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Home My WebLink About190-015pTD / g0 Loepp, Victoria T (CED) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Thursday, June 27, 2019 11:33 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 2K-26 Follow Up Flag: Follow up Flag Status: Flagged Thank you! From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, June 27, 2019 11:33 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: (EXTERNAL)KRU 2K-26 Steve, Approval is granted for this additional cement to top off the OA. Include this work with the subsequent sundry(10-404) for the workover and first top job. Thanx, Victoria From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Thursday, June 27, 2019 11:30 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 2K-26 Victoria, To recap what we talked about on the phone: After the rig moved off, the well was flowed naturally, with your approval. I pumped a top job on 6/8/19 and it passed a DDT on 6/13/19. Top of cement is at 16'9". 1 was going to have the guys go out and top it off all the way to surface since that is what we said we would do (get cement all the way to surface) in the original RWO procedure. Below is a screen capture of the passing test and further down is the email between you and Ron. Let me know if you think it's ok to complete this top job under the RWO sundry. Thanks! Report Start DateReport End Date Status at Reporting Time ZX code 61131201906:00 6113;201909.45 0&'1412019 zxC'8AnnulusCommunicabonEvaluallon this data box is reviewed daily by engineers, supervisors, and techs. Last 24hr Summary General Remarks (AC EVAL) OA CCT PASSED. OA TOC = 16'9" Initial T111O =�4074001vac Final T7110 = 240;420;0 weather related data when and A weather has affecton job Weather wind T (-F) Rig (Manns], AES OHD TIMELOG can :"-r uga vtr r>re 53•I r�r? ---d RTe ]Xiv-) iT ejap Cale �T-x opaam VOW 06:00 07:D0 100 1.00 NE TRAY P Sync computer. travel fromKOCto2Kpad. 07:00 07:15 0.25 1.25 NE RURC P R;Uhosesmanifolds. andgaugs. 07:15 09:15 2 00 3.25 NE CND P l- C E'JALj OACCT Passed. OATOC = 16'9' Initial TATO -240!400/vac. IAFL @ SF. OAFL ( possible cement] near surface or at surface. AL blinded. OApressure rose to 14 psi dueto chargefrom echbmeter gun indicating cement near surface or at surface. OAcasing vane and upstream needle valy e s eem to operate normally Bled OAto 0 psi in 5 sec. le` on open Meed for 30 min. SI bleed. Tilto -240142510 15 min 2401415M 30 min. 240141010 Ran string line down OA cement @ 201"(16'9"), OAFL@66"(6'6"). Final T;UO = 2401420/0 09:15 09:30 Q.251 3.50 NE KURD P JR;D hoses. manifolds. and gauges. 0930 10945 1 -1.261 175111E TRA'-' IP JTravel from 2Kpadto 1Ypad. CONTRACTOR TS> czrror ) m[newart %1:W- BECK VICHAEL OHIO Tech CHC Tech I NIA DUFFY. PAUL.DHO Tech CHC Tech JAES 559.7088 1 WA From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Wednesday, April 24, 2019 7:11 AM To: Phillips, Ron L <Ron L Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 2K-26(PTD 190-015, Sundry: 318-541) OA cement approval post production Ron, Approval is granted to bring this well on production prior to bull heading cement down the OA. Please include this approval with the approved Sundry. 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. LoeppCg)alaska.gcv CONFIDENAAUTY 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 Victoric.Loer)p@alaskg.gov From: Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Sent: Tuesday, April 23, 2019 1:29 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Pogany, Mandy W <Mandy.W.Pogany@conocophillips.com>; CPF2 Prod Engrs <n1135@conocophillips.com> Subject: KRU 2K-26, PTD: 190-015, Sundry: 318-541 Victoria, On well 2K-26 we just finished up the subsidence rig workover. We had trouble getting the new 2055' of 7" production casing into the well, so we had to run 8.75" string mills to clean up the 9-5/8" surface casing. We milled holes in the surface casing at 134' to 153', 226' to 274' and 745' to 762'. We also encountered losses at these three areas with the upper being the worst at 40 bph. Since we encountered losses we decided to pump 200% excess cement and the max amount of LCM Halliburton recommended pumping through their HES cement staging tool. During the cement job we had partial returns and never got cement back to surface. Halliburton did not bring extra cement to pump a top down job and they were on call for another job. After we landed casing, pulled in tension and set slips we NU the tubing spool and reinstalled BOPE. We pumped diesel freeze protect down the annulus 8.5 hours after the cement job was finished, which confirmed we could bull head cement after the rig moved off. We have a 2,500 psi pressure test on the 7" production casing, charted for 30 minutes, that passed on 4/18/19. Can we put this well on production prior to bull heading the cement down the annulus or should we plan to pump the cement job first. The reason I ask is because the PTD step #14 said we would cement to surface. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO -13-1334 Steve Drake CPF2/Alpine Wells Engineer ConocoPhillips Alaska, Inc. Steve. g. d rake (a)con ocop h i l l i ps. co m Office: (907) 263-4062 Mobile: (907) 223-1166 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ECEWEE ) MAY 16 - 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing E] Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑+ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool El RepairWell Q Re-enter Susp Well El Other: ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Exploratory ❑ Stratigraphic❑ Service ❑ 190-015 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20126-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25588, ADL 25667 KRU 2K-26 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,350 feet Plugs measured None feet true vertical 6,387 feet Junk measured None feet Effective Depth measured 10,241 feet Packer measured 9685, 9793 feet true vertical 6,324 feet true vertical 5963, 6025 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 115' MD 115' TVD SURFACE 4,236 feet 95/81, 4,271' MD 3034' TVD PRODUCTION 8,275 feet 7 10,330' MD 6340' TVD TIE -BACK 2,025 feet 7 2,058' MD 1846' TVD Perforation depth: Measured depth: 9902-9908. 9995-10015 10047-10084 feet True vertical depth: 6088-6091 6143-6154 6173-6195 feet Tubing (size, grade, measured and true vertical depth) 3.5" L -80/J-55 9,842' MD 6,053' TVD Packers and SSSV (type, measured and true vertical depth) PACKER -BAKER FHL PACKER 9,685' MD 5,963' TVD PACKER - BAKER HB RETRIEVABLE 1 9,793' MD 6,025' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments (required per 20 MC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-541 Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: Sr. Wells Engineer Contact Email: Ron.L.Phillips@cop.com Authorized Si nature: Date f 9 Contact Phone: (907) 265-6312 • S /6 Oil, s/2!/<<J RB®MSL Form 10-404 Revised 4/2017 ! TG � MAY 1 71019 Submit Original Only KUP PROD WELLNAME 2K-26 WELLBORE 2K-26 ConocoPhillips Well Attributes Max Angle 8 MD TD re4vuum wellln,e saws M Alaska. Inc. I Veeoeone on,10 1 -.1 I^ ................ I____ IL c1 JIM MKS) ACI atm MKB) xKx, sheaT+s o:n:9z AM ownssu Last Tag vw4L MmaEc la<3� Annotation IceMh(M(B) End Wh Welllw,e La¢t Motl BY .............._........._......_...... ...................... ........... __. Last Tag: RK8 I 1 .068.0 9111201] K-26 11pproven Last Rev Resson NxMx. 911 Annotation EMDt.W¢IIIgN LasI s --- eY Rev Reason: Replaced Gas Lift Valve B Pulled IBP SIY2019 2W26 xembaej Casing Strings Cxinp WunWion o0(In) ID(nl TOPMUS Bet Depth MKS) Set Depth("la, sai ll_. Grace Top Tbuss CONDUCTOR 16 15.06 36.0 1150 115.0 62.50 H -0D WELDED Casllp Onotlpllon OOIIM r. M Top gq(el Set DepMM e) Sal Deplh(NW Rosen 1-1(tride TOP Tell SURFACE 95at 8.92 35.0 4,2)10 3,034.5 36.00 J-55 BTC CONDUCTOR, 86150 lis ¢.raga l3e.o Mie casing Demrgotbn Oplln) I011n) TOPMKB) Bet WPM MKBI set WpM (IVDI... WpLen II... Grunt Top Those! Tie -Back String ] 628 330 2,057.fi 1,8460 28.00 LA0 Ryd583 CasingDescnptlon OD IMI IO 11.)lg n) Top i Set bear ",set Oeplh (ND)... WOLen VJIU tle Top Threetl ORIGINAL ] 6.28 2,055.0 10,330.3 6,3396 2600 J-55 BTC PRODUCTION Tubing Strings 1 Tubing th-on lion String Ma.. Tubing - Production 312 2019 lint 2.99 1'2 top MKal 0.0 Set DepM IM1. 9)]1.0 SN DryM IND1 I... 6,012.1 W111bYD 9.30 GiMe Lr Tap Connecgan EUEARDAB- Mod Completion Details 1peacC Sovq; y.0.3,D5T8 Top(ryDj Top l,lcl Nominal Tap Hies) IM(al I°1 ..a- Cam Mpnl 31.1 31.1 0.00 Hanger WKM Gen IV Tubing Hanger 3.5500 Tmxre.:3037a 9,558.7 5,954.1 5554 Lowror GBM-22Locetor Sub 3000 9,872.0 5,955.9 5551 PBR Baker PBR 80-00 3010 9,8854 5,963.5 55.4 Packer Baker FHL Packer 2.970 9,74.7 59948 55.32 Nipple - X HES 2. 12'X-nipple(wiM RHCProfile) 2813 SURFACE', 10a,T11 a- 9,]6.0 6,002 55.09 MUle shoe Baker overshot (7.5' swellm-1 space Dug) 3.000 ruhingDescnplion Sninp Ma... 10(m) Tap MKal SM Depas 1q.. Sgt WpM IND) I- m(IpM) Graf¢ Tap Conn"Re original tubi ng 31x2 289 9,765.0 9.8424 6053.4 9.30 J-55 EUE-MOD minstervol sslel Completion Details rop (rv0) ioPmcl Kann' Top MKS) IXKBI (•l Ilam Des Cam 101in) 9,]]94 B4Otfi.9 ..on PBR BAKER 80-0D PER wl 10' STROKE m4"SEAL BORE 3.000 noneaemml; 9,151.1 9,]93.1 6,024.8 54.69 PACKER BAKER HB RETRIEVABLE PACKER ,880 9,830.3 ,0464 5449 NIPPLE OTIS XNNIPPLE NO GO 2.750 9,8416 6,053.0 54.46 505 BAKER BHEAR OUT SUB 2,375 iWirq MHN&; a,9N3 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Toa IND) Tapincl Top MKS) MKIR 1'1 Des Com Run pass ID (lot 9,83110 ,0462 5409 NPlugw .8 NPIug ingie8pade auge AL- 11212019 Spanek Gauge 8-3/16' EO Point) iuAnBMVWe1; 9,18]8 perforations i Slots Shot TUGM MvgM; 9.8133 Top Me) BM MKBI Sim INDI -MIS) MKBI MKBI Dene LMbYxone DaM Iehoni 1 Typ Gqn 9.902.0 9.808.0 6,088.1 ,091,6 C-0, e, K 427/19W 60 APERF -26 60 deg. Pleasing; 2.5"HSO 9,995.0 1 015.0 6.1425 ,1542 A -52K46 4171199] 60 APERF fiO4eg. Phasing: .5"HSD L�Ix'emel PBR: 9.872.0 1004"0 10,064.0 61]3.0 ,194.7 A -0, 2K-26 4/4/1990 4.0 IPERF 18 sig_ haling; 4.' Casing Guns evkh,.ela Manarel Inserts st m NRY•-Halms an Top(NO) Valve lehh P..SW TRO Run N Top IKKBI (t1NB1 Make .0 ODllnl Se" Type Type lint (WI) on. I Cam 1 3,037.4 2,384A lCarl MMG 1112 IGAS LIFT IGI.V RK BIN 1, SO 14126M19 2 5.51S.2 3,699.0 ICaahN MMG 112 GAS LIFT GLV RK .188 1,218.0 Y32019 3 7,151. 4,589.0 lCanow MMG 112 GAS LIFT OV RK 0250 0.0 42512019 this. ', 91exa 4 8,348. 5,240.8 Camco MMG 1112 GI LIFT DMY 7 -0000 00 41182019 5 9,180.9 5,6852 Carrico MMG 000 112 GAS LIFT DMY RK 0. 00 41182019 Pars; 9.TR.a fi 9.612.3 5,922.6 Camco MMG t tl2 GAB LIFT DMY RK 000 0.0 42512019 Puma M 9.Tm.1 Nobs: General b Safety ..E An+pleHon a.Stla 11152010 NOTE. View Schematic wl Alaska Schounic9.0 raN neegwr l.x mq.. sa.o 9flip 0 50s. 9.a418 APERF e93L.P9WE 0� PPERF; 9.91 P10.0150� I PERF; I O.M]AI O.W 0 ORIGINAL PRODDCTION; 2R•6.P10,931.9 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stag Time 3/24/2019 End Time 3/25/2019 Our (hr) 24.00 Phase MIRU Op Code MOVE ActivRy Code Time P-T-X Operation Stan Depth (ftKB) End Depth (WB) DMOB P RDMO2E-17. 00:00 0000 3/25/2019 3/25/2019 12.00 MIRU MOVE MOB P RU on 2K-26. 00:00 12:00 3/25/2019 3/25/2019 6.00 MIRU MOVE MOB P Accept rig @ 1200 Hrs on the 3-25-19 12:00 18:00 Continue take on S/W in pits. Rig up hard line to flaw back tanks and spot mud shack and smoke shack and start loading pipe shed w/ 3 1/2" HT38 work string. Hook up hi line power PU lubricator. Hold pre spud meeting w/ both crews 2K-26 3/25/2019 3/25/2019 3.50 MIRU WELCTL KLWL P Rig up to kill well, take returns to the 18:00 21:30 tiger tank. Tree 200psi IA 1450psi, OA 150psi. Bleed off tree. Bleed down IA 15min, 16bbl fluid to tiger tank. Shut in IA, blow down lines, pressure built back up to 1450psi in 5min. Bleed IA 30min, additional 241bbl to tiger tank (total 40bbl), shut in, pressure built back up to 1450psi in 5min. 3/25/2019 3/25/2019 2.00 MIRU WELC_TL KLWL P RU lifting equipment to tree and pull 21:30 23:30 straighten it enough to get a lubricator rigged up on it. 3/25/2019 3/26/2019 1.00 MIRU WELC_TL KLWL P RU lubricator, pressure test 250/2500 23:30 00:30 5min. 019 3/26/2019 1.00 MIRU WELCTL MPSP P PuII BPV. RD lubricator. 00:00 00:00 01:00 3/26/2019 3/26/2019 4.00 MIRU WELCTL CIRC P Pump 50bbl 8.6ppg seawater down IA 01:00 05:00 taking returns to tiger lank, one for one returns 1600psi. Shut down and change to pump down the tubing.taking returns to tiger tank 1600psi 280bbl. Shut down to swap to second flow back tank, bleed IA to 300psi before shutting in, built back up to 1100psi. Resume circulating holding 1300psi to 430bbl total. Shut down final shut in pressure on tubing 1100psi, on IA 1100psi. 3/26/2019 3/26/2019 4.00 MIRU WELCTL OWFF T Shut well in and observe build up. 05:00 0900 Empty the flow back tanks.Build up 1050 psi Both IA and Tubing Test casing U 2500 PSI 2X Bleed down to 1050 PSI on chart (failed). Shut in well and stand by forAK E-line 3/26/2019 3/26/2019 9.00 MIRU WETCTL T Waiting on AK E-line w/ Baker 2 1/8" 09:00 1800 inflatable plug. R/U AK E-line RU and PU and test lub 1000 PSI 10min good. Install lock cap on SSV. RIH w/ 2.125"OD Drift and CCL, not enough weight. Popoff well and add weight bar. Re-test same. RIH with drift T/ plug at 9830'WLM, tagged plug. Drifted through tubing cut several times. POOH. Page 1/19 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time 3/26/2019 End Time 3/27/2019 Our 6.00 Phase MIRU Op Code WELCTL Activit Code Y Time P-T-X Operation Start Depth (ttKB) End Depth (kHB) 18:00 00:00 FLOG T Lay out drift, PU Baker 2 1/8" IBP. PT lubricator U 1100psi f/ 10min good. RIH with IBP, tag plug. Log into place to set in joint above plug in tubing tail. Irregular setting readings, didn't see amp spike at start or plateau, stayed on bottom 30 extra minutes to allow time to inflate saw spike indicating set and shear off. Slacked off, stack wt on it, good indication it's set. Picked up, saw 20001b overpull on surface sheared emergency Bellville disconnect POOH. Fish neck 1 3/8" on running tool at 9797', two feet inside packer, center of IBP element at 9808'. 3/27/2019 3/27/2019 1.00 MIRU WELCTL ELOG T POOH with elme to lubricator. Close 00:00 01:00 swab valve. 3127/2019 3127/2019 1.00 MIRU WELCTL PRTS T RU to pressure test well. Pressure 01:00 02:00 test to 2500psi, lost 200psi in 10 min. Bleed all pressure off slowly to tiger tank, SI and blow down lines, T, IA at zero psi. Pumped 3.6bbl to pressure up, bled 7bbl to tank. Observe well, no increase in pressure, 3/27/2019 3/27/2019 1.00 MIRU WELCTL FLOG T Break off, LD eline tools, RD 02:00 03:00 lubricator. RDMO eline. 3/27/2019 3/27/2019 4.50 MIRU WELCTL PRTS T RU to circulate, found ID00psi on 03:00 07:30 Tubing and IA. Bleed off well to Tiger tank 15min. SI and observe well. Attempt to pressure test 2500psi. bleed down to 2100 PSI in 30 mins 3X. Check OA, no subtantial pressure response during PT 3/27/2019 3/27/2019 12.00 MIRU WELCTL SLKL T R/U Halliburton slick line unit, P/U 07:30 19:30 lubricator, extensions, MU from tree to rig floor. PT lubricator 2500psi 15min OK, bleed off to 1000psi. RIH to retrieve Baker RBP with weight bars and pulling tool, tag up, latch up, pulled off POOH, no fish. Check fishing neck fits on retrieving tool - good. RU lubricator, test same. RIH second run, tag up, latch up, observed overpull, some drag, POOH L/DIBP#1. No visible damage; elements intact, rubbed; indications run tool sheared, therefore packer had to have 1000 to 1500psi in it. PT well 2500psi same signature drop off as before IBP set, lost 1500psi in 15minutes. 3/27/2019 3/28/2019 4.50 MIRU WELCTL ELOG T LD lubricator and R/D Halliburton unit 19:30 00:00 and R/U Pollard E-line Unit. PT lubricator 1000psi. RIH w/ # 2 Baker IBP and Set @ 9810' mid element. Fishing neck at 9803' Back up Plan Halliburton is Mixing 12.2ppg Drilling Mud Tot 500 BBLS @ mud plant Page 2/19 Report Printed: 5/3/2019 . . Operations Summary (with Timelog Depths) +r..j 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time 3/28/2019 End Time 3/28/2019 Dur (hr) 1.00 Phase MIRU op Code WELCTL ANvit Code Time P-T-X Ope Stan Depth (ftKB) End Depth(ftKB) 00:00 01:00 PHIS T Pressure test with eline tools on line bottom to 2500psi 10min rock solid 2.7bb1 to pressure up. Bleed well off to tiger tank 3bbl, no flow. 3/28/2019 3/28/2019 2,50 MIRU WELCTL ELNE T POOH with elme set tools. Break off 01:00 0330 lubricator, lay out set tool, properly sheared. Lay down lubricator, RDMO Pollard eline. 3/28/2019 3/28/2019 —2.00 MIRU WELCTL CIRC P RU to circ seawater tlown tubing and 03:30 05:30 up IA. Circ 290bbl 6bpm 1480psi adding Barilube to system, taking returns to tiger tank. SD, observe well 30min. Hook up OA to bleed trailer bleed to zero, NFT good. 3128/2019 3/28/2019 0.50 MIRU WHDBOP MPSP P Set BPV. Pressure test 1000psi 5 05:30 06:00 mins All good Bleed all pressure to 0 3/28/2019 3/28/2019 14.50 MIRU WHDBOP BOPE P N/D Tree, bleed off SSSV control line, 06:00 2030 N/U BOP. Rig BOP to straighten. Change out VBR Bottom set rams to 7". Inspection on All Ram bodies - between well maintenance 3/28/2019 3/29/2019 3.50 MIRU WHDBOP BOPE P FTU test tool, MU ,-overs to 7" donut 20:30 0000 test it and ported 3 1/2" EUE test it. Test BOPE 250psi low, 4200psi high. AOGCC Waive witness, Adam Earl. 3/29/2019 3/29/2019 —6.00 MIRU WHDBOP BOPE pi— Finish testing BOPE. Choke valve #12 00:00 06:00 failed, rebuilt. Test 7" pipe rams 250psi low / 4200psi high, LD testjt. PU 3 1/2" testjt, Cameron Whd tech stab in test jt. Test VBR with 3 1/2" test joint 250/4200psi. Test annular 250/2500psi wtih 3 1/2" test it. Test 3 1/2" FO valve. LD test it. 3/29/2019 3/29/2019 2.00 MIRU RIGMNT RGRP T Un able to get passing test on valve 06:00 08:00 #12. Change out choke valve and re- test. Good 250/4200 PSI 3/29/2019 3/29/2019 3.00 MIRU RIGMNT TL—PC-P-- P Cut Drilling line 53' off and slip 53' and 08:00 11:00 service Rig and top drive 3/29/2019 3/29/2019 2.00 MIRU RPEDPT MPSP P R711 to Pull Back pres valve and L/D 11:00 13:00 same; No press below. Work on LDS 1 lock down pin 3/29/2019 3/29/2019 2.50 COMPZN RPCOMP PULD P M/U landing joint and BOLDS. RU 13:00 15:30 control line spooler. Pull Hanger to Floor PUW 97K over Pulled 6-8 K Drag L/D Hanger Monitor well 30 mins All Good 3/29/2019 3/29/2019 3.00 T50 M PZN RPCOMP PULD P Continue L/D 3 1/2" 9.3# J-55 EUE - 15:30 18:30 Mod IPC Tubing. Spooling control line. Joints 24-34 bent. 34jts laid down, recovered 15 SS control line clamps. Pulled 20k over with TRSV in the buckled 7". RIH, set tubing in slips. Call town. Cut control line and secure to tubing with bands. Page 3/19 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time 3/29/2019 End Time 3/29/2019 Dur (hr) Phase Op Code ANvity Code Time P-T-% Operation Stan Depth (ftKB) End Dept(ftKB) 5.00 COMPZN RPCOMP TRIP P Latch on tleployment sleeve and GS 18:30 23:30 to 3 112" tubing. RIH picking up 3 1/2" DP See DP connections/ hardbanding (OD approx. 5.25") drag increase every 30ft 10k diminishing to 5k. Tag tubing cut @9765', Set down 10k on tubing cut. PU wt 112k. Stab on with top drive pump 2bpm, 1100psi set down 25k to release, PU wt showed loss of string wt. POOH standing back DP, break off deployment sleeve. TOF 3 1/2" EUE 8RM tubing 1072' Nabors 7ES RKB. 3/29/2019 3/30/2019 0.50 PROD? WELLPR CLEN P Clean and clear rig floor prepare for 23:30 00:00 eline operations. 3/30/2019 3/30/2019 5.00 PROD? WELLPR ELOG P MIRU Pollard eIme. PU Baker 3 3/8" 00:00 0500 IBP, RIH, set in 7" production casing at 1050' mid element (between collars at 1036' and 1076') leaving top of plug at 1043' from Nabors rig floor. Inflation time 70min. POOH with set tool. LD same. RDMO Pollard. 3/30/2019 3/30/2019 -3 00 PROD1 WELLPR PRTS P Pressure test IBP 1000psi 10min. All 05:00 08:00 good No loss. P/U 4 1/2" joint and Dump 16 - 5 gal buckets of sand on top of IBP tot of 50' sand. 3/30/2019 3/30/2019 2.00 PROD1 WELLPR NUND P KID BOP 08:00 10:00 3/30/2019 3/30/2019 2.00 PROD1 CSGRCY NUND P Wellhead remove Tubing head 10:00 12:00 Flange and Prep Well head for Hydratight remove IA valve flange and studs. Leave open OA as we work on well head 3/30/2019 3/30/2019 3.00 PR0D1 CSGRCV NUND P Start break out well tubing spool and 12:00 15:00 hook up bolls to allowing well head to grow approximately 12inches. 3/30/2019 3/30/2019 1.00 PROD1 CSGRCY NUND P Pull tubing head off r stump, pull 15:00 16:00 pack off 3/30/2019 3/30/2019 1.50 PROD1 CSGRCY TRIP P PU Baker fishing tools, MU spear, 16:00 17:30 align and spear 7" pull 125K up. Pull slips. Release tension, release spear, grew approximately 6m addiitional. 3/30/2019 3/30/2019 4.00 PROM CSGRCY NUND P NU 11 x 13 5/8" adapter spool, BOP 17:30 21:30 on same. Straighten BOP. Install riser. 3/30/2019 3/30/2019 2.00 PROD1 CSGRCY TRIP P PU Baker 55 mechanical casing 21:30 23:30 cutter. RIH on 3 1/2" DP out of derrick. Sat down 15k at 733' unable to pass restriction in 7" casing. POOH. LD 5.5m cutter. 3/30/2019 3/31/2019 0.50 PROD1 CSGRCY TRIP FF-- PU Baker 45 mechanical casing 23:30 0000 cutter RIH on 3 1/2" DP out of derrick 3/31/2019 3/31/2019 1.00 PROD1 CSGRCY CUTP 5 RIH to cut depth. Pump 2bpm, 00:00 01:00 550psi, rot 60rpm, 900ft1b. Saw antic pak in returns. Cut 7" casing at 936', 800psi @ 2bpm, torque ranging 900-1200ft1b, 60- 70rpm, spike to 2000ft1b two times, then even out at 1200ff1b, appear to be through casing. Page 4119 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log start Time 3/31/2019 End Time 3/31/2019 our (hd 1.50 Phase PROD' Do Code CSGRCY Activity Corte Time P -T -x0 P eration start Depth (ftKB) End Dept (11KB) 01:00 02:30 TRIP P POOH, found bull nose left in hole, box looking up, 4 1/8", 8in long; Dogs on cutter intact but difficult to operate. Bring casing spear to floor. 3/31/2019 3/31/2019 0.50 PR0D1 CSGRCY PULL P Stab in with spear to 7" casing in 02:30 03:00 wellhead. Pull up, UWT=75k casing free. Release spear. 3/31/2019 3/31/2019 1.00 PROD? CSGRCY KURD P Rig up to circulate LRS hot diesel 03:00 0400 through cement line down DP, through the 7" out cut and up OA taking returns to tiger tank. Stab spear, pull up on casing. 3/31/2019 3/31/2019 5.00 PROD? CSGRCY CIRC P LRS Pump 64bb 1180deg diesel at 04:00 09:00 approx 2bpm, SD and allow to soak 1 hr. LRS pump 100bbl heated seawater, allow to soak 20min; circ out heated seawater at 6bpm until good clean seawater returns. RD LRS, cement line. Bring 7" tongs and handling tools to floor. RU to pull casing. 3/31/2019 3/31/2019 5.50 PR0D7 CSGRCY PULD P POOH, LD 7" with spear, change 09:00 1430 elevators and continue POOH L/D 7" Casing Tot 21 full joints and 2 cut joints (cut looks good) - lost one centering guide, recovered 7. Pulled tight every 40ft for 5 joints. The last 5 joints corkscrew see in photo file Clean up floor, RD Weatherford casing tools. PU, Release spear, LD same 3/31/2019 3/31/2019 0.50 PROD? RIGMNT OTHR P . Inspect the derrick and top drive due 14:30 15:00 to over pulled on the 7" casing a Surface jumping as pulling up F/ 65k T/ 135k the first 5 joints 3/31/2019 3/31/2019 2.00 PROD1 CSGRCY ROPE P Install test plug and test Flange 15:00 17:00 connection on Casing heart / BOP stack 250/2500 PSI Pull and LD test plug. 3/31/2019 3/31/2019 2.00 COMPZN RPCOMP TRIP T M/U Baker 6- ffshing magnet and RIH 17:00 19:00 T/ 1002' (no problem entering 7") work up and down rotating slow at 1002', POOH. Recovered one bracket. LD magnet. 3/31/2019 3/31/2019 1.50 COMPZN RPC 0 MMP TRIP T RIH with crossover sub, pin looking 19:00 20:30 down. Rotate and work pipe, POOH, did not recover bullnose. No sign of threads engaging. 3/31/2019 3/31/2019 1.00 COMPZN RPCOMP SHAH T PU and MU 6 1/8" OD x 4 3/8" ID 20:30 21:30 reverse circulating junk basket, two boot baskets and oil jars. 3/31/2019 4/1/2019 2.50 COMPZN P`PCOMP TRIP T TIH, sat down wt at 735', PU, got 21:30 00:00 through, continue in hole to top of 7" cut at 936', rotate and circulate, fell through, saw artic pack in returns, CBU until returns clean up. Continue in hole. 4/1/2019 4/1/2019 1.00 COMPZN RPCOMP FISH T Circ 8.5bpm and operate RCJB. Work 0000 0100 down 1Oft into sand. Page 5/19 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Dept (ftKB) 4/1/2019 4/1/2019 1.50 COMPZN RPCOMP TRIP T POOH. Recovered one portion of 01:00 02:30 centralizing guide, lodged in the bottom. Clean and check traps. Run back in hole. 4/1/2019 4/1/2019 0.50 COMPZN RPCOMP CIRC T Rotate in hole to 1020', 30RPM, 1-4k 02:30 03:00 ftlb 15min then bring pumps on 10bpm, 1300psi pick up to 1010' and operate RCJB, without rotating. 20ft of sand remains on top of plug. 4/1/2019 4/1/2019 1.00 COMPZN RPCOMP TRIP T POOH. Check and clean traps and 03:00 04:00 boot baskets. Recovered small pieces of centralizer. 4/1/2019 4/1/2019 0.50 -CO MPZN RPCOMP BHAH T LD RCJB, PU 5 7/8" overshot. 04:00 04:30 4/1/2019 4/1/2019 2.50 COMPZN RPCOMP FISH T RIH W overshot .Tag up @ 1025Work 04:30 07:00 pipe Attempt to latch up set down 2-6K POOH No Fish 4/1/2019 4/1/2019 5.00 COMPZN FTPCOMP FISH T RIH w/ Same Over shot 5 7/8" 3X to 07:00 12:00 recover Fish and Centralizer, Baker Bullnose Pump sweep @ 10bpm, 400psi. L/D Bull nose RiH open End to 943' 4/1/2019 4/1/2019 6.00 PROD? WELLPR MPSP P Dump more sand on top of plug f/ 12:00 1800 1030'T/ 997'. Establish circulation, RIH, tag to confirm TOS @ 997'_ POOH 4/1/2019 4/1/2019 3.50 PROD1 WELLPR MILL T7— PU 8.375" string mill on 3 1/2" DP, TIH 18:00 21:30 T/730', Pick up to 725' establsh parameters 60rpm 700ft1b, 5bpm 100psi. Mill restriction in 9 5/8" casing 60rpm 1000-3800fi 2k WOB 100psi 5bpm F / 730' , T/ 740'. Unable to slack off. 4/1/2019 4/1/2019 0.50 PR0D1 WELLPR SVRG P Rig service 21:30 22:00 4/1/2019 4/2/2019 2.00 PROD1 WELLPR RGRP T Trouble shoot drawworks emergency 22:00 00:00 brake. Pump occasionally 4/2/2019 4/2/2019 1.00 PROD1 WELLPR RGRP T Remove guard from disc brake and 00:00 01:00 attempt to disengage. Lock out brake. CBU. 4/2/2019 4/2/2019 2.00 PROD1 WELLPR MILL P Resume milling restriction in 9 5/8" 01:00 0300 casing 10min, fell through. Continue in hole to tag 7" stub at 936'. POOH Tot Milling time 2.25 hrs 4/2/2019 4/2/2019 0.50 PROD1 WELLPR SHAH P LD 8 3/8" mill, found bull nose and top 03:00 0330 connection showing signs of wear PU 8 1/2" string mill. 4/2/2019 4/2/2019 4.00 PROD1 WELLPR MILL P RIH w/ 8 1/2" string mill F1730' milling 03:30 0730 T/743' Tot Time Milling 1.5 Hrs RIH to top of 7" stub @ 936' and pump hi vis sweep around @ 8 BBIs min w/ 300 PSI POOH Page 6119 ReportPrinted: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stars Time 4/2/2019 End Time 4/2/2019 Dur (hr) 6.50 Phase PROD1 Op Code Activity Code Time P -T -X Operabon Start Depth (fiKa) End Depth (MIKE) WELLPR MILL P M/U 8 3/4" Mill RIH and Tag up @ 126' 07:30 14:00 in Start Milling @ 07:30 F/126' . Milling Parameters: 8 bpm, 85 psi, 60 RPM, TO off btm 620 ft/lb, TO on btm 3500 ftlbs. Ream troubled area from 115' to 138', four times. Attempt to drift troubled area and tagged at 132'. Losing ground when working pipe. POOH to surface to inspect mill, observed sever gouging in mill fishing neck and drill pipe tool joint, approximately 1/4" deep gouging on mill. Trip back in hole and tag same spot at 132', able to rotate through spot. Continue in hole to mill troubled area at approximately 736'.T/740' RIH and tag up 7" top @ 936'. 4/2/2019 4/2/2019 0.50 PROD? WELLPR CIRC P Pump 10 bbls Hi vis sweep @ 8 bbls 14:00 14:30 w/ 520 psi and circulate bottoms up. 4/2/2019 4/2/2019 0.50 PROD1 WELLPR TRIP P POOH UD mills Tot Time milling on 9 14:30 15:00 5/8" casing 3 Hrs. 4/2/2019 4/2/2019 0.50 PR0D1 WELLPR BHAH P Pick up tandem string milling 15:00 1530 assembly. Pick up 8.5" and 8.75" string mills. 4/2/2019 4/2/2019 3.00 PROD1 WELLPR MILL P Trip in hole and tag casing obstruction 15:30 1830 at 126'. Mill with tandem string mill assembly from 115'to 143'. Milling parameters 8 bpm, 470 psi, 60 rpm, TO off 780, TO on 3900, and WOB 1- 5k. Pump hi -vis sweep and trip in hole, no rotation, to 200'. POOH to 110' and attempt to drift again, tagged at 130'. Mill from 126' to 130'. 4/2/2019 4/2/2019 1.50 PROD1 WELLPR TRIP P Trip in hole with tandem string mill 18:30 2000 assembly from 130' to 262'. Took approximately 10k weight at 262'. Rotate through spot with 60 rpm, 2-3k torque, 5bpm at 200 psi. 4/2/2019 4/2/2019 2.00 PROD1 WELLPR MILL P Wash and ream with tandem 20:00 22:00 assembly from 730' to 750'. 8 bpm, 500 psi, 60 rpm, TO off 1000, TO on 3500-7500, WOB 1-51k. 4/2/2019 4/2/2019 0.50 PRODt WELLPR CIRC P Pump 10 bbls hi -vis sweep. Circulate 22:00 22:30 2 bottoms up at 8 bpm with 550 psi. 4/2/2019 4/3/2019 1.50 PROD1 WELLPR TRIP P POOH from 936't surface. Lay down 22:30 00:00 tandem string mills. 4/3/2019 4/3/2019 5.00 PROD1 WELLPRMILL P M/U Baker r dress off mill and RIH to 00:00 05:00 936' and Dress off top stub T/ 937' swallow 2.8' of stub. All good and spot 1 drum Bara Lube Friction reducer in hole. POOH and UD Dress off shoe Tot Time dress off stub 1.5 hours. 4/3/2019 4/3/2019 1.50 PROD1 WELLPR CLEN P Clean up Floor and Flush out slack. 05:00 0630 12 bpm, 1300 psi, 20 rpm. Blow down choke and kill lines. 4/3/2019 4/3/2019 1.50 PROD1 WELLPR RURD P PJSM with Weatherford and rig crew. 06:30 0800 Rig up Weatherford Casing equipment. 4/3/2019 4/3/2019 1.00 PROD1 RPCOMP -FTU-NL P Make up Baker casing patch sealing 08:00 09:00 overshot. Make up 7" L-80 26# HYDRIL 563 casing to 9400 fibs. RIH from surface to 132'. Tag 9 5/8" casing obstruction at 132', unable to work pipe or rotate through spot. POOH laying 7" down. Page 7119 Report Printed: 5/3/2019 r Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log StanTine End Time our (hr) Phase Op Code Activity Code Time e P -T -X Operation Stan Depth (WB) End Depth dtKB) 4/3/2019 4/3/2019 0.50 PROD1 RPCOMP RURD P Rig down Weatherford 7" casing 09:00 0930 equipment. 4/3/2019 4/3/2019 1.00 PROD1 RPCOMP OTHR P Load 6 1/4" drill collars into pipe shed. 09:30 10:30 Strap, drift and tally drill collars. Load string mills into shed. 4/3/2019 4/3/2019 1.50 PROD1 RPCOMP BHAH P PU and MU 3-6 1/4" drill collars, 1- 8 10:30 12:00 1/2" string mill, 1- 8 3/4" string mill and bull nose to 107'. Make up blower hose to top drive. 4/3/2019 4/3/2019 6.00 PRODt RPCOMP MILL P Make up stand of 3 1/2" drill pipe and 12:00 1800 drift in hole to 127'. Tag up on 9 5/8" obstruction at 127'. Begin milling at 127'to 143' with following parameters: 8 bpm, 570 psi, 60/80/100 RPM, TQ off 1500 ftlbs, TQ on 4000 ftlbs. Ream through obstruction area 4 times, able to pass trough obstruction with 9k weight. Continue in hole with 3 1/2" drill pipe until tagging obstruction at 252'. Begin milling obstruction with same parameters. 4/3/2019 4/4/2019 6.00 PROD1 RPCOMP MILL P Continue Milling obstruction f/ 252' 18:00 00:00 U280 and 737 U 751 with 1-3 k on mills Tq 2000-2500 70 RPM w/ 9bbls min w/ 1420 psi 4/4/2019 4/4/2019 -2 00 PRODt RPCOMP MILL P Continue Milling obstruction f/737 U 00:00 02:00 751 with 1-3 k on mills Tq 2000-2500 70 RPM w/ 9bbls min w/ 1420 psi Tag Up on 7" stub @ 936' pump 10 tins sweep All good 4/4/2019 4/4/2019 0.50 PROD? RPCOMP CIRC P Pump 10 bbls of hi -vis sweep. 02:00 02:30 Circulate 2 bottoms up at 10 bpm and 900 psi. 4/4/2019 4/4/2019 3.00 PROD1 RPCOMP TRIP P POOH Change out BHA MTU 8 3/4" 02:30 05:30 mill w/ dress off shoe and 6 1/4" d.c and RIH and push with 2-4K through 136-142'. Continue RIH and dress off stub. 4/4/2019 4/4/2019 0.50 PROD1 RPCOMP CIRC P Spot 40 bbls of Bara Lube pill on 05:30 0600 bottom. 4/4/2019 4/4/2019 2.00 PROD? RPCOMP TRIP P POOH from 936to 117'. Lay down 06:00 0800 BHA 4/4/2019 4/4/2019 0.50 PRODt RPCOMP CIRC P Flush out BOP stack, kill line and 08:00 0830 choke line. Blow down top drive and clear rig floor. 4/4/2019 4/4/2019 0.50 PRODt RPCOMP SVRG P Perform rig service. Service top drive. 08:30 09:00 4/4/2019 4/4/2019 -3 00 PROD? RPCOMP FTU NL P PJSM with Weatherford and rig crew. 09:00 12:00 Rig up casing equipment. Pick up Baker sealing overshot. Run 7" L-80 26# HYDRIL 563 casing, torquing to 9400 ft)bs. Tagged up at 130', able to rotate through spot, confine in hole with casing. Continue in hole to 917'. Change out elevators to drill pipe elevators. Pick up crossover and landing joint, make up to casing stump. RIH to 933', 4' off 7" casing stub. Up weight 55k and down weight 45k. Page 8/'19 Report Printed: 5/312019 Operations Summary (with Timelog Depths) r,. 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log startTime 4/4/2019 End Time 4/4/2019 our (hr) 0.50 Phase PROD1 Op Code Activity Code Time P -T -X Operation Stan Depth (ftKB) Entl DepN (ftKB) 12:00 12:30 RPCOMP CIRC P Pressure lest LRS lines to 3000 psi. Test good. Reverse circulate 27 bbls of diesel to freeze protect 9 5/8" x 7" annulus. Engage 7" sealing overshot on to 7" casing stub at 938.5'. Pull test, 7" casing overshot engaged. 4/4/2019 4/4/2019 0.50 PROD1 RPCOMP PRTS P Pressure test 7" casing. Pressure up 12:30 13:00 to 2500 psi and hold for 10 mins. Pressure test good. 4/4/2019 4/4/2019 0.50 PROD1 RPCOMP RURD P Blow down top drive. Drain BOP 13:00 1330 stack. Rig down Weatherford casing equipment. 4/4/2019 4/5/2019 10.50PROD1 RPCOMP NUND P Nipple down BOP stack. Drain 7" 13:30 00:00 casing. Set casing slips with 75k tension, cut 7" casing stub. Install 7" casing pack off Test Pack offto 3000 PSI 15 mins N/U Tubing spool and Adapter flange,set test plug 4/5/2019 4/5/2019 2.50 PROD1 RPCOMP NUND P N/U BOP and install secondary anti 00:00 02:30 valve 4/5/2019 4/5/2019 1.50 PROD1 RPCOMP BOPE P R/U test Equipment and test Adapter 02:30 04:00 flange and spool 250/4200 psi 5min low and 5min high R/D test equipment and set wear ring 4/5/2019 4/5/2019 1.00 PROD1 RPCOMP BHAH P M/U Baker BHA# 21 with RCJB,2 04:00 05:00 Boot Basket ,2 magnets B.S O.J. and XO 4/5/2019 4/5/2019 1.50 PR0D1 RPCOMP TRIP P Trip in hole from 61'to 913'. 05:00 06:30 4/5/2019 4/5/2019 1.50 PR0D1 RPCOMP WASH P Hook up blower hose, connect top 06:30 0800 drive and wash in hole with following parameters: 2 bpm, and 154 psi. Tag sand @ 976', tagged sand high approximately 20'. Begin rotating at 80 rpm, increase flow rate to 7 bpm, 1520 psi, TQ off 950 ftlbs, TQ on 4500 ftlbs, WOB 5k. Mill from 976' to 984'. No sand observed at shakers, cement slurry observed at shakers. Due to slow progress, decided to POOH and inspect RJCB for plugging. 4/5/2019 4/5/2019 2.50 PR0D1 RPCOMP TRIP P POOH from 984'to surface. Inspect 08:00 1030 cleanout BHA. Observed large amount of fine metal shavings accumulated on both magnets. When inspecting the RCJB observed RCJB was plugged with metal shavings and pieces. Breakdown BHA and lay out the same. 4/5/2019 4/5/2019 1.50 PROD1 RPCOMP BHAH P Pick up Junk mill assembly as follows: 10:30 12:00 6 118" junk mill, 2- boot baskets, bit sub, extreme magnet, grabitz magnet, bumper sup, oil jars, 9- 4 3/4" DC's, XO and drill pipe. 4/5/2019 4/5/2019 1.50 PROD? RPCOMP WASH P Trip in hole with junk mill assembly 12:00 13:30 from surface to 982'. Begin washing from 982' to 997', no indication ofjunk in hole. Parameters as follows: 80 rpm, TQ off 890, TQ on 970, 3 bpm and 216 psi. Observed sand back at shakers. Page 9/19 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log SartTime End Time Dur(h,) Phase Op Code Agivily Code Time P -T -X Operation Start Depth (ftKB) End Depth (WD) 4/5/2019 4/5/2019 2.00 PROD1 RPCOMP TRIP P Pump 10 bbls of Hi-Vls sweep at 8 13:30 15:30 bpm and 1370 psi. Circulate sweep out of hole. POOH from 997' to surface with junk mill assembly Rack back drill collars, clean magnets and boot baskets, and lay down junk mill. 4/5/2019 4/6/2019 8.50 PROD1 RPCOMP BHAH P Pickup Cleanout assembly as follows. 15:30 0000 RCJB, DBL pin sub, 2- boot baskets, bit sub, extreme magnet, grabitz magnet, bumper sub, oil jars, 9- 4 3/4" DC's, and XO sub.RIH 3X w/ RCBP Pic in s -drive ofjunk UD BHA# 25 4/6/2019 4/6/2019 1.50 PROD1 RPCOMP -BH-AH-F7- Lay down BHA from 337' to surface. 00:00 01:30 M/U BHA # 24 with retrieving tool 4/6/2019 4/6/2019 1.50 PROD1 RPCOMP MPSP P RIH and latch up on RBP @ 1043' and 01:30 03:00 Release RBP Monitor well 15 mins all good. 4/6/2019 4/6/2019 1.50 PROD1 RPCOMP TRIP P POOH UD RBP. Bow down top drive. 03:00 04:30 4/6/2019 4/6/2019 1.50 PROD1 RPCOMP TI -SH -P- MIN BHA# 25 with pump out sub 04:30 06:00 retrieval head. RIH to recover 3 1/2" tubing @ 1070' and latch up on tubing. Tag stump at 1073'. Unable to latch on to fish. Pump 1.5 bpm with 685 psi and wash down to latch on to tubing. Unable to latch on to tubing. 4/6/2019 4/6/2o19 0.50 PROD1 RPCOMP TRIP P POOH from 10-46 to surface. 06:00 0630 4/6/2019 4/6/2019 2.00 PROD1 RPCOMP FISH P Lay down retrieving head. Make up 06:30 0830 overshot. RIH to 1046', pick up single and Kelly up. Break circulation with 4 bpm and 340 psi. Wash over fish at 1076'. Pull 100k, overshot engaged on fish. POOH, while POOH fish saw reduction in string weight, Tubing string parted. Continue to POOH. String weight 52k, approximately 4 k over original weight. Partial fish engaged. 4/6/2019 4/6/2019F1.50 PROD1 RPCOMP TRIP P POOH from 1046' with partial tubing 08:30 09:30 string engaged to overshot. Up weight 52k. 4/6/2019 4/6/2019 PROD1 RPCOMP RURD P Rig up 3 1/2" tubing tongs. Make up 09:30 11:00 pup joint to overshot. When overshot at surface observed 3 1/2" tubing engaged in overshot with control line wrapped around tubing and in overshot. Lay down overshot and one joint of 3 1/2" tubing. Rig up control line spool. Change out elevators and prepare to POOH with partial 3 1/2" tubing string. 4/6/2019 4/6/2019 3.50 PROD1 RPCOMP PUTB P POOH with partial 3 1/2" 9.3# J-55 11:00 14:30 EUE modified tubing and control line. Laying 3 1/2" tubing down. Approximately 750' (24 joints) of tubing recovered. 3 1/2" completion string parted at top of SSSV (3.91' recovered), approximately 7.76' of SSSV and 7943' of 3 1/2" tubing left in hole. SSSV body looking up 5 5/8" OD, and ID of 2 7/8". Atotal of 32 bands originally ran, 27 recovered, 5 bands left in hole. Estimated TOF 1820'. Page 10/19 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Sart Time End Time our (hr) Phase Op Code Activity ivity Code Time P-T-X Operation Depth (ftKB) End Depth(ftKB) 4/6/2019 4/6/2019 3.00 PROD? FISH OTHR T Wait on Baker fishing Tools and 14:30 17:30 service Top drive Derrick Inspection 4/6/2019 4/6/2019 1.00 PROD1 FISH -ETH-AH T M/U BHA# 27 W/ spear 2 7/8" grapple 17:30 18:30 4/6/2019 4/6/2019 3.50 PR0D1 FISH TRIP T RIH W/ drill pipe to 1818' Attempt to 18:30 22:00 latch up on fish No go POOH and UD BHA#27 4/6/2019 4/7/2019 2.00 PROD1 FISH FISH T M/U BHA 28 with Ext and 2.812 22:00 00:00 Grapple RIH tag up @ 1818'Attempt to latch up no go POOH 4/7/2019 4/7/2019 1.50 PROD1 FISH FISH T POOH from 1818'to 24'. Lay down 00:00 01:30 BHA/ Spear. Up weight 55k. 4/7/2019 4/7/2019 4.50 PROD1 FISH FISH T RIH w/2.812 grapple Attempt to latch 01:30 0600 up on fish @ 1818' No go POOH and I/D 2,812 grapple and M/U 2.31 RIH for Drift run tag up same spot@ 1818' pump Hi vis sweep 10 bbls POOH L/D Drift and order more fishing tools 4/7/2019 4/7/2019 1.00 PROD1 FISH SVRG T Perform rig service. Clean and clear 06:00 07:00 rig floor. 4/7/2019 4/7/2019 5.50 PROD1 FISH SLKL T Rig up Pollard slick line unit. RIH with 07:00 12:30 braided line brush. Tag top offish at 1822' SLM. POOH and recover 3 stainless steel bands. Leaving 2 bands in hole. RIH again with braided line brush to attempt to enter top of fish and ensure clear of obstructions in order to fish with spear. POOH and recover remaining 2 stainless steel bands. All bands recovered, total of 32. RIH with braided line brush again (3rd run). POOH recovered nothing, entered TOP fish approximately 8" to 1832'. Make 4th run and still unable to enter TOF pass 8" from top. Lay down braided line brush and RIH with Bailer. Unbale to enter TOF, nothing bailed. Lay down bailer and run Lead Impression Block. POOH and observe LIB. Observed half moon circular impression, approximately 3 1/2" long and 2 3/8" wide. 019 4/7/2019 0.50 PROD1 FISH RURD T Rig down Pollard slick line equipment. 12:3 12:30 13:00 4/7/2019 4/7/2019 0.50 PROD1 FISH BHAH T Pickup BHA# 30 as follows: Bull 13:00 13:30 nose junk mill (3.34' of stinger w/ 2 3/4" mill on end), 6" packer mill, Drive sub, boot basket, bit sub, stabilizer, bumper sub, XO, 1- pup joint. 4/7/2019 4/7/2019 1.50 PROD? FISH TRIP T Trip in hole from 30'to 1733'. Hook up 13:30 15:00 blower hose and Kelly up. 4/7/2019 4/7/2019 1.50 PROD? FISH REAM T Break circulation at 2 bpm and 150 15:00 16:30 psi. RIH and tag TOP offish at 1819'. Rotate at 50 rpm, TO off 970 ftlbs, TO on 1300 ftlbs. Mill down to 1823' with 2 3/4" mill to enlarge SSSV ID. Ream up and down 3 times. Drift 2 3/4" mill into SSSV with no rotary, successfully drifted. Pump 10 bbl hi-vis sweep and circulate out of hole. 4/7/2019 4/7/2019 5.50 PROD? FISH TRIP T POOH with packer milling 16:30 22:00 assembly.UD M/U BHA# 31 W/ 2.875 grapple and Ext RIH and Latch up @ 1824' POOH PUW 107K Page 11119 ReportPrinted: 5/312019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 4/7/2019 4/8/2019 2.00 PROD1 RPCOMP PULL P LID spear and SSSV R/U Tubing 22:00 00:00 Equipment and LID 3 1/2" # 9.3 J-55 EUE production string 4/8/2019 4/8/2019 11.50 PROD1 RPCOMP PULD P Continue UD 3 1/2" #9.3 J-55 EUE 00:00 11:30 tubing 4/8/2019 4/8/2019 0.50 5R0D1 RPCOMP SHAH P Pick up fishing BHA and break out 11:30 1200 overshot and SSSV Lay out the same. 4/8/2019 4/8/2019 0.50 PROD1 RPCOMP GLEN P RD tubing tongs. Clean and clear rig 12:00 1230 Floor Prep floor to rig up E -line. 4/8/2019 4/8/2019 1.50 PRODi RPCOMP RURD P PJSM with rig crew and SLB E -line 12:30 14:00 crew. Spot wire line unit. Pickup Caliper tools and rig up a -line equipment. 4/8/2019 4/9/2019 10.00 PROD1 RPCOMP ELOG P RIH with Caliper tools to 4000' and 14:00 00:00 caliper 7" casing. POOH laying down Caliper tools and pick up/make up CBL tools. Perform CBL log on well From 4000' to surface. R/D SLB -E-line 4/9/2019 4/9/2019 0.50 PROD1 RPCOMP KURD P Continue laying down SLB wire line 00:00 00:30 tools. 4/9/2019 4/9/2019 4.00 PROD? RPCOMP TRIP P M/U Baker RBP and RIH, P/U 42 00:30 04:30 singles Set RBP @3111' POOH 200', test 1/2500 psi 10 mins All good 4/9/2019 4/9/2019 3.00 PROD? RPCOMP OTHR P Dump sand on top of RBP @ 3100' 04:30 0730 100' on top of RBP. Tag sand with drill pipe at 3035'. 4/9/2019 4/9/2019 2.00 PR 0 D 1 RIRPCOMP TRIP P POOH from 3035'to surface. Lay 07:30 0930 down mechanical setting tool. 4/9/2019 4/9/2019 1.50 PROD? RPCOMP TRIP P Pick up Baker 7" mechanical cutting 09:30 11:00 tool. Trip in hole from 7'to 1944'. Make up blower hose, connect top drive. Pump 2 bpm at 270 psi and locale casing collar with knives at 2077'. Lay down single and pick up 5' pup joint. 4/9/2019 4/9/2019 1.00 PROD1 RPCOMP KURD P PJSM with rig crew and LRS. Rig 11:00 1200 LRS to OA. Rig up OA to tiger lank. 4/9/2019 4/9/2019 0.50 PROD1 RPCOMP CUTP P Cut 7" casing at approximately 2055'. 12:00 12:30 Good indication from pressure and torque drop off casing cut. Open OA to tiger tank and pump to observe returns to tiger tank. 7" casing confirmed cut. Blow down top drive. 4/9/2019 4/9/2019 8.00 PROD1 RPCOMP CIRC P RU side entry sub and cement hose to 12:30 2030 stump. Pump 50 bbls of hot diesel down drill string out the OA to the tiger tank to displace arctic pack. Chase with 15 bbls of seawater down drill pipe to clear string of diesel. Shut down and allow diesel to soak for 1 hour. Pump approximately 80 bbls of hot seawater to displace diesel out the OA. Good clean brine observed on surface. Monitor 1 hr All good 019 4/9/2019 1.50 PROD1 RPCOMP TRIP P POOH and L/D Baker BHA # 33 20:30 20:3 22:00 4/9/2019 4/10/2019 2.00 PROD1 RPCOMP NUND P Start N/D BOP and stop N/D BOP 22:00 00:00 Well U -tubing up 7" casing side and stop U -tubing Monitor well 1 hr No Flow Mud wt on Ann 8.8 and Tubing side clean SAN W/ 8.5 Page 12/19 Report Printed: 5/3/2019 1.. Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Op Cotle Activity Code Time P -T -X Operation Start Depth (W!3) End Depth(ftKB) 4/10/2019 4/10/2079 0.50 PRO 1 0RPCOMP OWFF T Continue Circulate Clean S/W and 00:00 0030 take Returns to flow Back tank pump 2 B.U. and Shut down and monitor flow back 8 bbls Back and Continue to monitor well IA and OA open No Flow @ 03:00 Small dribble out OA and IA 5 gals in 20 mins 4/10/2019 4/10/2019 1.00 PROD? RPCOMP NUND T Nipple up BOP. Install turn buckles, 00:30 01:30 and riser. Torque flanges. While nippling up BOP observed well to start to flow. Well out of balance, U -tubing. 4/10/2019 4/10/2019 2.50 7ROD1 RPCOMP CIRC T Close blind rams and pump 165 bbls 01:30 0400 of 8.5 ppg clean seawater through kill line. Pump at 3.5 bpm at 200 psi. Taking returns to flow back tank. 82 bbls returned to surface, losing 83 bbls of fluid to the hole. 4/10/2019 4/10/2019 3.00 PROD1 TPCOMP T Well continuing to u -tube. Allow well 04:00 0700 to u -tube to equalize, monitoring flow out the OA and IA. No flow observed after approximately 3 hours of allowing u -tube to balance. 4/10/2019 4/10/2079 2.50 PROD1 RPCOMP NUND T Nipple down BOP. Blow down choke 07:00 09:30 and kill line. Pull riser, remove turn buckles. Set BOP on stump. Nipple down tubing spool. 4/10/2079 4/10/2019 0.50 PROD? RPC MMP PULL T Pull 7" casing packoff. Make up 7" 09:30 10:00 casing spear. Spear 7" casing and pull 7" casing slips. While pulling 7" casing to rig floor well began to u -tube up casing and drill pipe, clean seawater observed at surface. 4/70/2019 4/10/2019 6.00 FROM RPCOMP OWFF T Monitor returns on trip tank. Well u- 10:00 16:00 tubing at approximately 36 bbls/hr. Continue to monitor well while building 30 bbls of 10 ppg slug. Prepare to pump dryjob and make up crossovers to hang 7" casing in well head. 4/10/2019 4/11/2019 8.00 PR0D1 RPCOMP OWFF T NU BOP Continue monitor well and 16:00 00:00 build 8.6 U10.2 and Pump 140 bbls 10.2 brine static lost rate 15 bbls Hr monitor well 2 hr R/U 7" casing Equipment L/D Baker spear and cut Dint. 4/11/2019 4/11/2019 4.00 PROD? RPCOMP PULD 5 Continue lay down 7"Hyd 563 casing 00:00 04:00 and cut back 10.2 brine t/ 9.9 brine. L/D 21 joints 563 and 1 cut joint and 26 joints BTC 1 cut BTC join Total. 4111/2019 4/11/2019 1.00 PR0D1 RPC 0 MMP CLEN P Clean up Floor and break down baker 04:00 05:00 7" casing spear f/ cut joint and m/u BHA 36 lost rate 5 BBIs Int -filling hole w/9.9 brine 019 4/11/2019 1.00 PROD? RPCOMP PULD P Lay down spear and cut 7" joint. 05:00 05:00 06:00 4/11/2019 4/11/2019 1.00 PROD? RPCOMP SVRG P Perform rig service. Service top drive. 06:00 07:00 Inspect and strap 6 1/4" drill collars. 4/1112019 4/17/2019 1.00 PROD1 RPCOMP BHAH P Pick up Baker milling assembly as 07:00 08:00 follows: Bull nose, String mill (8 5/8"), flex joint, string mill (8 3/4'), 3- 6 1/4" drill collars, and XO. RIH to 116'. 4/11/2019 4/11/20191.00 PROD1 RPCOMP TRIP P RIH from 116'to 135'. Tag up with 9k 08:00 09:00 at 135'. Page 13/19 Report Printed: 5/312019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our (hr) Phase Op Code ActNity Code Time P -T -X Opembon Start Depth mKa) End Deah(ftKB) 4/11/2019 4/11/2019 6.00 PROD1 RPCOMP MILL P Begin milling at 134'to 153' at 09:00 15:00 following milling parameters: 6 bpm, 814 psi, 80 rpm, TO off 1100 ftlbs, and TO on 3000 It lbs. Mill from 134' to 153'. Drift 9 5/8" from 153' to 226'. Tag up at 226'. Mill from 226' to 230'. Drift from 230' to 274'. Mill from 274' to 290'. Drift from 274' to 745'. Mill from 745' to 762'. Drift in hole from 762' to 2010'. Wash down to 2055', tag 7" casing stump. While milling experienced losses at rate listed below: 134' - 153' 40 bbls/hr 226' - 274' 20 bbls/hr 745'- 762' 10 bbls/hr Approximate total losses for the day - 150 bbls. 4/11/2019 4/11/2019 0.50 PROD1 RPCOMP CIRC P Pump 10 bbl hi -vis sweep. Circulate 15:00 1530 bottoms up at 6 bpm and 1066 psi. 4/11/2019 4/11/2019 6.50 TROD RPCOMP TRIP T POOH from 2006'to surface. Up 15:30 2200 weight 63k. Due to high winds and phase # 2 slow 4/11/2019 4/12/2019 2.00 PROD1 RPCOMP BHAH T LD Baker polish mill and 3- 6 1/4" 22:00 00:00 D,C. and Clean up floor R/U weatherford Casing equipmint. Go to phase 3 @ 2330 Hrs weather hold 4/12/2019 4/13/2019 24.00 PROD1 RPCOMP WAIT T Phase 3 conditions. No activity due to 00:00 0000 inclimate weather. 4/13/2019 4/13/2019 9.00 PROD1 RPCOMP WAIT T Phase 3 conditions. No activity due to 00:00 09:00 inclimate weather. 4/13/2019 4/13/2019 7.50 PROD? CASING PUTB P PJSM M/U Baker casing patch and 09:00 16:30 Halliburton Cementer on 7" 26# L-80 HYD563 casing, bow spring centralizers on every other joint, (tot 19). RIH Tot joint run # 49 w/ baker patch ,xo, halliburton,cementer 2054' PUW 82k SOW 60k 4/13/2019 4/13/2019 2.50 PROD1 CASING PUTB P R/U to wash down F/ 2045't/2054' 16:30 19:00 and patch swallow 3.5' t/ no go pick up 50k over and set slips and test t/ 1500 psi All good R/U halliburton cement Head and load plug Hold PJMP w/ crew Page 14119 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time 4/13/2019 End Time 4/14/2019 Our (hp 5.00 Phase PRODi Op Code CEMENT Activity Code Act Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 1900 0000 CMNT P PJSM with crew and Halliburton. Pump with rig pump down casing to shift cement staging tool open. Staging tool shifted at approximately 3000 psi. Circulate bottoms up at 3 bpm. Slow rate to 2 bpm at 43 psi. Pump Cement Job as follows: Pressure test cement lines to 4000 psi 5 bbls FW 20 bbls Spacer @ 10.5 ppg 183bbls Cement @ 15.6 ppg (1/2ppb Well Life LCM) 73.6 bbls of displacement with rig pumps at 9.9 ppg Plug shifted stage tool on calculated displacement. Shifting closed at 700 psi final circulating pressure with 1400 psi shift pressure for total of 2100 psi. Only partial returns to surface with no cement observed. CIE at 23:30 hours 4/14/2019 4/14/2019 2.00 PRODi CEMENT RURD P Rig down Weatherford casing 00:00 02:00 equipment. Rig down Halliburton cement head and cementing equipment. Clear and clear rig floor. 4/14/2019 4/14/2019 6.00 PROD1 WELLPR NUND P Suck fluid out of 7" casing. ND BOP 02:00 08:00 and DSA. Visually confirmed that 9 5/8" x 7" annulus void of fluid. Unable to see fluid level. Install 7" casing slips with 50k ftlbs of tension. Install 7" packoff. Nipple up tubing spool. Test 7" casing packoff to 250 psi low for 5 minutes and 3000 psi high for 10 minutes. Test good. 4/14/2019 4/14/2019 1.00 PROD1 WELLPR CIRC P RU Little Red Services to 9 5/8" 08:00 09:00 casing valve. Pump20 bbls of diesel down 9 5/8" x 7" annulus at.25 BBI min w/80 psi and @ 1.5 bbl min w370 psi. no pres. 4/14/2019 4/14/2019 4.50 PR0D1 WELLPR NUND P Continue to NU 13 5/8" BOP stack to 09:00 13:30 tubing spool. Change out 7" casing rams to 2 7/8" x 5 1/2" VBR's. Install riser. R/U test equipment 4/1412019 4/14/2019 4.50 PROD1 WELLPR BOPE P PERFORM BOP TEST. 250/4200 5 13:30 18:00 MIN LOW&HIGH (W/AOGCC BRIAN BIXBY WITNESS) 4-14-19 @13:30 HRS 4/14/2019 4/14/2019 1.00 PROD1 WELLPR RURD P Lay down test tool, test joint. blow 18:00 19:00 down choke manifold. 4/14/2019 4/14/2019 0.50 PROD1 WELLER OTHR P Install wear bushing. 19:00 19:30 4/14/2019 4/14/2019 1.00 PROD1 RPCOMP BHAH P Pick and make up Cleanout assembly 19:30 20:30 (mill tooth bit BHA # 37) as follows: Tri -cone bit, 2- boot baskets, bit sub, bumper sub, oil jars, 9- 4 3/4" DC's, and XO sub. 4/14/2019 4/14/2019 1.50 PROD1 RPCOMP PULD P RIH picking up 3 1/2""singles of drill 20:30 22:00 pipe from 306'10 2009'. Make up blower hose. Up weight 65k and down weight 60k. Page 15119 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time log Start Time End Time Dur (hp Phase Op Code Activity Code Time P-T-X Operah.n Stag Depth (nKB) End Depth(ftKB) 4/14/2019 4/15/2019 2.00 PROD1 RPCOMP DRLG P RIH from 2009 to 2033'. Tag cement 22:00 00:00 stringers at 2033' with 10k. Establish drilling parameters as follows: 5 bpm, 355 psi, 60 rpm, TQ off i k ftlbs, TQ on 1.3k ftlbs and WOB 5-71k. Up wt 62k, Down wt 60k, Rot wt 62k. Drill cement stringers from 2033' to 2041' (top of plug). Mill cement plug, observed rubber back at shakers. 4/15/2019 4/15/2019 8.00 PROD1 RPCOMP MILL P RIH from 2009 to 2033'. Tag cement 00:00 08:00 stringers at 2033' with 10k. Establish drilling parameters as follows: 5 bpm, 355 psi, 60 rpm, TQ off 1k ftlbs, TQ on 1.3k ftlbs and WOB 5-7k. Up wt 62k, Down wt 60k, Rot wt 62k. Drill cement stringers from 2033' to 2041' (top of plug). Mill cement plug, observed rubber back at shakers Clean and wash down to 3019' CBU 4/15/2019 4/15/2019 7.50 PROD1 RPCOMP TRIP P POOH and UD clean out Bit and M/U 08:00 15:30 Baker junk reverse basket and P/U single out of pipe shed U 3019' 4/15/2019 4/15/2019 1.50 PROD1 RPCOMP WASH P Wash down to top if sand @ 3019't/ 15:30 1700 3045' CBU @ 7.5 BBIs min 4/15/2019 4/15/2019 3.00 PROD1 RPCOMP TRIP P POOH clean out reverse basket from 17:00 2000 3041' to 337'. Rack back drill collars. Clean magnets. 4/15/2019 4/15/2019 1.00 PRODt RPCOMP BHAH P Pick up BHA with reverse circulating 20:00 21:00 basket. 4/15/2019 4/15/2019 2.50 PROD1 RPCOMP TRIP P Pick up 3 1/2" drill pipe singles from 21:00 2330 33T to 2608'. RIH from 2608'to 3042'. Up wt 82k, down wt 65k. 4/15/2019 4/16/2019 0.50 PROD1 RPCOMP WASH P Tag sand at 3042'. Wash down to 23:30 0000 3054'. Circulate two bottoms up at 6 bpm and 1225 psi. 4/16/2019 4/16/2019 1.50 PROD1 RPCOMP TRIP P POOH from 3054'to 337'. Blow down 00:00 01:30 Itopdrive. Up wt 82k, down wt 65k. 4/16/2019 4/16/2019 0.50 PROD1 RPCOMP SHAH P Lay down BHA. Rack back drill collars. 01:30 0200 Clean boot baskets, magnets and RCJB. RCJB was full of metal debris. 4/16/2019 4/16/2019 1.00 PROD1 RPCOMP SVRG P Perform rig service. Service draw 02:00 0300 works. Clean and clear rig floor. 4/16/2019 4/16/2019 0.50 PROD1 RPCOMP BHAH P Pick up and make up RCJB BHA. 03:00 0330 4/16/2019 4/16/2019 1.00 PROD1 RPCOMP WASH P RIH from 337' to top of sand at 3048'. 03:30 0430 Wash down to 3071' with 6 bpm and 1200 psi. 4/16/2019 4/16/2019 1.50 PROD1 RPCOMP TRIP P POOH from 3071'to 337'. Up w[ 75k 04:30 0600 and down wt 65k. 4/16/2019 4/16/2019 1.00 PROD? RPCOMP BHAH P Lay down BHA. Rack back drill 06:00 0700 collars, clean magnets, boot baskets and RCJB. RCJB clean, free of debris. Lay down boot baskets, jars, bumper sub. 4/16/2019 4/16/2019 1.00 PROD1 RPCOMP BHAH P Pick up Baker retrieving tool and 07:00 08:00 magnets. 4/16/2019 4/16/2019 1.00 PROD? RPCOMP TRIP P Trip in hole form 35'to 3042'. Tag up 08:00 09:00 at 4042' with 5 k. Up wt 75k and down wt 57k. Page 16119 Report Printed: 5/3/2019 Operations Summary (with Timelog Depths) T 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stare End Time Dur (hr) Phase Op Code Ac[Wity Code Time P -T -X Operation Start Depth (ftKB) End Depth(9KB) 4/16/201919 4/16/2019 1.50 PROD? RPCOMP WASH P Wash down from 3042'to 3059'. 09:00 1030 Circulate 2 bottoms up at 9 bpm and 1185 psi. Observed green cement and sand at shakers. Wash down to 3099'. Circulate 1.5x's bottoms up. Observe only sand at shakers. 4/16/2019 4/16/2019 0.50 PROD1 RPCOMP PRTS P Pressure test T casing. Pressure up 10:30 11:00 to 2500 psi and hold for 10 mins. Good pressure test. 4/16/2019 4/16/2019 1.00 PROD1 RPCOMP CIRC P Pump 35 bbls hi -vis sweep and 11:00 12:00 displace well bore from 9.9 ppg to 8.6 ppg seawater. Taking 9.9 ppg brine to the cuttings tank. 4/16/2019 4/16/2019 1.50 PROD1 RPCOMP MPSP P New up weight 77k and down wt 62k 12:00 1330 after displacement. Pumping 4 bpm, slack off from 3099' to 3104', set dawn approximately 4k to engage retrieving tool on RBP. Release RBP, allow rubber elements to relax for 15 mins. Rack back one stand and monitor well for Flow for 10 mins. 4/16/2019 4/16/2019 2.00 PROD1 RPCOMP SLPC P Perform slip and cut at 2968'. Cut and 13:30 15:30 slip 89.5' of drill line. Service crown, draw works, iron roughneck and top drive. 4/16/2019 4/16/2019 1.50 PROD1 RPCOMP TRIP P POOH from 2968'to 35'. 15:30 17:00 4/16/2019 4/16/2019 1.50 PROD1 RPCOMP BHAH P LD BHA, clean magnets. 17:00 18:30 PU dress off BHA with 6" x 3 1/2" dress off shoe, washover boot basket, 7" casing scraper, two 6 1/8" string mills, two magnets, jars, 4 3/4" DCs. 4/16/2019 4/17/2019 5.50 PROD1 RPCOMP TRIP P TIH, to tubing cut stub at 9738', mill to 18:30 00:00 9739' up wt 185k do wt 95k roil 25k, 60rpm, tq off 9500ftib tq on 11500ft1b pump 2bpm 200psi. Washed over, saw torque even out then saw inner mill engange, milled approx 6inches off top of stub. 4/17/2019 4/17/2019 0.50 PROD1 WELLPR MILL P Clean casing for packer f/9710'to 00:00 00:30 9730' three times pumping 2bpm 200 psi. 4/17/2019 4/17/2019 1.00 PROD1 WELLPR CIRC P Pump 30bb1 high vis sweep 3bpm 00:30 01:30 535psi chase with seawater 8bpm 2600psi. 4/17/2019 4/17/2019 9.00 PROD1 WELLPR TRIP P POOH LD DP from 9713'to 4890'. 01:30 10:30 RI withstands from derrick from 4890' to 5269', to lay down all drill pipe from derrick. Continue POOH laying down drill pipe from 5269' to 348'. 4/17/2019 4/17/2019 3.00 PROD1 WELLPR BHAH P Lay down drill collars and clean 10:30 13:30 magnets. Lay down 3 1/2" polish milling assembly. No abnormal wear on mill. 4/17/2019 4/17/2019 0.50 PROD1 WELLPR OTHR P Pick up single of drill pipe and wear 13:30 14:00 bushing retrieval tool. Pull wear bushing. 4/17/2019 4/17/2019 1.00 PROD1 WELLPR WASH P Make up XO's to joint of drill pipe. 14:00 15:00 Flush BOP stack out. 4/17/2019 4/17/2019 1.00 COMPZN RPCOMP RURD P RU tubing handling equipment and 15:00 16:00 tubing tongs Page 17/19 Report Printed: 513/2019 Operations Summary (with Timelog Depths) 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start lime End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (MKS) End Depth (ftKB) 4/17/2019 4/18/2019 8.00 COMPZN RPCOMP PUTB P Pick up and make up Baker non- 16:00 00:00 sealing overshot, HES 3 1/2" x 2.812" X-Nipple, Baker 7" x 3 1/2" FHL Packer, 80-40 PBR, Seal Assembly, and Locator sub. RIH with the same. Pick up 3 1/2" 9.3# L-80 EUE 8RD AB -Mod tubing and torque to 2400 ftlbs. Run 3 1/2" completion string to 5296'. 4/18/2019 4/1812019 6.50 COMPZN RPCOMP PUTS P Continue running 3 1/2" 9.3# L-80 00:00 06:30 EUE 8RDM tubing, 2240 ftlbs, from 5296', tag up on Baker overshot no-go at 9747.59', observe shear pins shear. 3 1/2" tubing stump fully swallowed. Up wt 1001k and down wt 64k. Make up side entry sub and slack off to 9738' 4/18/2019 4/18/2019 1.00 COMPZN RPCOMP CIRC P Pump 15 bbls of Corrosion Inhibited 06:30 07:30 8.6 ppg Seawater. Displace tubing string with seawater, spotting 10 bbls of Cl Seawater in annulus, leaving 5 bbls in tubing. 3bpm at 250 psi. 4/18/2019 4/18/2019 2.00 COMPZN RPCOMP PUTB P Space out string 1' off overshot no-go 07:30 09:30 to 9751'. Drop 1 5/16" ball and rod. Allow to fall. Pressure up tubing string to 2000 psi and set Baker FHL packer at 9665.5' per original RKB. Pressure up to 2800 psi and allow elements to expand. Up wt 100k and down wt 64k. Pick up to 15k over up weight to 115k. Shear out of PBR. Lay down 3 joints. Pick up 2 space out pups, to space out approximately 3' above collar locator. Pick up hanger and landing joint. New up wt 99k and down wt 63k. Circulate at .5bpm to see pressure indication seals enter PBR. Good pressure indication. Bleed pressure off and land hanger. Run in lock down screws. Total of 308 joints, 2 pups, and hanger/pup assembly ran. 4/18/2019 4/18/2019 1.50 COMPZN RPCOMP PRTS P Pressure test 3 1/2" tubing to 3000 psi 09:30 11:00 for 5 minutes, charted. Good test. bleed tubing down to 1500 psi. While maintain tubing pressure of 1500 psi, increase IA pressure to 2500 psi. Hold IA and tubing pressure for 30 mins, charted. Test good. Bleed down tubing pressure from 1500 psi to 0 psi. Observe Shear out valve open and tubing/IA pressures equalize. Positive indication valve open. Pump 2 bbls down IA to verify open and returns. Lay down landing joint. Blow down equipment. 4/18/2019 4/18/2019 0.50 COMPZN WHDBOP MPSP P Install HP BPV with T-bar. Pressure 11:00 11:30 test BPV to 1000 psi for 5 mins. Test good. 4/18/2019 4/1812019 1.50 COMPZN WHDBOP NUND P Nipple down BOP. Remove riser, turn 11:30 13:00 buckles, bolts. Set BOP Stack on Pedestal. Remove adapter flange. Page 18/19 Report Printed: 5/3/2019 b ` Operations Summary (with Timelog Depths) fir?z4 2K-26 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start -rime End Time Dur (hr) Phase Op Code Activity ty Code Time P -T-% Operation Depth (ftKB) End Depth(ftKB) 4/18/2019 4/18/2019 2.00 COMPZN WHDBOP NUND P Prepare cellar to nipple up. Install test 13:00 1500 dart on BPV Install 7-1/16" 5M X 3 1/8" 5M tubing head adapter. Test hanger packoff to 250 psi low for 5 mins and 5000 psi high for 10 mins. Test goad. Nipple up CIW 3-1/8" 5M psi production tree. Torque all bolts. Test tree to 250 psi low for 5 mins and 5000 psi high for 10 mins. 4/18/2019 4/18/2019 0.50 COMPZN WHDBOP MPSP P Pull BPV, and test dart. 15:00 15:30 4/18/2019 4/18/2019 3.50 COMPZN WHDBOP CIRC P Displace well bore fluid from 8.6 ppg 15:30 1900 seawater to 8.6 ppg corrosion inhibited seawater. Pump 275 bbls of corrosion inhibited seawater dawn IA taking returns out of tubing to flow back tank. 41bpm, 600psi. Little Red pump 82 bbls of diesel down IA to freeze protect well. Equalize the IA and tubing and allow to u -tube one —1 hour. 4/18/2019 4/18/2019 00 COMPZN WHDBOP MPSP P Install HP BPV with T -bar. 19:00 20:00 "Rig released at 20:00— Button up tree, install gauges. RDMO to 1 R-01 Page 19/19 Report Printed: 5/3/2019 ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION BP North Slope 1 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. 11 0 0 Attn: NSK-69 MAY 0 6 2019 700 G Street ((��((�� Anchorage, Alaska 99501 OGCC AOGCC 1 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 1 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Print Name ' — SigrWtM // / Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: 07 Fro / qo -%5 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, April 24, 2019 7:11 AM To: Phillips, Ron L Subject: KRU 2K-26(PTD 190-015, Sundry: 318-541) OA cement approval post production Ron, Approval is granted to bring this well on production prior to bull heading cement down the OA. Please include this approval with the approved Sundry. 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. Loepo(a)alaska.00v 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 Loeoo@alaska aov From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Tuesday, April 23, 2019 1:29 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Pogany, Mandy W <Mandy.W.Pogany@conocophillips.com>; CPF2 Prod Engrs <n1135@conocophillips.com> Subject: KRU 2K-26, PTD: 190-015, Sundry: 318-541 Victoria, On well 2K-26 we just finished up the subsidence rig workover. We had trouble getting the new 2055' of 7" production casing into the well, so we had to run 8.75" string mills to clean up the 9-5/8" surface casing. We milled holes in the surface casing at 134' to 153', 226' to 274' and 745' to 762'. We also encountered losses at these three areas with the upper being the worst at 40 bph. Since we encountered losses we decided to pump 200% excess cement and the max amount of LCM Halliburton recommended pumping through their HES cement staging tool. During the cement job we had partial returns and never got cement back to surface. Halliburton did not bring extra cement to pump a top down job and they were on call for another job. After we landed casing, pulled in tension and set slips we NU the tubing spool and reinstalled BOPE. We pumped diesel freeze protect down the annulus 8.5 hours after the cement job was finished, which confirmed we could bull head cement after the rig moved off. We have a 2,500 psi pressure test on the 7" production casing, charted for 30 minutes, that passed on 4/18/19. Can we put this well on production prior to bull heading the cement down the annulus or should we plan to pump the cement job first. The reason I ask is because the PTD step #14 said we would cement to surface. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO -13-1334 ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 19 90 15 Kuparuk 30 62 4 BP North Slope 1 0 1 0 ( 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids FNE� 900 E. Benson Blbd. - Anchorage, AK 99508 g2 : C Conoco Phillips Alaska Inc. 1 0 0 Attn: NSK-69 /� OG 700 G Street Anchorage, Alaska 99501 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Print Name/ I Signature V V Date Please return via e-mail a copy to both Alaska E -Line Services and C no Phillips Alaska: Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: r7 j/ AOGCC ti ATTN: Natural Resources Technician II S r✓ Alaska Oil & Gas Conservation Commision .,� 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 1900 15 TRANS WITAL DATE TRANSMITTAL N Name return via courier or sign/scan and email a copy Date and OPAL Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this poi nt. SLB YV\ ut Z -Z Sc f -lb 00015o Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, April 12, 2019 12:30 PM i�jl4 To: NSK RWO CoMan r Cc: DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA) Subject: RE: Nabors 7 ES on 2K-26 testing KRU 2K-26 PTD 1900150 Sundry 318-541 (revised 1/26/19) Nabors 7ES workover ops were suspended last evening due to Phase 3 weather as the rig was preparing to run new 7" casing in KRU 2K-26. AOGCC approves your request to postpone the BOPE test— due today 4/12 — until the 7" casing has been landed/cemented and new tubing head has been installed (Step 15 of the revised sundry work procedure). Please continue to coordinate the timing of the BOPE test with AOGCC's North Slope Inspectors. I have copied the Inspectors with this message so you have their correct email address. Jim Regg Supervisor, Inspections AOGCC 333 W.7'h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regggDalaska.eov. From: NSK RWO CoMan <NSKRWOCoMan@conocophillips.com> Sent: Friday, April 12, 2019 11:09 AM To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Subject: FW: Nabors 7 ES on 2K-26 testing Eli Garza/Ronnie Dalton CPAI Wells Supervisors RWO / Nabors Rig 7ES Site Office: (907) 670-6130 Rig Office: (907) 670-6135 Mobile: (907) 223-6303 AN WELLS TEAM Ir i ConocoPh PN 5 P I R I T From: NSK RWO CoMan Sent: Friday, April 12, 2019 10:02 AM To: 'doa.admin.webmaster@alaska.gov'<doa.admin.webmaster@alaska.gov> Subject: Nabors 7 ES on 2K-26 testing Jim, Due to weather conditions not able to run 7" casing on 4-11-19 due to weather testing date is today 4-12-19 . Asking for a delay Thanks Eli Garza/Ronnie Dalton CPAI Wells Supervisors RWO / Nabors Rig 7ES Site Office: (907) 670-6130 Rig Office: (907) 670-6135 Mobile: (907) 223-6303 WELLS TEAM cDY &hiNips S P I R I T From: AOGCC Inspections <noreply@!otform.com> Sent: Thursday, April 11, 2019 5:57 PM To: NSK RWO CoMan <NSKRWOCoMan@conocophillips.com> Subject: (EXTERNAL]AOGCC Inspection Form Confirmation Email This email confirms your request for an inspection with the following information: Type of Test Requested: Inspection BOPE Requested Time for Inspection: 04-12-2019 6:00 PM Location: Nabors 7ES Rig Pad 2K-26 Kup Name: Ronnie Dalton E-mail: nskrwocoman@conocophillips.com Phone Number: (907) 6706130 Company: Other Information: I will update you tomorrow at noon Thanks Ronnie If you are not contacted within 12 hours, please notify Jim Regg at 907-793-1236. Thank you! Alaska Oil and Gas Conservation Commission ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TRANSMITTAL D'�2/1312019TRANSMITTAL it: RECEIVED Kuparuk FEB 19 2019 1 9 0 0 15 AOGCC 30 3 6 5 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 USPS Tracking # Conoco Phillips Alaska Inc. 1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 USPS Tracking # n/a AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 USPS Tracking # 9405 5036 9930 0417 5293 91 DNR 0 0 1 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 USPS Tracking # 9405 5036 9930 0417 5293 84 Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: PTD /90- 01S Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Saturday, January 26, 2019 5:05 AM To: Phillips, Ron L Subject: Re: KRU 2K-26, PTD:190-015 ,Sundry:318-541 Ron, Approval is granted to modify the BOP test pressure to 4200 psig and to modify the completion to a stacked packer completion. This approval should be placed with the approved sundry and available for the AOGCC inspector to view at the job site. Thanx, Victoria Sent from my iPhone On Jan 25, 2019, at 4:17 PM, Phillips, Ron L <Ron L Phillips@conocophiIIips.com> wrote: Victoria, KRU 2K-26 is a subsidence well that has buckling, drift issues and a surface casing leak all at -700'. The SBHP test was from 2015 and no one wanted to risk pulling the plug to get an up to date SBHP test. I talked them into it last weekend after a good drift and the reservoir pressure has jumped from 1,830 to 4,630 psi. We feel the pressure is coming from the 2G-14 injector, which is now shut in and will remain shut in until the completion of the 2K-26 RWO. The original plan was to pull the entire completion and run a selective completion. We can not pull the entire completion with the pressure this high and we do not want to wait any longer to perform this work over since the subsidence issues are getting worse. We would like to cut and pull the completion just above a tested tubing tail plug and production packer. Then perform the repair on the production casing. And run back in with a stacker packer and overshot. This means our uppermost production packer will be at 9,703' MD instead of the sundry approved 9,786'. Our MPSP went from 1,831 psi to 4,015 psi, therefore our BOPE test pressure is now 250/4200 psi (annular 250/2500 psi). I attached the 2K-26 approved sundry, the revised proposed schematic and revised general procedure. We plan to perform the RWO the second week of February. Please call or email if you have any questions or need more information. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO -13-1380 2K-26 Rig Workover P & R Tubing and Casing Repair (PTD #: 190-015) Current Operations: This well is currently shut-in for a tubing leak & casing damage and awaiting a RWO Scope of Work: Pull the 3-1/2" completion from the pre -rig tubing cut at 9,765'. Cut and pull the 7" casing above the top of cement -1,952'. Open up the 9-5/8" casing with mills. Run 7" casing and cement back to surface. Run in hole with the new 3- 1/2" completion. General Well info: Well Type: Producer MPSP: 1-16 4,015 psi using 0.1 psi/ft gradient Static BHP: 1834 4,630 psi / 6,145 TVD (3-7 14.5 ppg EMW) measured on 01 /18 1101-3-01/18/2019 Wellhead type/pressure rating: WKM Gen 4, 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TXIA 2,500 psi PASSED- 12/25/2017 MIT -OA 1,800 psi FAILED - 11/25/2018 IC POT & PPPOT PASSED -11/25/2018 TBG POT &PPPOT PASSED -11/25/2018 Production Engineer: Mandy Pogany (263-4148/Mandy.W.Pogany@ConocoPhillips.com) Workover Engineer: Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre-Rie Work 1. TBG and CSG PO tests. 2. Dummy all GLM's leaving GLM #6 open for circulation point. 3. String shot and chem cut firstjoint above the PBR at 9,765' MD. 4. FT LDS and grease tree valves. Workover Procedure 1. MIRU. Pull BPV. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 2.500 4.200 psi and annular to 2,500 psi. 3. Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4. POOH laying down 3-1/2" tubing. 5. RIH on DP and fish the tubing stub and seals free from the PBR. 6. RIH on DP and fish PBR/HB packer and tubing tail. 7. RU E -line and perform a CBL to find top of cement -1,952'. 8. RIH and set a IBP 500' below top of cement. 9. ND BOP stack, NO tubing head and NU BOP stack to casing head. 10. Cut the 7" casing just above the top of cement. 11. Spear the 7" casing and POOH laying it down. 12. Open up the 9-5/8" casing to 8-3/4" drift with mills. 13. RIH with 7" overshot patch, cementing port collar and new casing. 14. Cement 7" x 9-5/8" annulus to surface. 15. ND BOPE, NU new tubing head and BOP stack. PT BOPE. 16. MU a clean out BHA and RIH to clean sand off IBP. Pull IBP. 17. MU selective stacker packer completion, drop ball and rod and set bath-paek@Fs packer. 18. Space out and MU tubing hanger. Circulate corrosion inhibited fluid in the IA. 19. Land the tubing hanger, RILDS. 20. PT the tubing. Hold pressure on tubing and pressure test IA and chart. Bleed tubing pressure quickly to shear the SOV. 21. Pull the landing joint, install BPV. 22. ND BOPE. NU tree. 23. Pull BPV and install tree test plug. Test tree and pull test plug. 24. Freeze protect well with diesel. Set BPV. 25. RDMO. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV and run OLD. 4. Handoff to operations to put back on production. 2K-26 Proposed RWO Schematic 16" 62.5# H40 shoe @ 115' MD 9-5/8" 36# J-55 shoe @ 4271' MD C4 -sand perfs 9902' - 9908' MD A5 -sand parts 9995'- 10,015' MD A4 -sand Paris 10,047'- 10,084'MD 7" 26# J-55 shoe @ 10,330' MD Updated: 23 -Jan -2018 RLP 3-1/2" x 1-1/2" Camco MMG gas lift mandrels @ 3060', 5517', 7174', 8374', 9207'& 9725' RKB 3-1/2" 9.3# L-80 EUE W Tubing to surface Baker 10' PBR @ 9690' MD Baker FHL Packer @ 9703' MD X -Nipple (ID=2.81") @ 9751' MD Overshot @9765' MD Original Com Baker 10' PBR @ 9779' MD Baker HB Packer @ 9793' MD M -Nipple (ID=2.81") @ 9830' MD Tubing tail @ 9842' MD • • LD We Qr 0r r r r r r r r 0o x > ua aJ E v, \ rL P O i 4- O) 4) O LL to +' cocD > rD IA wf w '1 _7 5 0 Y cD 4- 'B COr0 Q w ) r0 +' O v, CU 9 � m Q. c c 0 oc • _' C a- a � a CI -' W r r r n n T co aJ O J Q NW r r r r r to L aJ U q k• tO a Q a a a a a a E -o ° W VI N CO N N fig I N N fI 'O L L v, 41 F- ap . 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U C aa w0 a 30 v I-- m E v > 0 To 7 d y F' L) of I-I Q v v c0 CO O N CO 4-, W E ;32 Z m rn z N 0 N N O V ` , = `) Lo _, _i 2 Y Y Y Q Q C9 E rD a _ err a < O N W c') N N N N vi z h Y W + O Na a Q H ; a Q • STATE OF ALASKA ALOIL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate p Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool E Repair Well p. Re-enter Susp Well rOther: 1-jfLh F. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: vfl— ConocoPhillips Alaska, Inc. Development 1 Exploratory r 190-015 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 • 50-103-20126-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025667 J KRU 2K-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): , N/A Kuparuk River Field/Kuparuk River RE E 1 V E D 11.Present Well Condition Summary: C G SEP 01 2Ui3 Total Depth measured ' 10350 feet Plugs(measured) None true vertical , 6351 feet Junk(measured) None AOGCC Effective Depth measured 0 feet Packer(measured) 9793 true vertical 0 feet (true vertical) 6025 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115' 0 0 SURFACE 4236 12 4271 3035' 0 0 PRODUCTION 10297 7 10330 6340' 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9902-9908, 9995-10,015, 10,047-10,084 True Vertical Depth: 6088-6092, 6143-6154,6173-6195 SCANNED ' 1 12016 Tubing(size,grade,MD,and TVD) 3.5, J-55, 9842 MD, 6053 TVD Statewide retrievable patch set from 9720'-9754' Packers&SSSV(type,MD,and TVD) PACKER-BAKER HB RETRIEVABLE PACKER @ 9793 MD and 6025 TVD SAFETY VLV-CAMCO TRDP-1A SSA SAFETY VALVE @ 1822 MD and 1704 TVD 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-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A _ N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fi Exploratory r Development Service r Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: • Oil P' Gas r WDSPL Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Brent Rogers/ Kelly Lyons Email N1617(a�conocophillips.com Printed Name Brent Rogers Title Problem Well Supervisor Signature Avy/47 ,,,„, Phone:659-7224 Date 08/29/15 vii- q//////S' Form 10-404 Revised 5/2015 Submit Original Only . . • RECEIVED ConocoPhillips SEP 0 1 2015 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 August 29, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. KRU well 2K-26 (PTD 190-015). This report is for a tubing patch set to repair a tubing leak above the top packer. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments • • 2K-26 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/18/15 SET LOWER PARAGON PACKER @ CCL STOP DEPTH=9973.5' RKB, CCL TO MID ELEMENT=20.5', MID ELMENT SET DEPTH=9754' RKB 08/19/15 SET TTS TEST TOOLS IN LOWER PARAGON PACKER, PERFORM CMIT PRE MIT PRESS T/IA/OA= 350/50/100# INITIAL MIT PRESS = 2650/2350/115# 15 MIN PRESS= 2600/2300/115#30 MIN PRESS= 2580/2280/115#*****PASS***** PULL TTS TEST TOOL JOB IN PROGRESS. 08/20/15 SET UPPER TTS PACKER, SPACER PIPE & SNAP LATCH INTO LOWER PACKER. PATCH MID ELEMENT SET DEPTH = 9754' & 9720' RKB. OAL = 32.70'. ATTEMPTED TO MIT-T WI TTS TEST TOOL AND LRS TO 2500#2 TIMES. JOB IN PROGRESS. 08/21/15 PASSING MIT-T W/TRIPLEX, STARTING T/IA/OA PRESS= 2500/250/100# 15 MIN PRESS= 2450/250/100#30 MIN PRESS= 2450/250/100#. PASSING CMIT-T/IA STARTING T/IA/OA PRESS = 2600/2400/100# 15 MIN PRESS= 2550/2350/100#30 MIN PRESS= 2550/2350/100# WELL READY FOR PRODUCTION. 08/25/15 (AC EVAL): TIFL-PASSED. Initial T/I/0=200/1215/130. IA FL @ 9063', 198' above OV. Shut in well, stacked out T 60 mins with lift gas: T/I/O= 1050/1090/130. Bled IA 60 mins: T/I/O= 1050/600/130. IA FL @ same. Continued to bleed IA 15 mins: T/I/O= 1050/500/30. IA FL @ same. Bled AL line to 200 psi. 15 min: T/I/O= 1075/500/130. 30 min: T/I/O= 1075/500/130. IA FL @ same. 45 min: T/I/O= 1075/500/130. 60 min: T/I/O= 1075/500/130. IA FL @ same. Final T/I/O= 1075/500/130. Summary Set a 30' element to element Statewide retrievable tubing patch. The TIFL post patch passed. • z KUP PROD • 2K-26 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,IOC. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) COrlcxnfldilips 501032012600 KUPARUK RIVER UNIT PROD 60.75 3,075.00 10,350.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-26,81251201510:10:47 AM SSSV:LOCK OUT 90 11/1/2014 Last WO: 39.99 2/14/1990 • Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag,SLM 10,158.0 1/18/2015 Rev Reason:SET STATEWIDE PATCH hipshkf 8/25/2015 i -- HANGER,31.1 1_'i._ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread � • �'_lr- CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread r SURFACE 9 5/8 8.921 35.0 4,271.0 3,034.5 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 [ PRODUCTION 7 6276 33.0 10,330.3 6,339.6 26.00 J-55 BTC 1 Tubing Strings ' ' ' 'mu'Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection TUBING 31/2 2.992 31.1 9,842.4 6,053.4 9.30 J-55 EUE-MOD ..A.A.,CONDUCTOR;360-115.c• Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.00 HANGER WKM GEN IV TUBING HANGER 3.500 SAFETY VLV;1,822.21 - 1,822.2 1,703.5 50.71 SAFETY VLV CAMCO TRDP-1A SSA SAFETY VALVE(Locked Out 2.812 5/2/13) 9,779.4 6,016.9 55.05 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL BORE 3.000 9,793.1 6,024.8 54.69 PACKER BAKER HB RETRIEVABLE PACKER 2.890 GAS LIFT;2,935.2 9,830.3 6,046.4 54.49 NIPPLE OTIS XN NIPPLE NO GO 2.750 9,841.6 6,053.0 54.46 SOS BAKER SHEAR OUT SUB 2.375 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • Top(TVD) Top Incl • Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 9,720.0 5,983.1 55.75 UPPER UPPER TTS PACKER 8/20/2015 1.630 PACKER 9,724.0 5,985.4 55.81 PATCH SPACER PIPE AND SNAP LATCH 8/20/2015 1.630 SURFACE;35.04,271.0--4 9,749.9- 6,000.1 55.01 LOWER LOWER PACKER 8/18/2015 1.630 PACKER GAS LIFT;5,924.9 Perforations&Slots Shot Den GAS LIFT;7,736.3 *lb Top (TVD( Btm(ND) (shotslf Top(ftKB( Btm(ftKB) (ftKB) (ftKB( Zone Date I) Type Com 9,902.0 9,908.0 6,088.1 6,091.6 C-4,UNIT B, 4/27/1997 6.0 APERF 60 deg.Phasing;2.5" 2K-26 HSD GAS LIFT;8786.6 s_+ 9,995.0 10,015.0 6,142.5 6,154.2 A-5,2K-26 4/27/1997 6.0 APERF 60 deg.Phasing;2.5" HSD 10,047.0 10,084.0 6,173.0 6,194.7 A-4,2K-26 4/4/1990 4.0 IPERF 180 deg.Phasing;4.5" Casing Guns Mandrel Inserts GAS LIFT;9,261.4 ;3!-7; St l on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 5,924.9 3,916.0 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,296.0 11/5/2012 3 7,736.3 4,908.1 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,275.0 11/4/2012 UPPER PACKER;9.720.0 ' 'i ,_:• 4 8,786.8 5,471.7 MERLA TMPD 1 GAS LIFT GLV BK 0.188 1,297.0 7/20/2015 I',. • • 5 9,261.4 5,729.5 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.188 0.0 7/20/2015 6 9,738.5 5,993.5 CAMCO MMG-2 1 1/2 GAS LIFT OPEN 7/29/2015 PATCH;9,724.0 Notes:General&Safety GAS LIFT;9,738.5il; End Date Annotation ''.• 1 11/5/2010 NOTE:View Schematic w/Alaska Schmatic9.0 1 I 10/21/2013 NOTE:Mandrel Orientation#1)12:30#2)5:00,#3)12:00,#4)10:30#5)5:30,#6)8:30 ill LOWER PACKER;9,749.9 i=.1 PBR;97794 PACKER;9,793.1 W NIPPLE;9.8303 SOS',9,841.6 APERF;9,902.0-9,9030- APERF;9,9930-103150- ._ ,995.010,0150- IPERF;10,047.010,084.0- PRODUCTION;33.010,330.3 • 2557'1 WELL LOG TRANSMITTAL DATA LOGGED M.K.GEND R To: Alaska Oil and Gas Conservation Comm. March 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 . I V E D MAR 2. 42015 RE: Multi Finger Caliper(MFC): 2K-26 AOGCC Run Date: 3/7/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2K-26 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20126-00 SCANNED °t PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: I1e4CAt Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~0' 0 i,~'" File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA rq Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: rBren Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 Mr. Tom Maunder.; Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: r~ 1~0~ o ~5 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 June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, July10, and July 24, 2008. 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, 3i~ ~ ,. M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Fieid 7/29/2008 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 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3' 10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7!24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24!2008 t THE MATE~AL UNDER THIS COVER HAS BEEN MICROFILMED ON .OR BEFORE OCTOBER 27, 2000 E P M C:LORhM~LM.DOC L A T E R IA L THIS MA. E W UNDER R K E R ~ ~'"' STATE OF ALASKA AL, _ ..A OIL AND GAS CONSERVATION COMMI~..,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Operation Shutdown__ Stimulate X Plugging Perforate __ Alter casing Repair well Other 5. Type of Well: 99510 4. Location of well at surface 321' FSL, 94' FEL, SEC 2,T10N, R8E, UM At top of productive interval 1825' FNL, 1559' FWL, SEC 7, T10N, R8E, UM At effective depth 1853' FNL, 1824' FWL, SEC 7, T10N, R8E, UM At total depth 1865' FNL, 1935' FWL, SEC 7, T10N, R8E, UM Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) RKB 154 feet ...... 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-26 9. Permit number 90-15 10. APl number 5o-1 03-201 26-00 1 1. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 1 0350 feet Plugs (measured) None true vertical 6387 feet Effective depth: measured 1 0241 feet Junk (measured) None true vertical 6 3 2 4 feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 200 CF Surface 4235' 9-5/8" 1080 Sx AS III & Intermediate 450 Sx Class G Production 1 02 91 ' 7" 175 Sx Class G Liner Perforation depth: measured 9902'-9908', 9995'-10015', 10047'-10084' true vertical 6112'-6116', 6167'-6179', 6198'-6220' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 @ 9842' ORIGINAL Measured depth True vertical depth 115' 115' 4271' 4235' 10327' 6374' Packers and SSSV (type and measured depth) Packer: Baker HB @ 9793'; SSSV: Camco TRDP-1A-SSA @ 1822' 13. Stimulation or cement squeeze summary Fracture stimulate A & C sands on 9/24/97. Intervals treated (measured) 9902'-9908', 9995'-10015', 10047'-10084' Alaska 0i!,:,,:~..~, Cons. C0mmissior~ Treatment description including volumes used and final pressure Pumped 269 Mlbs of 20/40, 12/18, and 10/14 ceramic proppant into the formation, tp = 6900 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 21 1 6 3 4 775 266 Subsequent to operation 5 4 3 382 24 785 276 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~,,~ .~~,,,~'~...¢_.,,~ ' Title Wells Superintendent Form Date /__j,~i~,~ SUBMf~ IN DUPLICATE ARCO Alaska, Inc. , KUPARUK RIVER UNIT ---- WELL SERVICE REPORT ~ , K1(2K-26(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-26 FRAC, FRAC SUPPORT 0918970901.1 DATE DAILY WORK UNIT NUMBER 09/24/97 REFRAC "A" & "C" SANDS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR . 1 (~) Yes L~ No! (~) Yes (~ No DS-YOAKUM ' BLA,C,~ FIELD AFC.,~ CC,~ DAILY COST ACCUM COST ~i~Ine'~' ,~ ESTIMATE KD1478 230DS28KL $1 58,1 31 $158,131 Initial Tb.q Press Final Tbq Press Initial Inner Ann "'Final Inner Ann I Initial Out ' I Outer Ann 0 PSI 6900 PSI 1 950 PSI 500 PSII 250 PSI 250 PSI DALLY SUMMARY PUMPED "A" & "C" SAND FRAC THRU ALL BUT7 BBLS FLUSH. INJECTED 269,000 LBS OF PROP IN FORMATION W/13 PPA OF 10/14I I TIME LOG ENTRY 06:00 09:00 10:00 11:00 13:45 MIRU DS FRAC CREW (YOKAUM & CREW), APC VAC TRUCK & LRS. HOLD SAFETY MEETING (15 ON LOCATION) & REVIEW JOB. SET TREESAVER & PT BACKSIDE LINES TO 4100 PSI & TREATING LINES TO 9500 PSI. WO ARCO (IN STAFF MEETING). BEGIN FU~!P~NG B~EDOWN W/50# XL GW F/15 - 30 BPM. PUMP TOTAl. ~F .=;~1 qRt ° ON INITIAL BD STAGE (MAX ~' ;~?i~'~'?: = ", ,, '~ ~-:-,:~.:~,~,--,-, &'~.)0 PSI). ISIP-1520 PSI W/F.G. .69. (STEPS: 2750 PL' 'i' : · '. .'b PIS @ 8 BPM & 1850 PSI @ 4 BPM ). SD. PULSE, SD & MONITOR PRESSURES F/CLOSURE. BEGIN PUMPING DATAFRAC W/50# XL GW F/5 - 15 BPM. PUMP TOTAL OF 175 BBLS. ISIP - 2200 PSI W/F.G = .80. SD & MONITOR PRESSURES F/CLOSURE. PC @ 1560 PSI &TC IN 10 MIN. BEGIN PUMPING FRAC. PUMP 805 BBLS 0# XL GW @ 15 BPM PAD. PUMP & RAMP F/2 PPA TO 10 PPA FLAT & RAMPED UP TO 13 PPA. COMPLETED JOB W/7 BBLS LEFT IN FLUSH (SCREENED OUT). PUMPED TOTAL OF 2892 BBLS (ENTIRE JOB). PUMPED 274,500 LBS PROP (21,310 LBS 20/40, 240,690 LBS 12/18 & 12,504 LBS 10/14). INJECTED 269,000 LBS PROP IN FORMATION W/13 PPA OF 10/14 @ PERFS. LEFT 5504 LBS OF PROP IN WELLBORE. FREEZED PROTECTED DOWN TO 5900' W/51 BBLS DIESEL. BEGIN RD. DEPRESSURE IA TO 500 PSI & RD / RELEASE LRS. REMOVE TREESAVER (SMALL AMOUNT OF 1 CUP LEFT IN HOLE}. RD COMPLETE & WELL SECURE. TURN OVER TO PRODUCTION. LEAVE WELL SI AWAITING CTU CLEANOUT. 15:30 SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $9,000.00 $9,000.00 ARCO $300.00 $300.00 DOWELL $147,071.00 $147,071.00 LITTLE RED $1,760.00 $1,760.00 TOTAL FIELD ESTIMATE $158,131,00 $158,131,00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 321' FSL, 94' FEL, SEC 2,T10N, R8E, UM At top of productive interval 1825' FNL, 1559' FWL, SEC 7, T10N, R8E, UM At effective depth 1853' FNL, 1824' FWL, SEC 7, T10N, R8E, UM At total depth 1865' FNL, 1935' FWL, SEC 7, T10N, R8E, UM 12. Present well condition summary Total Depth: measured 1 0 3 5 0 true vertical 6 3 8 7 Effective depth: measured 1 0 2 41 true vertical 6 3 2 4 Casing Length Size Structural Conductor 8 0' 1 6" Surface 4235' 9 - 5/8" Intermediate Production 1 0 2 91 ' 7" Liner Perforation depth: feet feet feet feet 6. Datum elevation (DF or KB) RKB 154 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-26 9. Permit number 90-15 10. APl number 50-103-20126-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Junk (measured) None Cemented 200 CF 1080 Sx AS III & 450 Sx Class G 175 Sx Class G measured 9902'-9908', 9995'-1 0015', true vertical 6112'-6116', 6167'-6179', Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 @ 9842' Packers and SSSV (type and measured depth) Packer: Baker HB @ 9793'; SSSV: Camco TRDP-1A-SSA @ 1822' 10047'-10084' 6198'-6220' ORIGINAL Measured depth True vertical depth 115' 115' 4271' 4235' 1O327' 6374' JUi ] D 13. Stimulation or cement squeeze summary Perforate 'A5' and 'C4' sands on 4/27/97. Intervals treated (measured) 9902'-9908', 9995'-1 001 5' Treatment description including volumes used and final pressure Perforate using HC guns w/DP charges @ 6 spf, phased 0°, fp -- 800 psi. 14. Representative Daily Average Production or Injection Data OiloBbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 31 6 2 9 7 1 1 860 24O Subsequent to operation 4 6 1 825 1 865 245 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations i 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Wells Superintendent Form ~:'~'04 / Date SUBMIT-II~ DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1 (2K-26(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-26 PERFORATE, PERF SUPPORT 0407970802.8 DATE DAILY WORK UNIT NUMBER 04/27/97 PERFORATE: 2 1/2: HSD, 6SPF, DP 8293 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes O NoI (~) Yes O No SWS-JOHNSON CHAN,EY FIELD AFC# CC,# DAILY COST ACCUM COST Si~ne~d ESTIMATE KAWWRK 230DS28KL $9,1 39 $10,766 Initial Tb~ Press Final Tb~ Press Initial Inner Ann "Final Inner Ann ~ Initial O~er Ann ~ Final Outer ~n 480 PSI 800 PSI 800 PSI 800 PSI~ 220 PSI~ ~0 PSI DALLY SUMMARY PERFORATEDTHE "C4" SAND INTERVAL @ 9902' RKB TO 9908' RKB W/2-1/2" HC GINS, DP CHGS, 6 JSPF, 60 DEGREE PHASING AND "A5" SAND INTERVAL @ 9995' RKB TO 10015' RKB,W/2-1/2" HC GINS, DP CHGS, 6 JSPF, 60 DEGREE PHASING. NO IMMEDIATE WHTP CHANGES. TIME LOG ENTRY 14:00 15:00 BEGIN RIG UP WITH UNIT 8293 (JOHNSON) PRESSURE TEST TO 3000 PSI - OK SHUT WELL IN AT WING VALVE 15:25 RIH WITH 6' WT BAR AND 20' 2 1/2" HSD PERF GUN 16:15 TIE INTO PET LOG DATED 4/3/90 16:25 PERFORATE 9995' TO 10015', 6 SPF 16:35 POOH 17:10 AT SURFACE, ALL SHOTS FIRED 17:50 RIH WITH WT BAR AND 6' PERF GUN 18:20 TIE IN TO PET LOG DATED 2/19/90 18:30 PERFORATE 9902' TO 9908', 6 SPF 18:35 POOH 19:15 AT SURFACE, ALL SHOTS FIRED RIG DOWN 20:00 LEAVE LOCATION SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $378.00 APC $250.00 $250.00 HALLIBURTON $0.00 $635.00 LI~-FLE RED $0.00 $615.00 SCHLUMBERGER $8,889.00 $8,889.00 TOTAL FIELD ESTIMATE $9,139.00 $10,767.00 · STATE OF ALASKA ~ (~) - ~.~'-'~ . A~,~A OIL AND C_:r, AS CONSERVATION CO, ..... ISSION "~ /r ~,".~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG /,~, ~ 1 status of Wetl ' ' Classification of Service V~ell OIL ~'J GAS r-'J SUSPENDED r'~ ABANDONED r'-] SERVICE r'-I .... '" £ N'"~ of O~ator ARCO Alaska, Inc 90-15 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20126 ,, 4 Location of well at surface ~- ,,S ~¥';~*~*~/'*~.~.'"2'I_ ~ 9 Unit or Lease Name 321' F'~L, 94' FEI., SEC 2, TION, R8E UM ~ bO,...~'~,~ .?.~![. KUPARUK RIVER At Top Producing lnterval ~ ....... ,~ ~ 10 WetlN~mber 1499' FNL, 1603' FWL, SEC 7, TION, RgE UM * ~'~'~ .... ~ . 2k-26 . At Total Depth ........... -~..-.~ 11 Field and Pool 1534' FNL~ 1966',FW1~ SEC 7~ T10N~ RgE UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. ' ' KUPARUK RIVER OIL POOL RKB 154'J ADL: 25667 ALK: 2588 12 Date Spudded 13 Date T.D. Reached 14 Date Comp~, Susp. or Aband. I 15 Water Depth, if offshore J16 No. of '~;omPletions 2/5/90. 2/12/90. 4/4/90..I . NA feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 10350' MD & 6376' 'I'VD 10228' MD & 6312' TVD YES [~] NO E~] 1822' feet MD 1400' AP PROX 22 Type Electric o~ ~ LOgs Run ' ' DIL/SFL/GR/SP/FDC/CNIJCAL/CBL/GYRO 23 CASING. LINER AND'CEMENTING RECORD , ,, , , SETTING DEPTH MD CASING SIZE w'r. PER FT. GRADEI TOP RD'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , ,, 16' 62.5# H-40 SURF 115' 24' 197 SX AS II 9 5/8' 36# J-55 SURF 4271' 12-1/4' 11300 SX AS IIIr 450 SX CLASS G 7' 26~ J-55 SURF 10327' 8-1/2' 300 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} 3-1/2' 9842' 9793' 10047' - 10084' W/4-1/2' Csg gun @ 4 SPF MD 6198' - 6220' TVD ............... 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED AD~'~NDU~ 27 PF:IODUCTION TEST , , Date First ProducUon IMethod of Operation (Flowing, gas lift etc.) I Date of Test Flours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO F~wTu~ng C~ng ~,es~,o C~LCUL~TED O,-Sm. =AS-MCF ' WATER-Sm. OI~.GRAVrrY-API (~o~) .... Press. 24-HOUR RATE m- , ,, 28 CORE DATA None Fractured 5/19/90 -- Form 10-407 Rev. 7-1-80 ~ED ON REVERSE SIDE Submit in duplicate NNV~ ............. Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. ,, ,, ,, , , KUPARUK C TOP 9900' !6111' NA KUPARUK C Bo'FrOM 9906' 16115' KUPARUK A TOP 9974' 16155' KUPARUK A BoTTOM 10184' !6279' 31. LIST OF ATTACHMENTs ..... GYRO, Fmc a .dd~ndum, Daily Operations ....... 32. I hereby certify that the foregoing is true and correct to the best of mY knowledge 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 2~26 8/19190 Frac Kuparuk "A" sand perfs 10047'-10084' 180 deg oriented 158deg ccw in seven stages as follows. Stage 1: Pmp 200 bbls Gel H20 prepad @ 25 bpm 6870.5600 psi 60 bbls Gel H20 prepad @ 20 bpm 5200-5140 psi 45 bbls Gel H20 prepad @ 15 bpm 4600-4810 psi 30 bbls Gel H20 prepad @ 10 bpm 4500-4700 psi Stage 2:91 bbls Slick Diesel flush @ 25 bpm 5750-4900 psi Stage 3:900 bbls Gel H20 pad @ 25 bbls 5150-5000 psi Stage 4:83 bbls Gel H20 w/2ppg 16/20 Carbolite @ 25 bpm 4750-4800 psi Stage 5:85 bbls Gel H20 w/4ppg 16/20 Carbolite @ 25 bpm 4800-4850 psi Stage 6:87 bbls Gel H20 w/6ppg 16/20 Carbolite @ 25 bpm 4800-4900 psi Stage 7: 41bbls Gel H20 w/8ppg 16/20Carbolite @ 25 bpm 5160-7410 psi Well screened off w/6# @ perfs, immediate press increase @ surface. Fluid to recover: 1575bbls Sand in zone: 45,000 lbs Sand in csg: 22,637 lbs Avg pressure: 4750 psi D~,~mg upervisor D 1 - '~~--- Date ARCO Oit .J Gas Company Well History - Initial Report - Dali' Prepare and ~ubmlt the "la#Ill, RIII~I¥' on the first Wednelday after a well is spudded or workover operations are started. Daily work prior to IPUddl~l~.~,, be lummerlzld on the form giving inclusive dltel only. District ARCO ALASY~ INC. Field ICounty, parish or borough NORTH SLOPE Lea~e or Unit Title ADL: 25667 COMPLETIONS JState AK KUPARUK RIVER 'UNIT ALK: 2588 J Well no. K-26 Auth. or W.O, no. AK4583 Operator ARCO Spudded or W.O, begun IARCO W,I. 55.8533 Prior ~tatus if a W.O. SPUD Date and depth as of 8:00 a.m. IDete IHour 02/05/90 00:00 04/03/90 (10) TD: 0 PB:10241 SUPV:DB 04/04/90 (11) TD: 0 PB:10241 SUPV:GB Complete record for each day reported NORDIC i BOP TEST 7"@10327' MW:10.4 NaC1 MOVE RIG FROM 2K-1 TO 2K-26. ACCEPT RIG ON 2K-26 @ 0230 ON 4/3/90. ND TREE, NU BOPE. TEST BOPE TO 3000 PSI. DAILY:S18,362 CUM:$1,026,112 ETD:S1,026,112 EFC:$1,438,800 RIH WITH COMP STRING 7"@10327' MW:10.5 NaCl/NaBr FINISH BOP TEST. RU HLS PERF UNIT. SHOT GUN #1 10067'-10084', 4 SPF, 4.5" GUN, 180 DEGREE PHASING, 36 AND 30 GRAM ALTERNATING CHARGES. ALL SHOTS FIRED. SHOT GUN #2, 10047'-10067', SAME CONFIGURATION AS GUN 91. GUN #1- HLS ORIENTATION TOOL=155 DEGREE CCW FROM TOP OF HOLE, TARGET = 158 DEG SPERRY TOOL WAS UNSCREWED SOME SO DATA COMPARISON NOT RELEVANT.. GUN #2- HLS=166 DEGREE CCW AND SPERRY=iS5-162 DEGREE C.CW, TARGET= 158 DEG CCW. ORIENTATION WAS OK. RIH WITH 3-~/2" SINGLE COMPLETION INCL TWO 1-1/2" GLMS AND FOUR 1" GLMS. CONTROL LINE LOST PRESSURE, HOLE WAS RUBBED IN C-LINE. POOH AND RERUN CONTROL LINE ON TUBING. DAILY:S56,805 CUM:$1,082,917 ETD:S1,082,917 EFC:$1,438,800 The above is corre~ Signature For form preparation m)ll~letrtbu~on, see Procedures Manu¥, ,~ectlon 10, Drilling, Pages 86 and~'. AR3B-459-1-D Number MI dally well htltory fo,mi conlecutlvely am they are prepared for each well. iPage no. ARCO C ~nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Fii#i{ R~rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted at~ whell operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report com~14)ll alld representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State AK District ICounty or Parish ARCO ALASKA INc. I NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT ADL: 25667 ALK: 2588 Auth. or W.O. no. ITitie AK4583 I COMPLETIONS I Wel[ no. 2~-25 Operator A.R.Co. W.I. ARCO tDats 55. 8533 Spudded or W.O. begun SPUD I 02/05/90 Date and depth as of 8:00 a.m. 04/05/90 (12) TD: 0 PB:10241 SUPV:GB Complete record for each day reposed NORDIC I I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our Prior status if a 00:00 RIG REL @ 16:30 4/4/90 7"@10327' MW:10.4 NaCl/NaBr FINISH RUNNING 317 JTS OF 3-1/2" TBG AND JEWELRY. SET BAKER "HE" PACKER WITH 2500 PSI ON TBG FOLLOWED BY 1000 PSI ON ANNULUS. PU AND SHEAR PER. TEST SSSV OK, SET BPV, ND BOPE, NU TREE. TEST TREE OK. PRESSURE TEST ANNULUS TO 2500 PSI, OK. PRESSURE TBG TO 3400 PSI TO SHEAR OUT BALL. REVERSE CIRC 6 BBLS DIESEL DOWN ANNULUS, PUMP 2 BBLS DIESEL DOWN TBG, CHECK VALVE HOLDING OK. SICP-0 PSI, SITP-100 PSI. RIG DOWN, RELEASE RIG @ 16:30 HRS, 4/4/90. DAILY:S163,386 CUM:$1,246,303 ETD:S1,246,303 EFC:$1,438,800 Old TD Released rig Classifications (oil, gas, etc.) INew TD 1PB Depth Date IKind of ri.g Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date i Reservoir Producing Interval IOil 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 Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively as they are prepared for each well. iPage no. Olvllloe el Atla~tlcRIchfleldCompml¥ OR GINAL S..URVEy. REPORT ARCO ALASKA INC, KUPARUK FIELD, PAD 2K WELL NO. 26 NORTH SLOPE, ALASKA FEBRUARY 23, 1990 * IC O :ILMED Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713/461-3146 Fax: 713/461-0920 February 23, 1990 Re: Mr. Tim Billingsly Arco Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 ~ ~ ~: ~ . ' Kuparuk Field, Pad 2K Well No. 26 North Slope, Alaska Dear Mr. Billingsly: Enclosed please find one (1) original and nine (9) copies of the completed survey of Well No. 26. We would like to take this oppommity to thank you for using Gyrodata and we look forward to serving you in the furore. Sincerely, Gary Uttecht ViCe President, Technical Services GU/cv Enclosures Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LANentura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway A Gyrodata Directional for ARCO ALASKA INC. KUPARUK FIELD, PAD 2K, WELL NO. 26 NORTH SLOPE, ALASKA Survey Date Run: 19-FEB-90 12:27:34 Job Number: AKO290G208 Surveyor: MIKE HOWATT Calculation Method: RADIUS OF CURVATURE Survey Latitude: 70deg 14min 37sec N Sub-sea Correction from Vertical Reference: 118.0 ft Bearings are Relative to TRUE NORTH Proposed Well Direction: S 75deg 25min 0sec E Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodat a Directional Survey kRCO ALASKA INC. 2UPARUK FIELD, PAD 2K, WELL NO. 26 IORTH SLOPE, ALASKA [ob Number: AKO290G208 Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min .0 0 0 N 0 0 E 100.0 0 20 N 55 0 E 200.0 0 20 N 50 39 E 300.0 0 22 N 49 34 E 400.0 0 28 N 44 15 E 500.0 0 37 N 67 15 E 600.0 2 14 S 86 51 E 700.0 5 29 S 73 27 E 800.0 9 38 S 76 31 E 900.0 10 44 S 78 15 E 1000.0 13 5 S 78 7 E 1100.0 15 48 S 77 55 E 1200.0 20 13 S 75 45 E 1300.0 24 11 S 75 40 E 1400.0 27 39 S 75 43 E 1500.0 32 40 S 75 2 E 1600.0 36 21 S 75 27 E 1700.0 43 33 S 73 21 E 1800.0 50 18 S 73 59 E 1900.0 52 15 S 72 48 E 2000.0 53 6 S 70 34 E 2100.0 57 5 S 76 39 E 2200.0 55 58 S 76 15 E 2300.0 54 11 S 77 18 E 2400.0 56 12 S 74 3 E DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/lO0' ft ft CLOSURE DISTANCE BEARING ft deg min .00 .0 .0 .0 N 0 0 E MULTI SHOT SURVEY IN 7 INCH CASING ALL DEPTHS ARE REFERENCED TO KB ELEVATION KB TO GROUND = 36 FT. ( KB ELEVATION = 154 FT. ) .34 100.0 .2 .3 N 55 0 E ..03 200.0 .6 .9 N 53 34 E .04 300.0 .9 1.5 N 52 9 E .10 400.0 1.3 2.2 N 50 26 E .27 500.0 1.9 1.70 600.0 4.2 3.35 699.7 10.8 4.18 798.8 24.0 1.14 897.2 41.7 3.1 N 52 1 E 5.4 N 64 23 E 11.6 N 84 1 E 24.3 S 84 49 E 41.9 S 81 41 E 2.35 995.1 62.3 2.71 1091.9 87.2 4.47 1187.0 118.1 3.97 1279.6 155.9 3.47 1369.5 199.6 62.5 S 80 32 E 87.5 S 79 49 E 118.3 S 79 2 E 156.1 S 78 14 E 199.7 S 77 40 E 5.01 1455.9 249.8 3.70 1538.3 306.5 7.33 1614.9 370.6 6.75 1683.2 443.6 2.16 1745.7 521.5 249.9 S 77 13 E 306.5 S 76 51 E 370.7 S 76 25 E 443.6 S 75 58 E 521.5 S 75 35 E 1.97 1806.4 600.9 6.39 1863.6 682.8 1.16 1918.8 766.2 1.98 1976.0 848.2 3.35 2033.1 930.2 600.9 S 75 4 E 682.8 S 74 54 E 766.2 S 75 4 E 848.2 S 75 14 E 930.2 S 75 16 E HORIZONTAL COORDINATES feet .00 N .00 E .17 N .24 E .52 N .71 E .91 N 1.17 E 1.41 N 1.70 E 1.94 N 2.48 E 2.36 N 4.91 E 1.21 N 11.52 E 2.20 S 24.23 E 6.06 S 41.49 E 10.29 S 61.69 E 15.47 S · 86.09 E 22.51 S 116.18 E 31.84 S 152.79 42.64 S 195.14 55.33 S 243.74 E 69.76 S 298.51 E 87.01 S 360.31 E 107.54 S 430.37 E 129.83 S 505.12 E 154.82 S 580.60 E 177.94 S 659.22 E 197.48 S 740.31 E 216.24 S 820.13 E 236.55 S 899.67 E ~CO ALASKA INC. }PARUK FIELD, PAD 2K, WELL NO' 26 ~RTH SLOPE, ALASKA ,b Number: AKO290G208 A Gyrodata Directional Survey Page 2 MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 2500.0 56 9 S 73 18 E 2600.0 54 57 S 75 3 E 2700.0 54 47 S 71 52 E 2800.0 55 46 S 74 35 E 2900.0 59 39 S 76 44 E 3000.0 60 18 S 75 40 E 3100.0 59 57 S 74 59 E 3200.0 57 47 S 75 56 E 3300.0 57 53 S 75 37 E 3400.0 57 47 S 76 15 E 3500.0 57 52 S 75 2 E 3600.0 57 32 S 74 9 E 3700.0 57 24 S 73 46 E 3800.0, 57 17 S 72 46 E 3900.0 57 40 S 72 13 E 4000.0 57 42 S 71 19 E 4100.0 57 51 S 71 13 E 4200.0 57 54 S 70 48 E 4300.0' 57 30 S 70 21 E 4400.0 57 31 S 70 37 E 4500.0 57 28 S 71 27 E 4600.0 57 46 S 70 44 E 4700.0 57 31 S 72 14 E 4800.0 57 33 S 71 38 E 4900.0 57 22 S 72 32 E .61 1.87 2.61 2.44 4.28 1.13 .69 2.31 .29 .56 1.04 .81 .35 .84 .61 .76 .17 .36 .54 .22 .71 .68 1.28 .50 .78 VERT DEPTH ft 2088.7 2145.3 2202.9 2259.8 2313.2 2363.3 2413.1 2464.8 2518.0 2571.2 2624.5 2677.9 2731.7 2785.7 2839.5 2892.9 2946.3 2999.4 3052.9 3106.6 3160.3 3213.9 3267.4 3321.1 3374.9 VERT SECTION ft 1013.3 1095.7 1177.4 1259.6 1344.1 1430.7 1517.4 1603.0 1687.6 1772.3 1856.9 1941.4 2025.7 2109.8 2194.0 2278.3 2362.7 2447.1 2531.4 2615.4 2699.5 2783.7 2868.0 2952.2 3036.4 CLOSURE DISTANCE BEARING ft deg min 1013.3 S 75 8 E 1095.7 S 75 4 E 1177.5 S 74 57 E 1259.6 S 74 51 E 1344.1 S 74 54 E 1430.7 S 74 58 E 1517.4 S 75 0 E 1603.0 S 75 1E 1687.6 S 75 3 E 1772.3 S 75 6 E 1856.9 S 75 7 E 1941.4 S 75 6 E 2025.7 S 75 3 E 2109.9 S 74 59 E 2194.1 S 74 53 E 2278.5 S 74 46 E 2362.9 S 74 39 E 2447.4 S 74 31 E 2531.8 S 74 23 E 2615.9 S 7~ 16 E 2700.1 S 74 10 E 2784.5 S 74 4 E 2868.9 S 74 0 E 2953.2 S 73 56 E 3037.5 S 73 53 E HORIZONTAL COORDINATES feet 259.§0 S 979.39 E 282.38 S 1058.72 E 305.65 S 1137.11 E 329.36 S 1215.80 E 350.29 S 1297.69 E 370.95 S 1381.77 E 392.91 S 1465.65 E 414.41 S 1548.51 E 435.21 S 1630.56 E 455.79 S 1712.67 E 476.78 S 1794.66 E 499.24 S 1876.15 E 522.54 S 1957.17 E 546.77 S 2037.79 E 572.13 S 2118.19 E 598.57 S 2198.45 625.74 S 2278.57 653.29 S 2358.64 681.40 S 2438.36 709.57 S 2517.87 736.97 S 2597.62 E 764.33 S 2677.52 E 791.16 S 2757.62 E 817.33 S 2837.84 E 843.25 S 2918.05 E A Gyrodat a Directional Survey IRCO ALASKA INC. ',UPARUK FIELD, PAD 2K, WELL NO. 26 IORTH SLOPE, ALASKA lob Number: AKO290G208 Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 5000.0 57 12 S 73 25 E 5100.0 57 22 S 71 51 E 5200.0 57 31 S 73 44 E 5300.0 .57 26 S 73 42 E 5400.0 57 32 S 73 34 E 5500.0 57 22 S 73 24 E 5600.0 57 15 S 73 13 E 5700.0 57 37 S 72 37 E 5800.0 57 30 S 72 39 E 5900.0 57 16 S 73 9 E 6000.0 57 13 S 72 43 E 6100.0 57 4 S 73 36 E 6200.0 56 46 S 72 50 E 6300.0 56 35 S 73 49 E 6400.0 56 35 S 73 9 E 6500.0 56 25 S 74 0 E 6600.0 56 18 S 73 36 E 6700.0 56 21 S 73 51 E 6800.0 56 14 S 74 48 E 6900.0 56 6 S 74 2 E 7000.0 56 lO S 74 12 E 7100.0 55 44 S 74 55 E 7200.0 56 33 S 74 54 E 7300.0 56 46 S 74 58 E 7400.0 56 52 S 75 0 E ,76 1.32 1.59 .10 .16 .22 .20 .63 .12 .48 .37 .75 .71 .84 .55 .73 .36 .22 .79 .65 .73 .82 .23 .10 VERT DEPTH ft 3428.9 3482.9 3536.8 3590.5 3644.3 3698.1 3752.1 3805.9 3859.6 3913.5 3967.6 4021.8 4076.4 4131.4 4186.4 4241.6 4297.0 4352.5 4408.0 4463.6 4519.4 4575.4 4631.1 4686.0 4740.8 VERT SECTION ft 3120,4 3204,5 3288.7 3372.9 3457.2 3541.5 3625.6 3709.7 3794.0 3878.2 3962.2 4046.1 4129.9 4213.4 4296.8 4380.1 4463.4 4546.5 '4629.7 4712.8 4795.8 4878.6 4961.7 5045.2 5128.9 CLOSURE DISTANCE BEARING ft deg min 3121.6 S 73 51 E 3205.7 S 73 50 E 3290.0 S 73 48 E 3374.3 S 73 48 E 3458.6 S 73 48 E 3542.9 S 73 47 E 3627.0 S 73 46 E 3711.3 S 73 45 E 3795.7 S 73 44 E 3879.9 S 73 43 E 3964.0 S 73 42 g 4048.0 S 73 41 E 4131.8 S 73 40 E 4215.3 S 73 40 E 4298.8 S 73 40 E 4382.2 S 73 40 E 4465.4 S 73 40 E 4548.7 S 73 40 E 4631.8 S 73 41 E 4714.9 S 73 41 E 4797.9 S 73 42 E 4880.8 S 73 43 E 4963.8 S 73 44 E 5047.3 S 73 45 E 5131.0 S 73 46 E HORIZONTAL COORDINATES feet 867.88 S 2998.50 E 893.00 S 3078.81 E 917.93 S 3159.32 E 941.57 S 3240.25 E 965.33 S 3321.15 E 989.31 S 3401,96 E 1013.48 S 3482.57 E 1038.25 S 3563.12 E 1063.44 S 3643.67 E 1088.20 S 3724.18 E 1112.87 S 3804.57 E 1137.21 S 3884.97 E 1161.41 S 3965.19 E 1185.38 S 4045.23 E 1209.10 S 4125.26 E 1232.67 S 4205.25 1255.89 S 4285.20 1279.21 S 4365.08 1301.68 S 4445.18 1324.00 S 4525.20 1346.72 S 4605.06 E 1368.78 S 4684.92 E 1390.40 S 4765.10 E 1412.11 S 4845.76 E 1433.80 $ 4926.60 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 26 ORTH SLOPE, ALASKA ob Number: AKO2~OG208 A Gyrodata Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 7500,0 56 39 S 74 48 E 7600,0 56 26 S 74 51 E 7700,0 56 35 S 74 41 E 7800,0 56 35 S 74 49 E 7900,0 56 49 S 74 48 E 8000,0 56 51 S 75 3 E 8100,0 56 31 S 76 12 E 8200.0 56 32 S 75 22 E 8300,0 58 4 S 78 14 E 8400,0 57 52 S 79 3 E 8500,0 57 48 S 80 9 E 8600,0 58 13 S 79 40 E 8700,0 58 12 S 79 57 E 8800,0. 58 5 S 80 44 E 8900,0 58 12 S 81 3 E 9000,0 56 12 S 82 1 E 9100,0 56 19 S 82 3 E 9200,0 56 15 S 82 13 E 9300,0 56 17 S 82 49 E 9400,0 56 28 S 82 58 E 9500.0 56 27 S 82 46 E 9600,0 56 9 S 83 11 E 9700,0 55 18 S 83 1 E 9800,0 54 23 S 83 45 E 9900.0 54 8 S 83 59 E ,28 ,22 ,20 ,11 ,22 ,21 1.01 ,70 2.86 .72 ,93 ,59 ,25 ,68 ,29 2,16 .12 .16 ,50 ,22 ,17 ,45 ,87 1,08 ,32 VERT DEPTH ft 4795,6 4850,7 4905,9 4961,0 5015,9 5070,6 5125,5 5180,7 5234.7 5287,7 5341,0 5394,0 5446,6 5499,4 5552,2 5606.4 5661.9 5717.4 5772,9 5828,3 5883.6 5939,0 5995,4 6052,9 6111,3 VERT SECTION ft 5212,5 5295.9 5379,3 5462,8 5546,4 5630,1 5713,6 5797,1 5881,2 5965,8 6050,2 6134,8 6219,5 6304,2 6388,7 6472,3 6554.9 6637.5 6720.0 6802.6 6885.2 6967,7 7049,6 7130,6 7210.8 CLOSURE DISTANCE BEARING ft deg min 5214,6 S 73 47 E 5298,0 S 73 48 E 5381,4 S 73 49 E 5464,9 S 73 50 E 5548,4 S 73 51 E 5632.1 S 73 52 E 5715,7 S 73 54 E 5799,0 S 73 55 E 5883,1 S 73 58 E 5967,6 S 74 2 E 6051,8 S 74 6 E 6136,2 S 74 11 E 6220,8 S 74 16 E 6305,3 S 74 21 E 6389,7 S 74 26 E 6473,1 S 74 31 E 6555.5 S 74 37 E 6638.0 S 74 43 E 6720.4 S 74 49 E 6802,9 S 7~ 54 E 6885,4 S 75 0 E 6967.8 S 75 6 E 7049,7 S 75 11 E 7130.6 S 75 17 E 7210.9 S 75 23 E HORIZONTAL COORDINATES feet 1455,60 S 5007,34 E 1477.44 S 5087,86 E 1499,34 S 5168,32 E 1521,29 S 5248.86 E 1543.19 S 5329.52 E 1564,95 S 5410.35 E 1585.69 S 5491,30 E 1606,18 S 5572,16 E 1625,39 S 5654,08 E 1642,08 S 5737,19 E 1657,35 S 5820,45 E 1672,22 S 5903,95 E 1687.26 S 5987,61 E 1701,51 S 6071,34 E 1714,97 S 6155.21 E 1727.34 S 6238.35 ~ 1738.87 S 6320.71 ~ 1750,26 S 6403.10 _ ~ 1761.09 S 6485.56 E 1771.38 S 6568.19 E 1781.73 S 6650.89 E 1791,90 S '6733.46 E 1801.82 S 6815.50 E 1811.24 S 6896.71 E 1819.90 S 6977.42 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 26 ORTH SLOPE, ALASKA ob Number: AKO290G208 A Gyrodata Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING ft dee min dee min 10000.0 53 52 S 83 56 E 10100.0 53 54 S 85 12 E 10184.0 54 0 S 84 32 E DOG-LEG VERT VERT SEVERITY DEPTH SECTION deE/lO0' ft ft .28 6170.1 7290.9 1.03 6229.1 7370.6 .66 6278.5 7437.6 CLOSURE DISTANCE BEARING ft deg min 7290.9 S 75 29 E 7370.6 S 75 35 E 7437.7 S 75 40 E COORDINATES HORIZONTAL feet 1828.42 S 7057.87 E 1836.07 S 7138.28 E 1842.15 S 7205.92 E Final Station Closure: 7437.7 feet South 75 deg 39 min 35 sec East · . [ , ELD~ 'I. £LD · · . I · . o '1~£0 ~':[ELI], · .I RI~CO-_RL[ 0G208 SURVEY REPORT ARCO ALASKA INC. KUPARUK FIELD, PAD 2K WELL NO. 26 NORTH SLOPE, ALASKA FEBRUARY 23, 1990 ICROFILHI:D Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713/461-3146 Fax: 713/461-0920 February 23, 1990 Mr. Tim Billingsly Arco Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk Field, Pad 2K Well No. 26 North Slope, Alaska Dear Mr. Billingsly: Enclosed please find one (1) original and nine (9) copies of the completed survey of Well No. 26. We would like to take this opportunity to thank, you for using Gyrodata and we look forward to serving you in the furore. Sincerely, Gary Uttecht Vice President, Technical Services GU/cv Enclosures Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA/Ventura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina / Bergen, Norway A Gyrodata Directional for ARCO ALASKA INC. KUPARUK FIELD, PAD 2K, WELL NO. 26 NORTH SLOPE, ALASKA Survey. Date Run: 19-FEB-90 12:27:34 Job Number: AKO290G208 Surveyor: MIKE HOWATT Calculation Method: RADIUS OF CURVATURE Survey Latitude: 70deg 14min 37sec N Sub-sea Correction from Vertical Reference: 118.0 ft Bearings are Relative to TRUE NORTH Proposed Well Direction: S 75deg 25min Osec E Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 26 ORTH SLOPE, ALASKA ob Number: AKO290G208 A Gyrodat a Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min .0 0 0 N 0 0 E 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 0 20 N55 0 E 0 20 N 50 39 E 0 22 N 49 34 E 0 28 N 44 15 E 0 37 N 67 15 E 2 14 S 86 51 E 5 29 S 73 27 E 9 38 S 76 31 E 10 44 S 78 15 E 13 5 S 78 7 E 15 48 S 77 55 E 20 13 S 75 45 E 24 11 S 75 40 E 27 39 S 75 43 E 32 40 S 75 2 E 36 21 S 75 27 E 43 33 S 73 21 E 50 18 S 73 59 E 52 15 S 72 48 E 53 6 S 70 34 E 57 5 S 76 39 E 55 58 S 76 15 E 54 11 S 77 18 E 56 12 S 74 3 E DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/100' ft ft C L O S U R E DISTANCE BEARING ft deg min .00 .0 .0 .0 N 0 0 E MULTI SHOT SURVEY IN 7 INCH CASING ALL DEPTHS ARE REFERENCED TO KB ELEVATION KB TO GROUND = 36 FT. ( KB ELEVATION = 154 FT. ) .34 100.0 .2 .3 N 55 0 E ..03 200.0 .6 .9 N 53 34 E .04 300.0 .9 1.5 N 52 9 E .10 400.0 1.3 2.2 N 50 26 E .27 500.0 1.9 1.70 600.0 4.2 3.35 699.7 10.8 4.18 798.8 24.0 1.14 897.2 41.7 2.35 995.1 62.3 2.71 1091.9 87.2 4.47 1187.0 118.1 3.97 1279.6 155.9 3.47 1369.5 199.6 5.01 1455.9 249.8 3.70 1538.3 306.5 7.33 1614.9 370.6 6.75 1683.2 443.6 2.16 1745.7 521.5 1.97 1806.4 600.9 6.39 1863.6 682.8 1.16 1918.8 766.2 1.98 1976.0 848.2 3.35 2033.1 930.2 3.1 N52 1 E 5.4 N 64 23 E 11.6 N 84 1 E 24.3 S 84 49 E 41.9 S 81 41 E 62.5 S 80 32 E 87.5 S 79 49 E 118.3 S 79 2 E 156.1 S 78 14 E 199.7 S 77 40 E 249.9 S 77 13 E 306.5 S 75 51 E 370.7 S 7~ 25 E 443.6 S 75 58 E 521.5 S 75 35 E 600.9 S 75 4 E 682.8 S 74 54 E 766.2 S 75 4 E 848.2 S 75 14 E 930.2 S 75 16 E HORIZONTAL COORDINATES feet .00 N .00 E .17 N .24 E .52 N .71E .91N 1.17 E 1.41N 1.70 E 1.94 N 2.48 E 2.36 N 4.91 E 1.21 N 11.52 E 2.20 S 24.23 E 6.06 S 41.49 E 10.29 S 61.69 E 15.47 S 86.09 E 22.51S 116.18 E 31.84 S 152.79 ~ 42.64 S 195.14 55.33 S 243.74 E 69.76 S 298.51 E 87.01 S 360.31 E 107.54 S 430.37 E 129.83 S 505.12 E 154.82 S 580.60 E 177.94 S 659.22 E 197.48 S 740.31 E 216.24 S 820.13 E 236.55 S 899.67 E ~RCO ALASKA INC. iUPARUK FIELD, PAD 2K, WELL NO. 26 'ORTH SLOPE, ALASKA 'ob Number: AKO290G208 A Gyrodata Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 2500.0 56 9 S 73 18 E 2600.0 54 57 S 75 3 E 2700.0 54 47 S 71 52 E 2800.0 55 46 S 74 35 E 2900.0 59 39 S 76 44 E 3000.0 60 18 S 75 40 E 3100.0 59 57 S 74 59 E 3200.0 57 47 S 75 56 E 3300.0 57 53 S 75 37 E 3400.0 57 47 S 76 15 E 3500.0 57 52 S 75 2 E 3600.0 57 32 S 74 9 E 3700.0 57 24 S 73 46 E 3800.0 57 17 S 72 46 E 3900.0 57 40 S 72 13 E 4000.0 57 42 S 71 19 E 4100.0 57 51 S 71 13 E 4200.0 57 54 S 70 48 E 4300.0 57 30 S 70 21 E 4400.0 57 31 S 70 37 E 4500.0 57 28 S 71 27 E 4600.0 57 46 S 70 44 E 4700.0 57 31 S 72 14 E 4800.0 57 33 S 71 38 E 4900.0 57 22 S 72 32 E .61 1.87 2.61 2.44 4.28 1.13 .69 2.31 .29 .56 1.04 .81 .35 .84 .61 .76 .17 .36 .54 .22 .71 .68 1.28 .50 .78 VERT DEPTH ft 2088.7 2145.3 2202.9 2259.8 2313.2 2363.3 2413.1 2464.8 2518.0 2571.2 2624.5 2677.9 2731.7 2785.7 2839.5 2892.9 2946.3 2999.4 3052.9 3106.6 3160.3 3213.9 3267.4 3321.1 3374.9 VERT SECTION ft 1013.3 1095.7 1177.4 1259.6 1344.1 1430.7 1517.4 1603.0 1687.6 1772.3 1856.9 1941.4 2025.7 2109.8 2194.0 2278.3 2362.7 2447.1 2531.4 2615.4 2699.5 2783.7 2868.0 2952.2 3036.4 CLOSURE DISTANCE BEARING ft deg min 1013.3 S 75 8 E 1095.7 S 75 4 E 1177.5 S 74 57 E 1259.6 S 74 51 E 1344.1 S 74 54 E 1430.7 S 74 58 E 1517.4 S 75 0 E 1603.0 S 75 1E 1687.6 S 75 3 E 1772.3 S 75 6 E 1856.9 S 75 7 E 1941.4 S 75 6 E 2025.7 S 75 3 E 2109.9 S 74 59 E 2194.1 S 74 53 E 2278.5 S 74 46 E 2362.9 S 74 39 E 2447.4 S 74 31 E 2531.8 S 74 23 E 2615.9 S 74 16 E 2700.1 S 74 10 E 2784.5 S 74 4 E 2868.9 S 74 0 E 2953.2 S 73 56 E 3037.5 S 73 53 E HORIZONTAL COORDINATES feet 259.90 S 979.39 E 282.38 S 1058.72 E 305.65 S 1137.11 E 329.36 S 1215.80 E 350.29 S 1297.69 E 370.95 S 1381.77 E 392.91 S 1465.65 E 414.41 S 1548.51 E 435.21 S 1630.56 E 455.79 S 1712.67 E 476.78 S 1794.66 E 499.24 S 1876.15 E 522.54 S 1957.17 E 546.77 S 2037.79 E 572.13 S 2118.19 E 598.57 S 2198.45 E 625.74 S 2278.57 653.29 S 2358.64 681.40 S 2438.36 ~ 709.57 S 2517.87 E 736.97 S 2597.62 E 764.33 S 2677.52 E 791.16 S 2757.62 E 817.33 S 2837.84 E 843.25 S 2918.05 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 26 ORTH SLOPE, ALASKA ob Number: AKO290G208 A Gyrodat a Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 5000.0 57 12 S 73 25 E 5100.0 57 22 S 71 51 E 5200.0 57 31 S 73 44 E 5300.0 57 26 S 73 42 E 5400.0 57 32 S 73 34 E 5500.0 57 22 S 73 24 E 5600.0 57 15 S 73 13 E 5700.0 57 37 S 72 37 E 5800.0 57 30 S 72 39 E 5900.0 57 16 S 73 9 E 6000.0 57 13 S 72 43 E 6100.0 57 4 S 73 36 E 6200.0 56 46 S 72 50 E 6300.0 56 35 S 73 49 E 6400.0 56 35 S 73 9 E 6500.0 56 25 S 74 0 E 6600.0 56 18 S 73 36 E 6700.0 56 21 S 73 51 E 6800.0 56 14 S 74 48 E 6900.0 56 6 S 74 2 E 7000.0 56 10 S 74 12 E 7100.0 55 44 S 74 55 E 7200.0 56 33 S 74 54 E 7300.0 56 46 S 74 58 E 7400.0 56 52 S 75 0 E .76 1.32 1.59 .10 .16 .22 .20 .63 .12 .48 .37 .75 .71 .84 .55 .73 .36 .22 .79 .65 .15 .73 .82 .23 .10 VERT DEPTH ft 3428.9 3482.9 3536.8 3590.5 3644.3 3698.1 3752.1 3805.9 3859.6 3913.5 3967.6 4021.8 4076.4 4131.4 4186.4 4241.6 4297.0 4352.5 4408.0 4463.6 4519.4 4575.4 4631.1 4686.0 4740.8 VERT SECTION ft 3120.4 3204.5 3288.7 3372.9 3457.2 3541.5 3625.6 3709.7 3794.0 3878.2 3962.2 4046.1 4129.9 4213.4 4296.8 4380.1 4463.4 4546.5 4629.7 4712.8 4795.8 4878.6 4961.7 5045.2 5128.9 CLOSURE DISTANCE BEARING ft deg min 3121.6 S 73 51E 3205.7 S 73 50 E 3290.0 S 73 48 E 3374.3 S 73 48 E 3458.6 S 73 48 E 3542.9 S 73 47 E 3627.0 S 73 46 E 3711.3 S 73 45 E 3795.7 S 73 44 E 3879.9 S 73 43 E 3964.0 S 73 42 g 4048.0 S 73 41 E 4131.8 S 73 40 E 4215.3 S 73 40 E 4298.8 S 73 40 E 4382.2 S 73 40 E 4465.4 S 73 40 E 4548.7 S 73 40 g 4631.8 S 73 41 g 4714.9 S 7~ 41 g 4797.9 S 73 42 E 4880.8 S 73 43 E 4963.8 S 73 44 E 5047.3 S 73 45 E 5131.0 S 73 46 E HORIZONTAL COORDINATES feet 867.88 S 2998.50 E 893.00 S 3078.81 E 917.93 S 3159.32 E 941.57 S 3240.25 E 965.33 S 3321.15 E 989.31 S 3401.96 E 1013.48 S 3482.57 E 1038.25 S 3563.12 E 1063.44 S 3643.67 E 1088.20 S 3724.18 E 1112.87 S 3804.57 E 1137.21 S 3884.97 E 1161.41 S 3965.19 E 1185.38 S 4045.23 E 1209.10 S 4125.26 E 1232.67 S 4205.25 1255.89 S 4285.20 1279.21 S 4365.08 1301.68 S 4445.18 1324.00 S 4525.20 1346.72 S 4605.06 E 1368.78 S 4684.92 E 1390.40 S 4765.10 E 1412.11 S 4845.76 E 1433.80 S 4926.60 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 26 ORTH SLOPE, ALASKA ob Number: AKO290G208 A Gyrodata Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 7500.0 56 39 S 74 48 E 7600.0 56 26 S 74 51 E 7700.0 56 35 S 74 41 E 7800.0 56 35 S 74 49 E 7900.0 56 49 S 74 48 E 8000.0 56 51 S 75 3 E 8100.0 56 31 S 76 12 E 8200.0 56 32 S 75 22 E 8300.0 58 4 S 78 14 E 8400.0 57 52 S 79 3 E 8500.0 57 48 S 80 9 E 8600.0 58 13 S 79 40 E 8700.0 58 12 S 79 57 E 8800.0 58 5 S 80 44 E 8900.0 58 12 S 81 3 E 9000.0 56 12 S 82 1 E 9100.0 56 19 S 82 3 E 9200.0 56 15 S 82 13 E 9300.0 56 17 S 82 49 E 9400.0 56 28 S 82 58 E 9500.0 56 27 S 82 46 E 9600.0 56 9 S 83 11 E 9700.0 55 18 S 83 1 E 9800.0 54 23 S 83 45 E 9900.0 54 8 S 83 59 E .28 .22 .20 .11 .22 .21 1.01 .70 2.86 .72 .93 .59 .25 .68 .29 2.16 .12 .16 .50 .22 .17 .45 .87 1.08 .32 VERT DEPTH ft 4795.6 4850.7 4905.9 4961.0 5015.9 5070.6 5125.5 5180.7 5234.7 5287.7 5341.0 5394.0 5446.6 5499.4 5552.2 5606.4 5661.9 5717.4 5772.9 5828.3 5883.6 5939.0 5995.4 6052.9 6111.3 VERT SECTION ft 5212.5 5295.9 5379.3 5462.8 5546.4 5630.1 5713.6 5797.1 5881.2 5965.8 6050.2 6134.8 6219.5 6304.2 6388.7 6472.3 6554.9 6637.5 6720.0 6802.6 6885.2 6967.7 7049.6 7130.6 7210.8 CLOSURE DISTANCE BEARING ft deg min 5214.6 $ 73 47 E 5298.0 S 73 48 E 5381.4 S 73 49 E 5464.9 S 73 50 E 5548.4 S 73 51 E 5632.1 S 73 5'2 E 5715.7 S 73 54 E 5799.0 S 73 55 E 5883.1 S 73 58 E 5967.6 S 74 2 E 6051.8 S 74 6 E 6136.2 S 74 11 E 6220.8 S 74 16 E 6305.3 S 74 21 E 6389.7 S 74 26 E 6473.1 S 74 31E 6555.5 S 74 37 E 6638.0 S 74 43 E 6720.4 S 74 49 E 6802.9 S 74 54 E 6885.4 S 75 0 E 6967.8 S 75 6 E 7049.7 S 75 11 E 7130.6 S 75 17 E 7210.9 S 75 23 E HORIZONTAL COORDINATES feet 1455.60 S 5007.34 E 1477.44 S 5087.86 E 1499.34 S 5168.32 E 1521.29 S 5248.86 E 1543.19 S 5329.52 E 1564.95 S 5410.35 E 1585.69 S 5491.30 E 1606.18 S 5572.16 E 1625.39 S 5654.08 E 1642.08 S 5737.19 E 1657.35 S 5820.45 E 1672.22 S 5903.95 E 1687.26 S 5987.61 E 1701.51 S 6071.34 E 1714.97 S 6155.21 E 1727.34 S 6238.35 E 1738.87 S 6320.71 1750.26 S 6403.10 1761.09 S 6485.56 E 1771.38 S 6568.19 E 1781.73 S 6650.89 E 1791.90 S 6733.46 E 1801.82 S 6815.50 E 1811.24 S 6896.71 E 1819.90 S 6977.42 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 26 ORTH SLOPE, ALASKA ob Number: AKO290G208 A Gyrodat a Directional Survey Page MEAS INCL BORE HOLE DOG-LEG VERT VERT DEPTH BEARING SEVERITY DEPTH SECTION ft deg min deg min deg/100' ft ft 10000.0 53 52 S 83 56 E .28 6170.1 7290.9 10100.0 53 54 S 85 12 E 1.03 6229.1 7370.6 10184.0 54 0 S 84 32 E .66 6278.5 7437.6 CLOSURE DISTANCE BEARING ft deg min 7290.9 S 75 29 E 7370.6 S 75 35 E 7437.7 S 75 40 E COORDINATES HORIZONTAL feet 1828.42 S 7057.87 E 1836.07 S 7138.28 E 1842.15 S 7205.92 E Final Station Closure: 7437.7 feet South 75 deg 39 min 35 sec East 08/02/90 by GREAT LAND DIRECTIONAL DRILLING, INC. for~Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK Well ...... : KRU 2K-26 Section at: S,75.42,E Engineer..: MIKE HOWATT Computation...: RADIUS OF CURVATURE Survey Date...' 07/13/90 RKB Elevation.: 154.00 ft API Number .... : 50-103-20126 Job Number .... : AK0290G208 INTERPOLATED MARKERS REPORT Surface Location: 321 NSL 94 WEL S2 TiON R8E MARKER I DENT I F I CAT I ON 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUKA MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST 0 0.00 0 -154 4271 57.62 3037 2883 9900 54.14 6111 5957 9906 54.12 6115 5961 9974 53.93 6155 6001 DIRECTION REL-COORDINATES BEARING FROM- WELLHEAD 0 N O.OOE ON 0E 2507 S 70.49 E 673 S 2415 E 7211 S 83.99 E 1820 S 6977 E 7216 S 83.99 E 1820 S 6982 E 7270 S 83.95 E 1826 S 7037 E BASE KUPARUK A PBTD 7" LINER TD 10184 54.01 6279 6125 10241 54.01 6312 6158 10327 54.01 6363 6209 10350 54.01 6376 6222 7437 S 84.53 E 7483 S 84.53 E 7552 S 84.53 E 7570 S 84.53 E 1842 S 7206 E 1846 S 7252 E 1853 S 7321 E 1855 S 7340 E- 14OUSTON A U,~TIN, TEX,~ CI:4A R T NO, _LI~_J J~RUt?,_~]~LII~ ~.:I£L[J:I,,.I%)O~2R,.WE,,L:L:N0. :2~ .~ ..! :~ , .~i ,., :..,..~,~ ::~,. ! 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'!,. ~:.,::~; . ::,' ...... . . t i t-'t L ' ,~j_ ' 'i_~. : ' ' .~. _! , : ~ . i i,~_]_~_. ; ]: i: . . i . . . '. ...... : .. '.: i . !'t-J-F ,,. I .~ :, ,. ~ ~ ;~ ~ 't -44es't"-E,~s"b{-,j'L"]~ ~ ":~-':'~"'---" "='--~ :ii: _~L~.~7!'-!",'-7 'i'~':" ~:i :i ' ::' : :;;. ::: ''' i ''' ', J',, !~ i ;i ~ '':: :'': '':' :'' ''.'' ., ~i-J-~-I,--'t-f i-l, t: !.t-- .j., ~ :- ; . ; : !: r ! ' ;: ~ !: ! ! i ! i; ; ~ ' ; ' ' : ' ' ' ; ' ~ . .. '-t-'!-1'+' 'I--'. t !- i ~ ,.. ~ ~ ~ · , ........ t ~ ~ ~ .... , i ~-~ ~ '~ !'i .... : ! ......... ~ ' , ' : · i .......... : I.. .i-J-J,: ,i , ~ 'i'I]? ! ! :"-! !'~ ! :~!! ril' '!': ''; .... ':i~ 'I'i ':'~ ' t ....... !'; ...... :~; .... f---? t~ ! t'? ' ~- -id ! f '-t : · · · , · : ~ . , · : : j , -- ~ : ~ ! . . : ; · . . .. , : ....... : . . , ~ . . t . ' 'T . ~ i - ! ' ! ! '. ' ' ! ...... --'-~- ....... -'-~' : ......... : ........ ! ' ----"-;-~' -I i-.q-!-u-~-~-.-~ ,..,~ - , :.., ~--q-~--!-i-il~i-4,-~: f -i;-tl-: - :;: i' ; ':"!':'' ::~'~'"~ ...2.:: '~:!.:;:!' :;': '":]";:: .... ;':'I ' .' :-;Ti l-i-i--f--i-!+f!-!!-i! ,,:: ':~' ..... , i ':~; ;~::"::~ ....... "'. :::. :i i -' I ' -¢4~L~,' ~ .... - ,~_ 3[_~_i~ ,~_, ............................................. _ , , ~~ -. · ..... ] ~ . : I ..... : ~ . . . ~ . , I .... ; ~ ....... : . , ~ : .... ; ...... ;.ill ~ . -t-+i-!' ,,-, -,-'~ , , 'F!": -~ .''': '~ :', ........ ~,.. i ;:: ! : ....... ~': ;: ::': :'; .... :fi HOUSTON INSTR[~ T ~UST~N. TEX CHART NO. I0 -z z © - ! - .I i'i_-: Z'i i~I 'i':i:" AOGCC GEOLOGICAL MA1'EtllALS INVENTOIIY LIST FOIl DEVELOPMENTAL WELLS COMPLETION DATE ~ ! ,, ~-/, ?~ co. CONTACT I / '1 si i i i I ! ! I I I I I I I I I I i I I I I I I ARCO Alaska, Inc. Date: June 29, 1990 Transmittal #: 7799 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. 3G-12 2K-26 LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return 6- 2 3- 9 0 AKRB900623 ~ 5/-5'-',-'~ ~'~ 2-1 8-90 378829 .~ ~'C'-.~~'- Receipt Acknowledged' Date: DISTRIBUTION: Lynn Goettinger Stat~5'[Alaska ~. R'EC EIVED d U L - 2 1990 cons. cor issio Anchorage . ARCO Alaska, Inc. Date: May 17, 1990 Transmittal #: 7760 RE71JRN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510'-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-24 2K-26 2K-23 2K-25 2K-13 KRU State #1 Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET · Pulse Echo Evaluaton PET Receipt Acknowledged: 2-13-90 7800-9696 2-19-90 8300-10220 2-1 2-90 2-14-90 8146-10130 2-11-90 6400-9464 2-27-90 559~-7140 Date: .......... DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) ARCO Alaska, Inc. Date: April 26, 1990 Transmittal #: 7746 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '2K-26 Gamma Neutron Log 2-18-90 4216-10226 Receipt Acknowledged' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) ., (: RECEIVED APR o ~ ]990 · N~sk~ O~t'& Gas Con~ Commission Anchorage gT^'t'£ OF' ALAS~\ O!I. ~ CA5 COII,",I~RW~T]OIt COHH(SSIOI] 8,0.P,£. l~spection Repot~ " · ~,,,~, ~ix: ._~/~ _l IJlll II -- . ^ud~o - -.:--- · , pstg_. : _--- Fump ihcr, cloe. pre~, 200 Full Charge Presaure Controlsl Hast~r ,_~7_/_ --~ ........ _ _. ,__-- __.- _:---. _Kelly_and Floor Safe~y Valves Upper'Ke[[¥~_~Te~: Fresaure Lover Kelly. ~/~ ?eat.Pressure ~all Type_~_~Te~ Pressure Choke _ Test ~ime ........ I,,',:. . :Ptp~ Ram$~ Blind Choke Line · Repair or Replacemene Co~im~ton office noc~fed, Remark;: or.tS, - AO&GCC ' cc' - Operator cc - Supervisor STATE OF ALASKA - ~,-~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Suspend _ Operation Shutdown X Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 99510 5. Type of Well: Development ...X. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 321' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1825' FNL, 1559' FWL, Sec. 7, T10N, R9E, UM At effective depth 1853' FNL, 1824' FWL, Sec.7, T10N, R9E, UM At total depth 1865' FNL, 1935' FWL, Sec. 7,T10N, R9E, UM (approx) 12. Present well condition summary Total Depth: measured 10350' feet (approx) true vertical 6387' feet (approx) (approx) Plugs (measured) None RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-26 9. Permit number 90-1 5 Effective depth: measured (approx) true vertical 10241' feet Junk (measured) 6 3 2 4' feet None Casing Length Structural 8 0' Conductor Surface 4 2 3 5' Intermediate Production 1 0 2 91 ' Liner Perforation depth: measured Size Cemented 16" 9 5/8" 1300 Sx AS III & 450 Sx Class G 7" 300 Sx Class G None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 10. APl number 50-103-20126 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 4271' 4235' (approx) 1 0327' 6374' (approx) RECEIVED 13. Attachments Description summary of proposal _ MAR -1 1990 Alaska OiJ & Gas Cons. CommisSl Anchorage BOP sketch 14. Estimated date for commencing operation March, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Detailed operation program , Status of well classification as: Oil X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~;[. ~ ~ Title Area Drillin9 En~]ineer FOR COMMISSION USE ONLY 10- ~)~/ Commissioner IApproval No. Date ~--2--~43 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test m Location clearance__ Mechanical Integrity Test M Subsequent form require ORIGINAL SIGNED ElY LONNIE C. SMITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History- Initial Report - Daily Inatractiofla: Prepare and submit the "Initial Repod" 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 ARCO ALASKA INC. KUPARUK RIVER FIELD ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25667 Title DRILLING ALK: 2588 Field Auth, or W.O. no. AK4583 KRU 2K-26 IWell no. Operator ARCO Spudded or W.O. begun IDate Hour SPUD I 02/05/90 18:30 Complete record for each day reposed DOYON 14 Date and depth as of 8:00 a.m. 02/06/90 ( 1) TD: 831'( 831 SUPV:SC 02/07/90 ( 2: TD: 3544' ( 2713] SUPV:SC 02/08/90 (3) TD: 4291'( 747 SUPV:CD 02/09/9O (4) TD: 4301' ( 10 SUPV:CD 12/10/90 (5) TD: 7880'( 3579 SUPV:CD 02/11/90 (6) TD: 9586'( 170 SUPV:CD 02/12/90 (7) TD:10194'( 6081 SUPV:CD 02/13/90 (8) TD:10350'( 156 R ¢ElVt s v:c -![ 1990 GaS Cons. C, omm; at '- ,Anchomg T~e above is correct Signatur~ ARCO W.I. 55.8533 Prior status if a W,O. CHANGING BHA MW: 8.8 VIS: 79 MOVE RIG FROM 2K-23, RU DIVERTER, SLIP AND CUT DRLG LINE, MU BHA, FILL STACK AND CHECK FOR LEAKS, DRLG W/ SS GYRO, POOH, PU MWD. RIG ACCEPTED 1000HRS- 2/5/90, SPUD 1830HRS-2/5/90. DAILY:S112,006 CUM:$112,006 ETD:S112,006 EFC:$1,439M DRLG MW: 9.3 VIS: 74 CHANGED OUT BHA, RIH, DRLG FROM 831' TO 3544'. DAILY: $57,437 CUM: $169,443 ETD:S169, 443 EFC:$1,439M CIRC MW: 9.5 VIS: 74 DRLG TO SURFACE TD, POOH PU HOLE OPENER, RIH, CIRC, POOH, RUN 9.625" CASING. DAILY: $52,785 CUM: $222,228 ETD:S222,228 EFC:$1,439M TEST FORMATION 9-5/8"@ 4271' MW: 9.1 VIS: 36 CMT 9.625" CSG W/1300 SX ASIII & 450 SX CLASS G, ND DIVERTER, NU BOPE, TEST SAME, OK, MU BHA AND RIH, DRILL OUT SHOE AND 10' FORMATION, TEST FORMATION TO 12.5 EMW, OK. DAILY: $223,839 CUM: $446,067 ETD:S446, 067 EFC:$1,439M DRLG 9-5/8"@ 4271' MW: 9.4 VIS: 37 :~ ~'/4301, T/ 7880'. D~ZLY:$77,159 CUM: $523,226 ETD:S523, 226 EFC:$1,439M For form preparation,~d d~strib~tion, ~ see Procedures Man~aJ, Section 10, Drilling, Pages 86 arl~87. DRLG 9-5/8"@ 4271' MW: 9.4 VIS: 35 DRLG, CIRC., SHORT TRIP, DRLG. DAILY:S62,170 CUM:$585,396 ETD:S585,396 EFC:$1,439M DRLG 9-5/8"@ 4271' MW:10.3 VIS: 45 DRLG, POOH TO TEST FORMATION, TEST TO 10.SPPG, TIH, CIRC AND INCREASE MUD WEIGHT, DRLG AHEAD. DAILY:S97,171 CUM:$682,567 ETD:S682,567 EFC:$1,439M RUNNING CSG 9-5/8"@ 4271' MW:10.4 VIS: 43 DRLG 194 TO TD,CIRC, POOH LDDP,LD RLL TOOL, NO LOGS BECAUSE BATTERY DEAD, RU TO RUN 7" CSG, W.O. ORDERS, RUN CASING. DAILY:S78,356 CUM:$760,923 ETD:S760,923 EFC:$1,439M / / (~ - i AR3B-459-1-D Number all daily well history forms consecutively no. as they are prepared for each well. Page ARCO ,land Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Filtal Rell~rl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted al~o when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completlorl and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. County or Parish NORTH SLOPE Field Lease or Unit I Well no. I KUPARUK RIVER FIELD ADL: 25667 ALK: 2588 KRU 2K-26 JTitle J DRILLING District ARCO ALASKA INC. Accounting cost center code State Auth. or W.O. no. AK4583 Operator A.R.Co. W.I. ARCO 55. 8533 Spudded or W.O. begun Date SPUD 02/05/90 Complete record for each day reported Date and depth as of 8:00 a.m. 02/14/90 ( TD:10350 PB:10241 SUPV:CD DOYON 14 I otal number of wells (active or inactive) on this pst center prior to plugging and ~ bandonment of this well our I Prlor status if a W.O. 18:30 RIG RELEASED 7"@10327' MW:10.4 NaCl RUN 7" CSG, CIRC.,CMT W/ 300SX CLASS G, ND STACK, NU TBG SPOOL, INJECT MUD RIG RELEASED, 0330 HRS, 2/14/90. DAILY:S246,827 CUM:$1,007,750 ETD:S1,007,750 EFC:$1,439 ECEIVED MAE-1 1990 .Oil & Gas Cons, Qmmissl Old TD PB Depth Released rig Kind of rig JNew TD Date Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir !Producing Interval Oil or gasTest time Production Oil on test Gas per day Pumo size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abo~,~i~ correct For form prepar~o~ an~ distributio~ / ~ ~ -- ~ see Procedures~ual, Section 10, Drilling, Pages ~and 87. AR3B-459-3-C INumber ell daily well history forms consecutively as they are prepared for each well. jPage no. OlvlliO~l of AtlantlcRIchfleldCompeny ARCO Alaska, Inc. Date: February 22, 1990 Transmittal #: 7673 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 2 6 LIS Tape and Listing 2 - 1 5 - 9 0 # 9 0 - 0 2 - 005AK Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: February 22, 1990 Transmittal #: 7674 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith is the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K- 2 6 Electromagnetic Resistivity/Dual Gamma Ray 2 - 1 3 - 9 0 2 K ~ 2 6 Dual Gamma Ray/Compensated Neutron Porosity/ 2- 1 3- 9 0 Simultaneous Formation Density 4291-~ 4291-- Receipt Acknowledged: DISTRIBUTION' D & M Drilling Franzen NSK state of Aiaska(+sePia) January 22, 1990 Telecopy.. (907)276-7542 ?, J. Archey Area Drilling Engineer ARCO Alaska, %nc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re ~ Kuparuk River Unit 2K-26 ARCO Alaska,' Inc. Permit Mo. 90-15 Sur. Loc. 321'FSL, 94'FEL, Sec. 2, T10N, ~SE, UM. Bt~ole Loc. 1567'FML, 1795'FWL, Sec. 7, T10N, RgE, UM. Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equi~ent so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~ truly 3ours, Chairmam of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COI~ISSION dlf Enclosure cc: Department of Fish & Gama, }{abitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AL~6KA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 i la. Type of Work Drill X Redrill m I lb. Type of Well ExpIoratory~ Stratigraphic Test Re-Entry _ Deepen --I Service _ Development Gas ~ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 154. Pad 118' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25667 ALK 2588 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 321' FSL, 94' FEL, Sec. 2, T10N, R8E, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1500' FNL, 1540' FWL, Sec. 7, T10N, RgE, UM 2K-26 #U63061 0 At total depth 9. Approximate spud date Amount 1567' FNL, 1795' FWL, Sec 7, T10N, RgE, UM 02-01-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K- 1 10223 MD 1567' @ TD feet 15' at 520 MD feet 2560 6389TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 500 feet Maximum hole an~le 56° Maximum surface 1 81 0psig At total depth (TVD) 6389' 3455 pslg 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casinc, i Weight Grade Couplin~i Length IVD TVD IVD TVD linclude stac~e data) 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 CF 12.25 9.625 36.0# J-55 BTC 4141 35' 35' 4141 3056 1080 Sx AS III & HF-ERW 450 Sx Class G 8.5 7" 26.0# J-55 BTC 10223 35' 35' 10223 6389' 175 SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet CasingconductorStructural Length Size Cemented True Verticaldepth Surface Intermediate JAN Production Liner ~'. i::;i~ Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat ~ BOP Sketch ~ Diverter Sketch Drilling fluid program X Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best el my knowledge Sisned '~~ '~ ~C~ Title Area Drillin~ Engineer Date Commission Use Only Permit Number I APInumber I Approval date I See cover letter for d~;~.)../~{~' 50-/0~' ~_.0/2_~' (]~ / 99 /Qlq other recluirements Conditions 'of 'approval Samples required __Y e s ,~ N o Mud log req~r'ed---'__-Y-e s ~ N o Hydrogen sulfide measures__Yes ~' N o Directional survey required ,~Yes __ N o Required working pres~,~,l~for BOP~ ._~-~;~ ~ 3 M; __ 5 M; __ 10 M' __ 15 M Other: //"~//~ //__~/// Z .... by order of Approved by % ~ ,/, L ~'~~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 / · ~n triplicate DRILLING FLUID PROGRAM (2K-26) Spud to 9-5/8" Drill out to Weight up surface casind weidht uo to TD Density 8.8-9.0 8.6-9.4 10.3 PV 15-30 8-10 10-16 YP 20-40 5-8 7-1 2 Viscosity 70-80' 35-40 35-50 Initial Gel 5-15 2-4 4-8 10 Minute Gel 15- 30 4 - 8 5-1 2 APl Filtrate 10-15 7-9 4-5 pH 9- 1 0 8.5-9 8.5-9.5 % Solids 10 +/- 4- 7 <12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser RECEtVED - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators ~:~,~ Oil.& ~as £,ons~ C~m~m~,~,~' Notes' ~, gnchor~'~ - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2K-26 is 2K-1. As designed, the minimum distance between the two wells would be 15' at 520'MD. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 1 000 1000 2000 ARCO ALASKA. ln~. Pad 2K. Well No, 26 Kupa~uk Field, Nor{h HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET Propoeed Slope, Aleaka 1000 0 I 1000 I SURFACE LOCAT I ON ~ 321' FSL. g4' FEL SEC. 2. TION. RSE WEST-EAST 2000 ~000 4000 I ! I 5000 I 6000 ! S 75 DEG 7150' 9TO 15 MINE TARGET) TARGET CENTER TVD=6216 THD=g908 DEP=? 150 SOUTH 1821 EAST 6914. TARGET LOCAT[ON~ 15OD' FNL. 1540' FWL SEC- T. TION. RgE TD LOCATION~ 1.56;7' FNL. l?g$' FWL SEC. ?. TION. RaE 7000 I 800{ ARCO ALASKA, Pad 2K. Well Not 26 Propoeed Kuperuk Field, North Slope, Alaeke 0 . RKB ELEVATION~ 154' 1000 _ 2000 _ 3000_ 4000_ 5000_ 6000_ KOP TVD=500 'TMD=500 DEP=O 3 BUILD 3 OEO 9 PER ioo FT 15 21 ? 33 B/ PERMAFROST TVD=1508 TMD=1562 DEP=288 3e T/ UGNU SNDS TVD=1642 TMD=1724 DEP=379 45 st EOC TVD=2098 TMD=2392 DEP=863 T/ W SAK SNDS TVD=2306 TflD=2773 DEP=ll81 B/ W SAK SNDS TVD=2856 TMD-3776 DEP-2021 9 5/8" CSO PT TVD=3056 TMD=414! DEP=2326 K-lO TVD=3283 TMD=4556 DEP=2673 AVERAGE ANGLE 56 DEG 46 HI N K-5 TVD=4658 TMD=7065 DEP=4772 T/ ZONE C TVD-6114 TMD"9722 DEP=6994 T/ ZONE A TVD=6153 TMD=9793 DEP-7054 TARGET CNTR TVD=6216 TMD=9908 DEP-Z150 B/ KUP.SNDS TVD=6279 TMD=IO023 DEP=7246 TD (LOG PT) TVD=6389 TMD=10223 DEP=7413 I 1000 I 2O00 3000 4000 5000 6000 7000 YER'r I CAL SECT I ON 8000 40 20 40 60 40 20 0 20 40 60 80 I I I I 800 0 - [ 500 1100 100 I 120 I 140 60 80 100 _ 1000 120 ....... I I I I I I I I i I I 60 40 20 0 20 40 60 80 1 O0 1 20 140 _ 40 _ 20 _0 _ 20 _ 40 _ 60 _ 80 : 100 .120 7 , 6 5 4 I3 t,,, .13 5/8" 5000 I-,51 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 15(X) PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST BO'Fi'OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 KUPARUK RIVER UNIT 20~ DIVERTER SCHEMATIC ,,I i_ 6 4 MAINTENANCE & OPEIRA~ 3 2 I I 1. UPON INfT1AL I~TALL4TION. (XOeE IqIIEVF..NI'r~ AND VERIFY THAT VALVE OPEN8 PROPERLY. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCE9 · GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4)Run and cement 9-5/8" casing. 5)Install and test BOPE. Test casing to 2000 psig. 6)Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs . g) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin!). Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. MUD CLEANER SHALE SHAKERS STI STIR STIR MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) L o.__Ec (2' thru (8) (3) Admin /~ ~ 9. (9 thru~ 10. l-Iv. 9o (10 and 13) 12. 13. (4) Casg (14 thru 22) 14. 15. (5) BOPE (23 thru 28) Company Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is we~] located proper distance from property line .................. 4. Is we~d_located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included .............. .. 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number .................. , ...... 16. 17. 18. 19. 20. 21. 22. Lease & Well No. /~D~ YES NO -- 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... z{~ ,,, 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 all casing give adequate safety in collapse, tension and burst.. .~ ,,, Is this well to be kicked off from an existing wellbore ............. ~.~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ....................................... ~. Is the drilling fluid program schematic and list of equipment adequate.4~ ,, , Are necessary diagrams and descriptions of diverter and BOPE attached.-~ ~oes BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/AMI RP-53 (May 84) .................. Is the presence of H2S gas probable .................................. ~ (6) OTHER (2~9~_thru 31) (6) Add: /~r'.~.~-/r: Geolo~/. Engineering: DWj~__ LCS -_~_~S ~EW~/ rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of Seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: ~3( -~$ ~4~f jv-~ ~,~'~;/v ~5' ) o~ m/< -/ 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. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SPERRY DATE: 90/02/20 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/02/20 ORIGIN OF DATA: 2K26 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** IClIOFILMED ,, ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 2K-26.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/02/20 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC. WELL: 2K-26 LOCATION: KUPARUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA RIG: DOYON 14 ENGINEERS: M. HANIK & R. KRELL COMMENTS: TOOL SHUT-DOWN DUE TO LOW BATTERY VOLTAGE AT 9852' MD. NUCLEAR DATA NOT QUANTITATIVE UNDER NON-ROTATING CONDITIONS. HARDCOVER TYPE EWR USED. ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# DEPT EWR MWD FXE MWD ROP MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD RHOB MWD DRHO MWD NPSC MWD LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY 255 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR , FXE ROP NF0 NFl NN0 NN1 GRC CAL RHOB DRHO NPSC MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD OHMM HOUR FT/H CTS CTS CTS CTS API INCH G/C3 G/C3 P.U. 68 68 68 68 68 68 68 68 68 68 68 68 ** DATA DEPT NN1 VERIFICATION (every 500 FT) EWR FXE ROP GRC CAL RHOB 4100.000 -999.250 4500.000 2632.000 NFO DRHO 5000.000 2584.000 NFl NPSC 5500.000 2660.367 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6000.000 2680.000 5.238 .471 254.063 671.000 599.000 94.783 8.400 2.383 -.012 39.484 6500.000 2936.000 4.216 .392 253.125 647.000 639.000 108.696 8.400 2.530 -.046 40.615 7000.000 2680.000 3.861 .569 276.730 627.908 564.450 101.501 8.400 2.335 -.018 40.568 7500.000 2552.000 3.635 .403 275.851 655.000 639.000 92.250 8.500 2.306 -.022 37.282 8000.000 2712.000 3.983 .469 286.388 695.000 711.000 116.522 8.550 2.302 -.016 33.568 8500.000 2712.000 3.745 .364 332.386 783.000 751.000 127.826 8.400 2.538 -.014 33.150 9000.000 2664.000 2.035 .475 256.471 695.000 647.000 147.826 8.400 2.267 -.008 40.935 9500.000 2584.888 735.000 -.001 10000.000 -999.250 3.745 .861 195.672 122.900 8°400 2.380 663.000 35.653 5.035 .692 151.758 687.000 719.000 103.016 8.570 2.448 -.010 33.068 4.679 .743 162.609 703.000 679.000 126.182 8.450 2.418 -.019 37.051 4.216 1.166 57.416 989.429 1022.634 351.339 8.610 2.274 -.007 42.513 -999.250 -999.250 88.728 -999.250 8.320 .500 ** 664 DATA RECORDS ** FROM 1024 -999.250 .000 4100.00 TO ** FILE TRAILER** FILE NAME: 2K-26.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/02/20 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: -999.250 -999.250 10400.00 FT NN0 -999.250 2632.000 2552.000 2623.458 2712.000 2648.000 2968.000 2584.000 2760.000 2920.000 2664.000 2545.985 -999.250 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/02/20 ORIGIN OF DATA: 2K26 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SPERRY DATE: 90/02/20 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT DIRECT DIGITAL LOGGING COI"IPUTER PROCESSED ANALYSIS Company _ARCO ~L~,KA I, de 11 .~.-.!,,~!~, ~!~:!::~i~ ' ~P I NUM : 5 O- 02"3-20126 Field KJPARUK RIVER DATE LOGGED: 02-18-90 Country USA CLIENT FORMAT DATA T APsE LOG I NFORMAT I ON STANDARD FORMAT ( L, I . S, ) Name: 2K-26 AP I NUM: 50-029-201 26 Well No.: ARCO 2K-26 Depths: ..... :42!.8,,,,0,0 to 1 0247. O0 Fimld: KUPARL~ RIVER DATE LOGGED: 02-18-90 Date: 19 JUNE, 1990 Tim~: 3:54 PM TUE, Pagm: .................... !,-~ ............ L, I I S I TAPE RECORDS REEL HEADER Pr~viou~ reel: TAPE HEADER 'H EA D.E R Date: 90/06/'19 Origin: Comments: Date: 9070G/'l 9 Origin: Previou~ .tape: Commentz: RECORDS Reel name: 378829 Page Tape nmmm: 378829 Continuation Continuation ~: Ol File name: ,OOi Service name: Maximum length: i'024 File type: LO HEADER RECORDS Version Previous ?ile: MHEM CN WN FN COUN STAT CTRY APIN LATI "LONG SECT TOWN RANG EKB EDF EGL PD LNF DHF RUN TINE DATE LC{3 SON LUN FL LUL ENGI WITN DD DL CBD1 CBLt TLI TCS TLAB BHT NAT MT MSS DFD NVIS DFPH DFL RM RMF MFST HFSS INFORI'IRT!ON RECORDS CONTENTS ~IRCO ALASKA INC ..................... 2K-26 APl NUll: 50-029-20126 ........ KUPARUK RIVER DATE LOGGED: 02-i8-90 NORTH SLOPE ........................ ~LIqSKA .............................. · usa ........................... 20 ! 26 ........................... 0 De:g, 0 Min. O, 0 Sec, N , . .0 Dig, 0 Min, O, 0 Sec, W ,, ..... : ......... '0, ~0 0 0 ................. O, 'OO 0 ................. HS ........ K8 K8 ........ i924,0.00, , lsd 2~90, , .3 '0 ........ 378829 G-2& 11 NORTH .SLOPE NORTH SLOPE EOEDER PYRON%STRRTTON ........ 1035.0, '000 ............. t 0228,000 ............. O, ~000 ................. O, .000 ................. 4216. 000 .............. 10226,000 ............. 0,000 ................. 1936. 000 .............. O, .000 ................. O, 000 ................. BRIHE · i : t I ~ e · a t · · t t I J · t 0 · 000 ................. 0.000... , ............. O. O00 ................. 0.000 ................. 0,000 ................. 0,000 ................. I· It · · 1 t · till lilt ·Ill ·Ill /lie llllll$11 ellililll l[lllllll Ill i/I/Iai tIlllll al. lllttl I1 IJtltl lllill #lllll IIlllllllllllllll lIIllllllllllllll ll·llllllllllllll l#IIlllllllllllll IIl·J eltel tlltl Il. Itt tlltl Illl Ifil ltll Imll IIIl lmml Iii· lllII lllii Jllil IllllllllllllmllllI·llllll· llllll·IlllllllllllllllllIl ·llllllllIIllIItlllllIIllil lllllIlllllllllllllllllIII1 llIIIlllllllllIllllIlllllIl llllllIIlllIlllllIIIIllllel lllllllllIIllIIlllllllllllll lllllllllllllllIIlllll, lIllll UNIT TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 &5 0 0 20 g5 0 0 20 g5 0 I0 4 ~8 0 0 34 ~5 0 0 34 65 0 '0, 2 65 0 -0 3 65 FT 0 3 4 6@ FT 0 3 4 6~ FT O 3 4 6S :0 3 2 65 O 3 2 65 :0 0 4 68 :0 0 8 65 0 0 2 79 0 0 10 65 .0 O 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 .0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT .O 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF .0 i 4 68 DEGF 0 i 4 68 · 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP 0 2 4 68 '0 2 4 68 '0 2 4 68 OHMH 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHMM 0 2 4 68 Page: MIDST MC .SS C$ BS I NFORMAT I ON RECORDS CONTENTS O..:0 0 0 ~'~b ................................................... I tli tIIlIIIII II IItlI II lII$& I Il II IlIIlIII II 8 '5 0 0 'l IIIlIIIWIiIlIIlIIIItIIlIIIIlIItIIlIIllItlIIImIIIIII UNIT DEGF TYPE CAT~ 2 2 SIZE 4 i2 4 4 CODE 68 ~5 Page WEll Location Comment 1: Well Location Comment 2: W~lt Location Comment 3: i.~ll Location Comment 4: SURFACE: COMMENT 321' FSL & 94' FEL RECORDS Page ~ell File Comment l: Well Fil~ Comment 2: ~11 File Comment 3: Well File Comment 4: COMMENT RECORDS MAGNETIC MARKS USED FOR DEPTH CONTROL. Pag~ COMMENT .RECORDS LIS tape writtmn by: ANCHORAGE COMPUTING CENTER mm All curve and tool mnemonics used are those which most closel~ match mm Halliburton curve and tool mnemonics. ~m HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 42~?o8:8 ~.0247,88 TENS CHT LBS TENS CNT LBS 4217,00 10246,88 GR CNT APl GR CNT APl 4217,00 1~246,.08 FCNL CNT CPS FCNL CNT CPS 4217,80 18246,80 NCNL CNT CPS NCNL CNT CPS 42l?,80 I~246,80 NPHI CNT SSPU NPHI CNT SSPU 4217,80 ~0246,~0 NEAT CNT NEAT CNT 4217,00 10246,'00 Page DATA ENTRY ~FORMA T SPEC I f I CA TYPE SIZE CODE ~ GG T I 0 N S · $*~ ENTRY BLOCK LE~E.ND *~*~ ****************************** TYPE gESC~PTION t Tmrmina.tor ( no more en%riez ) DATA FOR~I. AT SPEC I F I CAT I OHS · ~ DATUN SPECIFICATION BLOCKS SERVICE SERVICE API API API AP1 FILE ID ORDER ~ UNIT LOG TYPE CLASS HOD # DEPT TENS CNT- FCNL CHT NCNL CNT~ NPHI CNT NRAT CNT 8829 FT 0 0 0 S829 LBS 94 635 0 i 8829 APl 94 3i0 i i 0 8829 CPS 94 334 3i 1 0 8829 CPS 94 334 30 I 0 8829 SSPU 94 890 J i 0 8829 94 420 i i 0 PRC SIZE LVL SNPL RC 4 0 t 68 4 0 i :68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 t 68 PROCESS iNDiCATORS 000000 O00'O00 000000 000000 0.0.000'0 000000 000000 0:00000 000000 000000 000000 000000 00000'0 000000 000000 000000 OOO000 000000 000000 '000000 000000 Page i 0 DATA RECORDS DEPT TENS GR FCNL NCNL NPHI NRAT Page I 0146.500 2953. 000 64.50:0 39.1 O0 120. 000 45. 760 2.'~49 i 0046.5~00 292.3. 000 55,60'0 62.500 159,800 32,160 2,4t9 9946,500 2906,000 72,900 49,100 133,300 37,340 2,62.8 9846,50,0 2852,000 1'04, I O0 42,0t30 122.600 42,420 2,800 9746.500 2913. OOO 92,200 37.9100 113.700 44,61 0 2,890 9646,500 2884.00.0 95. 800 39,400 I I :1 , ?00 43/220 2. 814 9620,50.0 2796,000 1.07,.800 39,600 118,900 47,470 2.999 .9520,500 2687,000 184,600 32,70'0 1.09,400 46,1 20 2. 949 9420,5-00 2727,'000 19i . ?00 35. 000 1 05,900 46. 040 2,930 9320,500 2?63,000 127,.300 38,400 112,800' 45,800 2.939 9220.5:0'0 2691 . 000 86,900 41,300 1I?,200 41,380 2.765 DEPT TENS D A T A RECORDS FCNL NCNL NPH I NRA T Pagm 9120,5100 2691 . 000 ;:'2,200 56. 1 O0 122. 800 30. 740 2 . 330 9020,500 2598,000 ;:'2. 600 46.400 121,900 34,500 2.528 8920,500 26:03. OOO 94,800 38..7:0:0 1 07.70'0 42. 920 2. 833 8820. 500 2483. 000 83. 000 §5.300 125,000 29,900 2.296 8720,500 2530.0'00 1.03,200 4'1,600 111,400 38,320 2,662 862.0.500 2354,00'0 93. SO0 48.4;0'0 121 ,600 34, '660 2,512 8520,500 2508,000 53,600 118,9010 27,290 2.165 8420,500 234'5,000 54,6~0 124.700 31.280 2.386 8320,5:00 235'0.000 65.400 48,000 126. 900 3'3. 460 2, :5'01 8220,500 . 2331,0'00 ?0,00.0 SO,O00 120,800 34.880 2.565 8120,500 2383.'000 70,50:0 50.500 123,700 32,450 2,446 DATA RECORDS DEPT TENS GR FCNL NCNL NPHI NRAT Page 8020.50'Q 2297,000 87,300 41 .800 I 11 .200 ,34.370 2.523 7920,50Q 230'8. 000 90,700 38.500 I 07,200 40,300 2.759 ?$20,5.0Q 2224. 000 106.5'00 35 . 4'00 96.800 ;~9.810 2.717 7720,500 21 ?4. 000 103,90:0 35,0~00 I 03, :000 45,450 2,946 7620,50'0 2049,000 135,900 35,4.00 1 00,000 43,77'0 2,871 ?5;20,5.00 2!092,000 i 26,00 rO 30' 200 94' ?00 49' I 1 0 :3' 075 7420''5:00 2'089' 000 83' 700 34' 300 96' 800 44'41 0 2'926 ?320'500 '1991'000 100'000 4'I''00~0 110'000 38.250 7220,500 2002.'000 86, ?'00 41 · 000 113. 600 37,320 2. 672 .- 7120.500 1971 . 000 123,400 45.8~0 I 08,300 36, '050 2.3;32 7020,500 1927,000 99,1 O0 39,500 I 18,700 37,770 3. 029 DA TA RECORDS DEP T TENS GR FCNL NC NL NP H I NRA T Page 14 6920,50~0 1.912,000 85, I O0 41 .6!00 1 {8,300 31 .300 2,522 6,82.0,50.8 J883,000 .'BI ,300 38,2~00 1 08,300 35,580 2,413 6720,50.~0 194:7. 000 67',800 54,590 1 07,200 39,80.0 2.,362 6620,500 t872.008 116,900 46,500 115,500 41,670 2,5.09 6520,500 1878. 000 87,.600 52,6:00 '112,200 47,210 2.31~ 6420.500 1821 . 000 67,1 O0 4'0.3010 114,000 40.520 2.685 6320,500 1793.000 88.500 40.300 126.300 47.150 2.703 6220,500 18t1,000 75,600 35,800 121.600 50,930 2,925 6120.500 1761 · 000 90,300 3'9,3~00 1 09. 800 45,540 2,643 6020. 500 1 7:34. 000 85. OOO 40,000 1 05. '000 51 . 500 2. 782 5920.500 t69S,000 84,900 37,700 98,300 45.460 2,576 DATA DEPT TENS GR FCNL RECORDS NCNL NPNI NRAT Page t5 5820,5'00 1693.000 78-,500 36,6'00 11 !,600 40.890 2.761 5720.500 16.05,000 81 ,800 35,000 103.300 46,620 2,678 562.0,500 1623,000 ?4.400 39.300 t19.600 49,640 2,977 5520.50,0 16'02,000 81 .60'0 35,490 I 06,400 47. 120 2,823 542.0.500 1539.000 82,800 36.6,98 98,300 44,670 2.745 5320,5.00 1483. OOO 72,40.0 33,890 93,5.00 47,150 2.677 5220. 500 '!495,000 83.4 0'0 232, ? O 0 1 0 O, .0'00 45 ;.31 0 2.85:2 5120.5:0'0 1452.00-0 74.900 36.600 tlt.d, OO 56.620 2.855 5020.500 143:7. 000 83.800 33.800 108.400 44.990 2.916. 4920.500 1422,000' 67. 700 31 . 600 93. 300 64. 780 2. 746 4820.500 1410.000 69.800 29.500 10! .600 47.240 2.91:0 DATA RECOR'DS. DEPT TENS GR FCNL NCNL NPHI NR~T Pmgm 16 472.0,50.0 13:37.00'0 75,200 35,~00 t 00,000 54,140 2.891 4620,500 '1359.00'0 71 .600 36,60'0 I 01 ,60'0 56.490 2.842 4520.500 t295. 000 76. 500 36.000 93,400 47.51 0 2.576 4420,50{3 13:05. 000 7! ,600 33,8~0 I 08, '000 55,970 2,9'07 4320,5.00 1'261 .-000 87,200 32,7'0'0 98. 300 50,050 2,796 4220,50'0 1227. 000 42.300 27.40~0 80.60'0 62,700 .3. 099 Fila nama.., &GSFO!.O01 Maximum length: I'024 File t.wpe: LO TRAILER RECORDS Version Next ~ile: Dat~: Page l? :** EOF *** **~* FILE HEADER *********************** HEADER RECORDS File name: ,002 Service name: Version Maximum length: 1024 File typ~: LO Previous ?ile: Dat~: Page MNEM CH ~!N FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG .KB EDF .GL PD LNF RUN TIME DATE LCC SON LUN FL LUL ENGI WITN DL CBD1 CBL ! TLI BL'I TCS TLAB BHT HRT lit DFD M¥IS DFPH DFL RM RMF MFSS I NFORMAT I ON RECORDS CONTENTS ~RCO ALASKA INC .............................. 2K-:26 API NUN: 50-029-20126 ................. KUPARUK RIVER DATE LOGGED: 02-18-90 ......... NORTH SLOPE ................................. ,~ L ~S KA ....................................... 20t2g' 666 0 Dec. 0 Min. O, 0 Sec, H ........... 0 Deg, 0 Min, ~.02 .............. 1;0 .............. ;0,9 .............. 154,00.0 .......... :0,000 ........... O, 000 ........... tis KB KB i 924,0 O0 ....... t8/ 2/.9'0 ....... 30 ............. 37'8829 ......... NORTH SLOPE NORTH SLOPE ROEDER ......... PYRON/STRATTON, 10350,'000 ...... O, 000 .......... 0,000 ............ 4216. 000 ......... ~022~,000 ........ O, 000 ............ ~ 936. 000 ......... O, O00 ............ O, 000 ............ BRINE ........... Sec W i IIllIIIlIIllIII~II'ilII I I¢III,llIlII,IlIIIIIII IIIlIIIIlIIIIIIlIIIIIIII IIIlII IIIIIIIIIllllIIlI IlIIIlllIiIIItllIIllIIllI IIt. I.IIIllIIlmImlllll.|I · IlIlltIIIltt,,It/IlIllIII III.lllli..lltltll,IllIIlll i6:, 66; ...... ::" · O. 000 ............ 0.000 ............ 0,000 ............ O, O00 ............ 0,000 ............ O, 000 ............ "666 ......... :" IIlI .Ill lIII IIII II.liI|rllIIll,lillI|IlI! IIlitl|lllIIlIIIlIIltlIIl IlIlIIllIIlIIIlIIIIlIIIIl IIIll.lIIIIlIIlIItIIIIiIl IliIlIIIIlIIIIIIIIIIlIl·l IlIIIlIlIIlIlIlIIlIlIIIlI IIIIIIlIIIII IlIIItIIIlIl IIIIIIItlIIl IIllI.IlI·tl IlIlIIIaIIIIIIIImIItIaIlIIIIIlIIIlIIII .lWIIlIIIIIIIIIIllItllIIIIlellIIIIlIII IlllllIIlIlIIlIIIllllIllIllltll.lllll. IIIllIIIlIlllIIIIllIIIlIIllIlIlIlIlIli I.IIIIIilIlIIIlIIIIlIIIIIIIIlllIlIIlII IIlIlllIIIIlIIIIll'lllllIiIiIIIIllllIII IilIlIIIIlIIlIIIIlIIIiIIIlllllIllIIlII iilllIlllIIllIIIliIllIIIIlIIllllIIIIII IIllIIlIIIIlIIlIIIllllIlIIIIlllIlIlIII UNIT ..TYPE CATG SIZE 0 0 40 0 0 4.0 0 0 40 0 0 20 0 0 20 0 0 2.0 0 0 4 0 0 34 0 0 :34, 0 0 2 0 .0 3 0 0 3 FT 0 3 4 FT ~0 3 4 FT .0 3 4, 0 ~ 2 0 3 2 0 3 2 0 :0 2 0 0 4 0 0 8 · 0 0 2 0 O i 0 0 0 JO 0 0 20 0 0 20 0 0 20 0 0 2 0 FT 0 3 4 FT .O 3 4 FT 0 3 4 FT 0 3: 4 FT 0 3 4 FT 0 3 4 HR -0 2 4 HR 0 4 4 DEGF 0 l 4 DEGF 0 I 4 O. 2 20 .0 2 2 0 LB?G 0 2 4 CP 0 2 4 0 2 4 0 2 4 OHMM 0 2 4 OHMM 0 2 4 DEGF 0 2 4 0 2 i2 OHMM 0 2 4 CODE 65 6,5 ,S5 65 65 68 65 65 6,5 65 65 65 65 '79 65 '79 65 65 65 65 68 6,9 6,8 6,8 68 65 65 6,8 68 68 6,5 6,8 Page 19 I NFORMAT I ON RECORDS 2O MNEM HCST .CS CONTENTS O, :000 ................................................... ? .000 ................................................... 8..500 .................................................... UNIT DEGF TYPE 0 0 0 0 CflTG SIZE 4 i2 4 4 CODE ~8 68 CO~MMENT Well Location Comment 1: SURFACE: 32'1' FSL & 94I FEL W~lt Location Comment 2: W~ll Location Comment 3: Well Location Comment 4: R E C 0 R D S Page Well File Comment Well File Comment Well File Comment Well File Comment C O M,MEN T R E CO R ~ S MAGNETIC MARKS USED FOR DEPTH CONTROL. LIS ~ape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonicz uzmd ar.e thoze which most closely match Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 42t?.~0'~ ~0247.00 TENSt CNT LBS TENS CNT LBS 9620.56 1'0247.:0'0 GR! CNT API GR CNT API 9620.50 10247,'00 F.CflL! CHT CPS FCHL CNT CPS 9620.56 t9247,~0 NCNLI tNT CPS NCNL CNT CPS 9620.50 10247,60 NPHI1 CNT SSPU NPHI ~CNT SSPU 9620,56 '1~247.~0 NRAT! CNT HRAT CNT 9'620.50 1.0247.00 Page 2.3 DATA ENTRY · ~ ENTRY BLOCK LEGEND TYPE DESCRIPTION Terminator ( no more entries > FORMA T SPEC I F I CAT IONS TYPE SIZE CODE 16 1 66 Pag~ DATA FORMAT SPEC I F I CAT IONS ***~ DATU~ SPECIFiCATiON BLOCKS MNEM SERVICE SERVICE API API APl API FILE ID ORDER ~ UNIT LOG TYPE CLASS MOD i~ DEPT 8829 NCNL CNT 8829 NPNI CNT' 8829 NRAT CNT 8829 FT '0 0 0 iO LBS 94 635 0 3 1 API 94 31'0 i 3 i OPS 94 334 30 3 i SSPU 94 89'0 3 3 94 42'0 1 3 i PRC ~ SIZE LVL SMPL RC 4 0 1 68 4 O I 68 4 0 I 68 4 0 1 68 4 0 ~l 68 4 0 1 68 4 0 i 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 O00000 000000 800000 000000 000000 8.00000 000000 000000 80OO00 000000 000000 000000 000000 000000 00:0000 000000 Pag~ ¸25 DA TA RECORDS DEPT TENS GR FCNL NCNL NPHI NRAT I 0247.000 I7'2:8. 000 0.:000 Page 26 0,000 0.000 43.640 0,000 1 0147. !000 2920. 000 64,70:0 45. 900 123.4~00 40.7'60 2.75'5 J 004:7,000 2'967. 000 54,80'0 72.400 145.800 28.600 2.224 2806.000 69.900 46,900 128.300 34.890 2,539 984:7,000 2896.000 106,900 41 ,00~0 119.6:00 3"3,850 2.707 9747,000 2869, 000 90,600 38.9~0 ! 15,000 43. ~60 2,830 9647.~000 282'0,000 10.0.60:0 41 .400 113.500 42. 220 2.7'9'1 9'620,5:00 2770. 000 101 . 000 38,9{10 1 ! S, 000 41 . 060 2 , :876 FILE TRAILER ************************ TRAI LER RECORDS File name.: &GSF~0'I.002 Smrvice namm: Version #: Date: Maximum lmngth: i'024 File type: LO Next ¢ile: Pagm 27 :~* EOF TAPE TRAILER Service name: &GSF01 Next tape: TRA I LER .RECORDS Date: 90/0G719 Origin: Tape name: 370829 Comments: Pag~ Continuation #: O~ 28 *** REEL TR~ ILER *********************** Service name: &GSFO'I Next ceel: Date: 90/06/19 Origin: Reel name: 37.8829 EOF Continuation #: 01 EOF