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192-131
RECEIVED • STATE OF ALASKA • FEB 01 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN6QacC la.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned I] Suspended❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 12/21/2016 , 192-131/316-509/ 3.Address: 7.Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 1/7/1993 50-029-22315-00-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 671'FNL, 1156'FEL,Sec 33,T12N, R10E,UM 1/10/1993 KRU 1H-16 Top of Productive Interval: 9. Ref Elevations: KB:96 17. Field/Pool(s): 1225'FSL, 1150'FEL,Sec 28,T12N, R10E, UM GL:54 BF: Kuprauk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1549'FSL, 1140'FEL,Sec 28,T12N,R10E, UM 7179/6627 ADL 25639 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.Land Use Permit: Surface: x- 549192 y- 5980029 Zone- 4 7510/6908 ALK 464 TPI: x- 549181 y- 5981925 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 549188 y- 5982249 Zone- 4 1793/1793 1454/1646 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth, if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL)I N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper,resistivity,porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A %MINED APR U 3201? 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 41 121 41 121 24 200 sx CSI 9.625 40 L-80 40 2672 40 2671 12.25 570 sx PF E CMT,190 SX Class G 150 sx PF C Top Job 7 26 J-55 39 7485 39 6887 8.5 590 sx Class G CMT 24.Open to production or injection? Yes ❑ No 2 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 6841 6805/6312 All Perfs squeezed offr'„/;)°'N-61C2 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. 12'%r Zt(\� Was hydraulic fracturing used during completion? Yes❑ No ❑ Per 20 AAC 25.283(i)(2)attach electronic and printed information l,t' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 6820'-7179' 50 bbls 16.5 ppg Class G CMT 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 8hrs Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - orm�10--4p �iced 11/2 p, /0767 fry---/....,z,`5-/ CONTINUED ON PAGE 2 RBDMS u� FEB - 2 2017Submit ORIGINIAL only/6, • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 2 If Yes,list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑ Permafrost-Top Surface Surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1454 1646 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. P - R f� I-510 Gcl0" / Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary,Schematic Information to be att- hed includes,but is not I. ited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, N. t. paleontological reports •duction or well test re ults.Der 20 AAC 25.070. 32. I hereby certify th' foregoing is true an'\correct to the best of my knowledge. Contact: Mike C- )r.-n • 263-4180 Email: Mike.Callahan@cop.com Printed Name: G.Eller l`���C Title: Lead CTD Engineer viihh -4‘ Signature: Phone: 263-4172 Date: \ (-22\1\1 INSTRUCTIONS General: This form and the required attac ents provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well c. • • report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. ofmultiple and the location of the cementingtool. Item 23: Attached supplemental records should show the details any cementing PPstage Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • S 1 H-16 DTTMSTF JOBTYP SUMMARYOPS 12/19/16 DRILLING Finish initial BOP test. Cut coil, perform coil pull test to trouble-shoot reoccurring coil SIDETRACK damage, linked to chain tension. Cut coil, perform slack management(total 74' coil cut). Pull BPV. MU cement pilot hole milling BHA#1 and RIH. 12/20/16 DRILLING Tag TOC @ 6837', turn hole over to milling fluid and mill 2.80" pilot hole in cement to SIDETRACK 7180', dressed same, POOH & un deploy BHA#1. PU and deploy BHA#2, real time caliper, RIH and log cement pilot hole from 6700 - 7170'. 12/21/16 DRILLING Complete final logging pass of cement pilot hole, POOH and lay down BHA#2. PU and SIDETRACK run BHA#3, 3.5" XL whipstock, RIH and set at TOW @ 7150'. Unable to stack weight on whipstock, push same to bottom @ 7180' & release. POOH & LD BHA#3. PU BHA#4, 3.5"XL whipstock#2, RIH and set TOW @7138'. POOH. Lay down BHA#4, PU BHA #5, RIH, dry tag TOW @ 7138'. Time mill exit window in 7" casing. 12/22/16 DRILLING Complete milling and dressing exit window in 7" casing at 7138'. POOH and PUD BHA SIDETRACK #5, PU and PD BHA#6, build bend drilling assembly. RIH and drill build section to planned TD of 7355'. POOH and PUD BHA#6. 12/23/16 DRILLING PUD BHA#6, PD BHA#7, A lat drilling assembly, RIH and drill from 7355 to 8874'. Cross SIDETRACK unexpected fault @ 7758' and expected fault at 8120'. Set down while RBIH from tie in wiper trip @ 8545 & 8565'worked through at reduced pump rate. Small amount of small shale returned to shaker— 1/16", suspect A6/A5. Pulled Geo wiper and continued drilling ahead per Geo. 12/24/16 DRILLING Drill from 8874' to TD of 10214'. Encountered sticky area at 8470-8565' and 8621' during SIDETRACK wiper trip, cleaned up same. Pumped sweeps and started long wiper to swab. 12/25/16 DRILLING Completed wiper to swab, RBIH, confirm TD @ 10216', POOH laying in beaded/lubed SIDETRACK liner running pill and 11.8 ppg KW fluid. Lay down BHA#7 over a dead well. PU BHA#8, 1H-16A Lower Lateral Assembly( 49 jts 2 3/8" Slotted Liner, non-ported bullnose, BHA and run to TD @ 10216'. POOH, and lay down BHA#8 over a dead well. 12/26/16 DRILLING Run Middle section of"A" lat, 2 slotted, 30 blank, & 10 slotted joints 2 3/8" liner. POOH, SIDETRACK Lay down BHA#9. PU BHA# 10, Upper section of"A" lat, one 2 3/8" slotted joint below an anchored billet. RIH, unable to orient, trip for HOT, replace same, RBIH. Set anchored liner top billet, top at 7402', POOH, Lay down BHA# 11. PU BHA#12, AL1 lateral drilling assembly, RIH and circulate out KW fluid. 110 0 .W.'0 Operations Summary (with Timelog Depths) 014 o 1 H-16 + , Phitii Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 12/17/2016 12/18/2016 12.00 MIRU MOVE MOB P Mob from 2X-13 to 1H-16, Leave 0.0 0.0 12:00 00:00 location 16:00 Arrive 1H pad @ 21:00. Remove jeeps,spot drilling sub over the well. 12/18/2016 12/18/2016 1.50 MIRU MOVE MOB P On location,spot pit sub,safe out 0.0' 0.0 00:00 01:30 walkways and landings 12/18/2016 12/18/2016 2.50 MIRU MOVE RURD P Start working rig up checklist,Connect 0.0 0.0 01:30 04:00 PUTZ,get steam around 12/18/2016 12/18/2016 2.00 MIRU MOVE NUND P Prep tree and set down stack,nipple 0.0 0.0 04:00 06:00 up BOP 12/18/2016 12/18/2016 2.40 MIRU MOVE RURD P Crew change,Work check list,C/O 4' 0.0 0.0 06:00 08:24 riser to 3', Measure stack, Perform valve checklist 12/18/2016 12/18/2016 0.60 MIRU WHDBOP RURD P PJSM for full BOPE test,fluid pack 0.0 0.0 08:24 09:00 stack.Leaking between Swab#1 & Swab#2.Tighten flange between swab valves. 12/18/2016 12/18/2016 9.00 MIRU WHDBOP BOPE P Start BOP test(3,500 psi/250 psi, 0.0 0.0 09:00 18:00 2,500 psi annular). Pin hole in MP line. Replace line. "RIG ACCEPT 09:00- 12/18/2016 12/18/2016 3.00 MIRU WHDBOP BOPE T Finished testing that does not require 0.0 0.0 18:00 21:00 MV. Test lower blinds against MV-fail. Close SSV,re-try test-fail. Open lower blinds,close upper blinds (already tested),re-test-pass. Open upper blinds,close lower blinds, re-test-fail(no fluid leaking at rig floor). Open SSV(which failed pre-rig DHD testing),grease MV,re-test lower blinds against MV-high&low pass. 12/18/2016 12/19/2016 3.00 MIRU WHDBOP BOPE P Cont. BOP test 0.0 0.0 21:00 00:00 12/19/2016 12/19/2016 0.70 MIRU WHDBOP BOPE P Cont initial BOP test(3500 psi/250 0.0 0.0 00:00 00:42 psi,2500 psi annular) 12/19/2016 12/19/2016 0.50 MIRU WHDBOP BOPE T Generators went down. 0.0 0.0 00:42 01:12 *0.5 hrs NPT for Nabors* 12/19/2016 12/19/2016 0.80 MIRU WHDBOP BOPE P Finish BOP testing. 0.0 0.0 01:12 02:00 *3 hrs NPT for Nabors due to 17 hr total BOP test time w/4 hrs backed out for trouble with MV&swabs* 12/19/2016 12/19/2016 1.50 MIRU WHDBOP PRTS P PT ODS PDL and TT line while 0.0 0.0 02:00 03:30 waiting on external coil connector and pull plate.Generators shut down when pumps came on,troubleshoot. 12/19/2016 12/19/2016 2.50 SLOT WELLPR CTOP P Trim marked/scared up CT 24',MU 0.0 0.0 03:30 06:00 external coil connector and pull plate. Overpull to 15k to ensure made up properly. 12/19/2016 12/19/2016 0.50 SLOT WELLPR CTOP P Crew change out,Valve check list 0.0 0.0 06:00 06:30 Page 1/17 Report Printed: 1/16/2017 • u. 0 Operations Summary (with Timelog Depths) ex 1H-16 < 'tai!li ss Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKD) 12/19/2016 12/19/2016 3.70 SLOT WELLPR CTOP P PJSM, Prep to pull test injector.Test 0.0 0.0 06:30 10:12 in stepwise manor 30K,60K and 90K with 800PSI tension pressure. Traction per pressure vs pull.No marks on pipe.Lower tension to 500 PSI.Traction to auto.First test produced no marks.Came up to top out speed and retest.Made marks 10' up from pull plate 12/19/2016 12/19/2016 3.70 SLOT WELLPR CTOP P PJSM,Cut 30'of CT-Boot wire. 0.0 0.0 10:12 13:54 Reverse circulate coil. Unstab injector. Trim 20'of coil to find wire(Cut total of 74'CT) 12/19/2016 12/19/2016 1.50 SLOT WELLPR CTOP P PJSM-Prep Coil and install CTC 0.0 0.0 13:54 15:24 connector-Pull test to 35K 12/19/2016 12/19/2016 1.00 SLOT WELLPR CTOP P PJSM,Head up eline to UQC and test 0.0 0.0 15:24 16:24 wire,550MOhmes/ 63 Ohmes Good test 12/19/2016 12/19/2016 3.30 SLOT WELLPR OTHR P Skid injector back-R/U to pull BPV. 0.0 0.0 16:24 19:42 Lubricator has some frozen ports, BPV out,Lay down BPV lubricator. WHP=950 PSI 12/19/2016 12/19/2016 0.20 SLOT WELLPR CTOP P PT CTC/UQC to 4000 PSI 0.0 0.0 19:42 19:54 12/19/2016 12/19/2016 1.10 SLOT WELLPR PRTS P Skid injector on well,valve frozen on 0.0 0.0 19:54 21:00 TT line,thaw,PT TT line,Bleed off well. 12/19/2016 12/19/2016 0.50 SLOT WELLPR OWFF P Flow check well. 0.0 0.0 21:00 21:30 12/19/2016 12/19/2016 1.50 PROD1 RPEQPT PULD P PJSM-M/U BHA#1 Cement pilot 0.0 62.0 21:30 23:00 hole BHA with D-331 slick guage(2.8" NoGo)and 0.9 AKO motor 12/19/2016 12/20/2016 1.00 PROD1 RPEQPT TRIP P RIH BHA#1 pumping 1 BPM of SW 62.0 6,500.0 23:00 00:00 displacing diesel out of wellbore. 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT TRIP P Cont RIH BHA#1 6,500.0 6,740.0 00:00 00:12 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT DLOG P Tie-in to K1 for a+5.5'correction. 6,740.0 6,764.0 00:12 00:24 12/20/2016 12/20/2016 0.10 PROD1 RPEQPT TRIP P Cont RIH and tag-up @ 6,837'. 6,764.0 6,837.0 00:24 00:30 12/20/2016 12/20/2016 0.60 PROD1 RPEQPT CIRC P PUH,swap to used PowerPro mud for 6,837.0 6,837.0 00:30 01:06 milling.PUW=34k.Close EDC.RBIH. 12/20/2016 12/20/2016 1.30 PROD1 RPEQPT MILL P Couple stalls to get started milling 6,837.0 6,893.0 01:06 02:24 cement.Milled cement for-0.5'. Minimal WOB,increased ROP to 50+ FPH to find cement. 12/20/2016 12/20/2016 2.30 PROD1 RPEQPT MILL P WOB increased @ 6,893',however, 6,893.0 7,000.0 02:24 04:42 ROP has remained in the 40-50 FPH range(suspect cement integrity). 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT WPRT P PUH to 6,780'to ensure hole clean. 7,000.0 7,000.0 04:42 04:54 RBIH. 12/20/2016 12/20/2016 4.80 PROD1 RPEQPT MILL P Milling ahead,WOB 2.2k, ROP 45 7,000.0 7,180.0 04:54 09:42 12/20/2016 12/20/2016 2.86 PROD1 RPEQPT REAM P At Pilot Hole TD of 7,180 ft. Make a 7,180.0 6,820.0 09:42 12:33 dry drift and observe a weight bobble at 6,850 ft/ 6,855 ft. Dress off area of interest at a low side orientation and then begin making backreaming passes as per procedure. Page 2/17 Report Printed: 1/16/2017 . . O 0 Operations Summary (with Timelog Depths) 1H-16 Conocoehillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/20/2016 12/20/2016 0.55 PROD1 RPEQPT OWFF P Conduct a No-Flow Test prior to 6,820.0 6,820.0 12:33 13:06 POOH. No-Flow Test was good. 12/20/2016 12/20/2016 1.58 PROD1 RPEQPT TRIP P POOH pumping at 1.7 bpm 6,820.0 71.4 13:06 14:41 12/20/2016 12/20/2016 0.60 PROD1 RPEQPT OWFF P At surface.Monitor well once again for 71.4 71.4 14:41 15:17 a 30 minute No-flow Test. 12/20/2016 12/20/2016 1.34 PROD1 RPEQPT PULD P L/D Pilot Hole Milling BHA#1 71.4 0.0 15:17 16:37 12/20/2016 12/20/2016 2.00 PROD1 RPEQPT WPRT P RBIH and Jet Stack, Change out, 0.0 0.0 16:37 18:37 blow down chokes,opeen and inspect, 12/20/2016 12/20/2016 0.70 PROD1 RPEQPT WPRT P Pull and lay down Mouse hole#1 in 0.0 0.0 18:37 19:19 preperation to lay down PDL#1 12/20/2016 12/20/2016 0.40 PROD1 RPEQPT PULD P Halliburton Logging on location, 0.0 0.0 19:19 19:43 unoad tools,make up same in pipe shed. 12/20/2016 12/20/2016 0.90 PROD1 RPEQPT PULD P PJSM,make up tools BHA#2 24 arm 0.0 24.8 19:43 20:37 caliper,bump up,zero. 12/20/2016 12/20/2016 2.40 PROD1 RPEQPT TRIP P RIH,shallow tool test at 300,good, 24.8 7,170.0 20:37 23:01 RIH.Tie into K1 for+5.5'correction 12/20/2016 12/20/2016 0.20 PROD1 RPEQPT TRIP P When pulling off bottom,observed 7,170.0 7,033.0 23:01 23:13 some noise from the injector, increased chain traction from 830 to 1020 psi,noise subsided. Observed a few small marks in the coil.retracted caliper arms. 12/20/2016 12/20/2016 0.30 PROD1 RPEQPT TRIP P RBIH,inspect pipe and buffed out with 7,033.0 7,170.0 23:13 23:31 file and emery cloth.RBIH Pull up hole with no noise or indication of chain slip. RIH to logging depth 12/20/2016 12/20/2016 0.30 PROD1 RPEQPT DLOG P Open caliper arms and POOH @ 45 7,170.0 6,700.0 23:31 23:49 fp/min logging pilot hole from 7170- 6700'. Note fingers 4.55'feet up from bottom of caliper,bottom of log starts at 7165.45' RBIH 12/20/2016 12/21/2016 0.17 PROD1 RPEQPT DLOG P RBIH 6,700.0 7,170.0 23:49 00:00 12/21/2016 12/21/2016 0.30 PROD1 RPEQPT DLOG P Perform second logging pass over 7,170.0 6,700.0 00:00 00:18 same interval at 45 ft/min. Note fingers 4.55'feet up from bottom of caliper,bottom of log starts at 7165.45 12/21/2016 12/21/2016 1.30 PROD1 RPEQPT TRIP P Retract caliper arms and POOH 6,624.0 25.8 00:18 01:36 12/21/2016 12/21/2016 1.00 PROD1 RPEQPT PULD P Bump up,30 min flow check-good. 25.8 0.0 01:36 02:36 PJSM, LD BHA#2. 12/21/2016 12/21/2016 1.00 PROD1 RPEQPT PULD P PJSM,PU BHA#3,whipstock,Open 0.0 74.3 02:36 03:36 EDC,tag up. 12/21/2016 12/21/2016 1.50 PROD1 RPEQPT TRIP P RIH w whipstock,90 fpm. Tie in at the 74.3 6,770.0 03:36 05:06 K1 for a+4.5'correction,Wt ck,38k lbs. Pumps down,close EDC,zero WOB. 12/21/2016 12/21/2016 0.55 PROD1 RPEQPT WPST P RIH, Online with the pump,pressure 6,770.0 7,180.0 05:06 05:39 broke back at 3611 psi. Set whipstock at 7150'and 0 deg ROHS. Attempt to set 5k down,unable to stack weight. Consultwith town,push whipstock to bottom. Page 3/17 Report Printed: 1/16/2017 0 • 0 Operations Summary (with Timelog Depths) 1H-16 conocommips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/21/2016 12/21/2016 0.51 PROD1 RPEQPT WPST T Whipstock on bottom at 7,180.6 ft. 7,180.0 7,180.0 05:39 06:09 Release from Whipstock. 12/21/2016 12/21/2016 1.44 PROD1 RPEQPT TRIP T POOH . 7,169.0 78.9 06:09 07:36 12/21/2016 12/21/2016 0.55 PROD1 RPEQPT OWFF T At surface. Perform 30 minute No- 78.9 78.9 07:36 08:09 Flow Test.Hold Undeploy PJSM while waiting on flow test. Note:Just recieved email confirmation on plan forward @ 0739 hrs. .Will set a second Whipstock w/OH Anchor. tows depth will be 7,138 ft(12 ft higher than previous attempt)oriented 5 deg ROHS. 12/21/2016 12/21/2016 0.65 PROD1 RPEQPT PULD T L/D BHA#3. 0.0 0.0 08:09 08:48 Note:Shear stud had all threads on rod and also was in stroked position as it should be. 12/21/2016 12/21/2016 3.00 PROD1 RPEQPT WAIT T Wait on new whipstock to be sent from 0.0 0.0 08:48 11:48 Baker in Deadhorse. 12/21/2016 12/21/2016 0.88 PROD1 RPEQPT PULD T Baker shows up with Whipstock#2. 0.0 72.9 11:48 12:40 P/U BHA#4 with second Whipstock. Open EDC,tag up. 12/21/2016 12/21/2016 1.89 PROD1 RPEQPT TRIP T RIH w whipstock,80 fpm. Tie in at the 72.9 6,777.0 12:40 14:34 K1 for a+5'correction,Wt ck,38k lbs. Pumps down,close EDC,zero WOB. 12/21/2016 12/21/2016 0.96 PROD1 RPEQPT WPST T RIH, Online with the pump,having 6,777.0 7,138.0 14:34 15:31 trouble getting the whipstock to set. Have taken the pump pressure up to 6,800 psi numerous times with no luck We set down 10k while pumping,but little overpull when PUH. It appears the OH Anchors have set.We are having difficulty now releasing from the Whipstock. PUH again and now appears we have released off the Whipstock. Set whipstock at 7138' and 5 deg ROHS. 12/21/2016 12/21/2016 1.44 PROD1 RPEQPT TRIP P POOH with open EDC pumping at 7,138.0 70.0 15:31 16:58 1.46 bpm 12/21/2016 12/21/2016 0.55 PROD1 RPEQPT OWFF P At surface.Perform 30 minute No- 70.0 70.0 16:58 17:31 Flow Test. Hold PJSM while waiting on flow test. 12/21/2016 12/21/2016 1.40 PROD1 RPEQPT PULD P UD BHA#4 and P/U BHA#5 Window 70.0 74.3 17:31 18:55 Milling BHA 12/21/2016 12/21/2016 1.80 PROD1 WHPST TRIP P RIH with Window Milling BHA,90 fpm. 74.3 7,138.0 18:55 20:43 Tie in at the K1 for a+4.5'correction, Wt ck,37k lbs. Pumps down,close EDC,zero WOB. 12/21/2016 12/21/2016 2.28 PROD1 WHPST WPST P Tag up @ 7138'. pick up 38k lbs,park 7,138.0 7,139.0 20:43 23:00 and increase pumps to drilling rate 1.80 bpm,CT off bottom,4170 psi, diff,512 psi,Stack WOB 2 klbs,759 diff,7137.50' Time milling. 12/21/2016 12/22/2016 1.00 PROD1 WHPST WPST P 1.81 bpm,CT 4228 psi,diff,800 psi, 7,139.0 7,139.9 23:00 00:00 WOB 3.43 k lbs,ROP 0.6 fph, Page 4/17 Report Printed: 1/16/2017 • • Operations Summary (with Timelog Depths) .0: 1H-16 comccehimps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/22/2016 12/22/2016 3.00 PROD1 WHPST WPST P 1.81 bpm,CT 4293 psi,diff,861 psi, 7,139.9 7,142.0 00:00 03:00 WOB 3.89 k lbs,ROP 0.5 fph, 12/22/2016 12/22/2016 1.00 PROD1 WHPST WPST P 1.81 bpm,CT 4123 psi,diff,696 psi, 7,142.0 7,143.0 03:00 04:00 WOB 1.78 k lbs,ROP 0.8 fph 12/22/2016 12/22/2016 3.75 PROD1 WHPST WPST P 1.81 bpm,CT 4033 psi,diff,639 psi, 7,143.0 7,159.0 04:00 07:45 WOB 0.63 k lbs,ROP 2 fph 12/22/2016 12/22/2016 1.00 PROD1 WHPST REAM P At window exit TD of 7,159 ft. Make 7,159.0 7,126.0 07:45 08:45 several reaming passes and a final dry drift through window. Vey smooth dry drift no WOB bobbles. 12/22/2016 12/22/2016 1.94 PROD1 WHPST TRIP P POOH after pumping a 5 x 5 sweep 7,126.0 79.8 08:45 10:41 and chase to surface with and open EDC. PUW=37.5k 12/22/2016 12/22/2016 1.44 PROD1 WHPST PULD P At surface. Conduct Pressure 79.8 79.8 10:41 12:07 Undeploy Operations after PJSM. 12/22/2016 12/22/2016 0.75 PROD1 WHPST PULD P L/D BHA#5 79.8 0.0 12:07 12:52 Note:String Mill and Window Mill 2.79"No-Go 12/22/2016 12/22/2016 1.49 PROD1 DRILL SVRG P Nabors takes their daily 1 hour 0.0 0.0 12:52 14:22 maintenance to install whipchecks on high pressure return hose line and to pressure test the Driller's side PDL 12/22/2016 12/22/2016 0.70 PROD1 DRILL PULD P P/U BHA#6 w/Build Drilling Assembly 0.0 72.9 14:22 15:04 12/22/2016 12/22/2016 1.00 PROD1 DRILL PULD P Pressure Deploy BHA#6 after PJSM. 72.9 72.9 15:04 16:04 12/22/2016 12/22/2016 1.60 PROD1 DRILL TRIP P RIH with open EDC pumping at 1.5 72.9 6,700.0 16:04 17:40 bpm 12/22/2016 12/22/2016 0.30 PROD1 DRILL DLOG P Log for K1 Marker and make 6,700.0 6,800.0 17:40 17:58 correction of+7.5' 12/22/2016 12/22/2016 0.80 PROD1 DRILL TRIP P Swap hole over to new mud,System 6,800.0 7,150.0 17:58 18:46 #1 Close EDc,Wt Ck,41k lbs,RIH 12/22/2016 12/22/2016 2.80 PROD1 DRILL DRLG P Drilling rate, 1.76 bpm,CT 4000 psi, 7,159.0 7,355.0 18:46 21:34 off bottom diff 520 psi. RIH Wt 12.9k lbs,CT Wt 14.6k lbs, WOB 1.3k lbs,ROP 60 OBD.ROP increased from 60 to-120 fph as we cut into A4 pay finioshed TD of build @ 12/22/2016 12/22/2016 1.90 PROD1 DRILL TRIP P TD build section,PUH,Wt 42k lbs. 7,355.0 79.0 21:34 23:28 Drive by, RA tag at 7143.5',six feet below original TOW tag,7137.5'. Park at 6800',open EDC,POOH pumping 1,22 bpm 12/22/2016 12/23/2016 0.53 PROD1 DRILL PULD P At surface.PJSM, PUD BHA#6,build 79.8 79.8 23:28 00:00 drilling assembly,crew change. PJSM,continue PUD. 12/23/2016 12/23/2016 0.70 PROD1 DRILL PULD P Continue PUD BHA#6. 79.8 0.0 00:00 00:42 12/23/2016 12/23/2016 0.70 PROD1 DRILL PULD P L/D BHA#6 0.0 0.0 00:42 01:24 12/23/2016 12/23/2016 0.40 PROD1 DRILL PULD P P/U BHA#7.A lat drilling assembly. 0.0 0.0 01:24 01:48 12/23/2016 12/23/2016 1.40 PROD1 DRILL PULD P PJSM,Pressure Deploy BHA#7 0.0 78.0 01:48 03:12 Page 5/17 Report Printed: 1/16/2017 • • `' Operations Summary (with Timelog Depths) 0 1H-16 ConocoPhillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time.P-T-X Operation (ftKB) End Depth(ftKB) 12/23/2016 12/23/2016 1.20 PROD1 DRILL TRIP P RIH, EDC open,pumping min rate. 78.0 6,700.0 03:12 04:24 12/23/2016 12/23/2016 0.20 PROD1 DRILL DLOG P Tie into K1 for+6'correction,Wt Ck, 6,700.0 6,772.0 04:24 04:36 34k lbs,Close EDC. 12/23/2016 12/23/2016 0.58 PROD1 DRILL TRIP P RIH, 6,772.0 7,355.0 04:36 05:10 12/23/2016 12/23/2016 4.60 PROD1 DRILL DRLG P 1.80 bpm,Off bottom,CT 4392 psi, 7,355.0 7,810.0 05:10 09:46 diff 711 psi, BOBD,CT Wt 12.6 k lbs,WOB 1.11 k lbs,ROP 87 ft/hr Perform numerous BHA wiper trips due to weight transfer issues and to faciliate tool face changes.Average ROP was approximately 112 fph. Encountered Ankerite only briefly. 12/23/2016 12/23/2016 0.68 PROD1 DRILL WPRT P Perform a wiper trip to the window so 7,810.0 6,756.0 09:46 10:27 the K1 and RA can be logged. Average ROP was approx. 112 fph. Encountered Ankerite only briefly. Crossed an unexpected Fault A at 7,758 ft. Geo thinks its a 15 ft down turn 12/23/2016 12/23/2016 0.37 PROD1 DRILL DLOG P RBIH logging the K1 and then the 6,756.0 7,189.0 10:27 10:49 RA correction at K1 was +2.0 ft and the RA came exactly where it should have at 7,744 ft. 12/23/2016 12/23/2016 0.40 PROD1 DRILL TRIP P After logging the K1 and the RA, 7,189.0 7,810.0 10:49 11:13 continue RBIH to bottom. 12/23/2016 12/23/2016 3.76 PROD1 DRILL DRLG P BOBD. 1.80 bpm, CTP 5,026 Diff 7,810.0 8,260.0 11:13 14:59 1,230 CTW 8 klb WOB 2.23 ROP 178 fph IA 649 OA 293 WHP 409 After crossing Fault A we had turned down thinking it was a 15 ft down turn. Instead the fault was a 17 ft Up thrown. Decision made to not chase the pay and instead turn slightly down until crossing Fault 1 at 8,120 ft and he can determine where we are at. 12/23/2016 12/23/2016 0.68 PROD1 DRILL WPRT P Perform a 859 ft wiper trip. Average 8,260.0 8,260.0 14:59 15:40 ROP was around 119 fph. 12/23/2016 12/23/2016 3.33 PROD1 DRILL DRLG P BOBD. 1.80 bpm, CTP 5,232 Diff 8,260.0 8,710.0 15:40 19:00 1,276 CTW 3.1 klb WOB 2.03 ROP 197 fph IA 142 OA 315 WHP 322 12/23/2016 12/23/2016 1.20 PROD1 DRILL WPRT P PUH,wiper to window to tie in. PU Wt 8,692.0 6,751.0 19:00 20:12 43K lbs 12/23/2016 12/23/2016 1.20 PROD1 DRILL DLOG P Tie into K1 for+3.5'correction RBIH 6,751.0 8,692.0 20:12 21:24 Note,Sat down twice at 8545'and 8565'in some areas of high gamma in the A5. 12/23/2016 12/23/2016 1.50 PROD1 DRILL DRLG P Off bottom,RIH Wt 9.6k 1.80 bpm,CT 8,710.0 8,871.0 21:24 22:54 4844 psi,diff 758 psi. BOBD,CT 5014 psi,952 psi diff,Ct Wt 7.4 k lbs,WOB 2.33 k lbs ROP 188 ft/hr 12/23/2016 12/23/2016 1.00 PROD1 DRILL WPRT P Pull Geo wiper trip,jogging from 8900 8,871.0 8,871.0 22:54 23:54 to 8700' PU Wt 47k lb Told to turn down. RBIH Page 6/17 Report Printed: 1/16/2017 `° Operations Summary (with Timelog Depths) 0 1H-16 Conoco1i11ips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/23/2016 12/24/2016 0.10 PROD1 DRILL DRLG P Off bottom,1.80 bpm,CT 4655 psi,diff 8,871.0 8,874.0 23:54 00:00 7605 psi. BOBD,CT 4866 psi,894 psi diff,Ct Wt 7.8 k lbs,WOB 1.78 k lbs ROP 34 fUhr 12/24/2016 12/24/2016 3.00 PROD1 DRILL DRLG P OBD,CT 4889 psi,945 psi diff,Ct Wt 8,874.0 9,190.0 00:00 03:00 6.18 k lbs,WOB 1.38 k lbs ROP 90 ft/hr 12/24/2016 12/24/2016 0.50 PROD1 DRILL WPRT P Pull wiper trip#1 after 500'drilled. PU 9,190.0 8,368.0 03:00 03:30 Wt 40 k lbs. Encountered overpulls to 60k lbs total between 8565-8536, cleaned up area. 12/24/2016 12/24/2016 0.50 PROD1 DRILL WPRT P RBIH,slight weight bobbles @ 8535 8,368.0 9,190.0 03:30 04:00 and 8565' 12/24/2016 12/24/2016 5.10 PROD1 DRILL DRLG P RIH Wt 9 k lbs, Off bottom,@ 1.84 9,190.0 9,651.0 04:00 09:06 bpm,CT 4895 psi,Diff 719 psi OBD,CT 5134 psi, 1000 psi diff,Ct Wt 3.7 k lbs,WOB 1.3 k lbs ROP 150 ft/hr Perform several BHA wiper trips and a 400 ft wiper to facilitate weight transfer 12/24/2016 12/24/2016 0.79 PROD1 DRILL WPRT P Wiper trip#2 after 461 ft drilled. 9,651.0 9,651.0 09:06 09:53 Having weight transfer issues/in the process of swapping to Mud System #2/1,000 ft wiper trip 12/24/2016 12/24/2016 6.30 PROD1 DRILL DRLG P BOBD. 1.80 bpm, CT Press 5,062 9,651.0 10,100.0 09:53 16:11 Diff Press 937 CTW-3.0 WOB 1.78 klb ROP 56 to 119 fpm IA 484 OA 363 12/24/2016 12/24/2016 1.41 PROD1 DRILL WPRT P Perform a wiper trip and log the RA 10,100.0 7,170.0 16:11 17:36 12/24/2016 12/24/2016 0.18 PROD1 DRILL DLOG P Log for the RA and make a correction 7,170.0 7,182.0 17:36 17:46 of+7 ft 12/24/2016 12/24/2016 1.40 PROD1 DRILL TRIP P Continue RBIH to bottom. Weight 7,182.0 10,100.0 17:46 19:10 bobbles from 8365-8585' Sat down ©8656',at the start of the A4 lower silt. 12/24/2016 12/24/2016 1.90 PROD1 DRILL DRLG P Struggled with weight transfer issues. 10,100.0 10,126.0 19:10 21:04 Managed to get drilling at reduced pump rate. OBD, 1.55 bpm,CT 4032 psi,Diff 633 psi,CT wt-1.2 k lbs,WOB 1 k lbs, ROP 20-100 ft/hr Diminishing weight transfers,build and pump 10 bbl lube/bead pill. 12/24/2016 12/24/2016 1.90 PROD1 DRILL DRLG P OBD, 1.2 bbls out the nozzle,surface 10,126.0 10,214.0 21:04 22:58 weight from-7k lbs to neutral,WOB 1.57 ROP 100 ft/hr. Weight transfer issues returned once pill exited annulus at surface.Confer with Geo's,Call TD. 12/24/2016 12/25/2016 1.02 PROD1 DRILL WPRT P Pump 10 x 10 low/high vis pills. 10,214.0 8,865.0 22:58 00:00 Chase sweeps out of hole out of hole 12/25/2016 12/25/2016 1.03 PROD1 DRILL WPRT P Chasing sweeps CT wt 60k lbs and up 10,214.0 6,800.0 00:00 01:01 to-4 k WOB through ratty area,8470- 8565'and 8621'. Lots of silt/sand at the shaker,no rocks. PUH to 6700, RBIH jog to 6800'. Page 7/17 Report Printed: 1/16/2017 • 08 Operations Summary (with Timelog Depths) 0 1H-16 hiliips i�-sky 111 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/25/2016 12/25/2016 1.30 PROD1 DRILL WPRT P Open EDC,Pumps up to bpm, 6,800.0 6,800.0 01:01 02:19 Circulate bottoms up.Lots of sand at the shaker on bottoms up,no rocks. Shut down pumps holding 11.8 ppg equiv at the window,wellhead solid, circ pressure falling. Close EDC 12/25/2016 12/25/2016 0.90 PROD1 DRILL WPRT P RBIH,pumping min rate, one slight 6,800.0 8,850.0 02:19 03:13 WOB bobble @ 8557' Clean hole. 12/25/2016 12/25/2016 2.81 PROD1 DRILL WPRT P POOH wiper to window, 1.5 bpm saw 8,850.0 78.0 03:13 06:02 -10k lbs overpull at 8530,some evidence of minor packing off. Much cleaner. Pull above window,open EDC,POOH. 12/25/2016 12/25/2016 1.36 PROD1 DRILL TRIP P RBIH 78.0 6,700.0 06:02 07:24 12/25/2016 12/25/2016 0.16 PROD1 DRILL DLOG P Tie into K1 for+7.5 ft correction. 6,755.0 6,799.0 07:24 07:33 12/25/2016 12/25/2016 1.37 PROD1 DRILL TRIP P Continue to RIH. Past the bad spot 6,799.0 10,214.0 07:33 08:55 with no weight bobbles. TD confirmed at 10,216.0 ft. 12/25/2016 12/25/2016 1.47 PROD1 DRILL DISP P POOH laying in liner running pill. 10,214.0 6,778.0 08:55 10:24 PUW=43k Pulled up through bad area with no issues or overpulls. Baker called at 8:53 am for noon arrival. Paint yellow EOP flag at 8,738 ft 12/25/2016 12/25/2016 1.40 PROD1 DRILL DISP P Trip out at 112 fpm laying in 11.8 ppg 6,778.0 80.6 10:24 11:48 NaBr KW fluid to surface. Follow 11.8 ppg Trip Schedule. Paint white EOL flag at 5,578 ft 12/25/2016 12/25/2016 0.55 PROD1 DRILL OWFF P At surface.Perform 30 minute No- 80.6 80.6 11:48 12:21 Flow Test. No-Flow Test good. Hold PJSM for laying down BHA#7. 12/25/2016 12/25/2016 0.71 PROD1 DRILL PULD P UD BHA#7 over a dead well. Bit 80.6 0.0 12:21 13:03 Graded at 1 -1 12/25/2016 12/25/2016 0.47 COMPZ1 CASING BOPE P Perform BOPE Test(Function). 0.0 0.0 13:03 13:31 12/25/2016 12/25/2016 0.59 COMPZI CASING PUTB P BOPE Test completed. Prep Rig floor 0.0 0.0 13:31 14:07 for running liner.PJSM. 12/25/2016 12/25/2016 3.00 COMPZ1 CASING PUTB P P/U BHA#8, 1H-16A Lower Lateral 0.0 1,548.7 14:07 17:07 Assembly(49 jts 2 3/8"Slotted Liner, non-ported bullnose,BHA). 12/25/2016 12/25/2016 3.00 COMPZ1 CASING RUNL P RIH with BHA#8.tie into window flag, 1,548.7 10,216.0 17:07 20:07 +1.27'foot correction. Wt Ck,36.7 K lbs. Continue tripping in hole with BHA#8 to TD depth of 10216'. PU 40 k lbs, SD,stack 5 k,pull neutral coil weight, pumps up to 1.5 bpm,CT 4000 psi, PU,CT wt,34k lbs,off liner. down on pumps 12/25/2016 12/25/2016 2.40 COMPZI CASING TRIP P POOH,paint white flag @ 5744.21'. 10,216.0 56.0 20:07 22:31 continue to POOH. 12/25/2016 12/25/2016 0.50 COMPZ1 CASING OWFF P At surface,30 min no flow-good, 56.0 56.0 22:31 23:01 PJSM 12/25/2016 12/25/2016 0.30 COMPZ1 CASING PULD P LD BHA#8, 56.0 0.0 23:01 23:19 Page 8/17 Report Printed: 1/16/2017 : • • >t .., 0 Operations Summary (with Timelog Depths) 1H-16 conocdii iliips �o-:Rxg Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/25/2016 12/26/2016 0.68 COMPZ1 CASING PUTB P Prepar rig floor for running liner. 0.0 1,265.5 23:19 00:00 PJSM, Pick up middle section of A lat, 2 slotted,30 blank,and 10 slotted joints of 2 3/8",4.6#,L-80,ST-L liner hung off a shorty deployment sleeve. 12/26/2016 12/26/2016 3.30 COMPZ1 CASING PUTB P Run middle section of A lat,2 slotted, 0.0 1,265.5 00:00 03:18 30 blank,and 10 slotted joints of 2 3/8",4.6#,L-80,ST-L liner hung off a shorty deployment sleeve. Total length 1265.47. Call well control drill, 4:15 time to simulate S/I. AAR to discuss+/-'s. Lay down safety joint. MU BHA#9,stab on. 12/26/2016 12/26/2016 2.30 COMPZ1 CASING RUNL P RIH W BHA#9,middle section,"A"lat, 1,309.7 8,709.0 03:18 05:36 2 joints slotted,30 solid,and 10 slotted,2 3/8",4.6#,L-80,ST-L.. Tie into painted flag 5701,for no correction. Wt Ct 39 k lbs,@ 8709', S/D,release off liner. 12/26/2016 12/26/2016 1.71 COMPZ1 CASING TRIP P POOH, 8,708.0 48.2 05:36 07:18 12/26/2016 12/26/2016 0.55 COMPZ1 CASING OWFF P At surface,30 min no flow-good, 48.2 48.2 07:18 07:51 PJSM 12/26/2016 12/26/2016 0.55 COMPZ1 CASING PULD P LD BHA#9 48.2 0.0 07:51 08:24 12/26/2016 12/26/2016 0.76 PROD2 STK PULD P Run upper A lat,open hole anchor, 1 0.0 104.5 08:24 09:10 joint slotted,2 3/8",4.6#, L-80,ST-L liner hung off an aluminum liner top billet. Total length 42.95'. MU BHA #10,stab on. 12/26/2016 12/26/2016 2.11 PROD2 STK TRIP P RIH with BHA#10.tie into window 104.5 7,446.5 09:10 11:16 flag,+6.5 foot correction. Wt Ck,34 K lbs. Close EDC Continue tripping in hole with BHA#9 to TOL tag depth of 7,446.5 ft. PU 38 k lbs at 5 fpm as the HOT is malfunctioning at the DD.MWD tries unsuccessfully to set the anchor oreintation at 340 degrees ROHS(20 LOHS), 12/26/2016 12/26/2016 1.49 PROD2 STK TRIP T POOH to replace HOT. 7,446.5 104.5 11:16 12:46 12/26/2016 12/26/2016 0.55 PROD2 STK OWFF T At surface,30 min no flow-good, 104.5 104.5 12:46 13:19 PJSM 12/26/2016 12/26/2016 0.71 PROD2 STK PULD T LD BHA#10 and remove 104.5 0.0 13:19 14:01 malfunctioning HOT 12/26/2016 12/26/2016 0.50 PROD2 STK PULD T P/U BHA#11 with new working HOT. 0.0 104.5 14:01 14:31 Page 9/17 Report Printed: 1/16/2017 • 411 ' Operations Summary (with Timelog Depths) 0 ex 1H-16 C€�noco hiti®ps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/26/2016 12/26/2016 1.94 PROD2 STK TRIP T RIH with BHA#11.tie into window 104.5 7,446.5 14:31 16:28 flag,+5.5 ft correction. Wt Ck,34 K lbs. Close EDC Continue tripping in hole with BHA#11 to TOL tag depth of 7,446.5 ft. PU 38.5 k lbs Set back down and then pull up to neutral weight bring pump online and pressure breaks over at 2,700 psi....set down 6k PUH....puw=38k anchor oreintation at 340 degrees ROHS(20 LOHS), 12/26/2016 12/26/2016 1.63 PROD2 STK TRIP P POOH 7,403.6 62.7 16:28 18:06 12/26/2016 12/26/2016 0.55 PROD2 STK OWFF P At surface,30 min no flow-good, 62.7 62.7 18:06 18:39 PJSM 12/26/2016 12/26/2016 0.60 PROD2 STK PULD P UD BHA#11. 62.7 0.0 18:39 19:15 12/26/2016 12/26/2016 1.24 PROD2 STK PULD P Replace UQC/Rehead as UQC was 0.0 0.0 19:15 20:29 houred out. Note:Tested at 210 megs / 61 ohms. Packoffs checked- Good condition 12/26/2016 12/26/2016 1.00 PROD2 STK PULD P P/U BHA#12 with Weatherford 0.7° 0.0 74.8 20:29 21:29 Motor and 2.70"x 3.0" HCC Bi-Center Bit after PJSM. WFT Motor SN# 22505,Bi-Center Bit SN#7041613 12/26/2016 12/26/2016 1.30 PROD2 STK TRIP P RIH with closed EDC pumping at 74.8 6,795.0 21:29 22:47 minimum rate 12/26/2016 12/26/2016 0.30 PROD2 STK DLOG P Log for K1 Marker and make 6,700.0 6,795.0 22:47 23:05 correction of+5'ft, 12/26/2016 12/27/2016 0.91 PROD2 STK DISP P Open EDC,Circulate KWF out with 6,795.0 6,795.0 23:05 00:00 8.6 drilling fluid. 12/27/2016 12/27/2016 0.60 PROD2 STK TRIP P EDC closed and continue RIH to TOL 6,795.0 7,403.0 00:00 00:36 12/27/2016 12/27/2016 0.70 PROD2 STK TRIP P Down on pump,RIH,dry tag top of 7,403.0 7,403.0 00:36 01:18 billet at 7,403 ft. PUW=36k.. PUH, slip chains,lots of geese on chains, Inspect area,one old relatively deep gouge,Pressure wash blocks as we slowly POOH,RBIH and re tag to verify counter,ok. PU and set drilling rate,RBIH 12/27/2016 12/27/2016 0.10 PROD2 STK TRIP P Set drilling rate off bottom, 1.73 bpm, 7,403.0 7,403.0 01:18 01:24 CT 4700 psi,diff 722 psi,zero WOB RBIH RIH Wt 13.9k. 12/27/2016 12/27/2016 3.10 PROD2 STK KOST P Time mill on billet. 1.72 bpm 7,403.0 7,460.0 01:24 04:30 CT 4791 psi,CT Wt 15.9 k lbs,Diff 976 psi,WOB 0.32 k lbs, 1ft@ 1 ft/hr, 1 ft @ 2 ft/hr,2 ft @ 5-6 ft/hr,2ft@8-10ft/hr,2ft@15'ft/hr, 2 ft @ 20'ft/hr,drilling ahead,WOB 1k lbs,ROP 136 ft/hr. 12/27/2016 12/27/2016 0.20 PROD2 STK KOST P PU,Wt 38k lbs, PUH,min rate,clean 7,460.0 7,460.0 04:30 04:42 drift, RBIH 10 ft/min,pumps off,clean dry drift. 12/27/2016 12/27/2016 1.80 PROD2 DRILL DRLG P Kicked off billet at 7,408 ft. Drilling 7,460.0 7,736.6 04:42 06:30 ahead in AL1 Lateral as per plan. Off bottom, 1.75 bpm,CT 4559 psi, diff 872 psi, RIH Wt 13.5 k lbs OBD,CT 5389 psi,diff 1500 psi,CT 11,WOB 1.6,ROP 200 ft/hr Page 10/17 Report Printed: 1/16/2017 • 0 0 Operations Summary (with Timelog Depths) 1H-16 CcwtocoPlt,illips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time. Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/27/2016 12/27/2016 1.00 PROD2 DRILL RGRP T While picking up to perform BHA 7,460.0 6,811.0 06:30 07:30 wiper,encountered difficulty with the injector. Trouble shoot issue,suspect a bad encoder,motors not balancing torque. PUH into casing to repair/ replace. Open EDC,pump 2 bpm for 1 hr,reduce to min rate. Discover motor#2(towards storge reel),love joy connection(lower coupler)from AC VDF to input of right angel drive slid down and slipped a key. Parts sourced and repairs implemented. Counting 1st hr of troubleshooting against daily rig maint. 12/27/2016 12/27/2016 7.60 PROD2 DRILL RGRP T Repair injector. 7,460.0 6,811.0 07:30 15:06 12/27/2016 12/27/2016 0.40 PROD2 DRILL RGRP T Button up injector drives. Move pipe, 6,811.0 7,736.0 15:06 15:30 all good. Close EDC.test motor©1 bpm-good. RIH inspecting pipe. Tie- in to RA tag,no correction. 12/27/2016 12/27/2016 3.00 PROD2 DRILL DRLG P Off bottom, 1.80 bpm,CT 4820 psi, 7,736.0 8,190.0 15:30 18:30 diff 828 psi,RIH Wt 13.k lbs OBD,CT 5178 psi,diff 1179 psi,CT 10.5,WOB 1.5,ROP 132 ft/hr 12/27/2016 12/27/2016 1.10 PROD2 DRILL WPRT P Wiper trip#1,40K PUW,to 7340', 8,190.0 8,190.0 18:30 19:36 RBIH to drill,establish off bottom rate 1.8 bpm,CT 4870 psi,WH 262 psi,dP 836 psi, 11K RIH Wt,41K PUW 12/27/2016 12/27/2016 3.80 PROD2 DRILL DRLG P Drill at 1.8 bpm,CT 5480 psi,WH 115 8,190.0 8,622.0 19:36 23:24 psi,4215 psi diff on bottom,BHA wiper at 8350',48K PUW,sticky,BHA wiper 8608',weight transfer. 12/27/2016 12/28/2016 0.60 PROD2 DRILL WPRT P Wiper trip#2 early due to weight 8,622.0 8,622.0 23:24 00:00 transfer,40K PUW,to 7775',RBIH to drill 12/28/2016 12/28/2016 2.00 PROD2 DRILL DRLG P Drilling ahead,crossed fault at 8610', 8,622.0 8,675.0 00:00 02:00 wrap around gamma,almost all clay at shaker. Drill ahead with caution taking frequent PUW,TF oriented to highside. 12/28/2016 12/28/2016 6.60 PROD2 DRILL DRLG P Drill ahead taking frequent PUW,38K 8,675.0 8,882.0 02:00 08:36 to 42K. Got a PUW of 46K,pulled 100 ft wiper,on bottom parameters, 1.80 bpm,CT weight between+2K after pick-ups dropping off to-5K lbs,CT 5072 psi,WH 265 psi,930 psi diff 12/28/2016 12/28/2016 0.20 PROD2 DRILL WPRT P Pull short wiper over trouble spot, 8,882.0 8,553.0 08:36 08:48 WOB-4k lbs @ 8679',motor work. 12/28/2016 12/28/2016 0.30 PROD2 DRILL WPRT P RBIH S/D 8686' work through,46k 8,553.0 8,882.0 08:48 09:06 PU Wt 12/28/2016 12/28/2016 4.10 PROD2 DRILL DRLG P OBD, 1.70 bpm,CT 5024 psi,Diff 940 8,882.0 9,130.0 09:06 13:12 psi,CT Wt,negative 2-5k lbs,WOB 1.5 k lbs. ROP 100-20 ft/hr pump 5 x 5 sweeps Page 11/17 Report Printed: 1/16/2017 i • `0 Operations Summary (with Timelog Depths) tdt O 1H-16 Conoco hitiips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/28/2016 12/28/2016 1.30 PROD2 DRILL WPRT P PU Wt 42 k lbs,Long wiper for tie in. 9,130.0 7,167.0 13:12 14:30 10-30k overpulls 8750-8615'. Work through area. Jog above build section,CT wt went from 50k to 41 k. Lots of silt and clay at the shaker some shale chips, 1/4"-3/8". 12/28/2016 12/28/2016 0.40 PROD2 DRILL DLOG P Tie into whipstock RA tag for a+7.5' 7,167.0 7,187.0 14:30 14:54 correction. Seeing CT wt go from—40 to—50 k at 7168',suspect solids. 12/28/2016 12/28/2016 2.20 PROD2 DRILL WPRT P Struggle to get diff pressure below 50 7,130.0 7,650.0 14:54 17:06 psi,Open EDC, Rate to 2.16 bpm,circ bottoms up. Steady stream of rocks at the shaker, 1/2"to 3/4"minus,Geo says A5/A6 from near the window. A couple flat sheets of metal in returns, some magnetic some not. Pump 5x5 sweep. Large amount of silt and pea gravel at the shaker as the low vis landed,larger rocks but less as the high vis landed. Continue to PUH, send another 5 x 5 sweep. A small number of rocks back but mostly clean. CT Wt back to 31 k lbs. 12/28/2016 12/28/2016 2.30 PROD2 DRILL WPRT P RBIH,close EDC.sat down at 8651' 7,130.0 9,130.0 17:06 19:24 and 8761',lower pump rate and worked thru with minimal issue,hole trying to pack off,send 5 bbls Hi vis sweep and reciprocate pipe from 9120 to 9015'until sweep reaches bit. 12/28/2016 12/29/2016 4.60 PROD2 DRILL DRLG P OBD, 1.4 bpm,CT 4438 psi,diff 860 9,130.0 9,381.0 19:24 00:00 psi,1.8K WOB,0.5K to negative 2-5K, increase drilling rate to 1.6 bpm,hole packing off and have difficulty getting WOB,lower rate back to 1.45 bpm, prep to swap mud to system 3 w/1% Lo Torq and 1%776. ROP 40 to 120 ft/hr. New mud at bit at 9299'@ 22:30 pm. 12/29/2016 12/29/2016 0.20 PROD2 DRILL DRLG P Short BHA wiper to 9280',PUW 42K, 9,381.0 9,381.0 00:00 00:12 12/29/2016 12/29/2016 0.60 PROD2 DRILL DRVE P OBD,4.4K CW,CT 4535 psi,932 psi 9,381.0 9,417.0 00:12 00:48 diff,1.4K WOB,80 ft/hr ROP, 12/29/2016 12/29/2016 0.30 PROD2 DRILL WPRT P Slow Geo wiper,found top of A4 pay, 9,417.0 9,417.0 00:48 01:06 turn TF down to get to 88° 12/29/2016 12/29/2016 2.50 PROD2 DRILL DRLG P OBD,4K CW, 1.52 bpm,CT 4654 psi, 9,417.0 9,580.0 01:06 03:36 900 psi dif on bottom, 1.5K WOB,30 to 60 ROP 12/29/2016 12/29/2016 0.30 PROD2 DRILL WPRT P Wiper trip#4,PUW 38K,50FPM, 1.55 9,580.0 8,780.0 03:36 03:54 bpm,CT 4453 psi,651 psi diff,pull heavy at 8780',42K 12/29/2016 12/29/2016 1.20 PROD2 DRILL WPRT P Turn around,RIH,SD several places, 8,780.0 9,580.0 03:54 05:06 PUW 46k to 60k,packing off,work through tight areas 8780'to 8930', pump 5x5 Lo/Hi vis sweep,RIH, stacking weight taking turn arounds, hole conditions marginal,reciprocate to clean hole better at 1.50 bpm Page 12/17 Report Printed: 1/16/2017 ,, Operations Summary (with Timelog Depths) .,... , : ,miiik, • •00 0 1H-16 ConocoPhiilkps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr). Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 12/29/2016 12/29/2016 1.40 PROD2 DRILL DRLG P BOBD, 1.51 bpm,CT 4463 psi,CT Wt 9,580.0 9,636.0 05:06 06:30 0.3 k lbs,WOB 1.1 k lbs,ROP 75 ft/hr. fragile weight transfer. 12/29/2016 12/29/2016 1.50 PROD2 DRILL WPRT P Lose wt transfer and struggle to get 9,636.0 7,958.0 06:30 08:00 started with a couple BHA wipers and variable pump rate. Decide to PUH, clean up trouble spots. CT wt up to 70k from 8764-8660. RBIH,send 5x5.large amount of solids returned at the screen,mostly pea gravel and silt/sand,some larger 3/4"minus flakes. 12/29/2016 12/29/2016 1.00 PROD2 DRILL WPRT P Continue to PUH,CT weight 39k lbs, 7,958.0 7,100.0 08:00 09:00 second 5x5 sweep landed at the shaker,lots of solids in the to vis, heavy silt sand and pea gravel, 1/16" to 1/4". Next to nothing in the high vis. CT Wt 38-36k. Hole looks to be fairly clean.last 5x5 did surface some solids but the amount was greatly diminished,CT wt 38k. 12/29/2016 12/29/2016 1.00 PROD2 DRILL DLOG P Tie into the WS RA tag fora+7' 7,100.0 7,182.0 09:00 10:00 correction. 12/29/2016 12/29/2016 0.30 PROD2 DRILL WPRT P Continue to RIH,RIH Wt 13k,two very 7,182.0 9,638.0 10:00 10:18 slight weight bobbles at 8712'S/D 7k and 9394'S/D 2 k 12/29/2016 12/29/2016 0.20 PROD2 DRILL DRLG P Off bottom, 1.51 bpm,CT 4200 psi,diff 9,638.0 9,641.0 10:18 10:30 570 psi, OBD, CT Wt 5 k lbs,WOB 1.5 k lbs, ROP 90 ft/hr.Great weight transfer. Town called TD early,change of plans. 12/29/2016 12/29/2016 3.00 PROD2 STK TRIP T POOH for open hole anchored billet. 9,641.0 77.0 10:30 13:30 Pump 5x5 sweeps,timed to exit nozzle @ 8100'. Pumps to min rate as the coil passed through 8700 to 8600'. Open EDC in tbg,continue to POOH. Sweeps returned all fines,silt and sand.Jog near surface. 12/29/2016 12/29/2016 2.20 PROD2 STK PULD T PJSM,PUD BHA#12.and laydown 77.0 0.0 13:30 15:42 12/29/2016 12/29/2016 0.90 PROD2 STK PULD T PJSM,PU and PD BHA#13,AL1 0.0 72.0 15:42 16:36 open hole anchored billet. While deploying had pressure above closed 2-3/8"pipe/slip rams,attempt to bleed off,pressure builds back to WH. 12/29/2016 12/29/2016 0.70 PROD2 STK PULD T PJSM to discuss plan forward,decide 72.0 0.0 16:36 17:18 to PUD and inspect FVS sub,if float valves are holding,PU and run test joint and test 2-3/8"pipe/slip rams. 12/29/2016 12/29/2016 1.40 PROD2 STK PULD T PUD BHA#13,checked FVS sub, 0.0 0.0 17:18 18:42 checks appear to be holding. MU and deploy test joint,closed lower 2-3/8" rams,pressure up below against closed swabs to 900 psi,rams are holding. Broke apart FVS to fully inspect check valves. Both checks are stuck open with fine grit/shale. Bled off 900 psi,LD test joint. Page 13/17 Report Printed: 1/16/2017 • • 0 Operations Summary (with Timelog Depths) WI 1 H-16 ConocdPhilllps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code. Time P-T-X Operation (ftKB) End Depth(ftKB) 12/29/2016 12/29/2016 0.90 PROD2 STK PULD T PJSM,clean and clear rig floor,re- 0.0 73.0 18:42 19:36 deploy BHA#14(swapped FVS with a different sub). Off trouble time at 19:30 pm(3.0 hours of trouble time) 12/29/2016 12/29/2016 0.80 PROD2 STK PULD T Continue with deploying BHA#14. 73.0 19:36 20:24 12/29/2016 12/29/2016 1.90 PROD2 STK TRIP T Trip in with BHA#14 Baker OH anchor 73.0 6,750.0 20:24 22:18 billet,minimum rate 12/29/2016 12/29/2016 0.20 PROD2 STK DLOG T Tie-in to K1,+7 ft correction 6,750.0 6,770.0 22:18 22:30 12/29/2016 12/29/2016 0.80 PROD2 STK TRIP T Get PUW 33.5K,close EDC,RIH at 6,770.0 8,111.6 22:30 23:18 30 FPM until past whipstock and window,speed up to 40 FPM in OH, 12K to 14K RIH Wt, Get PUW 38K, Get on depth,PU 33K,orient top slip at 0°HS,Online 1 bpm, sheared at 4800 psi,SO 4K WOB,good set,pick was clean 12/29/2016 12/30/2016 0.70 PROD2 STK TRIP T POOH,stop at 6785,open EDC, 8,111.6 6,120.0 23:18 00:00 continue OOH 12/30/2016 12/30/2016 1.00 PROD2 STK TRIP T Continue to POOH. 6,120.0 73.0 00:00 01:00 12/30/2016 12/30/2016 1.70 PROD2 STK PULD T At surface,bump up,space out,hold 73.0 0.0 01:00 02:42 PJSM,PUD BHA#14 Baker#10 setting tool. LD BHA#14 12/30/2016 12/30/2016 2.00 PROD2 STK PULD T PU BHA#15 w/Weatherford 0.65° 0.0 74.8 02:42 04:42 AKO motor, HYC 3.0"bi-center bit, PJSM,PD BHA#15. Pull upper checks,inspect,checks looks good, went ahead and replaced. Inspect stripper/pack-offs,PO's were worn, replaced them 12/30/2016 12/30/2016 1.30 PROD2 STK TRIP T RIH w/EDC open 74.8 6,710.0 04:42 06:00 12/30/2016 12/30/2016 0.90 PROD2 STK DLOG T Tie into the K1 for+16'correction, 7,100.0 8,101.0 06:00 06:54 Inspect both injector and storage reel counters and clean same, Close EDC,continue to RIH,log RA tag toverify counters,zero correction. RIH 12/30/2016 12/30/2016 0.40 PROD2 STK KOST T dry tag TOB @ 8101'. PU 36k lbs, 8,101.0 8,101.0 06:54 07:18 RBIH Set drilling rate 1.80 bpm off bottom, CT 5140 psi,diff 909 psi,Zero WOB 12/30/2016 12/30/2016 2.00 PROD2 STK KOST T Tag,stall once,PUH,RBIH,stack 8,101.0 8,110.0 07:18 09:18 weight 8100.4 1 ft/hr for 1' 2 ft/hr for 1' 3'ft/hr for 1' then target 1 k WOB. 12/30/2016 12/30/2016 0.50 PROD2 DRILL DRLG T Drilling rat hole 8,110.0 8,140.0 09:18 09:48 12/30/2016 12/30/2016 0.20 PROD2 DRILL WPRT T PU,RBIH,dry drift,clean,RIH 8,140.0 8,140.0 09:48 10:00 12/30/2016 12/30/2016 1.30 PROD2 DRILL DRLG T off bottom, 1.79 bpm,CT 4900 psi, 8,140.0 8,311.0 10:00 11:18 diff,840 psi, OBD,Ct 5500, Dif, 1696 psi,CT Wt, 12 k lbs,WOB1.9k lbs, 202 ft/hr.pull 2 short DD wiper,PU Wt,37k 12/30/2016 12/30/2016 0.10 PROD2 DRILL WPRT T Drilled into some hard stuff,pull BHA 8,311.0 8,233.0 11:18 11:24 wiper Page 14/17 Report Printed: 1/16/2017 K 0Operations Summary (with Timelog Depths) 1H-16 Coro lisps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End.Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/30/2016 12/30/2016 0.10 PROD2 DRILL WPRT T RBIH 8,233.0 8,311.0 11:24 11:30 12/30/2016 12/30/2016 2.00 PROD2 DRILL DRLG T BOBD,Ct 5017, Dif, 1517 psi,CT Wt, 8,311.0 8,600.0 11:30 13:30 11 k lbs,WOB 1.7k, 150-200 ft/hr. Pump 10x10 sweeps,42k lbs 12/30/2016 12/30/2016 1.90 PROD2 DRILL WPRT P Long TD wiper to swab 8,600.0 78.0 13:30 15:24 12/30/2016 12/30/2016 1.60 PROD2 DRILL TRIP P RBIH 78.0 6,000.0 15:24 17:00 12/30/2016 12/30/2016 0.70 PROD2 DRILL TRIP T Field wide Phase 3, 6,000.0 6,000.0 17:00 17:42 12/30/2016 12/30/2016 0.50 PROD2 DRILL DLOG P Tie into K1 for+6.5'correction,Close 6,000.0 6,000.0 17:42 18:12 EDC, 12/30/2016 12/30/2016 0.50 PROD2 DRILL TRIP P RIH,stop to check pressure at window 6,000.0 7,077.0 18:12 18:42 7077'(6407'TVD),crew change,after 30 min,annular pressure was 3685 psi,11.1 ppg EMW 12/30/2016 12/30/2016 0.80 PROD2 DRILL TRIP P Sat down 2X at 7040'(bottom of 7,077.0 8,601.0 18:42 19:30 window). Picked up 3rd time,rolled pump,down on pump,run in clean past window,continue RIH.Tag at 8601'. 12/30/2016 12/30/2016 1.70 PROD2 DRILL DISP P POOH,lay in liner pill and displace to 8,601.0 78.0 19:30 21:12 11.8 ppg NaBr,paint yellow TD flag at 6780', EOP depth,paint white Window Flag at 5200'EOP depth,continue POOH 12/30/2016 12/30/2016 0.50 PROD2 DRILL OWFF P At surface,4 bbl loss laying in KWF, 78.0 78.0 21:12 21:42 perform 30 min flow check. 12/30/2016 12/30/2016 1.90 PROD2 DRILL PULD P PJSM,laydown BHA#15 over dead 78.0 0.0 21:42 23:36 well,insppect coil,observered a deep gouge approx 17 ft up from coil connector. 12/30/2016 12/31/2016 0.40 COMPZ2 CASING PUTB P Prep floor for running liner 0.0 0.0 23:36 00:00 12/31/2016 12/31/2016 2.90 COMPZ2 CASING PUTB P PJSM,PU and run 58 jnts,2-3/8" 0.0 1,767.6 00:00 02:54 slotted liner with solid bullnose. Performed well control drill while running liner,3 min 20 sec response time to install safety joint. 12/31/2016 12/31/2016 1.00 COMPZ2 CASING PULD P Clean&clear rig floor,PJSM,MU liner 1,767.6 1,811.8 02:54 03:54 running BHA#16,deploy over dead well 12/31/2016 12/31/2016 2.00 COMPZ2 CASING RUNL P Trip in, EDC closed,Blacked out rig, 1,811.8 8,601.0 03:54 05:54 sub and service mod for 6 minutes, Started generator while on shore power,high idle caused the load sharing to kick off shore power. Tie into window flag for+2.66' correction. Set down,PU,and had to work pipe through 8304,8340,and 8367'near A4-A5 silt intertface. 12/31/2016 12/31/2016 0.20 COMPZ2 CASING RUNL P Tag bottom,PU Wt 44-55k,SD,pump 8,601.0 8,592.0 05:54 06:06 off,PU 32k lbs,down on pumps, Page 15/17 Report Printed: 1/16/2017 0 • 0.7 Operations Summary (with Timelog Depths) ex 1 H-16 Conoillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/31/2016 12/31/2016 1.30 COMPZ2 CASING DISP P Adjust depths for 1767.64'of liner left 6,824.4 6,774.0 06:06 07:24 in hole,complete seawater transfer, line up to seawater and displace coil to seawater,PUH,open EDC. 12/31/2016 12/31/2016 1.10 COMPZ2 CASING DISP P POOH displacing 11.8 ppg KW fluid 6,774.0 2,563.0 07:24 08:30 with seawater. 12/31/2016 12/31/2016 1.40 COMPZ2 CASING DISP P Pump 30 bbls diesel FP&contin to 2,563.0 45.0 08:30 09:54 POOH 12/31/2016 12/31/2016 1.00 COMPZ2 CASING PULD P Bump up, PJSM,PUD,BHA#16,AL1 45.0 0.0 09:54 10:54 liner running assembly. 12/31/2016 12/31/2016 0.50 COMPZ2 CASING PULD P LD BHA#16 0.0 0.0 10:54 11:24 12/31/2016 12/31/2016 2.10 DEMOB WHDBOP RURD P Rig up nozzle and jet stack,pop of 0.0 0.0 11:24 13:30 and position reel,remove pressure bulkhead and cap.call out N2. 12/31/2016 12/31/2016 2.30 DEMOB WHDBOP MPSP P PJSM, Rig up Central shops lubricator 0.0 0.0 13:30 15:48 and set BPV,(Note:trapped 1000 psi under BPV)PJSM,w SLB,rig up N2 to customer valve. 12/31/2016 12/31/2016 1.00 DEMOB WHDBOP CTOP P PJSM,Blow down reel for reel swap 0.0 0.0 15:48 16:48 prior to moving from 1H-16,cool down N2 unit, PT 4000 psi,Pump 1500 scf for 15 min, 12/31/2016 12/31/2016 4.50 DEMOB WHDBOP CTOP P PJSM,LOTO reel,cut off coil 0.0 0.0 16:48 21:18 connector,rig up grapple,sheeve,tie- downs,pull test grapple to 900 psi, prep to unstab coil. 12/31/2016 1/1/2017 2.70 DEMOB WHDBOP CTOP P PJSM,unstabe pipe and secure to 0.0 0.0 21:18 00:00 storage reel. Remove saddle clamps, PEAK on location at 23:40 1/1/2017 1/1/2017 1.50 DEMOB WHDBOP CTOP P Rigged down inner reel iron,removed 0.0 0.0 00:00 01:30 saddle clamps,rigging installed,reel hoisted 1/1/2017 1/1/2017 4.00 DEMOB WHDBOP CTOP P Had to remove hub from the old reel 0.0 0.0 01:30 05:30 (driller side)and swap with hub on new reel. New reel sent over with wrong size hub. 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP CTOP P Completed loading the old storage 0.0 0.0 05:30 06:30 reel onto Peak truck 1/1/2017 1/1/2017 1.40 DEMOB WHDBOP CTOP P Hub installed on new storage reel, 0.0 0.0 06:30 07:54 MS1801400965N 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP CTOP P Set storage reel in place,shim and 0.0 0.0 07:54 08:54 tighten pillow block bolts. 1/1/2017 1/1/2017 2.00 DEMOB WHDBOP CTOP P Install inner reel iron,and bulkhead 0.0 0.0 08:54 10:54 Off High line and on rig power at 10:00 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP CTOP P Stab stripper,prep to pull/stab CT 0.0 0.0 10:54 11:54 1/1/2017 1/1/2017 4.00 DEMOB WHDBOP CTOP P install internal grapple,pull test,stab 0.0 0.0 11:54 15:54 coil 1/1/2017 1/1/2017 2.10 DEMOB WHDBOP CTOP P Install 2"coil connector,install horses 0.0 0.0 15:54 18:00 head. 1/1/2017 1/1/2017 1.50 DEMOB WHDBOP NUND P Blow down lines,suck out stack,pour 0.0 0.0 18:00 19:30 5 gal MEOH to tree. Pull test coil connector to 35K 1/1/2017 1/1/2017 1.00 DEMOB WHDBOP DMOB P Install and test Eline UQC,RD lines in 0.0 0.0 19:30 20:30 PUTZ,lost gen power to rig sub briefly at 20:05 Page 16/17 Report Printed: 1/16/2017 ® • Operations Summary (with Timelog Depths) W 1H-16 ConocoPhillips ir aa� Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/1/2017 1/2/2017 3.50 DEMOB WHDBOP NUND P Finish RD of lines in PUTZ,ND pick 0.0 0.0 20:30 00:00 BOP stack,install tree cap "'Rig Release @ Midnight"` Page 17/17 Report Printed: 1/16/2017 • • 1H-16 Proposed CTD Schematic Modified by RLP 1/3/2017 3-1/2"TRDP-4A SSSV at 1793'MD (includes 2.813"X-profile) 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 16"62#H-40 3-1/2"Camco KBUG gas lift mandrels at 2498',3930',4634', shoe at 121'MD 5337',6071',&6426' - 3-1/2"Camco MMG gas lift mandrel at 6755' 9-5/8"40#L-80 shoe at 2672'MD Baker GBH-22 Locator Seal Assembly at 6803'MD Baker FB-1 packer 6805'MD Otix XN landing nipple 6828'MD (2.80"min ID) 3-1/2"tubing tail at 6840'MD C-sand perfs(sgz'd) 6914'-6974'MD 7013'-7033'MD KOP©7138'MD —WV5,� 1H-16AL1 wp02,West TD et 8601'MD ALiner Top at 6833'MD A-sand perfs(sqz'd) H-InAL1P81 TD 7218'-7243'MD at 8641'MD Binet 8100'MD 1H-16Awp01,North 7"26#J-55 shoe at TD at 10040'MD 7485'MD Liner Binet at 7500'MD G-. • • o i (11 V v to w c9 w �..., :. 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Co O N ` cc . �s w V1 ro ��tlcc r CO M N CO cm — — 0 CO CO 0 M o 0 0 0 0 o v w Pe (Wj..;°it.. 0 0 lL lL LL LL cm -.-,. 00 00 H H F- I- Co O 0 0 0 00 0 0 0 0 0 0 c CC1 osu o o o o o O C 0 0 0 0 0 0 00 or NvNNNo •N I Nco vi o r!) M M M t-- 0 O N a- M O0U N _ N N N N N N .. _0 I� ` C) C) C) 0) 0) 0) a1 O +. N N N N N N 'L. G1 O O O O O O U az C.. c )() IC) )() uin y) Cr) ) S E v C wan u W` cc ` O CU yj rl Q co C CD D O N ++ V) i e ? b eo „}, z c ,_ o O T +� L oc v1 1� 03 a d a p N N r") _ E z w ra _ N �G W y .0 'w' 'i C ^ • Cl 6 OC/� � Qg Cl_` F. '-,< ID • tiOF 771, THE STATE Alaska Oil and Gas F ,,;,.—s � OfA LASKA Conservation Commission 1-11t 333 West Seventh Avenue _ _ Anchorage,GOVERNOR BILL WALKER g e, Alaska 99501-3572 R.__==, 0' Main: 907.279.1433 F ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Gary Eller CTD Team Lead SCANNED MA,' 0 `° 7'; ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-16 Permit to Drill Number: 192-131 Sundry Number: 316-509 Dear Mr. Eller: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this ely of October, 2016. RBDMS C OCT 1 0 2016 • • R_ECEIVED L 03 016 STATE OF ALASKA /o1C f( ALASKA OIL AND GAS CONSERVATION COMMISSION AOG C APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well LI Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program LI Plug for Redd! 1:I. Perforate New Pool ❑ Re-enter Susp Well LI Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Q. 192-131 I 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510 50-029-22315 -Ob"'CA 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A - l KRU 1H-16 , Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 25639 ALK 464 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): ' Plugs(MD): Junk(MD): 7510' % 6908' * 7398' . 6813' 3785 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A N/A N/A Conductor 121' 16"62.5# 121' 121' 1640 psi 630 psi Surface 2672' 9-5/8"40# 2672' 2672' 5750 psi 3090 psi Intermediate N/A N/A N/A N/A N/A N/A Production 7485' 7"26# 7485' 6887' 4980 psi 4320 psi Liner N/A N/A N/A N/A N/A N/A Perforation Depth MD(ft): ?14) Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): GI II 6 '-7243' 6404'-6681' 3-1/2"9.3# J-55 6841' Packers and SSSV Type: SSSV:Camco TRDP-4A Safety Valve Packers and SSSV MD(ft)and TVD(ft): SSSV:1793'MD&1793'ND Packer:Baker FB-1 Permanent ' Packer: 6805'MD&6312'TVD 12.Attachments: Proposal Summary Q Wellbore schematic ❑r 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development QY Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1211/201C- \Q(5[\CD Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑., 16.Verbal Approval: Date: GAS LI WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ElOp Shutdown ❑ Abandoned LI 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact TOOv. \X'c-\/...I Printed Name G-a v'y E1 2r Email ,\p g.5,1\,g.5,1\ \O . urK2�o Coe.C o we l \ Title C-Tc�Tq-a'"" \-Kt J Zb3-4\72 I l3oI 1b Signature �\ Phone Date ) COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I Scct Plug Integrity ❑ BOP Test Mechanical Integrity Test ID Location Clearance El lJ Other: /C) 4t UO 75 t v�P firvi,v1 e , �r �fir� ��r�5 to 2 5av Psl 4 .moi l trr-n a�r p 5 p l a c z- v�r�� app eV 1) f r 6 Art-C z 5-, r z L l�- Post Initial Injection MIT Req'd? Yes ❑ No ❑ r U Spacing Exception Required? Yes ❑ No 0/ Subsequent Form Required: `a APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:l0,G _4(:,ro� /4. ,(4t%Q bfr7 to/ / Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ORIGINAL RBDMS OCT 1 0 7016 KRU 1H-16 CTD Summary for Plugging Sundry (10-403 Summary of Operations: KRU well 1H-16 is a Kuparuk A-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A4 sand to the north and west of the 1H-16. The laterals will improve production in the 1 H-16. Prior to CTD operations the nipple at 6828' RKB will be milled out and the existing A-sand perforations will be squeezed with cement, the 3-1/2" tubing tail will be punched and cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A-sand perforations in this manner. Following the cement squeeze, Nabors CDR2-AC or CDR3-AC will drill a pilot hole to 7180' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 7150' MD. All the laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3-1/2" tubing tail. Using the maximum formation pressure in the area of 4442 psi in 1H-19, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3785 psi. Based on this the BOPE will be tested to 4000 psi. CTD Drill and Complete 1H-16 Laterals: November 2016 Pre-CTD Work 1. RU Slickline: Dummy off gas lift mandrels; perform MITIA and obtain a SBHP 2. RU Pumping: Swap hole over to diesel and perform injectivity test 3. RU E-line: Punch tubing tail at 6825' MD. Using WelITec milling system mill the nipple out to 2.80" at 6828' MD 4. RU Service Coil: Lay in cement plug and squeeze off the A-sand perforations. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for CTD rig and set BPV. Rig Work 1. MIRU Nabors CDR2-AC or CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1H-16A Sidetrack(A4 sand - North) a. Drill 2.80" high-side pilot hole through cement to 7180' MD b. Caliper pilot hole c. Set top of whip-stock at 7150' MD d. Mill 2.80"window at 7150' MD. e. Drill 3" bi-center lateral to TD of 10040' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 7500' MD. 3. 1 H-16AL1 Lateral (A4 sand -West) a. Kick off of the aluminum billet at 7500' MD. b. Drill 3" bi-center lateral to TD of 10500' MD. c. Run 2%" slotted liner with a deployment sleeve from TD up to 6820' MD. 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production 6e Co„,ktee( OA 7'4 Sonet/ /s eci ick r n7o Pr°pied (atergf w/ l�S ��,� (A/,if COr//II .e To Ca/freer il' e�✓�1 eio'•5 wp(f6ore So rile well 113 Ccarentf colkci/1,�� TherPt`+'c 7 ^d /PSA"v-1e"'e,,, Page 1 of 1 9/30/2016 • • 1H-16 Proposed Plugging Schematic Modified by JAB 9-27-16 3-1/2"TRDP-4A SSSV at 1793'MD IN 41 (includes 2.813"X-profile) 3-1/2"9.3#J-55 EUE 8rd Tubing to surface 3-1/2"Camco KBUG gas lift mandrels at 2498',3930', 16"62#H-4011= 4634',5337',6071',&6426' shoe at 121'MD - -ry 3-1/2"Camco MMG gas lift mandrel at 6755' 9-5/8"40#L-80 shoe .* at 2672'MD Baker GBH-22 Locator Seal Assembly at 6803'MD Baker FB-1 packer 6805'MD OtixXN landing nipple 6828'MD (2.75"min ID,will be drilled out to 2.80"ID) ++` 3-1/2"tubing tail at 6840'MD C-sand perfs(sqz'd) 6914'-6974'MD 7013'-7033'MD A-sand perfs(sqz'd) 7218'-7243'MD 7"26#J-55 shoe at 7485'MD KUP D 1H-16 ' Con©coPhillipsOP. Well Attribut Max Angle D TD Alaska,IrIc Wellbore APVUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c )ptp, 500292231500 KUPARUK RIVER UNIT PROD35.02 5,383.10 7,510.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 11416,10/3/201611:42:02 AM SSSV:TRDP 125 12/18/2013 Last WO: 1/10/1993 Vertical schernabp(swap Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .:- _... Last Tag:SLM 7,192.0 4/19/2015 Rev Reason:MANDREL ORIENTATION hipshkf 6/9/2015 i ,rte HANGER;37.6 i CO I Casing Strings E' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I' CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-00 WELDED � 1 Casing Description OD(in) ID(in) Top)ftKB) 'Set Depth(ftKB) Set Depth(ND)...'WtlLen(I...Grade Top Thread : I ,, SURFACE 95/8 8.835 40.3 2,671.9 2,671.0 40.00 L-80 BTC if '.., : f Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 39.3 7,485.4 6,886.9 26.00 J-55 ABMOD Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...WI(Ib/ft) Grade Top Connection TUBING 31/2 2.992 37.6 6,840.9 6,342.8 9.30 J-55 ABM-EUE ,1 -.Completion Details CONDUCTOR 41.0-121.0 l - Nominal ID ( Top(ftKB) Top(ND))ftKB) Top Incl(') Item Des Com (in) 37.6 37.6 0.09 HANGER FMC GEN IV HANGER 3.500 it 1,793.2 1,793.1 • 1.00 SAFETY VLV CAMCO TRDP-4A SAFETY VALVE 2.812 SAFETY VLV;1,793.2 11 .C.. 6,802.6 6,310.6 32.99 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 6,804.9 6,312.5 32.98 PACKER BAKER FB-1 PERMANENT PACKER(1.5 SPACE OUT 3.000 ABOVE PKR) 6,828.4 6,332.2 32.86 NIPPLE OTIS XN NIPPLE NO GO 2.750 GAS LIFT,2,498.3 - 6,840.0 6,342.0 32.80 SOS BAKER SHEAR OUT SUB 3.015 Perforations&Slots Shot Den Top)TVD) Btm(ND) (shots/ Top)ftKB) Btm(f0(B) (ftKB) )ftKB) Zone Date ft) Type Corn • 6,914.0' 6,974.0 6,404.2 6,454.6 UNIT D,C-4, 11/20/1993 4.0 APERF 180deg Phasing;50 deg C-3,1H-16 CCW Orientation;2.5" SURFACE;40.3-2,671.9 Titan Guns 7,013.0 7,033.0 6,487.4 6,504.2 C-1,1H-16 10/13/1993 4.0 APERF 180 deg Phasing;86 deg CCW Orientation;2.5" GAS LIFT;3,9301 Titan Guns 7,218.0 7,243.0 6,660.3 6,681.4 A-4,1H-16 6/13/1993 4.0 IPERF 180 deg Phasing;1 deg CCW oriented;4.5"SWS Mandrel Inserts GAS LIFT;4,633.5 t_ St I ati Top(TVD) Valve Latch Port Size TRO Run Ion N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GAS LIFT 5,337.1 1 2,498.3 2,498.0 CAMCO KBUG 1 GAS LIFT GLV BTM 0.156 1,226.0 5/21/2015 2:00 2 3,930.1 3,889.6 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,272.0 5/21/2015 5:30 , 3 4,633.5 4,499.5 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 5/21/2015 5:30 GAS LIFT;6071.1 4 5,337.1 5,095.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/21/2015 2:00 5 6,071.1 5,702.1 CAMCO KBUG - 1 GAS LIFT DMY BTM 0.000 0.0 5/21/2015 8:00 6 6,425.9 5,998.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/21/2015 EXT GAS LIFT;8,425.9 PKG 9:00 7 6,754.8 6,270.5 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/21/2010 1:00 Notes:General&Safety End Date Annotation GAS LIFT;6,754.6 I `�� 9/24/2010 NOTE View Schematic w/Alaska Schematic9.0 • II } :, SEAL ASSY;6,802.6 1.•1-1•.e, PACKER,8,804.9 NIPPLE;6,828.4 fr505;6,840.0 APERF;6,914.0-6,9740 APERF;7,013.0-7,033.0----+ IPERF;7,218.0-7,243.0-� PRODUCTION;39.3-7,485.4 • • Ina) �� ;` M 3 ' , 2M03 ,tf — 3o(0 o co [�iN , ,, t 0 M ¢:F o❑o _Q : a) V in CO _ f �� ,e. MIS in co , _ -O CO N N- N CO i, m 4- co .fl O , F-J'a ❑ 0T2 E ,, o N J ,‘GM Q ❑ q �� ,,,o) m n E Q , - E ❑ 0 ,• 'O N N co c "6 '‘ t• i 6 Q co co Cn,fl co N O i`. c,. CO->k W m oco N-0 co `' Cno— W co Co D mNV oY E 3 m ``, ii. c0 J 1.N L Y o?$ 0 N N Cn- s 1 CL N -3 o-- o N Q a.0 0) �, U 0 U M E O E m m 12 E 9 'ssi �. I- c rn 0 c 0 CD L ziiir2 .E p Nom'.' N NM N YY X`N-' N ,/-1 ,, r co r (6 (0 r O . M M Ci)co M CO CO 0 M pN` t, V a 0 / 7:1_,:„ .....-:-.....,,,r1 m co 1 i ..:.'. CI U 'a u) IY , l o o a) Q 1 s _ o O I N -o _O N L op N N LO d cr � ❑ J p N❑0 v❑ O tO _ N r .1f CV tviM `CM co in - N- �N.co 0 - N Mt W.co Q,o)O 0. - •at T... *f9 to N12 CO N- -o N. N- f— (NO N 6) N 00'd'M co W N CO 0 6 co P Q N- N • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or V/ "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial / then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. 410 c�2 MAY 06 2016 WELL LOG TRANSMITTAL# 4,0GCC To: Alaska Oil and Gas Conservation Comm. April 27, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 MSK`6END4 ER RE: Static Bottom Hole Pressure Record: 1H-16 Run Date: 2/18/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22315-00 Static Bottom Hole Pressure Record (Field Print) 1 Color Log 50-029-22315-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett $ MNEP 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 25g1S WELL LOG TRANSMITTAL DATA LOGGED 'lig/201 M.K BEND F To: Alaska Oil and Gas Conservation Comm. June 17, 2015 Attn.: Makana Bender M ;� l 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 JUN 19 21i1;, RE: Production Profile &Multi-Finger Caliper: 1H-16 Run Date: 6/4/15 - 6/5/15 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1H-16 Digital Data(LAS), Digital Log files, Interpretation Reports, 3D Viewers 1 CD Rom 50-029-22315-00 Production Profile Log SCANt4E .`i t 2[m: 1 Color Log 50-029-22315-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: D / 6.ekreet 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. //¢.~-~//Fi la Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type OVERSIZED · n Logs-of various kinds . n Other COMMENTS: Scanned by: Beverly Dian~an Lowell Date:'~~ [] TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si • ConocoPhillips aas~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 12, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: DECEIVED FED 1 6 2010 A~8gk8 pit & 6a3 Celts. Commission Anchorage (1~-tlv 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 corrosion inhibitor/sealant was pumped February 9~' &10~`, 2010. 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. ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Pad 1 H. 1 J& 1 R Well Name API # 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 ff al 1 H-15 50029223280000 1930030 23" n/a 23" n/a 4.2 2/9/2010 1 H-16 50029223150000 1921310 25" n/a 25" n/a 4.8 2/9/2010 1 H-19 50029223120000 1921280 22" n/a 22" n/a 4 2/10/2010 1 H-20 50029223130000 1921290 25" n/a 25" n/a 4.6 2/10/2010 1 H-22 50029223640000 1930600 22" n/a 22" n/a 4.2 2/9/2010 1H-105 50029207270100 2042280 3" n/a 3" n/a 3.4 2/9/2010 1J-180 50029233290000 2061500 18" n/a 18" n/a 3.8 2/9/2010 1J-182 50029233210000 2061320 17.5" n/a 17.5" n/a 3.6 2/9/2010 1 R-21 50029222110000 1911130 24" n/a 24" n/a 4.6 2/9/2010 A ~~c~~mb~t~g Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # c~ ~t y,JL i Log Description / \ ' ! ~ r 1 j ' / / .- A _ ~~ ~~ NO. 5005 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE (- f 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE q '~ 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL _ / _ -" 11/28/08 1 1 30-01 12097434 LDL ~Q ~ 11/29/08 1 1 1E-04 12097436 LDL 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE l - 11/27/08 1 1 i H-16 12096581 PRODUCTION PROFILE ~ - 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE C - f 12/02/08 1 1 iG-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE - 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE ~-+ 12/08/08 1 1 iJ-102 12086701 INJECTION PROFILE - 12/14/08 1 1 i D-07 12114999 USIT _ ~ 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE ~ 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE 12/17/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumbepgep Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# RECEl\JEO ~l n>~(1n~ ',1 './ (, LUUU lJ.2:$t3 ~ '~-mm~"--n (~':;as ~ÜS.. ¡...'\J ~ .'. JXr·::ra;a ") 06/02/06 NO. 3831 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 F;old, Kup",uk \ q ~- \ ~ \ e .~c-· ~ 1\,J"Jf=t, 'v .r~J .:,'~""'- Log Description Date BL Color CD 1Y-12 l-=t~-,~,·~~. 11235362 INJECTION PROFILE OS/20/06 1 1 L-06 ì 'ffl../- r ~ 11213748 PRODUCTION PROFILE WIDEFT 05/19/06 1 1 Q-24 } C;.ç- -ItJ i 11213849 INJECTION PROFILE OS/20/06 1 1 H-04 /1.f;:) -1 ,""; ~ 11213752 INJECTION PROFILE OS/23/06 1 1 H-08 )~':1- ~.c¡: 11213751 RSTIWFL OS/22/06 1 2Z-02 1'7<3 - ~"X(: 11235362 INJECTION PROFILE OS/28/06 1 ~-L~t 11235365 PRODUCTION PROFILE W/DEFT OS/24/06 1 2A-T15'Ÿ - (.."'5< 11213755 CROSSFLOW DETERMINATION OS/26/06 1 31-10 ¡ 'is -1'::\1 11213759 PRODUCTION PROFILE W/DEFT 05/30/06 1 1 H-19 ,oCJ ;:)- J;:J7, 11320975 INJECTION PROFILE OS/29/06 1 2A-13 ¡~~- - 1'/4 11320976 LDL 05/30/06 1 2Z-04 i*3 -c:~ 11213757 INJECTION PROFILE OS/28/06 1 2Z-12A I q,~- - N~ 1123568? GLS OS/27/06 1 3F-02 i 4(:~-,::).q~ 11213758 PRODUCTION PROFILE W/DEFT OS/29/06 1 C_ it -- e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. THE MATERIAI, UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE DECEMBER 01, 2000 E PL W M ATE IA L U N D ER T H IS M A R K E R PERMIT 92-131 92-131 92-131 92-131 92-131 AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS 5567 LT/'2581-7519 CDR/CDN/ENHANCE 407 ~d~/COMP DATE :06-13-93 · DWOP ~t~ 01/07-06/13/93 SURVEY [~ 0.00-7510 GCT SCHLUM. SURVEY ~ 0.00-7510 GCT SCHLUM. 92-131 CBT ~A-~ 5090-7373 1 CDN/PAR/DN/GR ~2671-7510 DEPTH CORRECT / , CDR VERY ENHANCE~i~ 7052-7320 DEPTH CORRECT CDR VERY ENHNCED'~L'/6948-7480 DEPTH CORRECT CDR/PAR/DN/GR g~/2671-7510 DEPTH CORRECT CET ~.~ L 5090-7382 1 92-131 92-131 92-131 92-131 92-131 Page' 1 Date' 04/11/95 RUN DATE_RECVD 04/02/1993 07/15/1993 07/15/1993 03/09/1993 07/15/1993 03/15/1993 1 05/14/1993 1 08/30/1993 1 09/14/1993 1 05/14/1993 03/15/1993 Are dry ditch samples required? t~2~ description received? Was the well cored? yes/ no/ Analysis & Are well tests required? yes ~'~n~°~ Received?~es_ ~. no Well is in compliance ~ I COMMENTS yes no PERMIT DATA 92-131 5567 92-131 407 92-131 DWOP 92-131 SURVEY 92-131 SURVEY .OGCC Individual Well Geological Materials Inventory T DATA_PLUS T 2581-7519 CDR/CDN/ENHANCE 1 R COMP DATE:06-13-93 R 01/07-06/13/93 R 0.00-7510 GCT SCHLUM. R 0.00-7510 GCT SCHLUM. 92-131 CBT L 5090-7373 1 CDN/PAR/DN/GR L 2671-7510 DEPTH CORRECT 1 CDR VERY ENHANCE L 7052-7320 DEPTH CORRECT 1 CDR VERY ENHNCED L 6948-7480 DEPTH CORRECT 1 92-131 L 2671-7510 DEPTH CORRECT 1 L 5090-7382 1 92-131 92-131 92-131 CDR/PAR/DN/GR 92-131 CET Page- 1 Date' 01/10/95 RUN DATE_RECVD 04/02/93 07/15/93 07/15/93 03/09/93 07/15/93 03/15/93 05/14/93 08/30/93 09/14/93 05114/93 03/15/93 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial COMMENTS yes no yes no ARCO Alaska, Inc. ~-'~--. Post Office ,. , 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 12, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. John!ston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION Stimulate Perforate Perforate Stimulate Perforate (C3,4) Perforate (C1) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer' Kuparuk Petroleum Engineering CE/v[D ARCO Alaska, Inc. is a Subsidiary o! AtlanticRIchfieldCompany STATE OF ALASKA ALAUr,,~ OIL AND GAS CONSERVATION COMMI~,S,.. 5N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging_ Perforate X Pull tubing __ Alter casing Repair well Other 2. Name of Operator ARCO Alaska, lng. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 671' FNL, 1156' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1225' FSL, 1150' FEL, Sec. 28, T12N, At effective depth 1490' FSL, 1140' FEL, Sec. 28, T12N, At total depth 1549' FSL, 1140' FEL, Sec. 28, T12N, 12. Present well condition summary Total Depth: measured true vertical R10E, UM R10E, UM R10E, UM 7 5 1 0 feet 6 9 0 8 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1H-16 9. Permit number/approval number 92-1;~1 10. APl number 5o-029-22~15 11. Field/Pool Kuparuk River Oil Field/Pool NoRe Effective depth: measured 7398 true vertical 6813 feet feet Junk (measured) None Casing Length Structural Conductor 78' Surface 2 6 3 0' Intermediate Production 7444' Liner Perforation depth: measured 6914'-6974' true vertical 6404'-6454' Size 16" 9.625" 7" Cemented Measured depth True vertical depth 200 Sx CS I 1 2 1' 570 Sx PF "E" & 2672' 190 Sx Class G w/150 Sx PFC Top Job 590 Sx Class G 7483' , 7013'-7033', 7218'-7243' , 6487'-6504', 6660'-6682' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6840' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 6804'; SSSV: Camco TRDP-4A @ 1793' 78' 2671' 6885' RECEIVED 13. Stimulation or cement squeeze summary Perforated "C3,4" sands on 11/19-20/93 @ 4 spf. Intervals treated (measured) 6914'-6974' Treatment description including volumes used and final pressure N/A ;v ._:kr: 0it & 6as Cons. C0rr~miss! Anch0ragr~ 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Press~Jre Prior to well operation Subsequent to operation 9O3 972 0 50 285 902 ~- 540 0 0 290 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. Si,ned ¢~'~* ~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. 0 Subsidiary of Atlantic Richfield Company WELL 1H-16 DATE 11/19/93 DAY 1 DESCRIPTION OF WORK PERFORATE C34 CONTRACTOR ! KEY PERSON SCHLUMBERGER/JACK RATHERT PBTD (RKB)]LAS~ TAG (RKB) - DATE 7398 110- 11/11/93 FIELD COST EST. $7,804 SSSV TYPE / STATUS CAMCO TRDP 4-A KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# - SCA# [ 997633 IACCUMULATED COST ! $7,804 TIME LOG ENTRY 0800 MIRU SCHLUMBERGER, SAFETY MEETING, PRESSURE TEST TO 3000. PUMP 30 BBLS 1030 RIH W/1 11/16" TOOL STRING, HEAD, 6' WT. BAR, COL, MPD, 20' 2,5" TITAN 4 SPF, 180 DEGREE PHASING, ALTERNATING BH (DOWN) AND DP (UP), ORIENTED 50 DEGREES COW. 4.5' FROM COL TO TOP SHOT 1115 TIE IN TO CBL DATED 1/31/93. OPEN WELL, FLAG LINE AT 7100', CHECK TIE IN, PULL UP TO 7949.5' W/COL, SHOOT 6954' TO 6974', SHUT IN WELL, HUNG UP IN D NIPPLE AT 6780', PULL BINDS UP TO 2700 PSI AND HELD, WOULDN'T COME FREE, PULL OFF AT 2900 PSI (1700 OVER TS). POOH RIG DOWN SUMMARY': PERFORATED C34 FROM 6954' TO 6974' WITH 4 SPF. HUNG UP IN D NIPPLE POOH. LEFT 33.8' TOOL STRING IN D NIPPLE. 40' LEFT TO PERFORATE CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather ]Temp. Report Chill FacWr Visibility miles] Wind Vel. ISigned COMPLETE INCOMPLETE ~oxt~ ~ttolltn~smorth ARCO Alaska, Inc. O Subsidiary of Atlantic Richfield Company WELL 1H-16 DATE 11/20/93 DAY 2 TIME 0715 0930 1010 1100 1220 1255 1345 1430 DESCRIFrION OF WORK PERFORATE C34 CONTRACTOR / KEY PERSON SCHLUMBERGER/JACK RATHERT PBTD (RKB)ILAS~ TAG (RKB) - DATE 7398 146 - 11/19/93 LOG ENTRY HELD COST EST. $8,300 SSSV TYPE / STATUS .CAMCO TRDP 4-A KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# - SCA# 997633 ACCUMULATED COST $17,048 ON LOCATION, SAFETY MEETING, MIRU scHLUMBERGER, PRESSURE TEST TO 3000. RIH W/1 11/16" TOOL STRING, HEAD, 6' WT. BAR, CCL, MPD, 20' 2.5" TITAN 4 SPF, 180 DEGREE PHASING, ALTERNATING BH (DOWN) AND DP (UP), ORIENTED 50 DEGREES CCW. 4.5' FROM CCL TO TOP SHOT TIE IN TO CBL 1/31/93, OPEN WELL, CHECK TIE IN, PULL UP TO 6929.5' W/CCL SHOOT 6934' TO 6954', SHUT IN WELL, HUNG UP IN D NIPPLE AT 6780', PULL BINDS UP TO 2875 PSI, CAME FREE, POOH OOH, ALL SHOTS FIRED, TIE NEW HEAD RIH W/20' SAME TYPE GUN, SAME ORIENTATION CHECK TIE IN, OPEN WELL, CHECK TIE IN AGAIN, PULL UP TO 6909.5' W/CCL SHOOT 6914' TO 6934', SHUT IN WELL, POOH, SAW INCREASE IN WEIGHT THROUGH D NIPPLE BUT DID NOT HANG UP OOH, ALL SHOTS FIRED RDMO SUMMARY: PERFORATED C34 FROM 6914' TO 6954' WITH 4 SPF Gas Cons. Commission arlcP, ora¢r: CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK i miles Wind Vel' ISignedmph] COMPLETE INCOMPLETE 9~oxte ~iolll~sn, orth STATE OF ALASKA ALAS~,A OIL AND GAS CONSERVATION COMMIS,.,,,.)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging ~ Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Ira;. Exploratory _ RKB 96 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 671' FNL, 1156' FEL, Sec. 33, T12N, R10E, UM .,~-.-~'~ 1H-16 At top of productive interval ~ /'.. ,. , '~''~ 9. Permit number/approval number 1225' FSL, 1150' FEL, Sec. 28, T12N, R10E, UM ~'//'"/"~ 92-131 / (,~ i¢~"/ 10. APl number At effective depth '-/,,//.!/ 5 o-029 22~1 ~; 1490' FSL, 1140' FEL, Sec. 28, T12N, R10E, UM '". - At total depth ,- '_ 11. Field/Pool 1549' FSL, 1140' FEL, Sec. 28, T12N, R10E, UM "-'-" Kuparuk River Oil Field/Pool 12. Present well condition summary Total Depth: measured 751 0 feet Plugs (measured) None true vertical 6908 feet Effective depth: measured 7 3 9 8 feet Junk (measured) None true vertical 681 3 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 7 8' 1 6" 200 Sx CS I 1 21' 7 8' Surface 2630' 9.625" 570 Sx PF "E" & 2672' 2671' Intermediate 190 Sx Class G w/150 Sx PFC Top Job Production 7444' 7" 590 Sx Class G 7483' 6885' Liner Perforation depth: measured 6914'-6974', 7013'-7033', 7218'-7243' true vertical 6404'-6454' 6487'-6504', 6660'-6682' ' ECEIVED Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6840' Packers and SSSV (type and measured depth) ,,.i /~!~ ["l PKR: Baker FB-1 @ 6804'; SSSV' Camco TRDP-4A @ 1793' :. 13. Stimulation or cement squeeze summary 17' 0ii 6,, L-iaS 60rls, C0l]'~r~issi0n Fracture stimulation of "C1,3,4" sands on 12/3/93. /;,nch0ra~ Intervals treated (measured) 6914'-6974', 7013'-7033' Treatment description including volumes used and final pressure Pumped 166 Mlbs of 12/18 and 16/20 ceramic proppant into form., fp was 6520 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 902 540 0 1250 290 . Subsequent to operation 2 0 0 4 ~¢ 1605 84 1250 246 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations X Oil Z Gas Suspended ~ Service 17. I hereby/~rtify that the foregoing is true and correct to the best of my knowledge. Si~lnedt~'~~ t~. //~~ Title Senior Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICA-rE ~""- FRAC 1 STIMULATION ~LIMMAR' WELL NO: _L~- :~ _ AFC: qc~'/~ PROCEDURE DATE: ~_J2~_q~ -- -- SERVICE CO: "~, ~ , __. PSI ANNULUS PRESS: ~ ~/~ _ PERFS: [~C~IL~- [oC:l"/~ _ STAGE VOL FLUID PROP CoNC. pRoP sIzE RATE IS?M) PRESSURE It ,, " ,' " ~, ~ , ,; ,; ,, ~ F., ~,~ m m i i_ -_ _m J m m m ---- i i i i i I ISIP: PSI __ FLUID ¥O RECOVER: / D~ _ -- SAND IN ZONE: / ~)~. ~::3t") _ =., ITEMIZED COST: FLOC: ROUSTABOUTS; , DIESE~ 15 MIN. PSI AVG, PRESS: .. _ _ BBL JOB COMPLETE: ~ ~] H~5 ..... LB SAND IN CASING: ~,, f/o/~. ~F~ HOT OIL SERVI~CE;' ,~.- ~o~'~¢;~ _ TRUCKING: . ,. · -/~r4/~ _ SUPERVISION: PSi R~ ~0P~RV~SOR RECEIVED Oil & Gas Cons. Commission ' Anchorag, ARCO Alaska, Inc. Post Office £ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 27, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 31--~¢15 1A-13 Perforate q'~-o~ 1 H-02 Perforate 1 H- 1 6 Stimulate ~'i5~ 1 H-16 Perforate S-~-l~'~ 1L-05 Perforate %,~.-~:~ 1 Y- 14 Other If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Aiask~t 0il & 6as Gens. 6omCss~°° Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISo~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address Stimulate X Plugging Repair well P. O. Box 100360, Anchorage, AK 99510 5, Type of Well: Development .._X. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 671' FNL, 1156' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1225' FSL, 1150' FEL, Sec. 28, T12N, R10E, UM At effective depth 1490' FSL, 1140' FEL, Sec. 28, T12N, R10E, UM At total depth 1549' FSL, 1140' FEL, Sec. 28, T12N, R10E, UM 12.Present well condition summary Total Depth: measured 7 5 1 0 feet true vertical 6908 feet Perforate ~~ Other "~') ~ J 6. Datum elevation (DF or KB) RKB 9§ meu-' 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-16 9. Permit number/approval number 92-131 10. APl number 50-029-22315 11, Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) NOlle Effective depth: measured 7 3 9 8 feet true vertical 6813 feet Junk (measured) NOne Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 78' 16" 2630' 9.625" 7444' 7" measured 7218'-7243' true vertical 6660'-6682' Cemented Measured depth True vertical depth 200 Sx CS I 121' 570 Sx PF "E" & 2672' 190 Sx Class G w/150 Sx PFC Top Job 590 Sx Class G 7483' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6840' Packers and SSSV (type and measured depth) PKR: Baker FB-1 @ 6804'; SSSV: Camco TRDP-4A @ 1793' 13. Stimulation or cement squeeze summary Fractured "A" sands on 9/4/93. Intervals treated (measured) 7218'-7243' Treatment description including volumes used and final pressure 14. 78' 2671' 6885' q CT 2 g 1;99 Aiask~, Oil & Gas Cons. Anchorage Pumped 222 Mlbs of 16/20 and 12/18 ceramic proppant into form., fp was 5224 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 182 114 0 450 120 Subsequent to operation 902 571 9 650 408 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'~~~)" ~['~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date /~)-~.7'" ~'-~' SUBMIT IN DUPLICATE KUi RUK STIMULATION SUMM, _i[ WELL: SERVICE CO: HOLE ANGLE @ PERFS: DATE: ARCO REPS: AFE #: We tt PERFORATED INTERVAL: ~ ORIENTATION COM M ENTS/OTH ER FRICTION CORRELATIONS: RATE (PSI/F-I' vs, BPM) 3~ XLGW GW SLK WTR SLK DSL TVD TOP PEF~; G/.~O MD TOP PERF; 7?_. [~ MDTBGTAIL ~8, q [ MDTBG~; HZ FORMATION FRAC GRADIENT; FFIAC FLUID O. ~5" o. qqz /?, 2._7 PRE-TREATMENT CALCULATIONS a. ~35 (~'~,~,[~ ~.u,~c:, o. :~' G g~ t EXPECTED TR~NG PRESSURE = (FORM F~C GRAD X ~D TOP PER~ + ~G FRIC X MD ~G TAIL) -(~UID~X~~P~= ~//1~ ~ ~,'~'~ ~USH VOLUME = (MD ~G TAIL- MD ~G HGR) X ~G BBLS~ + (MD TOP PERF- MD ~G TAIL) X (~ ~-(~ ~D~~ = PRESSURE ANALYSIS ACTUAL FRAC GRADIE~ = ISIP / ~D TOP PERF + F~C ~UID G~DIE~ ~CESS FRIC~ON = ~- ISlP - ~ FRIC X MD ~ T~L) FWHTP ISIP FG XS FRIC 53¢'(¢, 2¢0.0 ,7 9' / oo 3 542? 23o7 ,7°/. /o~O · 77 /n '7 F EFFECTA/E PAD; CLOSURE PRESS 50 5o g a/z], B u 3?4(o 2-.5~7 ,7~ 5594 24o~f TREATMENT ~UMMARY EFFECTIVE SLURRY; PROP PUMPED: PPA@ PERFS: I~ 16,'20~ 12/18¢4) I ~ 31 10/14 PROP IN WE:_~ ~ BORE: S' ~ 2. 4- SEA WATER USED: 1 5 4(~ DIESEL USED: i/,'1 bb/"' STATE OF ALASKA AI_Abc, A OIL AND GAS CONSERVATION COMMI,5o~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate ~ Plugging ~ Perforate x Pull tubing Alter casing Repair well Other feet 2. Name of Operator ARCO Alaska, Inc. 3, Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 671' FNL, 1156' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1225' FSL, 1150' FEL, Sec. 28, T12N, R10E, UM At effective depth 1490' FSL, 1140' FEL, Sec. 28, T12N, R10E, UM At total depth 1549' FSL, 1140' FEL, Sec. 28, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 7 5 1 0 feet true vertical 6908 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-16 9. Permit number/approval number 92-131 10. APl number 50-029-22315 11, Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth' measured 7398 feet true vertical 6813 feet Junk (measured) None Casing Length Size Structural Conductor 7 8' 1 6" Surface 2 6 3 0' 9.62 5" Intermediate Production 7444' 7" Liner Perforation depth: measured 7013'-7033', true vertical 6487'-6504', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J~55 @ 6840' Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 200 Sx CS I 121' 570 Sx PF "E" & 2672' 190 Sx Class G w/150 Sx PFC Top Job 590 Sx Class G 7483' 78' 2671' 6885' 7218'-7243' 6660'-6682' PKR: Baker FB-1 @ 6804'; SSSV: Camco TRDP-4A @ 1793' 13. Stimulation or cement squeeze summary Perforated "C1" sands on 10/13/93. Intervals treated (measured) 7013'-7033' Treatment description including volumes used and final pressure N/A Oil & Gas Cons. Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 902 571 9 2111/' 1295 0 650 408 75O 275 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "~~J' ~~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. O" Subsidiary of Atlantic Richfield Company WELL DESCRIPTION OF WORK 1 H- 16 Perforate C 1 sands DATE 10/13/93 DAY 1 TI31E 0645 0815 0955 1045 CONTRACTOR/KEY PERSON Schlumberger / Johnson PBTD (RKB)ILAS~ TAG (RKB). DATE 7398' 168' - 10/2/93 LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT AFC/CC# - SCA# 997633 - 80223 I FIELD COST EST. ACCUMULATED COST $7,605 $7,605 SSSV TYPE / STATUS CAMCO TRDP-4A / In service RU. Held safety meeting. PT'd to 3(X)0g. NU with 1.375" RS, 18" CCL, 22" x 1.68" magnet, 2.5" X 20' Titan gun. Gun loaded with 4 spf, 180° phasing, alternating BH/DP charges. Gun is oriented to 86° CCW from the high side, BH charges down. 4' from CCL to top shot. IH. Tie in with CET. Tag fill at 7204' rkb. Log up thru jewelry to 6680' rkb. Drop down to 7100' and open well to production. Check tie in and pull up to 7009' CCL (7013' top shot. Perforate 7013' to 7033' rkb. SI well and POOH. Gun hung up in XN nipple. Worked free and continued OOH. All shots fired. RDMO. · Summary: Perforated 'C1' sands at 4 spf, 180° phasing with 2.5" titan guns. Alternated BH/DP charges oriented to 86" CCW from the top, BH charges down. Perforated from 7013' - 7033' rkb. Logged jewelry up to bottom mandrel Tagged fill at 7204' rkb. BH charges: .45" hole w/11gr, charge. 6.85" ave. penetr. DP charges: .36" hole w/11 gr. charge. 8.43" ave. penetr. KUh'Ai-idk PE i-~OLEUM E~Gi~EER~a ',~ :,"3 ¢' 'Cb~-~ ~ ,~ _it.~i .,~ ~I' ~" Anchorage CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK ~e~rt' I 28°F O/C ma~ mphI COMPLETE ,7. estrada INCOMPLETE ARCO Alaska, Inc. Date' September 10, 1993 Transmittal #' 8863 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. 1H-.16 CDR Very-Enhanced 3-02-93 LWD/Depth Corrected Receipt Acknowledged: Please acknowledge 6948-7480~ '5" ~ Date' DISTRIBI, JTION' D&M Drilling Catherine Worley(Geology) NSK :?State of Alaska (+Sepia).' :~,. ..... ARCO Alaska, Inc. Date: August 27, 1993 Transmittal #: 8845 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 · Transmitted below are the following items receipt and return one signed copy of this transmittal. Please acknowledge 1 H-15 -"CDR Enhancement 2-27-93 LWD/Depth Corrected 1H-17 -~CDR Very Enhanced 2-26-93 LWD/Depth Corrected "CDR Very Enhanced LWD/Depth Corrected -- CDR Enhancement LWD/Depth Corrected J CDR Enhancement LWD/Depth Corrected .-- CDR Enhancement LWD/Depth Corrected ---CDR Enhancement LWD/Depth Corrected .~ CDR Enhancement LWD/Depth Corrected --' CDR Enhancement LWD/Depth Corrected Receipt Acknowledged: DISTRIBUTION: D&M Drilling 5-02-93 1-21-93 1-12-93 3-26-93 4-05-93 4-12-93 4-14-93 Date: 9678-10337 7848-8422 7052-7320 9568-9802 8398-8993 7988-8632 4392-7512 5960-9772 5296-10002 Catherine Worley(Geology) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Servic~Ne?l _ OIL ~] GAS r~ SUSPENDED r'~ ABANDONED [~ SERVICE [~] /'~C"~, . 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 92-131 3 Addre~ 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22315 4 Location of well at sudace 9 Unit or Lease Name 671' FNL, 1156' FEL, SEC 33, T 12N, R 10E, UM ~-~0~'~'~ :~' KUPARUK RIVER At Top Producing lnte~al ~ ~ ~?i'~/ ~ ~-~~ 10 WellNumber 154~' FSk, 1140' FEk, S~G 28, T 12~, B ~ 0E, UM .... ~-~ ~ KUPA~UK 5 ~levation in loet (indicate KB, DF, etc.) ~ ~ koase Desi~naUon an0 Serial ~o. BKB ~', ~AD 54' Gk~ ADk 25~3~ AkK 4~4 ~2 Date Spu0~od ~3 Data T.D. Boach~d 14 ~ato Gomp., Susp. or A~an0. ~ ~5 Wator Dop~, ff o~shoro 1~ ~o. ol Completions 07-dan-~3 10-dan-~3 0~/13/~3 (Comp)[ ~A ~eet ~Sk 17 Total Depth (MD+TVD) 18 ~lu~ Back Dopth (MD+~D) ~ Directional Su~oy 20 Dep~ where SSSV set ~ 2~ Thickness o[ permafrost 7510' MD, ~08~ IVD 73~8' MD, ~813' ~D YE8 ~ ~O ~ 17~3' feet MD] 1 ~00' ~OX 22 Typo filoctdc or Othor ko~s ~un CDS, GD~, CBT, G~T, 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP ~ HOLE SIZE C~~ 16" 62.5ff H-40 SURF 121' 24" 200 SX CSI 9.625" 40ff L-80 SURF 2672' 12.25" 570 SX PF E CMT, 190 SX C~SS G 150 SX PFC TOP JOB 7" 26ff J-55 SURF 7483' 8.5" 590 SX CLASS G CMT 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9.3ff J-55 6840' 6805' 7218'-7243' ~ 4 SPF W/4-1/2" CSG GUN MD 6660'-6682' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production ~Me~od of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ] GAS-OIL RATIO TEST PERIOD ~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Pre~. 24-HOUR RATE ~ 28 CORE DATA Brief description of litholo~, porosi~, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska 0il & Gas Cons. Corn 'Anchoraga. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP OF KUPARUK C 6905' 6397' BASE OF KUPARUK C 7021 ' 6494' TOP OF KUPARUK A 7185' 6632' BASE OF KUPARUK A 7315' 6742' ,/: .% .;. ,... ~,,..- ._.. . 31. LIST OF A'Ff'ACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed Title ~"~/"h ~¢-~,~( DATE / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1H-16 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-22315 92-131 ACCEPT: 01/06/93 05:30 SPUD: 01/07/93 02:00 RELEASE: 01/11/93 07:30 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 01/07/93 ( 1) PARKER 245 TD: 600'( 600) 01/08/93 (2) PARKER 245 TD: 2690' (2090) DRILLING 9-5/8"@ 2671' MW: 9.2 VIS: 84 MVE RIG F/1H-17 TO 1H-16. ACCEPT RIG @ 17:30 HRS ON 01/06/93. NU 20" ANN & DIVERTER LINES. 41.94' F/RT TO STARTING HEAD. CHANGE OUT UPPER IBOP VALVE ON TOP DRIVE. SERVICE RIG. FUNCTION TEST DIVERTER. FILL STACK W/MUD. NO LEAKS. CUT DRLG LINE. RESET CROWN-O-MATIC. PU BHA. ORIENT TOOLS W/MWD. DRLG OUT CONDUCTOR F/70'TO 121' CLEAN OUT FLOWLINE. DRLG 12.25" HOLE F/121'-560'. WORK ON UPPER IBOP ON TOP DRIVE. DRLG 12.25" HOLE F/560'-600' ND DIVERTER 9-5/8"@ 2671' MW:10.5 VIS: 44 DRLG 12.25" SURF HOLE W/MOTOR & MWD TO 2030' CIRC OUT GAS @ 2030' MUD GAS CUT F/10.5 PPG TO 10.2 PPG. DRLG 12.25" HOLE F/~030'-2690' TD. CIRC HOLE CLEAN. PUMPED SLUG. MADE 17 STD SHORT TRIP TO 1100'. HOLE IN GOOD SHAPE NO FILL. CIRC & COND HOLE FOR 9-5/8" CSG. VERY SMALL ~MT OF TRIP GAS. DROP SURVEY. SLUG. POH. LD BHA. RU CASERS. HOLD SAFETY MEETING. RAN 61 JTS 9-5/8" 40# L-80 CSG. SHOE SET @ 2672' RU HOWCO. CIRC-COND MUD & CLEAN UP HOLE FOR CMT JOB. FULL RETURNS. SET & CMT 9-5/8" CSG @ 2672' HOWCO CMT'D W/570 SX PERMAFROST E + 1/4 PPS FLOCELE TAILED IN W/190 SX CLASS G + 2% CC + 1/4 PPS FLOCELE. RECIP PIPE. GOOD RETURNS THOUGHOUT JOB. DISPLACED W/20 BBLS WATER & 176 BLS 10.5 PPG MUD. PLUG DOWN & JOB COMPLETE @ 5:00 HRS 01/08/93. HAD WATER SPACER TO SURF-NO CMT. ND DIVERTER-WILL DO TOP JOB. AiaSk~-t Oil & G~ts Go~s. Oom~-c~s~U~' 'A~ohom,qe WELL: 1H-16 API: 50-029-22315 PERMIT: 92-131 PAGE: 2 01/09/93 ( 3) PARKER 245 TD: 3740' (1050) 0i/i0/93 ( 4) PARKER 245 TD: 7092' (3352) 01/11/93 ( 5) PARKER 245 TD: 7510' ( 418) 01/12/93 ( 6) PARKER 245 TD: 7510'( o) DRILLING 9-5/8"@ 2671' MW:10.4 VIS: 38 LD LANDING JT. ND DIVERTER. RAN 1" TO 90' BELOW GL. WASHED OUT 16" X 9-5/8" ANN W/16 BBLS WATER. CMT'D W/150 SX PF "C" @ 15.6 PPG. CIRC GOOD CMT TO SURF. LD 1" PACKED VOID BEHIND PIPE W/DRY CMT. SCREWED ON 11"-3000 PSI BRADEN HEAD. TORQUED TO 16,000 FT/LB. NU 13-5/8" BOP'S. TEST CHOKE MANIFOLD, PIPE & BLIND RAMS, HYDRIL, STABING VALVES, UPPER & LOWER KELLY COCKS TO 250 PSI & 3000 PSI. PULL TEST PLUG & INSTALL WEAR BUSHING. PU BHA. ORIENT & PROGRAM TOOLS. CHANGE OUT JARS. TEST MWD. RIH. TAGGED UP @ 2576'. DRLG CMT & PLUG F/2576' TO FC @ 2585'. RU LINES. TEST 9-5/8" CSG TO 2000 PSI FOR 30 MIN. LEAKED OFF 100 PSI. DRLG FC @ 2585', CMT, SHOE @ 2671, & 15' NEW FORM TO 2705' CIRC & COND MUD. CMT CONTAMINATED-RAISE WT TO 10.3 PPG. PULLED UP INTO CSG. RAN EMW TEST W/10.3 PPG MUD. PRESS UP TO 325 PSI. HELD. EMW=12.6+ PPG. DRLG 8.5" HOLE W/MOTOR & MWD F/2705'-3740'. GAS SHOW @ 3257'-CUT MUD WT TO 8.7 PPG. DRILLING 7"@ 7483' MW:10.1 VIS: 40 DRLG 8.5" HOLE W/MOTOR & MWD F/3740'-4755'_ SERVICE RIG. DRLG 8.5" HOLE F/4755'-7092' CUT MUD WT F/10.5 PPG TO 10.2 PPG. NO GAS WHILE DRLG & CIRC. RUNNING 7" CSG 7"@ 7483' MW:10.1 VIS: 38 DRLG 8_5" HOLE W/MOTOR & MWD F/7092'-7510'_ CIRC & COND MUD @ 7510' SLUG DP. POH W/54 STDS TO 2600' HOLE IN GOOD SHAPE. CUT DRLG LINE. RESET & CHECK CROWN-O-MATIC. RIH. HAD 5' FILL. CIRC & COND HOLE FOR 7" CSG. HOLE UNLOADING & HEAVING SHALE SLIVERS. APPEAR TO BE A LITTLE UNDER-BALANCED IN KINGIK SHALE. CIRC CLEAN ON THIRD BMTS UP. SLUG DP. POH. SLM. DOWN LOAD LWD TOOLS. LD BHA. PULL WEAR BUSHING. RU CASERS. HOLD SAFETLY MEETING. RUN 7" 26# J-55 BTC CSG AS PER WELL PLAN. CIRC @ 2600' & 6000'. CSG ON BTM @ 06:00. SHOE @ 7483' & FC @ 7397' CIRC 30 SPM-400 PSI. RELEASED & MOVE RIG 7"@ 7483' MW:10.1 VIS: 38 CIRC & COND MUD W/CSG ON BTM @ 7483', CIRC @ 6 BPM - 650 PSI, TEST HOWCO LINES TO 4000 PSI, SET & CMT 7" CSG @ 7483' W/ 50 BBLS PREFLUSH, 20 BBLS SPACER, LEAD 330 SX PREM "G", AND TAIL 260 SX PREM "G". DISPLACE W/282 BBLS 10.1 BRINE. RECIPOCATED PIPE W/ FULL RETURNS THROUGH OUT JOB. PLUG DOWN & JOB COMPLETE @ 11:45 1/11/93. TEST CSG TO 3500 PSI FOR 30 MIN - OK. PU BOPS, LANDED 7" CSG W/150,000# ON SLIPS, BLEW BRINE OUT OF CSG, CUT OFF 7" CSG, ND AND SET BACK BOPS, NU 11" 3000PSI X 7 1/16" 5000PSI TBG HEAD W/TREE, TEST TO 3000 PSI, OK, FP 9 5/8" X 7" ANNULUS W/ 20 BBLS WATER & 70 BBLS DIESEL, PUMPED TO FINAL PRESSURE 1150 PSI @ 2 BPM., RKB TO TBG HEAD HOLD DOWN SCREWS = 37.4' RELEASE RIG @ 19:30 ON i/ii/93. WELL: 1H-16 API' 50-029-22315 PERMIT: 92-131 PAGE: 3 06/13/93 (8) TD' 7510 PB' 7398 MOVED TO 1H-17 7"@ 7483' MW:10.1 NaCl/Br MOVE RIG F/1H-22 TO 1H-16. ACCEPT RIG @ 0600 HRS, 06/12/93. ND TREE, SET TEST PLUG, NU BOP. TEST BLIND RAMS & FLANGES TO 250 PSI & 3000 PSI. RU SWS, TEST LUB TO 1000 PSI. PU PERF GUN #1. PERF F/7218'-7243' W/4-1/2" CSG GUNS @ 4 SPF, 43C UP CHARGE UP & 34B HJ2 CHARGE DOWN. MU 5.95" GAUGE RING & JB & RIH TO 7350'_ POH. MU BAKER D PERM PKR W/TAILPIPE. SET PKR W/TOP @ 6800' WLM & TBG TAIL @ 6836' WLM. RD SWS. RU FLOW RISER & TBG RUNNING EQUIP. MU BAKER HB PKR & TAILPIPE ASSY. RIH ON 3-1/2", 9.3#, J-55, ABM-EUE, IPC TBG. CONT RIH W/3-1/2" TO CAMCO SSSV. HOOK UP CONTROL LINE & TEST TO 5000 PSI. SPACE OUT 1-1/2' ABOVE PERM PKR. MU FMC HGR & HOOK UP CONTROL LINE & TEST TO 5000 PSI. LAND TBG. RILDS. PRESS TBG & ANN TO 1000 PSI. CLOSE SSSV & BLEED TBG TO 500 PSI. HOLD FOR 15 MIN. PRESS TBG TO 1000 PSI & OPEN SSSV. PRESS TBG & ANN TO 2500 PSI FOR 15 MIN. INCREASE TBG TO 3000 PSI & BALL SHEARED. SET BPV. ND FLOW RISER & BOP. NU FMC LOWER & UPPER TREE, TESTED PACKOFF TO 5000 PSI, TESTED TREE TO 250 PSI & 5000 PSI, PULLED TEST PUG. RU & PMP LINES, PMP 12 BBLS DIESEL DOWN ANN & 4 BBLS OF DIESEL DOWN TBG. SECURED WELL. SICP=0 PSI, SITP=1800 PSI. RELEASED RIG @ 0330 HRS ON 05/13/93. SIGNATURE: ( dent ) DATE: SUB - S URFA CE DIRECTIONAL SURVEY J'~ UIDANCE r~ ONTINUOUS ~ OOL Company Well Name ,~'~"~'~'" Oil & Gas Cons. Cori~,rnissi°~' ARCO A~S~, INC. 1H-16 (671' ~L, 1156' ~L, SEC 33, I12N, RIOE, ~) Field/Location KUPARIJK, NORTH SLOPE, ALASKA Job Reference No. Date Log~ge3~SB'V: ~~ ~[ ~ O FI L H [ ~C°m3pz~t~eZ-B~); ~ · SCHLUMBERGER GCT DZRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO 1H-16 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE' 31-JAN-93 ENGZNEER' SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORZZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 0 DEG 2 MIN WEST ARCO 1H-16 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE' 25-FEB-93 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 99 98 199 97 299 96 399 96 499 96 599 96 699 95 799 95 899 95 PAGE 1 DATE OF SURVEY' 31-JAN-93 KELLY BUSHING ELEVATION- 96.00 FT ENGINEER' SARBER 0 O0 100 O0 200 O0 300 O0 400 O0 5OO O0 600 O0 700 O0 800 O0 900 O0 INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 0 N 0 0 E 0 14 N 3 54 E 0 18 N 52 36 E 0 21 N 43 24 E 0 25 N 42 55 E 0 26 N 44 9 E 0 2O N 46 10 E 0 16 N 26 37 E 0 17 N 2 38 E 0 23 N 7 25 W -96 O0 3 98 103 97 203 96 303 96 403 96 503 96 603 95 703 95 803 95 FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O0 0 19 0 67 1 1 2 3 3 4 23 83 47 07 57 02 0 O0 0 O0 0 64 0 52 0 53 0 $5 0 50 0 46 0 46 0 40 0 O0 N 0 O0 N 0 19 N 0 67 N 1 23 N 1 83 N 2 47 N 3 08 N 3 57 N 4 02 N 0 O0 E 0 O0 E 0 12 E 0 44 E 0 77 E I 14 E 149 E I 84 E 2 10 E 2 13 E 0.00 N 0 0 E 0.00 N 0 0 E 0.22 N 32 41E 0 8O N 33 2 E I 45 N 32 5 E 2 16 N 31 46 E 2 89 N 31 5 E 3 58 N 30 54 E 4 14 N 3O 24 E 4 55 N 27 58 E 1000 O0 1100 O0 1099 1200 O0 1199 1300 O0 1299 1400 O0 1399 1500 O0 1499 1600 O0 1599 1700 O0 1699 1800 O0 1799 1900 O0 1899 999 95 95 1003 95 1103 94 1203 94 1303 93 1403 92 1503 91 1603 89 1703 87 1803 903 95 95 95 94 94 93 92 91 89 87 0 19 N 10 12 W 0 17 N 48 50 W 0 28 N 67 40 W 0 39 N 75 30 W 0 41 N 81 16 W 0 39 S 85 0 W 0 52 S 80 11W 0 56 S 8O 8 W 0 59 S 75 21W 1 11 S 67 20 W 4 5O 4 98 ,5 46 5 81 5 95 S 95 .5 89 5 62 ,.5 15 4 55 0 71 0 43 0 48 0 45 0 43 0 39 0 36 0 34 0 37 0 80 4 50 N 4 98 N 5.46 N 5.81 N 5.95 N 5.94 N `5.89 N 5.62 N ,5.14 N 4.55 N 1 96 E 1 62 E I 05 E 0 23 E 0 79 W 2 12 W 3 45 W 4 92 W 6 65 W 8 ,54 W 4 91 N 23 29 E 24 N 17 58 E 56 N 10 52 E 81 N 2 17 E O0 N 7 32 W 31 N 19 39 W 82 N 3O 24 W 47 N 41 14 W 41 N 52 17 W 68 N 61 58 W 2000 O0 1999 85 1903 85 2100 O0 2099 22OO O0 2199 2300 O0 2299 2400 O0 2399 2500 O0 2499 2600 O0 2599 2700 O0 2698 2800 O0 2798 2900 O0 2897 83 2003 83 82 2103 82 80 2203 80 78 2303 78 66 2403 66 43 2503 43 99 2602 99 47 2702 47 95 2801 95 1 16 S 68 1,5 W 1 6 S 75 46 W 1 4 N 2 59 W 1 10 N 11 26 E 1 43 N 14 42 E 3 9 N 15 38 E 4 41 N 9 53 E 5 42 N 7 51E 5 56 N 6 41E 5 46 N 5 23 E 3 88 3 26 3 88 S 78 7 88 12 63 19 19 28 37 38 53 48 65 0 41 0 4O 1 21 0 87 0 45 1 37 1 22 1 45 0 76 0 33 3 87 N 3 25 N 3 88 N ,5 78 N 7 88 N 12 63 N 19 19 N 28 36 N 38 52 N 48 64 N 10 52 W 12 44 W 13 16 W 12 94 W 12 56 W 11 39 W 9 98 W 8 73 W 7 45 W 6 30 W 11 21 N 69 46 W 12 86 N 7`5 21W 13 71 N 73 35 W 14 17 N 65 57 W 14 83 N 57 55 W 17 O1 N 42 3 W 21 63 N 27 28 W 29 68 N 17 7 W 39.24 N 10 57 W 49 05 N 7 23 W 3000 O0 2997 44 2901 44 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 3096 O0 3196 O0 3294 O0 3392 O0 3489 O0 3584 O0 3679 O0 3771 O0 3862 94 3000 16 3100 78 3198 57 3296 35 3393 82 3488 08 3583 65 3675 54 3766 5 44 N 6 7 E 94 5 46 N 4 21E 16 8 34 N 3 43 E 78 10 33 N 1 12 E 57 13 13 N 0 46 W 35 15 37 N 0 59 W 82 18 26 N 0 39 W 08 20 52 N 0 32 W 65 23 33 N 0 21W 54 25 46 N 0 22 W 58 64 68 58 80 90 97 4`5 118 31 143 44 173 14 206 52 244 32 285 99 0 32 0.27 1 71 2 37 2 47 2 24 2 81 2 72 I 19 1 64 58 64 N 68 58 N 80 90 N 97 45 N 118 31 N 143 43 N 173 14 N 2O6 51N 244 32 lq 285 99 N ,5 26 W 4 44 W 68 3 64 W 80 2 95 W 97 2 92 W 118 3 43 W 143 3 86 W 173 4 13 W 206 4 48 W 244 4 72 W 286 58 88 N 5 7 W 72 N 3 42 W 98 N 2 35 W 49 N 1 44 W 35 N 1 25 W 48 N 1 22 W 18 N 1 17 W 55 N 1 9 W 36 N 1 3 W 03 N 0 57 W ArCO 1H-16 KUPARUK NORTH SLOPE, ALASKA COMPUTATZON DATE: 25-FEB-93 PAGE 2 DATE OF SURVEY: 31-JAN-93 KELLY BUSHZNG ELEVATZON: 96.00 FT ENGZNEER: SARBER ZNTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTZCAL DOGLEG RECTANGULAR COORDZNATES HORZZ. DEPARTURE MEASURED VERTZCAL VERTZCAL DEVZATZON AZZMUTH SECTZON SEVERZTY NORTH/SOUTH EAST/WEST DZST. AZZMUTH DEPTH DEPTH DEPTH DEG MZN DEG MZN FEET DEG/IO0 FEET FEET FEET DEG MZN 4000 O0 3951 82 3855.82 27 31 N 0 58 W 331 02 4100 O0 4040 4200 O0 4129 4300 O0 4216 4400 O0 4301 4500 O0 4385 4600 O0 4470 4700 O0 4556 48OO O0 4641 4900 O0 4727 54 3944.54 27 20 N I 19 W 377 31 4033.31 27 50 N I 48 W 423 19 4120 19 31 10 N 0 12 W 472 14 4205 14 32 4 N I 11E 525 94 4289 94 31 57 N 0 51E 578 90 4374 90 31 39 N 0 18 E 631 16 4460 16 31 20 N 0 1W 683 83 4545 83 30 47 N 0 17 W 734 93 4631 93 30 22 N 0 25 W 785 15 18 64 39 38 12 37 95 82 1.89 1 . 78 1 . 33 1 56 1 62 1 58 1 25 0 50 0 40 0 46 331 O1N 377 14 N 423 17 N 472 64 N 525 39 N 578 38 N 631 12 N 683 36 N 734 95 N 785 81N 5 30 W 331 06 N 0 55 W 13 W 377 42 W 423 49 W 472 68 W 525 74 W 578 22 W 631 11W 683 17 W 734 54 W 785 19 N 0 56 W 24 N 1 0 W 71 N 1 2 W 44 N 0 50 W 42 N 0 40 W 15 N 0 34 W 39 N 0 31 W 98 N 0 29 W 84 N 0 29 W 5000 O0 4813 90 4717 90 31 44 N 0 31 W 836 89 5100 O0 4897 5200 O0 4981 5300 O0 5064 5400 O0 5147 5500 O0 5229 5600 O0 5311 5700 O0 5393 5800 O0 5475 5900 O0 5558 74 4801 24 4885 98 4968 47 5051 47 5133 43 5215 40 5297 82 5379 99 5462 74 33 35 N 1 1 W 891 24 33 12 N 1 38 W 946 98 33 18 N 2 1 W 1001 47 34 58 N 0 57 E 1057 47 34 56 N 0 58 E 1114 43 34 59 N 1 7 E 1172 40 34 46 N 1 24 E 1229 82 34 8 N 1 10 E 1285 99 33 32 N 0 43 E 1341 36 38 O1 52 75 04 29 9O 42 0 63 1 14 891 1 13 946 1.12 1001 1 36 1057 1 06 1114 0 95 1172 0 59 1229 0 29 1285 0 46 1341 36 N 7 37 N 8 O1 N 10 51 N 10 75 N 9 03 N 8 29 N 7 90 N 6 42 N 5 836 88 N 65 W 891 93 W 946 74 W 1001 88 W 1057 95 W 1114 92 W 1172 67 W 1229 33 W 1285 38 W 1341 7 07 W 836 91 N 0 29 W 39 N 0 30 W 41 N 0 32 W O7 N 0 37 W 57 N 0 35 W 79 N 0 31W 06 N 0 26 W 31 N 0 21W 92 N 0 17 W 43 N 0 14 W 6000 O0 5642 45 5546.45 33 13 N 0 18 E 1396 50 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5726 O0 5810 O0 5893 O0 5976 O0 6O59 O0 6141 O0 6224 O0 6308 O0 6392 43 5630.43 32 34 N 0 2 E 1450 24 5714 24 33 45 N 0 43 E 1505 54 5797 54 33 13 N 0 42 E 1560 90 5880 90 34 20 N 1 45 E 1615 05 5963 05 34 39 N 1 52 E 1672 66 6045 66 34 0 N 1 39 E 1729 78 6128 78 33 33 N 1 46 E 1784 38 6212 38 33 0 N 1 56 E 1839 42 6296 42 32 44 N 1 57 E 1893 79 33 65 88 86 19 75 6O 76 0 77 1396 50 N 72 1450 74 1505 72 1560 89 1615 08 1672 95 1729 91 1784 57 1839 49 1893 4 86 W 1396 50 N 0 12 W 79 N 4 33 N 4 65 N 3 88 N 2 86 N 0 19 N 1 76 N 2 60 N 4 76 N 6 78 W 1450 46 W 1505 75 W 1560 71W 1615 74 W 1672 O0 E 1729 63 E 1784 43 E 1839 25 E 1893 80 N 0 11 W 34 N 0 10 W 66 N 0 8 W 89 N 0 6 W 86 N 0 2 W 19 N 0 2 E 76 N 0 5 E 61 N 0 8 E 77 N 0 11 E 7000 O0 6476 48 6380 48 32 49 N 1 33 E 1947 90 7100 O0 6560 67 6464 67 32 34 N 1 35 E 2001 84 7200 O0 6645 06 6549 06 32 24 N 1 49 E 2055 47 7300 O0 6729 61 6633 61 32 9 N 1 42 E 2108 85 7400 O0 6814 45 6718 45 31 56 N 1 37 E 2162 25 7500 O0 6899 33 6803 33 31 56 N 1 37 E 2215 10 7510 O0 6907 82 6811 82 31 56 N 1 37 E 2220 39 0 39 1947 91 N 7 88 E 1947 92 N 0 14 E 0 34 2001 84 N 9 37 E 2001 87 N 0 16 E 0 26 2055 47 N 11 01 E 2055 50 N 0 18 E 0 27 2108 86 N 12 65 E 2108 89 N 0 21 E 0 O0 2162 25 N 14 20 E 2162 30 N 0 23 E 0 O0 2215 11 N 15 70 E 2215 17 N 0 24 E 0 O0 2220 40 N 15 85 E 2220 45 N 0 25 E COMPUTATION DATE: 25-FEB-93 PAGE 3 ARCO 1H-16 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 7510 0 O0 -96 O0 0 0 N 0 0 E O0 999 O0 1999 O0 2997 O0 3951 O0 4813 O0 5642 O0 6476 O0 6907 95 903 85 1903 44 2901 82 3855 90 4717 45 5546 48 6380 82 6811 95 0 19 N 10 12 W 4 85 1 16 S 68 15 W 3 44 5 44 N 6 7 E 58 82 27 31 N 0 58 W 331 90 31 44 N 0 31 W 836 45 33 13 N 0 18 E 1396 48 32 49 N 1 33 E 1947 82 31 56 N 1 37 E 2220 0 O0 50 88 64 02 89 5O 9O 39 0 O0 0 0 0 1 0 0 0 0 0 O0 N 71 4 41 3 32 58 89 331 63 836 77 1396 39 1947 O0 2220 0 O0 E 50 N 1 87 N 10 64 N 5 O1 N 5 88 N 7 50 N 4 91 N 7 40 N 15 0.00 N 0 0 E 96 E 4.91 N 23 29 E 52 W 11.21 N 69 46 W 26 W 58.88 N 5 7 W 30 W 331.06 N 0 55 W 07 W 836.91 N 0 29 W 86 W 1396.50 N 0 12 W 88 E 1947.92 N 0 14 E 85 E 2220.45 N 0 25 E ARCO 1H-16 KUPARUK NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 96 02 196 03 296 04 396 04 496 O4 596 04 696 05 796 05 896 05 0 O0 96 O0 196 O0 296 O0 396 O0 496 O0 596 O0 696 O0 796 O0 896 O0 COMPUTATION DATE' 25-FEB-g3 PAGE 4 DATE OF SURVEY' 31-JAN-93 KELLY BUSHING ELEVATION' 96.00 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN -96 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0.00 0 13 N 3 44 E 0.00 0 17 N 53 39 E 0.18 0 20 N 43 27 E 0.65 0 24 N 44 37 E 1.21 0 25 N 46 3 E 1.81 0 20 N 42 56 E 2.46 0 17 N 23 20 E 3.06 0 19 N 4 15 E 3.55 0 23 N 3 59 W 3.99 O. O0 O. O0 0 66 0 53 0 53 0 55 0 5O 0 46 0 46 0 40 0 O0 N 0 O0 N 0 18 N 0 65 N 1 21 N 1 81 N 2 46 N 3 06 N 3 55 N 3 99 N 0 O0 E 0 O0 E 0 10 E 042 E 0 75 E 1 11 E 1 48 E 1 83 E 2 09 E 2 14 E 0.00 N 0 0 E 0.00 N 0 0 E O.2O N 3O 41E 0.78 N 32 43 E 1.42 N 31 52 E 2.13 N 31 37 E 2.87 N 31 I E 3.56 N 30 57 E 4.12 N 30 31E 4.53 N 28 10 E 996 05 1096 1196 1296 1396 1496 1596 1696 1796 1896 996 O0 05 1096 05 1196 06 1296 06 1396 07 1496 08 1596 09 1696 11 1796 13 1896 900.00 O0 1000.00 O0 1100.00 O0 1200.00 O0 1300.00 O0 1400.00 O0 1500.00 O0 1600.00 O0 1700.00 O0 1800.00 0 17 N 10 24 W 0 17 N 52 26 W 0 29 N 65 55 W 0 39 N 73 33 W 0 39 N 80 44 W 0 39 S 84 8 W 0 52 S 80 35 W 0 55 S 80 25 W 1 0 S 73 59 W 1 12 S 67 59 W 1996 15 1996 O0 1900 O0 2096 2196 2296 2396 2496 2596 2696 2797 2898 17 2096 18 2196 20 2296 22 2396 34 2496 56 2596 99 2696 52 2796 04 2896 O0 2000 O0 2100 O0 22OO O0 23OO O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 O0 O0 O0 O0 O0 O0 O0 O0 O0 1 16 S 68 13 W 1 6 S 76 38 W 1 2 N 2 52 W 1 10 N 11 46 E 1 37 N 14 54 E 3 9 N 15 31E 4 39 N 10 2 E 5 42 N 7 42 E 5 56 N 6 42 E 5 46 N 5 25 E 2998 SS 2996 O0 2900 O0 3099 3199 3301 3403 3506 3611 3718 3826 3937 05 3096 83 3196 25 3296 53 3396 91 3496 78 3596 16 3696 59 3796 30 3896 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 5 44 N 6 9 E O0 5 46 N 4 20 E O0 8 34 N 3 43 E O0 10 35 N 1 10 E O0 13 21 N 0 51W O0 15 57 N 1 2 W O0 18 41 N 0 34 W O0 21 20 N 0 36 W O0 24 5 N 0 23 W O0 26 37 N 0 42 W 4 48 4 97 5 45 5 79 5 95 5 95 5 90 5 63 5 17 4 58 3 91 3 27 3 82 5 71 7 78 12 44 18 92 28 07 38 27 48 45 58 50 68 49 80 88 97 68 119 13 145 31 176 86 213 10 255 O0 302 47 0 74 0 43 0 48 0 45 0 43 0.40 0.36 O. 33 0 37 0 82 0 42 0 40 I 19 0 92 0 42 I 36 I 23 I .48 0.78 O. 33 0 31 0 27 I 71 2 35 2 46 2 26 2 77 2 78 I 29 I 76 4 48 N 4 97 N 5 45 N 5 79 N 5 95 N 5 95 N 5 90 N 5 63 N 5 16 N 4 58 N 3 91 N 3 27 N 3 81 N 5 70 N 7 78 N 12 43 N 18 91 N 28 07 N 38 27 N 48 45 N 58 50 N 68 48 N 80 88 N 97 68 N 119 13 N 145 31 N 176 86 N 213 10 N 254 99 N 302 47 N 1 96 E 1 63 E 1 08 E 0 27 E 0 74 W 2 08 W 3 39 W 4 86 W 6 59 W 8.47 W 4 89 N 23 36 E 23 N 18 10 E 56 N 11 12 E 80 N 2 43 E 99 N 7 5 W 30 N 19 16 W 80 N 29 55 W 44 N 40 50 W 37 N 51 54 W 63 N 61 36 W 10.44 W 12 37 W 13 15 W 12 96 W 12 59 W 11 44 W 10 02 W 8 77 W 7 48 W 6 32 W 11.14 N 69 29 W 12.79 N 75 12 W 13 69 N 73 51W 14 16 N 66 15 W 14 80 N 58 18 W 16 90 N 42 38 W 21 40 N 27 55 W 29 41 N 17 21W 38 99 N 11 4 W 48 86 N 7 26 W 5 27 W 4 3 2 2 3 3 4 4 4 58 73 N S 9 W 45 W 68 63 N 3 43 W 64 W 80 96 N 2 35 W 94 W 97 72 N I 44 W 94 W 119 17 N 1 25 W 46 W 145 35 N I 22 W 90 W 176 90 N I 16 W 20 W 213 14 N 1 8 W 54 W 255 03 N 1 1W 88 W 302 51 N 0 55 W COMPUTATZON DATE: 2S-FEB-93. PAGE 5 ARCO 1H-16 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 31-JAN-g3 KELLY BUSHZNG ELEVATZON: 96.00 FT ENGZNEER: SARBER ZNTERPOLATF__D VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTZCAL DOGLEG RECTANGULAR COORDZNATES HORZZ. DEPARTURE MEASURED VERTZCAL VERTZCAL DEVZATZON AZZMUTH SECTZON SEVERZTY NORTH/SOUTH EAST/WEST DZST. AZZMUTH DEPTH DEPTH DEPTH . DEG MZN DEG MZN FEET DEG/IO0 FEET FEET FEET DEG MZN 4049 82 3996 O0 3900 O0 27 31 N 0 57 W 354 05 4162 4276 4393 4511 4629 4746 4862 4978 5097 43 4096 46 4196 94 4296 86 4396 48 4496 57 4596 97 4696 97 4796 91 4896 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 45O0 O0 4600 O0 4700 O0 4800 O0 27 21 N I 44 W 405 O0 30 30 N I 7 W 460 O0 32 5 N I 12 E 522 O0 31 56 N 0 47 E 584 O0 31 33 N 0 10 E 646 O0 31 5 N 0 0 E 707 O0 30 30 N 0 30 W 767 O0 30 46 N 0 38 W 825 O0 33 35 N I 0 W 890 79 53 17 65 57 49 O5 85 2O I 85 I 51 I 50 I 63 I 58 I O0 0 36 0 45 0 51 I 13 354 O4 N 4O5 79 N 46O 53 N 522 17 N 584 65 N 646 57 N 7O7 49 N 767 05 N 825 84 N 890 2O N 5 68 W 354 09 N 0 55 W 6 8 7 6 6 6 6 6 7 64 W 890 89 W 405 85 N 0 58 W 42 W 460 61 N I 3 W 75 W 522 22 N 0 51 W 65 W 584 69 N 0 39 W 15 W 646 60 N 0 33 W 11 W 707 52 N 0 30 W 39 W 767 08 N 0 29 W 97 W 825 87 N 0 29 W 23 N 0 29 W 5217 64 4996 O0 4900 O0 33 10 N I 50 W 956 03 5337 5459 5581 5703 5824 5944 6063 6182 6302 36 5096 19 5196 17 5296 16 5396 35 5496 39 5596 85 5696 87 5796 94 5896 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 34 21 N 0 25 W '1021 O0 34 54 N 0 56 E 1091 O0 34 58 N 1 0 E 1161 O0 34 45 N 1 24 E 1231 O0 33 51 N 1 10 E 1299 O0 33 29 N 0 38 E 1365 O0 32 47 N 0 4 W 1431 O0 33 38 N 0 42 E 1495 O0 33 12 N 0 42 E 1562 82 40 24 10 54 93 29 81 27 1 13 1 41 1021 1 11 1091 0 97 1161 0 56 1231 0 34 1299 0 48 1365 0 74 1431 0 71 1495 0 72 1562 956 02 N 9 21 W 956 07 N 0 33 W 82 N 11 15 W 1021 88 N 0 38 W 39 N 10 34 W 1091 23 N 9 13 W 1161 10 N 7 63 W 1231 54 N 6.05 W 1299 93 N 5.10 W 1365 28 N 4.77 W 1431 81 N 4.58 W 1495 27 N 3.73 W 1562 44 N 0 33 W 27 N 0 27 W 12 N 0 21 W 55 N 0 16 W 94 N 0 13 W 29 N 0 11W 81 N 0 11 W 27 N 0 8 W 6423 16 5996 O0 5900 O0 34 53 N 2 4 E 1628 97 6544 6665 6785 6904 7023 7141 7260 7378 7496 82 6096 43 6196 23 6296 25 6396 21 6496 89 6596 29 6696 26 6796 08 6896 O0 6000 O0 6100 O0 6200 O0 6300 O0 6400 O0 6500 O0 6600 O0 6700 O0 6800 O0 34 20 N 1 48 E 1698 O0 33 42 N 1 41 E 1765 O0 33 4 N i 56 E 1831 O0 32 44 N I 56 E 1896 O0 32 43 N I 35 E 1960 O0 32 26 N I 46 E 2024 O0 32 15 N 1 46 E 2087 O0 31 56 N 1 37 E 2150 O0 31 56 N 1 37 E 2213 22 61 56 06 45 34 7O 75 O3 0 98 1628 97 N 1 O0 1698 0 93 1765 0 60 1831 0 48 1896 0 38 1960 0.30 2024 0 25 2087 0 O0 2150 0 O0 2213 2 30 W 1628.97 N 0 5 W 22 N 0 07 E 1698.22 N 0 0 E 61 N 2 05 E 1765.61 N 0 4 E 56 N 4 16 E 1831.56 N 0 8 E 06 N 6 33 E 1896 07 N 0 11 E 45 N 8 23 E 1960 47 N 0 14 E 34 N 10 02 E 2024 37 N 0 17 E 71 N 12 01 E 2087 74 N 0 20 E 76 N 13 87 E 2150 81 N 0 22 E 04 N 15 64 E 2213 09 N 0 24 E 7510.00 6907.82 6811.82 31 56 N 1 37 E 2220.39 0 O0 2220.40 N 15 85 E 22~0 45 N 0 25 E COMPUTATION DATE: 25-FEB-93 PAGE 6 ARCO 1H-16 KUPARUK NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK A GCT LAST READING PBTD 7" CASING TD DATE Df SURVEY: 31-JAN-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 671' FNL, 2 1156' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB 'TYD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2672 O0 6905 O0 7021 O0 7185 O0 7315 O0 7350 O0 7398 O0 7483 O0 7510 O0 2671 13 6396 63 6494 14 6632 40 6742 31 6771 99 6812 76 6884 90 6907 82 2575 13 6300 63 6398 14 6536 40 6646 31 6675 99 6716 76 6788 90 6811 82 25.60 N 1896.47 N 1959.26 N 2047,.44 N 2116.83 N 2135.37 N 2161.20 N 2206.13 N 2220.40 N 9 08 W 6 34 E 8 20 E 10 75 E 12 89 E 13 4O E 14 17 E 15 45 E 15 85 E COMPUTATION DATE: 25-FEB-93 PAGE 7 ARCO 1H-16 KUPARUK NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a PBTD TD DATE OF SURVEY: 31-JAN-93 KELLY BUSHING ELEVATION: 96.00 FT ENGINEER: SARBER ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 671' FNL, A 1156' FEL, SEC33 T12N RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 6905 O0 7021 O0 7185 O0 7315 O0 7398 O0 7510 O0 6396 63 6494 14 6632 40 6742 31 6812 76 6907 82 6300 63 6398 14 6536 40 6646 31 6716 76 6811 82 1896 47 N 1959 26 N 2047 44 N 2116 83 N 2161 20 N 2220 40 N 6 34 E 8 20 E 10 75 E 12 89 E 14 17 E 15 85 E FINAL WFIL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7510.00 6907.82 6811.82 2220.45 N 0 25 E DIRECTIONAL SURVEY COMPANY ARCO FIELD KUPARUK WELL I H-1 6 COUNTRY USA RUN I DATE LOGGED 31 - JAN - 93 DEPTH UNIT FEET REFERENCE 93051 ,All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and ,we shall not. except in the case of gross or wilfull negligence on our par't, be liable or responsible for any loss, costs, damages or expenses IncurTed or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These Interpretations are also subject to our (~eneral Terms and Conditions as set out in our current price Schedule. WELL' 1H-16 (671' FNL, 1156' FEL, SEC 33, T12N, RIOE, UM) HORIZONTAL PROJECTION SOUTH -1000 -2000 NORTH 3000 REF 930Sl SCALE = I / 500 IN/FT _ oo ,., .., -- : :· : ' I !': ' ' ' i 1 -1500 -1000 -500 0 500 1000 1500 2O00 WEST EAST WELL' 1H- 1-6 ~ (671' FNL, 1156' FEL, SEC 33, T12N, RIOE, UN) VERTICAL PROJECTION -1000 -500 0 0 500 1000 1500 2000 2500 3OOO 30000 PROJECTION ON VERT1CAL PLANE 180.00 360.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1 500 IN/FT ARCO Alaska, inc. Date: May 07, 1993 Transmittal #: 8732 RETURN TO: ARCO Alaska, Inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360. Transmitted here with are the folloWing Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. H-16 ~,~,~ I;~~H'19 H-19 ~o~--- J~O /1H-17 ~ ~,,,1H-17 Wg~'"~' M - 01 ~.~...~L~J.~2 M- 12 ':~.~ !5 2M-04 c~..~,~ 2M-14 ~.~M-08 ,_,~,~ 2M-02 ~M-02 CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDR-LWD/Depth CDN-LWD/Depth CDR, LWD/Depth Corrected 1/8-10/93 2671-7510 Corrected 1/8-10/93 2671-7510 Corrected 12/13-16/92 5364-8990 Corrected 12/13-16/92 5364-8990 Corrected 1/2-5/93 4981-8185 Corrected 1/2-5/93 4981-8185 Corrected 10/25-29/92 3347-9800 Corrected 9/6-8/92 2801-4766 Corrected 9/23-26/92 4260-12370 Corrected 7/14-17/92 3664-9811 Corrected 11/3-7/92 4253-12151 Corrected 8/31 to 9/3/92 3437-10003 Corrected 8/31 to 9/3/92 3437-10003 Receipt Acknowledged: DISTRIBUTION: D&M Drilling Date' -,-,v£u MA Y 1 4 1995 Alaska 011 & ~as Cons. Cor~rnission Ancho~ge Vendo~a~age(John~on) NSK State of Alaska(+Sepia) Kathy Worley(Geology) ARCO Alaska, Inc. Date: April 2, 1993 Transmittal #: 8701 RETURN TO: ARCO Alaska, inc. Attn: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signe,~opy of this transmittal. --1 H- 1 6 ~%to"~ LIS Tape and Listing Please acknowledge receipt and return 01-10-93 CDR/CDN & Enhanced Resolution CDR LIS Tape and Listing 01 - 1 5 - 9 3 CDR/CDN In 2 Bit Run LIS Tape and Listing 0 2 - 2 0 - 9 3 CDR/CDN In 2 Bit Runs. 1 Mad-Pass & Resistivity --..1 H - 2 0 -~%'77.. LIS Tape and Listing 1 2 - 2 7,- 9 2 CDR/CDN In 3 Bit Runs. Phasor Enhanced -1 H-01 S~'7~LIS Tape and Listing 01- 2 9- 9 3 tCDR/CDN In 2 Bit Runs/Enhanced Resistivity c~....-O~--------1 H-0 2'--~.o~ LIS Tape and Listing 0 2- 0 5- 9 3 CDR/CDN & QRO Enhanced Resistivty LIS Tape and Listing 0 9 - 2 6 - 9 2 CDR Data from Bit Runs 1 & 2/HLDT/LDWG Format LIS Tape and Listing 0 8 - 1 8 - 9 2 CDR/CDN 1 Bit Run in LDWG Format & HLDT Data LIS Tape and Listing 1 0 - 2 9 - 9 2 CDR Bit Runs 1 & 2/Hi Resolution CDR Processed HLDT & 3 Passes CNTG 93013 93007 93038 92735 93O45 93056 92586 · 92511 92640 ReCeipt Acknowledged' - ............................ Date' - ......... DISTRIBUTION: Bob Ocanas State of Alaska RECEIVED APR 02_ 1993 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' March 12, 1993 Transmittal #: 8682 RETURN TO: ARCO Alaska, Inc. ATTN: Nikki Stiller Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. Cement Bond Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Receipt Drilling Please acknowledge receipt and Acknowledge' 03-02-93 03-02-93 01 -31 -93 01 -31 -93 01 -31 -93 01 -31 -93 Date' State of Alaska(+sepia) 6800-8518 6800-8541 6480-8313 648O-8332 5090-7373 509O-7382 NSK RECEIVED MAR 1 5 1993 /gaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: March 05, 1993 Transmittal #: 8676 RETURN TO: "ARCO Alaska, Inc. Attn: Nikki Stiller' Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1H-16 StJb-Surface Directional 01 -31 -93 93051 Survey Receipt DISTRIBUTION: D&M State of AlasI~,,(2 copies) Date'- ............. ALASKA OIL AND GAS , CONSERVATION COMMISSION / WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 12, 1993 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1H-16 Rev. ARCO Alaska, Inc. Permit No: 92-131 Sur. Loc. 671'FNL, l156'FEL, Sec. 33, T12N, R10E, UM Btmhole Loc. 1573'FSL, l173'FEL, Sec. 28, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated December 16, 1992 are in effect for this revision. Sincerely, Russell A. Douglass Commis s ioner BY ORDER OF THE COMMISSION dlf/En¢losures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALA,Sr,,A OIL AND GAS CONSERVATION ~MIS~ PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work Drill X Redrill l-I 1 b Type of Well Exploratory r-I Sb'atigraphic Test I-'i Development Oil X Re-Entry l-'l Deepen ['-I Service I-I Development Gas r"i Sinl:lleZone X aultipleZone D 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Reid and Pool ARCO Alaska, Inc. RKB 96', Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360. ADL 25639, ALK 464 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.O25) 671' FNL,1156' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At tOl~ of productive interval (@ TARGET ) 8. Well number Number 1,180' FSL, 1,170' FEL, Sec. 28, T12N, R10E, UM 1H-16 #UG630610 At total depth 9. Approximate spud date Amount 1,573' FSL, 1,173' FEL, Sec. 28, T12N, R10E, UM 1/6/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and'l'VD) property line 1H-03 7,560' MD 3,707' ~ TD feet 104' ~ 940' MD feet 2560 6~876' TVD feet 16. To be competed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 3,139' feet Maximum hole an¢ile 36° Ma~rn=~,ce 2~523 Oslo At total depth (TVDI 3~126 osk~ 18. Casing program Settin~l Depth size Specifications Top Bottom Quantit~ of cement Hole Casin~l Wei~lht Grade Coupling Length MD TVD MD TVD {include stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _t:200 CF 12.25" 9.625" 40.0# L-80 BTC 2,609' 41' 41' 2,650' 2r650' 360 Sx Permafrost E & HF-ERW 190 Sx Class G 8.5" 7" 26.0# J-55 BTCMOE 4,376' 41' 41' 4,417' 4,326' 330SxClassG HF-ERW To BTM of Surface Casing 8.5" 7" 26.0# J-55 BTC 3,143' 4,417' 6,876' 7,560' 6,876' 210SxClassG HF-ERW Top 500' above Kuparuk i 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural R E C E IV E D Intermediate Production Liner- 4 Perforation depth: measured Alaska 0ii & Gas Cor!s. Col-[-,,rflissio~ true vertical Anchorage 20. Attachments Filin~ fee I-I/ Property plat I-! BOP Sketc~ X Diverter Sketch X Drilling program X Drilling fluid program~ ~(ne vs depth plot r-I Refraction analysis I-'l Seabed report D 20 AAC 25.050 requirements X 21. I hereby cerlJ~y th/a~he fyr'~loing is true and correct to the best of my knowledge Si~ned r .4. ~.--~. ~ q:¢C;~ ~ Title Area Drilling Engineer Bate '~' 7',," "" ''~ · ~.?-- Commission Use Onl~f Permit Number I APl number I Approval date - . ] See cever letter for ?.2.-/31 5 o- 0.2., ? .... ~ ~ ~ / ~' / ~ -/. ~' - ¢s,~ "' other requirements 'r"'l ' Conditions of approval Samples required r-I Yes l~l No Mud log required Yes [~I No Hydrogen sulfide measures I--] Yes J~ No Directional survey required I~] Yes r=l No Required working pressure for BOPE i-1 2M ~l 3M I"l 5M I-! 10M I-! 15M Other: by order of Approved by Commissioner the commission Date Pnrm 1{3-~.131 Rnu 7-D4.,q.Cl R~hrnit in trinli~-.ntn . . . = . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1H-16 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (2,650')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (7,560') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 ^AC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. Aiask~.. Oil & Gas Cons. Corflffl~s¢o~ Anchorage DRILLING FLUID PROGRAM Well 1H-16 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~] 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD See Well Plan 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. 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 2,523 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1 H-16 is 1 H-03. As designed, the minimum distance between the two wells would be 104' @ 940' MD. The wells would diverge from that point. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping, *Spud mud should be adjusted to a FV between 55-75 sec/qt to ddll gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. "AN -~' Aiaska, Oil & Gas Cons. A~]chore. ge ! · r[0 ~¥ . ~o~ For: D ~FOL~Z PLOTTED : 6-#Ov-92 '. :ROINATE~ ARE :N FEET REFERENCE ~LOT ~16. EASTMAN © 0 ~o 600 . 18oo. Q. . S?~ ELEVATION: 96' 8/ PERMAFROST TVD=161~ ARCO ALASKA, Inc. Structure : Pad 1H Well : 16 Field : Kuparuk River Unit Location : North Slope, Alaska N .43 DEG w 185]' (TO TARGET) JTD LOCATION: J 1573' FSL, 1173' FEL SEC. 28, TI2N, RIOE TARGET LOCATION: J i $ 80' FSL, I I 70' FEL SEC. 28, T12N, RIOE TARGET TV0=633! TUD=6888 DEP=1851 NORTH WEST T/ UGNU SND$ 'FVD=3116 KOP ~D=31&O TMD=3140 DEP=O 3.00 8u~ 3 ~ / too' 9.OO T/ W SAK 5NDS ~D=3553 TMD=3556 OEP=~ 15.00 21.00 27.00 B/ ~ SAK SN05 ~D=~06~ TM0=~tO0 0EP=234 33.00 ~8 MODIFIED CSG' ~=4~26'1M0=~I? DEP=407 K-lO ~0=~96 TMD=~627 0EP=529 AVERAGE ANGLE 35.76 DEG 300 150 0 ISO ~ ISURFACE LOCATION: 671' FNL, 1156' FEL SEC. 33, TI2N, Rt0[ 210'0 · .19~o .I ]50 j I 0 7~,0 3OO · 60O43 630Q.. 660~ L, K-5 T'VO=S951 TM0=6420 OEP=IS77 TARCET TI/D=633t 1'MD=6888 DEP=I851 T/ ZONE C TVD=6373 TldO=6g40 0EP=1881 T/ ZONE A TV0=6619 TMD=7243 DEP=2058 8/ KUP SND$ 'CV0=671- TM0=7360 DEP=2127 TI) / LOGGING Fl' '1'VD=6~75 TMD=75~O DI~P=~4/ 1350 I I 1 300 1 250 West 1 200 1150 SCALE 1 : 50.00 1100 1 050 1 000 950 1100 4.100 900 1700 11 3900 90~ 1500 300 70t 500 3700 1300 3500111 O0 ~oo ARCO ALASKA, Inc, Sfrucfure : Pad 1H Well: 16/17/19/20 Field : Kup(iruk River Unlf Loceflon : Norfh Slope, Alaska 350 _400 -- _450 _5OO _55O - 0 _600 (i _650 - I _700 J - V _750 _800 __BSO Casing Design / Cement Calculations 4-Jan-93 Well Number: 1 H-16 Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A 'rVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Well TD, TMD: Well TD, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 2,650 ft 2,650 ft 4,417 ft 4,326 ft 7,560 ft 6,876 ff 3,556 ft 6,888 ft 6,331 ft 7,560 ft 6,876 ft 9.8 ppg Note: Wells withTD less than ll,0(X)' TMD recommend using all J-55 7" casing. Wells with TD greater than ll,000'TMD recommend crossing over to L-80 7" casing at 5800' TMD from surface. 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 2,650 ft {(13.5*0.052)-0.11}*TVDshoe =1 1,569 psi] Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = =1 9.8 ppg 6,331 ft 3,226 psi 3126 psiI Surface lead: Surface Casing, TMD = 2,650 ft Design lead bottom 500 ft above the Bottom of Casing Shoe = 2,150 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 673 cf Excess factor = 15% Cement volume required = 774 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 360 sxI Surface tail:TMD shoe = 2,650 ft (surface TD - 500' above BTM of Surface Casing ) * (Annulus area) = 157 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 191 cf Excess factor = 15% Cement volume required = 219 cf Yield for Class G cmt = 1.15 Cement volume required =[ 190 sx] R CEiV D d - 4 199 Alaska 0il & Gas Cons. Anchorage Casing Design / Cement Calculations 4-Jan-93 Production lead: ~ Surface Casing,TMD Design lead from 500' above Target to bottom of Surface Casing Annular area (9" Hole) Lead length * Annulus area Excess factor Cement volume required Yield for Permafrost Cmt Cement volume required 2,650 ft 3,738 ft 0.1745 cf/If 652 cf 15% 750 cf 2.28 330 sxI Production tail: RECEIVED AIaska Oil & Gas Cons. Commission Anchorage TMD = Top of Target, TMD = Want TOC 500' above top of target = Annulus area (9" Hole) = (TD-TOC)*Annulus area = Length of cmt wanted in csg = Internal csg volume = Cmt required in casing = Total cmt = Excess factor = Cement volume required = Yield for Class G cmt = Cement volume required =[ 7,560 ft 6,888 ft 6,388 ft 0.1745 205 cf 80 ft 0.2148 17 cf 222 cf 15% 255 cf 1.23 210 sxJ Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud TENSION - Minimum Design Factors are: T(pb)=1.5 and T~s)=1.8 Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) Design Factor Surface (Joint Strength): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air --Buoyancy = Tension (Pipe Body) = Design Factor =[ Production A (Joint Strength): Casing Rated For: Tension (Pipe Body) -- Dead Wt in Air - Buoyant Force Length = Dead Wt in Air = Length * (Wt/ft) Casing Wt (lb/fi) = Buoyancy = Weight of displaced mud Dead Wt in Air = Buoyancy = Tension (Joint Strength) = 2 Design Factor =1 916000 lb 2,650 ft 40.00 Ib/ft 1 O6OOO.O lb 15451.1 lb 90548.9 lb 10.1J 9790OO lb 2,650 ft 40.00 Ib/ft 106000.0 lb 15451.1 lb 90548.9 lb lO.8J 415O00 lb 7,560 ft 26.00 lb/fi 196560.0 lb 29052.4 lb 167507.6 lb 2.51 490000 lb 7,560 ft 26.00 lb/fi 196560.0 lb 29052.4 lb 167507.6 lb 2.9J Casing Design / Cement Calculations 4-Jan-93 Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud BURST- Minimum Desian Factor = 1.1 -- Surface Casing: Burst = Maximum surface pressure Production Csg A: 1. Design Case -Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Production Csg B: 1, Design Case- Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.gppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2, External pressure =Mud Wt * 0.052 * TVD Production Csg A 1, Worst Case - Full evacuation of casing 2, Mud weight on outside = Mud Wt * 0.052 * TVD Production Csg B 1. Worst Case - Full evacuation of casing 2, Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 415OOO lb 3,143 ft 26.00 Ib/ft 81718.0 lb 12078.3 lb 69639.7 lb 49OOOO lb 3,143 fi 26.OO lb/fi 81718.0 lb 12078.3 lb 69639.7 lb 7.0J Casing Rated For: Max Shut-in Pres = Design Factor =~ Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =b Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ 5750 psi 1568.8 4980 psi 5705 psi 2002 psi 3702 psi 1.3J 4980 psi 7004 psi 3182 psi 3822 psi 1.3J Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =J Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =J Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =J 3090 psi 0.510 lb/fi 1350 psi 2.3J 4320 psi 0.510 lb/fi 22O5 psi 2.0J 4320 psi 0,510 Ib/ft 3504 ps! RECEIVED ,.IAt',! - 4 997) Gas Co~s. Commission A~chor'~ge Casing Design / Cement Calculations 4-Jan-93 Surface Casing Choices oo ID Ib/ft Grade Metal X-Section 1 9.625 8.681 47 L-80 13.5724 sq. in. 2 9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength Body Strength Collapse Burst 1161000 lb 1086000 lb 4750 psi 6870 psi 979000 lb 916000 lb 3090 psi 5750 psi 639000 lb 564000 lb 2020 psi 3520 psi 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices oo ID Ib/ft Grade Metal X-Section I 7.000 6.276 26 L-80 7.5491 sq. in. 2 7.000 6.276 26 J-55 7.5491 sq. in. Jt Strength 667000 lb 490000 lb Body Strength Collapse Burst 604000 lb 5410 psi 7240 psi 415000 lb 4320 psi 4980 psi Alaska Oil & Gas Cons. Corrm'dssion Anchorage _ _r 7 6 I 13 5/8" .500P - SI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FlU. ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WITH 1500 PSI DOW~~ OF THE REGULATOf:~ 3. O~SERVE 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 REi::K:N::iT. THE ACCEPTABLE LOWER MMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING 5 4 3 1. 16' - 2000 PSI STARTING HEAD 2. 11' - 3(XX) PSI CASING HEAD 3. 11' - 3(X)O PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5(X)0 PSI PIPE Fl;AMS 5. 13~5/8' - 5000 PSI DRLG SPCX:)L W/ CHOKE AND KILL MNES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2. CHECK THAT ALL I-K:N.I:)q:X3~ SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCKq:X:)WN 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. & OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE 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 3(XX) PSi HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSi AND 3(XX) PSI. 9. OPEN PIPE RAMS. EACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 30(X) PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY CCX::;KS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON I~.OWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRIllING SUPERVISOR. 14. PERFORM ~ BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. f , · Alaska 0il & 6ao Oor~s. ¢on-~mlsston Anchor,~g ~ SRE &'22/89 .~ %UPARUK RIVER [~"T 20" DIVERTER SCHEMATIC I 6 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 5 5 5 I MAINTENANCE & OPERATION i O 3 O , . UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WE/!RORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP~:)N WELD STARTING HEAD 3, FMC DIVERTER ASSEMBLY WITH TWO 2-1/16'- 2000 PSI BALL VALVES 4. 20" - 2,000 PSI DRILLING SPOOL WITH TWO 10' OUTLETS. 5. 10' HCR GATE VALVES WITH 10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY O_.,O~D TO ACHIEVE DOWNWIND DIVERSION. 6. 20" -2000 PSI ANNULAR PREVENTER MLP 8/14/91 , . Alaska Oil & Gas Ccns. Cornrnis¢or~ A.-~,_,horage "(UPARUK RIVER I,,. 'T 20" DIVERTER SCHEMATIC · I 6 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES 5 5 5 MAINTENANCE & OPERATION 3 . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WE~ ~RORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FRC~ 20AAC25.035(b) 1. 16' COND(X~TOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16'- 2000 PSI BALL VALVES 4. 20' - P~000 PSI DRILLING SP(:X:)L WITH TWO 10' OUTLETS. 5. 10' HCR GATE VALVES WITH 10' DIVE~ LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTI:I~ I Fr3 TO ACHIEVE DOWNWIND DIVERSION. A~,chorag~ 1H-1 ~CMT.XLS State: Well: Field: State Permit /H-l~' I(LIPARL!K RV. 92.13i Engineer: 'w'ork Sheet: Bate: A~ £bmer~l Foi~ ¢me £'alc~ #al~o/ 1/$/$2 Casing Type Casing Size -Inches Casing Length- Feet Hole Diameter-Inches Cement- Sacks Cement- Yield Cement- Cubic R Cement- Cubic It ,"il Cement-Sacks ~2 Cement- Yield ~2 Cement-Cubic ft ~2 Cement- Cubic R Cement-Sacks I:t3 Cement-Yield ~3 Cement- Cubic tt$13 Cement-Cubic it Ceme,'~ - Cubic ft /VOl Cement- Fill Factor Casir,9 Type Casing Size -Inches Casing Dep~,h- Feet Hole Diamete~-Inches Cement- Sacks .~i CamarO:- Yield Cerner~ - Cubic fl Cement-Cubic It Cemer~ - Sacks ~12 Cerr'~nt -- Yield :!:12 Cement- Cubic i't 1i2 '~Cemenl - Cubic ft Cement-Sacks ~3 Cement-Yieid ~3 Cement- Cubic R ~3 Cement-Cubic R :I:i3 Cement-Cubic ft /Vol Cement-Interval ft Top o¢ Cemenl:- Fee,~ Conducto~ 18.080 80.000 24.000 0.000 0.000 0.000 200.000 0.000 0.000 O. O00 0.000 200,000 1.432 Intermediate ~1 O. O00 0.000 0,000 0.00 0.00 0.00 0.00 0,00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 ~,DIV/O! I.I:DIV/O! Surface 9.625 2,609.000 12.250 360.000 2.170 781.200 781.200 !90.000 1.150 218.500 218.500 0.000 0.000 0.000 O. OOO 999.700 1.223 Intermediate ~12 0.000 O. O00 0.000 0.00 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 I:IDIV/O! ~DIV/O! Liner 0.000 0.000 0.000 0.000 0.000 O. O00 0.000 0.000 0.000 0.000 O. O00 0.000 :I:i:DIV/O! Production 7.000 7,560.000 8.500 330.00 2.28 752.40 752.40 210.00 1.23 258.30 258.30 0.00 0.00 O. O0 0.00 'i ,010. 70 7,970.40 -410.4 Printed 118/93 Borough: Well: 1H-16 Fieid: Kuparuk River St. I='erm ;92-131 Date 1/8/98 Engr: M. Minder 1H-16RV.XLS Casing Interval Interval Size Bottom Top lA 16 I21 4.! 2A 9.625 2650 4I 3A 7 6876 4i 4A 0 0 0 5A 0 0 0 6A 0 0 0 7A 0 0 0 8A 0 0 0 9A 0 0 0 10A 0 0 0 Description ascription ascription Length Lbs Grade Thread 80 62.5 H-40 WELD 2609 40 L-80 BTC 7519 26 J-55 iTC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Tensior~ Lbs 0 0 0 0 0 0 0 0 0 0 lB 2B SB 4B 6B 6B 7B 8B 9B 10B Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ft psi/ff 9.6 0.499 0.399 9.6 0.499 0.899 9.9 0.510 0.410 0.0 0.000 -0. 100 0.0 0.000 -0. i 00 0.0 0.000 -0.100 0.0 0.000 ~0. 100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi N/A 1640 2523 5750 2523 498O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 BDF ####### 2.3 2.0 #DIVI0.1 #DiVi0! #DIVI0.1 #DIVI0.I #DIVi0! #DIVi0! #DIVI0! Tension Strength K/Lbs K/Lbs 1 C 5 736 2C 104.36 916 3C 195.494 415 40 0 0 50 0 0 6C 0 0 7C 0 0 8C 0 0 ~ 0 0 10C 0 0 TDF 147.20 8.78 2.12 #DiVi0! #DIV/0! 9D~iO~ ~D~ ~DIV~ Collapse Collapse P~Bo~Psi Resist. 48 670 1058 3090 2816 432O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CDF 13.871 2.921 1.534 #DIV/0! #DIV/0! #DIVJO! #DIVi0! ~D~/0~ ~DiV/0~ ~DWl0! CHECK LIST FOR NEW WELL PERMITS ** [9 thru 13] [10 & 13] [14 thru 22] [23 thru 28] Company .~.~_ ~ YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. ~__ 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. NO REMARKS Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is a diverter system required ........................................ ~ Is drilling fluid program schematic & list of equipment adequate ..... ~t/ Are necessary diagrams & descriptions of diverter & BOPE attached .... ~ Does BOPE have sufficient pressure rating -- test to ~~ psig ..... /~z. Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other A//~_ j,,,,7~j~ ['29 thr~ ~1']- (7) Contact [32] geo 1 ogy' DWJ_~]:~:~ RPC~ rev 12/92 jo/6.011 en9ineerinq' BEW 29. 30. 31. 32. 33. FOR EXPLOP~TORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA SHORE 0 --~ -rz ~0 Add i t i ona 1 remarks: ~-~f;~ ~j~-// ,'r /¢ , ~ ~.e~_./~~ . ~ / UM / ~ Exp/Dev ~ Inj MERIDIAN: SM ~ ~ TYPE: Redril'l Re~ WA LTER J. HICKEL, GOVERNOR ALA~I~A OIL A~D GAS CO~NSEI~X~ATIO~N CO~I~ilSSIO~ December 16, 1992 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 'I'ELECOPY: (907) 276-7542 A W McBride P O Box 100360 ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1H-16 ARCO Alaska, Inc. Permit No: 92-131 Sur. Loc. 671'FNL, l156'FEL, Sec. 33, T12N, R10E, UM Btmhole Loc. 1573'FSL, l173'FEL, Sec. 28, T12N, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ,N.A~KA OIL AND GAS CONSERVATION COMMIb,.51ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [~ lb Type of Well Exploratory D Stratigraphic Test r~ Development Oil X Re-Entry D Deepen C] Service C] Develol~"nentGas r"! SinoleZone X Multiple Zone C] 2.. Name of Operator '5. Datum ElevatJon (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 96', Pad 54' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25639, ALK 464 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 671' FNL,1156' FEL, Sec. 33, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1,180' FSL, 1,170' FEL, Sec. 28, T12N, R10E, UM 1H-16 ~H::t~lgfJO6'tO At total depth 9. Approximate spud date Amount 1,573' FSL, 1,173' FEL, Sec. 28, T12N, R10E, UM 12/29/92 $200,000 1 2 Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1H-03 7,560' MD 3,707' ~ TD feet 104'~ 940' MD feet 2560 6~876' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 3,1 39' feet Maximum hole anole 3 6° Maximum~rface 2~523 DsI~ At total doeth CTVD) 3~ 1 26 18. Casing program Settin~ DePth size Specifications Top Bottom Quanti~ of cement Hole Casing Weight Grade Coupling Length MD '~/D MD TVD (include stage data) 24" 1 6" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+_200 CF 12.25" 9.625" 47.0# L-80 BTC 4,293' 41' 41' 4~334,' 4~261' 510 Sx Permafrost E & HF-ERW 440 Sx Class G i i 8.5" 7" 26.0# J-55 BTCMOE 4,376' 41' 41' 4,,~17' 4,326' HF-ERW 8.5" 7" 26.0# J-55 BTC 3,1 43' 4,41 7' 6,876' 7,560' 6,876' 210SxClassG HF-ERW . Top 500' above KuparUk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size -.C~emented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production ~"! 0V ~ 0 Liner Perforation depth: measured ~_S~ 0il '~ {~$ ~0rt$, ~0 true vertical '~['[C~_0_m~~. · 20. Attachments Filing fee X Property plat C] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot C] Refraction analysis D Seabed report C] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is t]'ue and correct to the best of my knowledge Si,ned ~'/~/~ ~~Z Title Area Drillin~ Engineer Date - / - Commission Use Only Permit ~l~,.m5 I API number I Approval date~/,,/~ '~"'-I See cover letter for be. ~ /' 50- OZ~ --~-..,~ ?J ~ ~ Z'~/F'" -- recluJrem,ents -- _ other Conditions of approval Samples required C] Yes ['~ No Mud Iot:i required C] Yes [~ No Hydrot~en sulfide measures r'J Yes r~ No Directional survey required J~J Yes r=J No Required workin, l:)ressureforBOPE .D. 2M a 3M 0 5M C] 10M O 15M Other: Original by order of Approved b~/ Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate , . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1H-16 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,334')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (7,560') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test to 3500 psi. ND BOPE and install lower production tree assembly. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. ^lOV 0 Alaska Oil & Gas ¢'ons. Somrdissiort 4nchorag - DRILLING FLUID PROGRAM Well 1H-16 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-9.6 15-25 15-35 45-75* 5-15 15-40 10-12 9.5-10 +10% Drill out to wei~]ht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD See Well Plan 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. 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 2,523 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1 H-16 is 1H-03. As designed, the minimum distance between the two wells would be 104' @ 940' MD. The wells would diverge from that point. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well ddlled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 55-75 sec/qt to drill gravel beds. Adjust FV to 45-55 sec/qt below gravel beds. Casing Design/Cement Calculations 13-Nov-92 Well Number: 1 H-16 Surface Csg MD: Surface Csg TVD: Production Csg A MD: Production Csg A TVD: Production Csg B MD: Production Csg B TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Mud Weight: Surface Casing Choice: Production Csg A Choice: Production Csg B Choice: Production Casing Frac. Pressure 4,338 ft 4,261 ft 4,417 ft 4,326 ft 7,560 ft 6,876 ft 3,553 ft 6,888 ft 6,331 ft 9.8 ppg 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 4,261 ft {(13.5'0.052)-0.11}*TVDshoe =1 2,523 psiJ Estimated BH pressure at top of target zone Anticipated Mud Weight = Top of Target Zone, TVD = 100 psi Overbalance = :1 9.8 ppg 6,331 ft 3,226 psi 3126 psij Surface lead' Top West Sak, TMD = 3,553 ft Design lead bottom 500 ft above the Top of West Sak = 3,053 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 956 cf Excess factor = 15% Cement volume required = 1,100 cf Yield for Permafrost Cmt = 2.17 Cement volume required =1 510 sxJ Surface tail: TMD shoe = 4,338 ft (surface TD - 500' above West Sak) * (Annulus area) = 402 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 437 cf Excess factor = 15% Cement volume required = 503 cf Yield for Class G cmt = 1.15 Cement volume required =l 440 sxI Casing Design/Cement Calculations 13-Nov-92 Production tail: TMD = 7,560 ft Top of Target, TMD = 6,888 ft Want TOC 500' above top of target = 6,388 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 205 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 222 cf Excess factor = 15% Cement volume required = 255 cf Yield for Class G cmt = 1.23 Cement volume required =1 210 sxI TENSION - Minimum Design Fector8 are: T(pb)=l.5 end T(js)=l.8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production A (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =[ Production A (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 564000 lb 4,338 ft 36.00 Ib/ft 156168.0 lb 22644.7 lb 133523.3 lb 639OO0 lb 4,338 ft 36.00 Ib/ft 156168.0 lb 22644.7 lb 133523.3 lb 415000 lb 7,560 ft 26.00 Ib/ft 196560.0 lb 29052.4 lb 167507.6 lb :2.51 490000 lb 7,560 ft 26.00 Ib/ft 196560.0 lb 29052.4 lb 167507.6 lb 2.91 Casing Design/Cement Calculations Production B (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body)= Design Factor =1 Production B (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg A: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor Production Csg B: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Worst Case - Lost circulation and casing pressure = 0 2. External pressure =Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg A 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =i Production Csg B 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 13-Nov-92 415000 lb 3,143 ft 26.00 lb/fi 81718.0 lb 12078.3 lb 69639.7 lb 6.01 490000 lb 3,143 ft 26.00 Ib/ft 81718.0 lb 12078.3 lb 69639.7 lb 3520 psi 2522.5 psi 1.41 4980 psi 5705 psi 2002 psi 3702 psi 1.31 4980 psi 7004 psi 3182 psi 3822 psi 1.31 2020 psi 0.510 Ib/ft 2171 psi 0.91 4320 psi 0.510 Ib/ft 2205 psi 2.01 4320 psi 0.510 Ib/ft 3504 psi 1.21 Casing Design / Cement Calculations 13-Nov-92 Surface Casing Choices OD ID I b/ft Grade I 9.625 8.681 47 L-80 2 9.625 8.835 40 L-80 3 9.625 8.921 36 J-55 4 10.750 9.950 45.5 J-55 Metal X-Section Jt Strength Body Strength Collapse Burst 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi OD ID I b/ft I 7.000 6.276 26 2 7.000 6.276 26 Production Casing Choices Grade Metal X-Section Jt Strength Body Strength Collapse Burst L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi -,~UPARUK RIVER UN, i' 20" DIVERTER SCHEMATIC I 5 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP~3N WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER EDF 3~10~2 J 7 6 5 4 13 5/8" 5000 r'SI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. ~C)P STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWSARE 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 PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TESTANY 8. CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'I-TOM 9. RAMS TO 250 PSI AND 3000 PSI. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10 CLOSE BLIND RAMSAND TESTTO 3(X)O PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEsT PLUG. MAKE SURE MANIFOLD 11. AND 12. UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 13. DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3(X:)O PSI CASING HEAD 3. 11' - 3(:X:X) PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5(XX) 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 ,?:,RE 8/22/89 CREATED BY : JONES For: D STOLTZ !DATE PLOTTED :6--NOV--92 PLOT REFERENCE IS 16 VERSION #4. iCOORDINATES ARE IN FEET REFERENCE SLOT #1 6. TRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. ~EASTMAN I g 300 _ 600. U - 900_ _ 1200_ - 1500_ - 1800_ (- _ ~ 2~oo_ C)._ _ (~ 2400_ - 2700_ _ 3000_ _ 3300_ _ 3600_ I I V 3900 _ 4200_ - 4500_ 5loc _ 5400_ _ 5700_ 72on 3O0 RKB ELEVATION: g6' B/ PERMAFROST TVD-- 1614- ARCO ALASKA, Inc. Structure : Pad 1H Well : 16 Field : Kuparuk River Unit Location : North Slope, Alaska N .43 DEG W ,e~' (TO TARGEt) TD LOCATION: ] 1 573' FSL, 1 173' FEL SEC, 28, T12N, R10E ITARGET LOCATION: 1180' FSL, 1170' FEL SEC. 28, T12N, R10E TARGET TVD=6331 TMD=6888 DEP=1851 NORTH 1851 WEST 14 ISURFACE LOCATION: 671' FNL, 1156' FEL SEC. 33, T12N, RIOE T/ UGNU SNDS TVD=3116 K0P TVD=3140 TMD=3140 DEP=0 3.00 BUILD 3 DEG / 100' 9.O0 T/ W SAK SNDS TVD=3553 TMD=3556 DEP:4¢ 15.00 21.00 27.00 B/ W SAK SNDS TVD:4061 TMD=4100 DEP:234 33.OO EOC -- 9 5/O"CSG PT TVD=4261 TMD=4337 DEP=360 A/B MODIFIED CSG TVD:4326 TMD=4417 DEP:407 K-tO TVD:4¢96 TMD:4627 DEP:529 AVERAGE ANGLE 35.76 DEG K--5 TVD=5951 TMD=6420 DEP=1577 TARGET TVD=6331 TMD=6888 DEP=I851 T/ ZONE C TVD=6373 TMD:6940 OEP=lB81 T/ ZONE A TVD=6619 TMD=7243 DEP=2058 B/ KUP SNDS TVD--6714- TMD--7360 DEP--2127 TI) / LOGGING PT TVD=6876 TMD=7560 DEP=2244 o 300 600 900 12 0 15 0 i SCALE I : 150.00 ¥~rtl¢ol ~cll0n on 359.57 ozlmu~h ',rlth refarence 0.00 N, 0.00 E from s~ot ~16 ~,, ~ <-- Werl : Ea,l --> 30O 150 0 150 300 I I I I I I I I I I 7400 - -2250 _ -21oo - _1950 - _1800 1500 - _1350 - _1200 - _1050 - _ 900 - _ 750 _ 300 - _ 150 o 150 g West 14-00 1350 1 300 1 250 1 200 11 50 11 00 SCALE 1 : 50.00 1 050 1 000 950 1100 I I I I I I I 130 4-100 900 1 70O 11 3900 1500 300 500 3700 1300 1100 350~ )900 ARCO ALASKA, Inc.. Structure : P(~d 1H Well : 16/17/19/20 Field : Kup(3ruk River Unit Loc(~fion : North Slope, 35O _400 -, _450 _500 _550 _600 - _650 - _700 - _75O ._800 _850 ! ... . Slate: Alaska Borough: W'ell: 1H-16 Field: Kuparuk River St. Perm ;92-31 Da~e I Engr: M. Minder 1H-16.XLS Casing Interval Interval Descriptionescriptionescription Tension Size Boflom Top Length lA 16 121 41 80 2A 9.625 4261 41 4293 3A 7 6876 41 7519 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 IOA 0 0 0 0 Lbs Grade Thread Lbs 62.5 H-40 WELD 0 47 L-80 BTC 0 26 J-553TC MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 !B 2B 3B 4B 5B 619 719 8B 9B 1019 Mud Hydraulic Wieght Gradient ppg psi,fit 9.6 0.499 9.6 0.499 9.8 0.510 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF N/A i 640 ####### 2550 3520 1.4 258O 498O 2.0 0 0 ~D~ 0 0 ~DlVl0! 0 o 0 0 ~D~] 0 0 ~DIVI0~ 0 0 ~DIVI0~ 0 0 ~D~10~ Tension Strength KJLbs 1C 5 2C 201.771 3C 195.494 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/tbs TDF 736 147.20 564 2.80 415 2.12 0 #DIV/O! 0 #DIV/0! 0 #DIV/O! 0 #DIV~! 0 #DIV/O! 0 #DIV/O! 0 #DIV/O! Collapse Collapse Pr-l~ot-Psi 6O 1280 2523 0 0 0 0 0 0 0 Resist. CDF 670 11 2020 1.578 4320 1.71 2 0 #DNIO! 0 #DIVI0! 0 #DIV/0.1 0 #DIVI0! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE Fee Loc [2 thru 8] (3) Admi n [9 thru 13] [ 10 & 13] [14 thru 22] (5) BOPE /~¢~.¢[-/~¢ ~-/-~/~_~ [23 thru 28] Company ~f~ Y\C t~ Lease S YES 1. Is permit fee attached ............................................... ~, 2. Is well to be located in a defined pool .............................. ~ 3. Is well located proper distance from property line ................... _L~ 4. Is well located proper distance from other wells ..................... /gM 5. Is sufficient undedicated acreage available in this pool ............. ~ 6. Is well to be deviated & is wellbore plat included ................... ~... 7. Is operator the only affected party .................................. /~ 8. Can permit be approved before 15-day wait ............................ /¢4 . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Well NO (6) Other ~ 2~l~r~ [29 thru 31] (7) Contact //~///~. ,, ~ [32] (8) Addl geo 1 ogy ' eng i nee r ing: DWJ_.I~ MTM ~ RAD.~~~z RPC '~ BEW rev 08/18/92 jo/~.Oll 29. 30. 31. 32. 33. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & number ............... ................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~o~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... requirements ............................................. Additional Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE REMARKS remarks' 0 -4 -rZ ,---~ 0 m z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED APR O 2 1993 Alaska Oil & Gas Cons. Commission Anchorage bis 'rape Ver.i. ficat.i.o~ I, isti~q ~c~,lurc~ber,~:er A..1..aska, Co~out,!nq C, enter 2-'t?~AR-] g93 09:57 REE:'L: 'I 0 M REEl,., **** TAPE HEADER **** SERVICE NA~!E : EDIT TAPE t'~g't~E : 93013 CONTINUATION ~ : 1 C O t~ ~ f~,; N T : A R C 0 T~PF HE]ADER I~tI.,IPARUK RTVE[.i UNIT A P I i',~ U i~ a E P: OPEPATOR ~ hOG,IN(; COt,,~PA~.tY: TAPE CRE,~TI'.ON DAT"E; JOB I) A T,a ~LEV~TI~q (FT KELLY BIJSF.ING: DERRICK G~f)UhjD R!T RUN 1 930111 I e, o T $ T n .T G 50029223 i ARC(:;.,! AI..,ASAA, INC, SCH h U :t"' B~: I,~ G E R 2 - t4 ~ R - 9 3 3 3 67i 11.56 q6.00 96.0 0 b 4.0 (' 'IS ~em~ Verification =,.chl~mber~er .A]:,as~a Computia¢,~ SFRViCE : FLIC V~:RSIOM : 001A07 D~I:F: : 93193/ 2 ~*,~X REC $:IZE : !,024 F I !,,,K T Y:P:t: : FI[:K HEADER Depth shifted and cl..ipmed curves; al]. bJ, t runs 0,5000 START DEPTH 2671,0 STOP OKPT~4 7411,0 7331.~ 7341,0 7286,0 7297,0 725Q.0 7P6!.0 7906,5 7218.0 710a,O 7114.5 7{)67,0 7077.0 7039.0 7n49,5 6990,5 7000.5 6gq2.0 On07,0 601.7.5 6840.5 6~51.,0 ..F.;ASF[,!NE CUI~VE FOR SHIFTS: Sc~,l. umberger ~].a.~ka Compu. tir,~ Center 993 09: 5'! 6825,0 6835,0 776,0 6786,0 ~722.5. 67,32 . n.. 66¢>2,5 667 ~, 5 6617,0 6626,5 6589,0 65gg, 0 6573,0 6583,0 6539,0 654~, :5 6475.5 64~5.0 6415.5 6424,0 6389.0 6398.5 s34 .5 357.5 6339.5 6348.5 6335,5 634:4,0 63].6,0 6325.0 lO0,O 109.0 E D D A T A .S [') U ~ C E g'RU TOOL CODE BASE Ti.{E DEPTH ADJt~ST~4~N~'~S $~{[)Wt~ ABOVE REFLE',CT ~WD GR TO WIRELINE OP, OF 21-FE~-93, ALi, OTHER Ct~RV.ES v/ERE CA~:RIED WITH ThE dR S}.tI'FT, TiC. F: SA~Pf,Z,[NG TICKS C[I('~TA. INED IN T}ilS EDITED FILE ~.E AT ,5 SA..F, PLING ~RTF, T}.~E SA~'~PL!NG TICKS S LIS F[]f~!A.T DATA ** DATA FORP'AT SP. ECIFIC.~TIU{',i REC,..IRD ** vet i.f.lcation L.i., s t i.. ncl Alaska Computi~q Center 2-M,Ag-! 993 091S7 RHUB ~,I'W D G/C3 DRHO MND G/C3 N~H'.T MWD PU 'RP MWO G e M W [,:, G A P 1, HFNA ~,~WD CPS T~B GTC F', ~wB N~CK NWD $ DTCK ~,.~ W D $ 618985 O0 0 618985 O0 0 6189~5 O0 0 6~8985 O0 0 618985 O0 0 61,8!)85 O0 0 618985 O0 61~985 O0 61~9~5 O0 61.8985 O0 618985 00 618985 O0 618985 O0 618985 O0 618985 O0 618985 O0 618985 00 618985 O0 6189~5 O0 O0 O0 0 1, 1, ~ ~ 68 o000000000 O0 O0 0 1 ! 1, 4 68 o000000000 O0 O0 0 1 ]. 1 4 68 0000000000 O0 60 0 l, 1 1 4, 6,8 0000000000 00 O0 o 1 1. I 4 68 0000000000 00 O0 0 1 1 1. 4 68 o000000000 00~ O0 0 1 1 I 4, 68 O000000000 000 O0 0 I 1. 1 4 68 ~0o0000000 000 O0 0 I 1. 1 4 68 0000000000 000 O0 0 I 1, 1, 4, 68 0000000000 OOO O0 0 1, 1 1 4 68 0000000000 000 O0 0 1. 1, ! 4 68 0000000000 000 O0 0 I 1 I 4: 68 0000000000 OOO O0 0 1 1 1 4 68 O00000000O 000 O0 0 1 ! I 4: 68 0000000000 000 O0 0 1, 1 1 4 68 0000000000 000 O0 0 1 1 I 4 68 000000o000 000 O0 0 1, I 1 4 6~ 0000o00000 ooo oo o , i 4 oooooooooo ooo oo o I DFPT. 7519.5 C ~ b N. t,,l I,,:~ L') - 999.2 ~Gr~. t,~'Wp 211.0 GTCF. t~ w D -999.2 728o.o 275,7 0 0 R ,-t 0 B. ~q w 73 NPH [. ~ W 00 ~4 ¢.'., F' A. Mw 5 :) ~" T C K, 71 w 0 b C,. R, ivi W -999,250 DRHO. ?~wD -999.250 PE~'. M~ID -999,2.50 RA.aWD -999,250 -999.~b0 NSI..q~'O ~ .000 ~S I. P.~'.~D O.nO0 TAn.vWD -99q.~50 ',t' A b:, D. ~: ~'~ D -o99,250 D TC' K, ~'.' ~'~ !) -999.250 RTCK .~ -999 z .... 0 -999,250 -999,250 -999.250 -999,250 3,649 1.q25 0,758 -q99.250 3,052 2,467 1,069 GTC K. H i,,¢ D -9 q,. 9 .25 ..... 0 N'T C K, !,~ W,, D DEPT. 6600,000 CALM. ~WD B. 596 NPH ~0P. MWD 151.668 HEiq~, H~J'D 260.447 HEFA. GTCK, ~WD 1. 000 NTCK. DEPT. 5bno. 0oo CAL~?. y,,u,iD R. 574 NPHI. POP. ~.~,'~ 259. lq5 HEN ~. MWD 27q. 500 GTCK. ~'wo -q99.2~0 '1TCK. ~.IW O DF{PT :;4r~o OO0 RHOk~. .- . · -.- . , , , ~ _ C A [.N. ,'4 W D 8.5 C, 0 t,tpH I.,'; ~ D POP. ~WD 251.5 ~ g GR. ~qt,"O HFNA. mWn 281. 375 HEFA. ~O 09:57 -999.25(, 2.437 DRHO.HdO 39. 766 R,a. f4WO 165.500 NS:I.MWD 5.598 TAB. I4WD -g9q. 250 D'PCK o 2.34'2. DPHO.~4WD 37. 800 5.9'77 -999.950 DTCK.,qwD 2.397 41. 200 ! 05. a t 7 NSI. 5.548 -999.250 DTC ~../4',qI) 2.35g D~HO.Y;wO 3!.300 PA. 'qwLO 78.5t:. 3 ~'tgI. -999.'.250 2.3o2 DP.H f J, :;wD 36. 400 82. 646 ,~S I. 6.315 TAB. -99q.250 DTC~. ;,~ w i.., -99~ . 250 -0.0,12 3.074 0.0 ¢,) 0 ,1. 344 !.. n 00 0.011 1.341 0.0 0 f.~ 0. 462 -999.250 ¢). 02 '7 2.308 0.000 0 359 -999: 25© 0.01,8 2.450 0. 000 0.307 -999.250 0. 008 3.~76 0.006 0.178 -999.250 -0.002 1.11.0 0.000 0.19-1 -999. 250 0.017 I..iB5 0. f) () 0 n.236 -999.250 -0.0!1. 2.10! 0. 000 0.231 I. ~On 0.000 2.!71 0.237 -99a.25o T A B D. N v; D R'r C K, m w P PEF.MW0 RP.M~D TABD.MWD RTCK:.gWD P E F. ~,I W D RTCK. ~,!WD PBF.~wD RMi.~WD TABD.~WD RTCK.mwD PEF'.~D RP.X~O RTCK.MWD PEF.~iWD 'R$I,~WD TABP.~wD [~TCK.~D PEF. R P. ,~ W D R T C K. ,~ W F) PEF. ~ WD [~P. a ,4D RST.~WD TAbD.MWD RTCK. v WD PAGL<: 1. 000 :2.773 3.646 0. 000 2. ,3!2 -999.250 .]. 1,45 I .307 0,000 1.661, -999. 250 4.400 2.409 0.000 0.71'7 1.000 3.719 2.264 0.000 0.680 -999.250 3.1.52 2.906 0. () 00 0. 567 -999.250 3.097 1.655 0.000 0.661 -999.250 3.4,75 1.103 0.000 0.5¢6 -999.250 3.019 2.052 0.000 0.652 -999.250 3.231 2.103 0.000 0.451 -999.250 ..... ~ ~..ao,, Veri. fication histf, nq. .~chlua'beraer. . , , ,alaska Comput. inq. Ce.,.ter' n 284.573 -999.250 000.000 8.562 28 ~, 205 1.000 800.00 o 8. 595 330.792 -9~9.250 ~ 00.000 450. 520 278.000 999.250 DEPT. 4400.000 C/~bN. ~qND 8.562 t.~PH I. g'WD P, OP. ~WD 291, .779 GR. ~.~'~ D EENA.~WD 265.750 HEF.A. ~WD GTCK.~WD -999.250 NTCK.MWO C [b~,:. MWD ,g. 500 ~tP}~l. ~,WD POP. ~¢.,P 247. 236 GR. :4WD ~KN.5. ~w~ 272. [1 O0 F{EF~. ~,~WD GTCO. ~WD -909.25n NTCK, [tWB 2-~ ~. F~- ,1., 993 09:57 33.200 "' F~ tx,. '?;~ v~ ,ii'.) 92.969 ~',~ S I 6.~63 1.000 3 3. 0 ~ A. ~1 O 76.141 6. 840 -999.250 DTCK.~wO 2 ~!23 DRHFi ?~iWD 77.406 NSI.4WO 6.580 T'AB.~WD -999.~50 DTCK.MWD 77. 895 NSI. :,~wD 6.860 T A [;~. '~ W a -999.250 DTCK,MWD 78.681 5.655 TAb. ~,~WD -999.250 DTCK.MWD 2.310 D P Ft ,r). ?4 W D 36. 300 RA. 75.686 -999.250 DTCK.qWO 2.277 33. R()¢I PA. 57. 960 NS]. ~ W [.? 6.497 -999.250 DTCK. ~qwo 2.187 37. 400 64. 400 N,S .!.. 6.208 l. 000 DTCK. :,a Wi) -0.01,6 2.7 o 8 0.000 0.2'78 -9'99. ,2,50 -000J. 0.00() 0. 260 -999.~50 -0.002 2.691 0.000 0.169 -999.250 -0.002 2.029 0.00 o 0.116 -099.250 0,038 2.1,26 0.o0o 0.243 -999.250 0.01,3 2.542 0.000 0.344 1.0o0 -0.019 3.!63 o.ooo 0.264 -999.~5o -0.018 6.C~54 1. 000 O. ?,4R -999.PS0 O.04g 10.5qq 0.524 -999.250 TABD, RTCK. Mwp PEF.~!!WD RP.Y~D RSI.~WD TABD.MWD RTCK.g~D PEF.~D RP.EWD RSI.~4~D TABD.~D RP.~WD PST .,~WD T A ~ D. ~ w D RP.\;wD 3.056 2.556 0,000 -909.250 3.043 2.567 1..000 0.649 -999.250 3.120 2.504, 0.000 0.595 -999,250 3.050 2,400 0.000 0.4.46 1,000 3.83'9 2.033 0.000 0.572 1.00o 3.055 2.538 i.000 0.58G -999.250 3,051 2.998 0.000 0.522 -999.250 2.857 5.221. 0.000 0.914 1.0oo 3.596 12.643 0.fi00 1.030 -90q.250 :,,IS Tape Ver.~,fJ, cat~,on Llst,i.~ 3chlUmberqer ,.,..l,'l, asKa ComputJDg Center D E p ?. 320 o. 000 R H O i!{. ?~ w D CaI.,N.MWD 9.300 NP'HI.igWD P0P. ~WD 505,015 GR. ~..~FM ~. ~WD 243,750 GTCK.N~WD -999.250 D~PT. 3000. 000 RHO C,~LN. ~WD g.676 POP, ~W[) 676,44B GR, NE'b~A. ~WD 258,22b HEFA. ~:'~wD GTCK. }~wO -999. 250 NTCK. NWD D E P ~. ,,?,, 8 0 0.0 0 {,~ P' ". POP. ~WD 5 ! 2. 964 GR. ~WD HE,~A .MWD 245.97b HEFA. kWP C a LN: ~!,,ID 8.705 ~JP.~D -99g.25o I,!Fr~) ~,..~WD 231.500 GTCK, ~WQ /.. ** ET?:;D (3F DATA ** **** FILE FT I.,F' DATF FTI..,E TYPE T.R A I !.,Ere **** EDIT' .00l FL!C O01A07 93/03/ 2 ~,024 **** FIbE FTL~ SERVICE F~II,,~ TYPE L ~.;Sr FILE MD.IT . (.)O2 FLIC OOlAO7 03/03/ 2 2-MAR-!993 09:57 0 061 0.000 0.317 -999. 250 2.097 t:) R H 0. ,~4 W D 0 .. 03 '2 43' 200 pa. gwr') 64.072 23.246 t"<tS,I,, gW D 0.000 4.9~0 TA ~::~. ~WD 0.141 -O99.250 DTCK. YiwD -999.250 36,,00 RA.?4WD 1 !: 5.857 T A [~..?4 W D 0.272 -999.250 BTC K. :,~.'IW D -q99.250 0 064 0.0 00 0.:271 -9qg. 25O PEF. ~u' wD TABD. MWD RTCK,.~WD PEF.M~O RS!.~WD ~TCK.~D PAGE: ,.t '7 90 7:564 1. 000 0,~46 -999.250 5.189 Jl4~,652 !.000 0.643 1.000 3653 0: 739 0.000 0,57~ -999,250 4,45.4 8'409 0,000 0,384 -999,250 -999.250 -999.250 0.000 -999.250 1.000 !,I~ ,rape veri.iSicat, l. on l.,ist:.in~ ~cblumber~'!er 4...1, ask:a Com[.~t.lti..nq Center 2-,',~AR- 1993 09:57 PAGE:: Curves and loq header dat. a for each bit run ~,n sen~arate fJ,,]es. DEPTH INCRI::?~E~T: 0.5000 Ir'ILK VENDOR T[)OL CODE STAkT DEPTH ~A'.FE LOGGED: DAT~, TYPE (YEMORY OR TD [)RILLE~:~ (VT): TOP LOG ,[NTERV~h ~OTTOM LOG INTERVAL BIT ROTATING SPEED (aP~): TOOt,, STRING (TOP Tr] CDR ;4ESISTIVITY ¢O~E[t[:')I,E h~',,,O C~SING DhTa, OPt~?,N H!'.)LE BIT SIZE DP.[I.,L~R$ C&SING D~:PTH gATRIX DENSITY-' DEPTH 74'01.,0 .!,.,0 GOS,, !, 6 . 2 V,4. OC 751.0.0 ~671.. 0 7 51 O. 0 ND$OI. 8 RGS058 a.500 2671.0 ~0.10 2,740 3.0!0 7~.0 67.0 '..,.I'~ Taoe Verifi. cation L;istlnc~ ~chl. U~ber~er /%.laska Computinq Center TOO!:., s'rANt)OFF (I~): .OIT TO aES 41 2 B T['~ (;~ 5J.6' ~'[T Tf'~ Dg~~ 108.4' .. . ' I.T ........ .... , .................... , ........ , . .8IT TO ~"~!EI. JT 1i5 ~' DPI[.,~ED i;NTEp. V?~L 2671' 'to 751o; !'~.AT!~!X DEaSITY i,6~ (a~/CC). FLUID 9ENSITY 1.0 (G~;.~C) RCT.h~I(jNaI,..., Bilbo, DEt~'.ISiTY PROCESSI. NF' f.ISED' a.hRiTE A[)DED 1 66 0 2 66 3 73 60 4 66 1 5 66 6 7 65 9 65 1.1. 66 !,7 12 13 66 0 15 ~6 68 16 66 1 ** SET TYPE - CH/~ ** ~,'~ SF'PV [jN1T S~: VICF' Ami AP! ...... ~'~. S REPR PROCESS DE:P~' .. O0 000 O0 O 2 .. nO00. _o000 R~O~ 1,~! G/C3 61~9~5 O0 OOO O0 0 2 ~ i 4 6R C,C, O00oO000 DPHC I,v;1 G/C3 618985 O0 OhO O0 0 P ~. 1. 4 68 0000000000 PFF I,~; ~ 618985 O0 go0 O0 0 2 1 1 4 68 0000000000 [~CA[, I, ~'11. I?~ 61.89~5 O0 o~0 aO 0 2 1. 1. 4 68 OOO000000o DPNT I., ~' 1 Pi~ 6'! ~985 O0 00() O0 0 2 ! 1 4 6~ TNPN T,,w] pl..~ 6189~5 Oo i)OO O0 0 2 1 I 4 6~ O0000OO000 5chl, umberoer ~],asKa Computing Center 2-MAR-!993 09:57 10 L~ A~ :IL' q' o L R V I. C, I~. A ID ORD~:P e Lr~G PSR LWl 0 F{ !*,,'~ N 618985 O0 ROPF LW1 F'tHP 618985 00 G~ LW1 GAPi 618985 O0 HMNA [.,W1 CPS 61R9~5 O0 HEF~ b~!.. CPS 6:1,~985 O0 T.~B Lwl 61 89~5 O0 W.a, BD I.., W 1 61.8982 00 A P I A P 7. F ]:. b E N u ~,~ i~ i~! !..~ !.: a E P R P R 0 C E 8 TYPE CbASS ~[','][) A][JM[.~ SAf,~P E!.,.ET~vi (,"[]DE: (HEX) ** DATa ** -:.;99.25) DPHI bWl PSR. I.,~ l -999.250 [~DPE. LW!, H E F a. I, W' 1 0. (.) 00 T A B. L W 1. D E P T. 74 o 0.000 a H 0 [,. [, W 1 OCAL.I,Wl 0 152 DDHI.t, Wl HEF'~,. LW1, -999. 250 TAB. I,,W 1 [') 1~ P T 6800 000 iSC~i., ~ l,W ~ 0;276 DSR.[,W1 1.196 ROPE.LWl HFF'a. I_,;,~ 1 6. 202 TAB. l,W 1 DFPT 6600. COO RHOR. Lw 1 PEAT,: L',~ I ,"). !.96 DPHI. b', 1 OSP.LW! 1.~45 Df')PE. Lw1 HKf'a. [,~ 1 5. 697 '.PA g. bw 1, -q99.250 DP Nf:']. Lw ~ -999 250 ,-999.250 T F,~ ~ ~. :t,~" 1 -999:250 211.010 GR.L, wl -999.250 -999.250 TABD. L;~I -999.250 2.510 D~HO. L;:I 0.001 PE:'F.LWI 8.500 TN'PH.LW1 -999.250 ATR.LW1 !,99.967 ~a. l,.,,w 1 76.527 0.197 TaB[).bWl 0.756 2 444 D P H ~"~, r.., W 1 0.009 P 12: 500 TNPH, low 1 26. 700 ATR. Lw 1. 97.299 GR.LWl 70.114 HENA. I,,,W 1 0.436 TA~[).bt- 1 1.069 1 17 2.585 DRP0.LW1 0.000 4.n00 TNPH,LWl 2r~. 00(') ATP.LW! 5.072 Ga.bWl 75.596 1.192 TAB{;~. [,,w 1 2.172 2.450 DRnt'~. L.W t 0.013 PE:F. !.,W ! 2.!,00 T~,PH. L, Wl 41.700 A TR. T,,'.~ I 8.216 GR.Lt~ 1 !15.922 0.350 TABD. I.,W1. 2.405 DRHF). bdl 0.000 4.9,00 ThPH.Lw! 37.100 0.157 GR.b~I 124.o89 C.353 T,~ gi~. 13'~ 1 O.bSg 999.25,,~ 0.000 3.24,9 2.097 -999.250 ~.966 4.308 292.250 2.8~6 2.999 310.750 3.298 1.324 257.000 3.577 2.049 270.250 3.409 2.40~ 271.750 [.,IS 'ra~.e ver.f..~i, cat,!.,on ~ch.l. Umberger Alaska ~omputi.~q D ~Tp T. 6200 ,,, 000 g C A !,,. [, W ! 0. !..49 HEF'~. LW 1 6. 705 DPPT. 6000.000 gC~t,.b~ 1, 0.,177 P,$~.L~ I 1'.565 [.{ E F ,~. L, w 1 5.640 DEPT. 5BO0. 000 DC~,L. LWl O. 143 PS~. L~I O. 987 Ur'~F'~.LWI 5,894 i) ~;7 P T. 56~0,000 D C ~ L. [,,, W ~. 0.009 P.S~.LW 1 2.055 H E~ F a. t., W ~ 6.7 ~ 3 DFPT. 5400. OOO DCAL. LW1, O. go0 PS~.LWI 2.0~3 I~EF.B. LWl 6.9~0 D~PT. 5200,000 DCA[,. [.,W 1 O. 079 PS~.LWl 2. 337 H~P"~.LW1 7,055 p F'p'r. 4, 800. t, 0 O D C A l,. L 'W .! 0.13 !. PS~. Lw 1 2. 475 H F F' l',. t,W 1 6,34,~ [." F', p T, 4600. !') C i~ r,. [, w I ,'). 01 PS~. LW1 _2... 250 HFFa. 1., w 1. 6.75g DFPT. 4400. ()nO DCAL. Lw 1 0.06I ~El;'a. t, W1 6.5~0 D~PT. 4200. ooo or'Ar,, l_, ~,~' !. 9. ()OF,, Hwr;' a. L ',,.~ 1 6. 259 nt: er [~ blOB ROPE np f41. ROPE. '?AB. PI'lOB, ROPE. ~HOB, ,~PHI, ROPK, L W !. Lw 1 LW 1 L W 1, I,,W 1 b w 1 LWl i,,w 1 LR ~. [jV! 1 LW 1 bw I L W 1. b W 1 LW 1 Lw 1 2 -'{,;i A'R - !,. 993 09: 5 '1 10. 1:87, O, 21, 0. o. 2. 17 222~ O. 2, 266, O. 2, 17 0 . 17. 21,5. O. 17. 1 a2. O. 2. 296 . 0. 2. 4,57. 0. 2. 19. 322. f). 2. 22. O. 481 r) .~? H [), L w !, '2., 00 T 336 GR, LW 17 4 TA,gO. 90 () T t,t P 3 q 2 357 DR Hf',J'. L,w 1 259 334 O~HO.,bW! J, 00 T F,~ P H. [, w' l 179 TABD.[,WI 362 I) ~; H O. L ~ 1 52 ? 228 T~Bi).bWl 357 D~HU, L, W1 700 T ~:! P 'H, L W 1 161. Ga.LWI 261 TARb. LWI 356 PaHO.L~i ~?0 Ga .bwl 351 DRHJ.bwI 1. O 0 T ~} F' ~4. f,., ~i '1 10 q 6; R. L '41 235 30 l DE 20~ {'I ~ .. , 776 ga. Lw1 120 325 700 073 G~. L,,'~ i 125 260 500 T !"l P It. I_, W ], 783 GR. t.,w 1 0.023 3 4.3 ('! 0 ,86.669 O. 560 0.01,7 :1..700 9 g. 447 0.65a 0.011 37.5(,)0 t~.663 n.584 -0.009 32.700 75. 406 0.567 0. ¢) 06 32,600 7B, 967 0,507 -0.004 31.600 93. ~47 0.52t 0.003 30,700 86,089 0.586 0.01~ 36.400 80.059 0.592 0.0o1 33. 500 '17. 392 o. 4.5O - 0.00 8 34..4o0 77.9.5.3 c). 465 0.0O9 34.. 3 r.) (., ~3.08r) o.711. PEF. LW 1. A T R. L W 1. H. E 'N~ A. L w I P E; F. [, W 1 ATR.L~I HENA .L;W! P E F. t, w ~ H'E ~v A, L W 1, PB:F'. L ATR.L~I H E !,~A. [,, W 1 P~?F. 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I 55 2.27 4 2 2.8 C 0 63~. 715 0.096 30.400 T~,~PH.bWl 500. ~43 GR. hw 1 0. 267 TABD. l.,W,1.. 2.180 DRB().L~I 28.500 TNF,~t.bW1 '999.250 GR,BWl '999.250 TAB[).I.,~I -09q.250 -99q.250 -999.2b0 GR.LWl -099.25a TAFO.LM1 0 0 0 !t 63,4 (:;' 7 0.515 0.009 35. 700 74.835 0. 938 - 0.01 'l 37.~0o 44..47 3 O. 838 -0.0o4 3 ~. 300 56.603 O. 873 0 O04 42 1000 23. 766 0 .. 648 0.04~ 3. ! 0 0 ~.78a o.3~2 -0.011 43. 400 44.974 0.51,6 -0,363 50.300 -999.250 -999.250 -~9q.250 -099.250 -q99.250 -999.250 PEF'. LC; 1 PEP'. [~'~ 1 A'I:R. L~I HE~,3 A .I,Wl A 'I'R. I:,~ 9i ! H E,~q /x . 1.,~ 1 PAGE: !2 2.815 3,03,,4! 270.750 ].100 5,106 275.500 2.798 26'7.750 2.964 5.809 256.250 5.372 72.510 252.75O ~.q.545 ~71.336 2,9~7 8.593 256.000 -909.250 223.200 -999,250 -999,2~0 O,O00 !IS Ta~e Yerlfication bist, ino Scblumberq'er Ala$~<~ Computino. Cent~er 13 Curves amd ,1, oc.! header dat:,a for each bit run I,n separate fil. es. VENDOR TODL CODE 8TART DEPTH CDR 267 ~.. 0 C.Obl 267 ~, 0 LOG ~[:ADER DATA O~TE bO(;~Eg: SOFTW.~RE: SURFACE SOFTWARE VERSIi.]H: DOWNHOb[z; 80~'TWAR~j vzas.[or,~: PATA TYPE (~Ea[.']RY Op, RF~AI.,-TI~E~: q'D DRILLER (FT): TOP I.OG I~.;TEPV~.I., (FT): POTTO~ LOG INTERVAl, PIT ROTATING SPEED HC)L[C INCLINATIOr4 CDEG) '.!'-qOb STPI~'!G (TOP Tr) gr!TT,','.'.)~) Vw_.HDOR TOOl., COD[-: Tr]DI, TYPE C [.) ~'~ _ T i~ ORDSI TY CDR PES rsr.[ V.!. T ~ STOP DEPTH 7401 · 0 I 0-. J A !.J- 9 3 LOGO.e,- 1. 6 . 2 WAST V4. OC 7510.0 267!.0 7510.0 ~,:1[$ TaPe Ver,lflcat~,on ;,chlumberqer Alaska ComDtltJ.,~,n,.g Center 2-~'~: A R- 1, 993 0g:57 PACE: , 4 $ OPEN N[!I,,E git SiZE DRILLERS CASIN[; DEPT~.~ ~.I.,]D DENSITY (.bB/G) ~.I.iD VISCOSITY (S) St..ID PH: ~ I,t' OC H 5 0 R I t') E $ t P P FLUID '~,,O,S8 (C.!): RESISTIVITY ((3H~M ~T TE~PE~ATI,,IRE DEGF) ~UD AT ~'~EASi,,IRED TEMPERATURE (~'~'~T): ~[,.ID .AT ~<~AX CIRCI..J[.,ATI~G ~UO FILTRATE AT '~'.~U'D CAKE AT NT ?~TRiX T[')OL STANDOFf' (II~): FREQUENCY (HZ): ~,500 2671,0 2.740 3.010 78.0 67,0 2,65 8,500 THIS Fit.,E CONThlN8 THE SAMPLING TICKS FRO,~' RU~,: 1. THIS DAI'A IS ~S CLOSE TI] T~'~E ACTUAL RATE OF AQt.iISITI[)N $ ** DATA P'ORO.{AT SP.F...CIF'ICAT!O~ RECORD ** ** SET TYPE - TYPE R~P~ C(.ID ~ V~I,UE ImlmIlIIIIlIIIIIIIIlIIIIllIIII 2 66 0 3 7.{ 20 4 ~6 1 5 60 ~ 73 7 65 8 6~ 0,5 q 65 ~T 1. I 66 ~1 12 6~ !'~I$ TaDe verJ. f,.:,i, cat:Io~ List:J. nq ~c~,lumberger A].aska Com,,pLltl. Dq Celt, er 993 09: 57 15 I4 65 ~T 15 66 6~ 16 66 !, 0 66 I ** SET TYPE - C~.RN ** A,.~ SKR¥' UMIT SE~Vl. .a , AP:I: :ID DRDER # LOG TYPE CLASS ~OD NI,,]~ Slap Ei,,,Ea CODE {HEX) Fg'T FT ~1~985 00 000 00 0 3 ! ~ 4 68 0000000000 GTCg: ~P $ 61,89~5 O0 000 O0 O 3 1, I 4 6~ 0000000000 aTC~' M~:D S 6189a5 00 000 00 0 3 I 1 4 68 0000000000 DTCK ~WD $ 610985 O0 00O 00 0 3 1. 1 4 68 0000000000 RTC~ ~i,!D S 6189$5 0O 000 00 0 3 1 1 4 68 0000000000 * * D A T ~ * * pi:pT, 7519 500 GTC:K.:iW[> -999.250 NTCK.HWD DEPT. 7400. 000 GTCK. e,~wO -999. 250 NTCK. ~,.'l~,;t) ~TCK. ~.WD -999.250 DE:PT, 7200.000 GTCK, ~IWD -999,250 NTCK. ~,~WD RTC~ , ~4WD !, 000 l')'~ P'T'. 7000.000 GTCK. YJWE -990.250 NTCK.MWD RTCK. ;~ WD -999. 250 DFP"I'. 660(;.on0 GTCK.q~.~D I..000 ~',~TCI<.}9~w,r) t)~PT. ~-40(}. 000 GTCK.~4wD -990.250 NTCK. ?![,'D ¢"r CK · ~.iCD -':}99. 250 DFpT. 62oo.oo0 GTC'K. ~.iw D ! .q()O NTCK. ?lWl') RT. CI< · '~'. l,~ r~ -999,250 '999. 250 0TCK. ~,w!) -999.250 -990.250 :OTCK. ~4 ~O 9'~' 9. 250 - . .O!CK. I ·000 DTCK.r4WF~ -99~.250 DTCK.MWD -99q.750 -999.250 DTC~.MwD -999.250 1,000 -999.250 1.000 -999.250 -9~9.250 -999.250 -99~,250 =999.25C ~c'hl~.]mber.r..,ler Alaska Comput:~.nq Centmr RTCK. ,~,~WD -99g. 250 ~ ':r,, c ~. M w p - 9 c~ 9,250 DEP'~. 5200.000 RTCK. b~,'W D -909. 250 DEPTo 500¢)°000 GTCK.,MWD ~TCK. MWD -999. D ~:: P ? o 4800,000 G T (7 K, M 'w' D [~TCK. ~wD -999.250 i} E P ?. 4. 400 000 (., 7 C,. !,{ 1~ D .'T.' ' ~WD 1.000 ~TFK ~'~'D "9gc~.250 D E P T. 4000.0 n 0 G T C K. t,,~ W D RTCK. ,~'.~, W P -999. 250 I}1~: PT . 360(.) . 000 GTCK'. .~.,~ ,,i .., t~ (.~'. ~WP -9~9. 250 L,E PT. 3 ~'t 0 (). 00(..t RTCK. I~.~WD -g99. 250 DJ?PT. .'._~ 200. 000 G'PCK. MW D kTCK. ,uND 1. 000 F F p"r. 3 (.) 00.0 O0 (;TCK. ,qw ~TCK. PW!) -99q. 250 DMFT. 2 ,.gO 0. !)OO GTCK. !,,~' I,i D RTC~. ~'.' ~.-' P -9gq. 250 l,~Wp?. 2600. 000 G'rCK. ~'~w[) R'rC~, . ~'~7~ -999. 250 p W P 7'. 2590.00 .,j G T C K. i,",, w 00:57 1 o 0 (,'~ 0 b, 7 (.,, K . 'iq W D - . ........ ~'.'..'., W D 999. 250 qTCK. .... I. 0 () 0 i'i T C I<. ,,',4 w P - 99 q , ~ 50 N ? C K . :~ W i) -999.250 NTCK.M~O NTCK °099.250 NTCI< . [~4Wl; 1,, 0 {) 0 N T C I<. ~,! w -999.250 NTC~.MWb . ' "n .. -999 25~., 1 . 000 NTCK o ;",','iD ,50 .... -99q. 2 NTCK. MWD -999.25o NTC~,:. MWD =999.~50 slTC' K. t,'~ W L', -ogo.25n HTCK.~.{~D -q99.25() -999.250 -o99.250 -g99.250 -999. 250 -999.250 -999.250 -g99.250 -g99. :!50 1,000 -~99.25{) -99o. 250 -999.250 -q99. 250. 1. r) 0 () -99g.250 DTr'~ tviND DTCK. ,~4 D T C K. M W D t., q. C ~ 'W P 0 T C ~. ~ W D D T C K . ~'~ N D D T C K. ~ w P DTCK. ~WD D T C K. ~.~ ~,i D DTCK .,~ ZD DTCK, ~.~ ~-; P t.)TCK . MWD P A (; E: 16 -9c~9 25o 1. , 0 0 0 -999.250 -999.25() -999 25) -999.25G, -999. 250 -999. 250 1. 000 -999.250 -999. 250 -999.250 -~g9.250 -999.250 -999.250 -999.250 1.000 -999.250 'IS TaPe \rer]..f~catJon I,,~ist~i. Dq ~cbl?~mber(~er A!ask~t Co.~PutlDq Ce~ter 8~V ICE : FL, IC VER$IO~.:~ : O0.iA07 DAT~ : ~'~AX REC SIZE : 1024 FIL~i T'YPE : bAST FIhE : **** FILE F!bE N~,E : EDIT .004 ~ERVlCE : ~LIC VERSION : 00~A07 1') ~ T ~! : 93103/ ~AX RFC SIZM : 1024 FILE TYPE : bO LaST FII, E : EDITED ~ERGED MWD DePth Shim!ted and Clipped curves~ 81,1 bit runs merqed. DEPTH INCRE~sE~T 0.5000 # wr~u TOOL, CO[)E STAg(T DEPTH CDR 6950.0 CI.IKVE SHIFT DATA (~,~EASOREf) DEPTH) ~[J TOOL STOP DEPTH .......... ~70UIVALktNT I!~JSHIF'TK['., ~.~]PTH- ......... TH!.g Flit.,[] Cfl!',1TAT.,'iS Ft.IHANCF:[? ~F.SOL!..'TIO.~.i RE.,SISTIVTY DaTa. $ ~chl. um'beroer ~.lasKa Com~:~tJ.n~ Center SPEC SET TYP[;- 64EB ** ~.. '~ ' .. P D 2 66 3 73 28 4 6 ~ 5 6 '73 7 65 8 68 0,5 9 65 FT i 1 ~6 36 12 13 66 o 14 65 15 66 16 66 0 6~ ** SET TYPE ,., C!H,~M ** ET 618985 dO 000 O0 0 00~ OHMF~ 61,~985 O0 000 O0 0 001 r3 ~ ~,~ ~618985 O0 000 O0 0 001. OH~M 6189a5 O0 000 oo 0 001 t3 H a.~.~61a'~85 Og 0o0 O0 0 001 OHgg 618985 O0 OOt) O0 0 GO1 (')N ~ ~ 61R985 O0 UO0 O0 0 ** DATA ** DF~T. 7477.5no hTP.['' . 0(.) 1 P$[fP. O01 2. ~t4g ATV !{. OC 1 O F..'p T. 7400.0O0 .~TPa. t,.)01 PSF~.O01 1 .503 ATVR.0Ol 2.545 PSPq.001 2.352 ATFP.O01 2.7o! PSV~:.O01 2.489, 1.545 PSP~l. O0]. !.4'15 ATEP.O0] 1.552 PSVo.O01 1.4a4 2,659 1.575 15 Ta, p,,.e verlff, cat, ion ;chl. U~,berqer ~lask:a Computl, nq Center D, ~'; P T . 7 2 0 0 . 0 0 0 ~ T P H . 0 0 1 PSER,OOJ, ~.532 ATVR.O01 DF:PT, 6950.50[) AT. PH.OOf PSEP.OO1 5.117 ATVR.001 2-P!.hR-1993 00:57 2,40 1 PSPH. Ofl) l 2. g ~ 3 P $ P ~', 0 o ,1. .4.224 ~ $ t! R. 001, 4,84~ PSVR.O01 2.356 2.752 024 5.34! ATER.O01, 4.932 2,5~5 3.660 5.025 **,** FT I..,E FIT.,~.:. N~ME : EDIT .004 SFiR'V ICE : FLIC VF~SION : 001A07 OaT~ : 93/03/ 2 ~I,AX REC SiZE : 1024 FILE TYPE blST F I [,.,~] : SERVICE NA~E : EDIT O/~TE : 93103/ 2 T~PE NA~E : 9301,3 CO~TI. NU~T!ON ~ : 1 P~ F;V IOt. IS TAPE CO~t.~EN'I.' : ~RCO a[,ASKA, INC,,WI.!PApt..IK RIV~TP UN'IT,J.H-],6,50-029-22315-O0 **** REEl., TRAI[,E~ *.*** DaTF : qB~f)3/ 2 ORI~I~ : wblC P~TEI.., ~,tA~E : 93013 P~E.V IOU8 ~ EE!., : CO?~E~'r : ANCO ~,I,ASK~, INC.,KUPARi. K RIV~jP ~NIT,l.~-!6,50-029-22315-O0
