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185-039
185-039 T38892 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.11 15:17:22 -08'00' • • a) ON N n (y °ai r..� v -� 0 c /1 Q" N (J N Z to T (D (7 if) (� W ro `H -0 (0 J-.m u O +C+ E j 1 i 0 O Y (° rn Q c ° Y CU C IP O� a) C T Y (o +' (o .0 +' -d N▪ C -E a (D 0 T Q Q 2-. n n n n n n n -111 n N CU c Q" 0- CO G Q N Y a) Ou o N �1,, it<LE91: aaaaao. o. asE -c -oCD La ) a) a) a) a) a) Na _CLO NC IL Nfn iii— fA (nfn !nN LSSV1 N M (f) (0 n CO W 00 (0 Y CG Z NNNNNNNU 0 (0 0 --' NU vo c Lu C1- 0NU 0 toC — QOWW WWWWWN a) CU LL LL LL LL LL LL LL _ III -a Q Q J J J J J J J J J — > +-' 4 CC F' Q Q Q Q Q Q Q Q Q a) N C ,a- v= [ Q U (o a) O C G' +, Z Z Z Z Z Z Z Z Z a r a) N �: LL LL LL LL LL LL LL LL LL CC E > N _c 0 .B Oy E a) u r z N 0_ _ u > U r O C O co > Cf- @ a) u C ce c Q a) a a C 0a V A Lt. W LL LL LL NN F y J U maaoN -b 0Z a O , = E....( /o U (y co ::; W WI U ‘ v W p > 0 « - • d . a5 is z R! oo d ° 113 W OdaR. 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Q o N W N N N N M N N N Z hrts - ' .-/ CC13 in ._ V) .-1 f6 C QJ ra STATE OF ALASKA • ALIC OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations E Fracture Stimulate rPull Tubing F Operations Shutdown Performed: Suspend E Perforate 1- Other Stimulate E Alter Casing F Change Approved Program E Plug for Redrill W,, Perforate New Pool n Repair Well F Re-enter Susp Well E Other:Stacked Packer F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory fl 185-039 3.Address: 6.API Number: Stratigraphic j— Service n P. O. Box 100360,Anchorage,Alaska 99510 50-029-21302-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25643 KRU 2U-10 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 7100 feet Plugs(measured) None true vertical 6118 feet Junk(measured) None Effective Depth measured 7074 feet Packer(measured) 5092, 6354,6477,6638 true vertical 6102 feet (true vertical) 4809, 5636, 5717,5824 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 115 115 SURFACE 2957 9 5/8 2994 2993 PRODUCTION 7040 7 7074 6102 ED Perforation depth: Measured depth: 6572-6609, 6724-6784,6828-6832,6838-6842,6868-6872 True Vertical Depth: 5780 5805, 5882 5920, 5949-5951, 5955 5957, 5974 5976 RECEI V Tubing(size,grade,MD,and ND) 3.5, L-80,6661 MD, 5839 TVD NOV 2 2 2016 ��yy Packers&SSSV(type,MD,and ND) PACKER= BAKER FHL RETRIEVABLE PACKER @ 5092 MD and 4809 TVD O PACKER= BAKER FHL PACKER @ 6354 MD and 5636 TVD PACKER= BAKER FHL RETRIEVABLE PACKER @ 6477 MD and 5717 ND PACKER= BAKER FB2 PERMANENT PACKER a 6638 MD and 5824 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE ' fi tit DE .A, 'i Treatment descriptions including volumes used and final pressure: Ati • 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In 0 0 0 0 Subsequent to operation Shut-In 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory Development F Service 1 Stratigraphic E Copies of Logs and Surveys Run E 16.Well Status after work: Oil F Gas E WDSPL E Printed and Electronic Fracture Stimulation Data E GSTOR ra WINJ E WAG I- GINJ E SUSP E SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-488 Contact Andrew Beat 265-6341 Email Andrew.T.Beat(cr�,conocophillips.com Printed Name A w Beat Title Sr. Wells Engineer Signature Phone:263-4612 Date tyoza, I Form 10-404 Revised 5/2015 VT 1- 312 1 iSubmit Original Only • Operations Summary (with Timelog Depths) '#,e s 2U-10 fip i 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(ftKB) 10/20/2016 10/20/2016 1.25 MIRU MOVE MOB P Blow down water and steam, 0.0 0.0 03:00 04:15 dissconnect water steam air,unplug electrical lines,Simops jack up pipe sheds and rock washer, Pull away from rig spot out of the way 10/20/2016 10/20/2016 0.75 MIRU MOVE MOB P Pull Complexes away from sub and 0.0 0.0 04:15 05:00 Spot on Pad 10/20/2016 10/20/2016 0.50 MIRU MOVE MOB P Prep prep sub to move 0.0 0.0 05:00 05:30 10/20/2016 10/20/2016 0.50 MIRU MOVE MOB P Pull sub off of well and position f/ 0.0 0.0 05:30 06:00 move off pad 10/20/2016 10/20/2016 1.75 MIRU MOVE MOB P Crane gas buster house onto pits 0.0 0.0 06:00 07:45 10/20/2016 10/20/2016 2.75 MIRU MOVE MOB P Move Rig f/1G pad 1/2U pad 0.0 0.0 07:45 10:30 10/20/2016 10/20/2016 1.25 MIRU MOVE MOB P Position sub to pull on well 0.0 0.0 10:30 11:45 10/20/2016 10/20/2016 1.00 MIRU MOVE MOB P Spot sub over well 0.0 0.0 11:45 12:45 10/20/2016 10/20/2016 3.50 MIRU MOVE MOB P Spot modules and rock washer pipe 0.0 0.0 12:45 16:15 shed 10/20/2016 10/20/2016 1.75 MIRU MOVE MOB P Hook up interconnects and work on rig 0.0 0.0 16:15 18:00 acceptance check list Rig Accepted @ 1800 hrs 10/20/2016 10/20/2016 1.00 MIRU WELLPR RURD P R/U to kill well 0.0 0.0 18:00 19:00 10/20/2016 10/20/2016 1.00 MIRU WELLPR MPSP P Pull BPV as per Cameron rep 0.0 0.0 19:00 20:00 10/20/2016 10/20/2016 1.75 MIRU WELCTL KLWL P PT lines t/3500 psi,Kill well w/8.8 0.0 0.0 20:00 21:45 ppg brine 220 bbls pumped @ 3 bpm 340 fcp 10/20/2016 10/20/2016 0.50 MIRU WELCTL OWFF P Observe well for flow,well static f/30 0.0 0.0 21:45 22:15 min 10/20/2016 10/20/2016 1.25 MIRU WHDBOP NUND P R/D Circ Equipment,N/U tree and 0.0 0.0 22:15 23:30 adaptor flange 10/20/2016 10/21/2016 0.50 MIRU WHDBOP MPSP P Prep tree and Install blanking plug into 0.0 0.0 23:30 00:00 hanger 10/21/2016 10/21/2016 2.50 MIRU WHDBOP NUND P N/U BOP and Adaptor Flange, 0.0 0.0 00:00 02:30 10/21/2016 10/21/2016 1.50 MIRU WHDBOP RURD P Welder Adding 2"to Riser,Simops- 0.0 0.0 02:30 04:00 Hook up lines to tiger tank bleed off 50 psi that built up,leave valve open monitor for returns static,Blow down lines 10/21/2016 10/21/2016 1.00 MIRU WHDBOP RURD P R/U t/test BOPE 0.0 0.0 04:00 05:00 10/21/2016 10/21/2016 3.00 MIRU 'WHDBOP WAIT X Wait for state man U witness test 0.0 0.0 05:00 08:00 10/21/2016 10/21/2016 6.00 MIRU WHDBOP BOPE P Test BOPE w/3.5 and 4"test jt t/ 0.0 0.0 08:00 14:00 250/2500 f/5 min,State Inspector Johnnie Hill witnessed test,Test Choke valves 1-14,HCR and Man choke and Kill,Auto and Man IBOP, TIW and Dart,Upper Lower and Blind Rams,Annular and 4"Kill line demco, Koomey Draw Down 200 psi-32 sec Full Pressure-188 sec Test Gas alarms and PVT sensors Page 1/4 Report Printed: 10/27/2016 • • '.' '' < Operations Summary (with Timelog Depths) 0 2U-10 C onocc Phitiipgs 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 (MKS) End Depth MKS)10/21/2016 10/21/2016 0.50 MIRU WHDBOP RURD P R/D test equipment,B/D Lines 0.0 0.0 14:00 14:30 10/21/2016 10/21/2016 0.50 MIRU WHDBOP MPSP P Pull BPV as per Cameron Hand 0.0 0.0 14:30 15:00 10/21/2016 10/21/2016 0.75 MIRU RPCOMP RURD P M/U Landing jt to Hanger and top 0.0 6,340.0 15:00 15:45 drive,BOLDS pull hanger to floor hanger unseated @ 82k seals pulled free @ 115k 10/21/2016 10/21/2016 1.50 MIRU RPCOMP CIRC P Circ 1 bpm attempt to sting back into 6,340.0 6,340.0 15:45 17:15 PBR unable to get down,Clrc bottoms up 10 bpm 900 psi sand back on bottoms up,Pump 30bbl Hi Vis sweep around very little sand on bottoms up, attepmpt to sting in again made 1'no pump psi increase. 10/21/2016 10/21/2016 5.50 MIRU RPCOMP PULL P POOH L/D 3.5"Completion 191 jts,6 6,340.0 0.0 17:15 22:45 gas lifts,seal assy, Holes located on jt 182 out Corrosion on collar on jts 164-172 10/21/2016 10/22/2016 1.25 MIRU RPCOMP SEQP P Set Wear Ring,Clean and Clear floor 0.0 0.0 22:45 00:00 10/22/2016 10/22/2016 0.50 MIRU WELLPR BHAH P M/U BHA test packer 0.0 0.0 00:00 00:30 10/22/2016 10/22/2016 3.25 MIRU WELLPR TRIP P RIH w/test packer t/3160' 0.0 3,160.0 00:30 03:45 10/22/2016 10/22/2016 0.50 MIRU WELLPR PRTS P Set test packer and test casing to 3,160.0 3,160.0 03:45 04:15 2500 psi f/5 min, R/U and test below packer injecting at 1600 psi shut down blled off pressure 10/22/2016 10/22/2016 2.25 MIRU WELLPR TRIP P RIH f/3160't/5483' 3,160.0 5,483.0 04:15 06:30 10/22/2016 10/22/2016 3.50 MIRU WELLPR PRTS P Test casing @ 5483'bad test, P/U to 5,483.0 5,180.0 06:30 10:00 5375'test casing bad test,P/U to 5280'test casing bad test,P/U to 5188'test casing Bad test,P/U to 5028'test casing good test to 2500 psi f/5 min,RIH t/5123'test casing good, RIH t/5140'test casing good test,RIH t/5155'test casing good test,RIH t/ 5180'test casing bad test injecting© 1 bpm 1600 psi R/D test equipment 10/22/2016 10/22/2016 0.75 MIRU WELLPR TRIP P RIH f/5180't/5702' 5,180.0 5,702.0 10:00 10:45 10/22/2016 10/22/2016 0.50 MIRU WELLPR PRTS P Set test packer attempt t/test below 5,702.0 5,702.0 10:45 11:15 packer to 2500 psi injecting @ 1 bpm 1800 psi 10/22/2016 10/22/2016 0.75 MIRU WELLPR TRIP P RIH f/5702't/6317' 5,702.0 6,317.0 11:15 12:00 10/22/2016 10/22/2016 4.25 MIRU WELLPR CIRC P R/U and reverse circ 2 tubing volumes 6,317.0 6,344.0 12:00 16:15 2 bpm 110 psi,strip through bag t/ 6338'until returns were clean,Make connection wash down t/no go @ 6344'pressure spiked 500 psi confirm no go,reverse circulate clean 2 bpm 100 psi 10/22/2016 10/22/2016 0.75 MIRU WELLPR PRTS P Set test packer @ 6316'test down 6,344.0 6,316.0 16:15 17:00 string t/2500 psi f/10 min confirm plug and packer holding. 10/22/2016 10/22/2016 1.25 MIRU WELLPR TRIP P POOH L/D DP t/5100' 6,316.0 5,100.0 17:00 18:15 Page 2/4 Report Printed: 10/27/2016 • Operations Summary (with Timelog Depths) Fes . iry 2U-10 ConocoPhimps 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) 10/22/2016 10/22/2016 0.75 MIRU WELLPR PRTS P Set test packer @ 5100'Test casing 5,100.0 5,100.0 18:15 19:00 to 2500 psi f/10 min good test 10/22/2016 10/22/2016 3.25 MIRU WELLPR TRIP P POOH UD DP f/5100't/Sufrace 5,100.0 0.0 19:00 22:15 10/22/2016 10/22/2016 0.25 MIRU WELLPR BHAH P 'UD Test packer BHA and Mule Shoe 0.0 0.0 22:15 22:30 10/22/2016 10/22/2016 0.75 MIRU WELLPR SEQP P Remove wear ring,clean and clear 0.0 0.0 22:30 23:15 floor 10/22/2016 10/23/2016 0.75 MIRU RPCOMP RURD P R/U to run completion 0.0 0.0 23:15 00:00 10/23/2016 10/23/2016 6.00 COMPZN RPCOMP RCST P Continue to RIH w/3-1/2,9.3#,L-80m 144.0 6,335.0 00:00 06:00 EUE 8rd Gas Lift completion from 144 -ft to 6,335-ft. MU Torque=2,250 ft/lbs PU wt=80K,SOW=75K 10/23/2016 10/23/2016 1.50 COMPZN RPCOMP WASH P MU head pin on jt#197 and break 6,335.0 6,339.0 06:00 07:30 circulation @ 1 bpm @ 30 psi with 9% return flow. Wash down to 6,338-ft observe entry into the PBR w/ pressure increase to 120 psiwith no returns. Shutr down pump and continue to ease down to 6,339-ft with 10k slack off. PU and work pipe 10-ft in attempt to wash out the top of the PBR-No Luck. Decision made to POOH. 10/23/2016 10/23/2016 4.50 COMPZN RPCOMP TRIP T RD circulating equipment,POOH from 6,339.0 0.0 07:30 12:00 6,339-ft rack back to seal assembly. Laying down all jewelry and re- installing seal rings in tubing. 10/23/2016 10/23/2016 3.25 COMPZN RPCOMP BHAH T Set wear ring,PJSM,Bring tools up 0.0 0.0 12:00 15:15 the Beaver slide and MU cleanout BHA. RIH to 200-ft and square couplings hitting wear ring,POOH and Pull wear ring. 10/23/2016 10/23/2016 3.00 COMPZN RPCOMP TRIP T RIH w/Clean out Assy t/6329' 0.0 6,329.0 15:15 18:15 10/23/2016 10/23/2016 0.75 COMPZN RPCOMP WASH T Wash down @ 4 bpm 250 psi f/6329' 6,329.0 6,347.0 18:15 19:00 U 6347'set down pressure increase 500 psi P/U and circ 10/23/2016 10/23/2016 1.25 COMPZN RPCOMP CIRC T Circulate 30 bbl hi vis sweep around 8 6,347.0 6,340.0 19:00 20:15 bpm 900 psi Sand back on bottoms up,Spot Hi vis pill on bottom 60 bbls pill f/6344't/4915' 10/23/2016 10/23/2016 1.75 COMPZN RPCOMP TRIP T POOH f/6340'U 5100',Trip back to 6,340.0 6,347.0 20:15 22:00 6347'ensure no fill 10/23/2016 10/24/2016 2.00 COMPZN RPCOMP TRIP T POOH f/6347't/3246' 6,347.0 3,246.0 22:00 00:00 10/24/2016 10/24/2016 1.75 COMPZN RPCOMP TRIP T Continue POOH f/3246't/Surface 3,246.0 0.0 00:00 01:45 10/24/2016 10/24/2016 1.25 COMPZN RPCOMP BHAH T L/D BHA Clean Out Run,clean and 0.0 0.0 01:45 03:00 clear floor 10/24/2016 10/24/2016 4.75 COMPZN RPCOMP RCST T Run 3.5"Completion as per detail t/ 0.0 6,330.0 03:00 07:45 6338'Locate top of PBR,RIH U 6350' NoGo on locator P/U t/6330' 10/24/2016 10/24/2016 0.75 COMPZN RPCOMP CRIH P Spot 50 bbl Corrosion Inhibited Pill 6,330.0 6,330.0 07:45 08:30 Around Packer and seal Assy. Page 3/4 Report Printed: 10/27/2016 i 0 Operations Summary (with Timelog Depths) 2U-10 'tllthp 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 MKS) End,Depth(ftKS)', 10/24/2016 10/24/2016 0.50 COMPZN RPCOMP PACK P RIH to Fully located @ 6350'P/U 1'off 6,330.0 6,349.0 08:30 09:00 locator Pressure up tubing to 2500 psi set packer,Bleed down to 1500 psi Shear out of PBR,verify packer set. 10/24/2016 10/24/2016 1.75 COMPZN RPCOMP HOSO P L/D 3 jts M/U space out pups and 6,349.0 6,349.0 09:00 10:45 Hanger and landing jt,R/U to Circ 10/24/2016 10/24/2016 0.75 COMPZN RPCOMP CRIH P Spot 190 bbls CI Sea Water in IA and 6,349.0 6,349.0 10:45 11:30 Tubing 4 bpm 175 psi 10/24/2016 10/24/2016 0.50 COMPZN RPCOMP OTHR P Drain Stack Flush Lines 6,349.0 6,349.0 11:30 12:00 10/24/2016 10/24/2016 0.75 COMPZN RPCOMP HOSO P Land Tubing on hanger,RILDS 6,349.0 6,349.0 12:00 12:45 10/24/2016 10/24/2016 1.50 COMPZN RPCOMP PRTS P Pressure test tubing to 3000 psi f/30 6,349.0 6,349.0 12:45 14:15 min,Bleed off tubing to 2000 psi pressure up on IA to 2000 psi SOV sheared early Test IA and tubing to 2500 psi f/30 min Solid test 10/24/2016 10/24/2016 1.00 COMPZN RPCOMP MPSP P L/D landing Jt set BPV and test in 6,349.0 6,349.0 14:15 15:15 direction of flow to 1000 psi f/10 min 10/24/2016 10/24/2016 0.75 COMPZN WHDBOP NUND P N/D Stack Rack Back on Stand 6,349.0 6,349.0 15:15 16:00 10/24/2016 10/24/2016 2.00 COMPZN WHDBOP NUND P Dress hanger and N/U tree and 6,349.0 0.0 16:00 18:00 adaptor flange test to 5000 psi void test,test tree to 5000 psi charted F 5 min 10/24/2016 10/24/2016 0.50 COMPZN WHDBOP MPSP P Pull BPV 0.0 0.0 18:00 18:30 10/24/2016 10/24/2016 1.25 COMPZN WHDBOP FRZP P Freeze protect well w/85 bbls of 0.0 0.0 18:30 19:45 diesel as per LRS 10/24/2016 10/24/2016 1.00 COMPZN WHDBOP FRZP P Allow well to U-Tube 0.0 0.0 19:45 20:45 10/24/2016 10/24/2016 0.50 COMPZN WHDBOP MPSP P Set BPV 0.0 0.0 20:45 21:15 10/24/2016 10/24/2016 0.75 COMPZN WHDBOP NUND P Secure well remove flanges and install 0.0 0.0 21:15 22:00 blind flanges and gauges Rig Released @ 22:00 hrs Page 4/4 Report Printed: 10/27/2016 i • 0 Operations Summary (with Timelog Depths) 2U-10 ConocoPtailltps '$-. Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phage Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/20/2016 10/20/2016 1.25 MIRU MOVE MOB P Blow down water and steam, 0.0 0.0 03:00 04:15 dissconnect water steam air,unplug electrical lines,Simops jack up pipe sheds and rock washer,Pull away from rig spot out of the way 10/20/2016 10/20/2016 0.75 MIRU MOVE MOB P Pull Complexes away from sub and 0.0 0.0 04:15 05:00 Spot on Pad 10/20/2016 10/20/2016 0.50 MIRU MOVE MOB P Prep prep sub to move 0.0 0.0 05:00 05:30 10/20/2016 10/20/2016 0.50 MIRU MOVE MOB P Pull sub off of well and position f/ 0.0 0.0 05:30 06:00 move off pad 10/20/2016 10/20/2016 1.75 MIRU MOVE MOB P Crane gas buster house onto pits 0.0 0.0 06:00 07:45 10/20/2016 10/20/2016 2.75 MIRU MOVE MOB P Move Rig f/1G pad t/2U pad 0.0 0.0 07:45 10:30 10/20/2016 10/20/2016 1.25 MIRU MOVE MOB P Position sub to pull on well 0.0 0.0 10:30 11:45 10/20/2016 10/20/2016 1.00 MIRU MOVE MOB P Spot sub over well 0.0 0.0 11:45 12:45 10/20/2016 10/20/2016 3.50 MIRU MOVE MOB P Spot modules and rock washer pipe 0.0 0.0 12:45 16:15 shed 10/20/2016 10/20/2016 1.75 MIRU MOVE MOB P Hook up interconnects and work on rig 0.0 0.0 16:15 18:00 acceptance check list Rig Accepted @ 1800 hrs 10/20/2016 10/20/2016 1.00 MIRU 'WELLPR RURD P R/U to kill well 0.0 0.0 18:00 19:00 10/20/2016 10/20/2016 1.00 MIRU WELLPR MPSP P Pull BPV as per Cameron rep 0.0 0.0 19:00 20:00 10/20/2016 10/20/2016 1.75 MIRU WELCTL KLWL P PT lines t/3500 psi,Kill well w/8.8 0.0 0.0 20:00 21:45 ppg brine 220 bbls pumped @ 3 bpm 340 fcp 10/20/2016 10/20/2016 0.50 MIRU WELCTL OWFF P Observe well for flow,well static f/30 0.0 0.0 21:45 22:15 min 10/20/2016 10/20/2016 1.25 MIRU WHDBOP NUND P R/D Circ Equipment,N/U tree and 0.0 0.0 22:15 23:30 adaptor flange 10/20/2016 10/21/2016 0.50 MIRU WHDBOP MPSP P Prep tree and Install blanking plug into 0.0 0.0 23:30 00:00 hanger 10/21/2016 10/21/2016 2.50 MIRU WHDBOP NUND P N/U BOP and Adaptor Flange, 0.0 0.0 00:00 02:30 10/21/2016 10/21/2016 1.50 MIRU WHDBOP RURD P Welder Adding 2"to Riser,Simops- 0.0 0.0 02:30 04:00 Hook up lines to tiger tank bleed off 50 psi that built up,leave valve open monitor for returns static,Blow down lines 10/21/2016 10/21/2016 1.00 MIRU WHDBOP RURD P R/U t/test BOPE 0.0 0.0 04:00 05:00 10/21/2016 10/21/2016 3.00 MIRU WHDBOP WAIT X Wait for state man t/witness test 0.0 0.0 05:00 08:00 10/21/2016 10/21/2016 6.00 MIRU WHDBOP BOPE P Test BOPE w/3.5 and 4"test jt t/ 0.0 0.0 08:00 14:00 250/2500 f/5 min,State Inspector Johnnie Hill witnessed test,Test Choke valves 1-14, HCR and Man choke and Kill,Auto and Man IBOP, TIW and Dart,Upper Lower and Blind Rams,Annular and 4"Kill line demco, Koomey Draw Down 200 psi-32 sec Full Pressure-188 sec Test Gas alarms and PVT sensors Page 1/4 Report Printed: 10/27/2016 • • 0 Operations Summary (with Timelog Depths) 2U-10 Conoccithps 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) 10/21/2016 10/21/2016 0.50 MIRU WHDBOP RURD P R/D test equipment,B/D Lines 0.0 0.0 14:00 14:30 10/21/2016 10/21/2016 0.50 MIRU WHDBOP MPSP P Pull BPV as per Cameron Hand 0.0 0.0 14:30 15:00 10/21/2016 10/21/2016 0.75 MIRU RPCOMP RURD P M/U Landing jt to Hanger and top 0.0 6,340.0 15:00 15:45 drive,BOLDS pull hanger to floor hanger unseated @ 82k seals pulled free @ 115k 10/21/2016 10/21/2016 1.50 MIRU RPCOMP CIRC P Circ 1 bpm attempt to sting back into 6,340.0 6,340.0 15:45 17:15 PBR unable to get down,Clrc bottoms up 10 bpm 900 psi sand back on bottoms up,Pump 30bbI Hi Vis sweep around very little sand on bottoms up, attepmpt to sting in again made 1'no pump psi increase. 10/21/2016 10/21/2016 5.50 MIRU RPCOMP PULL P POOH L/D 3.5"Completion 191 jts,6 6,340.0 0.0 17:15 22:45 gas lifts,seal assy, Holes located on jt 182 out Corrosion on collar on jts 164-172 10/21/2016 10/22/2016 1.25 MIRU RPCOMP SEQP P Set Wear Ring,Clean and Clear floor 0.0 0.0 22:45 00:00 10/22/2016 10/22/2016 0.50 MIRU WELLPR BHAH P M/U BHA test packer 0.0 0.0 00:00 00:30 10/22/2016 10/22/2016 3.25 MIRU WELLPR TRIP P RIH w/test packer t/3160' 0.0 3,160.0 00:30 03:45 10/22/2016 10/22/2016 0.50 MIRU WELLPR PRTS P Set test packer and test casing to 3,160.0 3,160.0 03:45 04:15 2500 psi f/5 min,R/U and test below packer injecting at 1600 psi shut down blled off pressure 10/22/2016 10/22/2016 2.25 MIRU WELLPR TRIP P RIH f/3160't/5483' 3,160.0 5,483.0 04:15 06:30 10/22/2016 10/22/2016 3.50 MIRU WELLPR PRTS P Test casing @ 5483'bad test,P/U to 5,483.0 5,180.0 06:30 10:00 5375'test casing bad test,P/U to 5280'test casing bad test,P/U to 5188'test casing Bad test,P/U to 5028'test casing good test to 2500 psi f/5 min,RIH U 5123'test casing good, RIH U 5140'test casing good test,RIH U 5155'test casing good test,RIH U 5180'test casing bad test injecting @ 1 bpm 1600 psi R/D test equipment 10/22/2016 10/22/2016 0.75 MIRU WELLPR TRIP 'P RIH f/5180'U 5702' 5,180.0 5,702.0 10:00 10:45 10/22/2016 10/22/2016 0.50 MIRU WELLPR PRTS P Set test packer attempt t/test below 5,702.0 5,702.0 10:45 11:15 packer to 2500 psi injecting @ 1 bpm 1800 psi 10/22/2016 10/22/2016 0.75 MIRU WELLPR TRIP 'P RIH f/5702'U 6317' 5,702.0 6,317.0 11:15 12:00 10/22/2016 10/22/2016 4.25 MIRU WELLPR CIRC P R/U and reverse circ 2 tubing volumes 6,317.0 6,344.0 12:00 16:15 2 bpm 110 psi,strip through bag U 6338'until returns were clean,Make connection wash down U no go @ 6344'pressure spiked 500 psi confirm no go,reverse circulate clean 2 bpm 100 psi 10/22/2016 10/22/2016 0.75 MIRU WELLPR PRTS P Set test packer @ 6316'test down 6,344.0 6,316.0 16:15 17:00 string U 2500 psi f/10 min confirm plug and packer holding. 10/22/2016 10/22/2016 1.25 MIRU WELLPR TRIP P POOH L/D DP U 5100' 6,316.0 5,100.0 17:00 18:15 Page 2/4 Report Printed: 10/27/2016 KUP 010OD 2U-10 ConocoPhillips . ' e 3` Well Attrib Max Angle MD TD Ali_!`,KC'Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm HIKE!) Cprpcpphglips 500292130200 KUPARUK RIVER UNIT PROD 51.53 7,000.00 7,100.0 • .°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2U-10,11/22/20162:01:40 PM SSSV:NONE 75 11/21/2015 Last WO: 10/24/2016 40.99 4/12/1985 Verbal schemata(octad) Annotation Depth(ftKB( End Date Annotation Last Mod By End Date Hanger;3z.o ��.�..f Last Tag: SLM 6,834.0 6/23/2015 Rev Reason:RWO,GLV C/O,PULL CATCHER pproven 11/16/2016 &CA-2 PLUG Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len 0...Grade Top Thread CONDUCTOR 16 15.062 37.0 115.0 115.0 65.00 H-40 WELDED t 11Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread V11L SURFACE 9 5/8 8.921 37.0 2,993.7 2,993.3 36.00 J-55 BTC is Casing Description OD(in( ID(in) Top(SOB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 34.5 7,074.0 6,102.2 26.00 J-55 BTC CONDUCTOR;37.0-115.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lbkt) Grade Top Connection TUBING Upper 3 1/2 2.992 32.0 5,087.01 4,805.6 9.30 L-80 EUE 8rd GAS LIFT;2,505.3 "it_ Completion 2016 RWO Completion Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID(in) 32.0 32.0 0.04 Hanger McEvoy Gen III 7 1/16 x 3 1/2 MSDP-1-6.5-MS-3 Tubing 2.950 SURFACE;37.0-2,993.7-.• Hanger 5,074.4 4,797.3 48.72 Locator Locator 2.990 GAS LIFT;3,805.5 5,075.4 4,798.0 48.73 Seal Baker 80-40 Seal Assembly 2.990 Assembly al Tubing Description String Ma...ID(inl Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt PM) Grade Top Connection TUBING Straddle 31/2 2.992 5,077.9 6,348.5 5,632.1 9.30 L-80 EUE 8rd 1. Packer Assy 2016 GAS LIFT;4,358.4It RWO Completion Details Nominal ID Top(ftKB) Top(TOD)(ftKB) Top Incl T) Item Des Com (in) GAS LIFT;5,517.7 5,077.9 4,799.6 48.73 PBR Baker Polish Bore Recptica 4.000 11 5,091.5 4,808.6 48.74 PACKER Baker 35 x 7 FHL Retrievable Packer Pinned to shear @ 60k 2.920 11. 6,335.9 5,623.7 48.53 Locator Locator 2.990 Locator;5,074.4 IN 6,336.7 5,624.2 48.53 Seal Assy Baker 80-40 Seal Assembly 2.990 Tubing Description String Ma...•ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection Seal Assembly;5,075.4., TUBING Straddle 31/2 2.992 6,340.8 6,466.8 5,710.3 9.30 L-80 ABM-EUE PBR;5,077,9 4,r: Packer Assy 2003 111 RWO PACKER;5,0e1s Completion Details iii Nominal ID II Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) 111 6,340.8 5,626.9 48.54 SBR BAKER 80-40 SBR 3.000 Locator 6,335.6 1116,354.0 5,635.7 48.57 PACKER BAKER FHL PACKER 3.000 Seal Any;6,338.7 •= 6,409.4 5,672.3 48.63 NIPPLE CAMCO DS'NIPPLE 2.812 SBR;0.34018 j - - 6,454.3 5,702.0 48.46 SEAL ASSY SEAL ASSEMBLY STABBED INTO ORIGINAL PBR 2.990 AM A Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(R..Set Depth(ND)(...Wt(INR) Grade Top Connection WI TUBING Original I 4 1/21 2.9921 6,462.9 6,661.01 5,839.91 1 • Completion Details it Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID (in) NIPPLE;8,409.4 6,462.9 5,707.7 48.42 PBR BAKER PINNED'F'PBR 3.000 X 6,476.6 5,716.8 48.37 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 6,565.0 5,775.8 48.02 BLAST RING BLAST RING(1) 2.992 SEAL ASSY;8,454.3 6,623.6 5,815.0. 48.08 NIPPLE AVA BPL 028 PORTED NIPPLE 2.175 (Changed 9/2/2016 from 2.375) PBR;6,462.9 6,637.7 5,824.4 48.20 PACKER BAKER FB-2 PERMANENT PACKER 4.000 PACKER;8,478.8 '' 6,641.0 5,826.6 4822 SBE LOCATOR SUB w/SEAL BORE EXT 4.000 6,652.6 5,834.3 48.32 NIPPLE CAMCO NO GO'D'NIPPLE 2.250 PRODUCTION,6,515.0 = 6,660.1 5,839.3 48.38 SOS BROWN SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) IPERF;6,572.08,809.0-- . I Top IND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 6,623.0 5,814.6 48.07 SLEEVE-O 2.75"TPC(old style,29"OAL,2.74"pogo,2.32"ID) 8/26/2016 2.320 SLEEVE-0;6,623.0 •I-; Perforations&Slots NIPPLE;6,623.6 S Shot Den Top(ND) Bim(ND) (shoal TUBING PUP;6,636.8 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com PACKER;6,637.7 6,572.0 6,609.0 5,780.4 5,8052 C-4,UNIT B, 5/25/1985 12.0 IPERF 5"Dressler Atlas SBE;6,641.0 2U-10 6,724.0 6,784.0 5,881.5 5,920.4 A-4,A-3,2U- 5/25/1985 4.0 IPERF 4"Dressler Atlas 10 NIPPLE;6,652.8 6,828.0 6,832.0 5,948.6 5,951.1 A-2,2U-10 5/25/1985 4.0 IPERF 4"Dressler Atlas 6,838.0 6,842.0 5,954.9 5,957.4 A-2,2U-10 5/25/1985 4.0 IPERF 4"Dressler Atlas 6,868.0 6,872.0 5,973.8 5,976.4 A-2,2U-10 5/25/1985 4.0 IPERF 4"Dressler Atlas SOS;13,860.1Mand rel Inserts St ae IPERF;6,724.0-6,784.0---• on Top(ND) Valve Latch Port Size TRO Run - N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com IPERF;s,e28.a6,8320-� 1 2,505.3 2,505.0 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,307.0 10/28/2016 2 3,605.5 3,601.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,287.0 10/28/2016 IPERF;0.838.06,842.0 3 4,358.4 4,286.0 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.000 0.0 10/28/2016 IPERF;6,068.06,872.0- 4 5,017.8 4,759.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/24/2016 5 6,515.0 5,742.4 CAMCO KBUG 1 PROD HFCV BK 0.000 0.0 8/26/2016 PRODUCTION;34.5-7,074.0 0 8 KUP OD • 2U-10 ConocoPhillips I Aldskd int, CorboaeOhias ••• 2U-10,11/22/20182:01.40 PM Vertcal achen46o.{ectn$/ Hanger,32.0 11,')!11 Notes:General&Safety End Date Annotation -.nT 9/9/2003 NOTE:WO 'r• "' 14',,..1/13/2011 NOTE:View Schematic w/Alaska Schematic9 0 10/24/2016 NOTE:WO CONDUCTOR;37.0-115.0 M GAS LIFT:2,505.3 SURFACE;37.0-2,993.7 + Ill GAS LIFT;3,805.5 . .. Ill GAS LIFT;4,358.4 so GAS LIFT 5,017.7 III Locator;5,074.4 Seal"444"1y;5,075.4 4, PBR;5,077.9 -I._.; PACKER;5,081.5 Locator,6,335.9 all Seal May,6336.7 SBR;6,340.8 ; A6.: 4 a in NIPPLE,6 406 4 SEAL ASSY;6,4543 PBR,6,462.9 PACKER;6,476.6 II PRODUCTION;6,515.0 = 11 (PERF;6,572.08,609.0 1 IF SLEEVE-O;6,623.0 -1—I,I NIPPLE;6,623.6 i O i TUBING PUP;6,636.8 PACKER,6,637.7 SBE;6,641.0 NIPPLE;6,652.6Eil SOS;6,680.1. IA (PERF,6,724.08,784.0--. IPERF;6,628.0-6,832.0—. (PERF;6,838.0-6,842.0 (PERF;6,868.0-6,872.0 PRODUCTION;34.5-7,074.0 • OF Tjj, • cal Iyyy< � THE STATE Alaska Oil and Gas ���, of LAsKA Conservation Commission _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 ,, ,_ P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Andrew Beat � c 2f 1 , Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2U-10 Permit to Drill Number: 185-039 Sundry Number: 316-488 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this to day of October, 2016. RBDMS L cv OCT 1 0 2016 STATE OF ALASKA OSKA OIL AND GAS CONSERVATION COMMIIIN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 ' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 • Change Approved Programs Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 . Other: ,if et Ckc(y 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Nit ConocoPhillips Alaska,Inc. Exploratory ❑ Development 0, 185-039 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21302-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a , KRU 2U-10 ❑ Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025643 ' Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7100' ' 6118' • 7074' - 6102' . 1990 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 115' 115' Surface 2951' 9.625" 2992' 2992' Intermediate Production 7038' 7" 7072' 6101' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6572'-6609' , 5780'-5805' 4.5"x 3.5" L-80 6661' 6724'-6784' , 5882'-5920' 6828'-6832' 5949'-5951' 6838'-6842' 5955'-5957' 6868'-6872' 5974'-5976' RECEIVED Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: CAMCO'DS'LANDING NIPPLE ' MD=500 TVD=500 D PACKER-BAKER FHL PACKER , MD=6354 TVD=5635 SEP -BAKER FHL PACKER ' MD=6476 TVD=5716 AOGCC s J 6 6 1 6 ' �� PACKER-BAKER FB-2 PERM PACKER \ MD=6637 TVD=5824 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/31/2016 OIL 0 , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Andrew Beat @ 265-6341 Email Andrew.T.Beat@conocophillips.com Printed Name AndrewBeat 265-6341 Title Sr.Wells Engineer Phone q /WHO Signature ) Date 2-1 /1.....,/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \C.Q — Li Plug Integrity ❑ BOP Test rfr Mechanical Integrity Test ❑ Location Clearance ❑ Other: rjd p fC,j./ 71-a Z s(i(J ,', i `1 .�r/n v!a. r- 0 r c v- . v— �-,'S-� f-d Z J`C% C✓�� '� „,,l Post Initial Injection MIT Req'd? Yes ❑ No RBDMS L_(_-OCT 1 0 2016 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: G—G( 0 / / APPROVED BY Approved by: ' M ISSIONER THE COMMISSION Date: /O-hrun/ and Farm 10 4R3 R,.'ped /2015 v fnr 1 months from o the date of approval Att.eh,,e d„ D Nfeet.. r7/114Sf 13 fr r 1�LI�,�llbf �6/ • • ConocoPhillips Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 3 October 2016 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Producer 2U-10(PTD#185-039). 2U-10 was originally drilled and completed in 1985 as a selective, 'A'and'C' sand producer in Kuparuk.A one- way production packer leak was detected in 2003.A workover was performed in 2003 to stack a packerabove the existing production packer which secured the packer leak.The well returned to production until 2016 when multiple tubing leaks were identified.During diagnostics,a casing leak around 5,800'MD was also identified.A RWO has been recommended to bring the well back online. The proposed workover scope for 2U-10 will include pulling the upper completion,performing a test packer run to confirm deepest depth of casing integrity,and running back in with new tubing and a stacked packer to isolate the casing leak.The top of cement was identified at 5,540'MD from a CBL taken May 19, 1985. This Sundry is intended to document the proposed work on the production well,including the modifications to the production casing,and request approval to work over the well.If you have any questions or require any further information,please contact me at 265-6341. Sincerely, Andrew eat Senior Wells Engineer CPAI Drilling and Wells • 2U-10 Rig Workover • P&R Tubing w/Stacked Packer (PTD#: 185-039) Current Status: Shut In Scope of Work: Pull the existing upper completion,run new upper completion with a stacked packer to isolate casing leak. General Well info: Well Type: Producer MPSP: 1,990 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 2,573 psi/5,832' TVD(8.5 ppg EMW)measured on 08/26/2016 Wellhead type/pressure rating: McEvoy Gen III, 5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT-TxIA FAILED-08/25/2016 MITOA PASSED—09/16/2016 Earliest Estimated Start Date: October 31,2016 Production Engineer: Mark Shulman Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards. Complete the PJSM. 2. Swap OV for dummy valve in GLM#4. 3. Pull dummy valve from GLM#6. 4. Set CA-2 plug in the nipple at 6,409' KB. 5. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 1. MIRU. 2. Pull BPV.Reverse circulate KWF.Obtain SITP&SICP, if still seeing pressure at surface, calculate new KWF, weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/2,500 psi. a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV, screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 3-1/2"tubing. 6. MU test packer assembly and RIH to 5,500' MD. 7. Set test packer and pressure test IA to vaerify casing integrity. a. If test fails,move up hole until integrity is found.If test passes,move downhole until casing leak is found. 8. POOH with test packer assembly. 9. RIH with 3-1/2"upper completion with retrievable packer spaced appropriately to isolate casing leak.Pump corrosion inhibited fluid to fill the IA up to surface.Locate seals and set packer. 10. Pressure test IA,and record,to confirm upper packer and casing integrity. 11. Shear out of PBR. Space out and MU tubing hanger.Land the tubing hanger,RILDS. 12. PT the tubing,bleed tubing.Ramp up the IA pressure quickly to shear the SOV. 13. Pull the landing joint, install BPV.Pressure test the BPV from below. 14. ND BOPE. 1 • 2U-10 Rig Workover P&R Tubing w/Stacked Packer (PTD#: 185-039) 15. NU tree.Pull BPV and install tree test plug. Test tree and pull test plug. 16. Freeze protect well with diesel. Set BPV. 17. RDMO. Post-Rig Work 1. Pull BPV. 2. RU Slickline to pull CA-2 plug and SOV.Run gas lift design. 3. Reset well house(s)and flowlines of adjacent wells. 4. Turn well over to operations. 2 • - - • 2U-10 ConocoPhillips KRU Producer P&R Tubing w/ Stacked Packer PROPOSED ow COMPLETION Well Details: API: 50-029-21302-00 MP PTD: 185-039 Wellhead: McEvoy Gen III 5M - — Camco 3-'/z" x 1-1/2" MMG GLM's Casing/Tubing Details: 16" 65# H-40 Conductor to 115' KB NM 9-5/8" 36#J-55 Surface to 2,993' KB 7"26#J-55 Production to 7,074' KB / MO 3-1/2" 9.3# L-80 Tubing to 6,476' KB TOC at 5,540' MD 4-1/2" 12.6#J-55 Tubing to 6,660' KB Misc Details: Max Inclination: 52° � Stacked Packer to Isolate Production Max Dogleg: 3.6°7100' SIE. Casing Leak (2016 RWO) Last Tagged Fill: 6,834' KB Total Depth: 7,100' KB Production Casing Leak at –5,800' MD Perforation Details: .:. . i: 6,572'-6,609' KB—C Sand i j- 6,724'-6,784' KB—A Sand I Stacked Packer to Isolate Production 6,828'-6,832' KB—A Sand A Packer Leak (2003 RWO) 6,838'-6,842' KB—A Sand ; '' 6,868'-6,872' KB—A Sand ,' 47 Camco DS Nipple MOITS Baker Retrievable Packer and PBR Camco Production Mandrel 4' C Perfs _ - _`, Blast Rings C 1 Sliding Sleeve Baker Permanent Packer and SBE Camco D Nipple A Perfs Date: September 21,2016 I Drawn By: Andrew Beat KUP PROD • 2U-10 • ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Statusncl(°) MD(ftKB) Act Btm(ftKB) yppc 500292130200 KUPARUK RIVER UNIT PROD I 51.53 7,000.00 7,100.0 ... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2U-10,9/2/20163:43:56 PM SSSV:NIPPLE 75 11/21/2015 Last WO: 9/9/2003 40.99 4/12/1985 Vertical schema5c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date l - Last Tag:SLM , pproven 9/2/2016 HANGER;32o TPITPCGC/OL&FTXIDinCOMPLETION „' „ Casing Strings r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread . ° I CONDUCTOR 16 15.062 37.0 115.0 115.0 65.00 H-40 WELDED I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(...Wt/Len(I...Grade Top Thread - ! SURFACE 95/8 8.921 37.0 2,993.7 2,993.3 36.00 J-55 BTC .�Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;37.0-115.0-, Ia PRODUCTION 7 6.276 34.5 7,074.0 6,1022 26.00 J-55 BTC NIPPLE;500.1 Tubing Strings =al Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD((...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 32.0 6,466.8 5,710.3 9.30 L-80 ABM-EUE al Completion Details GAS LIFT;2,475.7 g..7 Nominal ID Top(ftKB) Top(ND)(ftKB( Top Incl(°) Item Des Com (in) 32.0 32.0 0.04'HANGER TUBING HANGER 3.500 500.1 500.1 0.32 NIPPLE CAMCO'DS'LANDING NIPPLE 2.875 6,336.6 5,624.2 48.53 LOCATOR BAKER LOCATOR 2.960 SURFACE;37.0-2,993.7- 6,340.7 5,626.9 48.54'SBR 'BAKER 80-40 SBR 3.000 6,354.0 5,635.7 48.57 PACKER BAKER FHL PACKER 3.000 GAS LIFT;3,483.9 6,409.4 5,672.3 48.63 NIPPLE CAMCO'DS'NIPPLE 2.812 6,454.3 5,702.0 48.46 SEAL ASSY SEAL ASSEMBLY STABBED INTO ORIGINAL PBR 2.990 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING Original 41/2 2.992 6,462.9 6,661.0 5,839.9 GAS LIFT;4,302.1 Completion Details Nominal ID - Top(ftKB( Top(TVD)(ftKB) Top Ind(*) Item Des Com (in) 6,462.9 5,707.7 48.42 PBR BAKER PINNED'F'PBR 3.000 GAS LIFT;5,119.5 6,476.6 5,716.8 48.37 PACKER BAKER FHL RETRIEVABLE PACKER 3.0015- 6,565.0 .0006,565.0 5,775.8 48.02 BLAST RING BLAST RING(1) 2.992 � - 6,623.6 5,815.0 48.08 NIPPLE -AVA BPL O2B PORTED NIPPLE 2.175 GAS LIFT;5,842.4 (Changed 9/2/2016 from 2.375) 6,637.7 5,824.4 48.20 PACKER BAKER FB-2 PERMANENT PACKER 4.000 6,641.0 5,826.6 48.22 SBE LOCATOR SUB w/SEAL BORE EXT 4.000 6,652.6 5,834.3 48.32 NIPPLE CAMCO NO GO D'NIPPLE 2.250 GAS LIFT;6,282.1 6,660.1 5,839.3 48.38 SOS BROWN SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) , Top(ND) Top Incl Top(ftKB) (RKB) (°) Des Com Run Date ID(in) SBR;6,340.7 'e'; 6,399.0 5,665.4 48.67 CATCHER JUNK CATCHER.2.80"x 120" 8/29/2016 0.000 VT. 6,409.0 5,672.0- 48.63'CA-2 PLUG CA-2 PLUG 8/29/2016 0.000 6,623.0 5,814.6' 48.07'SLEEVE-0 2.75"TPC(old style,29"OAL,2.74"nogo,2.32"ID) 8/26/2016 2.320 CATCHER;8,399.0 0Perforations&Slots Shot Dens NIPPLE;6,409.4 i: Top(WD) etm(ND) (shots/f CA-2 PLUG;6,409.0 I Top(ftKB) BM(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,572.0 6,609.0 5,780.4 5,805.2 C-4,UNIT B, 5/25/1985 12.0 IPERF 5"Dressler Atlas 2U-10 6,724.0 6,784.0 5,881.5 5,920.4 A-4,A-3,2U- 5/25/1985 4.0 IPERF 4"Dressler Atlas 10 SEAL ASSY;6.454.3 6,828.0 6,832.0 5,948.6 5,951.1 A-2,2U-10 5/25/1985 4.0 IPERF 4"Dressler Atlas PBR;6,462.9 6,838.0 6,842.0 5,954.9 5,957.4 A-2,2U-10 5/25/1985 4.0 (PERF 4"Dressler Atlas PACKER;6,476.6 6,868.0 6,872.0 5,973.8 5,976.4 A-2,2U-10 5/25/1985 4.0 IPERF 4"Dressler Atlas Mandrel Inserts PRODUCTION;6,515.0 St II ali on Top(WO( Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com (PERF;Q572.0-6,fi09.0-� N 1' 2,475.7 2,475.4 CAMCO KBUG 1 Gas Lift GLV BK 0.156 1,280.0 9/21/2003 U 2 3,483.9 3,482.1 CAMCO KBUG 1 Gas Lift GLV BK 0.188 1,311.0 9/21/2003 I_ 3 4,302.2 4,239.6 CAMCO KBUG 1 Gas Lift GLV BK 0.188 1,304.0 9/21/2003 SLEEVE-0;6,823.0 4 5,119.5 4,827.1 CAMCO KBUG 1 Gas Lift OV BK 0.250 0.0 8/17/2016 NIPPLE;8,623.6 5 5,842.4 5,299.6 CAMCO KBUG 1 Gas Lift DMY BK 0.000 0.0 9/9/2003 I. 6 6,282.1 5,588.0 CAMCO KBUG 1 Gas Lift DMY BK 0.000 0.0 9/9/2003 TUBING PUP;6,636.8 a 7 6,515.0 5,742.4 CAMCO KBUG 1 PROD HFCV BK 0.000 0.0 8/26/2016 PACKER;6,637.7 Notes:General&Safety - SBE;6,641.0 AI _ End Date Annotation III 1/13/2011 NOTE:View Schematic w/Alaska Schematic9.0 II 8/18/2016 NOTE:HOLEFINDER DETERMINE TBG LEAK BETWEEN 5208'&5176'RKB NIPPLE;6,652.6 a SOS;6,660.1 IPERF;6,724.0-6,784.0 IPERF;6,828.0-6,832.0- . IPERF;6,838.0-6,842.0--. -4 IPERF;6,868.0-6,872.0 PRODUCTION;34.5-7,074.0 • L • IP . 1.-- ConocoPhillips AlaskaRECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 SEP 2 3 2016 21 September 2016 AOGCC Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 / Anchorage,Alaska 99501 % Dear Commissioner: / ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Producer 2U-10(PTD# 185-039). / / 2U-10 was originally drilled and completed in 19as a selective, 'A' and'C' sand producer in Kuparuk.A one- way production packer leak wad,detected in 200,3 A workover was performed in 2003 to stack a packer above the existing production packer which secured theOacker leak.The well returned to production until 2016 when multiple tubing leaks were identified. During diagnoyics,a casing leak around 5,800' MD was also identified. A RWO has been recommended to bring the well back nline. The proposed workover scope for 2U- will include pulling the upper completion,performing a test packer run to confirm deepest depth of casing inteity,and running back in with new tubing and a stacked packer to isolate the casing leak. The top of cement wasi,_dentified at 5,540' MD from a CBL taken May 19, 1985. This Sundry is intended to docu, ent the proposed work on the injection well, including the modifications to the production casing,request a v.. iance from 20 AAC 25.412,and request approval to work over the well. If you have any questions or require any ' her information,please contact me at 265-6341. Sincerely, , -.....„„k, _ Andr-w Beat i Senior Wells E ineer CPAI Drilling ,nd Wells C) C C ill! 4111 Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Monday, October 03, 2016 1:16 PM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2U-10(PTD 185-039, Sundry 316-488) RWO Attachments: 2U-10 Sundry Letter.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, My apologies, I was working on forms for this well and 1Y-05(an injector)and did not sufficiently proof read before submitting.Thank you for catching my mistake. The updated Sundry letter is attached. Please let me know if you have any other questions. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,October 03,2016 11:04 AM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]KRU 2U-10(PTD 185-039,Sundry 316-488) RWO Andrew, The letter refers to this well as both a producer and an injector and requests a variance from 20 AAC 25.412. Please correct and describe what variance you are seeking. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(?alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov 1 9 • • SIT !, 3 u o L CU i Us t0 (D _C -6 f9 r Y O a, Ti) N rii O vi C L o a o c -c o- - w �w5w d (13 ° E a a m H 0 0 0 O Ur N z W N O L J O J OO.-m �p m 0 m m m m m 0 m m co Q +�+ L "d O N Q m m m m m m m m m m a a - -0 Y ` `^ Q Y O 3 3 7 7 7 7 7 7 Q Q y ) U , N r o aaaaaa as u, u, L 0 ' C M N N N N 00 N 8 o t� U - 0 - vi Z a N N N N N N N N M M a) c \ Z Q D N O to O q - � U U c u Q1 O 0 0 0 0 0 0 - c µ- V O J J J J J J J J J J J J ' '- W W W W W W W W W W W W LL LL LL LL LL LL LL LL LL LL LL LL Y O- > ,-. 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L x N rl Y N O _@ d ' f> Q 0 0 0 0 0 0 0 0 0 0 0 0 Q j.E 0 0 0 0 0 0 0 0 0 0 0 0 0 00 N o M M N o r n M ao a_ - a Cr O 0)0 N N 0 �O a in O d' • _ _ .,,y f[f\� N M O M M M N N O O O N • r (V N N N N N N N N N N N N C 0 0_ N.Q -1 8 M 8 N O O N 0 0 0 O N f0 U 0 01 ' N O N N N N N N N N N N 0 UO _ O r' O O O O 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 v u en• C th C N N N N in N in v> u1 u1 ui C . innzth 15 E E E CID W f0 6C1 C Y i u a in GO O O • O In O CO Y C N a+ Y Z �1�p O O e- O O O O N O E 0,1 c v, C Q O fNl CO N N cis m N M M LI. tL m w E z tail O E _ R C co OCA ^ Jt H a a r 0 Q • \I 5-0Y\ • WELL LOG TruiNsmirrAL PROACTIVE DIAC{NOSTIC SERVICES, INC. DATA LOGGED q /M/2014 ;v1. K. BENDER To: AOGCC REU 1VED Makana Bender 333 West 7th Avenue SEP .0 8 ZUIb Suite 100 Anchorage, Alaska 99501 AOGCC e (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ale NOV Q 42016, 1) Caliper Report 28-Aug-16 2U-10 1 Report /CD 50-029-21302-00 2) Signed : ✓ ��-' v /..EAk:ef Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(75 MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • k=55-X39 = 2.1539 SH 08 'alb Memory Multi-Finger Caliper till it, AnCiCr' Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2U-10 Log Date: August 28, 2016 Field: Kuparuk Log No.: 15642 State: Alaska Run No.: 1 API No. 50-029-21302-00 Pipe Description: 3.5 inch 9.3 lb. L-80 ABM-EUE Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 6,441 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 6 at 6,282 feet(Driller's Depth). This log was run to assess the condition of tubing with respect to internal corrosive and mechanical damage, particularly around a hole located at 5,184 feet prior to patch setting operations. The caliper recordings indicate the 3.5 inch tubing around the hole at 5,184 feet and the 61%wall penetration at 5,183 feet is in good condition for setting a patch. A 3-D log plot of the caliper recordings from 5,120 feet to 5,240 feet is included in this report. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good to poor condition,with a hole recorded in joint 159 (5,184 ft)and a 52%wall penetration at an isolated pit in joint 178 (5,799 ft). No other significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. The caliper recordings indicate slightly cork-screwed tubing from the kick-off point at—3,225 feet to 6,441 feet(end of log). MAXIMUM RECORDED WALL PENETRATIONS : �cnetir�,r� E=ercr nt Wa'1 PH,//tratia3i 1 rt;, Hole 100 159 5,184 Ft. (MD) Isolated Pitting 52 178 5,799 Ft. (MD) No other significant wall penetrations(> 16%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (>9%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. B. Suhanek C. Waldrop T.Wiese Field F nq c/eel(s/ 11na, r ,%/11/10. ProActive Diagnostic Services, Inc. / P.O. Box 1369,Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalysis(@memorylog.com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot CRS Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2U-10 Date : August 28, 2016 Description : Detail of Caliper Recordings Across Hole Recorded in 3.5 Inch Tubing. Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map 1 ft:240ft I 0 % 100 t 2.5 inches 3.5 0° 0° 90° 180° 270° 0° Maximum I.D. I I 2.5 inches 3.5 Minimum I.D. I t 2.5 inches 3.5 Pup Joint 5120 1 )11,07111111 GLM 4 1 5130 mit v Pup Joint { 4 t 5140 +fei _ _ II ii 5150 E - Joint 158 5160 1[ I 5170 s, f %i i Joint 159 i 5180 €i Hole(5,184') 61%Wall ` Penetration 5190 II (5,183') I — 5200 I t 5210 I t Joint 160 t. II 5220 ir 5230 El Joint 161 i; 1rnwn • Correlation of Recorded Damage to Borehole Profile NI Pipe 1 3.5 in (39.9'-6,440.6') Well: 2U-10 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: August 28, 2016 . Approx.Tool Deviation ■ Approx.Borehole Profile 1 42 25 825 • 50 1,617 GLM 1 75 __ 2,408 5 100 - 3,225 GLM 2 �► "' t 125 4,042 GLM 3 150 4,860 GLM 4 175 5,676 GLM 5 GLM 6 -+ 195 6,419 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=1 95 • PDS Report Overview Body Region Analysis Well: 2U-10 Survey Date: August 28,2016 Field: Kuparuk Tool Type: UW MFC 24 No.211387 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 ABM-EUE Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 ABM-EUE 2.992 in. 40 ft. 6,441 ft. Penetration(%wall) Damage Profile(%wall) 250 — ow Penetration body EMI Metal loss body 0 50 100 0.1 _ 200 -- 150 100 50 47 0 0 to 20 to 40 to over 20% 40% 85% 85% GLM 1 Number of joints analyzed(total=215) 213 0 1 1 95 Damage Configuration(body) GLM 2 (2:00) 10 8 GLM 3 (3:00) 141 6 4 GLM 4 (5:30) 2 t� 0 GLM 5 (8:00) 187 Isolated General Line Other Hole/ l= Pitting Corrosion Corrosion Damage Pos.Hole E- GLM 6 (8:00) Number of joints damaged(total=9) 5 0 3 0 1 Bottom of Survey= 195 • • (P3S7 PDS Report Joint Tabulation Sheet Well: 2U-10 Survey Date: August 28, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 ABM-EUE Tubing 2.992 in. 0.254 in. 40 ft 6,441 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 40 0 0.03 13 0 2.97 Pup • 1 42 0 0.03 13 2 2.92 Lt. Deposits. ■ 1.1 74 0 0.03 12 0 2.92 Pup Lt. Deposits. Ns 1.2 76 0 0.03 12 2 2.90 Pup Lt. Deposits. 1.3 86 0 0.02 8 3 2.90 Pup Lt. Deposits. 2 97 0 0.03 10 3 2.90 Lt. Deposits. 3 128 0 0.03 10 2 2.92 Lt. Deposits. 4 160 0 0.03 11 2 2.92 Lt. Deposits. • 5 192 0 0.03 11 3 2.92 Lt. Deposits. ■ 6 223 0 0.02 9 2 2.92 Lt. Deposits. 7 255 0 0.02 9 3 2.92 Lt. Deposits. 8 286 0 0.03 10 2 2.92 Lt. Deposits. 9 317 0 0.03 12 2 2.93 Lt. Deposits. • 10 349 0 0.03 11 2 2.90 Lt. Deposits. • 11 381 0 0.03 10 2 2.91 Lt. Deposits. d 12 412 0 0.03 10 3 2.90 Lt. Deposits. • 13 444 0 0.03 10 3 2.91 Lt. Deposits. r 14 476 0 0.03 10 2 2.93 Lt. Deposits. 14.1 507 0 0 0 0 2.86 3.5"CAMCO DS LANDING NIPPLE 15 509 0 0.03 10 2 2.89 Lt. Deposits. r 16 541 0 0.03 12 2 2.92 Lt. Deposits. • 17 571 0 0.02 9 2 2.93 Lt. Deposits. • 18 603 0 0.03 12 2 2.92 Lt. Deposits. in 19 635 0 0.03 11 3 2.94 ■ 20 666 0 0.03 12 2 2.92 Lt. Deposits. 21 698 0 0.02 9 2 2.92 Lt. Deposits. 22 730 0 0.03 . 10 2 2.92 Lt. Deposits. r 23 762 0 0.02 9 2 2.93 Lt. Deposits. ■j 24 793 0 0.03 11 2 2.92 Lt. Deposits. ■ 25 825 0 0.03 10 2 2.92 Lt. Deposits. Ist 26 857 0 0.03 10 2 2.93 r 27 888 0 0.03 13 2 2.92 Lt. Deposits. ■ 28 920 0 0.03 11 2 2.93 Lt. Deposits. ■ 29 952 0 0.03 12 2 2.93 Lt. Deposits. Ill 30 983 0 0.03 10 2 2.92 Lt. Deposits. 31 1015 0 0.02 9 2 2.90 Lt. Deposits. 32 1047 0 0.03 11 2 2.92 Lt. Deposits. ■ 33 1079 0 0.03 13 2 2.92 Lt. Deposits. • 34 1110 0 0.03 10 2 2.92 Lt. Deposits. 35 1142 0 0.03 10 2 2.92 Lt. Deposits. 36 1174 0 0.02 9 2 2.92 Lt. Deposits. 37 1205 0 0.02 9 2 2.92 Lt. Deposits. 38 1236 0 0.03 13 2 2.92 Lt. Deposits. li 39 1268 0 0.03 10 2 2.92 Lt. Deposits. r 40 1300 0 0.03 10 3 2.92 Lt. Deposits. ■ 41 1332 0 0.03 11 2 2.92 Lt. Deposits. 42 1363 0 0.02 8 2 2.92 Lt. Deposits. 43 1395 0 0.03 11 2 2.92 . Lt. Deposits. • 44 142 7 0 0.04 15 2 2.92 Shallow Line of Pits.Lt. Deposits. ■ 45 1459 0 0.03 13 2 2.92 Lt. Deposits. IPenetration Body Metal Loss Body Page 1 i • CI it PDS Report Joint Tabulation Sheet Well: 2U-10 Survey Date: August 28, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 ABM-EUE Tubing 2.992 in. 0.254 in. 40 ft 6,441 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 46 1490 0 0.03 13 2 2.93 Lt. Deposits. ■ 47 1522 0 0.03 12 2 2.92 Lt. Deposits. 48 1554 0 0.02 9 2 2.93 Lt. Deposits. 49 1586 0 0.03 11 2 2.93 Lt. Deposits. 50 1617 0 0.02 9 2 2.92 Lt. Deposits. r 51 1649 0 0.03 11 2 2.91 Lt. Deposits. ■ 52 1681 0 0.03 11 2 2.93 Lt. Deposits, ■ 53 1712 0 0.03 11 2 2.93 Lt. Deposits. ■ 54 1744 0 0.03 13 3 2.93 Lt. Deposits. 55 1775 0 0.03 10 3 2.91 Lt. Deposits. 56 1806 0 0.03 12 3 2.94 ■ 57 1838 0 0.03 11 2 2.92 Lt. Deposits. ■ 58 1870 0 0.03 10 2 2.92 Lt. Deposits. ■ 59 1902 0 0.03 11 2 2.92 Lt. Deposits. ■ 60 1933 0 0.03 10 2 2.93 Lt. Deposits. ■ 61 1964 0 0.03 11 3 2.91 Lt. Deposits. 62 1996 0 0.02 9 2 2.94 63 2027 0 0.03 10 2 2.92 Lt. Deposits. 64 2059 0 0.02 9 2 2.93 Lt. Deposits. 65 2091 0 0.02 9 , 3 2.92 Lt. Deposits. 66 2122 0 0.03 10 2 2.91 Lt. Deposits. 67 2154 0 0.03 10 2 2.93 Lt. Deposits. 68 2186 0 0.03 10 4 2.93 Lt. Deposits. ■ 69 221 7 0 0.03 11 , 2 2.92 Lt. Deposits. ■ 70 2249 0 0.03 11 2 2.92 Lt. Deposits. ■ 71 2281 0 0.03 11 2 2.93 Lt. Deposits. ■ 72 2312 0 0.03 12 2 2.92 Lt. Deposits. 73 2344 0 0.02 9 2 2.92 Lt. Deposits. d 74 2376 0 0.02 9 2 2.94 75 2408 0 0.03 10 3 2.94 76 2439 0 0.02 9 3 2.93 76.1 2471 0 0.04 15 2 2.93 Pup Shallow Line of Pits.Lt. Deposits. 76.2 2481 0 0 0 0 2.83 GLM 1 (NO DEVIATION) 76.3 2487 0 0.02 9 2 2.92 Pup Lt. Deposits. 77 2498 0 0.03 11 2 2.93 Lt. Deposits. ■ 78 2529 0 0.03 13 2 2.92 Lt. Deposits. ■ 79 2561 0 0.03 11 2 2,94 ■ 80 2593 0 0.03 10 2 2.93 Lt. Deposits. ■ 81 2624 0 0.03 10 2 2.93 ■ 82 2656 0 0.03 10 2 2.92 Lt. Deposits. ■ 83 2687 0 0.03 10 2 2.93 Lt. Deposits, ■ 84 2719 0 0.03 11 2 2.93 Lt. Deposits. ■ 85 2751 0 0.03 11 3 2.92 Lt. Deposits. ■ 86 2783 0 0.03 11 2 2.92 Lt. Deposits. ■ 87 2814 0 0.03 11 2 2.92 Lt. Deposits. ■ 88 2846 0 0.03 11 2 2.94 ■ 89 2878 0 0.03 11 3 2.94 ■ 90 2910 0 0.03 11 2 2.92 Lt. Deposits. ■ 91 2941 0 0.02 9 2 2.92 Lt. Deposits. • 92 2973 0 0.03 13 3 2.89 Lt. Deposits. IPenetration Body Metal Loss Body Page 2 • • fit PDS Report Joint Tabulation Sheet Well: 2U-10 Survey Date: August 28, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 ABM-EUE Tubing 2.992 in. 0.254 in. 40 ft 6,441 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 93 3005 0 0.03 12 2 2.93 Lt. Deposits. 94 3036 0 0.03 10 2 2.92 Lt. Deposits. 95 3068 0 0.03 . 10 3 2.92 Lt. Deposits. 96 3099 0 0.03 12 3 2.92 Lt. Deposits. 97 3130 , 0 0.02 9 2 2.92 Lt. Deposits. 98 3162 0 0.03 11 3 2.92 Lt. Deposits. 99 3193 0 0.03 10 3 2.94 100 3225 0 0.03 11 2 2.92 Lt. Deposits. 101 3256 0 0.02 9 2 2.94 102 3288 0 0.03 10 2 2.92 Lt. Deposits. 103 3320 0 0.03 11 2 2.92 Lt. Deposits. 104 3351 0 0.03 12 2 2.92 Lt. Deposits. 105 3383 0 0.03 12 2 2.93 Lt. Deposits. 106 3414 0 0.03 10 2 2.94 107 3446 0 0.03 10 2 2.93 Lt. Deposits. 107.1 3477 0 0.03 11 2 2.90 Pup Lt. Deposits. 107.2 3487 0 0 0 0 2.88 GLM 2(LATCH @ 2:00) 107.3 3495 0 0.03 10 2 2.92 Pup Lt. Deposits. 108 3505 0 0.03 11 2 2.93 Lt. Deposits. 109 3536 0 0.03 . 12 2 2.95 110 3568 0 0.02 9 2 2.94 111 3599 0 0.02 9 2 2.92 Lt. Deposits. 112 3631 0 0.03 11 2 2.94 113 3662 0 0.03 10 2 2.92 Lt. Deposits. 114 3694 0 0.03 10 2 2.92 Lt. Deposits. 115 3726 0 0.03 10 2 2.94 116 3757 0 0.02 9 2 2.94 117 3788 0 0.02 9 3 2.94 118 3820 0 0.03 11 2 2.93 Lt. Deposits. 119 3852 0 0.03 12 2 2.93 Lt. Deposits. 120 3883 0 0.03 10 2 2.94 121 3915 0 0.02 8 2 2.91 Lt. Deposits. 122 3947 0 0.03 13 3 2.93 Lt. Deposits. 123 3978 0 0.03 12 3 2.91 Lt. Deposits. 124 4010 0 0.03 11 2 2.93 125 4042 0.05 0.02 9 2 2.94 126 4074 0 0.03 12 2 2.93 Lt. Deposits. 127 4105 0 0.02 9 2 2.94 128 413 7 0 0.03 10 3 2.95 129 4168 0 0.03 11 2 2.95 130 4200 0 0.03 10 3 2.95 131 4232 0 0.04 14 3 2.93 Lt. Deposits. 132 4264 0 0.03 11 2 2.95 132.1 4294 0 0.02 7 2 2.90 Pup Lt. Deposits. 132.2 4305 0 0 0 0 2.91 GLM 3(LATCH @ 3:00) 132.3 4311 0 0.03 11 2 2.90 Pup Lt. Deposits. 133 4322 0 0.03 10 3 2.94 134 4353 0 0.03 12 2 2.93 Lt. Deposits. 135 4385 0 0.02 9 2 2.93 136 4416 0 0.03 10 3 2.92 Lt. Deposits. Penetration Body Metal Loss Body Page 3 • • JilS. PDS Report Joint Tabulation Sheet Well: 2U-10 Survey Date: August 28, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 ABM-EUE Tubing 2.992 in. 0.254 in. 40 ft 6,441 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 lit 137 4448 0 0.03, 11 2 2.92 Lt. Deposits. 138 4480 0 0.04 16 4 2.93 Shallow Pitting. Lt.Deposits. 139 4512 0 0.04 15 2 2.93 Shallow Pitting. 140 4544 0 0.02 9 2 2.92 Lt. Deposits. 141 4575 0 0.02 9 3 2.95 142 4606 0 0.03 11 3 2.93 143 463 8 0 0.04 14 3 2.94 144 4670 0 0.03 10 2 2.93 Lt. Deposits. 145 4702 0 0.02 9 2 2.94 146 4733 0 0.03 11 3 2.90 Lt. Deposits. 147 4765 0 0.03 11 2 2.90 Lt. Deposits. 148 479 7 0 0.03 12 2 2.95 149 4828 0 0.03 10 2 2.93 Lt. Deposits. 150 4860 0 0.02 8 1 2.94 151 4890 0 0.03 11 2 2.93 •1 152 4922 0 0.02 9 2 2.86 Lt. Deposits. 153 4953 0 0.04 15 3 2.86 Shallow Pitting. Lt.Deposits. 154 4985 0 0.04 14 3 2.93 Lt. Deposits. 155 5017 0 0.03 . 13 2 2.91 Lt. Deposits. 156 5049 0 0.03 11 2 2.93 Lt. Deposits. 157 5081 0 0.04 16 3 2.93 Shallow Pitting. Lt.Deposits. 157.1 5111 0 0.03 10 3 2.95 Pup 157.2 5122 0 0 0 0 2.77 GLM 4(LATCH @ 5:30) 157.3 5128 0 0.02 8 2 2.96 Pup WI 5138 0 0.03 13 2 2.93 Lt. Deposits. 159 5170 0 0.30 100 9 2.93 Hole! Lt. Deposits. 7 160 5200 0 0.03 10 2 2.93 Lt. Deposits. 161 5233 0 0.03 11 2 2.90 Lt. Deposits. 162 5264 0 0.03 10 2 2.92 Lt. Deposits. 163 5296 0 0.03 10 2 2.93 Lt. Deposits. 164 532 7 0 0.03 12 2 2.92 Lt. Deposits. 165 5359 0 0.03 11 2 2.93 Lt. Deposits. 166 5391 0 0.03 11 2 2.92 Lt. Deposits. 167 5422 0 0.03 11 2 2.92 Lt. Deposits. 168 5455 0 0.04 14 2 2.92 Lt. Deposits. In 169 5485 0 0.03 10 2 2.92 Lt. Deposits. C 170 5517 0 0.03 11 3 2.92 Lt. Deposits. G 171 5550 0 0.02 9 2 2.93 Lt. Deposits. 172 5581 0 0.02 9 2 2.94 • 173 5613 0 0.03 11 2 2.93 Lt. Deposits. C 174 5644 0 0.03 13 2 2.94 175 5676 0 0.03 10 2 2.93 Lt. Deposits. • 176 5707 0 0.03 10 2 2.93 Lt. Deposits. 177 5739 0 0.03 10 3 2.92 Lt. Deposits. Immo 178 5770 0 0.13 52 4 2.91 Isolated Pitting. Lt.Deposits. 179 5802 0 0.02 9 3 2.93 Lt. Deposits. 179.1 583 3 0 0.02 9 3 2.95 Pup 179.2 5842 0 0 0 0 2.84 GLM 5(LATCH @ 8:00) 179.3 5850 0 0.04 15 2 2.91 Pup Shallow Line of Pits. C 180 5860 0 0.03 11 2 2.95 IPenetration Body Metal Loss Body Page 4 • • PDS Report Joint Tabulation Sheet Well: 2U-10 Survey Date: August 28, 2016 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 ABM-EUE Tubing 2.992 in. 0.254 in. 40 ft 6,441 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 181 5892 0 0.02 9 2 2.93 182 5923 0 0.03 11 3 2.92 Lt. Deposits. 183 5955 0 0.02 9 2 2.94 184 5986 0 0.03 13 3 2.93111 185 6018 0 0.03 10 2 2.93 ■I 186 6050 0 0.03 10 3 2.92 Lt. Deposits. ■ 187 6082 0 0.03 13 2 2.93 Lt. Deposits. • 188 6113 0 0.03 10 2 2.91 Lt. Deposits. 189 6145 0 0.02 9 3 2.94 190 6176 0 0.03 12 2 2.91 Lt. Deposits. 191 6208 0 0.03 10 2 2.94 192 6240 0 0.03 11 3 2.93 Lt. Deposits. 192.1 6272 0 0.02 9 2 2.95 Pup 192.2 6282 0 0 0 0 2.88 GLM 6(LATCH @ 8:00) 192.3 6288 0 0.03 . 10 2 2.90 Pup Lt. Deposits. 193 6299 0 0.03 13 3 2.93 Lt. Deposits. 193.1 6330 0 0.02 9 2 2.93 Pup Lt. Deposits. 193.2 6336 0 0 0 0 2.97 BAKER LOCATOR 193.3 6349 0 0 0 0 3.00 BAKER 80-40 SBR 193.4 6352 0 0 0 0 2.88 BAKER FHL PACKER 193.5 6360 0 0.02 8 2 2.93 Pup Lt. Deposits. 194 6366 0 0.03 10 2 2.94 194.1 6397 0 0.02 9 2 2.94 Pup 194.2 6407 0 0 0 0 2.80 2.81"D-CAT 194.3 6409 0 0.03 12 2 2.96 Pup 195 6419 0 0.02 8 2 2.92 Lt. Deposits. IPenetration Body Metal Loss Body Page 5 • cf3sPDS Report Cross Sections Well: 2U-10 Survey Date: August 28,2016 Field: Kuparuk Tool Type: UW MFC 24 No.211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 ABM-EUE Analyst: C.Waldrop Cross Section for Joint 159 at depth 5,183.746 ft. Tool speed=52 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=91% -"MIN. Tool deviation=47° / IP 1 IIIIIIIrf Finger=2 Penetration=0.296 in. Hole 0.30 in.= 100%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections Well: 2U-10 Survey Date: August 28, 2016 Field: Kuparuk Tool Type: UW MFC 24 No.211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 ABM-EVE Analyst: C.Waldrop Cross Section for Joint 178 at depth 5,799.450 ft. Tool speed=53 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% Tool deviation=46° 1 Finger= 11 Penetration=0.133 in. Isolated Pitting 0.13 in.=52%Wall Penetration HIGH SIDE= UP KUP PROD is 2U-10 ConocoPhillips Well Attributes Max Angle&MD TD AIaS14.3,104: 'WellboieGPeJWham 9 Plata Welton.Statue 66.x1`1 MO Mae) Adarm(0(K6) 50:222"112121 KUPARUK RIVER'UNIT PROD 7'X:0: 7 ... Comment H2S4cpTI Data annatatian End Date P13-Gra 45,41 Re Ra€aae Data r.e t:2:c'35x33Pu SSSL'.Ni''P__ 7f _ '_ Last WO. 4519$ ,Get-Cao:cpm-2000 Act., annotatwn a0ptn 18661 600 Gale Annotation LIN Mss 54 Dia Dale �4v35.-:c �� ..�� 35 _ 81.....1 6.534.0 0..,2 Res P. -2444,"i,. _G GLV SET= _ _.e U...._:c AoT_-T .,c .SEENOTOS Lasing Strings .I lir-510103 DeeaitCn 00(M1 ID(911 Tap 460(61 tat txptn 40(1(61 Sit DepSI 1091))..60t1(1.Grade Tap TT6e6a ,.DNDUCTCR 76 150't2 37.5 175.2 1:. 65,03 4-1-42 Wt.DED Caehrp DaaxtpeaP OD461) 6146l) Tap(0(1491 Sag Depth 41t66) Eat Depth(TM)._W'LA.en 4t...50086 Top Tnaaxi SURFACE 3,5E 8.921 27.: 2.963.7 2.993.3 SEX 2-83 ETC Caeulg Deo 1pDan 004in7 11(03 Top(0(K64 Sst Depth 4(6(6) tet Depth 4TOO)...WVLen 0..-Grea6 Top 200030 C1-DVCTJt 37.0#16 C. PRODUCTION 7 6.270 34.5 7.:74.'3 0102.2 26.5? 55 :; 1 n2E.680' Tubing Strings Tutwlp Dee4lpttan 00Y1p Ma...ID(mi Top(0(x9) let MVP.40(...td Daptn 4T-5934 4...0(4 461401) Grade Tap Cenn63801 7261'43 3 .2 2:9992 324 6,426.E 5 7 2.2 33:1-6: 407241-026 aka LP-r.2975. Completion Details NST Ina.i2 Tap I11101 T55ITv73141tKa1 140 ina,'i It1r.Dee ::ar ;x11 32:0 32.5 G.174 HANGER TUBING HANGER :..5:- 52ti.' 5,227 5.32 NIPPLE CAMCO'DS LANDINGNIPPLE 2 875 0.336 0 5.324.2 48.53 ,32ATOR BAKER LOCATOR 2.96: _ arra.=2'(9_4527 0.3407 5.626.9 48.54 538 BAKER 80.40S5R 2111_ 6.254: 5..0115.7 45.57 PACKER BAl .4_°ACK6- wa L4"2 492 5 0.4634 5.072.3 48.53 NI->LE CAMC27 282 ed'E=__ 5.454.3 57:2.0 4840 SEA_ASS' SEALASSEMBLY 51E2 ..3..4.4_=E 2.52 To 2168 Ob1a19pt)on Nang Ma...in(61) Top 410391 tat Dap=404...tat Not.oval 4..Wt 01.III 303l6 Tap Cana6dM11 'I 4444, 143CG' N3Cr,_i,2: 4';2 652 6.462.9 6.667-_ ..,23.0 Completion Details 1: m 3'1247 Tap:11KCI T:F 1.551',0(KE] TCF 1148'1 Gam Dee Car 'ni 6.482.0 5.707.7 4842PER BAKER PINNED'0'P3R -77: 6.476 6 5.716.8 45 37 PACKER BAKER FHL RETRIEVABLE PACK-640 ..__ 6.565.'5 5,775.3 48.:2 BLAST RING BLAST RING(1) :__ 6,523.6 5.815':: »_.33 NIPPLE AVA BPI 02B PORTED NIPPLE_ _17f Daae:rT 5192 1 0537-7 5.324.4 46 2217 PACKER BAKER PB-2 PERMANENT PACKER 0,64'.0 5.626.6 43-22 58£ LOCATOR SUSw'SEAL BORE EAT + e: 3,052.6 5.534.9. -1.32 NIPPLE CAa1C0 NC GO'D'NIPFLE - - 6,900.' 5,230.3 43.32 3:3 3RC-WN SHEAR OUT S:J: 2302 Other In Hole(Wireline retrievable plugs,valves.pumps,fish,etc.) T 1101 Ca Top and Vii-.-.l{1 _ Top(121(61 p4T., I'lpI GOB Ran Data 101 4 661 0,403 5 5072 0 43. . CAT S"2 2,h JCA' 8,1712016 _ 329.62401 A. 6.623.2 5.3^4.6 43.0. SLEEVE-2 2.75 TPli 29 2.k., 617.'2016 2122: I 6.5_:: 5.6'_4.6 46.3'.3 C. P�I1..3 2. A °,11 _ 624=..SPARTEK 60612016 1122_ 8611 . F J,.ES sc Perforations&Slots <='L6 64803 Sint Dane :04'6toe 4 'wcl Top4TVD) atm4Tw1 1060117 Tap4T1K61 60n Ma el 41(03) 40.491 zone Dale t1 Typo COT 6,572.0 5,650 >4.4 5,805.2 CA,UN)T B, 5251965 1.2'0 IPERP _,56r At.�s 20-10 6,724.5 5764_ _-- S 5 920.4 .A-4.A-3 21.1- 5125'1985 4.0 IPERF -_:__rSr,.. 22.+._A229 64543 70 6.828.0' 6832 - 5 '' .4-2.21.1 10 ,25.,985 40 IPSP= POW'646:5 iii- 6,838.^ 6.84< _:. .. 5.557.4 A-2.212-10 .:251985 4.: I _. ..__ 'lonER 6 476 6 . 6,868.0 6.872.: _1111__ 5.376.4 A-2,2U-08 -a 251985 -_ _. -- : 9R+X,I:RAT1 6 5,5 0 Mandrel Inserts n ws all Cl Top Mali "%o Lanai Part Site TRO Run PoPp 6 572 GE6030---. it Top;0(1(61 itt1(11 MSIai Moan 00)611 So's Typo Type )61 (PSI Ran Data Cam 2,475.7 2.475.4 CAMCO 4(62-3 . ass"At GLV 841 0.1566 1,285.0 921/2513 .4810 5,432 1 2 010CC- 4(623. < 3461437362 BK 0,188 1,311.0 9.°21.2003 a:22'.6c£6.E c- 4X32. 4,235 6 O'.ICO IS$UG I 344 Lit( GLV Bis 0.`88 1304 0 9.222063 a.=.:.e 6.2a,e :il' 4 5."G 4,827 1 CAMCC 4(9`JG 7 SES Lift DV 595 0251 '1(0 &'725'5 5 842 4 5,239 6 •1420 K5UG . 344 Lift DMY BK 0.103 030 'i 3 5232 5.538 001420 K3i1 G ' aa_a,,It 0617 BK 0502 113 r_e2sooF EEa1 6,515.5' 5.7424 t y _.. _ _ 046100 10303 PROD OM 81( :..t.-, .0U 8'.62025 =.4'A=9 Ee3'7 lila£6.,.( „�. Notes:General&Safety 595 Dale Annotation ® m NOTE:'Kew Sceeaae w'Aias ra&'oma'-6c9.0 V NOTE:HOLEF)NDER DETERMINE TBG LEAK BETWEEN 5206'65176 RIG Y991_6 665:6- qq on_:2036£530 1 11 SOP 6 lac• Y 066199 5 72404 714.0- R6R=6.020 61215 ~- 92.262260424:.0~ •_ - 'ER(0664127:0 P92..CTGAI 24.5 0749 9 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~ ~ 5- 0 ?:>-~ Well History File Identifier Organization (~o.e) ,~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) Color items: o Diskettes, No. [3 Maps: Grayscale items: Poor Quality Originals: Other: Other, No/Type Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: ~¢~ NOTES: ORGANIZED BY; ~ BREN VINCENT SHERYL MARIA LOWELL Other Project Proofing [] Staff Proof By: Date: PROOFED BY: Scanned (done) BEVERLY BREN ~SHERYL MARIA LOWELL III IIIIIIIIIII II III DATE: PAGES: 6~ (at the time of scanning) SCANNED BY: BEVERLY BREN ~ SHERYL MARIA LOWELL DATE: Isl RESCANNEDBY: BEVERLY BREN ~ ~;;-"7,','L ~'~'~A LOWELL General Notes or Comments about this file: PAGES: ~""~ Quality Checked (done) Rev1 NOTScanned.wpd • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 5, 2009 .~ c~ 2ti~'~~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ,.~~ ~~ ~ ~~~ , ;~ ~ ~~ -~3q ~u-!o 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 January 18th and January 24th, 2009. The corrosion inhibitor/sealant was pumped February 21St through February 23`a , 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i~ ~~y~ C M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ae~ Report of Sundry Operations (10-404) Kuparuk Field Date 315/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2U-01 185-004 50' 5.90 3'1" 1/18/2009 9.2 2/22/2009 2U-02 185-005 6' 1.20 22" 1/18/2009 3.4 2/22/2009 2U-03 185-006 34' 7.90 2' 1/18/2009 7.4 2/22/2009 2U-05 185-018 40' 6.50 3'S" 1/18/2009 9.4 2/23/2009 2U-06 185-019 54' 7.00 2' 1/18/2009 7.1 2/23!2009 2U-07A 185-091 6' 0.70 2'2" 1/18/2009 4.5 2/23/2009 2U-08 185-021 80' 11.40 2'10" 1/18/2009 5.2 2/23/2009 2U-09 185-038 12' 1.50 22" 1/18/2009 3.6 2/23/2009 2U-10 185-039 6' 0.80 22" 1/18/2009 3.5 2/23/2009 2U-12 185-041 18'6" 2.70 22" 1/18/2009 3.1 2/23/2009 2U-13 184-246 45' 6.50 2' 1/18/2009 5.9 2/23/2009 2U-14 184-247 22' 4.20 22" 1/18/2009 6.1 2/23/2009 2U-15 184-248 26' 3.90 2'2" 1/18/2009 3.6 2/23/2009 2U-16 184-249 64' 8.40 5'2" 1/18/2009 14.8 2/23/2009 2W-01 185-010 27' 3.50 3'9" 1/18/2009 5.2 2/21/2009 2W-02 185-016 12' 6.50 5'9" 1/18/2009 12.3 2/21/2009 2W-04 185-012 55' 8.10 5'4" 1/18/2009 15.1 2/21/2009 2W-05 184-191 22' 2.90 2'3" 1/18/2009 7.6 2/21/2009 2W-06 184-194 16" NA 16" NA 1.4 2/22/2009 2W-07 184-204 56' 6.60 21" 1/24/2009 5.6 2/22/2009 2W-09 184-219 16" NA 16" NA 3.4 2/22/2009 2W-11 184-222 49' 6.00 4'3" 1/18/2009 10.5 2/22/2009 2W-12 184-224 64' 10.00 22" 1/24/2009 2.1 2/22/2009 2W-13 184-236 6'6" 6.00 23" 1/18/2009 5.2 2/22/2009 2W-14 184-237 20'4" 3.30 22" 1/18/2009 3.7 2/22/2009 2W-15 184-238 41' 7.10 2'10" 1/18/2009 3.9 2/22/2009 2W-17 207-135 8" NA 8" NA 1.1 2/22/2009 FW: 2U-10 (PTD 1850390) Repo~f failed TIFL • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, December 28, 2007 1:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: FW: 2U-10 (PTD 1850390} Report of failed TIFL Attachments: 2U-10 schematic.pdf; 2U-10 90 day TIO plot.jpg '--~ t~~l~( ~ ~ ~~L' Sorry; I missed signing the first email. I apologize. Brent From: NSK Problem Well Supv Sent: Friday, December 28, 2007 1:14 PM To: 'tom maunder@alaska.gov'; 'Regg, James B (DOA)' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2U-10 (PTD 1850390) Report of failed TIFL ~~~.J~9'~~~ JHl~ ~ ~_ Ltf~~ Tom & Jim, ~,. Kuparuk gas lifted producer 2U-10 (PTD 1850390) failed a diagnostic TIFL on 12!27!07 and has been added to the weekly SCP report. The TIO prior to shut in for the TIFL was 275/1100/875. A leaking GLV is suspected. Slickline will -~'" trouble shoot the tubing leak and repair if possible. Attached is a 90 day TIO plot and a schematic. ~- Please let me know if you have any questions. «2U-10 schematic.pdf» «2U-10 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 1 /8/2008 KRU 2U-10 PTD 185-039 TII/C~ Piot - 2U-10 1400 1200 1000 N 800 a 600 400 200 0 ~.. . , I~~ ~I~ ...........................................................................................................t,...............,,. ...............................................................~..................,,.. . u ..,..~...... .~ .............................................. 28-Sep-07 11-Oct-07 24-Oct-07 06-Nov-07 19-Nov-07 Date 02-Dec-07 15-Dec-07 200 150 a E as 100 Y O L v 50 0 • • • • ~ ~ Cv~~~vPhil~ips Alaska, tnc. KRU 2U-10 -- - -- 2u-~o - --- -- _ _ NIP (500-501, OD:4.600) ~ ~ .~ ~ o ~_1 f ~I API: 500292130200 Well T e: - PRuD - An le TS: 48 d cD t3510 SSSV T : NIPPLE Ori Com {etion: 4/12/1985 An le TD: 52 d 7100 Annular Fluid: Last W/O: 9/9!2003 Rev Reason: TAG FILL Reference L : 32.8' RKB Ref L Date: Last U date: 11/1/2006 Last Ta : 6780 TD: 7100 ftKB Last Tag Date_10/17/2006 Max Hole Anc~le• ;Casing Stringy-ALL STRINGS Descri tion Size To 52 d~ ~ 7100 _ Bottom _ - TVD _ Vrtt Grade Thread SURF CASING 9.625 0 2994 2994 36.00 J-55 BUTTRESS PROD CASING 7.000 0 7074 6102 26.00 J-55 BUTTRESS CONDUCTOR 16 000 0 115 115 65.00 H-40 WELDED ' -r ~F' Tubing Strin TUBING ~- ~- ~ ~ ~ I ~ - c ~ m I B T~ ~ radc Thread G I ~ - o661 - 10 n -zSU SkuEi_i~f r_!D - [ 1 k,, u -ry Perforat ons Summa @~ - - - Interval TVD - - Zone Status Ft - SPF Date --- T e Comment 6572 - 6609 5780 - 5805 C-4,UNIT 37 12 5/25/1985 IPERF 5" Dressler Atlas 1 B "I = , ;~ 6724 - 6784 5881 - 5920 A-4,A-3 60 4 5/25!1985 IPERF 4" Dressler Atlas i 6828 - 6832 5948 - 5951 A-2 4 4 5/25/1985 IPERF 4" Dressler Atlas 1 11 6838 - 6842 5955 - 5957 A-2 4 4 5/25/1985 IPERF 4" Dressler Atlas , E ~ 111 _, -•~ 6868 - 6872 5974 - 5976 ~ Gas Lift Mandrels/Valves A-2 _ 4 _ 4 5/25/1 a8F IPERF 4" Dressler Atlac - ~ I -- - - - j St MD ND Man Man Type V Mfr V Typ e V OD Latch Port TRO Date Run Vlv ~ - Mfr Cmnt ~ ' ~ 1 2476 2476 CAMCO KBUG GLV 1.0 BK 0.156 1280 9/21/2003 2 3484 3482 CAMCO KBUG GLV 1.0 BK 0.188 1311 9/21/2003 3 4302 4239 CAMCO KBUG GLV 1.0 BK 0.188 1304 9!21/2003 ~ ,~ ff /~ 4 5119 4827 CAMCO KBUG OV 1.0 BK 0.250 0 9/21/2003 ~ „ 1 ~ Fnd~ Goo r`onnrn uRi ir_ nnnv ~ n au n nnn n oionnn~ i 6 j - 62821 - 55881 - CAMCO I - KBUG ~ _ DMY 1.0 - ~ BEK 0.000 0 9/9/20031 - _ ' Production MandrelsNa -- - -- lves -- t,~ St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv j Mfr Cmnt l i 7 6515- 5742 Cameo KBUG__ HFCV 1.0 __BEK 0.000 0 _11!22/200_ _ __ (p gT quip., etc. JEWELRY -POST WORKOVER ) - - - _ __ D th T 4D T e Descri tion , iD ~ 3 H ANGER TUBING HANGER SET 9/9/2003 3.500 ~ 500 500 NIP CAMCO'DS' LANDING NIPPLE SET 9/9/2003 2.875 6337 5624 LOCATOR BAKER LOCATOR SET 9/9/2003 2.980 I 6354 5636 PACKER BAKER FHL PACKER SET 9!9/2003 2.940 ~f~~ 6409 5672 NIP CAMCO'DS' NIPPLE SET 9/9/2003 2.813 6454 5702 PBR/SBR BAKER PBR WITHOUT SEALS SET 9/9/2003 3.000 Other ( plugs, equip., etc.) -JEWELRY -ORIGINAL ~ ~~ Depth TVD Type I Description I ID FdR4 F7nR PRR Rakar ninnarl 'F' CFT dl19/1 QRF ~ nnn ........._ i L... .'.. ,I _.-~ t.~~_. € -' - k I `4k LOCATOR ° ..... k€ -~- [ € (6637-6638, ~ t' ~ € [ [ € [ ~ ~3 a 3 ~: ~'~ [€ , d . SOS € < <, (6659-6660, f ,. ~rT-~ OD:3:500) 4 € ~ Perf [ [ I .. (6724-6784) r Perf l~ - (6826-6832) ~ -- Perf (6838-6842) ~ ~ ... Perf " I (6868-6872) --- ~ ~ ' Schlumberg8P Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well v/ 2N-305 J lJ O· ì J.ç J2N-308 I ((q -úic:. .I2N-317 ~ (1 3~ N], u 2G-06 I 3 1.( - ~~.). .../ 1 Y -04 ¡ 8> - f¡ ~ l \./3J-10 IYi-J.çò J2U-10 I~)-C)(~ oo-'1C-178 ~)-lY.( Job# 11047348 11047344 11047345 11022913 11047351 11058227 11047352 11022908 ~r i, h' 'C-. "-r'" C ï= - "", ('.J~I;MJ'HlJ~rJ . <, r y n t:; Jo nJ¡;: ~-Jt.....~ v v b ~ Log Description SBHP SURVEY SBHP SURVEY SBHP SURVEY FLOWING BHP INJECTION PROFILE V 'I L MULTI-FINGER CALIPER LOG PRODUCTION PROFILE WIDEFT PRODUCTION PROFILE W/DEFT />7/ ('! tl/1 II ;': ,} ! ,ljl/¡'rtV-f/ ...... (j !v¡ll,--t! SIGNED: Date 07/25/05 07/24/05 07/24/05 07/20/05 07/27/05 07/18/05 07/28/05 07/14/05 08103105 NO. 3443 }~5~069 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD ~ 1 1 1 1 1 1 1 1 ~ DATE: '~ \. '. \ ~ U 7~~ -?"':--.. V Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ConoCOPhillips October 7, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 Subject: Report of Sundry Well Operations for 2U-10 (185-039) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 2U-10. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader CPAI Drilling MM/skad OCT 1 A 2.003 qRI$1NAL i STATE OF ALASKA '{. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS '1. Operations Performed: Abandon D Suspend r-~ Operation Shutdown ~] Perforate ~ Variance ~ Annular Disp. [~ Alter Casing [] Repair Well E~ Plug Perforations E~ stimulate D Time Extension [~ Other ~'] Change Approved Program [--] Pull Tubing E~ Perforate New Pool E~] Re-enter Suspended Well r~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r-~ Exploratory [] 185-039 / 3. Address: Stratigraphic [ Service [] 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21302-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 105' 2U-10 8. Property Designation: 10. Field/Pool(s): ADL 25643, ALK 2574 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7100' feet true vertical 6118' feet Plugs (measured) 6494' Effective Depth measured 6758' feet Junk (measured) true vertical 5904' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SURF CASING 2889' 9-5/8" 2994' 2994' PROD CASING 6969' 7" 7074' 6102' Perforation depth: Measured depth: 6572'-6609', 6724'-6784', 6828'-6832', 6838'-6842', 6868'-6872' ' ,, true vertical depth: 5780'-5805', 5881'-5920', 5948'-5950', 5954'-5956', 5973'-5975' Tubing (size, grade, and measured depth) 3-1/2", L-80, 6661' MD. , Packers & SSSV (type & measured depth) pkr= 2 BAKER 'FHL' PACKER · BAKER 'FB-I' PERM. pkr=6354', 6477" 6638 . ; no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casin,q Pressure 'rubin,q Pressure Prior to well operation 1052 3352 3738 - 245 Subsequent to operation 1245 3692 2901 284 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory [~] Development [] Service r'-] Daily Report of Well Operations _X 16. Well Status after proposed work: Oil['~ Gas[]'-] WAG ['--~ GINJ [--] WINJ [--~ WDSPL [--'~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Mike Mooney @ 263-4574 Printed NameI// ~,,// Mike I~looney~f ~., Title Wells Group Team Leader ,/__~__._.~~//,,)/~ Signature ~//...~.-:~'-' ' ' /~//, ,,~z.~¥,/_ Phone Date Prepared by Sharon AIlSup;,Drak~ 26~3-4612 Form 10-404 Revised 2/2003 · ORIGINAL · ConocoPhillips Alaska Page 1 of 3 Operations SUmmary Report Legal Well Name: 2U-10 Common Well Name: 2U-10 Spud Date: 4/6/1985 Event Name: WORKOVER/RECOMP Start: 9/6/2003 End: 9/9/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/9/2003 Group: Rig Name: Nabors 3S Rig Number: ~ C°deSUb Phase Description of Operations ~ Date From-To HoUrs code 9/5/2003 15:30 - 23:00 7.50 MOVE RURD MOVE Rig release from 2U-08 at 1530. Prep rig for rigging down. Scope derrick down and lay derrick over. Prep 2U-10 location with mats and herculite. Separate pipe shed and pit modules from carrier sub. Prep to move rig. 23:00- 23:30 0.50 MOVE MOVE MOVE Pull carrier sub away from well. Move rig to 2U-10. Back carrier sub over well. 23:30- 00:00 0.50 MOVE RURD MOVE Set mats for carrier sub. 9/6/2003 00:00 - 12:00 12.00 MOVE RURD MOVE Spot pipe shed module and pit modules. Mate modules up to carrier sub. Raise and scope up derrick. Held pre-spud meeting with day crew and CPF-2 Lead Operator at Pre-Tour meeting. Position BOPE behind wellhead. 1/2 gal diesel spill from Peak Sow on pad. Report spill to Security. Clean up spill. Spill clean up approved by ACS. 12:00 - 19:15 7.25 WELCTL NUND DECOMP Accepted rig @ 12:00. Mark tree for alignment. ND tree NU BOPE. Function test BOP. Pull BPV. Hold pre-spud meeting with night crew, Toolpusher, CPAI Safety Specialist, CPAI Field Drilling Supervisor, MI, & Cameron. 19:15 - 21:00 1.75 WELCTL BOPE !DECOMP Run 2-way check. Threads in hanger felt rough while setting 2-way check. MU test joint and screw into hanger. Begin BOP test. John Crisp AOGCC is on hand to witness BOP test. Can get 250 psi Iow test, but 4000 psi high test bleeds off. No indication of external leaks and fluid level does not rise in BOP. 21:00 - 00:00 3.00 WELCTL BOPE DECOMP Troubleshoot high pressure leak on BOP test. Try testing with different configurations to isolate leak. We appear to be leaking by the 2-way check. Pull test joint. PT blind rams. Leak rate is much lower than before, but pressure is still leaking off. Pull 2-way check. Run new 2-way check. 9/7/2003--' 00:00 - 00:45 0.75 WELCTL BOPE DECOMP Line up to test stack with new 2-way check installed. Still have slight bleed off on blind ram test. Blinds are holding good. Bleed off is due to 2-way check. MU I jt of 3-1/2 L-80 for test joint to isolate 2 way check from testing. Screw jt into hanger. 00:45 - 05:30 4.75 WELCTL BOPE DECOMP Getting good test with 2-way check isolated. Continue with BOP test. John Crisp with AOGCC on hand to witness test. Discuss upcoming BOP test after packoff changeout with Mr. Crisp. Test rams and choke & kill equipment to 250/4000 psi. Test annular to 3500 psi. Will retest blinds after casi~ packoff changeout. Blow down choke and kill lines. Clean up floor. 05:30 - 06:45 1.25 FISH RURD DECOMP RU cement line hose for circulating. RU CAMCO control line spooler. 06:45 - 07:45 1.00 FISH PULL DECOMP Pull 2-way check. Screw landing jt into hanger. PU on hanger. String weight looks to be 63K. Continue to pull up to 110K max weight. Seals broke free and weight fell back to 63K. Pull hanger to floor. Fill backside with 10.8# brine. Getting some diesel at surface. 07:45 - 10:00 2.25 FISH ClRC DECOMP Rig up to circulate long way. Circulated surface to surface till hole was 10.8 ppg. 10:00 - 16:00 6.00 FISH PULL DECOMP Layed down tubing hanger. Start POOH with pipe and spooling control line. Connections very tight. Could not break connections with 4-1/2" Tongs. Rigged down and rigged up 7-5/8" tongs. Could not break connections without crimping pipe. After crimping 15 jts decided to lay pipe down and run L-80 inspected pipe back. Pulled 57 jts up to the SSSV (original tally said 56 jts were run above the SSSV). LD SSSV. 55 out of 57 jts were crimped. Recovered all 30 control line bands. 16:00 - 17:00 1.00 WELLSF PLGM DECOMP Set storm packer @ 30'. Unload tubing out of pipe shed. Begin loading inspected 3-1/2" L-80 tubing in pipe shed. Printed: 9/16/2003 3:25:16 PM ConOcoPhillips AlaSka Page 2 of 3 Operations Summary Report Legal Well Name: 2U-10 Common Well Name: 2U-10 Spud Date: 4/6/1985 Event Name: WORKOVER/RECOMP Start: 9/6/2003 End: 9/9/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/9/2003 Group: Rig Name: Nabors 3S Rig Number: Date From To Hours Code Sub Phase Description of operations Code 9/7/2003 17:00- 17:15 0.25 WELLSF DEQT DECOMP Test storm packer to 2000 psi 17:15 - 20:00 2.75 WELCTI. NUND DECOMP Pull mousehole. Pull riser. Remove choke and kill lines. ND BOPS. 20:00 - 23:30 3.50 WELLSF EQRP DECOMP ND Tubinghead. 7" casing came up 4" when tubing spool was removed. Call out welder. Continue to load inspected tubing in pipe shed. Drift tubing and install seal rings. Welder cut off casing stub to proper height. Released welder. Prep to replace primary packoffs in Braidenhead. BOLDS. Casing grew another 3". Call out welder to cut off stub again. Replace primary packoffs in braidenhead. Cut off casing stub to proper height. NU redressed tubinghead from 2U-02. Energize secondary seals. 23:30 - 00:00 0.50 WELLSR DEQT DECOMP Pressure test 7" casing packoff and void area to 3000 psi. 9/8/2003 00:00 - 01:30 1.50 WELCTL NUND DECOMP NU BOP. Install riser. Hookup choke and kill lines. 01:30 - 02:45 1.25 WELCTL BOPE DECOMP PU test jt. Set test plug in tubinghead. Test choke and kill lines and blind rams to 250/4000. BOP test witness waived by John Crisp AOGCC. Pull test plug 02:45 - 03:45 1.00 WELLSR PLGM DECOMP Fill hole above storm packer. MU retrieving tool. RIH and release storm packer. No pressure below packer. Pull storm packer. LD storm : packer and retieving tool. 03:45 - 11:30 7.75 FISH PULL DECOMP , Clean up rig floor. Continue POOH w/tubing. LD all joints. Almost all :joints have damage from breakout. Connections are very tight. Last ~two jts had significant amount of scale. Otherwise pipe is in good , shape. Breakout GLM's. These will be sent to CAMCO for testing. 11:30 - 14:15 2.75 CMPLTN PULD CMPLTN !Strap and drift all jewelery. Grind seals off of old seal assembly, prep to rerun. 14:15 - 14:30 0.25 CMPLTN SFTY CMPLTN I Held pre-job safety meeting. Went over in detail the running of the , completion. 14:30 - 23:15 8.75 CMPLTN RUNT CMPLTN =Picked up original 3-1/2" X12'Baker seal assemby (no seals), one jt i 3-1/2" L-80 tubing, 3-1/2"X2.812 Camco "DS" Nipple with RHC Plug in i place,one full jt 3-1/2" tbg (to space stacker packer away from old GLM !set pt) 3-1/2" Baker FHL Retrievable Packer (3" ID) with new 12' Baker !80-40 PBR Assembly, one full jt 3-1/2" tbg, 3-1/2"X1" Camco 'KBUG' GLM w/10 pup top and bottom and w/2500 psi casing to tubing SOV & latch. Continue to run remainder of completion. 6 total GLMs and ,3-1/2"X2.875" Camco 'DS' @ 516' jt. #181. Tag top of PBR w/seal assembly 22.5' in on jt 197. RIH seal length. Tag Iocator sub on top of PBR. PU above PBR. Start circulating with charge pump. RIH. Returns stopped when seal assembly entered PBR. PU until returns started plus 2'. 23:15 - 00:00 0.75 CMPLTN CIRC CMPLTN Line up to reverse circulate. Pressured up to 600 psi. Bleed off and PU 2'. Start circulating 2.5 BPM at 250 psi. Circ 2 bottoms up. Very small amount of oily solids in returns after 1 bottoms up. 9/9/2003 00:00 - 00:30 0.50 CMPLTN CIRC CMPLTN Continue to reverse circulate until 2 bottoms up. Returns are clean. 00:30 - 01:10 0.67 CMPLTN CIRC CMPLTN SD pump. Line up to pump down tubing. Start pumping with charge pump. RIH. Saw pressure increase and flow stopped. RIH 12 and tag top of PBR w/Iocator 20.5' in on jt 197. PU seal assembly 2' above PBR. Pump 20 bbls corrosion inhibited brine 2BPM at 150 psi. Displace with 2.5 BPM at 250 psi. 01:10 - 02:00 0.83 CMPLT~ PCKR CMPLTN SD Pump. PU to 1st connection. Drop Ball and rod. Up weight--56K. Down weight=48K. Block weight=10K. RIH and tag Iocator on PBR at same spot as before. PU to neutral plus 2'. Wait 25 min for ball and rod to drop. Pressure up on tubing. Packer set 6354' with 1700 psi. Walk pressure up to 2660 psi. Pressure dropped to 2510 psi in 10 min. Bleed pressure down to 1600 psi. Pull up and shear PBR with 68K. Printed: 9/16/2003 3:25:16 PM ConocoPhillips Alaska Page 3 of 3 Operations Summar Report Legal Well Name: 2U-10 Common Well Name: 2U-10 Spud Date: 4/6/1985 Event Name: WORKOVER/RECOMP Start: 9/6/2003 End: 9/9/2003 Contractor Name: nabors3scompanym@conocop Rig Release: 9/9/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Date From-To HoUrs COde: code PhaSe DesCriptiOn of OPerations · 9/9/2003 01:10 - 02:00 0.83 CMPLTI~ PCKR CMPLTN Pressure dropped to 1350 psi. 02:00 - 03:15 1.25 CMPLTI~ SOHO CMPLTN PU 2' after sheared PBR. Set back down on PBR. Figure space out. Pull 3 jts. Add 2-10' and 1-2.5' pups. RIH w/1 jt on top of pups. MU hanger with 2' pup on bottom. RIH and land hanger. Locater is spaced out 3.81' above top of PBR. RILDS. 03:15 - 04:30 1.25 CMPLTN DEQT CMPLTN Open up annulus to atmosphere. Pressure up on tubing to 2420 psi. Small flow out annulus then stopped. Pressure bled down to 2380 psi in 15 min. Bleed tubing down to 1600 psi. Pressure up on annulus to 2520 psi. Tubing pressure increased to 2280 psi. After 15 min, annulus down to 2470 psi. Tubing up to 2300 psi. Bleed tubing down to 1650 psi. Casing dropped to 2410 psi. Wanted to see more differential on tests. After 15 rain tubing still at 1650 psi and casing at 2400 psi. Bleed tubing pressure down to 0 psi and Shear out valve sheared. Bleed tubing and annulus down to 0 psi. 04:30 - 11:00 6.50 CMPLTi~ NUND CMPLTN Set BPV, Empty and clean out pits. Clean brine off of BOPE and rig floor. 11:00 - 17:30 6.50 CMPLTN SEQT CMPLTN ND BOPE. NU tree. Pulled BPV, set two way check, press test to 5000K. All tests good. Set BPV. 17:30 - 18:00 0.50 WELLSR PLGM CMPLTN Released rig at 18:00hrs. Move to 2U-06. Printed: 9/16/2003 3:25:16 PM G ConocoPhillips Alaska, Inc. NIP (500-501, -- 2U-10 0D:4.600) KRU 2U-10 APl: SSSV Type: Annular Fluid: Reference Log: Last Tag: Last Tag Date: 500292130200 NIPPLE ~2.8' rkb 6752 9114/2003 Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: PROD 411211985 9~9~2003 7100 ftKB 52deg@7100 Angle ~ TS: Angle @ TD: Rev Reason: Last Update: 48 deg@6570 52deg@7100 Workover, GLV design, Tag 10/112003 Casing String - ALL STRINGS Description i Size SURF CASING 9.625 PROD CASING 7.000 CONDUCTOR 16.000 Top 0 Bottom 2994 7074 115 TVD 2994 6102 115 IWt I Gradel Thread 36.ooiJ-SS I BUTmEss 26.001:.55 IBm-mESS 65.00 I H-40 I WELDED Tubing String - TUBING S,.e I Top I .o.om I Wt I Grade Thread 3.500 0 6661 5840 9.30 I L-80 8RDEUEMOD Interval TVD I Zone I StatuslEt ISPF Date I Type I Comment 6572-6609 5780-5805 IC-4,UNITBI I37 I12 15/25/1985l IPERF 15" Dressler Atlas 6724-6784 5881-5920 [ A-4~A-3 I I60 I 4 15/25/19851 IPERF 14" Dressler Atlas 6828-6832 5948-5951I A-2 I 1414 15/25/~9851 IPERF 14" Dressler Atlas 6838-6842 5955-5957I A-2 I I4 14 15/25/19851 IPERF 14" Dressler Atlas 6868-6872 5974-5976 I A-2 I I 4 I 4 15/25119851 IPERF 14" Dressler Atlas G~$:EiftM~:~d~bl~:~l:~ ::: :: : ::~::::::::: : : :::: : : : VIv Cmnt Vlv Cmnt Depth TVD Type 34 I 34 I HANGER I 500 15OOl NIP 6337 15624 I LOCATOR 6354 15636 I PACKER 6409 5672 I NIP 6454 5702I PBR/SBR Description I D TUBING HANGER SET 9/9/2003 3.500 CAMCO 'DS' LANDING NIPPLE SET 9/9/2003 2.875 BAKER LOCATOR SET 9/9/2003 2.980 BAKER FHL PACKER SET 919/2003 2.940 CAMCO 'DS' NIPPLE SET 9/9/2003 3.000 BAKER PBR WITHOUT SEALS SET 9/9/2003 2.812 :~EWEERY ORIGINAL ::i :::i : ::::: .: ;: ::: :: : :: i::: ::: DepthlTVOI 646315708I 6477 15717I 6624 158151 6624 158151 6637 158241 6638 158241 6652 158341 6659 15838I 6660 158391 Type PBR Description Baker pinned 'F' SET 4/1211985 PKR Baker 'FHL' Packer SET 4/1211985 Blast Joints SLEEVE 2.75" TPC SET 9~23~2003 NIP LOCATOR PKR NIP AVA BPL Ported Nipple SET 4/12/1985 LOCATOR SUB SET 4/1211985 SOS TTL SET 4/12/1985 Baker 'FB-I' perm. SET 4/1211985 Camco 'D' Nipple NO GO SET 4/12/1985 Brown SET 4/12/1985 ID 3.000 3.000 3.500 2.300 2.750 2.970 4.000 2.250 2.984 2.984 MEMORANDUM TO: Julie Huesser, Commissioner THRU: Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: December 2, 2000 Safety Valve Tests Kuparuk River Unit 2U Pad Saturday, December 2, 2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 2U Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 wells and 22 components with three failures observed. The Iow pressure pilots on wells 2U-5, 2U-14 and 2U-16 tripped well below the required set point. These three pilots were adjusted and retested at the time of this test. In addition to the three failed pilots several other pilots tripped very near the minimum pressure, these were reset and operated properly when retested. The 13.6% failure rate will require a retest of this Pads Safety Valve System in 90 daYs rather than the normal ~/~0~day cycle. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary: I witnessed the semi annual SVS testing at 2U Pad in the Kuparuk River Field. KRU 2U Pad, 11 wells, 22 components, 3 failures 13.6% failure rate Attachment: SVS KRU 2U Pad 12-2-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2U Pad 12-2-00 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Operator Rep: Emie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 2U Pad Separator psi: LPS 96 HPS 12/2/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2U-01 1850040! 96 70 50 P P OIL 2U-02 1850050 96 70 60 P P OIL 2U-03 1850060 2U-04 1850070 2U-05 1850180 3700 2000 . 500 3 P 12/2/00 WAG 2U-06 1850190 96 70 50 P P OIL 2U-07A 1850910 2U-08 1850210 96 70 50 P P OIL 2U-09 1850380 2U-10 1850390 96 70 60 P P. OIL 2U-11 1850400 , 2U-12 1850410 96 70~ 55 P P OIL 2U-13 1842460 96 701 50 P P OIL 2U-14 1842470 3700 2000 0 1 P 12/2/00 WAG 2U-15 1842480 96 70 60 P P ' OiL 2U-16 1842490 3700 2000 100 3 P 12/2/00 WAG , , Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.6%[~ 9o var Remarks: Three failed pilots repaired and retested Pad on 90 day test cycle 12/4/00 Page 1 of 1 SVS KRU 2U Pad 12-2-00 CS.xls STATE OF ALASKA ~-'- ALASKA ,,)IL AND GAS CONSERVATION C~,,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ...... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-39 , , 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21302 , 4. Location of well at surface 9. Unit or Lease Name 1254' FSL, 898' FWL, Sec.32, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1231' FSL, 1046' FEL, Sec.31, T12N, R9E, UM 2U-10 , At Total Depth 11. Field and Pool 1209' FSL, 1454' FEL, Sec.31, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6, Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 105'I ADL 25643 ALK 2574 , , 12'. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 04/06/85 04/1 2/85 04/12/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back DePth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7100'ND, 6118'TVD 6993'MD, 6051 'TVD YES ~ NO [] 1890 ·feet MD 1500' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, D IL/Cal/SFL/GR, FDC/CNL, RFT, VDL, CBL, Gyro, CET 23, CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT, PER FT, GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED l~~* 62.5# 'H-40 Surf 115' 24" 200 sx CS II 9-5/8" 36.0# J-55 Surf 2994' 12-1/4" 790 sx PF E & 350 sx ~F C Top ~iob performed w/5:) sx PFC 7" 26.0# J-55 Surf 7074' 8-1/2" 260 sx Class G & 250 ~x PFC , 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) · Perforated w/12 spf, 120° phasing 3-1/2" 6710' 6638' & 6477' 6572 ' -6609 'MD 5780 ' -5805 'TVD '26. ACID, FRACTURE', CEMENT SOUEEZE, ETC. Perforated w/4 spf, 120° phasing DEPTH INTERVAL(MD) AMOUNT& KIND OF MATERIAL USED 6724'-6784'MD 5881'-5920'TVD 6630'-6632' 300 sx Class G 6828'-6832'MD 5948'-5950'TVD See addendum attached to Well Completion 6838'-6842'MD 5954'-5956'TVD report, dated 9/13/85. for fracture data. . . 6868'-6872'MD 5973'-5975'TVD . . 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) I " Date of Test Hours 'Tested PRODUCTION FOR el L-BBL GAs-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 'TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED,k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c°rr) " 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 *Note: Tubing was run & the well was perforated 5/21/85. Form 10-407 Rev. 7-1-80 WC.5/15: DAN I CONTINUED ON REVERSE SIDE Submit in duplicate~,~ 29. 30. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand GEOLOGIC MAR K~-I~S TRUEVERT. DEPTH MEAS. DEPTH 6568 ' 6608 ' 6703 ' 691 2' 5777' 5804' 5867' 6001' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. See RFT data sheet attached to the Well Completion report dated 6/14/85. 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ & ~~, ~,,f.~_.,/ Tide Ass°¢iate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. ~ :~.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 ~ Telephone 907 276 1215 .. .. . R~TURN TO: ARCO KA, INC. KUPARUK OPERATIONS ENGINEERING -. R~CORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 10-31-85 TRANSMITTAL NO: 5421 TRANSMITTED HER/~WITH AR~ THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF T~IS TR3~NSMITTAL. FINALS/ SCHL/ CEMENT <ON~ * OF EACH> ~lA-3/ CEMEN~ EVALUATION TOOL -lB-4~ .CEMENT EVALUATION TOOL ~iR-1 CET/CEL -1R-12/ CET LOG ~2A-13- CBL/VDL \2A-13 / CET/CEL ~20-3-- CEMENT EVALUATION TOOL ~20-10 / CEMENT EVALUATION TOOL ~2Z-13/ CET LOG ~2Z-14~ CET LOG ~2Z-15~ CET LOG ~2Z-16-. CET LOG ~3B-4/ CEMENT EVALUATION TOOL %3B-12~ CET LOG ~B-12~ CEMENT EVALUATION LOG W/ AC ~3B-16/CEMENT EVALUATION TOOL ~3C-9 /~ CET LOG ~3C-10~ CET LOG 05-04-85 RUN #1 7468-8287 05-28-85 RUN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN ~1 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN #2 6100-6600 05-19-85 RUN #1 5450-6950 07-09-85 RUN #1 6000-8411 07-09-85 RUN #1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN #1 6100-8011 05-31-85 RUN #'1 6000-7743 07-14-85 RUN #2 6139-8089 07-06-85 RUN #1 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 I~UN #1 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: DISTkiSUTION: BPAE DRILLING*BL W. PASHEK B. CURRIEk L. JOHNSTON '' LXXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEkK*BL J. RATHMELL SOHIO UNION VAULT/ANO* FIL~IS ARCO Alaska, Inc. Post Office [ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 3B-13 2U-10 2W-12 2X-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L64 Enclosures RECEIVED SEP 1 91985 Alaska Oil & Gas Grins. Co[nrnission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfieldCompany . '. STATE OF ALASKA ALASKA,. . AND GAS CONSERVATION CC MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-39 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21302 4. Location of well at surface 9. Unit or Lease Name 1254' FSL, 898' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit ,, At Top Producing Interval 10. Well Number 1231' FSL, 1046' FEL, Sec.31, T12N, RgE, UM 2U-10 At Total Depth 11. Field and Pool 1209' FSL, 1454' FEL, Sec.31, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 105' RKBI ADL 25643 ALK 2574 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/06/85 04/1 2/85 04/12/85*I N/A feet MS LJ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7100'MD,6118'TVD 6993'MD,6051 'TVD YES I-~X NO [] 1890 feet MD[ 1500' (Approx) , , 22. Type Electric or Other Logs Run D IL/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, D IL/Cal/SFL/GR, FDC/CNL, RFT, VDL, CBL, Gyro, CET 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 115' 24" 200 sx CS II 9-5/8" 36.0# J-55 Surf 2994' 12-1/4" 790 sx PF "E" & 350 sx F'F "C" and performed top job w/5( sx PF "C" 7" 26.0# J-55 Surf 7074' 8-1/2" 260 sx Class "G" & 250 ,~x PF "C" 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) 7934' - 7974' 2-7/8" 7747' 7675' 7862' - 7916' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL UsED See attached Adde~dum~ dated 7/26/85~ for frae data. ., 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 ~AS-OILRATIO TEST PERIOD ~I~ , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co~'r) 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 Alaska 0il & Gas Form 10-407 * NOTE: Tubing was run and the well perforated on 5/16/85. GRUll/WC02 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 6568' 5777' See RFT data sheet attached to the Base Upper Sand 6608' 5804' Well Completion Report dated 6/14/85. Top Lower Sand 670:~' 5867' Base Lower Sand 6912' 6001 ' 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~L~.~ Title Associate Engineer Date ~'/~;)'~' INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 5/o6/85 6/10/85 2U-lO RU SOS. Rn VDL/CBL w/6-1/8" GR to 6971'. Rn CBL f/6963'-5500'. Rn GCT f/6942'-surf. RD SOS. Frac well in 8 stages w/284 bbls gelled diesel, 750# 100 mesh & 11,300# 20/40 mesh. Drill~ntendent I~ate ARCO Alas~;a. i Post OffIce. -~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 bATE: 8/30/85 TRANSMITTAL NO: 5305 RETUKi4 TO: ARCO ALASKA, INC. KUPARU K OPE~aTIONb RECORDS CLLkK ATO-1!15B P.O. BOX 100360 ANCHORAGE, AK 9951U ENGINEEhlNG TRANSMITTED hERL%~ITh ARE THE FOLLOWING ITU~S. RECEIPT AND RETgi~N ONE SIGNED COPY OF THIS bE~ULNCE OF EVENTS PREbbURE DATA ~ 2X-10~'PBU '~bW- 1 'ShBhP ~lT-9--PSU C SAND ~2A-2.~ PBU A ~2A-4' PBS P~ bT~S5 F~C A SAND 2A-4 PBU PRE STt<~b~ F~C a bAND '~2E-9~ PRESSURE REPORT '~ 2L-10-'PREbSURE REPORT ~2~. H~bS UP~ REPORT · 1-L--LS_~--PRESSURE REPORT ~'~2-~6- PRESSU~ REPORT ~2U-i0 PRESSURE ~PORT '~2U-it Pk~SO~ REPORT ~'2U- 16~PRESSURE REPORT ~ 2U-16 ~BOTTOM-HOLE-S~PLE ~2U-16-PBU C SAND ~2U-14~PBU A SAND ~2U-16~PBU A S~{D ~2U-14'PBU C SAND ~2W-13 PBU C SAND ~2U-16 PRESSU~ REPORT .~. RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DiST~iDgTiON: DRILLING W. PASHER L. JOHNSTON LXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RAThMELL* PLEASE ACKNOWLEDGE TRANSMITTAL. 4/25/~5 2/22185 5Ii2/85 !/24/85 12/6/84 12/28/~4 6/i3/~5 6/13/85 6/13/85 6/ 7/ 5 61 6185 5/27/85 5/27/85 5/29/85 6/13/85 6f 6/~5 6/30185 6/!6/85 6/17185 6/17/85 5/29/85 STATE OF A_LASKA* K. TULir~/VAULT ARCO Alaska. Inc. is a Subsidiary of Atlant~cRichheJdCompany ARCO Alaska, Inc.~ ~ Post Office ~_,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-20-85 TRANSHITTAL NO: 5294 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERE~{I'2H ARE THE FOLLOWING ITL~4S. PLEASE ACKNO;{LEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS / SCHLUHBERGER CET/CEMENT EVALUATIONS (ONE * OF EACH) '--~2Z-8 / CET LOG 04-26-85 '--2V-9"" CET LOG 04-25-85 '°2H-14 -"CET LOG 04-05-85 -OlR-7/CEHENT EVALUATION 06-19-85 ~{UN #1 8400-9208 RUN ~1 7000-7893 RUN ~1 7400-~700 RUN #1 4500-7033 FINAL PRINTS / SCHLUMBERGER CBL'S (.ONE * OF EACH) 3B-1/' 05-06-85 RUN #1 "'~ 2 U- 11"", 05- 03- 85 RUN #1 '~ 2U-10//05-03'85 RUN #1 "~2U-9 _w 05-02-85 RU~ %1 -~lQ-16/05-27-85 RUN #1 5040-7563 ..... 8423 5500-6963 5850-8089 4290-7018 I<ECEIPT ACKNOWLEDGED: ~PAE CURRIER ;HEVRON & M DRILLING*BL L. JOHNSTON MOBIL NSK CLERK*BL DIST~TBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL ~k:.: "~,'....,..;:, ..... ., ~..-, ~3or,s. Commission :,, ~l'acje STATE OF ALASKA*BL SOHIO /SE UNION K. TU LIN/VAU LT* FI LMS ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-08-85 TKAN:~MITTAL NO: 5285 ~,ETURN TO: ARCO ALASKA, INC. KUPAI{UK OPERATIONS ENGINEEkING ~ECOHD5 CLE Pd< ATO-1115B P.O. BOX 100360 ANCHOI{AGE, AK 99510 EHANSMITTED HERE~{ITH ARE THE FOLLOWING IT4/4S. ~ ACKNO~{LEDGE {ECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. iN BOX 1 OF 2: 3PEN ~OLE LIS TAPES PLUS LISYINGS (ONE COPY OF EACH) .~C-11 06-23.-85 RUN #1 4427.5-8881.5 REF ~70597 3C-10'" 07-02-85 RUN ~1 1785.0-8987.5 I~EF #70620 3C-9~' 07-10-85 HUN #1 3920.0-8332.5 REF ~70642 ]C-7~ 07-31-85 RUN #1 4617.5-8747.5 REF #70706 3B-14-- 03-20-85 RUN #2 3280.0-6803.5 R~F #70229 3B-12" 07-03-85 RUN ~1 4021.5-8261.5 kEF #70641 3B-11~ 06-26-85 RUN ~1 2190.5-9257.0 REF #70598 ~B-10' 06-17-85 RUN #1 3273.0-7270.5 REF #70555 3B-9-"' 06-10-85 RUN #1 2092.0-8415.0 REF #70634 2Z-15" 06-19-85 RUN ~1 2658.0-6620.0 REF #70562 '!Z-14/ 06-28-85 RUN #1 3876.0-8334.0 REF ~70600 !Z-13~ 07-05-~5 HUN #1 4180.0-8538.5 REF #70639 !Z-12-- 07-20-85 RUN ~1 4409.0-9412.5 REF ~70661 !Z-11,* 07-27-85 HUN #1 3531.5-7534.0 I~,EF #70704 SOX 2 OF 2: ~PklN, HOLE LIS TAPES PLUS .W-16~/ 01-28-85 RUN # .V-14// 05-16-85 iV-12~/ 04-22-85 ~.U 10~ 04-11-85 U-7w* 03-19-85 a-13-,'~ 07-16-85 R-13'/ 07-27-85 R-12 ~ 07-20-85 .R-11'~'~ 07-13-85 ~R-10~''/ 07-06-85 .R-9// 06-28-85 !{-7/ 06-04-85 LISTINGS (ONE COPY OF 1 3116.0-7038.5 RUN %1 3047.0-7086.5 RUN ~1 3960.0-9265.0 RUN #1 2972.0-7063.0 P, UN #1 3594.5-8179.5 HUN #1 7649.5-8160.0 kUN #1 3940.0-8578.0 RUN ~1 3935.0-8277.5 RUN #1 3810.0-7213.5 RUN #1 2991.0-8738.0 RUN #1 3991.5-8131.0 RUN #l&3 0045.5-7103.0 EACH ) REF #70436---KEVISED F, WF ~ 7 U 614---i{EVI SED REF # 70613---I{EVISED REF # 70612---kEVISED REF # 70505---iiEVlSED -' R~F #70645 REF # 70702 REF #70660 RWF #7(3643 t{EF #70640 REF #70601 kEF ~70509 ECEIPT ACKNO%~LEDGED: PAE · CURRIER iEVRON & ~4 D~ILLING L. JOH~STON NOB.IL NSK CLERK DIST?,IBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL AUs 5 DATE: ~.t~.~ n~,_. ~-~ :,--~,.~ .... Cons. Commission STAT~ OF ALASKA*"' ~ SOHIO UNION K.TULIN/VAULT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Alaska Oil and Ca~ C - ...... , o ...... x .... on Commission 3002 Porc. ni~m Drive Anchorasc, Ah[:]m 9;)50I RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION DATED: Copy sent to sender YES NO ~: STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION COn~ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of .~Jaska Alaska Off and Ga.: Conservation Commission 3001 Porcupine Drive ~chorage, M~ka' 99501 Receipt of the following material which was transmitted via /~/~, f./ is hereby acknowledged: 9UANTITY DE S CRI PT I ON RECEIVED: DATED: Copy sent YES to sender N0 Y- -. N~'W PROJECTS ' ENGINEERING T~SMITTAL t~ FI~M'. L. K. SMITH/?. S. ~BAXTEI~ TRANSMITTED H~TH AM.E THE FOLLOWING: P'L~E NOTE: BL- BL~I~, S - $~, F - F~, T ' ~" ~ ~ '~~ ~' ~" ~~~~O_~_..=_.-- A~N: PATS~ S. B~~ P. O. BOX 100360 ~.O~GE, ~ 99510 .. ARCO Alaska, ir?-'~' Post Offic~ ,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE' 07-16-85 TRANSMITTAL NO:5247 RETURN TO: TRANSMITTED RECEIPT AND ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO- 1115B P.O. BOX 100360 ~ ANCHORAGE, AK 99510 HEREWITH ARE THE FOLLOWING ITEM CKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE FINAL (ONE * OF EACH) lQ-15 ....... 5" 2" 5" 2" 5" 2" PRINTS/SCHL DIL/SFL-GR DIL/SFL-GR DEN/NEU-GR DEN/NEU-GR DEN/NEU-GR DEN/NEU-GR CYBERLOOK PORO PORO RA%~ RAW 2U-10 /5" 2" 51! . 2" 5" 2" DIL/SFL-GR DIL/SFL-GR DEN/NEU DEN/NEU DEN/NEU DEN/NEU CYBERLOOK RFT LOG PORO PORO RAW RAW 05-12-85 RUN 05-12-85 RUN 05-12-85 RUN 05-12-85 RUN #1 05-12-85 RUN 05-12-85 RUN 05-12-85 RUN 04-11-85 RUN $2 04-11-85 RUN 04-11-85 RUN 04-11-85 RUN 04-11-85 RUN 04-11-85 RUN 04-11-85 RUN 04-11-85 RUN $2 4416-8714 4416-8714 4416-8689 4416-8689 4416-8689 4416-8689 8000-8689 2994-7034 2994-7034 6350-7008 6350-7008 6350-7008 6350-7008 6350-6985 6575-6869 2U-ll 5" DIL/SFL-GR 2" DIL/SFL-GR 5" DEN/NEU 2" DEN/NEU 5" DEN/NEU 2" DEN/NEU CYBERLOOK PORO PORO RAW RAW 04-17-85 RUN $1 04-17-85 RUN 04-17-85 RUN $1 04-17-85 RUN 04-17-85 RUN 04-17-85 RUN $1 04-18-85 RUN $1 3767-8472 3767-8472 6000-8449 6000-8449 6000-8449 6000-8449 8000-8390 RECEIPT ACKNOWLEDGED BPAE B. CURRIER CHEVRON D & M*BL A!aska Oil & Gas Cons. Commission Anchorage DISTRIBUTION~ DRILLING*BL .W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK*BL J. RATHMELL*BL STATE OF ALASKA*BL SOHIO /SE UNION K.TULIN/VAULT*FILM ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComDany NE~ PROJECTS ENG~NEEP, ING ~RANSMITTED H~TH AiLE THE FOLLOWING: PI~E NOTE: BL- BLUELINE~ $ - SE'P--lA, F-' F~, T ' TAPE, PC ' PROTOCOPY P, ZCEZFT AC~OWn~DCZD ~ ~PL~$Z P,z'"r~ ~cz~.Pz TO: . ~/ ATTN: pATsy S. BAXTEX ATOIS0? P. O. BOX 100360 ANCP, OKAGE, AK 99510 .. RETURN TO: · AR C~"~laska, Inc. .~st Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 PAGE ARCO ALASKA, INC. KUPARUK OPER~XTIONS ENGINEERING RECORDS CLERK ATO-11!5B P.O. BOX 100360 AK 99510 · A~HORAGE, ~nTE: 06-19-85 TRANSMITTAL NO: 5230 2 OF 2 TRANSMITTED HEREWITH ARE RECEIPT AND RETURN ONE S ***CONTINUED. FROM PREVIO '2D-5 2D-3 2D-3 2E-9 2E-13 2E-!4 2E-i5 2G-1 2H-1 2H-15 2H-1 2H-3 2H-4 2H-i 4 2U-5 2U-6 2U-7 2U-8 2U-9 2U-iD 2U-16 2U-16 2V-10 2V-!! ' 2V-!i 2W-13 2X-!2 2Z-2 THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE IGNED COPY OF THIS TRANSMITTAL. US PAGE*** FLOWING BHP ETC 05-06-85 ACID JOB PREP 05-0 7-85 ACIDIZE 'C'SD 05-11-85 G.R. SBHP 06-11-85 SBHP 06-10-85 SBHP 06-10-85 SBHP 06-09-85 FLOWING BHP 04-2 9-85 BHP&TCL 05-27-85 SBHP & ETC. 04-29-85 BHP & ETC. 05-23-85 BHP & ETC. 05-23-85 COMP BHP 05-23-85 INT. SBHP&ETC 04-28-85 SBHP 05-02-85 SBHP & TCL 05-0 3-85 SBHP PRE PROD 05-04-85 SBHP & ETC. 05-04-85 PRESSURE TEST 05-27-85 BHP SAMPLE 06-05-85 'A'SD FLUID ID 06-09-85 PBU 06-07-85 BHP & ETC. 05-17-85 STATIC 05-12-85 STATIC 05-23-85 'C'SD ACID STIM 05-20-85 'C'SD ACID JOB 05-12-85 E/LINE FLUID ID 05-03-85 CAMCO BAKE R DOWELL OTIS OTIS OTIS OTIS CAMCO OTIS OTIS CAMCO OTIS OTIS OTIS CAMCO CAMCO CAMCO BAKER/cAMco OTIS OTIS OTIS OTIS OTIS OTIS OTIS DOWELL DOWELL OTIS/CAMCO RECEIPT ACKNOWLEDGED: B PAE * B. CURRIER CHEVRON* D & M /..'j/' _-., ~ ,. /~ ": ,. / DATE: DISTRIBUTION: DRILLING W. PASTIER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATH>~ELL STATE OF ALASKA SOHIO* UNZON* K.TULIN/VAULT ARCO Alaska. I.c. is a Subsidiary of AtlanticRichfieldComl~any ~E-Q ~ROJECTS ENGINEEEING · TAA~ S~ITTAL ~ ~, O,.S S ~ ,, F~0M: L. K. E'~ITEIT. S. BAIIEE ~ , __ i R-'-) TR.~Sl~iI~ HEEEWITN ARE TEE FOLLOWING: NOTE: BL- BLAINE, $ - SEPIA, F - TILI~, T- TAPE, PC - PROTOCOPT ~N: P~SY S. B~~ ATO/507 ~m:hor~t~ ~. O. BOX 100360 ~O~GE, ~ 99510 . .. RECEIPT ACKNOWLEDGED: PLEASE EETURN RECEIPT TO:~-"~CO INC. ARCO Alaska, Inc. iPost Office 9ox ,00360 A.~ch©rage, Alaska 99510-0360 :Telephone 907 276 t215 June 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2U-10 Dear Mr. Chatterton. Enclosed is a copy of the 2U-10 Well History (completion details) to include with the Well Completion Report, dated 06/14/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L87 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 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 submitted 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. District Alaska Field County or Parish Lease or Unit Tit e Kuparuk River North Slope Borough Accounting cost center code State Alaska ADL 25643 IWell no, 2U-10 Auth. or W.O. no. AFE 603511 Completion WWS #l Operator ARCO Alaska, Inc. Spudded or W.O. begun API 50-029-21302 Complete Date and depth as of 8:00 a.m. 5/22/85 Complete record for each day reported A.R.Co. W.I. 56.24% Date 5/16/85 I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prior status if a W.O. 0030 hrs. I 7" @ 7074' 6993' DPM, RR Kuparuk Crude Drop ball, set pkr, shear PBR. Set BPV, ND BOPE, NU & tst tree. Displ well to crude. RR @ 1530 hrs, 5/~2'/85. SSSV @ 1795' -Retrv pkr @ 6477' Old TD Released rig 1530 hrs. Classifications (oil, gas, etc.) O±l Producing method.' New TD Date PB Depth ~.,,/ IK nd of rig 5/.2~ 85 I Rotary Type completion (single, dual, etc.) · .... ~ng~e.. · Official reservoir name(s) ~Flowin. g Kuparuk. Sands Potential test data' ~'i ~ ?~1', {i-~ ~, ' ; ~]' ?-~ }~'~ Pf%du~cfO Well no. Date Reservoir Producing Interval Oil or gas Test time Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity .< ¢llq~,wal~le E~ffo,ct~lye-d~ate~, The above is correct .~lr~l' ~.~~ IDate 6/07/85 Signature ITitle #, For form preparation an~distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: 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 Alaska Field Kuparuk River Auth. or W.O. no. AFE 603511 ICounty, parish or borough North Slope Borough Lease or Unit Tme ADL 25643 Completion State Alaska IWell no. 2U-10 wws #1 API 50-029-21302 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete IDate ]Hour 5/16/85 Date and depth as of 8:00 a.m. 5/16/85 5/17/85 5/18/85 thru 5/20/85 5/21/85 iComplete record for each day reported 0030 hrs. ARCO W.I. Prior status if a W.O, 56.24% 6993' DPM, RD DA 10.2 ppg NaC1/NaBr Accept rig @ 0030 hrs, 5/16/85. ND tree, NU & tst BOPE. DA, RIH, perf 6630'-6632'. RD DA. RU 7" @ 7074' 6993' DPM, WOC 10.2 ppg NaC1/NaBr TIH w/Champ pkr & set @ 6356'. M&P 200 sx C1 "G" w/.8% D-60, .2% D-46 & 3% KC1. Sqz cmt @ 1/4 - 1/2 BPM/ 1200 psi initial sqz pr'ess & 1600 psi final sqz pressure. Open bypass'& rev, POH. PU bit/scrpr, RIH to 5500', circ & WOC. 7" @ 7074' 6993' DPM, Perf'g 10.2 ppg NaC1/NaBr WOC. RIH w/bit. Drl stringers & cln out f/6367'-6979'. Tst csg; leakoff @ 1BPM, 1750#, POOH. RIH w/Howco Champ pkr, set @ 6360'. Pmp 100 sx C1 "G" cmt w/3% KCl, .8% D-60 & .2% D-46. Rev circ, POH, WOC. Rn bit/scrprs. Drl firm cmt f/6380'-6550', soft cmt f/6550'-6701'. Tst csg; OK. POH, RU SOS. RIH, log GR/CET. RIH & perf 6670'-6672', POOH. PU Howco Champ pkr, RIH, set @ 6420'. Tst ann; OK. Att to est IR w/3000 psi; no IR on 1st or 2nd att. POOH, LD Champ pkr. RU DA, RIH w/perf gun #1. 7" @ 7074' 6993' DPM, Space out 10.2 ppg NaC1/NaBr RU WL. RIH w/4" csg guns, 4 SPF, 120° phasing. Perf 6872'-6868', 6842'-6838', 6832'-6828', 6784'-6724'. RIH w/5" csg guns, 12 SPF, 120° phasing. Perf 6609'-6572'. RIH w/WL pkr & tailpipe assy, set @ 6638'. RIH w/3½" compl string. The above is correct For form preparation and distributing-ii see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate 6107185 jTitle DrilltnA Superintendent ARCO Alaska, Inc. Post Office tg~x ~00360 .Anchorage, Alaska 99510~0360 Telephone 907 276 1215 June 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-10 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 2U-10. I have not yet received a copy of the well history summarizing 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 GRU9/L88 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA L ? AND GAS CONSERVATION CO AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-39 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21302 4. Location of well at surface 9. Unit or Lease Name 1254' FSL, 898' FWL, Sec.32, T12N, RgE, UM ~ · Kuparuk River Unit ;LOCATIONS, At Top Producing Interval , VEi~iFIED ! 10. Well Number 1231' FSL, 1046' FEL, Sec.31, T12N, RgE, UN . ~r~ ._ 2u-1 0 At Total Depth Surf. l/ 11. Field and Pool 1209' FSL, 1454' FEL, Sec.31, T12N, RgE, UN B.H. ~ .......... __ r Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 105' RKBJ ADL 25643 ALK 2574 12. Date Spudded04/06/85 13. Date T.D. Reached04/1 2/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re I 16' N°' °f C°mpleti°ns 104/12/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set ] 21. Thickness of Permafrost 7100'MD,6118'TVD 6993'MD,6051 'TVD YES I-~X NO [] 1890 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D I L/GR/SP/LSS, LDT/CNL/NGT/EPT, SHDT, D I L/Cal/SFL/GR, FDC/CNL, RFT, VDL, CBL, Gyro, CET 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 115' 24" 200 sx CS II 9-5/8" 36.0# J-55 Surf 2994' 12-1/4" 790 sx PF "E" & 350 sx 'F "C" and performed top ,iob w/5~ sx PF "C" 7" 26.0# J-55 Surf 7074' 8-1/2" 260 sx Class "G" & 250 x PF "C" 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) 7934' - 7974' 2-7/8" 7747' 7675' 7862' - 7916' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OILRATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c°rr)" Press. 24-HOUR RATE ~1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10407 * NOTE: Tubing was run and the well perforated on 5/16/85. TEMP/WC30 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 6568' 5777' See attached RFT data sheet. Base Upper Sand 6608' 5804' Top Lower Sand 6703' 5867' Base Lower Sand 6912' 6001 ' 31. LIST OF ATTACHMENTS Cvrn.~.nnim. ~rv~.v ~? ~nni~) RFT d~a 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ _~~ Title A,,ooiate E,g]neeF Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 .r 2U-10 RFT Data 6575 6590 6602 6727 6742 6757 6774 6831 6863 Hydro. Pressure 3160 psi 3164 psi 3157 psi 3199 psi 3197 psi 3189 psi 3200 psi 3223 psi 3221 psi Shut-in Pressure 2924 psi 2926 psi 2929 psi 3014 psi 3100 psi 3012 psi 3033 psi 3065 psi 3375 psi TEMP/WC3Ob.tw ARCO Alaska, Inc. ~ Post Office Box '~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 12, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2U-10 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 2U-10. The bottomhole location, geologic markers, and TVDs will be submitted when the gyroscopic survey is received. Also, I will forward a copy of the Well History (completion details) to you when I receive it. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU9/L54 Enclosure RECEIVED Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ..... ALASKA C._. AND GAS CONSERVATION COI~ ,ISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ..... ,,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-39 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21302 , '"4. Location of well at surface 9. Unit or Lease Name 1254' FSL, 898' FWL, Sec.32, T12N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2U-10 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 105' RKBJ ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 04/06/85 04/1 2/85 04/12/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7100'MD 6993'MD YES [] NO I~X 1795 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/GR/SP/LSS, RFT, LDT/CNL/NGT/EPT, SHDT, D IL/Cal/SFL/GR, FDC/CNL, CBL/VDL, GR/CET 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 115' 24" 200 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2994' 12-1/4" 790 sx Permafrost E & z.00 sx Permafrost C 7" 26.0# J-55 Surf 7074' 8-1/2" 260 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) 6868' - 6872' 3-1/2" 6710' 6638' & 6477' 6838' - 6842' w/4 spf, 120° phasing 6828' - 6832' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6724' - 6784' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6630' - 6632' 300 SX Class G 6572' - 6609' w/12 spf, 120° phasing . 27. N/A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) , DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ]~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None I?, F C E!V E D , Alasi~a Oii a gas Cons, Cor;~missior~ Form 10-407 * NOTE: Tubing was run & the wel 1 perforated 5/21/85. GRUg/WC15 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 6568' N/A N/A Base Upper Sand 6608' N/A Top Lower Sand G703' N/A Base Lower Sand 6912' N/A ,,4 31. LIST OF ATTACHMENTS Well History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~ ~~¢.Jt~/ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas CompanY Well History - Initial Report - Daily Instructione: 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 ICounty, parish or borough Alaska ] North Slope Borough Field Lease or Unit Kuparuk River ADL 25643 Auth. or W.O. no, ~Title AFE 603511 I Drill State Alaska IWell no. 2U-10 Doyon 9 API 50-029-21302 Operator ARCO Alaska, Inc. Spudded OrspuddedW.O. begun JDate 4/6/85 [Hour Date and depth as of 8:00 a.m. 4/06/85 to 4108185 4/09/85 . : ~., i~ :: · :::-'::~, 4/10/85 4/11/85 · . Complete record for each day reported 0300 hr. IARCO W.I. · 56 24% IPrlor status if a W.O. 9-5/8" @ 2994' 3015', (2900'), Tst csg Wt. 9.9, PV 27, YP 28, PH 8.5, WL 7.8, Sol 13 Accept rig @ 0001 hrs, 4/6/85. NU diverter sYs. Spud well @ 0300 hrs, 4/6/85. Drl & surv 12¼" hole to 3015', POH. RU SOS f/West Sak logs. Rn DIL/GR/SP/LSS, LDT/CNL/NGT/EPT (+ High Resolution rn) & SHDT f/3015'-1400', RD SOS. RIH, C&C mud, POH. Rn & lnd 68 jts, 9-5/8", 36#, J-55 BTC csg @ 2994', FC @ 2905'. Cmt w/790 sx PF "E", followed by 350 sx PF "C". Displ using rig pmps. Bump plug. CIP @ 0550 hrs, 4/85/85. No cmt to surf. 485', .16° 1004', .26° 1465', .10° 2024', 1.19°' 2498', 1.48° 9-5/8" @ 2994' 3587', (572'), Navi-Drl Wt. 8.7, PV 3, YP 2, PH 9.5, WL 14.8, Sol 3 ND diverter sys. Perform top job w/50 sx PF "C". NU & tst BOPE. RIH w/BHA to FC, tst csg to 1500 psi. DO cmt, flt equip + 10' new hole. Conduct formation tst to 11.5 ppg EMW. PU Navi-Drl, drl & surv 8½" hole to 3587'. 3402', 7.2°, N63W, 3401TVD, 14 VS, 7N, 14W 9-5/8" @ 2994' 6465', (2878'), Drlg Wt. 9.6, PV 9, YP 10, PH 0, WL 8.0, Sol 9 Navi-Drl f/3587'-5007', drl f/5007'-6465'. 3624', 12.5°, NS1.7W, 3620 TVD, 51VS, 19N, 50W 4100', 27.3°, N86.1W, 4066 TVD, 212 VS, 32N, 211W 4604', 42.8°, S86.5W, 4481TVD, 495 VS, 24N, 495W. 5263', 48.7°, N88.7W, 4930 TVD, 976 VS, 22N, 976W 6198', 48.3°, S88.6W, 5548 TVD, 1677 VS, 20N, 1677W 9-5/8" @ 2994' .7033', (568'), POH to log. ~'~" ~-~'~ ..... i i~;?i~'~' Wt. 10.2, PV 12, YP 14, PH 9.5, WL 5.0, Sol 14 !~.~ t~ & surv to 7033'. s,ort to 000'. = POH f/logs. 5263' 48.7° N88 7W, 4930 T~ 976VS, 22N, 975W j~j~ ~ ~ ~" , , · , ~ ~ 5728', 48.8°, S89.7W, 5237 T~, 1325VS, 25N, 1325W 6198', 48.3°, S88.6W, 5548 T~, 1677VS, 20N, 1677WAlask~ 0il & G;:[S C0[1S~ 6515' 48.3° S88W, 5759 T~, 1913VS, 13N, 1914W ' ' Anchorage 6975', 52~, Sg0W, 6053 T~, 2266VS, 6N, 2267W The above is correct Signature r o P p - - ' -at~ -butlon, Fo fr see Procedures Manua~Section 10, Drilling, Pages 86 and 87. Date ] Title 5120/85 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 submitted 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. District ICounty or Parish Alaska Field Lease or Unit Kuparuk River ADL 25643 Auth. or W.O. no. Title AFE 603511 Drill IAccounting cost center code State Alaska IWell no. 2U-10 North Slope Borough Doyon 9 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 4/6/85 Date and depth Complete record for each day reported as of 8:00 a.m. 4/12/85 4/13/85 5/06/85 API 50-029-21302 I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our IPrior status if a W.O. I 0300 hr. 9-5/8" @ 2994' 7100', (67'), POH, LD DP Wt. 10.2, PV 12, YP 14, PH 9.0, WL 4.8, Sol 14 RU Schl, rn DIL/CAL/SFL/GR f/7034'-2994', FDC/CNL f/7008'-6350', RFT f/6869'-6575'. RIH to 6896', rm 6896'-7033', drl 8½" hole to 7100', C&C, POOH & LD DP. 7" @ 7074' 6993' PBTD, RR LD DP. Rn 166 its, 7", 26#, J-55 BTC.csg to 7074', FC @ 6993'. M&P 260 sx Cl "G" cmt w/l% CFR-2, 5% KCl & 3% Halad-24. Displ w/10.2 ppg brine, bump plug. CIP @ 1845 hrs, 4/12/85. Lost rtns last 40 bbls. CIP @ 1845 hrs, 4/12/85. Tst csg to 3000 psi. Set slips, cut csg, instl pack-off, tst seals. RR @ 2200 hrs, 4/12/85. RU SOS. Rn VDL/CBL w/6-1/8" GR to 6971'. Rn CBL f/6963'-5500'. Rn GCT f/6942'-surf. RD SOS. Old TD I New TD I Released rig ~ Date I 2200 hrs. Classifications (oil, gas, etc.) Oil 7100' (4/11/85) .S Depth 4/12/85 Kind of rig IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test 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 _ For form-- preparation- ~d distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date 5/20/85 [Title Drilling Superintendent $ UB-$ URFA CE DIRECTIONAL SURVEY ['~1 UI DANCE I C'~, ONTINUOUS ~'~OOL Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY 2I~-~0 (~254' FSL. 898' FWL. S32. Tt2N. RqF.. ~5 KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 7o~3 Locj~3ed By: J. CRYER Date 22-MAY-1985 Computed B~: CUDNEY ~C? ~IR~TIONAb 8URV£¥ CUSTOMER LISTING FOR ARCO ALASKA, INC. 2U-10 KUPARUK NORTH 8bOP£,AbASKA SURVEY DATEI 3 MAY 85 ENGINEER! d,; CRYER METHODS OF COMPUTATION TOOL LOCATION: TANGENTfAL- averaged deviation and azimuth TNTERPObATION: I, INE~R V£R?ICAt SECT~ON~ HORTZ, PIST, PROdECTED ONTO A TARGET AZIMUTH OF NORTH 88 PEG 13 HIN WEST ARCO 2U'10 KUPARUK NORTH SLDPEwALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0 O0 0 O0 oo:oo oo:,oo 00.00 200,00 '~00.00 300.00 400,00 400,00 500.00 500,00 600,00 600,00 700.00 699,99 800,00 799,90 900.00 899,90 COMPUTATION DATE{ 29-MAY-85 PAGE DATE OF SURVEY: 3 MAY 85 KELLY BUSHING ELEVATION{ ENGINEER{ J, CRYER INTERPODATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 0 N 0 0 E 0,00 O8 N 46 39 ~ 0,01 0 lO S 54 31 E 0.00 0 11 S 58 21E -0,~8 0 lO S 8 29 W , 0 15 S 24 13 E , 0 5 S 10 58 W ,42 0 15 S 32 26 W -0,26 0 15 S 51 27 W 0.02 -105,00 -5 O0 95 O0 195 O0 295 O0 395 O0 495 O0 594 99 69~,99 79 .99 0 16 $ 54 34 W 0 2O S 54 3 W 0 27 $ 48 34 W 0 28 S 4O 54 w 0 20 S 34 6 W 023 S 42 4 W 0 29 S 48 ~ ~ 0 40 S 61 3~ ~ 0 42 S 84 1 ~ 0 52 N 74 47 E 1000,00 999 99 894,q9 10~,00 1099 99 994,99 ~20 .00 1199 99 1094.99 1300 00 i299 98 1194.98 1400 O0 1399 9~ 1~94.98 1500 O0 1499 98 1394,98 1600 O0 1599 98 1494,98 1700 O0 1699 97 1594,97 1800 O0 17q9 96 1694,96 i900 O0 1899 95 1794,95 1894,93 1994.00 ~ 2094.85 194.79 74 ~94.74 69 2394.69 66 2494,66 63 2594,63 79 ,59 I 24 N 54 I E 29 , 56 18 E 1 54 H 51 46 E 2 0 N 52 55 g ! 55 N 55 4O £ 1 29 N 56 4 E 1 21 ~ 51 27 g 1 lq N 49 1 14 . 49 46 E 0 55 N K3 4O E lO00O0 1999 100:00 2099 2200 O0 ~199 2300 O0 ~299 2400 O0 2399 2500 O0 2409 2600 O0 2599 2100 O0 2699 2800 O0 2799 2900 00 2899 0 54 56 0 43 56 0 35 45 4 99 7 0 90 9 25 ~1 11 48 43 15 17 O8 18 18 25 21 6 3000,00 2909 57 2894 57 3100 O0 3099 56 2q94 3200:00 3199 56 3094 3300,00 3209 45 3194 3400,00 3398 99 3293 3500 O0 3497 90 339'2 3600 O0 3596 21 3495 3700 O0 3693,43 3588 3800 O0 3789,08 3684 3900 O0 3883,25 3778 0 34 0 77 1 32 ! 88 2 36 2 81 2 68 1 77 0 60 -0 67 -2 48 -4 51 -6 79 -9 44 -12 '20 -14 70 -16,68 -18,47 :20,13 2i,58 '22,86 '24,04 '24,80 '2~,20 '1~,56 1,12 18,87 41.95 70,95 i04,58 0 O0 0 83 0 19 0 05 0 11 0 ~ 0 06. 0 24 0 06 0 12 0 04 0 05 0 22 0,26 0,52 0,1~ 0 3 o.]? O, l 0 66 0 73 0 25 0 49 0 3i 0 Ii 0 5! 0 18 0,36 0 75 3 30 1 67 3 48 2 72 2 89 3 71 0,.00 N 0.00 E O,09N 0,00 W ~ 0,09 $ 0,00 W .i 49 S 0,34 g 0 o. o o 90 S 0,36 g 1 31 S 19 E 65 $* 10 W 105,00 09 N 2 48 W 4~ 23 W 60 $ 34 40E 99 $ 11 2~ ] 49 $ 11 3~ 93 $ 10 41E 32 $ 4 38 g 65 S 2 12 ~ 2938 41~8 $ 4 5 $ 5 1 S 6 ~0 S 6 070 S 7 3 S 6 96 S 0 43 W 0 87 W 1 44 W 20~ w 2 51 w 2 98 W 2 88 W 9 8 w 82 W 0 45 E 2,96 S 8 17 W 3,97 8 2 W $ 25 4 4,73 W 5,56 $ 26 53 W 5 S 28 97 8 3 43 E 5 88 S 4448 2768 0 55 S I 42 N 3 12 N 4 59 N 6 10 N 7 59 N 8 78 N 2 30 E 4 39 E 6 71 E 9 43 E 12 25 E 14 80 g 16 83 E 18 67 E 20 38 E 21 87 E 6 6 7 9 12 15 17 19 21 23 8 36 g 25 $ 67 36 E 45 S 86 38 E 33 N 83 24 E 13 N 78 f 45 N 74 45 g 64 N 7! 53 E 75 N 69 34 E 56 N 68 7 g 9 73 n 10 42 N 10 75 N 12 99 M 17 07 N 22 93 N 27 61N 31 80 N 34 77 N 23.17 ~ 25 13 N 67 13 E 24 38 E 26 51 N 66 51 E 25 15 g 27 35 N 66 51 g ~1 61 g 25 21 N 58 59 E 13 10 E 21 51 N 37 29 E 0 41 W 22 93 N 1 1 W 18 03 W 32 97 N 33 8 W 40 98 ~ S! 07 N ~! It N 69 90 w 78 07 N W 29 N ~03 51 W 109 69 N 40 W 36 0 O0 N 0 OE ARCO AEASKA, INC, 2U-10 KUPARUK NORTH SLOPE,AhASKA ?RU£ 8UB-$ER COURSE MERSUR~D VERTICAL VERTICAb DEVIATION AZIMUTH DEPTH D£P?H DEPTH DEG MIN DEG MTN COMPUTATION DATE; 29-MAY-85 PAGE 2 ATE Or SURVEY1 3 ~AY 95 EbbY BUSHING EbEVATIONI. ENGTNEERI d, CRYER [NTERPOLATED VA[,UE5 FOR EVEN t00 FEET OF HEASURED DEPTH VERTTCAb DOGbEG EECTANGUbAR COORDINATES HORI[' DEPARTURE SECTION SEVERITY NORTH/SOUTHEAST/WEST DXST,~ AZZMUTH DEC/lO0 FE£T FEET FEET DEG MIN 4000 O0 3995 50 3870.50 24 16 4100 O0 4065 45 3q60.45 27 31 4200 O0 4152 87 4047,87 30 29 4300 72 4132.72 13 24 4400 4~00 4600 4700 O0 4237 O0 ~319 00 398 O0 1492 O0 .544 O0 4613 O0 4681 6 4214,56 36 42 4293,09 39 51 4367,98 43 3 3 4439,53 45 23 78 4508,98 46 59 20 4576,20 47 55 FEET N 87 25 W 143,13 ~ 89 27 ~ 186'76 ~ 88 8 W 235,27 S 86 7 W 287,97 $ 84 34 W 345,03 S 84 27 W 406,39 S 85 21W 472,19 S 86 49 W 541,65 S 89 16 W 613,63 S 89 34 W 687'43 4800 4900 5000 O0 4747 95 464~ 95 48 39 5i00 O0 4813 72 4708 72 48 45 O0 4879 O0 4945 O0 5010 O0 ~07'5 O0 5140 O0 5206 O0 5291 00 5336 67 4774 49 4840 85 4005 71 497O 84 5035 19 5101 4~ 5166 60 5231 67 48 44 48 58 71 49 31 84 49 16 19 49 10 43 49 19 60 49 23 S 89 46 W S 89 32 W 839 S 89 48 W 912 S 89 56 W 987 $ 89 43 W 1063 S 89 26 w 1139 S 89 12 W 1214 S 89 0 W 1290 $ 88 40 w 1 366 S88 13 W 1442 761,84 48 ~8 .08 59 28 O0 5400 5500 5600 5700 5800 5900 S 87 47 W 1517 64 S 87 22 W 1593 03 S e6 54 w 1668 10 S 86 27 W 1742 66 S 8b 24 W 1817 28 5 ~6 n w 1891 93 S 86 9 W 1965,7~ S 86 18 W 2040,08 S 86 24 W 2115,71 $ 87 0 W 2193,06 6000 O0 5401 82 5296,~2 ag 11 6100 O0 5467 29 5362,29 49 0 6200 O0 5533 07 5428,07 48 36 6t00 O0 5599 37 5494,37 48 27 6400 OO 5665 58 5560,58 48 40 6500 O0 5731 7! 5626,7! 48 17 6600 O0 5798 83 5693,83 47 53 6700 O0 5865 28 5760,~8 48 43 6800 O0 5930 31 5~25,31 50 14 6900 O0 5993 30 5888,30 51 24 6055,43 5950,43 51 32 6117,62 6012,62 51 32 $ 87 43 W 2271,20 S 87 43 W 2349,32 7000,00 7100.00 I 1° 8 3 22 3 10 67 26 1 72 0 28 40 0 ~5 0 52 0 56 0 69 0 40 ,30 ~,44 0,84 °:Ilo 1,37 97 20 0,00 0,00 ~8 33 N 142 O0 W 147 39 41 N 185 63 W 189 95 N 237 89 31 25 19 14 12 11 49 N 344 35 N 405 62 N 471 47 N 541 20 N 613 63 N 687 9 W 2 I W 345 ~0 W 406 81 W 472 46 W 541 54 W 61. 3 40 W 687 11 32 N 76 1 10 74 N 837 10 10 9 9 8 7 5 3 32 N 912 18 N 981 98 N 106 45 N 11t9 58 ~ 5 37 N 1 0 87 N 1~6 80 N 1442 1 2 5 10 14 19 24 29 34 39 79 S 1669 14 $ 1743 80 S 1818 71S 1893 63 S 1967 65 8 2041 43 S 2117 02 S 2195 105,00 -FI 86 W 761 94 N 89 8 W W 9i2 64 W 987 32 w t063 43 W 1139 30 W 1215 76 W 1 . 58 w i442 25 N 89 i5 W 4i N 89 21 ~ 69 N 89 24 W 36 N 89 27 W 47 N 89 31W 33 N 8935 W O, N 89 40 W 77 N 89 45 W 58 N 89 50 W 34 W 151 86 W 159~ 09 W 1669 81W 1743 6i W 1818 46 W 1893 43 W ~967 99 w 2042 81 w 2118 33 W 2195 4 N 89 ~7 W 6 S 89 5 W 10 S 89 48 W 84 S 89 40 w 67 S 89 32 ~ 56 $ 89 24 ~ 59 $ 89 1~ .~ 20 S 89 lO W 09 S 89 4 W 67 S 88 58 ~ 42,32 S 2273,61 W 2274,0! 8 88 56 W 45,42 S 2351,86 W 2352,30 S 88 53 W N 4 53 W N ~8 0 W ' N 8O 33 W N 82 47 W 5 N 84 46 W 9 N 86 25 67 N 88 51W 50 N 89 I W ARCO ALASKA, TNC. 2U-10 KUPARIIK NORTH SLOPE,ALASKA CONPUTATION bATE{ 29-NAY'85 DATE OF SURVEYI 3 MAY 85 Kg[,bY BUSHING E~EVATION{ ENGINEER{ d, CRYER INTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPT TRUE SUM-SEA COURSE MEASURED VERTICAL VERTICAL DEV)ATION AZIMUTH DEPTH DEPTH DEPTH PEG MIN DEG MIN 0,00 0 O0 -tO5,00 0 0 lO00 oo 999 99 894,99 0 16 2000 oo 1999 93 1894,q3 I 24 3000 O0 2999 5? 2894,57 0 54 4000 oo 3975 50 387o,50 24 16 5000 O0 4747 95 4642,95 48 39 6000,00 54n! 82 52'96,~2 ~9 11 7000,00 6055 43 5950,43 51 32 PAGE ~05,00 'F2 0.00 0,34 '22'86 0 0 0 O0 ~ 0 00 E 0,00 N 0 0 E 0 s s 21 20 0~: 6 9'7] N 2 17 E 2 N 67 13 E 0 38,33 N 72 1i,32 N 761.86 N 8~ 1 7 M 1518,34 W 1518,34 N 0.00 42, 2 ,61 22 4,01 N 0 0 E S 54 ]4 W N 54 1 E ,55 6 E N 87 25 W 14].1] S 89 46 W 761.84 S 87 47 W ~517.64 S 87 4] W 227!.20 VERTICAL DOGLEG R~CTANGUbAR COORDZNATES HORIZ.! DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DE~/100 FEET FEET FEET DEG ARCO ALASKA, INC. 211-10 KUPARUK NORTH SLOPE,ALASKA TRUE SUR-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG H[N DEG 0 00 5 O0 105 O0 205 00 305 00 405 00 505 O0 605 00 7O5 01 805 01 COMPUTATION DATE{ 2g-NAY-85 PAGE 4 DATE OF SURVEY= 3 MAY 85 KELLY BUSH[NO ELEVATION{ ENGINEER{ d, CRYER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 -105 00 5 00 -100 00 0 O0 100 00 200 00 30O 00 400,00 800.00 600,00 700,00 0 0 N 0 0 E 0.00 0 0 N 1 24 E 0,00 0 8 N 63 52 W 0,02 0 9 S 56 4 E -0,01 0 11 $ 58 4 ~ -0,29 0 12 S 75 25 W -0,]5 0 10 S 7 2~ W -0.22 o w -o.4, 0.15 S 32 50 W '0,25 gO~ 01 1005 1105 1205 1305 14 1605 1705 105 00 2O5 00 3O5 00 4O5 00 5O5 00 6O5 00 7O5 00 8O5 00 01 1005 01 1105 01 1205 O2 i305 02 1405 O2 1505 02 1605 O3 1705 905 00 800.00 00 g00,00 ~ 1000,00 O0 1100,00 1200.00 00 1300,00 gg ® 0,00 00 1600.00 00 1700.00 0 15 $ 53 24 W 0,04 0 16 S 54 5~ W 0,36 0 20 S 53 45 W 0,79 0 27 S 48 23 W 1,35 0 28 S 40 40 W 1.91 0 29 S 34 39 W 2,38 0 23 S 41 iq W ~.8 3 ~ ~ S 49 47 E 2.65 S R2 26 £ 1,72 0 42 S 84 28 E 0,54 1805.04 1805 0 54 N 72 41 E 1 24 N 53 44 E 1 30 N 56 8 £ I 56 '~ 51 46 {~ 2 0 N 53 40 E 1 54 N 55 40 ~ 1 28 N .55 33 E 127 N ~1 5 E I 20 N 49 12 ~ 1 12 N 49 57 £ 1905,05 1905 00 1~00,00 2005,07 ~005 00 lq00,00 2105.11 2105 00 2000.00 2205.15 ~205 00 2100,00 2]05 21 2305 00 2200,00 2405:27 2405 00 2300,00 2105.~! 2505 00 240~,00 2605,35 ~605 00 2500.00 27 05 37 9705,00 2600,00 2805:40 2805,00 2700,00 -53 45 E 55 45 N 67 21E N 40 15 W N 61 59 W 65 26 W N 71 30 W N 77 36 W ~2 lo w 86 57 w 2q05.41 ~905.00 280n,00 0 55 3005,43 ]005.00 2000.00 0 53 3105.~4 3105.00 3000 00 0 42 3205.44 3205,00 3100 00 0 4] ]05.57 3305,00 3200 O0 4 8 ~406 05 3405,00 3300 00 7 13 3~07:~0 3505,00 3400 O0 9 32 3609,00 3605,00 3500,00 12 5 3717,01 3705,00 3600.00 15 4~ 3816.77 3805,00 3700.00 18 44 -0,74 -~,58 -4.62 -6.92 -9,59 -!2,34 -14.8! -16.78 -18.56 -20.22 -21.65 -22,93 -24.10 '24,77 '20,84 -1~,87 2~,74 4 ,15 76.24 0 00 0 00 0 90 0 14 0 06 0 0 17 0 13 0 00 0:00 N 0 O0 N 0 09 N 0 0 S 0 129 S 0518 1,00 S 1,48 S 33 8' 0,00 E 1 W 0,01. E 0 28 E 0 33 E 0 ~1 E 0 35 E 018£ 105,00 FT 0 0 0 l 1 1 2 09 N 8 34 w 10 $ 5 29 E 40 $ 44 27 E S 10 51 · 96 $ 10 26 E 33 $ 4 18 E 16 04 16 06 03 5~ 23 2 66 s' 2948 3258 3738 4318 4 .99 s 5 63 S 7 04 S 0,12 W 0,45 W 0 89 W 147 W 2 04 ~ 2 54 W 3 01w 2 84 w I 93 w 0,75 W 2 66 $ 2 36 W 2 97 $ 8 38 W 3 37 S 15 21 W 4 01 $ 2t28 W 4 77 $ 25 22 W 560 S i! 57 W 6, 6 $ 2 W ,00 $ 15 9 W 7,08 S 6 7 W 1 16 0 24 0 0 ~2 0 56 0 36 0 33 0 26 0 10 0 39 6 5 -4 2 0 1 3 4 94 S 0 ~81S 2 36 S 4 66 S 6 45 $ 9 51N 12 19 M 14 67 N 16 18 N 18 66 N 20 53 E 40 E 49 E 84 E 58 E 40 E 92 E 93 E 76 E 47 E 6 96 S 6 6 7 9 12 15 17 19 21 4 20 E 28 S 22 26 E 26 S 45 48 E 34 S 68 46 E 59 S 87 19 E 26 N 77 55 . 56 N 74 35 E 75 N 71 45 E 85 N 69 28 E 011 47 9 93 10 3O 10 12 1 49 1~ 23 -10 28 6'7 32 93 35 78 N 23 44 N 24 79 N 25 8 21 O1 19 24 ~ 44 09 N 75 24 E 25 44 E 26 12 E 27 26 E 25 88 34 17 ~ 54 18 W 82 8 03 N 21 94 E 23 65 N 68 4 E 22 N 67 10 E 57 N 66 51E 34 N 66 45 E Ot N 58 12 E 36 3~ 32 E 68 ~ 53 97 N 64 W 0 O0 N 0 0 E O0 N 90 0 E COMPUTATION DATE~ 29-NAY-85 PAGE 5 · ARCO AbASKA, INC, 2U'lO KUPARIIK NORTH SLOPE.AI,ASKA DATE OF SURVEY{ 3 NAY 85 KELbY' BUSHING EbEVATIONI ENGINEERI d, CRYER 105,00 Fl iNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRU~ SUB-SEA COURSE MEASURED VERTICAl. VERT~CAb DEVIATION' AZIMUTH DEPTH DEPTH DEPTH DEG HZN DEG N{N VERTICAL DOC, bEG RECTANGULAR COORDINATES HORIZ' DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/!00 FEET FEET FE~T OEO MXN 3923.]9 ]905 O0 3800.00 21 50 4032 50 4005 O0 3000.00 25 16 , 4144.~7 4105 4261.08 4205 418].90 4305 4508 98 440.5 4644 76 4505 4787 15 4605 4935 54 4705 5086 77 4805 O0 4O0O O0 28 55 O0 4100 O0 32 17 O0 4200 O0 16 7 O0 4300 O0 40 10 O0 4400 O0 44 9 O0 4500 O0 46 44 O0 4600 O0 47 58 O0 4700 O0 48 47 N 87 3 W N 88 12 W S 89 40 W S 86 5] W S 84 46 W S 84 31 W S 85 34 W $89 3 W S 89 41 W S 89 31W 11].i7 156.76 207.97 266.99 ]34 ]6 412 08 5O2 55 604 26 71~ 80 827 17 3 8 14 O5 41 0 47 0 39 36 72 N 32 17 11 112 08 W 84 N 155 49 N 206 53 N 265 49 N 333 '79 N 41 1 15 ~ 502 3'2 N 604 45 N 713 82 N 827 63 W 1 95 W 2 52 W 335 51 W 41~ 26 W 50 17 W 604 79 W 713 24 W 827 5?38 43 4905 O0 4800.00 48 48 5~91 O0 5005 5545 04 ~105 5698 i9 5205 585] 46 5305 6004 86 5405 61.57 41 5505 6308 48 5605 6459.65 57O5 6609.23 5805 O0 4900,00 49 24 O0 5000,00 49 19 O0 5100,00 49 10 O0 5~00,00 49 19 O0 5300,00 49 O0 5400.00 48 51 O0 5500.00 48 27 O0 5600.00 48 37 O0 5700,00 47 59 S 89 52 W 941 11 S ~9 44 W 1.056 28 S 89 20 W 1173 36 S 89 1W 1289 22 S ~8 26 W 1.405 23 $ ~7 46 W 152! 32 S 87 5 W 1636.18 S 86 27 W 1748.97 ~ ~6 ll'W 1861.'85 S 86 8 W lg72.55 0 28 0 50 0 61 0 55 0 37 0 29 0 52 0 0 07 I 16 10 24 N 941 10 O1 ~ 1056 9 7 4 1 4 10 17 25 09 N 1173 40 N 1289 88 N 1405 03 N ~522 11 $ i637 53 S 1750 :69 S 1863 10 S 1974 25 W 941 31 N 89 22 W 48 W 1056 53 N 89 27 W 65W 117 62 w 128~ 75 w 1405 02 W 1522 10 w 1637 W 1750 28 W 1974 68 N 89 33 W 64 N 89 40 W 76 N 89 48 W 02 N 89 57 W ll $ 89 $ 89 27 W 44 S 89 16 W 676~,69 5905 OO 5800,00 49 37 691~.78 6005:00 5900,00 51 38 7079,71 6105.00 6000,00 51 3~ 7100,00 61~7,62 6012,62 51 3~ S 86 24 w 2085,76 S 87 2! W 2207. 7O S 87 43 W 2333,47 $ 87 43 w 2349,32 ,59 ,89 0.00 0,00 ;,53 S 2087 ,74 S 2210 44,79 S 2335 45.42 S 2351 ,78 W 2088,03 S 89 6 W ,00 W 2210,35 S 88 58 W ,99 W 2336,42 S 88 54 W ,86 W 2352,30 S 88 53 W ARCO AbASKAw ~:NC. KUPARIIK NORTH SLOPE,ALASKA MARKER TOP UPPER SAND TOP 50WER SAND PBTD TD COMPUTATION DATE{ 29-HAY-85 PAGE 6 DATE OF SURVE¥~ 3 HAY 85 KELLY BUSHING E~EVATZONI I05,00'F~ BNGINEERI d, CRY£R INTERPOLATED VAbUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB SURFACE LOCATION IGIN: 1254' FSL,898' FWb,SEC 32.T12N.RgE~.UM OTtO REC?ANGUL, AR COORD]:NAT£$ FRO" KB SUB-SEA NORTH/SOUTH EAST/WEST 6568 00 6608i00 6703 00 6952 00 6993,00 7100,00 5777.30 5~ 5804.58 5 5867,26 5762 6000.79 5895 605],08 5946 6517,62 6012 30 18 26 79 08 62 2] 08 25 04 29 80 3'9 50 ,5 4'2 45 42 S 197 044 204 2268 235! t)0 W 24 W 14 ) ARCO A6ASKA, INC, 2U-10 KUPARUK NORTH SLOPE,ALASKA ~ARKER COMPUTATION DATE~ 2g-MAY-B5 MEASURED DEPTH BELOW KB DATE OF SURVEY! 3 MAY 85 ~NGINEER{ d. CRYER SUR AC OCA?ZO. ORIGIa= i254' FSL,898' FWb.$EC3~T?X2N,R~£.UM FROM KB SUB-SEA TOP UPPER SAND 6568.00 5777.30 BASE UPPER ~AND 6608,.00 5804.1B TOP LOWER SAND 6703,00 5R67,26 BASF LOWER ~AND 6912,00 6000.79 PRTD 6993,00 6051,08 TD ?lOO,On 6117.62 7 0 576 26 589~ 79 5946 08 6012 62 NORTH/8OUTH EAST/WEST 23 08 $ 25 04 S 29 80 S 39 50 $ 42 tO $ 45 42 8 194] 204 235~ 105,00'1"1 80 W 37 W 24 W FINAL WELL LOCATION AT TRUE SUB-SEA HEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTUPE DISTANCE AZIMUTH FEET DEG 7100.00 6117.62 6012.62 2352,30 $ 88 53 W SCHLUMBERGER O I RECT l ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2U- 10 F I ELD KUPARUK COUNTRY USA RUN ONE OATE LOOOEO 3 MAY 85 REFERENCE 000070443 WELL NAME: 2 U- 10 SURFACE LOCATION: 1254' FSL, 898' FWL, S32, T12N, R9E, UM VERTICAL PROJECT ION 91. -1000 -S00 0 0 SOO 1000 IS00 2000 2~00 ~000 ~.-~.4.-..,f...,~... ~...l....i.~+..i ...... ~....i-~...;, ...... ,~-.i...i-.i ...... i-4.~.-i-. --i- ,'- -;: ~ ! ~:: ~' i,-~~- ~4-..i-.i,-4-- ,..,~-.i-.4..4.~. --.i-.i-.,4~.~.- t--i...i.--i....-i.-i..4..~-i.~4...-i.~ ...i-i-.4..4-.,,,.--i..~.i....i-.i ....... .i...-i....4...i.~....~.-L..,].... :~.. ....... ?.-½-.~-,. i...+.-+.+-.1' ...... .k. ,.k.+..,~ ....... ~,-...f...,~.--.'k-.....i...+....f....f.'-,..~-.f.-.-,'k+- -+-.+-~..-'f.----~..-'f.'...?'--+-...-+-, ..h--.~...f.' ...... ?'...i....+-,1'-. mF.+.-?'---.f.'.-+-.'f.'-.+.+.-?' ...... -~..+..~...+.+-+-+.+,-~ ....... q-..~-h...h.. ,-N-.,Ph. -i.-k+'-4--?"-.N~4 ..... 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BAXTER ~rr~ ,~z: /rg-/~ - /A~- 5' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - F]12~, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ATTN: PATSM $. BAXT~-R ATO/507 hd'~'~'" ~-: !~ P. O. BOX 100360 ~:~, ~ .... ~ c, o~s Cons. Commission ~O~GE, ~L 99510 ;~:~ct~orag~ A,.~CO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ,. Telephone 907 276 1215 ARCO Alaska, Inc'~' Post Office ~x 100360 Anchorage, Alaska 99510-0360 TelephOne 907 276 1215 May 15, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports · Dear Mr. Chatterton- Enclosed are the April monthly reports for the following wells' 1Q - 1 2U~10~i~ 2 V- 12 3 B - 16 9 - 28 1Q-2 2U-11 2V-13 3-16 (workover) 17-14 1Q-16 2U-12 3B-1 4-32 L1-1 1R-5 2V-10 3B-2 9-16 (workover) L~-9 2U-9 2V-11 3B-3 9-27 L2-28 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU6/LI06 Enclosures ~aska O;l & Gas Cons. ComraJssion Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA C._ AND GAS CONSERVATION COl,.. AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-39 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21302 4. Location of Well at surface 1254' FSL, 897' FWL, Sec.32, T12N, RgE, UM 5. Elevationinfeet(indicateKB, DF, etc.) 6. LeaseDesignationandSerialNo. 106' RKB ADL 25643 ALK 2574 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2U-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. Apri 1 , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0300 hfs, 04/06/85. Drld 12-1/4" hole to 3015'. Ran logs. Ran, cmtd, and tstd 9-5/8" csg. Drld 8-1/2" hole to 7033'. Ran logs. Continued drlg 8-1/2" hole to 7100'TD (04/12/85). Ran & cmtd 7" csg. PBTD = 6993'. Secured well & RR ~ 2200 hfs, 04/12/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Cmtd w/200 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/FS @ 2994'. Cmtd w/790 sx PF "E" & 350 sx PF "C". Top job performed w/50 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/FS @ 7074'. Cmtd w/260 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/LSS f/3015' - 1400' LDT/CNL/NGT/EPT f/3015' - 1400' SHDT f/3015' - 1400' DIL/Cal/SFL/GR f/7034' - 2994' FDC/CNL f/7008' - 6350' RFT f/6869' - 6575' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I herebv certify that the foregoing is true and correct to the best of my knowledge. NOTE-Repo~g/~)n this form is required for each calendar month, regardless of the status of ~;e~a;ions, 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 TEMP/MR28 Submit in duplicate March 11, 1985 blr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2U-10 ARCO Alaska, Inc. Permit No. 85-39 Sur. Loc. 1254' FSL, 897' FWL, Sec. 32, T12N, R9E, ~. Btm~hole Loc. 1329' FSL, 1497' FEL, Sec. 31, T12N, R9E, ~-i. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill 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 subject to AS 16.05.870 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 by 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. Mr. Jeffrey B. Kewin Kuparuk River Unit, 2U-10 -2- March 11, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ¥~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandor~nent, please give this office adequate advance notification so that we may have a witness present. Very trul}~T y~urs, Chai~an of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION lc Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~ Post Office b~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 26, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2U-10 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2U-10, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment If you have any o We estimate spudding this well on April 4, 1985. questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/HRE/tw PD/L50 Attachments RECEIVED MAE 0 8 1985 0il & Gas Cons. Commissior~ ,--.,. ~./~c~rage ARCO Alaska, Inc. is ,~ Subsidiary of AtlanticRichfieldCompany -~-- STATE OF ALASKA ALASKA ,.)IL AND GAS CONSERVATION C~.MMISSION ERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL [-XlX REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [~X 2. Name of operator ARCO Alaska, Inc. 3. Address RECEIVED P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1254' FSL, 897' FWL, Sec.32, T12N, RgE, UM At top of proposed producing interval 1316' FSL, 1090' FEL, Sec.31, T12N, R9E, UN At total depth 1329' FSL, 1497' FEL, Sec.31, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) RKB 106', PAD 69' 6. Lease designation and serial no. ADL 25643 ALK 2574 9. Unit or lease name K.paruk Ri 8 1985 10. Well number 2U-l(~,k~ 011 & Gas Cons, Commh~ 11. Field and poOl~-,,, Kuparuk River Field Kuparuk River 0ii Pool 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth (MD & TVD) 7182' MD, 6237' TVD feet 14. Distance to nearest property or lease line 897' ~ _~ZA~/~d~' feet 17. Number of acres in lease 2560 t15. Distance to nearest drilling or completed U-9 well 60' @ surface feet 18. Approximate spud date 04/04/85 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3165 feet. MAXIMUM HOLE ANGLE 21 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) _9679 psig@__80oF Surface 3062 psig@ 5978 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE ._ Hole 24" 1 2-1/4" 8-1/2" Casing Weight 16" 62.5# 9-5/8" 36.0# 7" 26.0# CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Grade 22. Describe proposed program: Coupling Length MD TOP TVD H-40 Weld 80' 35' I 35' I J-55 BTC 2980' 35' i 35' HF-ERW J-55 HF-ERW _ 7148' 34' I 34' I MD BOTTOM TVD 115' Il 115' 3015' I 3015' 7182' I 6237' I (include stage data) + 200 cf Poleset 630 sx Permafrost "E" 690 sx Permafrost "C" 260 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7182'MD (6237'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3015'MD (3015'TVD). A 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 (3000 psi for annular). Expected maximum surface pressure is 2679 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 2-7/8", 6/5#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ' TITLE Area Drillinq Engineer The space be~ ~'or~or~ on use~ CONDITIONS OF APPROVAL Samples required Mud Icg required []YES [~O []YES .[~10 Approval date Permit number ~r,~)~? ,o 03 11 8 Form 10q01 (~E) PD/PDSO Rev. 7-1-80 Directional Survey required I APl number [~t-YES r~NO ] 50- O't-~ - SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Mai:cb 11, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2U-10 installed and tested upon completion of the job. 2U-10 will be the fourteenth well drilled on the pad. It is ± 60' away from 2U-9 at surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at $623'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. After the completion rig has moved off location, the well will be fracture stimulated. RECEIVED IVtAR 0 8 1985 Oil & Gas Cons. Commissio~ -., Aachorage TOP UONUi SNDS T¥1~t835 ' - tL--.~ 2 1'vp-2.15 KOP'- ..... TVD,W31e$ TI'It~3-tB$:--!)EP-O ,. . . RECE i VED 3- . ~ - ! ~ - , J..__-L .~. --~'._ ~ T~ ~1t $~ TV~5855 T~t3 ~ti ~_ . ;_ ~~D~;Lr~ ~_.~~5~..T~*~....~~ ...... TO (L~ PT) TV~623~ T~71 ~~~5 _._ '~ .... ~ .......................................................... - ~ ' . -:.:--::-'~?_-:::.- .... ~-. -.-_:~. ~:. . _ : , -. I ......................... ~ ........... ~ ...... .. , --~ 4000 3000 2000 1 000' 0 I 000 N '88 DEG t.3~ MIN. ....................................................................................... ~ ...................... ~ ................ R-ECEt-VED ...... ' _MAR 0 819~5 : ' ~Ua, ska :)il & Gas Cons. ,Commission I ~00 1 ~00 1 12~n 1 1OO 10C)o ~100 200 ~00 40O N,ORTH ~oo ~oo aoo ~o ~c~oo ARCO ALASt~A. INC. PAD 2U, ~LL NO. g-10-11-1~ PROPOSED ~PARUK FIELD. NORTH SLOPE_. ALASKA NOTE, WELL PATHS EXTEND BEYOND THIS VIEWING WI~IDOW ,1! 7 Surface Diver:er Sys:em . 16" - 2000 psi Tankco star:lng head. Tankco quick connect assy. 16" x 20" 2000 psi double studded adapter. 20" 2000 psi drilling, spool w/lO" side outl ets. 10" ball valves, hydraulically actuated, w/lO" lines to resem~e pit.. Valves to open automat'ically upon closure of annular preventer. , ,~ 20' 2000 psi annular preventer. ,, 20' bell nipple. · . . Maintenance & Operation Upon initial installation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines every 12 hours. Clos~ annular preventer in the event.that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well underm any circumstances. · 16" Conductor RECEIVED . IAR 0 8 1985 Alaska 011 & Gas Cons. Commission ,., Anchorage T i 2 13. IS 45 ~CCINI::~ C~.O~IINI$ TIN(: ~ ;200 m~jl 2. O-ECx TI.~- ~L LCX::X CCVIN SC~V~ iN ,'~..~..AC AJ:~E FLJ. LY ~;~LrF~..~"'T~. $F.~l' TEST PLUG IN ,~.J.;.~F.A~ ~TW ~LNNINI$ JT x3JNl~ ~ IN LO0~ 9. ~N ~TT~I~ ~ ~ ~ ~~ ~ ~I. I. ~N ~I~ ~ ~ ~I~ ~T ~ ~ ~ ~. ~Y ~I~ v~ ~Y, ~y ~ ~I~ ~ ~I. ~E~Y ~~ F~I~Y ~TE ~ ~I.~. ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 25, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Conductor As-Built Location Plats - 2U Pad Wells 1-8, 9-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU3/L77 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany I I III III I III I El I II . WELL 9 Y = 5,976,461.43 LAT. 70020, 48.864" X = 509,426.32 LONG. 149°55' 24.538" ' PAD ELEV. 68.2 O.G. ELEV. 64.0 WELL 10 Y = 5,976,519.68 LAT. 70020, 49.436" X = 509,440.83 LONG. 149°55' 24.112" , PAD ELEV. 68.2 O.O. ELEV. 64.0 ~ WELL 11 Y = 5,976,577.87 LAT. 70020' 50.008" ' / "~ ~ i:7 I ×: ~o~,.~.~ ,.o~.,~o~,~.~.~.,, ! i PAD ELEV. 68.4 O.G. ELEV. 64. WELL 12 Y = 5,976,636.06 LAT. 70°20' 50. 581" X = 509,469.88 LONG. 149°55' 23.258" PAD ELEV. 68.4 O.G. ELEV. 64.3 FSL 1370 FWL 927 WELL 13 Y : 5,976,549.05 LAT. 70°20'49.7203'' X = 509,819.06 LONG. 149°55' 13.0574" PAD ELEV. 68.2 O.G. ELEV. 64. FSL 1283 FWL 1276 WELL 14 Y = 5,~76,490.99 LAT. 70°20'49.1494'' X = 509,804.34 LONG. 149o55' 13.4899" PAD ELEV. 68.2 O.G. ELEV. 64.2 ?SL 1225 FWL 126l WELL 15 Y = 5,976,432.60 LAT. ?0°20'4~. 5753'' X = 509,790.16 LONG. 149°55'13.9064'' PAD ELEV. 68.4 O.G. ELEV. 64. 3 FSL 1166 FWL 1246 WELL 16 Y = 5,976,374.56 LAT. 70°20'48.0046'' X = 509,775.62 LONG. 149°55'14.3336'' :~1 ~ PAD ELEV. 68.3 O.G. ELEV. 64.5 [[ FSL 1108 FWL 12J2 TOWNSHIP 12 N, RANGE 9 E, UMIAT MER. ~ :' .... 4~¢'0;" ~ -' ', ~,'., ~S- ~5o4 .,' N 13,55, E8,30 AND NI3+55, Eli+70 AND BASIS OF ELEVATION IS P-.U-5 AND 2U-4 '~",,'~rcrl"~l~a~"'-~' PER LHD I~ ASSOCIATES. LICENSED TO PRACTICE: L~ND qURVEY!NG IN THE :TATE OF THIS SURV'~Y-/ 1"' ALASKA AND THAT THIS ~-'_AT ,NEPRESENTS A SURVEY MADE (~"""~I I~ ~ /~~ : !UNDER MY C'RECT SUF'EF<v':$'ON 2'Nj' THAT ALL -~)ETA'LS ~l 33 ARE CORRECT AS OF /'/'~ ~:"~- ARCO Aleske, Inc. Kuporu~ Project North DRILL SITE 2_U :,!,a,,,.' CONOUC.O S-.U, oc ,o.s _.__o Dr;wn B y ' ~ D W I~ No. NsKg.05.221d2 CHECK LIST FOR NEW WELL P ~RMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (2/ thru 8) (3) Admin ~ 5J~ '~ 9. (9 thru 12) 10. (10 and 1'2)' 12. ( 4 ) C as g ,//P¢-,//TL' .7/:/J~ ( 13 'thru '21) '(22 thrt~ 2,6) 13. 14. 15. 16. 17. 18. 19. 20. 21. YES NO Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line .................. ~ Is well located proper distance from other wells ...................... 5. Is sufficient undedicated acreage available in this pool ............ $. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ...f ............................. _~ 3. Can perm~ be approved before ten-day wait .......................... 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. Is a conservation order needed ...................................... ~__ Is administrative approval needed ................................... Is the lease number appropriate ..................................... REMARKS Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... ~-~ 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., z~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~zt-~ , psig .. Does the choke manifold.comply w/AP1 RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ,,/'V,cT : uB,,',-lf Additional requirements ............................................. /~,~ Additional Remarks: t:~ o i-.i o Geolomv: Enzineerinz: HWK ~ LCd' y~f,' ~EW~~ WVAjAL --~~ HJH~Z~ rev: 10/29/84' 6. CKLT . ~,~,-,~: .', ,,, . ,.~,, :7,~ · POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF 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. L~$ T~P~ SEEV'iCE NAME : .~AT6:5:5/07/ 3R~GiN : RE~L NAM;f :l~91gi CGN'TiNjATI3N ~OMM~NTS : Li ~R,~R ~f Flute N~M~ 'EDIT .001 SERVICE NAME : VERSION m : DATE : MAXiMW~4 ~E~GT~ : iO2~ Pi~E T~PE : PRjViDJS FZLE ~* iNF3R'~ATISN RECCR2S ~ MNfM CONTENTS CS 4LASK~ £NC -10 ST S~K I~T-ZRVAL SL ~P~ ~S~A .~i~TfNTS PRE. S: -~,.,. CCM',~ENTS·. SNIT .~N IT TYPE 000 000 000 000 000 0~0 0 O0 T¥~E CATE 000 000 000 000 000 0 O C CATE SIZE 01~ 0i7 004 006 O04 SIZE COD ~ 065 065 005 O65 JO3 ~L~SER AT ACC: 70612 RUN ~2-~, DA : L,3GG~3: 11 .APR 35 LO~: L. a. C~DNEY SASING TY~E FLUID V.T. $C 3S ZT'¥ = i.393 ~ 1.37. SP SHIFT gN gU.AL iNOUC'TION LOG ZN T~i$ wAS SPL.~.C2D AT 5200' 3N F?ELD CVP OlO.~Ol VER,iFICATI~N LISTING PAGE ~ENTRY 5LCC(S OEPT FT SP 'OIL MV RH~B. ~DN G/CS NRAT FDN RNRA EON NP~ ~DN ~N .~S FCNL FDN SPS 3EPT 7963.0000 SPeW NPmZ 3S.23Z~ NCNL 2~PT 7300.0000 SFLU SP -19.~9~i GR RH~'3~ 2.14,57 OReO NPmI ~.5.99~i NCNL 2EPT 6]00.~0~0 SFNU SP -Z'9.4931 GR RM~5 2.39,57 ~R~ NP~I 3~.912i NCNL DEPT 6500.g0~0 SFLU NPm.i 3~,.326~ NC "~L ~EPT ~703.0000 SFLb SP -~5.~6~3 ;SR NP~Z 5S.10?e ~C~L SiZE I 7] 6:5 AP1 .APl AP.i APZ FILE LOG 'TYP~ CLASS O0 gO0 O0 0 0 O0 Z20 01 0 0 O0 IZO ~6 0 0 O0 i20 ~ 0 O gO OlO Ol 0 O JO 310 Ol O0 310 Oi 0 0 O0 ZSO Ol 0 0 OO 350 02 0 0 O0 35~ 01 0 0 O0 ~ZO O! 0 0 O0 000 ~0 0 0 O0 890 gO 0 gO 330 31 0 O0 .330 30 0 .IB93. 22367. . 103. 1~60. 3~ IlO. O. 1943. 6875 3875 O000 5120 ~023 O~IC ~875 30~9 ~52.3 0308 1335 0459 ~8 75 6875 .~,L. 3 SR ~RAT FC ',~L NR ~T i=C '~L NR~T FC~L ,=CNL iLO 3R :~R ~T O .1ZN 0 'SIZE SPL R~PR PROCESS IZ~9. 3. 5327. ~ 3. ~ i I 0. 3. ZOO. 3. 5 Z ~. ~ 3. 59 ~. 16,50 5875 Z307 2500 2659 7131 5523 1037 3125 930~+ ~523 04 ~ 1 Z346 31~ .iLM C~ I RNRA ILM CAci 2NR~ 'A~I RNRA ZLM CALl RNRA 66 68 OOO00000000000 O20000000gO00O 0000000000000~ OOO00000000000 ,58 OOO0000000000g 68 O000000000000~ 58 O000000000000O O00OO00OO00003 O00OO0000OO00~ O00OO00000000~ ZlS.Z773 5.50ZO 3. :~3 3~, 3.3167 10.56~ ~. u339 3.~9.Z. 9.~051 3.3~59 3.15~ 3.33,52 ~¥? ~%0.H02 VERIFiCATI'DN L.-ZSTiNG PA,SE 5 OEPT 6500.0000 SP -50.98a5 RH06 2.2991 DEPT ~00-0000 SF~U 5P -60.~863 GR RHj~ 2.3831 DR~C NPHI 43.065~ NC~L OEP'T 6300.00D0 SFLU SP -64.~72'? 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'5.5940 .iL3 11'7.0273 SR -999.2500 NRAT -999.2500 FCNL 7.3328 iLS Iii. 5273 -~9~.2500 N.R2T -:9~. ~Oo 5.5320 ZUJ -999.2500 ~R~T 3.5002 iLS 112.46,6 3R -999.25.00 ?~R~T 5i. ~555 CALl 2 .. '79.13 R N R A 775.3125 920 906 RNRA 3.0901 -~9:~.2.5~0 -99~.2590 ILM CALl RNRA 2.~530 I~M CALi RN.RA 3.7112 '-~99.2500 -999.2500 I'LM CALI RNRA -'~99. 2500 -'~9. Z 500 -999, 2500 iLM RN~A 3.~436 -999.2500 -999.2500 ILM CA~I RNRA 5.~968 -~9'~. 2500 -99). 2.500 CALl ZLM CAul RNRA C AL.i RNRA 63. 1 :~u ~. 3,30.1 3. i,252 ~..-~5 9.7.207 3.'146,7 -999.2500 -99'9.2500 -999.2500 -~99.2500 '-999.i500 3.,4i7 -~9~.:2500 -999.25J0 -999.2500 -99~. 25:" NPHI '-999. 2500 NCNL JEPT SP SP NPHI OE PT SP NPml ~T RH ~E NP ni ~PT SP SP NPHi DP_PT RH35 NP~i SP RH36 NP~I O~-?T SP ~H35 3~PT SP NP~i SP .5~00. ~000 SFLU -3~5. 207'0 GR -99 :~. Z530 ORHO --9'99-2500 NCNL -~.2383 jR --999.g500 NCNL 5300.0000 SFLU -999.2500 5ZOO.g000 SFLU -60.9883 -~99.2500 -999.Z500 NC'NL 5!00.0000 SFLO -999.1500 3RH3 -999.2500 NCNL 5200. 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Z590 CALI -t99.Z500 RNRA -999.Z500 ~.iI01 ZLM -999..2500 CAkl -999. 2500 RNR~ -999.2500 1.5870 iLM -999.2500 CALl -~99.Z500 RNRA -'399.Z500 2.2151 -999.2500 RNRA -999.Z$00 RNR~ -99~.Z500 .Z. '78~3 ZL~'i 3.i85.~ -999..g500 -999.2500 -999. t500 -99:.J. ~SgO 3.95?3 -999'2500 --999.2.500 - 999. 2500 -99 3.2,500 2. ?.5 ,~ 1 - 999 . Z5'~' ''''uu - 999. Z 530 I. ,5917 -99'~o lS00 - ~9 ~. g.SO0 2.Zi3t - 9 '9 9. Z .5 O 0 .~500 2. '77 70 LVP 0.1~;~.~0~ Vr-R~ fba~iON L~.StFiNG PA3f 7 SP S~PT NP SP NP,I SP OEP'T SP NP~.I DE~T SP NP~I SEPT SP SP DE?T SP -999. ,2500 - :R99. 2500 -~99.250~ ORHO --999.2500 NC~L ~300.0000 SFLU -399.2500 DRHU -999.2500 NCNL ~ZO0.O000 SF~u -65.~727 GA -~99.2500 ORMC -g99. ZSOO NC~L ~t00.0000 SFLU -2 ?. ~9.51 GR --999. ~.5~0 NC~L 4~00,0000 SF=U -999.2500 ORHj -!~99. Z5OO NCNL 3~00.0000 SFLU -3'Z.98d3 SA -999.Z500 NCNL 3500.0000 SF~b -33.7070 SR -99~.2500 OReO -999.Z500 NCNL S70~,2000 -37.9883 -999,2500 ~CNL 3500,0000 -3 9, '9653 jR -999,2500 -999,£500 3500.0000 -9'99.25,90 ~CNL 3;03.0000 SFLU -'999.2500 J~RAT -999. Z500 2.3733 iLO i0~.t~23 jR -999. Z500 NRAT -999.~500 FC~L -999.2500 FC~L -999.2500 NRAT I1%.?773 Sk -99'9.2500 NRaT -9'99.2500 FCqL 2.~866 iLD 10~..5.3 98 jR -999..2500 NRaT -999.2500 FCNL 2.7971 ILJ 107.83'96 3R -999. 2500 NRAT -999.2500 FCNL 103. 3398 SR -999. ZSO0 NRAT -999.2500 ~C'4L i14,%6%8 jR -999,2500 NR~T -999,2500 FC~L 11Z,%023 jR -999,2500 4.7781 ~'LJ 118.1523 3k -'99~.2500 NR;T -999,2500 FC~L -999. 2500 RNRA - 999. Z 500 RNRA S, 5£33 -999. 2500 CA 9.99,2500 R NRA -999. ~500 -999, ZSO0 -~ ~. k500 -999, RNRA g. 57.G5 iLM -99~. 2.500 ~*~" -999. 2500 RNRA -999. ZSO0 -999,2500 CA~i -999.2500 RNRA -999,Z500 .2.~206 riL~ -~99.Z$00 CALl -999.Z500 RNRA -~99.~500 Z,9729 ILM -999,2500 -'999,2500 RNRA -999,1500 3.1213 ,iLM -99~9,Z500 CALl -9'99, Z500 RNRA -999,2500 -~9~.Z500 CALl -999.Z500 RNRA -999,Z500 4.5906 -999.2500 CALl -999. Z500 i.~lSg ZLM -999,2500 2,5901 g.~9'75 -gg}.zSO0 Z,5608 -999.,Z500 -999, gSO0 2.7~59 -99'9., ZSO0 -999, ZSO0 -999,Z500 -999,2500 Z. 99~3 -99~.Z500 -~99,Z500 ~.%0Jl SP -43.98.B3 3R RH06 .-999. 2500 DR:HC NPriI -999.2.500 NCNL DE?T 3],,0:3.0030 SF~U SP - 5.3.,, 7'353 SR ~EPT 3000.0000 SF~U SP -55.7353 NP~i .-999..~500 NCNL RH;B .-~99. ZS~OO 3~Hg NPdZ -~9~.-ZSOO NCNL -999. Z500 NRAT -~99. 2500 FC 3.22~9 ZL-5 Ii~.o7773 ,R -39'9.2500 N~.~T -99'9.~500 FC~L -999.2500 FC~L 65.0896 GR --999.Z500 ~R ~T -9-99.2500 FC ~IL. 47..5117 SR $~: T;PE TRAILER :X~'~- S~:~V iC.-i NAME :~bZT DATE :55/C7/ 8 TA~ N~M~ ~2NTiNjATiDN ~ :JI NEXT T~P~ ~.ME : CGMM~NTS ;LiSR~RY TAPE -'999..2320 CALi -999.~500 RN~A -999.Z.500 3.3iZ7 -~99. 2500 CALI '35 5 Z Z L M 2500 RN:R~ -~9~.2500 -999.2500 - 99 9. Z 500 353.5906 -999.2500 -999.2500 ~LM CAL.i RNRA 5.ii16 -999.2500 ,- f ~ ..,~ ~ ~ ~ -999.250O -99~.2500 -999. 2500 -9~9. 2500 ~ ..... S CH~L,i;MB r.. R ~E R .... * LIS TAPE ¥~RIF IC~Ti~ ~ LISTING LVP 010.HOZ VERIFICATION LiSTiNG PAISE PREVIOiJS REEL : COMMENTS ~-~ TAPE HE&DER *~ SERVICE NAME :~DiT DATE :85/07/ 2 G~.N .0000 , ~ N~M~ .0.57i ~ :01 ~# FILE HE~DER FI~E NAM~ : £OI~. .001 . VERSION gATE : MAXIMUM ~ENGTH : FILE T~PE : PR~VI~S FiLE : ~* INFORMATION REC2R~S MN~M CONT:ENTS CN : 2~@ SKA INC WN : 2U-IO FN : KUPARUK RANG: 9E TONN: IZ~ SECT: 32 COON: MoSLOPE STAT: ALASKA CTRY: US~ MN~M CO~TENTS PR ES: -3 #.* COMMENT S "'""-,--.- UNIT TYPE CATE SIZE 000 000 015 065 000 OOO 005 065 000 000 007 000 000 002 0~5 000 000 003 0~5 OOO 000 002 055 000 000 007 000 000 006 055 000 000 003 055 ~N'IT tYPE CATE SiZE COOE 000 000 001 0,55 S CHLUM5 ER ~..E R ~ A T.L A ~ ' K~PAR~K ZU-iO WEST SAK NORTH SL:OPE ~OROUGH A L A S K A OS NUM~.ER AT 6C~: 70571 UN ~1, ~ATE LOGGEO: 7 APR 8S CASING TYPE FLUID DENSITY VISC2S[TY ~L~IO L~SS = 16,008" S 1,15~' - BIT S.I£E = 12o2S0" = GEL $~fX'TRIP : '9.7 LS/G RM = 7Z. 0 S = 9.0 R MC : 6.6 C3 R~ AT SHT LVP Oig. HOZ VER[FIC.AT'IgN L~' ,~. S T I N G e A ~S E 3 THiS DATA HAS NOT ~EEN D~PT;H S~I.=TED OV:-RL~¥S FI!ELD PRINTS SCHL:JMiS, ERG,2R LOGS iNCL~DEO WiTH THIS MAGNETIC DUALIi~DdCTIgN SPH~RtCAL~.Y FgCUS~D L~G (DiL) DATA AV'4ILASLE: i~O:D*: T3 5011' LONGSPACED SONIC LOG (LSS) D~T.~ ~VAZL.ASL~E= i:~ODj TD 29~1~ L~iTH~ O~NSITY CCMP~,NSATED ~OG (LDT) COMP~NSATEg NEUTRON LOG (L,DT) ELEC'TRDNAGN~TZC PROPAGATZO~ T~OL (.:EPT) D~T~ AVaIL.ABLE: [~0~3~ TD 2996'" NATURAL ~MMA TODL (NGT) DATA AVAIL.A~L~: l~Og' T~ 29~56' LVP OlO'HOZ VERIFiCATI~N LISTING P~i~ z~ ENTRY 5~JC~S TY ~E 2 0 DATUM MNEM SFLU SP GR S G R CAL[ NRAT RNRA NP~i NCNL FCNL CGR POTA POTA TM D R ~R ~T 2TL ~.ATT NV,j CALI SGR SPEC [FiC4TiO~ SERVICE SiERVI CE ID ORDER OIL DIL ~IL LDT LOT LOT LOT LOT LDT LDT LOT ~.DT ~.DT NG 1r NiGT NGT VOL ~GT NGT L S S LSS EPT ~PT SIZE 1 I I '2EPT SP RH~]B NPHi -999.Z500 g.~sg8 45.1172 SFcU GR 3RHO OCKS ~NIT 4PI 4PI AP1 LOG T~PE CLAS ET O0 000 O0 OHMM O0 220 OHMM gO 120 2HMM O0 120 MV O0 010 O1 ~API 00 ~10 O1 GAPi O0 310 IN O0 280 01 G/C3 O0 350 02 G/C3 OD 356 Ol O0 420 O1 O0 000 O0 PU 00 890 O0 00 358 01 CPS 00 330 C P S 00 330 ,30 SAPI O0 )I0 Oi ~API O0 3~0 O1 PU O0 719 50 PU O0 719 50 PPM O0 790 50 PPM O0 79Z ~0 JAPI O0 310 01 US/F 00 520 80 US/F 00 520 aO NS/M O0 l~Z 01 08/~ 00 130 Ol V 00 000 00 V O0 000 O0 V 00 000 00 V 00 000 00 iN O0 280 GAPI O0 310 O1 -ggg. Z$O0 -999.2500 1.94.14 2.1172 REPR NR:~T NCNL 6~ lin I 0 ~PI FiLE SIZE MOD NO. 0 0 O 0 ~ 0 0 .~ 0 0 0 0 0 O ~ 0 0 ~ 0 0 0 0 ~ 0 0 0 0 ~ 0 0 ~ 0 0 ~ 0 0 0 0 · 0 0 0 0 0 ~ ~ 0 0 0 0 ~ 0 0 ~ O 0 0 0 0 0 0 0 ~ 0 0 ~ O 0 0 0 -99~.2500 ~Ob.~O00 758~.0000 C OD ~ :(0 C T AL ) ,5:8 0000000000000~ 68 00000000000000 58 OO000000000OOO 68 00000000000000 ~6 OGO0000000000~ 68 000000000~0000 ~8 O000000000000J 68 OOO0000000000~ 58 00000000000000 ~B .0000000000000~ 68 O000000OOOOOOO ~58 O00000OO000000 68 O00000000~O00J 68 O000000OO0000'J 68 0000000000000J '~8 O00000000000O~ 6~ O000000000000J 58 000000000000.0~l ~8 O000000000000J 08 O000000000000g 65 00000000000000 5B 00000000000000 58 00000000000003 58 O000000000000J .~8 O000000000000J ILM CALI FCNL 188~8.0000 LVP OIO.HOZ VERIFICATION LISTING PAtE 5 SG~ ~.05..5,000 CGR THOR ~+S. 8~+37 UR AN DTL -999o Z.500 'TPL FV~ 0.50~8 NVU S,GR ~06. 5000 gEP'T 3gO0. 0000 SFLU SP -999. 2500 GR RH.D8 .2.0859 NPHI 47.!680 PEF SGR ~05. 5000 CG~ THgR 39.093~ ~R~N OTc -999.Z500 TPL FVD O. ¢893 NVU SG~ ~06.5000 DEPT 2900. 0000 i~F LLj SP -Z~,6875 GR NPNi ~9. 5117 ~EF SGR 8 ~. 31Z5 CGR THOR 8.91%i ~RAN 2TL 113.5000 TPL DV~ O. 58~'7 NVU SGR 89.3125 DEPT 2500.0000 SFLU SP -33.8~37 GR RHgB Z. 2109 ORHO NPHI ~8.3398 PE'F SGR 83. 875.0 CGR THOR 5.~391 ORAN ~T~ ~ZZ.50OO TPL ~VD 0.5523 NVU SGR 83.5750 OEP'T 2700.0000 SF~.U SP -35.31Z5 '&R RH;B 2.22'66 DRHO NPHt ~5.~650 PEF SGR 79. :~750 CGR THOR 6. 6094 UR AN 2TL IlO.O000 TPL FVD 0.~600 NVU SGR 79. ~7~0 OEPT 2500.0000 SFLU SP -45.3125 ~$R ~PHi 50.5371 PEF SGR 61.0313 CGR THOR 5.5195 ORAN OTc i35.5000 TPC Fro O. 32~8 NV~ .17.$¢57 ~R £1,~531 EATT 1,0391 NV~ -999.2500 ILO -999.~500 SGR 0.0786 ~R~T 2.3955 NC~L Z5~.3750 POTA 15.7188 ~'R 21,~658 ~ATT ~o 2305 IL 67.7500 O, 0~073 NRAT 2.0605 NCNL ~8,~688 POTA ~.~84~ GR 15.3490 ~ATT 2,2396 NV~ 7.i523 .IL2 71.5000 SGR 0.0073 NRAT 2.3828 NC~L 55.3125 PDTA 15.1120 fATT 1.5573 NVD ~%.1875 iLO 46.6250 SG~ 0.0059 NRaT 2.0898 NC~L 38.5938 P~T~ 2.~629 1Z.Z995 0.9007 NV~ 9.035Z -)99. Z500 -99~. ~500 5.570.3 ZLM 5.~023 89.31.25 CALI 1Z. 55.~7 R N R A 3 ,, 50 ,~ 7 FCNL ~13.OOOO P'O 'T A 0 . 01 Z 2 DT ilZ.:5000 355.8333 FV'~ 0:.6561 2.3594 C.A'L I 1,2.5547 ~.~8~ ZLM ¢.Z305 83.8750 CALI %.0195 RNRA ~. 12d, 9 522. ~OOO FC, NL 368. 5000 1 . 56i5 POTA 0 ~.6250 DT i2t.50G0 362. B3.33 ~V'O 0.5973 2. ~O'lO CALI 12.:~818 7.878'9 ILM 7.3555 79.8750 CALi 12.7344 3.8~i8 RNRA :¢.3555 154~.0000 FCNL 3'77.2.500 2.1~8~ POTA O.OZi5 7;i.5000 DT 110.7500 Z53.56~7 FVO 0.~I~ 1.5530 CALl IZ.73~ 2J.53i3 ILM 29.7031 61.0313 CALi 12.~9Z£ +.125@ RNRA -,.i85Z 1545.0000 FCNL 360.2500 1.2207 POTA O.OiZZ 4~.a250 DT 135.~000 1.0739 CALl t2.%922 LVP OlO.HOZ VERIFICATI2N LISTING PAgE 6 SGR DEPT SP NP~I SGR THOR DTL SGR OEPT SP RHJB NPH[ SGR THOR DTL SGR DEPT SP N:P~I THOR ~VD OE?T RH3B NPHI SGR THOR FVD SGR DEPT SP RHgB NPNI SG R TH2R FVD SGR OEPT SP 6.1. 031,3 2500.0.000 SFLU -54. 8750 GR 2.1035 gRHD 43.84'77 PEF 59.0:313 CGR 4844 ORAN 127.7500 TPL O. ~1~7 NVU 59. 0313 2%00.0000 SFLU -50.7813 GR Z.2383 DRii8 43. 70112 PEF 71. 5625 CGR g. 30%~7 ORAN 121. 7500 TPL 0.~2~3 NVU 71.5625 2~00. 0000 SFLU -6 Z. 875.0' GR l. 0 723 DR HO 4Z.0898 PEF 3'7. 0313 CGR i. 7832 ORAN 153.1500 TPL 0.~t93 37. 0313 2200.0000 5FLU -59.3750 ~R 2,222T ORHO 53.2715 PE? 69.1250 CG~ 6,6406 ~RAN 130,2500 TPL 0.3~07 NVU 69.1250 2100 0000 SF~'~ -55.3438 ~R 1.02~5 ORH~ 51.5137 PEF 33.18'75 CGR Z.33~0 dR~N [67.~00 TPL 0.Z697 35.I~75 2000.0000 SFLU -~7.3125 GR 9.6328 59.9687 0.0005 2.3086 58.3438 0.075'7 15.0729 I.~6.39 12:.0938 7~. 56.25 0.002~ 2.6563 65.3125 0.5812 I~.4167 19.3906 0.0015 1.9043 27. O 000 1.1035 15.2786 2.0094 i4.$59½ 66.8750 2.5016 4.8.7813 2.2344 15.7318 1.½909 28.5781 36.1552 0.0850 1.9727 12.6875 2.2520 1.1296 17.5156 52.5250 NR :A .t NC~L PO'T~ GR ~ATT iL3 SG~ NC ~L PO TA ~R NV9 SGR ~R4T NC~L POTA 5R EATT NC~L POTA ~R ~ATT ~V2 IL2 SG,~ ~R&T NC ~L POTA ~R ~ATT NVD ~ uTA OT I$35.~000 ~CNL 1.9:0~3 POTA 74.5625 DT ll. 95'9 3'7.~ 3.13 CALI ~.~9 RNRA 1761,0000 FCNL 28.6553 DT 300.3333 1.63T~ CALl 17. 3125 iLM 69,1250 CALl .+. 2773 RNRA ~8 3,000.0 FCNL 1. $602 PG'TA 66.8750 DT 262.6250 FVU 1. 5573 C~LI 30,0938 iLM 33.1875 CALI ~.191~ RNRA 1501.0000 FCNL 0.5371 POTA 35.t552 DT 15/.7708 FVU 0.79~5 CALl 17.i875 :LM 57.8125 CACI 9.9.657 ~... Z ~1 391.0000 11.9531 3.98O5, ~1t.0000 122.0000 0.3589 IZ.55~7 12.5250 0.0t07 156.7500 0.~523 1~.Z813 1Z.~609 338.2500 130.7500 0.2806 1Z.~o09 28.7500 341.0000 O.O0~ 0.i471 12.8281 15.~375 12.4375 VERIFICATION LISTING ~,~ NPHI ,5.Z. 3638 PEF S~ 57,, 8125 CGR THg'R ~. 5094 dRAN ~'TL 14.5. 5000 TPL FVD O' ~64~ NV~ ~GR 57.8125 SELU C,R HuB 2. 0410 DR~G NPHI 4'?,. 265.6 PE~: SGR 61. Z1 ~7 ~GR THDR 5.~I80 URAN T L ~ 4 ~. ,Z 5 O.O T P L ~Vg O. 29~5 NVU SG~ 6i. 21,27 ~, p u.E' T 1800.0000 SFLU SP -5 Z. 81~5 GR H~ 2. 0723 DRHO NPHI 54. 7363 PE:F SGA 70. ~375 CGR THOR ;~. 5938 URAN DTL L43. 7500 TPL FV'D 0.5197 NV~ SGR 7~. '~3 I5 DEP'T .i ?00,- 0000 SFLU SP -61.2500 GR RHOB 2,0449 DRHO NPHI '4,~. 38 ~+8 SGR 5Z.1250 CG~ THOR 7. 2070 URAN D'TL 159. 0000 TPL FVO 0.,3~29 NVU SG~ 52.1250 DEPT I$00.0000 SFLU SP -575.3438 GR RHgS 2.0586 9RHO NPHI 55.7353 ~EF SGR 61.78i3 CGR THOR 5. 2813 UR~N JTL I~g.2500 'TPL FVD 0.~106 NVU SGR 6~.~B~3 gEPT 1500.0000 SFLU SP -52.1552 GR Rid35 2. 0195 ORHO NP~I 52.392~ PEF SG~ 60.81Z5 CGR TH3R 5.73~4 URAN 0.0015 2. Z1%8 50.8750 O. ?607 14. ~1%1 1.5335 16, 9687 63 · 3438 O. 005.4 2.0723 4~.1,5938 Z.I5~2 1-6, 0'729 1.20,28 8. 329'7 63. 250.0 O. 0068 2.5703 4,8. %6.88 2. ~+l,Z 1 16.2. 24 0 1 o 9561 40.0625 49.90.62 0.0107 1.3027 55. 0313 -0.3193 15.8385 I.-44 92 39.5313 50.7500 0.0127 .2. i 5¢3 50.7500 1.2129 15.t031 14.1552 67.587.5 0.0171 2.3320 43.96~7 I..~486 NRAT NCNL PDTA ~R EAT T ~L~ SG~, POTA ~&R NVO iL3 SGR N R AT NC~L &R EATT NV3 SGR NRA T NC ~L PDTA ~R ~.ATT NVO NRAT NC~L POTA ~SR :_ATT NV3 N R AT 4C4L POTA 4. ZZ55~ RN, RA 9 ~ . 0000 P;C.N L i, 1230 P 0 T A 52'6250 D T 13. L 797 6'I. 21!57 CALl 1'Z255 CALI C,AL I ~. 36.33 RNR. A 1 ~31' 0000 ~CNL FrO CALI 35. ~437 iLM 52,1250 CALI j, 7969 RNRA 1539.0000 FCNL l. SbOi P~TA 49.9062 OT Z4~,. ~583 FVU 1.. ~101 CALl 22. 5781 61.7813 CALl ¢. ~7~6 RNRA 1773 . 0000 1.5602 POTA 50.1500 DT Z45. ?500 FVU 1.5482 CALI 19.5719 ILM 60.8125 CALl I~9Z.O000 FCNL 1.5113 P~TA 57.5875 DT .,~617 35~'Z5'00 0.0i.50 32.1. t43. 12,5953 37.0000 %. O0.O0 0.0156 132.2500 0.3,4 'i' 7 12.6172 12.5906 5.0938 '348.0 O0 0 14:9. 0000 0.3~,07 1Z.~90~ 1~.~92Z 13.10~ ~.71~8 31~.0000 O.Gl~ml 133.2500 LVP Oi3..HOZ VERIFICATION LISTING PA~E 8 OTL .SGR DEPT 5P NPHI SGR THOR FVD SGR O~PT SP NPHI THOR OTL SGR 13~.5000 'TPL 0.3219 NVU 60..S125 1%00.0000 -63.3?50 JR 50.34IS PEW 48.6250 ~GR B5.2500 TPL 0.~652 4~.6250 137.3.0000 SFLU -55.3~38 GR -999.Z5DO DRHG '-9~.2500 PEF -999.2500 CG2 '-999~.Z500 UR~N 7~.:2500 TP~ -99~o2500 NVU -~99,.25G0 16.6406 EATT 170.0000 ILO Z,.1552 5~..~063 POTA 23..2969 ~ATT 1.1813 835.5000 -99'9.2500 NR~T -~99.2500 POTA -999.2500 -999.2500 FAIT -999.,Z500 N¥O ,~ FIL~ TR~ILER FILE N~,I','I: .. rlD~.T SERVICE NAME VERSION m : OATE : MAXIMUM ~ '~GT~, FILE TYPE : NEXT FiLE NAME · -* FiLE HE~ FILE NAME SERVICE NAM V E R S i O ~ DATE : MAXIMUM LEN FILE TYP~ PREVIOUS Fi ~-~. iNFORMAT DER $, :~iT : : G T H : iON .001 .001 : I OZ, : R~C2R2S MN~.M ii II CN : ~N : FN : CONT.-~NTS 2~ ZU-IO ~iUPARUK SK A INC 75.12: .u ILM 48. 5250 CALI - :~99. 500 FCNL ~ 1. ~ 3 ? 5 O T -)99. 2500 FVO - 999. 2500 CA~LI UNiT TYPE CATE 1.6. Z. 00 ~ 0 -999.2500 - g9 :}. Z50 77. 0000 000 000 015 055 000 000 005 055 000 000 007 0o~ LVP O!O.MOZ VERIFICATION LI.STING PA~ ~ 32 000 000 002 MN E M C O ~ T E N T S g N I T 'T ¥ P E ~, A I E PP,~S: ~ 0~0 000 ~. 065 SCHLUMSER ~.E ,~LAS~A C~MPUTi~G CENTER COMPANY = ATLANTIC RICHFieLD COMPANY ~ELL : KUP~ROK ZU-iO , ~c~ : WEST SAK COJNTY = NORTH SLOPE ST6TE = ~LASK~ JO]~, NUM8'r..R A'T ~CC: 705'71 RUN ~1, OATE LOGGES: 7 APR LDP: L.8.~,rOONf¥~ CASING = 1,5.000" ~ i15~ - 6iT SiZE = 12.250'" LV? 010.HOZ VERIF,ICATI~N LISTING R~ R ~F RMC R M A'T BHT THIS DATA HAS NOT 3E~N DEPTH S~'iFTED ~ .... " ~ : ~': ~ ~'~'~'~'~'~ 'THIS FILE CONTAINS ALL i 2" SA~PLING RATE ,DATA ~"~ SCHL~MSERGER LgGS [NC,LOD~D WITH THiS MAG:NETIC DUALINDUCTION SPHr_R~.CALLY F3C D LOG (OIL) DATA AVAILABLE: l~OO' T~ 3011' LONGSPA:CEO SONIC ,~O~ C, LSS) OATA AVAILA/SLE' i~00~' Ti3 2951' gITM~ ~ENSiTY COMPENSATED LO~ (LDT} COM'P~NSATEO NEUTRON gOG (LOT) DATA AVAIL,ABLE: ~:~00~ 'TO 30~5:~ ELECTROMAGNETIC PROPAGATION TGOL CEPT; DATA AVAILA3L~E: i~00-' TO 29~6" _VP 010.HO'Z VERIFICATION LISTING PAGE NATURAL GAMMA TOOL (NGT) DATA FORMAT REC3RO ~NTR¥ 5LOC(S 'TYPE SIZE Z 8 9 0 OA'T'UM SPECIFICATION :SL~CKS MNEM SERV~.~,. SERVi~E UNIT lO ~ ~RD~R ~ D.EPT FT CALI SAM iN RHOB SAM ~ ~.3 DRHO SAM G/CB PEE SAM REaR APi API APi LOG TYPE CLASS O0 000 O0 O0 350 02 O0 355 01 O0 355 O1 C~D~E 6~ 6~ 4PI FILE MOO NO. 0 0 0 O 0 0 0 0 EN'T RY 0 .lin 0 SIZE ~, DAT~ DE~T ~E~ ~EPT D~T ~PT gEPT PEF 302'?. Z. 3000. Z. Z~O0. 280 210 1001 CALI 50i6 29'9~ CALI 1777 2998 CALI Z. 1895 J.2998 CALl 2.3516 0.2998 CALI 2.5293 0.290a CALI Z..Z256 12.2500 9.7500 1Z.54~4 12. ~Z97 ~H2B 1.7344 ORHO 0o0220 2.1133 ORHO RH2B 2.2012 DR~C 0.035Z 2.2539 0RHO 0.~3~7 2. 0751 ORHO O. 00~3 _VP O!O.HOZ VERIDICATION LISTING ~)EPT CALl DEPT Z~O0,29~8 CALI PEF Z., 52~9 1:2=55~7 RH3iB =. 09 '!9 ~ 1 Z. 7-~ Z 2 R H 2 ~ DEPT 2200.2'998 CALI PEF Z. 3056 2100.29~.~8 CA.LI ! Z. '8559 R H ] B DEPT ~DO0.2'uO0 uALI PEF Z. 576-2 12. ~609 RH ] B D~PT 1900.2000 CALl PEF 2.089,8 1Z,. 5.5~.7 RH3B OEPT 160,0. ZOO0 CALI P E F .2 . ~ 0 5 Z O£PT fi?GO, ZOO0 CALI PEF 2:, 27:54. 5859 RHG~ DEPT 1500.Z000 CALi PEP 2.5098 12.92'97 OEPT 1500.2000 CALI PEF 2.~863 13.2969 RHg8 OEPT lg69.1001 C~LI PEF 2.0234 15.2578 ** FILE TRAILER FILE N&Mi~ :EDIT .001 S;E'RV ICE NAM~ : VERSION m : DA'TE : MAXIMUM LENGTH : 102-~ FILE TYP~:. : NEXT FILE NAME : ** TAP=~. TRAILE~.,-.,-'"'~' SERV~.C~. 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