth K nd of rig 11/13/84 Rotary Type completion (single. dual. etc.) Single Official reservoir name(s) Kuparuk Sands Well no, Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P, Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date Title Z.~d~' ~,,.,..~..~ 11/21/84 For form preparation and o~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87'. AR3B-459-3-C ~r~.l~ir~g iS P~ ,ir~endent DEC 2 8 A~aska Oil & Gas Co~s. Number all prepared for ead~'~l.;O~ as they are daily well historyAf~.r~A.Ci?,,EL~,ec..ativety Page no, 3 Division of AtlantlcRIchfieldCompany SUB.$URFA CE DIRECTIONAL SURVEY n~ UIDANCE ~qONTINUOUS r~OOL Company Well Name Field/Location AT,LANTIC RICHFIELD COMPANY 2X-13 (1229',FSL, 238' FEL, S4, T11N,.R9E, UM) . KU..PA~RUK~ NORTH S, LOPE~ ALASKA , Job Reference No. 69806 PEPPEL Alaska Oil & Gas Cons,, ' ..... ~":":' Date DEC-06-84 Computed By: STEVENS A~CU AI,AS~A, [NC, 2X-13 FuPAPUK TOoL l,f)Ca'l'l!'iN: TA~:~iPi~'rl~l,- av~raqed qeviat, ioR aha azimuth 1 ?~TEPPfti,A'I'TI~N: h.l ~,~k Ff~l~ At-~Cd AT.A$~,A, [NC, NL]RJ'H 5!,[1pl~, AL, ASKA St_JP.V~:'y i)ATF: 18-Nt~V=B4 A~C~ AI~,^,";I'<'A, 2X-1 3 KIIPhR!IK T P UFc mEA(:3UkWb VVRTICA DEPTh DEI~TIi 0.0 {) 0.0 100.00 lO0.O 200. OU 200. 300.00 400.00 3q9.. 9 %00.00 4c)g.'- 6_00.00 59go9 TOn,nO 009.7 nO0.OU gUn,O0 8q'l . 7 10{){'). 01} 9q%. 3 1100.00 1U91..i l?On. O0 1185.9 1300,nO !279,3 1400,00 1370.6 1'~00, O0 1459,5 1600,~0 1S44.8 170~,00 t675.4 1~00,,, OO }r704'3 1~0~.00 1779,,0 2000.0U 1049. b 2100.00 1917.9 2?Oo.nu 19~b.8 2~00.n0 ?0%3.4 240o.00 2121.5 2bUn.no 9189.~ 2600, O0 22~8.2 2700.00 290o.o0 ~g6g.l 3200.00 ~66~,0 3400.00 2801.b 3~0o.00 7867.3 3fion.nb 2933.{) 37o0.o0 3800.00 3~R3.u CC~,4PUT',~TIi'QN L)AT~: 5-1)EC-84 Th/C. A [. ASK A !)ATE tJF SUPVEY: 18-NOV-B4 KI.;I,bY BLISHING FhEVATION: 112.00 FT ~NGINEER: [.F' P Pi-: [. .INiERP(~I,ATt.,.D VAI,UF,.'5 ["'~}{ EVI::]t! 1(.}0 Ft-.]FT (iF MEA,SI';RFD D.EPTH S tj R - $ [< A V t.P'l'T CA!, DIEP COt;RSF' VER'flCAL DJ)GbEG RECTANGI. II~AR COIJ DEVIATL~)h AZI~LITH SECTION SEVERITY ~JORTH/Sf]tITH Eh5 DEG a~[~ t)~G ~1~'~ FEET DEG/I UO FEET VE ROINATEfi HORIZ, I)EPARTURE T/WEST PlS']~, AZIMUTH FT FEET DEG ~IN 0 0 ['J o P F n.Ou 0.00 U,O0 0 10 ~.' lb O W 0.08 0.52 U.O9 () 20 ~, 14 il W 0,17 0,15 O,bO 0 25 r~, 31 q w 0.33 0.17 1,16 0 1~ ~' ~'/ 21 W t).~6 0,19 1.67 0 32 S ~0 0 F O.3F 1,44 2,24 2 46 h 53 ~ ? 2.09 2,01 4,24 5 2 ~ 64 24 ~ 9.54 2,44 7,41 7 47 ~' 59 34 F 2n.78 2,55 !2,79 11) 46 ~! 50 4° ? 36,9') 3.51 ~1.42 0.00 Fi 0,00 N 0 0 g 0,04 E u. U9 N 22 21 g 0,13 W 0,52 N 14 lb w 0.36 ~ 1,21 N 17 13 ~ 0.77 w 1,84 N 24 49 W 1,00 W 2,45 N 23 57 w 0,52 E 4,32 N 10 56 E ~,57 F 9,91 N 41 31 E 16,47 E 20.85 N 52 10 E 30,08 E 36,97 N 54 32 E 070,43 107'~,09 1167,31 1!47.5b 1437.g2 1514,41 1~92,~3 1607,n4 14 21 ~' gB lO K 5R.73 3,02 33.14 1'1 3~ g' 58 16 v 86.30 2,88 47,52 Po 5 ~ 54 1n F !.18,7~ 2.48 65.q~ 22 12 ~ q2 33 F' !54.60 2,76 87,19 2b 31 N 5J 56 F' 194,77 3,08 111.]4 29 11 N h5 6 F7 240.82 3,81 137.96 ]3 24 w 53 5! ? 299,96 4.0? 168.20 40 10 ~ 54 17 W 413,23 3.07 239.14 43 20 N 53 b~ ~i 47~,59 4,00 275,17 48,51 F 58,75 N 55 39 E 72.05 E 86.31 N 56 35 E 09.11 W 118'79 N 56 32 g 12'7,72 E 154:b5 N 55 40 E 159,94 E 194,~9 Id 55 9 E 197,57 F 240,97 N 55 4 E 240.10 F 293.16 N 54 59 E 28~.55 F 350.93 h 54 44 E 33'1,44 V 4~,59 I~ 54 40 E 391,23 W 480.04 N ~4 35 E 1737.53 1041,4b 2n'77.05 2146.?1 ~?14.63 29~3,41 2~b2.19 46 22 ~' qb 21 F 550.41 1,77 319,34 47 7 ~' 55 3n F 623.31 0,74 360.45 47 24 ~, 54 50 ~ 696.74 0,52 402,34 47 lg N 54 17 F 770.32 1,06 444.90 47 0 ~ 53 4o F' 843.43 0,13 488,08 4~ bl ~ 53 3 ~ 016,33 0.54 531.5q 4b 43 ~.) 50 55 F 100!.70 1,2l 621'03 a6 24 ~-' 5o 17 F l~33.80 0,44 ~67'27 46 .tn ,'~ 49 ,t6 E 1205.R4 0,42 713,95 448.96 F 550.94 I, 54 34 E 5n9.17 F 623,84 N 54 42 E 569.53 F ~07,31 N 54 45 E 629.03 F 770,95 N 54 45 E 688.78 F: 844.18 N 54 40 E 747,45 F 91'1.20 N 54 34 E b05.b~ E 990,15 N 54 ~6 E 562.77 F 1063.00 N 54 ]5 E 918.~8 E ~135,44 N 54 0 E 974,27 V 1207.~6 N 5] 45 E 2420.54 245R.61 2556,05 2622.~9 ~68Q.53 )75%,39 2~1.0! 2~6,~5 2°5!.60 30!7.56 47 'l ~ 49 45 E 1278.73 o,21 761.14 4'1 IR h' 48 51 F: 1350,8.3 1.22 808,'10 47 50 ~ 48 4 E 1423,82 0.72 857,81 48 3 h~ 47 37 F 1497.15 0,47 907.07 4H 32 ~ 47 R F' 1570,73 u. TR 958,17 48 50 ~' 45 26 F: 16~4.77 0,53 1009,71 a9 P [' 45 44 [' 1718.~3 0.49 1()62.10 49 1% l? 45 27 V 179~.02 0,56 1115,0] 49 ? ~ 4b 22 E 1807,1h 0.33 1168.2q ~8 .t7 ~' 4~ 33 ~ 1~40.89 2,4~ !2PO.d] 1029.96 F; 1280.59 n 53 32 g !085.60 E 1)53,76 ~ 53 18 E 1140.82 F 1427.34 N 53 3 E 1195,~9 E !501,34 N 52 48 E 1250.85 F ]575.07 N 52 32 g 1305.09 ~; 1650.56 t~ 52 17 E 1360.00 F: 1725,59 N 52 0 E ~414,11 E 1800o83 a 51 44 E 1467.95 E 1~70.1~ n bl 29 E [521.77 F 1950.95 N bl lb E 5000,OV 5100,00 520n,oo 530n.ou 5400.00 5500,n0 5600.00 5700.00 5Ron Ou 5gO0:Ou 600o.no 610o.oo 62oo.oo 6300.o0 0400.00 6~on.no b60O.O0 6700,0u b~O0.O0 60on.oo 7000.00 7100.00 7200.0U 730n.o0 740o.n0 7~OO.Ou 7600.00 770n.00 7800,00 TNC. c:r'.,P.,PUTATI. R~,, u~.',rE: I NT~:RPt)[,ATND VA TPUF SdR-FKA Cnl}Pb VFRT.ICp, I, VLPl'TC&I, DEVIATIr'~r4 A [.~FPTIt D F: P'f _~! DEG M~[N D 3835.s5 3724.~5 51 13 3~q9,58 3787,58 ~962,40 3~50.4o 51 8 4024.46 ~912.46 52 4085.jO 3073.30 52 34 414b.1~ 4f134,lB 52 2P 42~7,22 4095,~2 52 426~,~7 4156.47 52 43~9.~R 4217.o~ 51 43°i.H~ 427~.a8 g454.11 4542.1! 4510.62 4404.62 4579.22 4467,~2 51 12 4o41.94 ~52O.04 51 ~705,7q 4593,79 49 44 4769,97 4657,97 qO 14 48]q,27 4722.27 49 3o 4809,o? 4787.62 48 4~ 4965.6~ 4853.62 ~030.0% .;oIP,~5 I, UV5 5005,37 5159.70 5')47.70 5224,09 5360,26 54~2.'13 5120,7] 43 22 ~.' ~bOb,~% 5~9t,45 43 14 ~-~ 557~,'17 5456.77 42 5552.42 5540.42 a2 20 ~,; 57~6,36 bf, 14.'%6 42 20 ~.' F: ZIMi!Tit b - D F C - B 4 PAGE 2 DATE DF' StJRVE¥: 1B-NOV-U4 KEI,I,Y BUSHING ELEVATION: 112,00 Fl' ENGI.NEEP: PF:PPEL 100 Fk;F-T (JF MEA,SURED DE'PT}i VERTI'CAL · 5FCT ID, N FEET DOGLEG ~ECTANGUbaR SEVERITY i~nRTH/SOUTH PEG/lO0 FEET COORDINATES HORIZ, DEPARTURE; EAST/WEST DIST. AZIMUTH FEFT FEET DEG 20!5,26 2090.'t4 2166.33 2242.44 2394.]1 24'10,84 254~,44 2625.95 270~.59 0.8q 1271.0~ 4,16 1319,~5 0,41 1363,72 0,35 ~405,80 0.15 )449,57 0,36 1492,37 1.11 1535,35 0,26 1578 56 U,2g lb~1:97 1,03 1565,05 1577,B3 F' 2026.13 N 51 8 g 1. b36.03 E 21ol.73 N 51 6 g lbg7.~? F 217'1,69 N 51 13 E 1760.01 F 2253 b2 N 51 22 k 1~23..3q F 2329~37 N 51 30 E 1~8(. 12 F 7405.13 N 51 38 E 1949:46 E 2481.47 N 5! 46 g ?01~'9] E 2558.86 N 51 54 E ?07~.18 E 7616 23 N 52 1 E 2142,38 F ~'/1~:70 N 52 8 E 27~1.50 0,21 170~.59 N 2859,3B 0,14 1'151,17 N 2037.1.9 0.36 !7g3,7R N 30!5,58 1,70 1835 83 hi 3094.9¢) 0,22 1875:55 N 317a,17 0,17 1917 08 g 3253,32 U,23 1957142 ~1 313~,29 0,]4 19q7,45 N 341~.05 0,3] 2017.21 N 3489,50 0.35 2075.b] N 2207,41 F; 27ql.]9 [~ 52 15 E 2272,b0 £ 2869.02 N 52 23 E 2337.70 F 2946,01 N 52 29 E 2403,87 E 3024,71 N 52 37 E 2472,()0 E 3103.58 N 5~ 47 E 2540,19 F 3182,42 N 52 57 E 2608.36 ~ 3261,14 N 53 6 E 2576.53 E 3339,70 N 53 16 E 2744,b~ F 3418,06 a 53 24 E 28~2,55 E 3496,1~ N 53 33 E 3507,69 ]645.65 372].56 3878.26 3954.85 4031.]2 4106.79 4!81.70 4257,25 0.05 2115,92 0.16 215b,27 0.16 2194.73 0.21 22)4 31 0,90 2273i28 0,49 2311 02 1.71 2349 b7 0.56 2385~92 0 72 24~1.76 0~46 ~457,B2 288(),2% E 357],92 N 53 41 E 294'1,55 F )651,55 N 53 49 E ]0~4,91. E 3729,i4 N 5] 56 E 30~1.90 ? 3uOb.b~ N 54 3 E 314B,35 F 3083.2o N 54 10 E ]2~4.77 E ]959,58 m 54 lb E 32R1,23 E 4035.77 h 54 23 E 3347,~7 E 41~0,90 ~ 54 31 E 3413.69 F 41~5,48 N 54 38 E 34~0,]6 E 4260,73 N 54 46 E 4333,43 0,42 2494,28 4400,78 0.53 7530~95 4486.09 3,7t 2567o81 ,i5b0.17 1.00 2604,'14 4637,29 3,20 ?t, 40,53 ~701.06 O.]R 2674.1o 4769.5R 0,34 2'108,03 4~37.47 0.67 2741.76 40U5,02 oeoq 2775.qg 4q'12.27 0,73 ~0~.25 3547,b0 E a33b.b1 N 54 53 E 3b14,'11 F 4412,bq b 55 O E 3681.75 E 44~U,76 m 55 6 E 3'14b,09 E a562.07 N 55 11 E 38f)~.~4 F 4634,01 N 55 lb E 3868,97 F 470J.21 N 55 20 E 392H,59 E 4771.58 N 55 25 E 3987.13 ~ 4839,35 l~ 55 29 E 4046,37 F 4906.77 N 55 ]3 E 4104,b2 E 4973,91 N 55 3b E NOR'1'{t ~S! {]Pk, AbA,SI<A CC~hPbTA'T'Ifl{', b'A. IE: 5-[)F..C-~4 [[!'I'[,'k'.P~.II,ATk~[> V.a.[,t~)F,'5 F[)R ~]V~N lug FEET f)F b~ASURED D5;PTi{ TRtJ[-' Sl~-5~jh C~-)t_~P~; VEP'I'TCAL DOGLP:G R~?CTANGIJLAR C~/]~DTI~'!'E5 HfIRIZ, DEPARTURE ~;ASilR~,~ VVRTIOAI. V~]RTICAL [)EVIATIf'~ AZ[~UT}{ SECTION SEVErITy NORTH/SOUTH EAST/WEST D1ST, AZIMUTN 8000,00 5SO0,3,1 !)66R,ll 42 .]4 8t0o,c'0 5873,22 57,)1 .~2 45 40 8~O0,Ou q94b,3P bR33,~2 43 59 8]00,o0 601 /,O4 bo05,o4 44 24 ~4UO,O0 60Rb,23 5Q/6,~3 44 41 8500,0() 6159,33 o~47, ]~ 44 4] a53q,OO 61~7,d6 ~075,g6 44 4! bEG l.~ I r.: FF..I<T DEG/! O0 FEE'[' Fl.;liT ~'.' f.l 5 t-< 5030.46 ~'.,' 6.1 7 ~' 5lO7,73 ~ ~,() 51 Fi 5{76,86 ~: h(_, 2d p' 5246.41 ~- 6u 27 ~' 5316.52 ~ 60 ~7 F 5414.10 1,{9 0,70 0,17 0,58 0,00 0,UO 0,00 FEFT DEG MIN 2u4~.q0 ~ 4163 20 F 5O40 98 S 55 40 E 2875,~'? ~{ 4Y?3:IR F 5109:11 N 55 45 E ~909,00 N 4283,76 ~ 5178,1~ N 55 49 E ~943,15 N ~344,b0 F 5247,56 N 55 53 E 297'1,~6 N 4405.b6 E 53~7,58 N 55 56 E ]012,b] N 4466 74 ~ 5187,~8 N 56 0 E 302~,05 N 4490[60 ~ 54~5,02 N 56 I E ARCO A L, A,'-jK. A ~ 2×-13 KIIPARIIF, AbJ~SF^ .ll'J!'FkPul..nTl~.:l~ VALuF:5 I-'ON EVI<N FEET TpUF SHR-SE~, D~PTH [')F. FT H r~l~P'l' H O.OO o.uo ~0o0.00 9nb.3? 200n,O0 1849.53 ~737.53 3o0o,00 2532,b4 2420.54 4non,oo 31qb 36 5000,00 ~36~5 3724,85 6000.00 445~.~1 4~4~.~! 7000.00 509b. J7 UO00.O0 58o0.31 568~.31 PAGE 4 I)AT~ t)F SURVEY: 1B-NOV-ti4 KEhUY BUSii[NG .F. hEVATION: 112,00 FT ENGINEER: PF'PPtL MFASURE DEV!ATIF~h' AZI~aUTH 6ECT]DN ,SEVERITY ,',OATH/8 DEG MIN !)FG MT~,, F'Ek'T DEG/IOO FEET D DE PT 0 0 ~' 0 0 F' 14 21 ~: 5b lq ? b~.73 46 22 ~: Sb 21 F 550,41 47 3 N 49 45 ~' 127R,23 49 2 s~ 49 17 F 2015.2~ 51 13 N $~ 50 F 2781,50 51 25 ~ 59 ~7 F' JfibT,69 49 55 ~ 61 26 ~' ~]33,43 42 ]4 b' 61 % Fi 5039,4n 44 41 N 6{) 27 F' 5414,10 0.00 1.77 0.21 U,Ug 0,21 0,65 0,42 1,3g 0,00 UL, AR CF~()RDINATE$ H{lHIZ, DEPARTURE OUTH EAST/WEST DIST, AZIMUTH FI<ET FEET DEG NIN O,O0 N 0 33,14 N 48 t19.34 N 448 761,14 N 1029 1271.08 N 1577 1708,58 N 2207 2115.92 N 2B~O 2404,28 N 3547 28a2 40 ~ 4163 302b~O5 PI 4400 .00 E 0.00 N 0 0 E .bl g 58,75 N 55 39 g .96 F: 550.94 N 54 34 E .96 F 1280,09 N 53 32 E 83 E 2()?6 13 N 51 ~ E 741 E 27917~9 N 52 lb E 2, E 3573 ~2 N 53 41 E .50 E 433b,ul h 54 53 E ,20 E 5040,98 N 5~ 40 E .6o F 5415.0~ N 56 1 E ARCR AbASKA, 2X-13 N~R'rtt :il.,{iPl.'., TI",(",, AbA':K~., kj {~_.,'.; PlJ Ti'~T 1 {!N mE:~.,51~R["I) VEkTICA[~ VhRI'ICII., D ~; p T ~ ! I) E P T l i D K'- p i' ! t O.Oo 0.0 12,00 12.0 112,00 112,0 217,00 212.,U 312,~U 3!2,0 41?.hi 412,u 512,Ol 619,07 ~12,0 712.33 712,0 813,0b ~12,0 gld.$1 912.0 1017,73 1121 6,1 1112.0 1927174 1445,o6 14!2.o 15~0.Q~ 1946.05 2091 ,24 1 91 2238 75 20! 23B'~:O9 ?112.0 2532.1g 2212,U 26'7R,64 2~24,o~ 241 2960,~'/ 2512,U 3265.63 ?'ll~.u 3415,P2 PACE 5 ~)ATE ()F SURVEY: lB-N[)V-84 KEI,LY HUSHING FLEV~TION: 112,00 FT ENGIi~FEW: PEPPEL I~'[)~,( ~VKN 100 FEI<'[' ~lF' SUB-SbA DEPTH CO~JPSF DEVIATIOr4 AZIMUTH DEG MTb DEG alh -1 I 2,0(~ 0 0 1 t;O. OO 0 5 o.o0 0 1~ !on.mo O 21 ~00. Ol~ 0 25 '.tOn, no 0 lB 400. no 0 40 500, Or) 2 58 6{;0. o(} b 21 7()O.ou a 1n V~:RT ICAI., BOGLE(; RFCTA.NGIIL, At{ CgO SECTIOI'I SEVERITY NORTH/$g!JT}t EAS F~ET DEG/100 FEET FE RDINAT~S HO~IZ, DEPARTURE T/WEST DIST, AZIMI_IT~ E'~ F~ET DEG ~IN 0.0() 0.00 O.O0 0,00 0,03 o,OO 0.08 O,19 0,13 0,19 0,1~ 0.67 0.33 0.17 1.23 n.26 O.tg 1,'12 0,47 1,94 2,36 3,61} 1,O1 4,59 10.65 2,77 7 90 22.5q 3,1.5 13~'1! 0,00 F: 0,00 N 0 O E 0.00 E (),00 N 90 0 E 0,02 F 0.13 N 8 38 E 0,15 W 0,SO N 14 13 w 0.41 W 1,{0 N 18 10 ~ O.Ul W 1,90 N 25 11 ~ 0,97 k' 2,55 h 2~ 21 W 1,31 K 4,78 N 15 58 E 7,57 E 10,94 N 43 48 E 18.03 E 22.65 N 52 44 E 39,67 ],a9 22,94 ~ 3 03.04 3.O% 35,40 N 5 97.99 2,93 51,06 N 7 1.2~,41 1,86 71,21 N 10 !6n.23 3,14 95.4R N 13 215.1.6 4.23 123,23 N 17 271,R9 4,16 155.84 N 22 ]]0.69 ,i,t)R lOb,lO N 27 419.75 J,O? 242,9h N 34 511.69 3.62 297.02 N 41 2,40 K 39,70 N 54 42 E 2,18 E 63,06 N 55 51 E '1.72 F 93,00 n 56 41 E b*87 E 128,42 N 56 19 E H,bg E 16B.30 N 55 26 E ~.53 F 2~5,29 N 55 4 E 3,01 K 272,06 N 55 3 E 7, 10 E 339,96 N 54 46 E 2,75 E 420,12 N 54 40 E 7,27 K 512,1g N 54 33 E 616,Q0 O,1O 356 ~] N 50 725,27 0.91 41fl~76 N 50 833.20 O,U8 4R2,01 g 6R 039,g0 0,41 546,83 N 76 1046,72 0,97 611 26 N 85 115!.!0 0.54 678:4] N 9t 1256,37 0,]1 746.90 N 101 l~h] O~ 1.,22 ~16,92 N 109 1582,41 0,'15 96b.24 N 125 3 88 E b1'i,44 ~ 54 41 E 2~8o K 725,86 N 54 45 E 0,51 F B33,93 N 54 41E b.30 F' 940,82 n 54 32 E 0.~0 E t047,45 N 54 ~7 E 2,06 F: 1152,82 b 53 56 E J,14 E 1258,og t~ 53 36 E 4.90 E 136b. U8 N 53 lb E '1,00 F 1475,9n h 52 53 E 9.54 F ~587,4~ N 5~ 30 E 1695,08 0,66 1045,21 N 134 lqOg,Sh 0,,t2 1126 17 N !42 1921,35 1,45 !207:04 N lbO 2034.70 1,07 1283,56 N lbo 215o.72 0,95 1354,54 q IOR 2207,5~ 0,26 !420,96 q 2384,27 0,19 148b,71 N 2504,06 0,57 1553,~b N 197 2626,98 O,2R 1622,54 N 207 275n,5~ 0,50 16ql,o~ N 218 2,04 ~' 1701.51 N 52 O E 5.41 F 1816,60 N 51 41 E 1,43 E 1931,13 N 51 18 E 2.3~ ~ 2045,]0 N 5! 7 E 4.5R F: 9161,61 !~ 51 11 E 1.]7 F 2278,68 N 51 25 E 7,u3 F: 2395.11 n 51 37 E 7 05 ~ 2b~4 O0 N bl 50 E g:O? ~ 2637123 ~ b2 ! E 1,bl F: 275,0,55 h 52 12 E C I' '-' P tJ 'r A ? I o i.,-,-, . _ D A l' F. :. 5 - b F; C--, H 4 PAGE 6 DATE I.}F' SURVK¥: 1B-NOV-B4 KEi, UY RURH'[NG EI. EVATIUN: ENGINE[':R: PEPP[<I, PON 112,00 FT ~EASI1RFi..: 'VERTICAl, VLP-I'I('.Ab DEVIATIOq A'TI~iJTH DEPTH L)F'[-;'{~ ngP'lH DF;G MIN [)Fi:; ?-"TN 5119.79 ~912..~;r) 3~.00.00 51 6 b?7Q. 60 4012.0o. 3Q,)O. nO 52 ] 5443 P7 4112.0o 4nO~.O0 52 2q 5607~R1 4212,00 4tOO,nil 52 15 5770,R9 ~312,U~ 4~00.0(~ 51 5q 5Q]~.30 ~412.U(1 4'~00. ()0 5l 30 640Q.59 4~!2.Q0 46(')~. Ou 49 47 656R,48 ~812.oo 4700,~U ~'~ %4 671R.75 .1912.00 4RO0.O0 4~ 697ri.q4 50!?..00 4qOO.Ou 49 26 7025.~0 51!2.00 bnOO.OO ~q 50 7181.65 52!2.0o 5100.0U ~9 7330.~5 5312.0o 570o.nO 4'1 760~,q9 %512.~;0 b4UO.Ou 43 '7745.17 5612.u0 550n.00 42 7R80.56 5712.o0 5600,00 42 1q 8015,ql 5~12.U0 b7O~.Ou 42 46 ~' 50 4a F 2~'14,78 ~ ~ 14 F 299a.51 [' 59 !5 ~' 312q.oq ~ ~9 30 F 3259.49 ~' %9 43 F' 338~,1~ N 59 b3 E 3514.~1 ~; g9 40 ? 3639.~b ¥ ~9 27 F 3764.20 ~' gq 5q F 3885,g7 ~' ~1 2° ~ 4120.a3 ~ 61 ~5 F ,~235.21 r,~ 61 25 K 4353,11 ~' 60 44 K q681o%2 ~ 60 ]7 R 4775.73 ~' 60 4 F qRbR,O2 ~: ~9 49 F 495a.18 t~ 61 lO ~ 5050,23 0.16 2,59 0.33 0.21 0.90 0,14 0.15 0.21 1,36 0,24 0.75 0.42 4,11 3.06 0.17 0.50 0.69 1.21 0,54 0.46 0,00 0,00 17%9,59 N 22q5.49 E 2884,38 N 52 24 E 1827.~4 N 2390,16 E 300U,72 N 52 35 g !894,]5 N 2501.91 ~ 3138,18 N 52 52 E 1960.55 N 2~13.bR E 326'I 28 N 53 7 E 2025.O9 N 2724.83 F 3395130 N 53 22 g 2089,33 N 2~34.47 ~ 3521~29 N 53 3b E 7152,36 N ~942,66 ~ 3645,8o N 53 49 E 2215,42 N ~050,00 ~ 3769,69 N 54 0 E ~--. 7270o94 ~ 3154 08 F 38q0 56 N 54 10 E 7330,'13 ~ 325~25 F 4o09~55 N 54 21 E 2392.~4 ~ 3360.04 E 4124.U9 N 54 32 E 7447~30 N ~460 91 F 4238,/7 N 54 44 E 2503.72 N 356q:83 E 4350,22 N 54 55 E 2561,10 N 3069,0q F 4475.02 N 55 5 E 2blh.l? N 3765 77 E 4585,31 N 55 12 E 2664,01 N 3851190 E 46R3,73 N 55 19 E ~7il,oq N 39~4.04 F 4777 72 N 55 25 E ~'/57,00 ~ 40~4.26 F 4869:83 N 55 31 k ?BO2 66 N ~0q],29 Pi 4960.84 N 55 36 k 2847:b0 N 4172.67 E 5051,'13 N 55 41 E ?~93,37 N 4255.09 F' 5146,12 N 55 4'I E 2940,71 N 4340,21 g 5242,03 N 55 52 E 79R9,45 N 4476.01 g 5341,01 N 55 57 g ]020,0% ~' 4490.b0 E 5415,02 N 56 1E 8153,72 5912.0n bPOm.nu 43 5? 8292.g4 6u12.0n 5qun.O0 44 29 8433,43 6112.un hOoO.O0 44 4! ~: 60 56 v 5144.al ~: 60 26 v 5241.48 t: 60 27 w 5330.q9 t~ 60 27 ~' 5414.10 2X-1 .~ NORTtt $1,t)PL~ AI..,A,~KA IOP UPPI.¢R S~..',~I") I-~A,$1:.~ !~PPI~iR SAND b~SF LOW~'R PRI P C~t,:PUTATIrli',, OAT.E: 5-DEC-84 PAGE 7 DATE KELLY BIjSH[NG FbEVA'£ILIN~ 112,00 FT k;NGINEER-' PEPPE[. INTEJ';;PD[,a'Fk:!' Vp, I ijF~S F f-'~R C[t()SE,,'q H~,]R SURI.'ACE I,OCATION CIRIGIN= 1229' FSI,, 2.38' FEI,, 5KC 4, TIIN R9E UN TVI.',. RECTANGIII,A~ CODRDIN,~'I'ES ' MEAS~PE'D I~E. PTH ~'PtjM K}~ ,q U R-,qE h NUR'rH/SUII'I't.t EAST/WEST 797b.00 5784.07 5072.07 2835.20 RObl.O0 5844.95 5732.95 2H07.41 HI90,OO bo3fl.l] 582b 1] 2aOS.h2 R371.on 6067.60 5955~b0 2067.81 p498,0o o108.14 5996,14 2987.57 R539,00 6187,06 6075,06 3026,05 4150 22 E 4199 64 E 4277 69 g 4387 82 E 4422 69 E 4490 60 E 2×-'13 'lOP ijPPF{-< TOP Lrlw Et~ P 'l;fl'r A b P. bl I) W I<H b-DFC-84 PAGE 8 DATK lJF SURVI<YI KELLY niUSHl{,,{C, EL, EVATIUI'{: 112,00 r_ii-ilG!~= 19.29' FSI,, TOD 23t~' REC SORFACK LOCATION Ar SEC ~ Tll~ RgE~ T~GUbAR COORDINATES R'rH/sI)I.~TI.t EAST/WEST 5844,g5 5938,1{ 6~67,60 6108.{4 6187.00 5072,07 5'132,95 5826,13 5955,b0 5996'14 607b,06 2835,20 C~ 4150 2862,41 N 4199 2905,62 N 4277 2967.81 N 4387 2987.5'1N 4422 3026.0b N 4490 22 E 64 k 69 E 82 E 69 E 60 f FI."-~AT~ Wt<[,L LF~C~'FIO,q A'!' TP: i PtJF' M ['"' A,q U P D:D VFa'I'IC~I~ VE:R'rl CAL, 85~9. O0 61 b'l,Ob 6()7!'~,06 i~DNIZ(]NTAL I)EPgRTURE [)[STANCE ~ZIaIITH FEET pEG 5415,02 N 56 FT UM SCHLUMBER©ER ARCO ALASKA, INC. 2X-1~ KUPARUK NORTH SLOPE, ALASKA NOVEMBER 18, 1984 TVW PLOT FROM OCT DATA JOB REFERENCE 69806 $14 WELL: 2X-13 SURFACE LOCATION' 1229' FSL, 23S' FEL, S4, T11N, RgE, UM VERTICAL PROJECTION 0 0 1000 2000 3000 4000 ~000 N~ PROJECTION ON VERTICAL PLANE OF AZIMUTH S? SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/I000 IN/FT WELL- 2X-13 SURFACE LOCATION' 2OOO 1000 - ! 000 -2000 -~000 -4000 SOUTH -SO00 -- wEST 1229' FSL, 238' FEL, S4, TllN, R9E, UM HORIZONTAL PROJECTION K~EF 69806 SCALE : l/]~ ',N/FT .... ~' - : ........ - · 1 - - ,, , ' - , - - "%?-- -:'"."-'7!'"'"'7'"~ ....... !'"'"'+'?"+~-'"t""'":'"h! ................................ t': .......... f".~ ............... t ....... -~-, ,~--.---?-,..-I..--,=?-I ...... ,.-.,-..:...~ ......... ,-- ........... =, .......... l-., .......... :..., ............... -T"T"?'-~-?"'T-'-:'"?"'"T'"T"'7"T"I'"'"-'~'""? .................... t' T"?'"-"T ............. T T'"r'?'"~'"T"'? ...... ~ ................... T ............. T''~' .......... 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Reports and Materials to be received by: Required Date Received Remarks , ....... , , , , ., __ · .. · ........ · ..... , , ,,,, ,.,, , ., ,,, , ,, , ,,, ., , .... ·.. Samples .~. ' : _ · ........,¢'b ..:gl. "'------ d'f~'. I ' ~ ' ' ' '- ' ~u~ ~.~ ,v,~- £1 ----'" d 1<' ~.- , , ~,.,.,. , ~,, .... , ..... , , ,.., , .... · ..... ~~~:.., ~' ....... ~ ...... : M., ' Core ~scrip~on ..... - .............. ~v~' /o ~ ~.~-x~: .... ~ ~2 Registered S~ey Plat Y~-~ /.~ -O~"~gj" ,d f~ ~ ...... ~ ~ ,, , , Incl ina~on S~ey ,,~ZJ ~ D',I~ ~ , ,, . , . . , ..... .,. 04 . . ,. ~s R~ Yes ARCO Alaska, Inc. Post Office B ~0 Anchorage, A, ..~ 99510 Telephone 907 277 5637 Date: 12/04/84 Transmittal No: 4887 RETURN TO: ARCO ALASKA, INCo ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal° GEARHART/OH FINALS 2X-13 2" Dual Induction Laterolog "CDL/CNS/GR" I1 511 II ~! II 11 " 2" COmpensated Density/Neutron "Raw" "DIL/GR" I! 511 " 2" Compensated Density/Neutron "DIL/GR", Il 5II " Laserlog "WEL' "DIL/CDL/CNS/GR" . 11/10/84 Run 1 11/10/84 " 11/10/84 " 11/10/84 " 11/10/84 " 11/10/84 " 11/10/84 " 3753 - 8540 3753 - 8540 7440 - 8540 7440 - 8540 7440 - 8540 7440 - 8540 /cat Receipt Acknowledged: B. Currier Drilling · BPAE Geology' Chevron Mobil DISTRIBUTION W. Pasher D "',~s~a c~;~ ~ ~s Cons. Commfssfor~ AnchoraDo State of AK ~ G. Phillips Phillips Oil Sohio D & M NSK Cps. J. Rathmeli Union Well Files ARCO Alaska, I Post Oflk,= 6ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 F}ecember 11, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJ Dear F_CT: State Reports Mr. Chatterton' Enclosed are the November monthly reports for the following wells' 2D-14 2W-5 2X-ll 2D-15 2W-6 2X-12 2D-16 2W-7 2X-13 2E-14 2W-8 15-9 2E-15 2W-9 Also enclosed is a Well Completion Report for 2B-14. any questions, please call me at 263-4944. If you have Sincerely, · Gruber Associate Engineer JG/tw GRU3/L03 Enclosures RECEIVED Alaska 0ii & Gas Cons. Commission Anchorago ARCO Alaska, Inc. Is a Subsidiary ol AllanflcRIchfleldCompany -'~ STATE OF ALASKA ALASKA O,~-)AND GAS CONSERVATION COl~. )ISSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-174 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21197 UM 4. Location of Well at surface 1240' FSL, 241' FEL, Sec.4, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 112' RKB ADL 25645 ALK 2576 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2X-13 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0600 hfs, 11/04/84. Drld 12-1/4" hole to 3770'. Drld 8-1/2" hole to 8539'TD as of 11/11/84. R~n logs, PBTD is ~ 8428'. Injected returns and diesel cap in 9-5/8" annulus. Secured well & RR ~ 0600 hfs, 11/1.3/84. 13. Casing or liner rgn and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set @ 109'. Cmtd w/260± sx CS II. 9-5/8", 36.0#/ft, L-80, BTC csg w/FS ~ 3747'. CIP w/900 sx CS III + 650 sx CS II. 7", 26.0#/ft, J-55, BTC csg w/FS @ 8509'. CIP w/315 sx Class "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/CNL/CNS/GR f/8543' - 3753'. 16. DST data, perforating data, shows of H2S, miscellaneous data N/A !"~1 Y- ''~ Araska Oil & Gas Cons. Comrn!ss!sn AnchoraO3 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /_ JY~--/ .... OL~.'~-*~ / TITLE &SSOO,;,~-,~,~ -¢ng~""~r,.~ DATE ]'--/0-~-~1 NOTE----Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 JMM/MR32 Rev 7-1-R0 Submit in duplicate MEMORANDUM State of Alaska TO: ALASK& OII~.AND GAS CONSERVATION COMMISSIOt~ C. V ton November 13, 1984 Chaii~A'n '~ FILE NO: THRU: Lonnie C. Smith Commissioner FROM: A '" Doug mo~ Petroleum Inspector TELEPHONE NO: 105/L SUBJECT: Witness BOPE Test At ARCO's Kuparuk 2X-13 Well Sec. 4., TllN, R.9E, UM. Permit ~o. 84-174 On Nabors Rig No. 26E. Tuesd.ay....,Nov.e. mber 6,.1.98~'- I traveled this date from Anchorage to Prudhoe BaY to witness the BOPE test at ARCO's Kuparuk 2X-13 well. The BOPE test commenced a't 10:1.5 p.m. and ~¢as concluded at 11:45 p.m. There w'ere no failures and I filled out an AOGCC BOPE Inspection Report which is attached. In summary, I witnessed the successful BOPE test at ARCO's Kuparuk 2X-13 ~¢el I. 02-00IA(Rev. 10/79) . O&G #4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Well Location: Sec . ~. ~ ~/~R~ M ~,~. Drilling Contractor ~' , · . " Date '/'~' ,~/ /~/,~,~"' Well Z,~' --/~ Representative ' Permit ~ _ , ~'&asing se~ ~,~,7~7 ft. Rig ~~epresentativ~' Location, General Well Sign General Housekeeping .... 69~ '. .... · Reserve pit ~' .. Rig O~' BOPE Stack Annular Preventer Pipe Rams ~ ~ h Blind Rams .~..~]'~ Choke Line Valves H.C.R. Valve ~ Kill Line Valves ~ Check Valve Test Results: Failures Test Pressure o, ACCUMULATOR SYSTEM Full Charge Pressure '~.OP~ psig ! Pressure After Closure /Z~Q~) .. psig 200 psig Above Precharge Attained: min ~s( FUll charge Press~r~ Attained_: '~ min~s( Controls: Master . ~ , Remote ~K Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ; '~'~Test Pressure Lower Kelly / ~Test Pressure " Ball Type /~ Test Pressure /' "i Inside BOP /..A~Test Pressure Choke Manifold / ~Test Pressure , valves.., /3 No. flanges ~ Adjustable Chokes ~-- Hydrauically operated choke / Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Test Time / hrs. ~ days and Remarks: 1111 I1/ Ill Distribution orig. - AO&GCC' cc - Operator cc - Supervisor InsPector ARCO Alaska, I, ~ Post Offic,.~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 22, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Revised Conductor As Built Location Plat - 2X Pad Wells 9-16 Dear Elaine, Enclosed is a revised as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU2/L25 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany FROM' 'i.~ 10×18×'8~ 01:07 PHASE ~r AS-BUILT Thru, I ~0 e i- / WELLS 9 WELLS I Thru 8 NG LOCATED IN PROTRACTED SECTION 4 TOWNSHIP 11 H, RANGE 9 E, UMIAT MER, NO SCALE NOTE: BASIS OF BEARING I$ MONUMENTATION EX-NORTH AND ;EX IVtlDDLE PER LHD 6 ASSOCIATES. HIS SURV 14 WELL 12. WELL DRILL ,SITE 2:X CONDUCTORS AS-BUILT LOCATIONS i' _, ., , ,, . . . .... ,,.- ~._..-.::~. WELL 9 Y:5,971,05;.~.927 L0t, ?0e 19'55,4995~ X: 518,529,196 Long. 149°50'58.9185~ O.G, Elev. 72.1 Pod Elev, 763 I,O50' FSL 599' FEL, WELL IO Y=5.971,1}2,911 Lot, 70°lgSG.08g~ X~ 518,529.180 Long. 1490~0'58,g14G"~' OB Elev 720 Pad Elev, 76,R .'.~,~: SL' WELL I I Y =5~971 ~17Z,955 Lol. 70° Ig 56,6799"~.[~' 0 t X= 518,5~9.084 Long. 149 50 58,91~1 O.G. Elev. 7t.9 Pod Elev. 76,0 "..~J[.. Lot, 700 'Long. .~ ', PGd ~lev. 76, S ,,{.~'~: Lot. 70° I ~,'57,~6E a~' Long, 149°50 Pod Elav. 6,8 ..~ WELL 14 WELL 15 WELL 16 Y '-5,97 I X: 518,57-9 166 0,<3, Elev. 71.g I, 250' FSL Y; 6,971,233. 114 X 518,889. 151 O,G, Elev. 75.0 I,~-29' FSL Y; 5,g71,175,080 X= 518,,689,157 O.G. EIev. 73,1 I, I 69' FSL Y :5t971 ,11 X = 51R,889.0§4 O.G. Elqv, 75,2 I,IO9' FSL Y ;5~971 t055.154 X: 518,869.140 O,G. Elev. 7;5.4 ! ,049' F $ L 23,8' FEL Long, 149°50 Pod Elev. 77,0 258 F EL Lot, 70 1956~62 '~l Pad El~v. ? 7.0 ~.~J 259' FEL Rev./~ Sectior, Line 0iHo. ce~ OF A Elevotion$ Added 0Ct. I~, 1984 ~ ~ 49th DAVID flL I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED & LICENSED TO PRACTICE LAND SURVEYING IN THE STATE ALASKA ~ THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION 6 THAT ALL DETAILS APl CORRECT AS OF SEPTEMBER 21, 1984. ARCO Aleska, I nc, Kuperuk Project North Slope Drt DRILL SITE AX CONDUCTOR AS- BUILT LOCATIONS Dote: SEPT. $0, 1984 Scole; AS Drought sm.on: HZ D'~O. nO.; NSK 9,05,224! , ARCO Alaska, ' ')~ Post Offk,~'Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 3, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2X Pad Wells 9-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber ' Associate Engineer JG/tw GRU1/L75 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i, PHASE ]I WELLS AS-BUILT 9 Thru 16- II I0 14 15 16 · · / P~HA 9 IO SE I- EXISTING WELLS I Thru 8 LOCATED IN PROTRACTED SECTION 4 TOWNSHIP 11 N, RANGE 9 E, UMIAT MER. NO SCALE NOTE: BASIS OF BEARING IS MONUMENTATION ?.X-NORTH AND 2X MIDDLE PER LHD ~ ASSOCl ATES. DRILL SITE 2X CONDUCTORS 0 ,)--BUILT LOCATIONS Y = 5,97 1,05Z.927 Lot. ?0e 19'55.499' X= 518,529.196 Long. 149050'58.919' I,O50' FSL 599' FEL WELL 9 WELL I O WELL II WELL 12 WELL WELL 14 WELL 15 WELL 16 Y :5,971,112.911 Lot. 70° 19'56.089- X= 518,529.180 Long. 149°50'58.915" I,IIO' FSL 598' FEL Y =5,971 ,172.955 Lat. 700 19'56.680" X= 51 8,529.084 Long. 149°50'58.915. !,170' FSL 598' FEL Y=5,971,252.789 Lot. 70o 19'57.268" X = 518,529.168 Long. 149050'58.906" 2,230' FSL 598' FEL Y = 5,971,235. 114 Lot. 70° I 9'57.263" X= 518~889. 151 Long. 149°50' 48.394" 1,229' FSL 238' FEL ¥=5,971,173.080 Lot. 70°19'56.67Z- X= 518,889.137 Long. 149°50'48.399" I, 169' FSL 238' FEL Y =5,971,11 3.138 Lot. 70 ° 19'56.083" X= 51 8~889.054 Long. 14 9°50'48.406" I,IO9' FSL 238' FEL Y=5,971,053.154 Lot. 70°19'55.495' X= 518s889.140 Long. 149°50'48.407" I,O49' FSL 239' FEL .4 _ L!C~E-NSED TO PRACTICE LAND SURVEYING- IN THE STATE OF r' -=~[,THIS SURV '. ~ ALASKA 8~ THAT THIS PLAT REPRESENTS A SURVEY MADE - ~l I ~ ~ ,5!O~JUNDER MY DIRECT SUPERVISION 8~ THAT ALL DETAILS ARE CORRECT AS OF SEPTEMBER ~i, 1984. r. ~C.,~~.,-h.'-'-'-'' - ~ AF~CO Aiosko, Inc. 9 I ,,' Kuparuk Project North Slope Drilling - Ii:,,...~' DRILL SITE 2X co. c.o. LT "' '~ H~I][~': Dote: S£PT. 30,,984 Scole: AS SHOWN Oroughtsmon: HZ D~g. no.: ~K 9.05.224d 2 __ . : I ,~ISCA~.' ~: -- '" "" *' '"' ' '" '" - ~ · September 21, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2X-13 ARCO Alaska, Inc. Permit No. 84-174 Sur. Loc. 1240'FSL, 241'FEL, Sec. 4, Ti!M, R9E, UM. Btmho!e Loc. !156'FNL, !067'FEL, Sec. 3, TI!N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subj'ect to AS ].6.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and bv the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing i~.~stallation of the blowout prevention Mr. Je; ....... rey B Kewin Kuparuk River Unit 2X-13 Septe~ber 21, 1994 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Cor~ission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. C.V. terton Chaiz~nan of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~,.9~%ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office E, )i00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 10, 1984 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2X-13 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2X-13, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on November 4, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, n~ JBK/JG/tw GRU1/L25 Attachments RECEIVED SEP 1 7 19'8 u,~ ~x Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany ALASK, ) STATE OF ALASKA V~ IL AND GAS CONSERVATION O MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~( REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] ~RATIGRAP~ 9. Unit or lease name 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1240' FSL, 241' FEL, Sec. 4, T11N, R9E, UN At top of proposed producing interval 1404' FNL, 1449' FEL, Sec. 3, T11N, RgE, UH At total depth 1156' FNL, 1067' FEL, Sec. 3, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 112', PAD 77' ADL 256'45 ALK 2576 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1067' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8423' MD, 6177' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 48 o (see 20AAC25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program Kuparuk River Unit 10. Well number 2X-13 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling 'or completed 2X-14well 60'"@ surface feet 18. Approximate spud date 11/04/84 2709 psig@__80° F Surface 3110 psig@_.6_0_~b2~ft. TD (TVD) SIZE Hole Casing Weight 24" I 16" 62.5# i2-1/4"/ 9-5/8" 36.0# 8-1/2" / 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 ~ We1 d J-55 HF-:RW BTC J-55 HF- -.'RW BTC - SETTING DEPTH Length MD TOP 80' 35' I 35' 3673' 35' I 35' 1 l 34' I t 34' 8389' TVD M D BOTTOM TV D 115' I 115' 3708' 3002' 8423' I 6177' I QUANTITY OF CEMENT (include stage data) ± 200 cf 850 sx Cold Set III & 600 sx Cold Set II 350 sx C]ass G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8423'MD (6177' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2709 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2,000 psi prior to releasing the dril~l~g rig. Non-freezing fluids.~ will be left in uncemented annuli through the permafrost interval. 2X-13 will be ~ away from 2X-14 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) 23. I hereby~at the foregoing is true and correct to the best of my knowledge SIGNED '___/~/~~ ~_,~/.~' TITLE Area Drilling Engineer DATE ~7//~/~~/ ~ee ~ ~e[-p~vv:;f orC,~(fm m~si~'o ~- 6~e '' / Samples required []YES Permit number APPROVED BY Form 10-401 Rev. 7-1-80 CONDITIONS OF APPROVAL Mud log required I--lYES ...~ 0 Directional Survey required I APl number .~YES E._qNO I 50-~L~"~' i[~7 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSI ON ER by order of the Commission DATE September 21_ · Submit in triplicate Permit to Drill 2X-13 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-$5, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED SE¢~ 1. 7 !~ Alaska Oil & Gas Cons. Cemmission · . ............ ALASKA... .............. PAD: IX; .-.WELL;. 0~" 15;..'- 'NORT ''t'~- ~ .......... ~ ..... ::,2," i'":".'- .......... !:'::-::': :..::"t ......... .... i r=' , . ;. . ~ , . } · . , ~ ;, . ; ........ TOP R 'SNDS ' ·. t D£P::~7'$3-.: !. DEP=.,I,8$1 ~ . ! · · TVD-$902 )=8015 DEP=$OOS,, KUP:SNDS..TVD=60, 'T~D=8225 DEP-.5158[' ...I. -(LOGO[NO PT)- I TVD-6177'TI'ID=8423 DEP=5306 + · ..i SLOPE, I .:., SURt ''1 :T AR~GE'T LOCATION,' I . ~ ?. 20" bell nipple. .. Surface Diver-.er S,vstem 1~"-2000 psi Tankco starting head. )ankco quick connect asSy. l(~" X 20" 2000 psi (~ouble stuOOed a~apter. 20" 2000 ps~ Urillin9 spool w/lO" siOe outlets. . lO" bell velvet, hy~raulicall7 actuated, ,/lO" lines to reserve pit. Valves to open auto~ticaily upon closure of annular preventer. 20" 2000 psi annular preventer. Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify ~hat bail valves have openec properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid ,lo~ to surface is Oetecte¢. If necessary, ~nualt? overrioe and close ball valve to up-ind diverter line. Do not shut in ~ll under any circ~stmnces. ConOuctor A~NUL.,M~ ' _) PiPE BLIkiD R~ ~ !3-518" BOOD PSi RSRR~ BOP STACK ,, 11' - 3000 psi x 13-5/8' - 5000 psi s~cer 4. 15-5/8" - 5DOD psi x 13-5/B" - 5000 psi Oriiiinc 5. !3-5/B' - 5000 psi pipe rams 6. 15-5/B" - 5000 psi Orilling spool w/choKe an: kill linms · !3-5/B" - 5DOD ~si pipe rams !3-5/~' - 5000 psi blinO rams !5-5/8' - 5000 psi annular ACCUMULATOR CAP~CIT'Y TEST !. CHECK AND FiLL A~CUMULATOR RESERVOIR TD PRD~E~ LEVEL WITH, HYDRAULIC FLUID. 2, ~SURE THA~ ACCUMULATOR PRESSURE IS 3000 PS] W~Tt~ 1500 PS] DOWRSTR~ OF ~E E~ULATOE. 2. OBSERVE TIER, ~EN ~ZOSE ALL'UN~T5 SIMULTANEOUSLY AND RECD~ TEE TIME AND PRE, SURE RE~N)N6 A~ER ~L UNITS ARE CLOSED Wl~ C~RG)NG P~P OF~. 4. RECORD ON N~C REPORT. THE ACCEPTABLE LDWE~ LiK? !S aS SECONDS OLDS]NB TIME AND 1200 PS] R~!N]NG PR~SURE. '~'~ 5lB" BOP STACK TE.~T .- !. FILL BOP STACK AND I'Y~]FOLD WiTH ARCTIC D!~SEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULL~ RET'n~CT- ED. PR~DL'TE~M]NE DEPT~ T~AT T~ZST PLUG WILL AND S~ 1N WELLM~. RUN iN LOCK DOWN SCREWS, ~]NUTES. 5. INCREASE PRE,SURE TO iBOD PSI ~D HOLE FOR 6. OPEN ANNULAR PREYENTE~ AND CLOSE TOP S~ OF 7. INCENSE PRESSURE TO 3000 PS; AND MOLD FOR ~. ~~'P~SS~ m~~M 0F ~ I~TION V~S. TO ZERO PSi TO TEST VALVES. TBS7 RE~I~ING UKTEST~D ~N~FDLD,YkLVES', IF wlT~ 3DOD PSi UPSTREKK OF VALVE AND ZERO DO~NSTRE~,..BLEED SYST~, TO ZERO PSl. ..~OPEN TOP S~ DF PiPE ~S AND CLOSE ~O~O~ .~c ~ OF PIPE Rk~S. lO. INCR,[ PK..SUE. TO 3DOD PSI AND HOLD FOR H]NUTES BL[~ 70 ZERO P5i. i1. OPEN BO~O~ S~ OF P~PE ~. BACK OFF RUNN1NG JOINI AND PULL OUT OF HOLE. CLOSE BLIND ~S AND TEST TO 3000 PSi FOR t0 KINUTES. BLEED TO ZERO PSi. i2. OPEN BLIND ~ ~D RECDVE~ TEST PLUG. V~KE SUEE ~N]FOLD AND LINES ARE FULL OK ARCTIC C':~SEL AND ALL VALVES ARE S~ iN DRILLING POSZTION. 1~. TEST STANDP]PE VALVES TO 3000 PSi. i4. TEST KELLY CDC~ AND INSIDE BOY TO 3ODD YS~ KO.BY PUMP. . P ...... :~ 15 RECORD TEST ]NFORMAT!DN ON BLOWOb~ FDR~ SIGN AND SEND Tg DRiLL]NB SUPERVISOR. SEP I 7 ~ Alaska Oil & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee ~z;-~ ~ -f ~/7 (3) mdmin ~'~-/ ~ ~/~ '(~thru 11) '(10 and 11) . (12 thru 20) (21 thru 24) (6) Add: 10. 11. YES NO 1. Is the permit fee attached .......................................... / 2 Is well to be.located n a e ine poo ............................ 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells .................... -,_~__ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... ~_ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait.. ......................... -{~___ · Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. REMARKS Is conductor string provided ...................................... ~ Is enough cement used to circulate on conductor and s~rface . .. Will cement tie in surface and intermediate or produCtion st'rings .... ~j~ Will cement cover all known productive horizons ............ ' ..... ~ Will surface casing protect fresh water zones ................. Will all casing give adequate safety in collapse, tension and burst . ~ Is this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ pa ~--~ Is adequate well bore se ration proposed .......................... __ Is a diverter system required ...... , ............................ Are'necessary diagrams of diverter and BOP equipment attac~ed i i. .Does.BOPE have sufficient pressUre rating - Test to ~D~ psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. , AdditiOnal Remarks: Geolpgy: Engi_n, ee~rin~: WVA~JKT ~HJH JAL ~_~MTM ,,-' ' rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. , D~RECT D~O~TAL LOGGING COMPU TER PROCESSED RECEIYED .F E B 2 6 1987 ~ Oil & Gas Cons. Commission ANALYS~$ ARCO ALASKA IHC, I.,J ,=_. 1 1 '-" ':'.' · .-,,- 1 3 Fiel,d KUF'ARUK C o u n t. ~ NORTH oLOP~ Stat.¢ ALASKA Cour~trp USA F: L I E N T FORMAT DATA TAPE LOG I NFORMAT I ON FORMAT ( L , I S T AN DA RD RE£EIYEI) FEB 2 6 1987' AnCor'41e Wel 1 No,: Depth'_--.: ARCO 2W:-13 3694, O0 to 8453, Name: 2>(-13 F i m 1 d: f:.'.UPARL~( L I I I =%11 TAPE RECORDS Date; 1:3 NO\,', ,~_ 1984 Time; 11;47 a['l TUE, Page: 1 FEB 2 6 1B87 AWs~ O;t & C~m ConS. Comm~ssWn Smrvi,-e name: P~:GSFOi PRE:',..' i OLI$ i-'c__c_ 1 ; HEADER il~. RECORD.=, Date: 847ii,,:13 Origin: name P a '-3 e ~ 282004 Cont. inuation #: 01 -,: :-~: * * T A P E H E A D E R * * * * Ser',..'i,-e name: &GSFO1 Previous tape: Date: 84/'i 1/13 Origin: CoffilTlent ~ I Tape 282 004 Continuation #: O1 ,-:*** FiLE HEADER ;. :~; ~: :+: :~- 4: :~. :+: :+: :+: :~: :~ :~ :~ :~ :~ ~+: :~ FiI~' r,.~me: ~GSFO Maximum length: 1 024 HEADER RECORDS Set';,'ic~- nam~ I Fi 1 ~_ 'typ~.; LO Previou~ 'Fil~: P~g~ M N E f,1 C: N I.,.i N F N L-: 0 U N :--;TAT L-: T R "r' '.:;l-UT T FJ W N ~ KB rL) P E G L PD LhiF D H F L F: C: -_, u, ~ L U N FL L U L ENC I W i T N D D £~ L TLI BLI TCS TLAB BHT H R T M T t'i S S M V I S R H RHF M F S T MFSS RHC f'i C S T i'ICSS I NFORMAT i lIN RECORDS C 0 N T E N T S UN I T ARCO ALASKA --, w- 13 K U P A R U K NORTH SLOPE ALASKA USA 04 11N 09E 1i2,000 i i 1,000 ? 2,000, SL ..... KB, ..... J i I I I I i 282004 7611 NORTH SLOPE NORTH SLuM~ HUPP TENGBERG I N C, ii I i I ! I | I ii i i I I il I i~ i i i I I I I ; I I ! I I I i I , I I I I , I I · l 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 J I i ~ I r I I ; I I I I J i i I , i i ~ I ~ I I I i I I , i I ; , , i iIIII I ii,Il iliII ii&l illI iiiI iliiiiIlI IlIilllll liIilIII iillllll IiilIIiI IlIIllll iIliiItl lllllIII IiIliIiI IIIlIlll ilill Illii IillI IlllI IIIII 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 I II I II 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 t 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 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 ,..,.J c, ~ 000 ................................................ :~54S 00 (I ................................................ ..I I '~..,,.,i I ~ :2.540 000,, 13.30 000,, i925 000,, 13'8 OhO, i38,000,,, BEL FLOWL I NE ~2, 000 ...... i ,860 ....... 2,i60 ....... ?i ,200 ...... HE ~ S, 2,0~0 ....... 77,200 ...... HEHS, IlillllIIIlll:lllllllIlllllIIlllllllIlllllllI IlllIlllllIIlIllIIillIIllIIlIIlIllllIIlIlIIII IllIlllIIllIllllIlllllllIIllllllIlIlIIIlliilI IlllIlIllIIIIlIlllIIllllIIlIIllIIIIIIIll~IIII IlIlIIIIllIIlillIIilIlIIllllIIIlIIIlIIlllIlll iiIIllllllllllllllillIlIIlllllllllllIIIIltllll 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 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 ,illllIlIIll IIlIZIlIIIll IlIIII I I I ' T Y PE C A T G SIZE 0 iD 40 65 0 iD 40 65 O 0 4- ill 65 0 O 2 ili 65 0 0 ,=.'~ 0 65 0 0 '20 65 0 0 '2 E, 5 0 0 3 6 5 0 0 .3 6 5 F T ".! 3 ~ 6 8 F T 0 .3':, 4 68 Fl' 0 .S 4. 68 O .3 ',2 65 O ? '-' 65 0 S '" 6 5 0 0 2 79 0 0 2 79 0 iD 1 0 6 5 0 0 i 0 6.5 0 0 2 0 6 5 0 0 2 0 6 5 O 0 .-"~ 0 65 0 0 ',20 65 FT O 3 4 68 F T 0 S 4 ,S 8 F T 0 .3 4 68 F T 0 .3 4 ,S 8 H R 0 :-" 4 68 H R 0 4 4 · 68 DEGF 0 i 4 0 '" 2 n 65 0 2 2 0 65 C P 0 2 4 6 8 0 H Fi H O '2 4 6 8 0 H M H n. ,="', ~ 6 ~ DEdF 0 2 4 68 O '-' 12 65 0 H t'J fi iD '2 4 ,S F-: DEGF 0 2 4 68 O '2 i ',2 65 Psg6 COMMENT RECORDS This LIS tapm was wribtmn by G~_.s~-hart Industt-i~_s Wirmlinm Smrvic~_s, All curvm and tool mnmmonics used arm thosm which most closely mint. ch ~+~ G~zarhart curv~ .~nd tool mnemonics, GEARHART TO SCHLUMBERRER MNEM SERVICE UNiT MNEt'l SERVICE UNIT DEPTH FEET DEPT FT T E H M C P bl V T E N $ M V S P I"1 C P M V S P H V GR MCP GAPI GR GAP I XCAL MCP I H CALI IH YCAL MCP IN CAL2 I H ILD MCP. OHMM ILO OHMM i LM HCP OHMM I LM OH f'IM LLS f,ICP OHf,IH LLSU OHHM CILD MCP HHHO CILD MHHO P .~g 6: ._5 DATA E I--.I T R '.r' ~]IlilllIll~illlllIllllIllIllIiiliI TYPE DESCRIPTION 0 Terminator ( no mor~ ~ntr-im~ ) FORMA T SPEC 1 F I CA TYPE SIZE CODE 0 I 66 T IONS /1~- g~A J~UA ~ SERVICE SERVI MNEH I D ORDER DEPT T E I...'S :5 I~ C:AL ~ r: ~ L 2 iLD i Lr'l LL',3U C i LD DATA F 0 R Pi A T ATiOH BLOCKS **** ~ :~ :~ :+: :~ :+: :+: :+: :+: :4. :+: :+: :'l': :4': :+: :+: · :+: SPEC I F i PAT i OH'.='_, CE AP I AP I # UHIT LOG TYPE AP1 APl'FILE CLASS MOD -,o-~004 FT n 0 n n 2.°_.2 004- M,V 0 ~:~ 0 0 2820 04 My o i i'j Fj · y u., FI I.'l 4 iS A P l Ii .~ 1 Fi Ii ...':~:--' 004i N 0 28 0 O · -, o 2 F~ F~ 4 i iq ~] I] :] Ii ~. ~=m . . . . - = · -' ':' '" 0 0 4 0 H M M F~ i.-'; ~ 6 F~ 282004 OHMM 0 i2 44 0 --~ ,- -5 . .. ,.. · - :.d ,. ii 0 4 0 H [rd t'i 0 '-' '-' 8 O 2'82 004 t'tHHO 0 68 46. 0 P RiD SIZE LVL SMPL RC 0 4 0 i 68 0 4 0 i 68 0 4 0 i 68 O 4 O i 68 0 4 0 i 68 0 4 0 i 68 0 4 0 i 68 O 4 0 i 68 0 4 0 I 68 0 4 O i 68 PROCESS IND.iiSATORS 000000 000000 000000 000000 000000 L'IOt.'IOi'JO O0001]lO OI]ll'JOOI] 000000 000000 000000 O00FJO0 O00UUU 000000 O0000n 000000 000000 000000 O00uuu FlO0000 no0000 OHO000 0ii0000 000000 i'jO0000 000000 00 Oi.'l 00 000000 O00i'iO0 Dh_PT LLSU T E N :3 C I LD [:,A TA RECORD'-' , CALl CAL2 ILD I LM 7460.000 .4,624 736. 0, 000 7,55i 726~-J, 000 6. 067 7 i 60, 000 4,i21 706 O, 000 5, 023 696 n, 000 4,977 6860, 000 5, 070 6760, 000 5.i29 6660.000 3,342 6560, 000 3. 758 6460 ."5 6360, 0 n 0 3'3,63'9 E'-~" ii i'l 00 ~ 664 18, 000 · i 000, 000 1,000 i93,642 -4. rj 00 i 93. 197 2. 00 0 443,609 -11.000 254,6~d 0, 000 258, 8°,:. 1 O, 000 261 ,818 2, 000 246,604 -8. 000 615,1,', 2, 000 40.3,645 - 8. 000 343,558 - 15, V U U 394,4~. 0, 000 747 53:.6 52 5'9 75 64 70 6'2 67 65 64 66 65 000 900 000 :300 900 900 200 900 i 00 600 900 200 :300 O. 000 94, '200 88,500 109,600 1 1 0, I 0 0 1 0i . 800 i22 400 137~ °00 i24 800 i60 800 i i 5 400 °0 000 90 200 0,000 2,680 9.400 9,430 9 , 9 70 10,610 i0,690 9. 930 9. 000 9 370 9,:3'20 9,690 9, S 50 iO 0 000 550 :300 990 190 580 140 620 740 950 i '20 440 1 000 5 164 5 i76 2 254 3 926 3:364 3 8i9 4 055 i 6'26 '2 477 '2 9 i i '-,' 535 2 877 i 0 0 0 b 5 495 ':' 4 227 4 295 4 0.36 4 457 1 8i6 2 636 .S 14:3 · _', 0 E ;' [:,EP T LLSU 6060, 000 4, i50 5:360, 00 0 3,350 .. r~O 000 -'- 24.3 5660, 00 O ~' 243 5560, 000 5460,000 5760.. . 000 ? :';, '26 I'1 , tJ 00 _'3., 444 5i60, IJIJU .3,251 5060, 000 3,664 4. 9 60,00 0 '~' 6'a8 DATA TENS C I L D S F' G R RE CORDS -:-3, 000 30i ,30i 600 92 900 9,260 O, 000 62 200 :34 000 9..370 6, 000 331 ,895 60 50,9 i 07 800 9,i30 -:3, 000 346,737 8',3_, 200 dc.. 20fl 9,5i0 13, 000 369,828 i 05 400 1 O1 400 8.890 -._'3,0 i:, 0 380,189 115 600 97 400 9,840 - i 4, 0 ~:10 340,40:3 7,000 261,216 ii9 i24 200 800 i07 · 200 000 9,4'30 8,5.30 -3, 000 "~99 ,al 6 ,,- j . 132 200 87 900 280 il,000 3 04, 089 i 36 200 89 800 8,96 0 -5. 000 3 i 3,329 8,000 26.7,301 i 42 500 i 05 9,660 i 44 400 71 000 9. 780 -3,000 297, 167 146 buu 71 300 9,550 ,]AL I CAL2 8 920 8 980 760 9 0'20 8 460 9 1'20 9,270 8~370 8.5.50 8.590 9. 160 9,i80 '3.400 ILD I LM Page · 319 3 837 4 055 0i 3 3 25i 8.84 · ..s U b-5 704 8._'38 '2 7i6 2 938 3 097 4,i40 334 .'38i · 3. 420 i'32 3, '25i · 3,74 i 3,846 3, .365 · 3.631 DEPT LLSU T E N S C I L D DA TA RECORD':' · iI CALl CRL2 iLD I LM P ag,=- 486 0, 000 · _'., :399 4760, 00 O 3,412 466 0, 000 · 3, ,3 04 4560, 000 -~ 690 4460, 000 · 3, 0:33 4360, rio0 4,571 426 O. 000 ~ 698 4160. 000 .3,606 4060, 000 4, 055 3960, 00 O 4,477 3 8 E. 0, 000 6, .368 .'3_-. 760, 00 O 4,519 1 , f) O 0 245,471 ] 2, 000 287, 07:3 .3. O0 0 -5,000 ~.9i6 -5. 000 192,309 -i 4, O00 '"44 9 O'S -4, 000 264,850 -5, 000 '-'1A 272 -4,000 199,986 .3 0 Ii 0 127,.350 --~ , I'Jl'JO ! 52. 055 150 i49 i5i 150 1.52 i55 i57 i54 152 i 50 138 1.36 700 700 8 Iii 0 800 600 400 900 600 600 700 '20 0 '20 0 76 000 71 000 71 200 7' i 600 89 700 89 900 9i 400 82 900 81 ,500 76,i00 6 4 . 9 0 0 59,300 9,870 9,650 8,.31 0 9,290 9,870 9,3i0 9,740 8,99 0 9,610 9. 750 13,S70 i3 9 240 9 560 i 60 i 50 52O 630 0 '20 670 540 658 8i 0 09 0 4 074 · 3 483 420 ;3 :S.bb 3..34 5 200 4 08.3 ..3 776 4,624 5. UUU 7.852 6,577 4.3'35 3,556 3,475 3,98i 3,3i i 5,32i 4 i30 4,667 5, 012 7,889 6,7i,; FiLE TRAILER *. -'~. *.* Fli~- name: ~,GSFO1 , Maximum lengt, h: 1024 TRAILER RECORDS Version Fil~ t,.~pe:., LO Next ~"ile: [)ate: EOF *** name:: &G5FO1 , 002 i"laxirnum l~ngt, h: 1 024 HEADER RECORDS: Vet. zion ~: Fil~_ tppm: LO H hi E H C N i.d i..t F i-i C 0 U N STRT ,,.'-'TRY :_~- CT T 0 kl N RAHG '- L.; ~'~ b_ L) i- EGL -- - N D LHF · D i"1 F R U N LCC S A N ..... L UH FL .... L UL ENGI ...... D D E:, L TLI E:L i TC S TLA8 ~ H T H R T HT M S S H V I S F.: bi R H F' H F S T b1FSS RblC i"i C: S T P1L;~65 I NFORMAT I ON RECORDS iS 0 N T E N T S UNIT TYPE CRTG o I.SE CO£,E ARCO ALASKA INC:, 2X-13 i< i_I P A R U K NORTH SLOPE RLR'SKA USA IJ4 .............. lin ............. 09 E ............. i 12, 000 ......... i i i , O00 ......... ,-,-, Oi'ii'i .......... i i i i i i i i i I I i I il 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 I I t I I I I I I I I I I I : I I I J 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 i i i I i i I · i i |:lllIiIiliilIllliI iIiiiiiIilililliIii iiIllililllilIillil iiIiiIilIlaiiIiiIii IilIIilllIlIllllIiI i i : I i IilIliiIIl iIiIlii ii IIiilii iiIIilI ! i i I I I I i : II IlII '.:_:L , , , 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 KB ........................... KB ........................... .SO ~_'-,o20 O~ ,., ..................... ?6ii ................... NORTH :SLOPE ......... NORTH SLOPE ................................ HUPP ............................... TEHRBERC~ .................................. ~ , ~.=,39 000 ............... 85~ O00 ................................ · _' J -~ ~J 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 8540 000 ............................. i .z, 30000 ................. , , i925 000 .................. i 38, 000 ............. ' .... ~ , i38, 000 ................... iSEL ...... FLOWL [ NE ...... 4'~ OdO ................................ i ,868 ............................... ~, I 60 ............................... ,'1 ,200 ......................................... HERS ................... ' ................. 2, 040 .......................................... 7,' ,~00 ......................................... biERS .................................... 0 Ci I'J I'j I) I'j 0 0 0 0 0 0 0 0 0 F T 0 7, FT 0 FT 0 S 0 S 0 0 0 0 0 0 0 0 0 0 0 ri 0 0 0 0 0 FT 0 .S F T 0 3 FT 0 3 FT O H R 0 '2 HR 0 4 DEGF' 0 i Dbtsi- 0 1 0 C: P 0 .-'"' 0 H bl t,i 0 2 0 H i'.i i'.1 0 2 DEGF 0 '2 OHHH 0 2 D E G F 0 ,.':' 0 '2 40 65 4 0 65 40 65 ]--' 1.i ~, 2 0 65 20 65 2 65 ..:, 6 b ~ ~5 4 E, ':,,,.. 4 :S 8 .-'-' 65 2 65 2 65 12,. · 5 7 9 i 0 65 i0 65 · 20 65 2 0 65 20 65 '-' 0 65 .. 4 68 4 68 4 68 4 *_'.8 4 68 4 *_'.8 4 68 orj 65 .. 20 65 4 68 4. 6,8 4 6 A 4 68 i P 65 4 68 4 68 i '2 65 .i3 C 0 M M tS H T REC:ORI},=, Thi~ LIS taF.,~ was written bp Gmat-hart Industr-im-.s I.,Jir~zlin~ S~',~ic~ All curvm and tool mnmmonics usmd arm thos~ which moss. closmlu match ~]marhart curvm and tool mnmmonics. GEARHART TO SCHLUMBERGER MNEM SERV I CE UNIT MNEH SERVICE UNIT DEPTH FEET DEPT FT T E N 1 M C P M V T E N S M V S P 1 I'1 C P M V S P M V GR 1 f'ICP GAP 'i GR GAP I 'Z, C A L 1 MCP I N CALI I N "r'C AL 1 MCP I ['1 CAL2 I N I L D 1 M C P 0 H f'l M I L D 0 H Id M I L M I M C P 0 H f'l f'l I L H 0 H M L L 3 1 t'l C P 0 H M M L L 8 U 0 H M H FCDL 1 MCP CPS FFDL CPS HCDL 1 blCP CPS NFDC CPS RHOB 1 MCP G/C3 RHOB G/CS DRHO 1 MCP C./C~ DRHO GTCS CHc' 1 MCP ;"; LIME NPHI PU F C ~'~ S: 1 f'l C P C P S F C N L C P S 1'4 C: N S 1 f'l C P C PS N C N L C P S C: I L D 1 M C: P I"1 f'! H 0 C i L D M t"l H O '-',. t'~ b .¢ 1I"1 C P ~'~ 'o ~ H D N P H ~ P i_I DATA ENTRY ~tl:lllllll~l;llllllZllltlllllillll. FORMA T SPEC I F l CA TYPE SIZE CODE 0 1 66 TI ON'-'.z, 15 ~:~::+:*- ENTRY BLOF:K LEGEND .: t: :*: :4': ;~ :~- ~: :~. :~. W. ur: ~. :+: :t< ~. :~¢ ~: ~. ~: ~. :~ >~: :~ ~: ~,: ~: :~ :+: >f: >~: TYPE DESCRIPTION 0 Terminat,sc ( no mop~_ ~-rltt-i~s ) DATA FORMAT SERVICE SERVICE AP1 APl AP1 APl FILE ..,L R.:.,., MOD r.iNEH ID ORDER ~: Jji-,lI T LOG TYPE P: "'"c' DEPT TEHS 5 I-' CRLI CAL9 iLD I LM LLSU FFDL i'-I F D C RHOB DRHO NPH I F C N L N C N L C i L D NPH I NPH i RAT DPHI 2:32004 F'T n 0 0 0 0 · '-, ,:, .", n 0 4 t'l V 0 0 0 n 1 ~... ,.., ..". _ 2:92 004 MV 0 i 0 0 ", ':~ '-, A 04 G R P I n .'3_-. t ri n 1 ,--.. -- 0 0 2 d ~ r~ A 4i N 0 2:7¢ 2 0 Ij 4 i N O 2:32004 OHHH 0 aAafl04 AHMM Ii i2' 44 Fi 1 2:3'2 004 0 H t'i M 0 22 8 0 i .-'"82 004 j]pc._ ._, 0 ri. r~. A_ i .-% - .-. :~ ,:. 00.4 C P S 0 0 0 0 i OR2 Ii fl4 G/'F:._'F.. 2:32004 G/C.'3 0 39 m) 0 i v ~ ~ fl 04 P U 282004 CPS 0 0 2:32004 CPS ':28'2004 MMHO 0 68 46 0 2:320C'4 PU 0 68 3 0 i '282004 PU 0 68 28:2004 0 0 0 0 SPEC I F I P. Ai' I P R C SIZE LVL SMPL 68 68 68 68 68 68 68 A a -- o 68 68 6 ."3_' 68 ~ A 68 6:3 6:3 68 68 P R 0 C: E S S IJ IJ U U IJ U 0000 00 0 00 0 00 0 0 00 0 0 0 0 rj 0 0 0 0 0 0 0 0 0 U U U ti U ij 0000 0 0 000 ii 00 0000 0 ri U U U U U U FI I} I'j i:i i:i Fi U U U U U U t'i I] I:1 I'! I'1 t't 0 0 00 00 000000 Cl 00000 0 0 r: 0 0 A 0 O O 000 000 000 000000 I ND i CATORF: 000000 000000 000000 000000 000000 001]000 l'jl:iO O0 0 I'lOt'JO 01] 0001]00 I]li]ll]i'll]O 0 I'1 0 I]1 0 0 i'j Cl I.]i fJ I]1 I:i UUUUUU IJUUUUI.I I:1 i]l 0 I'i 1210 i:i i'J i:l n I:t UUUULIU IJUUUUU i_] i'1 0 t'j i'! l'j 0 i'j n 0 i'_t L'l 000000 000000 00riorjo 000000 000000 000000 I.'1 l'J I.'1 I"1 0 0 0 0 I)I'j 0 O0000L] O(iO000 000000 000000 000OO0 000000 O0000O 000000 UUUUUU UUUUUU Firiorjo0 000000 000000 000000 L) I- I'-' I L L :3 U C i LD T E t,i S FFDL NP H i S P N F D C' NHH 1 DA GR RH08 RAT TA RECORDS CALl DRHO [)PHi CAL2 NPHi iLC, FCNL i LM N C N L 8453, 000 i ._]-., 062 1 000, 000 8353, 000 c, '-, n 4 i 66 34 i ! .' 8253. 000 48,4 i 7 33.574 - F, ,.00 u 1 ._ 3 d 6,998 i90, i 08 47'-' 06 1 /~b.5, 00,] 3 , 837 s 70, 164 7, ,_,=,_3 ._..3, i]_ I]_ d. 7.. 87 ._'3. 47~,335 775.3, 000 4', 487' 363. 078 7653, t'~ F~ ri 4,875 42'2, e,e.~ 7553, ~-~ 0 Cf 5,559 269. i 53 1 0, 000 i'j , 000 4, 0 i'i 0 12, 000 49.3, E, 00 44,840 - i , 000 543,300 40,560 -5, 000 487, i 00 4i ,OiO 14. t) 00 42'2,300 42,220 - 7 , 000 4 i 6,6 ri ij 56,9 i 0 - eS 6, 000 404. 000 54,8 :--: 0 o 0 I] 0 4 n 5,700 57, 040 2, O00 337. 1 O0 5i , 120 4 i 1 , 900 53, i 9 0 0 , !) 0 0 0 , fJ 0 0 -1 ,663 45,700 6'24,900 .S 9, S .37 i 7, i 00 627,200 34, ._'3-. 5 ,'! 33.60 rj 638.500 34.865 ! ,600 6 i 0,900 36,254 37,500 5,1..3. 1 00 55, 186 50=, , 700 5 "" 3 n-' '-'0 i dO 505,200 55.374 I 6, i-ii'iLl 4:::6,500 4?' '"i .s i 4,400 ~4 70n 49. 981 0, 000 0, 0 I:~ 0 _,:~ --:,.~ ii 72, .300 '2,369 i .3i2 74,000 2,37.3 i ,245 45,8 00 2. 459 i, 283 i i 6,800 '-' 36i] i ·53.3 100,700 '~, ..', 53 i ,b35 99,700 '-' -324 ~ J i °09 .~hn 2.502 i .439 i 4 'i . 50 0 '-' 38 Ii i ,447 O, 000 O.OOO i 60,606 7,490 i7, 0.30 7,460 .i77 22,303 7,3i0 ,i98 i6,788 7,240 · i 95 11 . 576 7,230 , i05 i 7,576 8,760 ,070 i 8, 000 ii ,200 · 054 19.758 8,710 , 075 8,970 9,000 , 102 i6,364 0, O00 0,000 6,840 4 Fi o4ft . j ,_1 6,830 36.56 ii 6, ?50 37.0i0 6,7i 0 '-' 9 1 0 · - i 8, i70 50,880 9,630 5.3, 040 7 , 760 47. i20 :3, i 90 4 9, i 90 i , 0 0 0 0, 0 0 0 6. 0i2 i 5,3,200 29. 785 '200,900 5,2 60 i69,400 5° 'gi4 182,300 i . 754 t 0 3 , 7 0 0 "~ i ii 4 i 00.4 rj 0 2.754 110,100 '~ X66 i26.200 3.7i5 i20,600 1 Ij r, ¢1 0.000 i 97, 0 l:l 0 ~6 3 nR '-' "t g :30 I] 5,834 2 i 0, 'B 00 '2, 023 i59, 000 · - . 4, 07 i54, i O0 I 74,200 · -'-' , 944 i :3 i . 600 4, 064 i 74,500 DEPT LLSiJ ,.,'-' i LD T E N S FFDL NPH [ :-]: F' NFD'-' I".t P' H 1 DA GR RH08 RAT TA REPIDRD© iI ~I CALl DRHO DPHi CAL2 NPHI ILD F C: N L I LH hi C N L 7453, 0 0 0 23.- 1 , 740 0, 0 0 0 45, 100 53, 0 rj 0 499,200 39,649 106, i 00 '2,5:36 i , .373 9,930 092 .0.79 8,5t 0 4i , 1 O0 4,315 i 46, '200 200,800 Fiie name: ~G.SFOl , 00:'-"' i:taximum length: 1024 TRA i LER R E C: 0 R D S Date:
