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199-034
RECEIVED • l JUN2 9 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION &(,,,,C, . WELL COMPLETION OR RECOMPLETION REPORT AND L la.Well Status: Oil❑ Gasp SPLUG❑ .Other ❑ Abandoned 0 , Suspended LI lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 • Exploratory ❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or,sfl(/.14.Permit to Drill Number/ Sundry: �j ,,� � 199-034 /3�7- (3 ConocoPhillips Alaska,Inc. Aband.: 5/6/2017 II �� 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 4/29/1999 50-029-22942-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1659'FNL, 1277'FWL,Sec 12,T11N,R10E, UM 5/17/1999 KRU 1C-23 • Top of Productive Interval: 9. Ref Elevations: KB:95 17. Field/Pool(s): 278'FNL,2293'FWL,Sec 8,T11N,R11 E, UM GL: BF: Kuparuk River Field/kuparuk River Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: Pitt 235'FNL,2587'FEL,Sec 8,T11N, R11 E, UM 13458/6400 • 28242 as(oy9 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 562285 y- 5968578 Zone- 4 13975/6718 - ALK 2292 TPI: x- 573474 y- 5970062 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 573874 y- 5970109 Zone- 4 N/A 2268/1805 5. Directional or Inclination Survey: Yes ❑ (attached) No Ill 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) 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 t8451 JUL b+ 9 n q7> l 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT HOLE SIZE CEMENTING RECORD CASING FT. GRADE TOP BOTTOM TOP BOTTOM PULLED 16 62.6 H-40 34 121 34 121 24 9 cu yds High Early 9.625 40 L-80 33 8894 33 4573 12.25 1260sx ASIIIsx Class G 7 26 L-80 38 13960 38 6712 8.5 300 sx Class G 24.Open to production or injection? Yes ❑ No D 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; Date Perfd): 3.5 13504 13437 all perforations squeezed off ft(3garJnrJy) --r4-*moi .(.1 7;\'TE' 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. .(91.‘ 111- Was hydraulic fracturing used during completion? Yes❑ No 0 ERIFIFD Per 20 AAC 25.283(i)(2)attach electronic and printed information 1.k DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 13458-13660 30 bbls 16.5 ppg Class G 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: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-HourRate Form 10-407 Revised 5/2017 l�L �/ j CONTINUED ON PAGE 2 Submit ORIGINIAL only t77117 RBDMS (, J�1L - 6 1017 • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 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 2 Permafrost-Top SURFACE SURFACE If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 2268 1805 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. Formation @ TPI- Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results. per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: James Ohlinger Contact Name: Mike Callahan ✓� /dg//7 Authorized Title: Staff CTD Engineer Contact Email: mike.callahan(a)_cop.com SutnorizedContact Phone: 263-4180 Signature: Date: 4.4107 • INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion 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 la: 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 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123),Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. 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. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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 5/2017 Submit ORIGINAL Only • • 1C-23 DTTMS-JOBTYP SUMMARYOPS 4/27/17 DRILLING Continue milling cement, Mill down past TT to 1517 without encountering hard cement. Consult SIDETRACK town. Roll well back to seawater. Pressure test. Injectivity test. Pump in IA to remove gas and well bore fluids. Trip out for under reamer 4/28/17 DRILLING Trip in with under reamer. Make little progress with many stalls. Trip out to inspect BHA. some SIDETRACK indication blades were extended. Trip in with back up reamer and back up motor. Still slow going. Add .5% 776 to milling fluid 4/29/17 DRILLING Under ream 13519 to 13526. Stall at 13526, unable to work past. POOH underreaner damaged. SIDETRACK Left lower blades partial internal and external houseing in hole. Call out slick line to fish 4/29/17 DRILLING RAN SEVERAL MAGNETS RECOVER 1/2 OF INNER MANDREL, RECOVER 3/8"x 2" SUPPORT- RETAINING PINS, RECOVER SMALL METAL CHUNKS FROM BTM OF 6" MILLED HOLE IN CAPITAL CEMENT @ 13526' CTM. TAG BTM W/2.58" GAUGE RING @ 13,521' SLM, RIG DOWN. 4/30/17 DRILLING Running slickline to fish under reamer parts left in hole SIDETRACK 5/1/17 DRILLING Make multiple slick line fishing runs. Recoverd part of inner fork mandrel and cutter blade pin SIDETRACK 5/2/17 DRILLING Continue SL run#15 w/2.5" bailer, set-down at 13,486' & unable to pass, SL run#16 w/2.70" LIB, SIDETRACK set-down at 13,441 w/no marks on LIB, SL run#17 w/2.60" gauge ring & scraper brush, run to TD of 13,521', RIH with 4.2" nozzle, tie-in for-10' correction, flush hole, pump multiple sweeps at max rate, POOH & PU BHA#5 camera, RIH with camera and pump away—80 bbl lake water in attempt to obtain visuals with no success. 200 bbl of filtered fresh water arrived at rig (23:45 hrs) & 50 bbl of methanol on the way. 5/3/17 DRILLING Circulated fresh water and,40 bbl methanol, obtained video of fish at 13,526' from different depth SIDETRACK and orientations, POOH, looking for holes in tubing (none observed), LD BHA#5, perfrom BOPE test, PU BHA#6 Cement run, RIH and await SLB cement truck. 5/4/17 DRILLING Continue RIH with BHA#6, tag bottom, lay in cement as per procedure, contaminate down to SIDETRACK 13,450', POOH, PU BHA#7 pilot-hole milling assembly, begin milling pilot-hole to 13,473'with ROP = 65 fph, decision made to PUH, ciruclate and allow additonal cure time, RBIH and begin milling to 13,478', see improvement though ROP still high at 45-50 fph, PUH to allow additional cure time. 5/5/17 DRILLING Circulate wating for 24 hr cement cure time, mill pilot-hole from 13,483', stalls at 13,498', re- SIDETRACK orient TF to mill by 13,500', a bit grabby from 13,528'-13,530', TD pilot-hole at 13,625', good ROP througout milling, 15-25 fph. dress pilot-hole&transition as per procedure, dry drift pilot hole, POOH, flow-check well, LD BHA#7,jet stack. 5/6/17 DRILLING PU BHA#8 Caliper, RIH &caliper/CCL log pilot-hole, POOH & LD BHA#8, PU BHA#9 WS SIDETRACK Setting Assembly, RIH and set TOWS at 13,395', HS, LD BHA#9, PU BHA#10 Window Milling Assembly, RIH and begin milling window in 7" casing. 5/7/17 DRILLING Complete milling window in 7" casing, BOW called at 13,599.6', dress window, POOH & LD BHA SIDETRACK #10, PU BHA# 11 Build Dirlling Assembly, RIH, tie-in for-9.5' correction, drill build to 13,845', POOH, LD BHA# 11, PU BHA#12 "A" Lateral Drilling Assembly, tie-in for-10.5" correction, drill from 13,845' - 13,896'. 5/8/17 DRILLING SID Continued drilling "A" lateral from 13,896'— 15,121'. Performed WT's 14,346', 14,422, 14,584', 15007', and a window wiper from 15,121'to begin pumping new mud system (struggling with weight transfer). Experienced aired up mud at approx 3:30 am, allowing time for de-foaming agent to circulate resolved issue. • • 5/9/17 DRILLING SID Continue RIH from WT, lose ability to stop down-hole progress of coil, trouble shoot, replace injector stick (good), swap to new mud at 13,602', drilled from 15,121' to 15,400'with multiple pick ups, poor weight transfer and slow drilling. 5/10/17 DRILLING SID Drilled from 15,400'to 15,776' Drilled slowly with poor weight transfer from 15,400' to 15,497'. Trip for an agitator, POOH & lay down BHA#12 over a dead well. Function test BOPE. PU BHA #13, agitator with 1°AKO motor, RIH, Tie in and drill from 15,497' to 15,776'. • • 1C-23 Proposed CTD Schematic DS-nipple at 486'(2.875"min ID) 16"62#H-40 shoe 3-1/2"9.3#L-80 EUE-Mod 8rd Tubing to surface at 121'MD 3-1/2"Camco 1"KBMM gas lift mandrels at 3537',6295',8214', 9-5/8"40#L-80 shoe 9922',and 11,475'MD at 8894'MD 3-1/2"Camco 1.5"MMM gas lift mandrel at 13,350'MD W-nipple at 13,395'MD(ID=2.812") Baker KBH-22 anchor seal assembly at 13,436'MD Baker SB-3 permanent packer at 13,437'MD( ) D-nipple at 13,492'MD ' " (2.75"min ID, ad out to 2.80 for L ) 3-1/2"tubing tail at 13,504'MD mrimmie C-sand perfs 13,537'-13,587'MD 1C-23AL2-01 wp01 TD i 14,925'MD Liner fop©13,500'MD - +acew KOP @ 13,595'MD 1 C-23AL2 00' MD Liner top-13,800'MD 1C-23AL1 wp01 • .>.. -ar-r'- -_ TD(d1 16,475'MD --- "'---'" Liner top©13,660'MD 7"26#L-80 shoe at 13,960'MD 1C-23Awp05 TD @ 16,600'MD Liner top©14,000'MD 114 •rations Summary (with Timelog •ths) 0 1C-23 ConocoPhii 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) 4/25/2017 4/25/2017 5.00 MIRU MOVE • MOB P Continue rig down check list 0.0 0.0 06:00 11:00 4/25/2017 4/25/2017 1.00 MIRU MOVE MOB P Trucks on location,Load shop,Unspot 0.0 0.0 11:00 12:00 modules and jeep up for move 4/25/2017 4/25/2017 4.70 MIRU MOVE MOB P Left 2Z @ 12:00-Arrive on 1C pad, 0.0 0.0 12:00 16:42 De jeep and prep to spot modules 4/25/2017 4/25/2017 1.30 MIRU MOVE MOB P Modules spotted,Safe out location, 0.0 0.0 16:42 18:00 Lower stairs and prepare landings 4/25/2017 4/26/2017 6.00 MIRU MOVE 'MOB P Crew change,Berm cellar,Rig up 0.0 18:00 00:00 putz,rig up cellar,Spot up shop and half way house,Rig up steam.Work Rig up check list,Check tree bolts, Nipple up stack 4/26/2017 4/26/2017 9.00 MIRU WHDBOP BOPE P Rig Accept @ 00:00,Start full initial 0.0 0.0 00:00 09:00 BOPE test.Test witness waived by Matt Herrera,AOGCC.One TIW fail/pass. 4/26/2017 4/26/2017 2.30 MIRU WHDBOP MPSP P PJSM.RU valve crew lubricator and 0.0 0.0 09:00 11:18 pressure test.Run in and and retreive BPV.RD Lubricator.Clear floor. 4/26/2017 4/26/2017 1.70 MIRU WHDBOP OWFF P Observe well.30 psi built up on MP 0.0 0.0 11:18 13:00 line.Bleed to zero.Pressured back up to 20 psi.Bleed again to zero. Stabilized.Observe fluid column. Seeing some fluid movement.Suspect pressure from IA bleeding back into tubing through known tubing leak. Prepare to pressure deploy milling BHA. 4/26/2017 4/26/2017 2.50 PROD1 RPEQPT PULD P PU milling BHA#1 with 2.80"D331 0.0 0.0 13:00 15:30 mill and 0.9°AKO motor.Stab PDL and test to 1500 psi.Continue pressure deploy.Test BHA.Not reading VSS(vibration). Made decsion to change out tools. 4/26/2017 4/26/2017 2.00 PROD1 RPEQPT PULD T PUD BHA#1.Change out tools PD 0.0 62.5 15:30 17:30 BHA#1,M/U to coil and surface test. BHI NPT 2 Hrs 4/26/2017 4/26/2017 2.50 PROD1 RPEQPT TRIP P Trip in well,EDC open,test HOT on 62.5 13,225.0 17:30 20:00 way in 4/26/2017 4/26/2017 0.30 PROD1 RPEQPT DLOG P Log K1 for-.5' 13,225.0 13,270.0 20:00 20:18 4/26/2017 4/26/2017 0.80 PROD1 RPEQPT TRIP P Continue in displacing to used 8.8PPG 13,270.0 13,409.0 20:18 21:06 milling fluid.Attempt to bleed IA from 850PSi,Tracking with tubing,Out density @ 8 PPG with gas and crude shows,Maintaining 1 for one.Needing -900 PSI WHP to maintain,1.87 BPM, BHP=4448 Returns to TT 4/26/2017 4/26/2017 0.10 PROD1 RPEQPT TRIP P 13409',Close EDC.Out density still 13,409.0 13,409.0 21:06 21:12 light @ 8.2 PPG,PUW=38K 4/26/2017 4/26/2017 0.70 PROD1 RPEQPT TRIP P 13409 continue in to dry tag TOC, 13,409.0 13,438.0 21:12 21:54 Initial tag @ 13428,PUH bring pumps on 1.79 BPM @ 4229 PSI FS,see weight @ 13431 and stall,P/U and restart.Out returns still light-8PPG Page 1/35 Report Printed: 5/30/2017 :. •rations Summary (with Timelog Depths) 0P 1C-23 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) 4/26/2017 4/26/2017 0.90 PROD1 RPEQPT CTOP P Suspend pumping,PUH and pull 13,438.0 13,376.0 21:54 22:48 returns from TT.Bleed annulas from 1050 to 300 PSI.Tracks right back up 4/26/2017 4/26/2017 0.40 PROD1 RPEQPT TRIP P RBIH to mill cement 13,376.0 13,438.0 22:48 23:12 4/26/2017 4/27/2017 0.80 PROD1 RPEQPT MILL P 13438,Mill cement,1.75 BPM @ 4511 13,438.0 13,475.0 23:12 00:00 PSI FS,ROP 47 FPH with 1.1K DHWOB.Returns weight coming up, Able to bring returns inside 4/27/2017 4/27/2017 0.10 PROD1 RPEQPT MILL P Continue milling cement,1.79 BPM @ 13,475.0 13,480.0 00:00 00:06 4511 PSI FS,ROP=40-55 FPH, Stalled @ 13480 4/27/2017 4/27/2017 0.30 PROD1 RPEQPT MILL P Stalled,PUW=38K, Reset and go 13,480.0 13,492.0 00:06 00:24 back to milling,1.79 BPM @ 5010 PSI FS-Attribute circ pressure increase to 8.8 PPG fluid coming back 4/27/2017 4/27/2017 0.50 PROD1 RPEQPT WPRT P Mini Wiper,Get fluids to clear up. 13,492.0 13,492.0 00:24 00:54 Density down,PUW=32K 4/27/2017 4/27/2017 0.20 PROD1 RPEQPT MILL P 13492,Milling,1.79 BPM @ 5010 PSI 13,492.0 13,501.0 00:54 01:06 FS,BHP=4759 4/27/2017 4/27/2017 0.20 PROD1 RPEQPT WPRT P PUH,PUW=32K,Attempt to bleed off 13,501.0 13,501.0 01:06 01:18 IA from 1800 PSI,WHP=1100 to maintain 1 for 1,IA pressures right back up from 1000 PSI 4/27/2017 4/27/2017 0.30 PROD1 RPEQPT MILL P Consult town.Back on bottom milling 13,501.0 13,516.0 01:18 01:36 with reduced pump rate 1.42 BPM @ 4399 PSI FS,ROP 35 to 55 FPH, Decide to PUH above cement top and roll well back to seawater.Cement quality in question 4/27/2017 4/27/2017 3.00 PROD1 RPEQPT WPRT T PUH to 13400,PUW=30 K,Open 13,516.0 13,400.0 01:36 04:36 EDC.Get pits lined up to go back to seawater,call out additional seawater, 4/27/2017 4/27/2017 2.30 PROD1 .RPEQPT CIRC T Roll hole back to seawater.Density 13,400.0 13,400.0 04:36 06:54 out continuing to increase.Once density even in and out,close well in. 4/27/2017 4/27/2017 0.80 PROD1 RPEQPT SIPB T Monitor well pressures.Pressure 13,400.0 13,400.0 06:54 07:42 stabilized at 1550 psi WHP,and 1770 psi IA. 4/27/2017 4/27/2017 0.30 PROD1 RPEQPT PRTS T Start injectivity test.Bring well 13,400.0 13,400.0 07:42 08:00 pressure up in 250 psi incriments to 2300 psi WHP,and 2500 psi IA pressure.No leak off observed. 4/27/2017 4/27/2017 2.50 PROD1 RPEQPT CIRC T Line up to the IA.Circulate SW into 13,400.0 13,400.0 08:00 10:30 the IA to fluid pack.67 bbls put away. Stopped periodically to moitor pressures.No significant reduction in Tubing or IA pressure. Saw checks not holding.Close EDC. Lower checks not holding.Bring rate up and flush BHA.Close well,bleed off pump pressure.Checks holding. 4/27/2017 4/27/2017 0.80 PROD1 RPEQPT DLOG T PUH.Tie-in to the K1 for a+1 ft 13,400.0 13,400.0 10:30 11:18 correction.RIH and log CCL down to 13506 ft.(CCL 50 ft behind the bit). No 7"collars logged. Page 2/35 Report Printed: 5/30/2017 Operations Summary (with Timelog Depths) ozr 1 C-23 Cono> °nitihps AI.uF;.g 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) 4/27/2017 4/27/2017 4.10 PROD1 RPEQPT CIRC T Bleed IA down in 100 psi increments 13,400.0 13,400.0 11:18 15:24 from 1520 psi to 236 psi.Tubing pressure tracked IA pressure as gas was bled off the IA.Final T/IA pressure was 92/236 psi.Open well and bleed WHP to tiger tank.Line up and start circulating conventionally. Take 5 bbls diesel cut mud to the tiger tank.Even mud weight in and out, bring returns back inside. 4/27/2017 4/27/2017 2.20 PROD1 RPEQPT TRIP T POOH with BHA#1. 13,400.0 71.0 15:24 17:36 4/27/2017 4/27/2017 2.50 PROD1 RPEQPT .PULD T At surface,space out,Attempt to 71.0 0.0 17:36 20:06 bleed off WHP-No good.PJSM PUD BHA#1 4/27/2017 4/27/2017 0.90 PROD1 RPEQPT PULD T PD BHA#2,WFT UR and straight BHI 0.0 75.0 20:06 21:00 Motor,M/U to coil and surface test 4/27/2017 4/27/2017 2.50 PROD1 RPEQPT TRIP T Trip in with BHA#2 to UR cement, 75.0 13,255.0 21:00 23:30 EDC open 4/27/2017 4/27/2017 0.10 PROD1 RPEQPT DLOG T Log K1 for-12.5,Clean counter wheel 13,255.0 13,284.0 23:30 23:36 4/27/2017 4/28/2017 0.40 PROD1 RPEQPT TRIP T Continue trip in well,Midnight depth 13,284.0 13,400.0 23:36 00:00 13400 4/28/2017 4/28/2017 0.20 PROD1 RPEQPT TRIP T Stop and close EDC,Crew change, 13,400.0 13,510.0 00:00 00:12 Continue in and tag up dry at 13517 4/28/2017 4/28/2017 3.50 PROD1 RPEQPT UREM T PUH to 13505,Bring pups online 1.69 13,510.0 13,518.0 00:12 03:42 BPM @ 2944 PSI FS.Let blades work open jog up and down,start reaming 13510 to 13517 and stalled multiple times.Work 13505 to 13510.Loosing ground at stalls 4/28/2017 4/28/2017 0.10 PROD1 RPEQPT WPRT T PUH to tie in,Possible counter error 13,518.0 13,255.0 03:42 03:48 4/28/2017 4/28/2017 0.10 PROD1 RPEQPT DLOG T Log K1 for-.5',counters on 13,255.0 13,271.0 03:48 03:54 4/28/2017 4/28/2017 0.30 PROD1 RPEQPT WPRT T RBIH to under ream. 13,271.0 13,510.0 03:54 04:12 4/28/2017 4/28/2017 0.30 PROD1 RPEQPT UREM T Bring up pump slow.Stalled.PU to 13,510.0 13,505.0 04:12 04:30 13,505 ft.Bring up pump slow again. Stalled.POOH to 13,505 ft. 4/28/2017 4/28/2017 2.30 PROD1 RPEQPT TRIP T Unable to make forward progress 13,505.0 70.0 04:30 06:48 underreaming.POOH to inspect BHA. 4/28/2017 4/28/2017 0.50 PROD1 RPEQPT OWFF T Flow check well at surface.Well static 70.0 70.0 06:48 07:18 after 30 minutes. 4/28/2017 4/28/2017 1.00 PROD1 RPEQPT PULD T PJSM.Break off injector. LD motor 70.0 0.0 07:18 08:18 and Reeves underreamer from BHA #2. BHA overall in good condition.Most of the wear on the reamer blades indicate they were not working fully open. 4/28/2017 4/28/2017 0.50 PROD1 RPEQPT WAIT T Discuss BHA options with town. 0.0 0.0 08:18 08:48 SIMOPS,Change out CTES counter wheel. 4/28/2017 4/28/2017 0.50 PROD1 RPEQPT PULD T PU Inteq motor 0°AKO and back up 2 0.0 75.0 08:48 09:18 -1/8"Reeves undereamer dressed with 6"blades. Page 3/35 Report Printed: 5/30/2017 AhIoLt Operations Summary (with Timelog Depths) 0 1C-23 ConocoPillipss 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) 4/28/2017 4/28/2017 2.80 PROD1 RPEQPT TRIP T MU injector.Bump up.Reset 75.0 13,229.0 09:18 12:06 counters.RIH with Underreamer BHA #3. 4/28/2017 4/28/2017 0.20 PROD1 RPEQPT DLOG T Tie-in to the K1 for a-12.0 ft 13,229.0 13,229.0 12:06 12:18 correction. 4/28/2017 4/28/2017 0.20 PROD1 RPEQPT TRIP T Continue in the hole and dry tag 13,229.0 13,505.0 12:18 12:30 bottom of pilot hole at 13,519 ft.PUH to 13,505. 4/28/2017 4/28/2017 1.80 PROD1 RPEQPT UREM T Bring up pump to 1.8 bpm.Multiple 13,505.0 13,311.0 12:30 14:18 stalls trying to get started.PU and restart each time.PUW=50 Klbs. RIH to 13,512 ft and restart. 4/28/2017 4/28/2017 2.20 PROD1 RPEQPT UREM T Try reaming up to 13505 and RIH dry 13,311.0 13,311.0 14:18 16:30 4/28/2017 4/29/2017 7.50 PROD1 RPEQPT UREM T Go back to normal under reaming ops, 13,311.0 13,519.0 16:30 00:00 1.7 BPM @ 3300 PSI FS.Add.5% 776 to milling fluid.Slow going with stalls.Very pump rates 4/29/2017 4/29/2017 1.80 PROD1 RPEQPT UREM T Continue underreaming cement, 13,519.0 13,522.0 00:00 01:48 1.6BPM @ 3325 PSI FS.Slow ratty going with stalls-Smoothed out @ 13522 4/29/2017 4/29/2017 2.50 PROD1 'RPEQPT UREM T 13522,Bring rate up to 1.8 BPM @ 13,522.0 13,526.0 01:48 04:18 3717 PSI FS.Able to maintaing WOB, differential,and forward progress until stall at 13,526 ft. 4/29/2017 4/29/2017 4.30 PROD1 RPEQPT UREM T Continue to try and work past 13,526 13,526.0 13,526.0 04:18 08:36 ft with no success.Note 13,526 ft is top of the C sand.Review caliper log run 2/14/2017.Restricted ID measured at this depth and below. Consult with town. 4/29/2017 4/29/2017 2.00 PROD1 RPEQPT TRIP T Made decision to pull out of the hole to 13,526.0 70.0 08:36 10:36 inspect BHA and evaluate plan forward.POOH. 4/29/2017 4/29/2017 1.00 PROD1 RPEQPT OWFF T Flow check at surface.Could not 70.0 70.0 10:36 11:36 bleed off WHP.Bleed gas from IA down from 115 psi to 85 psi.Flow check again.Static. 4/29/2017 4/29/2017 0.60 PROD1 RPEQPT PULD T LD Underreamer BHA#3. 70.0 0.0 11:36 12:12 Underreamer parted.Fish in hole is 3- 1/2"of the lower 2-1/8"reamer housing and lower 2 reamer blades including retaining hardware. 4/29/2017 4/29/2017 2.00 PROD1 RPEQPT WAIT T Report findings to town.Evaluate plan 0.0 0.0 12:12 14:12 forward.SIMOPS Bleed gas off of IA until diesel seen at surface.Close bleed valve.Starting IA pressure 85 psi.Final IA pressure=65 psi. 4/29/2017 4/29/2017 4.00 PROD1 RPEQPT WAIT T Make preparation to RU slickline. 0.0 0.0 14:12 18:12 Review procedure.Stand back PDL. Evaluate shieve placement. 4/29/2017 4/29/2017 3.60 PROD1 RPEQPT RURD T PJSM, R/U HES slickline 0.0 0.0 18:12 21:48 4/29/2017 4/29/2017 1.10 PROD1 RPEQPT SLKL T SL Run#1 RIH with HES Slick line 0.0 0.0 21:48 22:54 with 2.7"magnet,set down in GLM @ 6288,unable to work past, POOH Page 4/35 Report Printed: 5/30/2017 • Operations Summary (with Timelog Depths) till 0.1 1C-23 ConocoPhitlips d,f.rks 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) 4/29/2017 4/30/2017 1.10 PROD1 RPEQPT SLKL T SL Run#2 Reconfigure slick line BHA 0.0 0.0 22:54 00:00 to 2.650 magnet and larger centralizer RIH. 4/30/2017 4/30/2017 1.80 PROD1 RPEQPT SLKL T cont.SL Run#2 Continue in with slick 0.0 0.0 00:00 01:48 line 2.65 magnet run,Set down at 13488.Unable to work past.Trip out metal shavings on magnet 4/30/2017 4/30/2017 3.10 PROD1 RPEQPT SLKL T SL Run#3 Reconfigure tool string, 0.0 0.0 01:48 04:54 2.65 magnet with smaller centralizers, trip in well.Set down @ 13493'. Unable to work past,POOH 4/30/2017 4/30/2017 3.50 PROD1 RPEQPT SLKL T SL Run#4 Reconfigure tool string with 0.0 0.0 04:54 08:24 2.5"drive down bailer.RIH to 13,513ft . SLM.Work bailer on bottom.POOH. At surface.Recovered cement chunks and metal shavings. Metal most likley from the UR working on the inside of the 7"casing.No reamer paerts identified in the recovered material. 4/30/2017 4/30/2017 3.80 PROD1 RPEQPT SLKL T SL Run#5. Reconfigure SL BHA to 0.0 0.0 08:24 12:12 2.45"magnet with 2.63"centralizer. RIH to 13,513 ft SLM.POOH 4/30/2017 4/30/2017 3.50 PROD1 RPEQPT SLKL T SL Run#6.Discuss findings from last 0.0 0.0 12:12 15:42 SL run with town.Reconfigure SL BHA to 2.6"LIB.RIH.Stack out at 11,659 ft.Could not go down.POOH to inspect.Observed impressions on the block showing an ID restriction. 4/30/2017 4/30/2017 3.80 PROD1 RPEQPT SLKL T SL Run#7.Reconfigure SL BHA to 0.0 0.0 15:42 19:30 2.45"magnet.RBIH to drift area around 11,659 ft.Out of well with wiskers.no solid metal 4/30/2017 4/30/2017 4.20 PROD1 RPEQPT SLKL T SL Run#8,2.6 LIB with decentralizer. 0.0 0.0 19:30 23:42 Could possibly be inner fork madrel top idexed @ 3-4 oclock position 4/30/2017 5/1/2017 0.30 PROD1 RPEQPT SLKL T Reconfigure slick line tool to 2.5 flipper 0.0 0.0 23:42 00:00 dog overshot with 2.74 bell guide. 5/1/2017 5/1/2017 1.00 PROD1 RPEQPT SLKL T Reconfigure slick line tols.Get 2.74 0.0 0.0 00:00 01:00 bell guide and 2.5 flipper dog overshot 5/1/2017 5/1/2017 2.50 PROD1 RPEQPT SLKL T Trip in hole SL run#9 flipper dog 0.0 0.0 01:00 03:30 basket,jar down @ 11665. Come out of hole with no pieces.Marks on bellguide and flipper basket.Photos on S drive. 5/1/2017 5/1/2017 3.50 PROD1 RPEQPT SLKL T SL Run#10:Reconfigure SL BHA for 0.0 0.0 03:30 07:00 overshot to swallow 2-1/8"reamer body.RIH.Tag up at 11,667 ft SLM. Jar down twicw.POOH.At surface, overshot is empty. 5/1/2017 5/1/2017 3.20 PROD1 RPEQPT SLKL T SL Run#11:Reconfigure SL BHA with 0.0 0.0 07:00 10:12 2.45"magnet.RIH and tag up at 13,484 ft SLM.Near milled nipple on RKB log. POOH.Recovered part of underreamer fish.3.5"long piece of the inner reamer mandrel. Page 5/35 Report Printed: 5/30/2017 r ! 0: 110 Operations SummaryKA 1C-(23with Timelog Depths) ConocciPhillips AI.z;A.x 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) 5/1/2017 5/1/2017 3.50 PROD1 RPEQPT SLKL T SL Run#12:Clean 2.45"magnet and 0.0 0.0 10:12 13:42 re-run in the hole.Tag at 13,523 ft SLM which is the deepest SL has been on this well.POOH.Mostly metal shavings.Small metal chunks that most likely came from the fish. 5/1/2017 5/1/2017 3.70 PROD1 RPEQPT SLKL T SL Run#13:Clean 2.45"magnet and 0.0 0.0 13:42 17:24 re-run in the hole.Tag at 13,523 ft SLM.POOH.recovered reamer blade hinge pin. 5/1/2017 5/1/2017 4.50 PROD1 RPEQPT SLKL T SL Run#14:Clean 2.45"magnet and 0.0 0.0 17:24 21:54 re-run in the hole.Tag at 13,486 ft. (milled nipple depth).POOH.No reamer parts recovered. 5/1/2017 5/2/2017 2.10 PROD1 RPEQPT SLKL T SL Run#15:Reconfigure BHA to 2.5" 0.0 0.0 21:54 00:00 OD drive down bailer to drift tubing. RIH Clear down to 13486.Jar down. Unable to get past,POOH.Metal marks on bailer bottom 5/2/2017 5/2/2017 1.10 PROD1 RPEQPT SLKL T Continue in SL run#15 2.5"drive 0.0 0.0 00:00 01:06 down bailer.Set down @ 13486.Jar down.Unable to pass.POOH fresh marks on bailer bottom,Photos on drive 5/2/2017 5/2/2017 3.00 PROD1 RPEQPT SLKL T SL run#16,2.70 LIB on 0.0 0.0 01:06 04:06 decenteralizer.Set down at 13441 No marks on LIB.Photos on drive 5/2/2017 5/2/2017 1.90 PROD1 RPEQPT SLKL T SL run#17,2.60 Gauge ring and 0.0 0.0 04:06 06:00 scraper brush.Run to TD @ 13521 to ensure tubing is clear for nozzle run 5/2/2017 5/2/2017 2.00 PROD1 RPEQPT SLKL T Rig down slick line 0.0 0.0 06:00 08:00 5/2/2017 5/2/2017 0.50 PROD1 WHDBOP CTOP T PJSM,M/U swizzle stick and jet stack 0.0 0.0 08:00 08:30 5/2/2017 5/2/2017 0.90 PROD1 RPEQPT PULD T PJSM,M/U BHA#4,2"Nozzle,M/U 0.0 54.3 08:30 09:24 to coil and surface test 5/2/2017 5/2/2017 2.30 PROD1 RPEQPT TRIP T Trip in hole,EDC open 54.3 13,230.0 09:24 11:42 5/2/2017 5/2/2017 0.20 PROD1 RPEQPT DLOG T Log K1 for-10'correction,Close EDC, 13,230.0 13,252.0 11:42 11:54 PUW=40K, 5/2/2017 5/2/2017 1.30 PROD1 RPEQPT TRIP T Trip in,tag up at 13526,recip 7" 13,252.0 13,526.0 11:54 13:12 pumping multiple Lo Hi vis sweeps, 1.8 BPM @ 3625 PSI,Recip 7" 5/2/2017 5/2/2017 0.60 PROD1 RPEQPT CIRC T Start filtered lake water down coil, 13,526.0 13,526.0 13:12 13:48 continue reciping 7 inch and up into 3 1/2 tubing 5/2/2017 5/2/2017 2.30 PROD1 RPEQPT TRIP T POOH pumping filtered seawater 13,526.0 68.0 13:48 16:06 5/2/2017 5/2/2017 0.90 PROD1 RPEQPT PULD T At surface,Blow down TT line,LRS 68.0 0.0 16:06 17:00 freeze protect filter pod and surface lines.PJSM,flow check well,Lay down BHA#4 5/2/2017 5/2/2017 1.40 PROD1 RPEQPT PULD T PJSM,MU/PU BHA#5 Camera,test 0.0 18.0 17:00 18:24 camera,tag up Page 6/35 Report Printed: 5/30/2017 0' • •rations Summary (with Timelog Depths) 1C-23 ConocoPhiElips 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) 5/2/2017 5/2/2017 4.60 PROD1 RPEQPT TRIP T RIH with camera BHA#5,begin 18.0 13,496.0 18:24 23:00 pumping 7 bbl methanol at 5840',then swith back to lake water,visual tie into GLV for+5'correction(multiple passes required w/difficulty obtaining visual).Ran out of lake water at 22:30 hrs,confer with town:pumping rig water behind 45 bbl lake water in coil, another water truck enroute. 5/2/2017 5/3/2017 1.00 PROD1 RPEQPT DLOG T Stop at 13,496' as EV hand attempts 13,496.0 13,496.0 23:00 00:00 to clear up area at TT&aquire visual, pumping bewteen.5-1 bpm.RIH to 13,503'and drop rate to 0 bpm,PUH & believe TT observed at 13,496', RIH to 13,510'(no visual),RIH to 13,515'(no visual),PUH to 13,507'(no casing visual),RBIH 13,518'pumping 1 bpm(no visual), PUH to 13,496'(no visual),RBIH to 13,519'at 1.5 bpm(no visual),PUH to 13,509,RBIH to 13,519'.Continue this process as an additional 200 bbl of lake water&50 bbl methanol arrive at rig. 5/3/2017 5/3/2017 1.70 PROD1 RPEQPT CIRC T Begin circulating filtered fresh water 13,496.0 13,532.4 00:00 01:42 (200 bbl arrived on site)at 13,518' pumping 1-1.5 bpm,jogging up& down in attempt to clear up hole and obtain visual.Hole begins to clean up with—15 bbl out the coil.With—100 bbl fresh water pumped begin pumping 40 bbl methanol down-hole. 5/3/2017 5/3/2017 0.80 PROD1 RPEQPT DLOG T Obtain visual of fish at 13,532.4', 13,532.4 13,532.4 01:42 02:30 continue shooting video,PUH,rolling camera to visualize fish layout.RBIH towards fish causes fish to move and re-orient in-hole. 5/3/2017 5/3/2017 0.20 PROD1 RPEQPT DLOG T PUH to find TT 13,532.4 13,480.0 02:30 02:42 5/3/2017 5/3/2017 0.20 PROD1 RPEQPT DLOG T RBIH to obtain another shot of fish. 13,480.0 13,532.0 02:42 02:54 5/3/2017 5/3/2017 3.40 PROD1 RPEQPT TRIP T Begin POOH,slow through 11,526'- 13,532.0 122.0 02:54 06:18 11,494'to inspect tubing for potential holes,no holes observed through interval.Continue out of well 5/3/2017 5/3/2017 1.20 PROD1 RPEQPT PULD T Tag up,Flow check,PJSM,Lay down 122.0 0.0 06:18 07:30 BHA#5 Camera 5/3/2017 5/3/2017 0.50 PROD1 WHDBOP CTOP T Stab on with swizzle stick and jet 0.0 0.0 07:30 08:00 stack,Prep for BOPE test,service valves 5/3/2017 5/3/2017 10.00 PROD1 WHDBOP BOPE P Start weekly BOPE test,Test witness 0.0 0.0 08:00 18:00 waived by Brian Bixby,AOGCC 5/3/2017 5/3/2017 2.50 PROD1 WELLPR RURD T Prep floor after BOPE test and prep 0.0 0.0 18:00 20:30 for PU BHA 5/3/2017 5/3/2017 1.20 PROD1 WELLPR PULD T PU BHA#6 Cement Nozzle,tag up 0.0 15.0 20:30 21:42 5/3/2017 5/4/2017 2.30 PROD1 WELLPR TRIP T Begin to RIH with BHA#6,pressure 15.0 11,250.0 21:42 00:00 test to 800 psi(held), Page 7/35 Report Printed: 5/30/2017 0 >,t 4 • • Operations Summary (with Timelog Depths) 1C-23 Conoc hitlips 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) 5/4/2017 5/4/2017 0.60 PROD1 WELLPR TRIP T Continue RIH,tag bottom with pumps 11,250.0 13,516.0 00:00 00:36 off,set counter to 13,526'MD for a- 13'correction,PUH 10'to 13516' 5/4/2017 5/4/2017 2.10 PROD1 WELLPR CIRC T Circulate.5 bpm at 13,516',waiting on 13,516.0 13,516.0 00:36 02:42 cement truck. 5/4/2017 5/4/2017 2.70 PROD1 WELLPR CMNT T PJSM, lay-in cement as per 13,516.0 12,925.0 02:42 05:24 procedure,pumping.5 bpm. 5/4/2017 5/4/2017 0.10 PROD1 WELLPR CMNT T RBIH contaminating cement 2 to 1 12,925.0 13,450.0 05:24 05:30 5/4/2017 5/4/2017 2.40 PROD1 WELLPR TRIP T POOH 13,450.0 25.0 05:30 07:54 5/4/2017 5/4/2017 0.30 PROD1 WELLPR PULD T At surface,shut swabs,Lay down 25.0 0.0 07:54 08:12 BHA#6 5/4/2017 5/4/2017 1.80 PROD1 WELLPR CTOP T M/U nozzle,stab on well,Jet stack, 0.0 0.0 08:12 10:00 Pull off well.P/U test joint and cycle all rams.Flush rig with more contaminate. 5/4/2017 5/4/2017 0.30 PROD1 WELLPR CTOP T Test Eline after installing flow sub. 0.0 0.0 10:00 10:18 Good test 5/4/2017 5/4/2017 6.00 PROD1 WELLPR WOC T Wait on cement-run bore scope 0.0 0.0 10:18 16:18 through BOPE to ensure good cement rinse 5/4/2017 5/4/2017 1.00 PROD1 RPEQPT PULD T PJSM,P/U BHA#7 pilot hole milling 0.0 62.5 16:18 17:18 BHA with.9°AKO motor and 2.80"D- 331 slick guage 5/4/2017 5/4/2017 2.30 PROD1 RPEQPT TRIP T RIH with BHA#7 pilot-hole milling 62.5 13,262.0 17:18 19:36 assembly. 5/4/2017 5/4/2017 0.20 PROD1 RPEQPT DLOG T Tie into K1 for'-11.5 correction 13,262.0 13,262.0 19:36 19:48 5/4/2017 5/4/2017 0.20 PROD1 RPEQPT TRIP T Continue RIH,tag TOC at 13,447', 13,262.0 13,447.0 19:48 20:00 pumping.5 bpm,compressive strength should be at 2000 psi as per SLB lab in 14 hours from set time of 5:30 am. 5/4/2017 5/4/2017 0.50 PROD1 RPEQPT MILL T PUH,PUW=31K,RBIH to begin 13,447.0 13,473.0 20:00 20:30 milling pilot-hole,TF=20°ROHS, pumping 1.5 bpm,WOB=1.5K,free spin=340 psi,ROP=57 fph at 13,450',ROP=68 fph at 13,455. Confer with town,decision made to mill to13,475'to evaluate cement, ROP= 70 fph at13,468',ROP=65 at 13,473'. 23'remaining to TT,PUH to allow more cure time for cement,PUW =41K.Currently at 15 hr cure time 5/4/2017 5/4/2017 0.20 PROD1 RPEQPT TRIP T PUH 13,473.0 13,400.0 20:30 20:42 5/4/2017 5/4/2017 2.30 PROD1 RPEQPT WOC T Open EDC,circulate allowing 13,400.0 13,373.0 20:42 23:00 additional cement cure time 5/4/2017 5/4/2017 0.10 PROD1 RPEQPT TRIP T Close ED,RBIH to attempt milling 13,373.0 13,473.0 23:00 23:06 again(17.5 cure time,should have compressive strength of-2650 psi based on SLB modeling) 5/4/2017 5/4/2017 0.20 PROD1 RPEQPT MILL T 17.5 hr cure time,milling at 13,473', 13,473.0 13,478.0 23:06 23:18 TF=20°ROHS,1.3-1.5 bpm,WOB= 1.4K, FS= 330 psi,ROP=45-50 fph Page 8/35 Report Printed: 5/30/2017 0. Operations Summary (with Timelog Depths) 01 1C-23 ConocoPhillips �Laska 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) 5/4/2017 5/5/2017 0.70 PROD1 RPEQPT WOC T PUH,PUW=41K,open EDC, 13,478.0 13,400.0 23:18 00:00 circulate to allow for additional cement cure time. 5/5/2017 5/5/2017 1.00 PROD1 RPEQPT WOC T Continue circulating allowing 13,400.0 13,478.0 00:00 01:00 additional cure time,close EDC,RIH to attempt milling pilot-hole 5/5/2017 5/5/2017 0.20 PROD1 RPEQPT MILL T 19.5 hr cure time,milling at 13,478', 13,478.0 13,483.0 01:00 01:12 TF=20°ROHS,1.5 bpm,WOB= 1.5K, FS= 340 psi,ROP=48 fph, ROP=50 at 13,482',(Note: 13'to TT) 5/5/2017 5/5/2017 4.30 PROD1 RPEQPT WOC T PUH to 13,400',open EDC, 13,483.0 13,483.0 01:12 05:30 circulating.Confer with town on plan forward,Plan forward is to begin milling at 5:30 am(24 hr total cure time),if ROP is still-50 fph,continue ahead milling pilot-hole. 5/5/2017 5/5/2017 1.10 PROD1 RPEQPT MILL T Close EDC,continue milling pilot-hole 13,483.0 13,498.0 05:30 06:36 at 13,483' 5/5/2017 5/5/2017 0.20 PROD1 RPEQPT WPRT T 13498',Wiper trip,multiple stalls, 13,498.0 13,498.0 06:36 06:48 consult with town could be 7"casing contact,cosult town,TT could be high as 13484. 5/5/2017 5/5/2017 3.00 PROD1 RPEQPT MILL T 13498,Milling, 1.5 BPM @ 2700 PSI 13,498.0 13,528.0 06:48 09:48 FS,Roll TF to 160 L to get by this spot - at 13500.Roll back to 20R @ 13502, ROP=-20 FPH or less 5/5/2017 5/5/2017 6.10 PROD1 RPEQPT MILL P 13528 to 13530 grabby with a few 13,528.0 13,625.0 09:48 15:54 stalls.Cleared up after 10530, ROP=15 to 20 FPH from here to TD @ 13625', 1.5 BPM @ 2700 PSI FS, DHWOB=1.5K 5/5/2017 5/5/2017 0.50 PROD1 RPEQPT WPRT P 13625',Pilot hole TD'd,Pump 5 x 5 13,625.0 13,240.0 15:54 16:24 sweeps,PUH,slight motor work at transition area.Pull up to 13240 5/5/2017 5/5/2017 0.10 PROD1 RPEQPT DLOG P Log K1 for+.5' 13,240.0 13,259.0 16:24 16:30 5/5/2017 5/5/2017 0.50 PROD1 RPEQPT REAM P Trip back in,took weight at 13500, 13,259.0 13,550.0 16:30 17:00 1500 Lbs DHWOB.Continue in past 13530 area where we were stalling. PUH to back ream 13500'area 5/5/2017 5/5/2017 2.00 PROD1 RPEQPT REAM P Back ream up through 13,500'area, 13,550.0 13,423.0 17:00 19:00 continue up&dress transition area as per procedure at 1 fpm up and 5 fpm down(13480'-13,515'-3 passes). 5/5/2017 5/5/2017 0.30 PROD1 RPEQPT TRIP P Dry drift pilot-hole through transition to 13,423.0 13,625.0 19:00 19:18 WS setting depth,set-down 1K WOB at 13,503', 1K WOB at 13,562-13,567' 5/5/2017 5/5/2017 0.60 PROD1 RPEQPT REAM P PUW=50K,PUH&back-ream up 13,625.0 13,420.0 19:18 19:54 through 13,567-13,562&13,503' 5/5/2017 5/5/2017 3.10 PROD1 RPEQPT TRIP P Open EDC,POOH to LD BHA#7,tag 13,420.0 62.0 19:54 23:00 up. 5/5/2017 5/6/2017 1.00 PROD1 RPEQPT PULD P PJSM,flow-check wel(good)I,LD 62.0 0.0 23:00 00:00 BHA#7,jet stack 5/6/2017 5/6/2017 1.00 PROD1 RPEQPT PULD P PJSM,PU BHA#8 Caliper/CCL. 0.0 25.0 00:00 01:00 5/6/2017 5/6/2017 2.40 PROD1 RPEQPT TRIP P 'RIH with BHA#8 25.0 13,300.0 01:00 03:24 Page 9/35 Report Printed: 5/30/2017 o 11 0 Iterations Summary (with Timelogpthe ) 1C-23 Cono 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) 5/6/2017 5/6/2017 0.40 PROD1 RPEQPT TRIP P Tie in for-13.5'correction,continue 13,300.0 13,616.0 03:24 03:48 RIH to 13,615' 5/6/2017 5/6/2017 0.20 PROD1 RPEQPT DLOG P Open caliper arms, PUH at 50 fpm to 13,616.0 13,145.0 03:48 04:00 log caliper&CCL from 13,615'- 13,3150',PUW=43K 5/6/2017 5/6/2017 0.20 PROD1 RPEQPT TRIP P Close caliper arms, RBIH to 13,615', 13,145.0 13,616.0 04:00 04:12 +3'correction 5/6/2017 5/6/2017 0.20 PROD1 RPEQPT DLOG P Open caliper arms,PUH to log caliper 13,616.0 13,350.0 04:12 04:24 &CCL from 13,615'-13,350'(2nd logging pass),PUW=43K 5/6/2017 5/6/2017 2.00 PROD1 RPEQPT TRIP P POOH to LD BHA#8,tag up 13,350.0 22.0 04:24 06:24 5/6/2017 5/6/2017 1.60 PROD1 RPEQPT PULD P At surface,PJSM,Flow check,Lay 22.0 0.0 06:24 08:00 down BHA,Lay down HES caliper 5/6/2017 5/6/2017 1.10 PROD1 WHPST PULD P M/U BOT whipstock on open hole 0.0 72.0 08:00 09:06 anchor,Make up to coil trak,M/U to coil and surface test,Change pack offs 5/6/2017 5/6/2017 2.50 PROD1 WHPST TRIP P RIH with BHA#9 Whipstock 72.0 13,230.0 09:06 11:36 5/6/2017 5/6/2017 0.20 PROD1 WHPST DLOG P Log K1 for-11.5'correction 13,230.0 13,267.0 11:36 11:48 5/6/2017 5/6/2017 0.30 PROD1 WHPST TRIP P Continue in with whipstock.Stop at 13,267.0 13,605.8 11:48 12:06 13447 and shut EDC,PUW=49K, Continue in to 13605.75,Orient to HS. See setting tool shift @ 4600PSI,Set 3K down,TOWS=13595 5/6/2017 5/6/2017 2.50 PROD1 WHPST TRIP P Trip out of hole 13,605.8 35.0 12:06 14:36 5/6/2017 5/6/2017 1.00 PROD1 WHPST PULD P At surface,flow check well,PJSM,lay 35.0 0.0 14:36 15:36 down BHA#9,Lay down whipstock setting tools 5/6/2017 5/6/2017 0.60 PROD1 WHPST PULD P PJSM,M/U BHA#10,Window milling 0.0 74.3 15:36 16:12 BHA with.6°motor,2.79 string reamer,and 2.80 window mill.Wear band turned in on motor.PDL not pre loaded ran same coil trak tool as whipstock setting.Check pack offs. M/U to coil and surface test 5/6/2017 5/6/2017 2.30 PROD1 WHPST TRIP P RIH BHA#10,EDC open,pumping 74.3 13,260.0 16:12 18:30 min rate 5/6/2017 5/6/2017 0.20 PROD1 WHPST DLOG P Tie into K1 for-13'correction 13,260.0 13,269.0 18:30 18:42 5/6/2017 5/6/2017 0.20 PROD1 WHPST TRIP P Continue RIH,weight check,PUW= 13,269.0 13,595.0 18:42 18:54 48K,weight bobbles observed at 13,510', 13,530',&13,560',dry tag TOWS at 13,595. 5/6/2017 5/7/2017 5.10 PROD1 WHPST WPST P Bring pumps up to 1.8 bpm,begin 13,595.0 13,598.6 18:54 00:00 milling window in 7"casing as per procedure,FS=475 psi,CWT=5.6K. Stall getting started at 13,595' 5/7/2017 5/7/2017 0.80 PROD1 WHPST WPST P Continue milling window as per 13,598.6 13,599.6 00:00 00:48 procedure at 13598.6,abrupt drop in WOB at 13,599,BOW called at 13,599.6 at 12:45 am. 5/7/2017 5/7/2017 2.60 PROD1 WHPST WPST P Continue milling window as per 13,599.6 13,616.0 00:48 03:24 procedure at 13,599.6',PUW=44K Page 10/35 Report Printed: 5/30/2017 0 0 .. •rations Summary (with Timelog Depths) 1C-23 Conoco Phillips 51.rke 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) 5/7/2017 5/7/2017 0.80 PROD1 WHPST REAM P Dress window at 1fpm,up-hole HS- 13,616.0 13,578.0 03:24 04:12 30L-30R,down-hole HS,as per town request 5/7/2017 5/7/2017 0.10 PROD1 WHPST TRIP P dry drift,good 13,578.0 13,610.0 04:12 04:18 5/7/2017 5/7/2017 2.10 PROD1 WHPST TRIP P POOH,to LD BHA#10,open EDC in 13,610.0 65.0 04:18 06:24 cased hole. 5/7/2017 5/7/2017 1.60 PROD1 WHPST PULD P At surface,PJSM, Lay down window 65.0 0.0 06:24 08:00 milling BHA#10, Mill and reamer out @ 2.79 No Go 5/7/2017 5/7/2017 1.00 PROD1 DRILL PULD P PJSM,M/U BHA#11 with 1.7°motor 0.0 72.2 08:00 09:00 and RB Hughes bi center.Make up to coil and surface test tool 5/7/2017 5/7/2017 2.40 PROD1 DRILL TRIP P Trip in hole with BHA#11,EDC open 72.2 13,250.0 09:00 11:24 5/7/2017 5/7/2017 0.20 PROD1 DRILL DLOG P Log K1 for-9.5',Close EDC and trip in 13,250.0 13,258.0 11:24 11:36 5/7/2017 5/7/2017 0.30 PROD1 DRILL TRIP P Continue in well,wt check @ 13410 13,258.0 13,616.0 11:36 11:54 PUW=46K,took some weight in p;ilot hole,clean pass through window 5/7/2017 5/7/2017 2.40 PROD1 DRILL DRLG P 13616', Drill ahead, 1.8 BPM @3880 13,616.0 13,823.0 11:54 14:18 PSI FS,BHP=3850,Start new mud down coil.At bit @ 13665, 12:35 5/7/2017 5/7/2017 0.20 PROD1 DRILL WPRT P BHA Wiper,PUW=42K 13,823.0 13,823.0 14:18 14:30 5/7/2017 5/7/2017 0.30 PROD1 DRILL DRLG P 13823',Drill, 1.78 BPM @ 3755 PSI 13,823.0 13,845.0 14:30 14:48 FS,BHP=3910 5/7/2017 5/7/2017 0.50 PROD1 DRILL WPRT P 13845',Call end of build-turn, Pump 13,845.0 13,245.0 14:48 15:18 5 X 5 sweeps,PUH,PUW=43K 5/7/2017 5/7/2017 0.20 PROD1 DRILL DLOG P 13245',Log K1 for+2' 13,245.0 13,268.0 15:18 15:30 5/7/2017 5/7/2017 0.10 PROD1 DRILL WPRT P Trip back in to log RA marker on 13,268.0 13,615.0 15:30 15:36 whipstock 5/7/2017 5/7/2017 0.10 PROD1 DRILL DLOG P Log RA @ 13601,TOWS 13595 13,615.0 13,635.0 15:36 15:42 5/7/2017 5/7/2017 0.90 PROD1 DRILL TRIP P POOH,Open EDC @ 13434' 13,635.0 9,342.0 15:42 16:36 5/7/2017 5/7/2017 0.30 PROD1 DRILL TRIP T Love joy connection to angle drive 9,342.0 9,342.0 16:36 16:54 cooling pump came loose. Injector angle drive over heat.Tighten lovejoy connection 5/7/2017 5/7/2017 1.50 PROD1 DRILL TRIP P Continue out of well,tag up. 9,342.0 74.0 16:54 18:24 5/7/2017 5/7/2017 1.30 PROD1 DRILL PULD P PJSM,flow check(good),LD BHA 74.0 0.0 18:24 19:42 #11 5/7/2017 5/7/2017 0.90 PROD1 DRILL PULD P PU BHA#12"A"Lateral Drilling 0.0 72.0 19:42 20:36 Assembly, 1°AKO X-Treme motor, HCC RB bit(same bit as build,graded 1-1),change pack-offs 5/7/2017 5/7/2017 2.30 PROD1 DRILL TRIP P RIH with BHA#12 72.0 13,252.0 20:36 22:54 5/7/2017 5/7/2017 0.20 PROD1 DRILL DLOG P Log K1 for a-10.5'correction 13,252.0 13,267.0 22:54 23:06 5/7/2017 5/7/2017 0.30 PROD1 DRILL TRIP P Continue RIH to bottom 13,267.0 13,845.0 23:06 23:24 Page 11/35 Report Printed: 5/30/2017 • • oil& Operations Summary (with Timelog Depths) 1 C-23 concicaP,ii Ai.sk:x 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 (EKE) End Depth(ftKB) 5/7/2017 5/8/2017 0.60 PROD1 DRILL DRLG P Drilling ahead at 13,845',pumping 1.8 13,845.0 13,896.0 23:24 00:00 bpm,FS=540 psi,dp=772 psi, CWT=7.6K,WOB=2K 5/8/2017 5/8/2017 2.80 PROD1 DRILL DRLG P Continue drilling at 13,896'pumping 13,896.0 14,345.0 00:00 02:48 1.8 bpm,CWT=7K,WOB=1.8K, ROP=270 fph,PU at 14,211,PUW= 42K,500'drill interval 5/8/2017 5/8/2017 0.30 PROD1 DRILL 'WPRT P Wiper up-hole,PUW=37K 14,346.0 13,675.0 02:48 03:06 5/8/2017 5/8/2017 0.30 PROD1 DRILL WPRT P Wiper dowh-hole,RIW=8K,issue. 13,675.0 14,085.0 03:06 03:24 5/8/2017 5/8/2017 2.70 PROD1 DRILL RGRP T Experience difficultly maintaining rate 14,085.0 13,398.0 03:24 06:06 in,pumping 42 stk/min with 50 psi at charge pump,45 psi at mud pump 1 & 2,this maintains.64 bpm out,and erratic rate in,b/w.2-1 bpm reading (should be 1 bpm at 42 stk/min). trouble shoot issue.Mud appears aired up 5/8/2017 5/8/2017 0.20 PROD1 DRILL WPRT P Mud has de-air enough to pump-No 13,398.0 13,625.0 06:06 06:18 other plumbing problems.RBIH 5/8/2017 5/8/2017 0.20 PROD1 DRILL DLOG P Log RA marker for no correction 13,625.0 13,641.0 06:18 06:30 5/8/2017 5/8/2017 0.50 PROD1 DRILL WPRT P PUH to casing and replace hardline 13,641.0 13,422.0 06:30 07:00 gasket in putz 5/8/2017 5/8/2017 0.50 PROD1 'DRILL WPRT P RBIH to drill 13,422.0 14,345.0 07:00 07:30 5/8/2017 5/8/2017 1.20 PROD1 DRILL DRLG P 14345',Drill,1.8 BPM @ 3825 PSI 14,345.0 14,584.0 07:30 08:42 FS,BHP=3935 5/8/2017 5/8/2017 0.30 PROD1 'DRILL WPRT P Pull 300'wiper,weight transfer issues, 14,584.0 14,584.0 08:42 09:00 PUW=44K 5/8/2017 5/8/2017 1.00 PROD1 DRILL DRLG P 14584',Drill,1.79 BPM @3865 PSI 14,584.0 14,655.0 09:00 10:00 FS,BHP=4070 5/8/2017 5/8/2017 0.40 PROD1 DRILL WPRT P 14655',Wiper to window with sweeps, 14,655.0 14,655.0 10:00 10:24 PUW=43K,tie in for-.5' 5/8/2017 5/8/2017 3.20 PROD1 DRILL DRLG P 14655',Drill 1.79 @ 3860 PSI FS, 14,655.0 14,787.0 10:24 13:36 BHP=3960 5/8/2017 5/8/2017 0.20 PROD1 DRILL DRLG P Been trying drop angle, Hanging @ 14,787.0 14,791.0 13:36 13:48 90.4,Reduce pump rate to 1.5 @ 3625 PSI FS.increase WOB 5/8/2017 5/8/2017 0.10 PROD1 DRILL WPRT P Pull BHA wiper,PUW=40K 14,791.0 14,791.0 13:48 13:54 5/8/2017 5/8/2017 2.50 PROD1 DRILL DRLG P 14791',Drill,1.5 BPM @ 3215 PSi FS, 14,791.0 14,904.0 13:54 16:24 BHP=3905 5/8/2017 5/8/2017 0.40 PROD1 DRILL WPRT P 14904', BHA Wiper,PUW=53K 14,904.0 14,904.0 16:24 16:48 5/8/2017 5/8/2017 1.30 PROD1 DRILL DRLG P 14904', Drill, 1.82 BPM @ 3925 PSI 14,904.0 15,007.0 16:48 18:06 FS,BHP=4020 5/8/2017 5/8/2017 0.80 PROD1 DRILL WPRT P 15007', 1000'wiper trip,PUW=38K 15,007.0 15,007.0 18:06 18:54 5/8/2017 5/8/2017 1.00 PROD1 DRILL DRLG P 14007',Drill,1.83 BPM @ 3855 PSI 15,007.0 15,084.0 18:54 19:54 FS,BHP=4007 5/8/2017 5/8/2017 1.00 PROD1 DRILL WPRT P 15084 wiper to window,POW=43K 15,084.0 15,084.0 19:54 20:54 5/8/2017 5/8/2017 1.30 PROD1 DRILL DRLG P 15084',Drill, 1.81 BPM @ 3925 PSi 15,084.0 15,121.0 20:54 22:12 FS,BHP=4025.Hard to maintain steady drilling,Drill solids at.7% 5/8/2017 5/9/2017 1.80 PROD1 DRILL WPRT P Early wiper as sending new mud down 15,121.0 11,125.0 22:12 00:00 -hole. Page 12/35 Report Printed: 5/30/2017 0,1, Operations Summary (with Timelog Depths) rpt 1C-23 m�ff,� 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) 5/9/2017 5/9/2017 0.90 PROD1 DRILL WPRT P Continue WT up to 9900' 11,125.0 9,900.0 00:00 00:54 5/9/2017 5/9/2017 4.10 PROD1 DRILL RGRP T RBIH to—13,000'and experience 9,900.0 13,141.0 00:54 05:00 difficulty stopping down-hole progress of coil,verify traction pressure,good at 1300 psi',attemped pushing stick forward and bringing back multiple times with no success,began manually adjusting set point down from 100 fpm to 30 fpm,at 50 fpm setpoint,were able to begin retarding down-hole progress,with coil stopped decision was made to come up-hole and reset injector and storage reel,a second RIH at slower speed,up-hole of window,experienced similar results, decison made to stop and replace injector throttle control&verify. 5/9/2017 5/9/2017 0.10 PROD1 DRILL WPRT P Continue RIH. 13,141.0 13,250.0 05:00 05:06 5/9/2017 5/9/2017 0.20 PROD1 DRILL DLOG P Tie into K1 for+1'correction 13,250.0 13,300.0 05:06 05:18 5/9/2017 5/9/2017 0.80 PROD1 DRILL 'WPRT P Continue RIH to bottom,begin 13,300.0 15,121.0 05:18 06:06 sending new mud down-hole at 13,602'(System#1 retired with.8% solids&1,500'drilled footage) 5/9/2017 5/9/2017 3.30 PROD1 DRILL DRLG P BOBD at 15,121',strugging to drill, 15,121.0 15,275.0 06:06 09:24 CWT=-5K,wob=2.5K,pump 20 bbl beaded pill.ROP increased to over 200 fph,geology believes break through Siderite. 5/9/2017 5/9/2017 0.40 PROD1 DRILL WPRT P WT up-hole,PUW=45K 15,276.0 14,276.0 09:24 09:48 5/9/2017 5/9/2017 0.50 PROD1 DRILL WPRT P WT in-hole,RIW=5K 14,276.0 15,275.0 09:48 10:18 5/9/2017 5/9/2017 4.70 PROD1 DRILL DRLG P OBD at 15,275,pumping 1.8 bpm,FS 15,275.0 15,302.0 10:18 15:00 =485 psi,CWT=--5K,WOB=1.7K, difficulty maintaining weight transfer, multiple BHA wipers,pump 20 bbl beaded pill. 5/9/2017 5/9/2017 1.50 PROD1 DRILL DRLG P Continue drilling ahead at 15302', 15,302.0 15,311.0 15:00 16:30 pumping 1.8 bpm,CWT=-6K,WOB= 1.1K,Siderite showing over shakers, slow ROP,constant PU's to continue drilling,good ROP when breaking-out of Siderite.Begin pumping 20 bbl 1.5%776, 1.5%LoTorq pill at 15,306' in attempt to gain weight transfer,able to stay reduce PU's and continue dirlling,confer with town,decision made to increase System#2 to 1.5%/1.5% 5/9/2017 5/9/2017 0.80 PROD1 DRILL DRLG P Break throuh Siderite,CWT=.7K, 15,311.0 15,347.0 16:30 17:18 WOB=1.2K,ROP=105 fph. Short lived. 5/9/2017 5/9/2017 0.30 PROD1 DRILL WPRT P Wiper trip,PUW=42K, 800' 15,347.0 14,547.0 17:18 17:36 5/9/2017 5/9/2017 0.30 PROD1 DRILL WPRT P WT in-hole, RIW=4.6 K,saw slight 14,547.0 15,347.0 17:36 17:54 bobbls @ 15,133&15,159' Page 13/35 Report Printed: 5/30/2017 Operations Summary (with Timelog Depths) .-t 1C-23 ConocoPhillips Akzka 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) 5/9/2017 5/10/2017 6.10 PROD1 DRILL DRLG P BOBD,ROP's,—10 FPH,poor weight 15,374.0 15,400.0 17:54 00:00 transfer w multiple pickups,CT Wt from neutral to-10 kl bs. Geo suspects we may have drilled out/ faulted out of zone,roll TF to 180°. Last sample looked like cement/inlet mud. 5/10/2017 5/10/2017 1.30 PROD1 DRILL DRLG P OBD, 1.80 bpm,Free spin diff 540 psi, 15,400.0 15,404.0 00:00 01:18 CT 4600 psi,CT wt-4 to-10 k lbs, WOB 0.5-1 k lbs. Multiple pick ups, TF 180,slow drilling turning back down looking for sand. Pump 5 x 5 lo x hi vis sweep and chase to bit. 5/10/2017 5/10/2017 0.70 PROD1 DRILL WPRT P Wiper trip#3 though the build.PUW= 15,404.0 13,700.0 01:18 02:00 36 K, 1704' POH chasing the sweeps 5/10/2017 5/10/2017 0.90 PROD1 DRILL WPRT P WT in-hole,RIW=—5 K with set 13,700.0 15,404.0 02:00 02:54 downs at 14,070', 14,114',&14,150'. No WOB,but lost Ct Wt. 5/10/2017 5/10/2017 3.70 PROD1 DRILL DRLG P BOBD, 1.79 bpm,Free spin diff 490 15,404.0 15,463.0 02:54 06:36 psi, CT 4600 psi,CT wt-10 k lbs, WOB 1.8 k lbs.ROP 14 ft/hr. 5/10/2017 5/10/2017 0.20 PROD1 DRILL WPRT P 200'Wiper 15,463.0 15,463.0 06:36 06:48 5/10/2017 5/10/2017 2.70 PROD1 DRILL DRLG P OBD,pumping 1.8 bpm, CWT=-10K, 15,463.0 15,497.0 06:48 09:30 WOB=.8K,pumping 5x5 sweeps as needed to keep drilling.BHA wipers, PUW's=38K-41K,confer with town, decision made to POOH for agitator, lower bend motor,&new bit. 5/10/2017 5/10/2017 3.00 PROD1 DRILL TRIP P Pumps sweeps,trip for agitator,lower 15,497.0 72.0 09:30 12:30 bend motor,new bit,tag up 5/10/2017 5/10/2017 1.00 PROD1 DRILL PULD P PJSM,flow check,LD BHA#12, 72.0 0.0 12:30 13:30 function test BOPE(bit came out a 2- 3). 5/10/2017 5/10/2017 1.00 PROD1 DRILL PULD P PU BHA#13"A"Lateral Drilling 0.0 78.0 13:30 14:30 Assembly#2,(1°AKO motor,agitator, HYC B8 bit),tag up 5/10/2017 5/10/2017 2.60 PROD1 DRILL TRIP P RIH with BHA#13,surface test 78.0 13,265.0 14:30 17:06 agitator 5/10/2017 5/10/2017 0.20 PROD1 DRILL DLOG P Tie into the K1 for-12'correction 13,265.0 13,280.0 17:06 17:18 5/10/2017 5/10/2017 1.20 PROD1 DRILL TRIP P Wt Ck 40k Lbs,@ Continue to RIH 13,280.0 15,495.0 17:18 18:30 5/10/2017 5/10/2017 2.90 PROD1 DRILL DRLG P OBD,pumping 1.81 bpm, CWT=0 15,495.0 15,609.0 18:30 21:24 ternding rapidly to-7k lbs,WOB= 2.27-1 k lbs,Free spin diff 1120 psi. On bottom CT 5100 psi,ROP 20-80 fUhr-averaged 39 ft/hr over on bottom interval. 5/10/2017 5/10/2017 0.50 PROD1 DRILL DLOG P PU to catch missed surveys and MAD 15,609.0 15,609.0 21:24 21:54 pass missed resistivity. PU Wt39 k lbs,turned around at 15,460'. RBIH Wt 3.5k lbs Page 14/35 Report Printed: 5/30/2017 !erations Summary (with Timelog Depths) • t t 1C-23 ConocoPhiilips 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) 5/10/2017 5/11/2017 2.10 PROD1 DRILL DRLG P RIH, pumping 1.82 bpm,CT 4915 psi, 15,609.0 15,776.0 21:54 00:00 RIHWt 4.9 k lbs. Free spin diff 1140 psi. Ct Wt-5 to-6 klbs,WOB 1.5 to 1.0 lbs,ROP 90-60 ft/hr averaged 79.5 ft/hr over on bottom interval 5/11/2017 5/11/2017 2.20 PROD1 DRILL DRLG P OBD1.78 bpm,CT 5250 psi,free spin 15,776.0 15,915.0 00:00 02:12 diff 1140 psi. Ct Wt-5 to-6 klbs, WOB 1.5 to 1.0 lbs,ROP 90-80 ft/hr averaged XX ft/hr over on bottom interval 5/11/2017 5/11/2017 0.40 PROD1 DRILL WPRT P Scheduled wiper trip after 400 foot 15,915.0 14,915.0 02:12 02:36 drilled, PU Wt 44 k lbs, -1000' 5/11/2017 5/11/2017 0.40 PROD1 DRILL WPRT P RBIH,RIH Wt 3.k lbs 14,915.0 15,915.0 02:36 03:00 5/11/2017 5/11/2017 0.90 PROD1 DRILL DRLG P OBD,atempting to hold WOB to help 15,915.0 15,931.0 03:00 03:54 build unable at 1.78 bpm,reduce pump to1.5 bpm,CT 4164 psi,free spin diff 790 psi. Unable to transfer weight to bit. Multiple pick ups. Restart @ 1.78 bpm,free spin diff 1090 psi,saw off bottom diff fall off to 900 psi then return to 1090 psi. Troubleshoot,no obvious surface cause, diff seems to come and go randomly. 5/11/2017 5/11/2017 4.10 PROD1 DRILL DRLG P Continue to drill ahead,1.78 bpm,CT 15,931.0 16,108.0 03:54 08:00 5193 psi,Ct wt 0.32 k lbs,WOB 0.86 k lbs,ROP 47 ft/hr 5/11/2017 5/11/2017 1.20 PROD1 DRILL WPRT P Wiper to Window,uphole,PUW=60K 16,108.0 13,000.0 08:00 09:12 5/11/2017 5/11/2017 1.20 PROD1 DRILL WPRT P Wiper in-hole,tie in for+3'correction 13,000.0 16,108.0 09:12 10:24 5/11/2017 5/11/2017 3.00 PROD1 DRILL DRLG P OBD,pumping 1.8 bpm, CWT=-5K, 16,108.0 16,244.0 10:24 13:24 WOB=1.3K,ROP-40 fph,begin pumping 20 bbl beaded pill at 16,178', PU at 16,178',PUW=47K,beaded pill reaches bit at 16,191'to good effect. Note:reached 3 hrs level 4 vibration on tools,.33 hr level 5&above, reduce rate to 1.5 bpm in effort to reduce vibration. 5/11/2017 5/11/2017 8.20 PROD1 DRILL DRLG P Continue drilling ahead at 16,244', 16,244.0 16,500.0 13:24 21:36 pumping 1.58 bmp,CWT=-5K,WOB =.9K,ROP=36 fph,continue to pump beaded pills with success. Diminishing returns,lacking 10' discussed w Geo's if they had what they needed. They do. Pumped 10x10 TD to-Hi vis sweep. TD as sweeps exit the bit. Allow weigh to drill off. 5/11/2017 5/12/2017 2.40 PROD1 DRILL WPRT P PU Wt 38 k lbs. POOH chasing 16,500.0 4,444.0 21:36 00:00 sweeps to swab 5/12/2017 5/12/2017 1.00 PROD1 DRILL WPRT P Continue pulling out of hole,jog at 4,444.0 68.6 00:00 01:00 surface, 5/12/2017 5/12/2017 0.30 PROD1 DRILL OWFF P Bump up,blead IA,S/I choke,open up 68.0 78.0 01:00 01:18 to half drum,flow check-good retet depths. Page 15/35 Report Printed: 5/30/2017 • • 0114 Operations Summary (with Timelog Depths) 1C-23 ConocoPhillip Fr,�x.9 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) 5/12/2017 5/12/2017 2.50 PROD1 DRILL TRIP P RBIH pumping min rate. 78.0 13,261.0 01:18 03:48 5/12/2017 5/12/2017 0.20 PROD1 DRILL DLOG P Tie into the K1 for a-8' 13,261.0 13,282.0 03:48 04:00 5/12/2017 5/12/2017 1.20 PROD1 DRILL TRIP P Wt Chk,38 k lbs,Continue to RIH, 13,282.0 16,499.0 04:00 05:12 pumps off,pass throug window with very slight weight bobble at the window,passed 15,438'clean, 1 k lbs WOB bobble @16,378. Tag bottom @ 16,499 5/12/2017 5/12/2017 1.00 PROD1 DRILL DISP P start pumping liner running pill, 16,499.0 16,499.0 05:12 06:12 allowing to get to bit 5/12/2017 5/12/2017 3.30 PROD1 DRILL DISP P Begin Laying in liner running pill& 16,499.0 78.0 06:12 09:30 KWF to surface(8.7 ppg PowerPro, 1.5%/1.5 776&LoTorq,1.5% KlaStop,2 ppb Alpine beads,60-70K LSRV),paint EOP flags. Observe MW out dropping beginning at 10,230',down to 5.5 ppg,divert returns to TT,bring up WHP to—125 psi, manual weight check at pits reads 8.7 ppg.Possible faulty reading at MicroMotion,another manual weight check indicates 8.7 ppg, continue manual weight checks every 1000',Micro Motion continues to have low MW out reading,bring WHP back to 0 psi.Flow check at surface indicates well is flowing.WHP stabalized at 62 psi,manual check of MW at pits indicates 8.7 ppg heavy. 5/12/2017 5/12/2017 2.50 PROD1 DRILL TRIP P RIH to window to displace to heavier 78.0 13,265.0 09:30 12:00 KWF. 5/12/2017 5/12/2017 0.10 PROD1 DRILL DLOG P Log K1 for-7'correction 13,265.0 13,280.0 12:00 12:06 5/12/2017 5/12/2017 0.10 PROD1 DRILL TRIP P Contiue RIH to window 13,280.0 13,550.0 12:06 12:12 5/12/2017 5/12/2017 4.00 PROD1 DRILL DLOG P Close choke,shut down pumps, 13,550.0 13,550.0 12:12 16:12 obtain SBHP at window,annular pressure=3438 psi,WHP=325 psi, discuss with pusher&town,circulate bottoms up of 9 ppg mud,filled backside plus 20 bbl and did not see 9 ppg out,rather 8.7 ppg continued out. Shut-in again,annular=3444 psi, WHP=274 psi.Swap fluids to truck and pill pits in preperation to pump 10.4 ppg NaBr KWF from 13,700'MD (belly of build)to surface as per town disucssion. 5/12/2017 5/12/2017 3.00 PROD1 DRILL DISP P Begin pumping 10.3 ppg NaBr KWF 13,550.0 4,000.0 16:12 19:12 down-hole,close EDC,RIH to 13700'(belly of build),lay-in KWF to surface. 5/12/2017 5/12/2017 1.20 PROD1 DRILL WAIT P Experiencing losses,park while 4,000.0 4,000.0 19:12 20:24 building more KW fluid 5/12/2017 5/12/2017 1.20 PROD1 DRILL DISP P Continue to POOH laying in 10.3 ppg 4,000.0 69.0 20:24 21:36 KW fluid. Bleed IA again,start 273 psi,stop 188 psi. Page 16/35 Report Printed: 5/30/2017 4.4 wi ( 0 ,_tOperations Summary (with Timelog Depths) 1C-23 Conocbthilhps 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) 5/12/2017 5/12/2017 0.40 PROD1 DRILL OWFF P Tag up,flow check,well on a vac, 69.0 69.0 21:36 22:00 PJSM,fill hole,2.3 bbls fillup. 5/12/2017 5/12/2017 1.20 PROD1 DRILL PULD P LD BHA#13 69.0 0.0 22:00 23:12 5/12/2017 5/12/2017 0.60 COMPZ1 CASING CTOP P Inspect and swap pack offs. In bad 0.0 0.0 23:12 23:48 shape,quite a bit of melted gnarled up pack off rubber above the brass. cleaned same. 5/12/2017 5/13/2017 0.20 COMPZ1 CASING CTOP P Change out Upper QC, 0.0 0.0 23:48 00:00 5/13/2017 5/13/2017 1.20 COMPZ1 CASING CTOP P Continue to change out Upper QC, 0.0 0.0 00:00 01:12 test and PT to 3500 psi-good. 5/13/2017 5/13/2017 3.60 COMPZ1 CASING PUTB P PJSM,prep to run liner,PU and run 0.0 1,998.0 01:12 04:48 50 joints 2-3/8"slotted 4.6#L-80 Slotted Liner topped w/a shorty deployment sleeve,(1997.99'). 5/13/2017 5/13/2017 1.40 COMPZ1 CASING PULD P Clean floor after running liner,PJSM, 1,998.0 2,042.0 04:48 06:12 make up BHA#14,A lat liner running assembly. 5/13/2017 5/13/2017 2.10 COMPZ1 CASING RUNL P RIH with BHA#14,pumping.5 bpm, 2,042.0 13,556.0 06:12 08:18 rate out=.84 bpm, 10.4 ppg in, 10.27 ppg out,IA=351 psi,OA=427 psi.At 10,290',MW in=10.4 ppg,MW out= 9.46 ppg, IA=420,OA=435,MW out begins to decline beginning at 4387' MD. 5/13/2017 5/13/2017 0.10 COMPZ1 CASING DLOG P Correct to EOP flag for-13.8' 13,556.0 13,556.0 08:18 08:24 correction,weight check,PUW=44K 5/13/2017 5/13/2017 1.30 COMPZ1 CASING RUNL P Continue RIH with BHA#14,drop 13,556.0 16,496.0 08:24 09:42 pumps in OH,IA=269 psi at 14,137'. 10.3 ppg in,9.49 ppg out,stack weight at 15,335', 15,690', 16,470',PUW= 51K at 16,470'.tag up&unable to pass 16,496',bring up pumps,1.5 bpm,release off liner. 5/13/2017 5/13/2017 2.70 COMPZ1 CASING TRIP P POOH,MW out-9.7 ppg while 16,496.0 41.0 09:42 12:24 POOH,MW rose to 10.4 ppg as approaching surface. IA =250 psi- 280 psi,tag up 5/13/2017 5/13/2017 1.00 COMPZ1 CASING PULD P PJSM,flow-check well(good),LD 41.0 0.0 12:24 13:24 BHA#14,bleed IA from 288 psi down to 88 psi,IA climbs back to 201 psi 5/13/2017 5/13/2017 2.20 COMPZ1 CASING PULD P PJSM,PU BHA#15 Liner Running 0.0 562.0 13:24 15:36 Assembly Run#2,ported bull-nose, 12 joints 2-3/8"slotted liner,OH anchor&aluminum billet.Open choke at jnt#8,visual verification fluid level is stable, IA=203 psi. 5/13/2017 5/13/2017 2.20 COMPZ1 CASING RUNL P RIH with BHA#15,IA=238 psi.park 562.0 13,750.0 15:36 17:48 at 13,538'Close EDC.Wt Ck,40 k lbs. continue to RIH. IA fell to-200 once parked. 5/13/2017 5/13/2017 0.50 COMPZ1 CASING DLOG P Tie into K1 for-14'correction. 13,750.0 13,760.0 17:48 18:18 Page 17/35 Report Printed: 5/30/2017 • • - Operations Summary (with Timelog Depths) 1C-23 ConocoPtaitlips r'I.u:ks 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) 5/13/2017 5/13/2017 0.80 COMPZ1 CASING RUNL P Continue to RIH w upper A lat slip 14,497.0 14,497.0 18:18 19:06 oriented to 180°,tag up at 14,497', PU,42 k lbs,RBIH tag up,pull to neutral CT weight,31k ibs,stage pump up,Circ pressure fell off at 4,199 psi. PU,41 k free.-park,reset depths, 5/13/2017 5/13/2017 3.00 COMPZ1 CASING RUNL P POOH,holding a little choke pressure 14,497.0 88.0 19:06 22:06 while bleeding the IA to the TT. @ start of trip,IA out 8.5 ppg,PV 4 Yp 9, for comparison 8.7 ppg mud PV 3-6, Yp 25-29. 5/13/2017 5/13/2017 1.30 COMPZ1 CASING PULD P Bump up,bleed off IA to 185 psi, 88.0 0.0 22:06 23:24 Bleed off WH,start no flow test. Observe flow for 10 min.Bleed IA from 188 to 170 psi. flow stopped,IA pressure continued to climb.PJSM PUD BHA#15. IA fluid out density 8.6 PP9. 5/13/2017 5/14/2017 0.60 PROD2 STK PULD P PU BHA#16,L1 lat drilling assembly, 0.0 61.0 23:24 00:00 PD same. Run-30'of pipe down into the mouse hole and check for flat spots-good. Stab injector,Open up, bump up set depth, 5/14/2017 5/14/2017 0.50 PROD2 STK PULD P PU BHA#16,L1 lat drilling assembly, 0.0 61.0 00:00 00:30 PD same. Run-30'of pipe down into the mouse hole and check for flat spots-good.Check pack offs,good. Stab injector,Open up,bump up set depth, 5/14/2017 5/14/2017 2.70 PROD2 STK TRIP P Park @ 185',close EDC,shallow test 61.0 13,265.0 00:30 03:12 agitator-good. Park,open EDC, continue to RIH. Bleed IA taking returns to the TT while RIH,estimate 35 bbls returned. 5/14/2017 5/14/2017 0.20 PROD2 STK DLOG P Tie into K1 for-12.5' correction 13,265.0 13,275.0 03:12 03:24 5/14/2017 5/14/2017 1.40 PROD2 STK DISP P Continue to RIH displacing 10.3 KW 13,275.0 13,458.0 03:24 04:48 fluid and 15 bbl spacer,close EDC. 10.3 ppg strung out more than normal. Saw almost imediate density increase when reducing pump rate 04:36 as IA pressure dropped unloading into the tubing. Suspect tubing leak is very shallow. 5/14/2017 5/14/2017 0.50 PROD2 STK TRIP P Continue to RIH,pass through window 13,458.0 13,995.0 04:48 05:18 clean. Tag TOB at 13,995,PU Wt 38 k lbs. 5/14/2017 5/14/2017 0.30 PROD2 STK KOST P RBIH,set rate 1.80 bpm,off bottom, 13,995.0 13,995.7 05:18 05:36 CT 5084 psi,free spin diff 1000 psi Start time drilling of billet.Began to lose most returns at 5:35 am 5/14/2017 5/14/2017 1.00 PROD2 STK CIRC P Rate In=1.8 bpm,Rate Out=.33 13,995.7 13,557.0 05:36 06:36 bpm,dropping rate to.5 bpm in continues to show.33 bpm out, PUH to above window, by-pass MicroMotion to check for plugging of line,still showing losses,notify town, begin building 40 bbl 100K LSRV pill. Page 18/35 Report Printed: 5/30/2017 0 • 1114 •Operations SummarY (with Timelo Dphs) 1C-23 ConocoP s 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) 5/14/2017 5/14/2017 2.20 PROD2 STK CIRC P Circulating above window awaiting 13,557.0 13,990.0 06:36 08:48 100K LSRV pill.Begin sending 400 bll pill at 8:00 am,close EDC,stack weight at the window with pumps off, roll the bit,stack weight at the window 2 additional times,orient to 20°ROHS to pass,RIH to just above billet to begin squeezing pill, 5/14/2017 5/14/2017 1.30 PROD2 STK CIRC P Squeezing in 40 bbl,100K LSRV pill, 13,990.0 13,995.7 08:48 10:06 1 bpm,closed choke,WHP up to 830 psi,ECD= 11.5 ppg,IA=718 psi, shut-down pumps and allow pill to set gel strength(15 min MI recommendation),RBIH to KO billet, losses healed to only.61 bpm out pumping 1.8 bpm in. 5/14/2017 5/14/2017 1.60 PROD2 STK KOST P Time milling off billet at 13,996'MD, 13,995.7 13,999.0 10:06 11:42 Rate In=1.77 bpm,Rate Out=.58 bpm,FS=978 psi,CWT=10K,WOB =.7K,IA=387,OA=435. 5/14/2017 5/14/2017 1.30 PROD2 DRILL DRLG P Drilling"AL1"lateral,Rate In=1.77 13,999.0 14,097.0 11:42 13:00 bpm,Rate Out=.5 bpm,IA=499 psi, OA=440 psi,PUW=38K,dry drift billet area(good),FS=935 psi,CWT =9.5K,WOB=2K,ROP=200 fph. 5/14/2017 5/14/2017 1.00 PROD2 DRILL DRLG P PU for new parameters at reduced 14,097.0 14,175.0 13:00 14:00 rate,PUW=38 K,continue dirlling ahead,Rate In=1.5 bpm,Rate Out _.5 bpm,FS=700 psi,CWT=K, WOB=2.7K,IA=509 psi,OA=438 psi. 5/14/2017 5/14/2017 2.70 PROD2 DRILL DRLG P Time drill at/fph allowing DD to 14,175.0 14,180.0 14:00 16:42 confer with geology rig and geology town,as build rate is not being made according to well-plan,plan is to continue to time drill to gain purchase in Siderite,then begin drilling ahead at maximum ROP.(Desired Inclination is 95°,actual inclination is 88°) 5/14/2017 5/14/2017 0.80 PROD2 DRILL DRLG P Drilling ahead at 16,180',Rate In= 14,180.0 14,201.0 16:42 17:30 1.56 bpm,Rate Out=.81 bmp,CWT =7K,WOB=1K, FS=780 psi,IA= 537 psi,OA=443 psi. 5/14/2017 5/14/2017 0.70 PROD2 DRILL WPRT P Geo wiper to discuss options and path 14,201.0 13,291.0 17:30 18:12 forward 5/14/2017 5/14/2017 2.20 PROD2 DRILL TRIP P POOH for higher bend motor.Open 13,291.0 66.2 18:12 20:24 EDC at TOC. Start taking influx, (0.25-0.5 bpm as high as 1.5 bpm) from the well,suspect IA as we increased pulling speed to 110 ft/min. Activate choke to increase WH until 1 for 1 returns. WH 244 psi, 1.45 bpm in, 1.03 bpm out @ 110 ft/min. walking WH up slowly as we pull, Page 19/35 Report Printed: 5/30/2017 • Operations Summary (with Timelog Depths) r� 1C-23 conoco pimps 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) 5/14/2017 5/14/2017 1.20 PROD2 DRILL OWFF P Bump up,space out,shut in choke, 66.2 67.4 20:24 21:36 monitor pressures,consult w/town. WH 647 psi, IA 597 psi observed slow relaxation to WH of 618 psi and IA of 485 psi. Open choke,bleed WH to zero,S/I, pressure climbed rapidly to 176 psi and slowly kept rising. Attempted to bleed again,same results. S/I observed pressures stabilize at WH 324 and IA of 364 psi. Caught sample if IA fluid,slightly diluted Power Pro @ 8.6 ppg. 5/14/2017 5/14/2017 1.60 PROD2 DRILL PULD P Checks leaking bump pumps to reset, 67.4 0.0 21:36 23:12 no luck.PUD with leaking checks,LD BHA#16. Halliburton Slick Line on location,PJSM,spot up unit and start rig up. 5/14/2017 5/15/2017 0.80 PROD2 DRILL SLKL T Prep rig floor,prep S/L lubricator,load 0.0 0.0 23:12 00:00 into pipe shed and position on skate, rehead,PJSM, 5/15/2017 5/15/2017 2.50 PROD2 DRILL SLKL T Complete PJSM,S/L crew prepping 0.0 0.0 00:00 02:30 tool string. S/L crew change out, continue to rig up/spot unit. Strapped tiger tank, 15 bbls bleed off the IA. 5/15/2017 5/15/2017 2.60 PROD2 DRILL SLKL T Load S/L wireline valves,tool string, 0.0 0.0 02:30 05:06 stuffing box,and sheave/load cell on to rig floor via the beaver slide. Pick lubricator,hang sheaves,lubricate toolstring and plug,stab on. PT, leaking 0 ring,repair,PT to 1500 psi, good. 5/15/2017 5/15/2017 4.20 PROD2 DRILL SLKL T RIH,pump at.25 bpm with closed 0.0 13,387.0 05:06 09:18 choke to allow for HAL to set plug,set W-Plug,pressure up to 700 psi WHP, shut in to verify plug is set,WHP bleeds,though HAL believes plug is set. 5/15/2017 5/15/2017 1.50 PROD2 DRILL SLKL T POOH with Slick-line run#1,at 13,387.0 0.0 09:18 10:48 surface 10:50 am,PJSM to LD tools, W-Plug did not set &came back to surface on setting tools. 5/15/2017 5/15/2017 3.60 PROD2 DRILL SLKL T PJSM,confer with town&HAL, 0.0 0.0 10:48 14:24 decision made to call out 150 bbl seawater and bull-head to plug set depth(13,387'),call out Weatherford with ISO plug,increase lubricator length from 44'to 52'to allow for additional weight bar.Await ISO plug arrival 5/15/2017 5/15/2017 - 1.80 PROD2 DRILL SLKL T Seawater arrived,off-loaded,begin 0.0 0.0 14:24 16:12 bull-heading 125 bbl seawater. Pumping rate not to exceed 1000 psi on managed pressure,this pressure is achieved with rate in of 1.25 bpm. 5/15/2017 5/15/2017 1.30 PROD2 DRILL SLKL T Weatherford ISO-plug arrived to rig, 0.0 13,375.0 16:12 17:30 bring up tools&plug to rig floor.PU& RU to SL.Confer with Weatherford, HAL and Nabors to set ISO plug at 13,375'MD(SL counter depth of 13,389,+14'correction),below lowest GLV.Set time of 4 hrs agreed upon by town&Weatherford. Page 20/35 Report Printed: 5/30/2017 II " •rations Summary (with Timelog Depths) , 11114 1 C-23 +CmnocCiPhitii 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) 5/15/2017 5/15/2017 4.00 PROD2 DRILL SLKL T RIH,arrive at set depth of 13,375'at 13,375.0 13,375.0 17:30 21:30 19:20,reach 21:00 hr set time,allow 30 min for set actuation,HAL& Weatherford are satified with set,751b lighter PUW. 5/15/2017 5/15/2017 2.00 PROD2 DRILL SLKL T POOH,PJSM LD setting tools,stack 13,375.0 0.0 21:30 23:30 back lubricator,intall night cap. 5/15/2017 5/16/2017 0.50 PROD2 DRILL PRTS T Perfrom C-MITT/I/O pre= 0.0 0.0 23:30 00:00 481/452/439 psi,pressure up to 2500 psi with-1 bbl,40 strikes. 15 min T/I/O=2492/2435/509,30 min T/I/O= 2476/2425/460,-PASS 5/16/2017 5/16/2017 0.30 PROD2 DRILL PRTS T Bleed down WH and IA to 0,return-4 0.0 0.0 00:00 00:18 bbls. Fluid pack stack,returns to the floor,bleed to zero and shut in. 5/16/2017 5/16/2017 3.30 PROD2 DRILL PRTS T Start build up test 0.0 0.0 00:18 03:36 T/1/O pre=0/0/354 psi, Initial T/I/O= 1/0/385 psi, 15 min T/I/O=7/0/417,30 min T/I/O=9/0/425,run out 45 min T/1/0=11/0/429,60 min T/I/O= 15/0/431. Pressure continued to climb-2 psi per min monitored total of 3:30 final T/I/O=31/9/437 psi.-fail 5/16/2017 5/16/2017 13.40 PROD2 DRILL SLKL T Rig up HES S/L with catcher(3.5:" 0.0 0.0 03:36 17:00 bait sub,short piece of stem and a blind box),PT-good,RIH attempt to set catcher,catcher returned to surface,repeat,same result,rig up KO tool,drop catcher and chase in hole w KO tool,pull GLV @ 8214'and replace w/dummy,Pull GLV @ 6295' and replace w/dummy,Attempt to pull valve at station 1 3,537',no valve returned,re pin tool re-attempt,found grit in tools 5/16/2017 5/16/2017 2.00 PROD2 DRILL SLKL T PT 1,000 psi,RIH w/3"OK-6 and 1.25 0.0 0.0 17:00 19:00 JD to 3,544 SLM,(3,537'RKB)Latch GLV,Hit 3 OJ licks,POOH 5/16/2017 5/16/2017 2.50 PROD2 DRILL SLKL T Drop OJ's PT 1,000 psi,RIH w/3.5" 0.0 0.0 19:00 21:30 OK-1 and BK Latch on DV to same depth,POOH 5/16/2017 5/17/2017 2.50 PROD2 `DRILL SLKL T Add OJ's RIH w/3.5"GR to 13,389' 0.0 0.0 21:30 00:00 SLM,unable to equilize pressure, POOH 5/17/2017 5/17/2017 2.50 PROD2 'DRILL SLKL T At surface,Add 5'x 1.875 RLR,RIH 0.0 0.0 00:00 02:30 w/2.63"CENT,2.5"Blind Box to 13,394'SLMD,Jar DN 3 times,TBG dropped to 500 psi,pump thru plug Jar DN 5 more times,POOH 5/17/2017 5/17/2017 1.75 PROD2 DRILL SLKL T RIH,w/2.63"CENT 2.5"RS to 13,396' 0.0 0.0 02:30 04:15 SLMD,POOH,recover plug 5/17/2017 5/17/2017 2.00 PROD2 DRILL SLKL T RDMO HES SL 0.0 0.0 04:15 06:15 5/17/2017 5/17/2017 1.00 PROD2 DRILL DISP P displace coil to freshwater,valve crew 0.0 0.0 06:15 07:15 on location,service tree valves and Tangos. 5/17/2017 5/17/2017 0.50 PROD2 DRILL DISP P Pull checks and fluid pack/purge. 0.0 0.0 07:15 07:45 5/17/2017 5/17/2017 0.30 PROD2 DRILL SFTY P PJSM w crew and Matt Herrera, 0.0 0.0 07:45 08:03 AOGCC, Testing against the master valve,no plug. Page 21/35 Report Printed: 5/30/2017 Operations Summary (with Timelog Depths) 0.1111 1C-23 Cono itiip 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) 5/17/2017 5/17/2017 0.90 PROD2 WHDBOP BOPE P Attempt low pressure,building 0.0 0.0 08:03 08:57 pressure,bled,refluid pack,reattempt, build,bleed,cycle master,reatempt low-good,high-good. AOGCC start clock @ 9:00 for test time. 5/17/2017 5/17/2017 0.20 PROD2 WHDBOP BOPE P Test#1,swab#2,good 0.0 0.0 08:57 09:09 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#2,swab#1,good 0.0 0.0 09:09 09:27 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#3,lower blind/shear,BOP TV2, 0.0 0.0 09:27 09:45 good 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#4,BOP TV1,good 0.0 0.0 09:45 10:03 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE 'P Test#5,Upper blind/shear,Bravo/ & 0.0 0.0 10:03 10:21 5,Charlie 4,5,8,&12,Romeo 1 and bleeder/,good-simultaniously tested gas alarms,good 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#6,Charlie 3,6,7,&11,Bravo 2 0.0 0.0 10:21 10:39 &6&Tango 2.-good 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#7,Manual choke D&super 0.0 0.0 10:39 10:57 choke C.-good 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#8,Charlie 2, 10,and Tango 1.- 0.0 0.0 10:57 11:15 , good 5/17/2017 5/17/2017 0.40 PROD2 WHDBOP BOPE P Test#9,Romeo 2,Bleeder2,Charlie 0.0 0.0 11:15 11:39 1 &9. Slow bleed,shut both Swab 1&2,same trend,S/I Bleeder 4,test- Good. Opened it up post test,trend held-good 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#10,Bravo 4&8,Romeo 3 and 0.0 0.0 11:39 11:57 bleeder 3-good 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#11 ,Bravo 3&7-good 0.0 0.0 11:57 12:15 5/17/2017 5/17/2017 0.70 PROD2 WHDBOP BOPE P Test#12,PU and install test joint. 0.0 0.0 12:15 12:57 Annular,leaked off initially on the low, cycled it three times, -good 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#13,Upper 2-3/8 pipe slips, 0.0 0.0 12:57 13:15 Upper TIW 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#14,Lower 2-3/8 pipe slips 0.0 0.0 13:15 13:33 5/17/2017 5/17/2017 0.30 PROD2 WHDBOP BOPE P Test#15,Lower 2" pipe 0.0 0.0 13:33 13:51 5/17/2017 5/17/2017 0.20 PROD2 WHDBOP BOPE P Test#16,Upper 2" pipe,lower TIW 0.0 0.0 13:51 14:03 , 5/17/2017 5/17/2017 0.50 PROD2 WHDBOP BOPE P Pit alarms,flow verification w micro 0.0 0.0 14:03 14:33 motion,Accumulator draw down.- pass 5/17/2017 5/17/2017 0.80 PROD2 WHDBOP BOPE P Lay down test joint,stab in jector,test 0.0 0.0 14:33 15:21 inner reel iron,packoffs-good. 5/17/2017 5/17/2017 1.20 PROD2 DRILL CTOP P Bleed down,unstab injector,install 0.0 0.0 15:21 16:33 checks, link tilt friction grip slipped, loosen and retighten clamps. 5/17/2017 5/17/2017 2.25 PROD2 DRILL PULD P PJSM,PU/MU/PD AL1 build BHA#17, 0.0 0.0 16:33 18:48 1.5°bend motor and RR HCC bi- center bit. 5/17/2017 5/17/2017 0.50 PROD2 DRILL PULD P Surface test Coiltrak tools,Strip down 0.0 0.0 18:48 19:18 INJH,check pac-offs,open BOP,tag up reset counters Page 22/35 Report Printed: 5/30/2017 `,.' Operations Summary (with Timelog Depths) 0 1C-23 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) 5/17/2017 5/17/2017 2.50 PROD2 DRILL TRIP P RIH,circulating coil to 8.6 ppg Drilling 0.0 13,250.0 19:18 21:48 fluid system#2 5/17/2017 5/17/2017 0.25 PROD2 DRILL DLOG P Log the K1 marker correction of minus 13,250.0 13,270.0 21:48 22:03 4.0' 5/17/2017 5/17/2017 0.75 PROD2 DRILL DISP P Displace well to 8.6 ppg drilling fluid 13,270.0 13,400.0 22:03 22:48 system#2 5/17/2017 5/17/2017 0.25 PROD2 DRILL TRIP P RIH,thru pilot hole/window clean,RIW 13,400.0 14,201.0 22:48 23:03 10 k 5/17/2017 5/18/2017 0.96 PROD2 DRILL DRLG P BOBD, 1.5 bpm at 3,000 psi off 14,201.0 14,217.0 23:03 00:00 bottom,BHP 3,804,WHP 0, IA 564, OA 443,ROP 12-25 fph,DHWOB 2.5 k,***Take 23 bbls returns to tiger *** 5/18/2017 5/18/2017 4.50 PROD2 DRILL DRLG P OBD, 1.49 bpm at 3,324 psi,BHP 14,217.0 14,471.0 00:00 04:30 3,822,WHP 45, IA 576,OA 443,ROP 182 fph,DHWOB 2.7 k 5/18/2017 5/18/2017 1.00 PROD2 DRILL DRLG P OBD, 1.52 bpm at 2,927 psi,BHP 14,471.0 14,490.0 04:30 05:30 • 3,862,WHP 0, IA 578,OA 445,ROP 13 fph,DHWOB 3 k,CTSW 2.7 k. 5/18/2017 5/18/2017 0.40 PROD2 DRILL TRIP P POOH,PU Wt 38 k,DD has what he 14,490.0 13,421.0 05:30 05:54 needs in regards to build turn. Tripping for AL1 lat drilling assembl;y, 1°AKO motor below an agitator. 5/18/2017 5/18/2017 0.20 PROD2 DRILL TRIP P Park,open EDC, 13,421.0 13,421.0 05:54 06:06 5/18/2017 5/18/2017 2.10 PROD2 DRILL TRIP P Continue to POOH,pumping 1.69 13,421.0 67.0 06:06 08:12 bpm in,returning 1.43 bpm out,pulling at 110 ft/min. taking influx while pulling,manipulate choke to hold 1 for 1 returns. Instal second IA casing valve and T. 5/18/2017 5/18/2017 1.40 PROD2 DRILL PULD P PUD&LD BHA#17 67.0 0.0 08:12 09:36 5/18/2017 5/18/2017 1.60 PROD2 DRILL PULD P PU&PD BHA#18, 1°AKO motor w 0.0 77.0 09:36 11:12 agitator.Inspect and replace pack off element. 5/18/2017 5/18/2017 2.50 PROD2 DRILL TRIP P RIH 77.0 13,260.0 11:12 13:42 5/18/2017 5/18/2017 0.20 PROD2 DRILL DLOG P Tie in to K1 for-12'correction 13,260.0 13,273.0 13:42 13:54 5/18/2017 5/18/2017 0.60 PROD2 DRILL TRIP P Wt Chk,38k lbs,Close EDC,continue 13,273.0 14,490.0 13:54 14:30 to RIH. 5/18/2017 5/18/2017 2.80 PROD2 'DRILL TRIP P RIH Wt 5.9 k lbs, 1.58 bpm in, 1.2 14,490.0 14,744.0 14:30 17:18 bpm out,fee spin diff 790 psi. OBD,CT Wt 4 k lbs,WOB 1.26,ROP 140 ft/hr ROP increased,PU on short wiper 42 k lbs,increased rate to 1.7 bpm in, 1.3 bpm out Free spin diff,845 psi,WOB 1.8 k lbs, ROP-180 ft/hr losses healed to 1.34 bpm BHA wiper,PU 45k lbs,Increase rate to 1.80 bpm in,wipe 100' RBIH Wt 5k lbs Free spin diff,940 psi,CT 4200 psi, CT Wt 0 k lbs WOB 1.8 k lbs,ROP 45 Page 23/35 Report Printed: 5/30/2017 0 0 Operations Summary (with Timelog Depths)) i� Y:.y et 1C-23 ConocoPhiiiips 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) 5/18/2017 5/18/2017 3.00 PROD2 DRILL DRLG P OBD, 1.8 bpm in, 1.4 bpm out,CT 14,744.0 15,000.0 17:18 20:18 pressure 4427 psi CT Wt 0 k lbs,WOB 1.7 k ROP 120 ft/hr PU Wts 42k 5/18/2017 5/18/2017 0.50 PROD2 DRILL WPRT P Wiper up hole @ 50 bpm.PUW 40 k, 15,000.0 14,050.0 20:18 20:48 pumping 1.8 bpm at 4,420 psi, BHP 4,046,WHP 0,IA 694,OA 449 5/18/2017 5/18/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 8 k,pumping 14,050.0 15,000.0 20:48 21:18 1.3 bpm at 3,233 psi. 5/18/2017 5/19/2017 2.70 PROD2 DRILL DRLG P BOBD,1.8 bpm at 4,574 psi,BHP 15,000.0 15,233.0 21:18 00:00 4,076,WHP 0,IA 705,OA 450,MM out 1.33 bpm. 5/19/2017 5/19/2017 4.00 PROD2 DRILL DRLG P OBD, 1.8 bpm at 4,459 psi,BHP 15,233.0 15,400.0 00:00 04:00 4,110,WHP 0,IA 717,OA 450,out MM 1.33,pump 5 lowvis x 5 highvis sweep 5/19/2017 5/19/2017 0.35 PROD2 DRILL WPRT P Wiper up hole,PUW 40 k,pumping 15,400.0 14,400.0 04:00 04:21 1.82 bpm at 4,378 psi,BHP 4,054, WHP 0, IA 706,OA 451. 5/19/2017 5/19/2017 0.30 PROD2 DRILL WPRT P Wiper back in hole, RIW 5 k,pumping 14,400.0 14,401.0 04:21 04:39 1.2 bpm at 3,116 psi,BHP 4037,WHP 0, IA 707,OA 451,returns 1.2 bpm 5/19/2017 5/19/2017 2.10 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 4,412 psi,BHP 14,401.0 15,487.0 04:39 06:45 4,109,WHP 0,IA 707,OA 451, DHWOB 1 k,CTSW 2 k,ROP 75 fph. 5/19/2017 5/19/2017 1.00 PROD2 DRILL WPRT P POOH,PU Wt,46 k,lbs,chasing 15,487.0 13,250.0 06:45 07:45 sweeps up hole, 5/19/2017 5/19/2017 0.10 PROD2 DRILL WPRT P Park,open EDC,pick up rate to 2.17 13,250.0 13,250.0 07:45 07:51 bpm, 1.67 bpm out. chase sweeps, and circ bottoms up. 5/19/2017 5/19/2017 0.10 PROD2 DRILL DLOG P Tie into K1 for+4' 13,250.0 13,278.0 07:51 07:57 5/19/2017 5/19/2017 0.50 PROD2 DRILL WPRT P Circ bottoms up,good cuttings 13,278.0 13,436.0 07:57 08:27 returned to the shaker. 5/19/2017 5/19/2017 0.10 PROD2 DRILL WPRT P S/D,Close EDC, 13,436.0 13,436.0 08:27 08:33 5/19/2017 5/19/2017 0.10 PROD2 DRILL WPRT P RBIH,slight bobble while tripping 13,436.0 15,487.0 08:33 08:39 through window,decent set down @ 13,927' 5/19/2017 5/19/2017 2.90 PROD2 DRILL DRLG P RIH wt 4.7 k lbs, 1.80 bpm,1.22 out, 15,487.0 15,569.0 08:39 11:33 950 psi free spinn OBD,CT 4729 psi,CT Wt 0 to-6k lbs, WOB 1.46 k lbs ROP 80 to 40 ft/hr. Drilling through some hard stringers, poor weight transfer at times,Out rates climded back to 1.5 bpm 5/19/2017 5/19/2017 0.20 PROD2 DRILL DRLG P Built beaded pill,pumped 10 bbl 15,569.0 15,576.0 11:33 11:45 sweep Pre CT Wt-5 k lbs,WOB 0.76 k lbs, ROP 61 ft/hr post 5/19/2017 5/19/2017 0.20 PROD2 DRILL WPRT P DD GEO wiper 15,576.0 15,576.0 11:45 11:57 Page 24/35 Report Printed: 5/30/2017 • Of,I. Operations Summary (with Timelog Depths) 1 C-23 ConocoPhiilips 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) 5/19/2017 5/19/2017 4.80 PROD2 DRILL DRLG P RBIH, 1.80 bpm in, 1.45 bpm out,free 15,576.0 15,747.0 11:57 16:45 spin 1050 psi BOBD beaded pill exited the bit CT Wt 0 k lbs,WOB 1 k lbs,ROP 70 ft/hr,effects short lived. Drill ahead while sending sweeps and performing pick ups as needed. Averaged 36 ft/hr over interval 5/19/2017 5/19/2017 0.20 PROD2 DRILL WPRT P 1000'wiper, PU Wt 46 k lbs, 15,747.0 14,747.0 16:45 16:57 5/19/2017 5/19/2017 0.40 PROD2 DRILL WPRT P RBIH,RIH Wt 4 k lbs 14,747.0 15,747.0 16:57 17:21 5/19/2017 5/19/2017 5.00 PROD2 DRILL DRLG P 1.80 bpm in 1.35 bpm out,free spin dif 15,747.0 15,885.0 17:21 22:21 900 psi OBD,CT 4871 psi,CT Wt-4.7 k lbs, WOB 0.74 k lbs,ROP 100 initially 5/19/2017 5/19/2017 0.50 PROD2 DRILL WPRT P Wiper up hole,PUW 48 k,pumping 15,885.0 14,885.0 22:21 22:51 1.8 bpm at 4,747 psi,BHP 4,224, WHP 0, IA 754,OA 450 5/19/2017 5/19/2017 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 4 k,pumping 14,885.0 15,885.0 22:51 23:21 1.2 bpm at 3,850 psi 5/19/2017 5/20/2017 0.65 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 3,845 psi,BHP 15,885.0 15,901.0 23:21 00:00 4,200,WHP 0,IA 755,OA 450, fighting weight transfer. 5/20/2017 5/20/2017 0.30 PROD2 DRILL WPRT P TD well,recip pipe while circulating 10 15,901.0 14,000.0 00:00 00:18 x 10 sweep,chase to surface 5/20/2017 5/20/2017 1.50 PROD2 DRILL WPRT P POOH,started pulling heavy with 14,000.0 14,750.0 00:18 01:48 motor word betwen 14,750'to 14,000', RBIH and clean hole. 5/20/2017 5/20/2017 3.25 PROD2 DRILL WPRT P POOH,pumping 1.8 bpm at 4,895 psi, 14,750.0 78.2 01:48 05:03 BHP 4,476,WHP 0, IA 783,OA 451 5/20/2017 5/20/2017 1.70 PROD2 DRILL CTOP T Tag up at surface,inspect pac-off,do 78.2 78.2 05:03 06:45 to finding energizer pieces on top of stripper,replace and clean out pack off rubble from between brass. Opened up to 750 psi well head, calculated 10.8 psi using 6554 tvd window depth and 8.6 ppg fluid. 5/20/2017 5/20/2017 2.50 PROD2 DRILL TRIP P RIH varying the choke to maintain 1 78.2 13,258.0 06:45 09:15 for 1 or less returns. Pushed away 5 bbls. 5/20/2017 5/20/2017 0.20 PROD2 DRILL DLOG P Tie into the K1 for-9.5'correction. 13,258.0 13,267.0 09:15 09:27 5/20/2017 5/20/2017 1.30 PROD2 DRILL TRIP P Continue to RIH,park at 13575 bit 13,267.0 15,904.0 09:27 10:45 depth,corrected DPS @ 6545 considering 95'sub sea correction and sensor off set from bit depth. Initial pressure=3689 psi,steady @ 3653 psi after 10 min. calculate BHP EMW @ 10.73 ppg,weight up KW fluid from 10.8 ppg to 11.0 ppg. Clean window, clean billet,continue to RIH,tag bottom 15,904',PU Wt 38 k. Pushed away 25.5 bbls while running in open hole. 5/20/2017 5/20/2017 0.80 PROD2 DRILL DISP P Displace coil to 11.0 ppg liner running 15,904.0 15,904.0 10:45 11:33 pill,pushed away 25 bbls. Page 25/35 Report Printed: 5/30/2017 • t' Operations Summary (with Timelog !ths) 1C-23 Conoc illips A(,rA.a 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) 5/20/2017 5/20/2017 0.80 PROD2 DRILL DISP P PUH laying in47 bbls of 2 ppb alpine 15,904.0 13,595.0 11:33 12:21 bead, 11.0 ppg liner running pill,0.64 bpm in,-0.44 bpm out @ 45.9 ft/min. pushed away 1 bbl 5/20/2017 5/20/2017 3.00 PROD2 DRILL DISP P Continue PUH laying in remaining 13,595.0 97.0 12:21 15:21 liner running pill to 11,750'. and 11.0 ppg KWF to surface. Painted yellow TD flag @ 13688.9 and White EOP flag at 11278.25'. pushed away 2 bbls 5/20/2017 5/20/2017 0.60 PROD2 DRILL OWFF P Stop short to enable pipe inspection, 97.0 97.0 15:21 15:57 Open bleeder on the stack,fluid pack stack,IA 558 psi,observe sustained flow,open la to bleed,flow at the stack instantly stops,bleed IA to 403 psi,S/I, IA rapidly climbed to 500 psi, and slowly climbed to 515 psi. Flood stack,returns to half drum,observe for flow, IA climbed slowly to 542 psi, 5/20/2017 5/20/2017 2.00 PROD2 DRILL OWFF P Bleed IA, 15 minutes,pressure fell 97.0 97.0 15:57 17:57 from 543 psi to 321 psi,S/I pressure built back up slowly, filled the hole,no flow. IA pressure built to 501 psi and stabilized,no flow. 5/20/2017 5/20/2017 1.05 PROD2 DRILL PULD P PJSM,UD Drilling BHA#18 97.0 0.0 17:57 19:00 5/20/2017 5/20/2017 0.50 COMPZ2 CASING SFTY ' P Prep to run liner,PJSM 0.0 0.0 19:00 ' 19:30 5/20/2017 5/20/2017 1.25 COMPZ2 CASING PUTB P Run 20 jts of 2-3/8"slotted liner 0.0 800.6 19:30 20:45 5/20/2017 5/20/2017 0.25 COMPZ2 CASING SFTY P Kick while tripping drill on Joint#20, 800.6 800.6 20:45 21:00 (time 3.10 mins),AAR in dog house, LD safety joint, 5/20/2017 5/20/2017 1.50 COMPZ2 CASING PUTB P Continue running liner.35 jts of slotted 800.6 2,226.6 21:00 22:30 liner 5/20/2017 5/20/2017 0.75 COMPZ2 CASING PULD P PJSM,PU/MU Aluminum Top Billet 2,226.6 2,288.3 22:30 23:15 and Coiltrak tools,close 2-3/8" combi's,surface test tools good test. stab INJH,open combi's,tag up and reset counters 5/20/2017 5/21/2017 0.75 COMPZ2 CASING RUNL P RIH w/BHA#19 AU !finer assembly 2,288.3 5,612.0 23:15 00:00 5/21/2017 5/21/2017 1.40 COMPZ2 CASING RUNL 'P Continue RIH with AL2 liner assembly 5,612.0 11,688.0 00:00 01:24 5/21/2017 5/21/2017 1.00 COMPZ2 CASING RUNL P Lost all returns,continue RIH,WC= 11,688.0 14,375.0 01:24 02:24 44 k 5/21/2017 5/21/2017 0.60 COMPZ2 CASING RUNL P Work pipe down hole from 14,375'to 14,375.0 15,273.0 02:24 03:00 15,273', 5/21/2017 5/21/2017 1.00 COMPZ2 CASING RUNL T Unable to move liner,work pipe at 15,273.0 15,273.0 03:00 04:00 15,275',max pull 65 k,call town and disscuss plan forward,decision was made to MU beaded pill,and circulate down the backside. 5/21/2017 5/21/2017 3.10 COMPZ2 CASING RUNL T Standby Making 50 bbl beaded pill 15,273.0 15,273.0 04:00 07:06 Page 26/35 Report Printed: 5/30/2017 'a gii/ Operations Summary (with Timelog Depths) 0 a. 1C-23 ConocoPhillip4 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) 5/21/2017 5/21/2017 2.70 COMPZ2 CASING RUNL T On line 0.56 bpm bullheadding 11.0 15,254.0 15,254.0 07:06 09:48 ppg beaded liner running pill down the coil by tubing annulus. Well head innitial 570 psi,staged pump rate back to 0.4 bpm as WH rose to 980 psi. 5/21/2017 5/21/2017 0.90 COMPZ2 CASING RUNL T S/D,WH relaxed to 530 psi,opened 15,254.0 15,254.0 09:48 10:42 up to the shaker,bleed WH down to 150 psi,climbed back to 167 psi. Squat down on billet to-5k,cycled pipe to max 67k,pumps on&off,min rate,up to 50 ft/min pulling speed. No movement 5/21/2017 5/21/2017 1.00 COMPZ2 CASING RUNL T talk with town,worked pipe for—1 hr, 15,254.0 15,254.0 10:42 11:42 22 cycles,squat down to-19k lbs,pull to 73 k lbs,pulling speeds up to 100 ft/min,pumps off and on,rate up to 1 bpm. Slow stedy pull and sling shot, bleed WH,surge pumps,-No movement. 5/21/2017 5/21/2017 4.60 COMPZ2 CASING RUNL T Consult w town,build two pits of liner 15,254.0 15,254.0 11:42 16:18 running pill w 2.5/2.5%776/low torque. 5/21/2017 5/21/2017 2.50 COMPZ2 CASING RUNL T Start pumping liner running pill @ 0.52 15,254.0 15,254.0 16:18 18:48 bpm,WH 658 psi,BHP 3817 psi. 5/21/2017 5/21/2017 1.25 COMPZ2 CASING RUNL T Beads on the back side to surface, 15,254.0 15,254.0 18:48 20:03 S/D pump, work pipe-5 k up to 70 k, no movement 5/21/2017 5/21/2017 1.00 COMPZ2 CASING RUNL T Discuss options with town team,work 15,254.0 15,254.0 20:03 21:03 pipe in 5 k increments 75 k to 78 k, pulled free seeing drag on CTSW 10 k -12 k,DHWOB-13 k 5/21/2017 5/21/2017 0.75 COMPZ2 CASING RUNL T POOH 15,254.0 13,883.0 21:03 21:48 5/21/2017 5/21/2017 0.25 COMPZ2 CASING OWFF T Park Coil,perform flow check,good 13,883.0 13,883.0 21:48 22:03 flow check 5/21/2017 5/22/2017 1.96 COMPZ2 CASING RUNL T Continue POOH 13,883.0 2,384.0 22:03 00:00 5/22/2017 5/22/2017 0.50 COMPZ2 CASING RUNL , T Continue POOH, 2,384.0 2,288.0 00:00 00:30 5/22/2017 5/22/2017 2.25 COMPZ2 CASING OWFF T Tag up at surface,space out,perform 2,288.0 2,288.0 00:30 02:45 flow check,flow observed,shut choke, bullhead kill weight 11.0 ppg,30 bbls down the backside,bleed WHP down, bleed IA pressure down to 355 psi, monitor well,no-flow observed, 5/22/2017 5/22/2017 1.08'COMPZ2 CASING PULL T Dead well,PJSM,close rams,L/D 2,288.0 2,243.8 02:45 03:49 Coiltrak tools using the mouse hole, observed flow at well head,bleed IA pressure down to 355 psi,monitor well while rigging up to LD liner assembly. 5/22/2017 5/22/2017 4.70 COMPZ2 CASING PULL T PJSM,LD liner 2,243.8 0.0 03:49 08:31 5/22/2017 5/22/2017 1.50 COMPZ2 CASING PULD T Clean rig floor of liner running equip, 0.0 62.0 08:31 10:01 PJSM,PU&deploy BHA#20,clean out assembly, 1°AKO motor W D331 bit. Page 27/35 Report Printed: 5/30/2017 Operations Summary (with Timelog Depths) 0.0 .4lo) 1 C-23 Cortoct')Phillips it:rks 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) 5/22/2017 5/22/2017 0.50 COMPZ2 CASING PULD T Inspect pack offs-good,bump up,set 62.0 62.0 10:01 10:31 counters 5/22/2017 5/22/2017 0.50 COMPZ2 CASING TRIP T RIH pumping 11 ppg KW min rate, 62.0 13,240.0 10:31 11:01 WH 513, IA 618 psi 5/22/2017 5/22/2017 0.50 COMPZ2 CASING DLOG T Tie into K1 for No correction. 13,240.0 13,258.0 11:01 11:31 5/22/2017 5/22/2017 0.50 COMPZ2 CASING TRIP T Continue to RIH,confirm RA,zero 13,258.0 14,250.0 11:31 12:01 correction.continue to RIH,small bobble in CT weight @ 13,785',and again,known spot at 13,922'with slight WOB bobble too,2.4k. 5/22/2017 5/22/2017 3.20 COMPZ2 CASING DISP T Displace CT with 50 bbls of liner 14,250.0 14,100.0 12:01 15:13 running pill,poor returns, 5/22/2017 5/22/2017 3.40 COMPZ2 CASING DISP T POOH laying in beaded liner running 14,100.0 44.7 15:13 18:37 pill,paint window flag,white,@ 13062.49 and TD flag,yellow @ 13652.53,top of beaded liner running pill 10,500. 5/22/2017 5/22/2017 1.20 COMPZ2 CASING OWFF T Bump up,Bleed IA for 10 minutes and 44.7 44.6 18:37 19:49 observe for 10 minutes,pressure built rapidly to above 510 psi,repeat, pressure built more slowly,repeat bleed a third time same results. Flow check continued to flow fluid to hald drum at the stack during the wole time. Consulted w town. 5/22/2017 5/22/2017 2.70 COMPZ2 CASING WAIT T Build 50 bbl liner running pill. Observe 44.7 44.6 19:49 22:31 Expro choke pressure increase from 15 psi to 43,Wellhead from 0 to 14 psi,and IA built to 506 psi in 1 hr and stabilized. 5/22/2017 5/23/2017 1.48 COMPZ2 CASING DISP T Start pumping liner running pill down 44.7 44.6 22:31 00:00 the back side at 0.5 bpm. Work rate up o 1.15 bpm. WH @ 372,Expro choke,(closer to the well is reading -408 psi) 5/23/2017 5/23/2017 0.34 COMPZ2 CASING DISP T Continue bullheading KW down TBG 44.6 44.6 00:00 00:20 5/23/2017 5/23/2017 1.66 COMPZ2 CASING OWFF T Monitor well and IA,bleed 20.5 bbls 44.6 44.6 00:20 02:00 back to the pits,monitor well,dead well 5/23/2017 5/23/2017 0.85 COMPZ2 CASING PULD T PJSM,LD Coiltrak tools 44.6 0.0 02:00 02:51 5/23/2017 5/23/2017 0.80 COMPZ2 CASING PUTB T PJSM,PU/MU 9 jts of 2-3/8"slotted 0.0 384.0 02:51 03:39 liner w/OH Anchored Billet. 5/23/2017 5/23/2017 1.00 COMPZ2 CASING PULD T PU Coiltrak tools,changed out checks 384.0 445.2 03:39 04:39 in UQ,MU CoilTrak tools,surface test, (good test) 5/23/2017 5/23/2017 0.30 COMPZ2 CASING RUNL T Inspect pack pac-offs(good),stab 445.2 445.2 04:39 04:57 INJH,tag up,reset counters,(OPEN EDC) 5/23/2017 5/23/2017 3.00 COMPZ2 CASING RUNL T RIH,80 fpm slowing down to 20 fpm 445.2 13,620.0 04:57 07:57 past jewelry w/open EDC,correct to the EOP flag,minus 16' 5/23/2017 5/23/2017 0.25 COMPZ2 CASING RUNL T Log the K1 marker correction of plus 13,620.0 13,632.0 07:57 08:12 10.0' 5/23/2017 5/23/2017 0.31 COMPZ2 CASING RUNL T Continue RIH through window to 13,632.0 14,044.0 08:12 08:30 setting depth. Page 28/35 Report Printed: 5/30/2017 Operations Summary (with Timelog Depths) 1C-23 ConocaPhi [0 lips 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) 5/23/2017 5/23/2017 0.25 COMPZ2 CASING RUNL T Bring pump up to shear 3,891 psi,set 14,044.0 13,471.0 08:30 08:45 down 5 k DHWOB,PUH clean,PUH to above cement. 5/23/2017 5/23/2017 1.00 COMPZ2 CASING DISP P Open EDC,Displace well to 8.7 ppg 13,471.0 13,471.0 08:45 09:45 drilling fluid 5/23/2017 5/23/2017 2.25 COMPZ2 CASING TRIP P POOH,displacing well from 11.0 ppg 13,471.0 61.1 09:45 12:00 to 8.6 ppg Power-Pro 5/23/2017 5/23/2017 1.50 COMPZ2 CASING PULD P PJSM,for PUD and LD liner running 61.1 0.0 12:00 13:30 BHA 5/23/2017 5/23/2017 1.25 PROD3 STK PULD P PJSM,PU/MU/PD AL2 kickoff/drilling 0.0 72.2 13:30 14:45 BHA#22 5/23/2017 5/23/2017 0.50 PROD3 STK PULD P Surface test Coiltrak tools,good test, 72.2 72.2 14:45 15:15 strip INJH down, PT QTS,Open rams, tag up,reset counters 5/23/2017 5/23/2017 2.50 PROD3 STK TRIP P RIH,AL2 kickoff/drilling BHA#22 with 72.2 13,245.0 15:15 17:45 Baker X-treme motor and HYC bi- center bit. 5/23/2017 5/23/2017 0.30 PROD3 STK DLOG P Log K1 tie in for-13.5',Shut EDC, 13,245.0 13,287.0 17:45 18:03 5/23/2017 5/23/2017 0.40 PROD3 STK TRIP P Continue in well,Clean pass through 13,287.0 13,660.0 18:03 18:27 window,Dry tag TOB @ 13660 5/23/2017 5/23/2017 1.10 PROD3 STK MILL P Pull up off billet,PUW=39K,Pumps on 13,660.0 13,660.6 18:27 19:33 1.6 BPM @ 3504 PSI FS,BHP=3900. Start time milling @ 13659.4 TF=60° LOHS 5/23/2017 5/23/2017 0.50 PROD3 STK MILL P Time drilling off billet,Go to 2 Ft/Hr 13,660.6 13,661.7 19:33 20:03 5/23/2017 5/23/2017 0.20 PROD3 STK MILL P Time drilling off billet,Go to 3 Ft/Hr 13,661.7 13,662.5 20:03 20:15 5/23/2017 5/23/2017 0.20 PROD3 DRILL DRLG P Control drill with 1K WOB, 1.6 BPM @ 13,662.5 13,667.0 20:15 20:27 3505 PSI FS,BHP=3936 5/23/2017 5/23/2017 2.30 PROD3 DRILL DRLG P go to normal drilling, 1.6 BPM @ 3505 13,667.0 13,813.0 20:27 22:45 PSI FS,BHP=3940. 1.5 BPM out 5/23/2017 5/23/2017 0.10 PROD3 DRILL WPRT P Stall,Mini BHA wiper, PUW=42K 13,813.0 13,813.0 22:45 22:51 5/23/2017 5/23/2017 PROD3 DRILL DRLG P 13813',Drill, 1.68 BPM @ 3710 PSI 13,813.0 13,914.0 22:51 22:51 FS,BHP=4016 5/24/2017 5/24/2017 2.40 PROD3 DRILL DRLG P 13941',Drill, 1.68 BPM @ 3710 PSI 13,914.0 14,100.0 00:00 02:24 FS,BHP=4026 5/24/2017 5/24/2017 0.30 PROD3 DRILL WPRT P Wiper to window with pressure survey 14,100.0 13,575.0 02:24 02:42 and tie in 5/24/2017 5/24/2017 0.30 PROD3 DRILL OTHR P Obtain static pressure,2:40, 13,575.0 13,575.0 02:42 03:00 WHP=525,Exp=590,IA=631, OA=453,Ann=3941 2:45, WHP=623,Exp=676,IA=654, OA=453,Ann=3942 2:50, WHP=641,Exp=694,IA=659, OA=453,Ann=3941 2:55, WHP=660, Exp=713, IA=663, OA=452,Ann=3941 Pressure sensor @ 13533, TVD=6431.9 Sub Sea 5/24/2017 5/24/2017 0.20 PROD3 DRILL DLOG P Log RA for+.5 13,575.0 13,642.0 03:00 03:12 5/24/2017 5/24/2017 0.20 PROD3 DRILL 'TRIP P Run back in hole to drill,Billet area 13,642.0 14,100.0 03:12 03:24 clean up and down Page 29/35 Report Printed: 5/30/2017 • • O 'CA Operations Summary (with Timelog Depths) 1C-23 ConocoPhillips ALxk: 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) 5/24/2017 5/24/2017 3.00 PROD3 DRILL DRLG P 14100',drill, 1.72 BPM @ 3923 PSI 14,100.0 14,305.0 03:24 06:24 FS,BHP=4047, 14,191'lower pump rate to try and get turn.1.5 bpm at 3,496 psi 5/24/2017 5/24/2017 0.60 PROD3 DRILL WPRT P Geo wiper for projections 14,305.0 14,305.0 06:24 07:00 5/24/2017 5/24/2017 2.00 PROD3 DRILL DRLG P BOBD,1.52 bpm at 3,526 psi,BHP 14,305.0 14,364.0 07:00 09:00 4,409,WHP 52,IA 580,OA 450, 14,322'bring pump up 1.8 bpm at 5/24/2017 5/24/2017 0.00 PROD3 DRILL DRLG P Perform mud swap on bottom 14,364.0 14,364.0 09:00 09:00 5/24/2017 5/24/2017 0.30 PROD3 DRILL DRLG P Contiue Drilling ahead, 1.8 bpm at 14,364.0 14,386.0 09:00 09:18 4,194 psi,BHP 4,006,WHP 0,IA 596, OA 451 5/24/2017 5/24/2017 0.25 PROD3 DRILL WPRT P 100 ft BHA wiper,PUW 43 k 14,386.0 14,286.0 09:18 09:33 5/24/2017 5/24/2017 0.25 PROD3 DRILL WPRT P Wiper back in hole,RIW 14,286.0 14,386.0 09:33 09:48 5/24/2017 5/24/2017 3.50 PROD3 DRILL DRLG P BOBD,1.8 bpm at 4,194 psi,BHP 14,386.0 14,640.0 09:48 13:18 4,044,WHP 0, IA 596,OA 451 5/24/2017 5/24/2017 0.60 PROD3 DRILL DRLG P OBD, 1.79 bpm at 4,473 psi,BHP 14,640.0 14,702.0 13:18 13:54 4,058,WHP 0, IA 620,OA 452,CTSW 1 k,DHWOB 1.8 k,ROP 109 fph, Diff=450 psi 5/24/2017 5/24/2017 0.80 PROD3 DRILL WPRT P Wiper to billet,PUW=38K. 14,702.0 14,702.0 13:54 14:42 5/24/2017 5/24/2017 1.30 PROD3 DRILL DRLG P BOBD,CWT=3K, WOB=1.8K,FS= 14,702.0 14,850.0 14:42 16:00 650 psi,WHP=0 psi,IA=597 psi, Rate In=1.8 bpm,Rate Out=1.8 bpm. 5/24/2017 5/24/2017 0.70 PROD3 DRILL WPRT P Geo wiper up to 14,550'to plan 14,850.0 14,850.0 16:00 16:42 targets 5/24/2017 5/24/2017 3.20 PROD3 DRILL DRLG P BOBD pumping 1.8 bpm,CWT=1K, 14,850.0 15,100.0 16:42 19:54 WOB=2.2K,FS=675 psi,WHP=0 psi, IA=606 psi,ROP=120 fph. 5/24/2017 5/24/2017 0.80 PROD3 DRILL WPRT P 15,100', 1050'wiper,PUW=35K 15,100.0 15,100.0 19:54 20:42 5/24/2017 5/25/2017 3.30 PROD3 DRILL DRLG P 15,100',Drill, 1.79 BPM @ 4138 PSI 15,100.0 15,271.0 20:42 00:00 FS,BHP=4127,Midnight depth 15271 5/25/2017 5/25/2017 1.00 PROD3 DRILL DRLG P Drilling,1.77 BPM @ 4142 PSI FS, 15,271.0 15,285.0 00:00 01:00 BHP=4138,Encountered tough spot @ 15285.Stacking with little WOB 5/25/2017 5/25/2017 0.20 PROD3 DRILL WPRT P Perform BHA Wiper to 15,000', 15,285.0 15,285.0 01:00 01:12 PUW=40K 5/25/2017 5/25/2017 0.80 PROD3 DRILL DRLG P 15,285',Drill, 1.48 BPM @ 3575PSI 15,285.0 15,290.0 01:12 02:00 FS,BHP=4115,Still having tough time getting drilling with multiple pick ups. Poor weight transfer.Pump 10 X 10 sweeps.Continue trying to drill waiting on sweeps.TD AL2 is 15290',Avg DLS=14.75°for lateral 5/25/2017 5/25/2017 4.20 PROD3 DRILL TRIP P Sweeps out,No change in drilling 15,290.0 72.0 02:00 06:12 performance,Trip out.EDC shut 5/25/2017 5/25/2017 1.40 PROD3 DRILL PULD P PJSM,PUD&LD BHA#22,blow- 72.0 0.0 06:12 07:36 down motor(Bit came out a 3-1) 5/25/2017 5/25/2017 2.30 COMPZ3 CASING PULD P PJSM,PU&PD BHA#23-ported bull 0.0 81.0 07:36 09:54 -nose,8'drilled pup jnt,OH anchor& aluminum billet(BHA#23 pre-loaded in PDL),tag up Page 30/35 Report Printed: 5/30/2017 ' • 0Operations Summary (with Timelog Depths) 1C-23 Cmc#2 11 11Wps Als.ks 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) 5/25/2017 5/25/2017 3.30 COMPZ3 CASING RUNL P RIH with liner, EDC open,tie into K1 81.0 14,220.0 09:54 13:12 for-4.5'correction,continue RIH, close EDC, bring up pumps to 1.1 bpm at set depth,4800 psi circ pressure,release off liner,set down 3.8K WOB to confirm,TOB=14,200' 5/25/2017 5/25/2017 2.80 COMPZ3 CASING TRIP P POOH to LD BHA#23,tag up 14,220.0 59.0 13:12 16:00 5/25/2017 5/25/2017 2.40 COMPZ3 CASING PULD P PJSM,PUD BHA#23,Check CTC 59.0 0.0 16:00 18:24 and pack offs 5/25/2017 5/25/2017 1.20 PROD4 STK PULD P PJSM,PD BHA#24 Kick off BHA with 0.0 78.2 18:24 19:36 agitator, 1°AKA motor,and new HYC bit.Pre loaded in PDL. Make up to coil and surface test 5/25/2017 5/25/2017 2.50 PROD4 STK TRIP P Trip in hole,EDC open,Pumping min 78.2' 13,250.0 19:36 22:06 rate 5/25/2017 5/25/2017 0.20 PROD4 STK DLOG P Log K1 for-8' 13,250.0 13,275.0 22:06 22:18 5/25/2017 5/25/2017 0.50 PROD4 STK TRIP P Continue in well,Stop and close EDC 13,275.0 14,201.6 22:18 22:48 @ 13432,PUW=36K,Dry tag TOB @ 14203' 5/25/2017 5/26/2017 1.20 PROD4 STK MILL P PUH and confirm dry tag,Pumps on 14,201.6 14,202.6 22:48 00:00 @ 1.6 BPM @ 4180 PSI FS, BHP=3909,Start time milling procedure from 14201.6 5/26/2017 5/26/2017 1.00 PROD4 STK MILL P Continue time milling off billet @ 2 14,202.6 14,204.6 00:00 01:00 FPH, 1.6 BPM @ 4180 PSI FS, BHP=3991 5/26/2017 5/26/2017 0.10 PROD4 STK MILL P Start control drilling @ 1K DHWOB 14,204.6 14,208.0 01:00 01:06 5/26/2017 5/26/2017 0.30 PROD4 DRILL DRLG P 14208'Drill, 1.6 BPM @ 4179 PSI 14,208.0 14,228.0 01:06 01:24 FS,BHP=4002 5/26/2017 5/26/2017 0.10 PROD4 DRILL WPRT P Drift billet area-All good,PUW=40K 14,228.0 14,228.0 01:24 01:30 5/26/2017 5/26/2017 3.40 PROD4 DRILL DRLG P 14228',Drill, 1.6 BPM @ 4212PSI FS, 14,228.0 14,523.0 01:30 04:54 BHP=4016. Increase pump rate to 1.8BPM @ 4800 PSI FS 5/26/2017 5/26/2017 0.30 PROD4 DRILL 'WPRT P Wiper trip to 14,250,PUW=55K 14,523.0 14,523.0 04:54 05:12 5/26/2017 5/26/2017 3.80 PROD4 DRILL DRLG P BOBD,CWT=2K,WOB=1.8K, Rate 14,523.0 14,919.0 05:12 09:00 In=1.78 bpm,Rate Out=1.71 bpm, FS=1244 psi, IA=677 psi. 5/26/2017 5/26/2017 0.20 PROD4 DRILL 'WPRT P Wiper trip up-hole,PUW=51K 14,919.0 14,245.0 09:00 09:12 5/26/2017 5/26/2017 0.30 PROD4 DRILL WPRT P Wiper trip in-hole,RIW=4K 14,245.0 14,919.0 09:12 09:30 5/26/2017 5/26/2017 3.30 PROD4 DRILL DRLG P BOBD,CWT=1K,WOB=1.5K,Rate 14,919.0 15,195.0 09:30 12:48 In=1.8 bpm,Rate Out=1.7 bpm,FS =1232 psi, IA=684 psi, ROP=164 fph. 5/26/2017 5/26/2017 0.20 PROD4 DRILL WPRT P Wiper-trip up to 14,903(300'),PUW= 15,195.0 15,195.0 12:48 13:00 51K,RIW=3.5K 5/26/2017 5/26/2017 0.80 PROD4 DRILL DRLG P BOBD,CWT=-1.2K,WOB=2K, 15,195.0 15,300.0 13:00 13:48 Rate In=1.78 bpm, Rate Out=.159 bpm,FS=1230 psi, IA=686 psi, ROP=145 fph,pumped sweeps, drilled to planned TD of 15,300'MD 5/26/2017 5/26/2017 0.30 PROD4 DRILL CIRC P Circulate allowing sweeps to reach bit, 15,300.0 15,300.0 13:48 14:06 PUH slowly. Page 31/35 Report Printed: 5/30/2017 ll =' Operations Summary (with Timelog Depths) t 0....74 1C-23 Ccanoc6Phillips fit.,, . 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) 5/26/2017 5/26/2017 3.40 PROD4 DRILL WPRT P Perfrom swab wiper trip,PUW=39K 15,300.0 78.0 14:06 17:30 5/26/2017 5/26/2017 2.40 PROD4 DRILL WPRT P At surface,Reset counters,Trip in 78.0 13,255.0 17:30 19:54 5/26/2017 5/26/2017 0.20 PROD4 DRILL DLOG P Log K1 for-.5' 13,255.0 13,276.0 19:54 20:06 5/26/2017 5/26/2017 0.20 PROD4 DRILL WPRT P Continue wiper in hole 13,276.0 13,531.0 20:06 20:18 5/26/2017 5/26/2017 2.80 PROD4 DRILL PRTS P Stop and get static pressure at 13,531.0 13,531.0 20:18 23:06 window, 13531MD/6431 TVD SS, Annular=3838,built to 3842,Annulas 535 built to 578 in KWM=11.5. Discuss with town.Order 12PPG from 1B pad.weigh up liner running pill to 11.7PPG 5/26/2017 5/26/2017 0.80 PROD4 DRILL WPRT P Perform weight check,PUW=39K,RIH 13,531.0 15,304.0 23:06 23:54 to confirm bottom @ 15304 5/26/2017 5/27/2017 0.10 PROD4 DRILL TRIP P POOH pumping beaded liner running 15,304.0 15,248.0 23:54 00:00 pill 11.7PPG followed by 12.0PPG KWF,PUW=37K 5/27/2017 5/27/2017 4.00 PROD4 DRILL TRIP P Continue out of well pumping 11.7 15,248.0 63.5 00:00 04:00 PPG Beaded liner running pill followed by 12.0 PPG KWF,Stop and paint EOP flags @ 13700'EOP and 11900' 5/27/2017 5/27/2017 0.20 PROD4 DRILL OWFF P At surface,Lost returns @ 800'.Fill 63.5 63.5 04:00 04:12 across top.Able to fill hole.Static losses at 8 to 10 BBI/Hr. 5/27/2017 5/27/2017 1.20 PROD4 DRILL PULD P PJSM,Lay down BHA#24 over dead 63.5 0.0 04:12 05:24 well 5/27/2017 5/27/2017 4.40 COMPZ4 CASING PUTB 'P Crew change,PJSM,PU BHA#25 0.0 1,598.0 05:24 09:48 (non-ported bull nose,8'pup,38 jnts slotted liner,liner top billet),roll in cart, stab on. 5/27/2017 5/27/2017 3.30 COMPZ4 CASING RUNL P RIH with BHA#25 at 80 fpm to reduce 1,598.0 14,770.0 09:48 13:06 losses,additional 50 bbl 12 ppg KWF arrive at rig,tie-into EOP flag for-17.5' correcction,weight check PUW=41K at window. 5/27/2017 5/27/2017 3.20 COMPZ4 CASING RUNL T Begin to log K1 and encounter stuck 14,770.0 14,770.0 13:06 16:18 pipe condition,work pipe with no success up to 55K CWT.Confer with town,pull up to 60K CWT with no success,begin building 45 bbl 2% LoTorq,2%776,2 ppb beaded pill to pump down the back-side,attempt pressuring up on backside with no success. 5/27/2017 5/27/2017 3.00 COMPZ4 CASING RUNL T Confer with town on updated plan 14,770.0 14,770.0 16:18 19:18 foward.Plan is to bull-head enitre back-side volume(70 bbl)and pull up to 75K CWT in 5K increments starting at 60K.Wait on fluids to arrive at rig and build additonal-25 bbl pill. 5/27/2017 5/27/2017 2.30 COMPZ4 CASING RUNL T All fluids here and mixed,Start 14,770.0 14,470.0 19:18 21:36 bullheading 1/2 BPM 5/27/2017 5/27/2017 0.20 COMPZ4 CASING RUNL T Pumped pill down back side,Shut 14,470.0 14,670.0 21:36 21:48 down and open choke.Work pipe 60K,65K and 70K.Came free on third cycle-68K,PUH 100' Page 32/35 Report Printed: 5/30/2017 • '=' •rations Summary (with Timelog Depths) 0 kz 0..411 1C-23 ConocoPhiilips 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) 5/27/2017 5/27/2017 0.20 COMPZ4 CASING RUNL 14670',RIH with liner,clean past 14,670.0 15,295.0 21:48 22:00 14770 and to bottom, 15295, PUW=48K.Set back down.Pumps on @ 1.5 BPM @ 5100 PSI,PUW=38K 5/27/2017 5/27/2017 0.10 COMPZ4 CASING TRIP PUH to 15254 remove liner length 15,295.0 13,700.0 22:00 22:06 from counters, 1553.61 5/27/2017 5/27/2017 0.10 COMPZ4 CASING TRIP PUH to 13,580' 13,700.0 13,580.0 22:06 22:12 5/27/2017 5/27/2017 0.10 COMPZ4 CASING DLOG Log K1 for+15' 13,580.0 13,612.0 22:12 22:18 5/27/2017 5/27/2017 0.10 COMPZ4 CASING TRIP 'PUH to 13550 13,612.0 13,550.0 22:18 22:24 5/27/2017 5/28/2017 1.60 COMPZ4 CASING CIRC Start high vis spacer down coil 13,550.0 13,550.0 22:24 00:00 followed by 8.6 PPG Flow Pro,Started @ 1 BPM,slowed to.3 in attempt to get returns.Went back up to.5 after.3 did not produce returns 5/28/2017 5/28/2017 1.00 COMPZ4 CASING CIRC P Continue to displace to 8.6 PPG 13,550.0 13,550.0 00:00 01:00 FloPro.Spacer out of coil.Unable to get returns 5/28/2017 5/28/2017 3.10 COMPZ4 CASING TRIP P Open EDC and trip to surface,start 13,550.0 29.1 01:00 04:06 seeing returns at 12732' 5/28/2017 5/28/2017 1.60 COMPZ4 CASING PULD P Tag up,PJSM,PUD BHA*25 liner 29.1 0.0 04:06 05:42 running tools 5/28/2017 5/28/2017 2.00 PROD5 STK PULD X Crew change,PJSM,PU/PD BHA#26 0.0 81.0 05:42 07:42 (1°Weatherford motor,agitator(57.7 hr),new HYC B8 DuraForce Edge), inspect pack-offs,good,tag up. 5/28/2017 5/28/2017 2.40 PROD5 STK TRIP X RIH to KO billet,close EDC,surface 81.0 13,255.0 07:42 10:06 test agitator at 500',visual on pipe movement,dp=1283 psi,agitator surface test good. 5/28/2017 5/28/2017 0.40 PROD5 STK DLOG X Log K1 for-4'correction 13,255.0 13,277.0 10:06 10:30 Note:DD confered with Baker town about changing the HS KO to a 45° ROHS due to the DTF at 13750'=15° LOHS,Confer with town engineer, town engineer agreed with this change to a 45°ROHS KO 5/28/2017 5/28/2017 0.30 PROD5 STK TRIP X Continue RIH,dry tag TOB at 13,750' 13,277.0 13,750.0 10:30 10:48 5/28/2017 5/28/2017 2.50 PROD5 STK KOST X Begin time drilling off billet at 45° 13,750.0 13,756.0 10:48 13:18 ROHS, Rate In=1.5 bpm,Rate Out= 1.5 bpm,CWT=8K,FS=1038 psi, 1 stall getting started,PUH and successfully get on billet 5/28/2017 5/28/2017 2.50 PROD5 DRILL DRLG X Off billet drilling ahead,CWT=6.3 K, 13,756.0 14,200.0 13:18 15:48 WOB=1.7 K, FS=1250 psi,Rate In =1.78 bpm,Rate Out=1.53 bmp,IA =657,ROP=170 fph Dry drift billet area up&down,clean 5/28/2017 5/28/2017 0.20 PROD5 DRILL WPRT X Wiper up-hole, PUW=41K 14,200.0 13,850.0 15:48 16:00 5/28/2017 5/28/2017 0.10 PROD5 DRILL WPRT X Wiper in-hole,RIW=7.5K 13,850.0 14,200.0 16:00 16:06 Page 33/35 Report Printed: 5/30/2017 • •rations Summary (with Timelog Depths) &MAD 1C-23 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) 5/28/2017 5/28/2017. 3.60 PROD5 DRILL DRLG X BOBD,CWT=5.4K,WOB=1K,Rate 14,200.0 14,667.0 16:06 19:42 In=1.8 bpm,Rate Out=1.37 bpm, IA =721 5/28/2017 5/28/2017 0.30 PROD5 DRILL DRLG X 14667',New mud at bit, 1.78 BPM @ 14,667.0 14,700.0 19:42 20:00 4953 PSI FS,BHP=4177 5/28/2017 5/28/2017 0.60 PROD5 DRILL WPRT X 14700',Wiper trip to 13780', 14,700.0 14,700.0 20:00 20:36 PUW=40K,Clean trip up and down 5/28/2017 5/28/2017 1.70 PRODS DRILL DRLG X 14700',Drill, 1.78 BPM @ 4576 PSI 14,700.0 14,881.0 20:36 22:18 FS,BHP=4107 5/28/2017 5/28/2017 0.10 PRODS DRILL WPRT X 14881,BHA wiper,PUW=43K 14,881.0 14,881.0 22:18 22:24 5/28/2017 5/29/2017 1.60 PROD5 DRILL DRLG X 14881',Drill, 1.79 BPM @ 4570 PSI 14,881.0 15,000.0 22:24 00:00 FS,BHP=4109 5/29/2017 5/29/2017 4.30 PRODS DRILL DRLG X 15000',Drill, 1.79 BPM @ 4764 PSI 15,000.0 15,200.0 00:00 04:18 FS,BHP=4099, Pump 10 X 10 sweeps 5/29/2017 5/29/2017 3.50 PROD5 DRILL WPRT X Reach plan TD L2-02 lateral,Chase 15,200.0 78.0 04:18 07:48 sweeps to swab,PUW=41K,notice increased motorwork spikes with no indications in CWT or WOB beginnning at 1500'from surface, trouble-shoot with driller and pusher, appears to have cleared up. 5/29/2017 5/29/2017 2.40 PROD5 DRILL TRIP X RBlli to confirm TD,tie-in for 0' 78.0 13,530.0 07:48 10:12 correction,continue RIH. 5/29/2017 5/29/2017 0.50 PRODS DRILL DLOG X Stop&obtain SBHP at window. 13,530.0 13,530.0 10:12 10:42 13,530'MD/6431'TVD SS/6526' TVD.Shut down pumps,close in choke. IA=627 psi,annular=3865 psi,annular stablizes at 3838 psi. KWF=11.4 ppg(rounded up),confer with town&would like to continue with 12 ppg KWF. 5/29/2017 5/29/2017 0.80 PROD5 DRILL TRIP X Continue RIH,confirm TD at 15,200' 13,530.0 15,200.7 10:42 11:30 MD. 5/29/2017 5/29/2017 3.50 PROD5 -DRILL DISP X POOH,laying in liner running pill&12 15,200.7 70.0 11:30 15:00 ppg KWF to surface,paint EOP flags. Begin losing significant returns at -2750'.Begin pumping over the top to fill hole at-1000'. 5/29/2017 5/29/2017 0.40 PRODS DRILL OWFF X Flow check at surface,good,PJSM, 70.0 70.0 15:00 15:24 establish static loss rate at-8 bbl/hr 5/29/2017 5/29/2017 1.20 PROD5 DRILL PULD X LD BHA#26,motor came out loose, 70.0 0.0 15:24 16:36 bit came out a 2-1 5/29/2017 5/29/2017 4.20 COMPZ5 CASING PUTB X PJSM,PU BHA#27(non-ported 0.0 1,770.0 16:36 20:48 bullnose,43 jnts slotted liner,shorty deployment sleeve),filling the hole as required,crew change, PJSM. Perfrom Safety Drill"Kick While Running Liner",change pack-offs. 5/29/2017 5/30/2017 3.20 COMPZS CASING RUNL X RIH with liner,storage reel lock-out 1,770.0 15,200.0 20:48 00:00 occured at 11,948',injector motor lock -out occured at 12,708',continue to RIH at 3ofpm&begin to trouble shoot issue,tie-into EOP flag for-13.4', weight check at window,PUW=40K, continue RIH at 45 fpm,PUW=45K, release off liner at TD,TOL=13,475'. 5/30/2017 5/30/2017 0.10 COMPZS CASING RUNL X PUH to 15166,remove liner length left 15,200.0 13,441.0 00:00 00:06 in hole from counters,13441.4 Page 34/35 Report Printed: 5/30/2017 : • • Operations Summary (with Timelog Depths) IC-23 Conor Phit ips �3.xkz 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) 5/30/2017 5/30/2017 1.50 DEMOB MOVE CIRC P Displace well to seawater, 13,441.0 13,441.0 00:06 01:36 5/30/2017 5/30/2017 3.30 DEMOB MOVE TRIP -P Trip out pumping seawater,pump 30 13,441.0 22.0 01:36 04:54 BBIs diesel,freeze protect tubing from 2500' 5/30/2017 5/30/2017 1.50 DEMOB MOVE PULD -P At surface,PJSM,PUD BHA#26 22.0 0.0 04:54 06:24 Liner running tools 5/30/2017 5/30/2017 0.50 DEMOB MOVE OTHR P Rig up floor to set BPV 0.0 0.0 06:24 06:54 5/30/2017 5/30/2017 2.00 DEMOB WHDBOP OTHR P PJSM with valve crew,R/U and set 0.0 0.0 06:54 08:54 BPV 5/30/2017 5/30/2017 3.10 DEMOB MOVE MOB P Work Rig down check list,Nipple 0.0 0.0 08:54 12:00 down stack,Check tree bolts, Pour methanol down tree.Load out fluids in pits,RIG RELEASE 12:00 Page 35/35 Report Printed: 5/30/2017 a KUP �D � 1C-23 onoc 3 11 �1 JS0 Well Attribut Max Angle D TD ISO6r1,Inc, Wellbore API/UWI Field Name Wellbore Status _Incl(°) MD(ftKB) Act Btm(ftKB) CoreocWhtldps 500292294200 KUPARUK RIVER UNIT PROD 49.59 1,655.61 13,975.0 CommentH2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-23,6/29/201710.54.55 AM SSSV:NIPPLE I 60 8/12/2016 Last WO: 40.02 5/21/1999 Vernal s.herneto{actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,30.0 ( .. Last Tag:RKB 13,458.0 4/19/2017 Rev Reason:SET PATCHES pproven 6/17/2017 I II Other In -tole Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) Whipstock 5/6/2017 1111I Perforations&Slots CONDUCTOR;34.0.121.0 6 V snot Dens • Top(TVD) Btm(TVD) (shots/ NIPPLE;486.2 Top(ftKB) Btm(ftKB) (ftKB) (MKB) Zone Date ft) Type Com I 13,485.0 13,487.0 C-4,1C-23 4/9/2017 3.0 APERF 2"GUN/2' LOAD/3SPF/120 DEG PHASING/7 SHOTS la 13,537.0 13,587.0 C-4,1C-23 6/6/1999 4.0 IPERF 2.5"HSD,180 phasing, GAS LIFT;3,537.1 Z _/-90 deg orient SP Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(RKB) (ftKB) (ftKB) Des Start Date Coin TAT,IF i 0,295 4 13,440.0 13,660.0 Cement Plug 4/13/2017 cement plug(C-sand squeeze)in the 7"production casing Al Notes:General&Safety End Date Annotation GAS LIFT;8,214.2 a8,13,2010 NOTE:View Schematic w/Alaska Schematic9.0 S. ill,i SURFACE;33.3-8,894.4 , 45::. GAS LIFT,9,922.0 GAS LIFT;11,474.7 PATCH;11,493.2 PATCH-UPPER;11,500.0 PATCH-LOWER;11,545.5 '1 €, IIR GAS LIFT;13,349.8 1 EE - NIPPLE;13,394.8 I'"` 4. SEAL ASSY;13,438.0 I. PACKER,13,436.9 ,•T"t. I APERF;13,485.0-13,407.D—� 3 2 NIPPLE;13,492.3 It SOS;13,503.3 s IPERF;13,537.0-13,587.0 WINDOW A;13,595.0.13,630.0 Whipstock;13,595.0 Liner Cement;13,440.05110 ✓i.-"- iv it SLOTS;13,882.0-1011.0 ' I :1 PRODUCTION;38.0-13,960.0 AL1 Lateral,13,659.3-14,044.0 ,a SLOTS;13,476.0-15,2tID.0\ SLOTS;13,767.0-15,303.0 AL2-02;13,474.5-15,200.0 -'f AL2-01,13,751.4-15,305.0 ) 1YED \.010,-03.4RECE • 26 VWWELL LOG TRANSMITTAL#904000441 AOGCC To: Alaska Oil and Gas Conservation Comm. June 20, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage,Alaska 99501 6Iz.s2o17 M.K.BENDER RE: Multi Finger Caliper: 1C-23 Run Date: 5/6/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-23 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22942-00 Multi Finger Caliper(Field Log) 1 color log 50-029-22942-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari SCANNED JUL, 7 2017 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / vaa4zoki / `eo%eaC �� • • co Q l ^ r H > t C^ ° 4 n f'4 ' > a ° u Y 3 N C7NZ m -0 (0 CO 0 �' I ° +�.' E > ' L FAY V a a c c v o 0U1, „ la •c :6 6.1 0 0 -o a c F. v Q Cs .+ 0 r r r r r N- +-' v E 0 s m 71 FF t k ~ O a Q Q Q Q Q Q (+- E t L v, c F o o (n v (0 r 0 ra y c 0 Z Q N N N N U -c ca 0 N Z QOa >cu E -0 v aa C I- y v co O IF rc v -0 V U C a W 0000000 C Q O. w W W W W W W v1 v s- 4-. .-- I- LL LL LL U.. LL LL LL O < J J J J J J J a SD C < Q Q Q Z Q Q Q a w DO 0 Z Z Z Z Z Z Z a) t O �O aJ I.I. LL LL LL LL LL LL. CC �-, C > a L O Cr z v a w u > a Y U C 1:i O d > U a C U fl_ -, O ,p Q a) a vi C a ,Q WC i U O J a Lu a, (/) E 0 a, d d a a L J a 73g E O < m v /� Ly N W U (0 +�., (V x � > o o0a2064 M 715 in in I C3W 0 Ma a a a wwW Ww www w W > > > > > > > arecccerewcece Z Y Y Y Y Y Y Y Ci W Q Q Q Q Q Q Q Q W a a a a a a a11 a Y Y Y Y Y Y Y Ca0 O WU w (0 r v (0 as X n .@ N V ce ° 000000 E Nom O O O O O O O Ov ° 0 0 0 0 0 0 Wco ♦.[ v fn fn fn r @ vCL. 'n° oY LV .a < 0 E Cr S O o 0 o O o a' O 6 N ° 0 0 0 0 0 0 Q a N oo 6o ro a+ • V) Cr CO COaO N h a a. •- a T M M (O N M N N 0 0 O M O N N N N N N N yL g. 6 r> A 6 r> 6 d, c 0 a N O ON O N N (d U O O O O O L 0 U 4 O O O O O O O 4•+ 44. C 0 C co LA in in Ln N n N I 0. d 0 0 en E v Q d Z t cu aJ @'-Z N N N `- N r O }, �1 d0 !:' a LY L1 a J U Y Y 6 F U E z y -, u C Q O -.1 N N N N N VI 0 . O To i , c ^ w, C c E E = ca C 01 L O O O Vi a La d I- a` 0.— 0 0 • • s,OF Tit A.SA \ I////, THE STATE Alaska Oil and Gas Conservation Commission LAsKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 UMain: 907.279.1433 A ;S� Fax: 907.276.7542 www.aogcc.alaska.gov James Ohlinger Staff CTD Engineer f ConocoPhillips Alaska, Inc. scoop ° lJ� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1 C-23 Permit to Drill Number: 199-034 Sundry Number: 317-139 Dear Mr. Ohlinger: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this day of April, 2017. RBDNIS 1_r-'APR 1 0 2017 0 . RECEIVED STATE OF ALASKA p U , ? ALASKA OIL AND GAS CONSERVATION COMMISSION 1! APPLICATION FOR SUNDRY APPROVALS / 20 AAC 25.280 A Vik 1.Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 2 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc . Exploratory ❑ Development Q • 199-034 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510 50-029-22942-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A k_'w 1 C-23 Will planned perforations require a spacing exception? Yes ❑ No 2 / 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL 28242, 25649 " Kuparuk River Field/Kuparuk 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): 13975 6718 ,. 13960 , 6712 3105 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 121' 121' 1640 670 Surface 8894' 9-5/8" 8894' 4573' 5910 3090 Intermediate Production 13960' 7" 13960" 6712" 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13537'-13587' . 6530'-6551' 3-1/2" L-80 13504' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): BAKER SB-3 Permanent Packer t 13437'MD,6487 TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q X13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/10/2017 ✓ OIL , 1 WINJ Ell WDSPL ❑ Suspended N 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Mike Callahan(263-4180) `//07 Email mike.callahan@cop.com Printed Name Ja es Ohlinger Title Staff CTD Engineer y/047 "7/0/11011044' '6.4'1 Signature Phone 265-1102 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- 13� Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ �Cl, 11y Other: 131 / fir5 f fo SO h /.) 5=� 4-7 r1 vl a Y p re- k?vi t-c re-5 t 2-5-0 c i�sL tfrr�a ft lVq a «'V2/7 r l 2( �� Post Initial Injection MIT Req'd? Yes ❑ No c—p 1--0Y -l� p cr 20 ��G Z 5 Spacing Exception Required? Yes ❑ No j' Subsequent Form Required:/ r13- .f-(y RBDMS f —4PP 1 0 2017 APPROVED BY Approved by: P [ 6„..._ COMMISSIONER THE COMMISSION Date: 4-7... / -(/7 �/� O' rrGa1PI1AsLd Submit Form and Form 10-403 evised 11(2015 i for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 �-1 ANCHORAGE,ALASKA 99510-0360 APR 0 5 2017 April 5, 2017 AOGCC Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill six laterals out of the Kuparuk well 1C-23 well using the coiled tubing drilling rig, Nabors CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. CTD operations are scheduled to begin April 18th, 2017. The objective will be to drill six laterals targeting the Kuparuk C Sands. A separate sundry application is attached to plug the KRU 1C-23 (199-034) perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from 20 AAC 25.112(c)(1) to plug the C Sand perforations in 1C-23. Attached to this application are the following documents: — 10-403 Sundry application to abandon KRU 1C-23 (199-034) — Operations Summary in support of the 10-403 sundry application — 10-401 Applications for 1C-23A, 1C-23AL1, 1C-23AL2, 1C-23AL2-01, 1C23-AL3, & 1C-23AL3-01 — Detailed Summary of Operations — Directional Plans for 1C-23A, 1C-23AL1, 1C-23AL2, 1C-23AL2-01, 1C23-AL3, & 1C-23AL3-01 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 1C-23 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 1C-23 is a Kuparuk C Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize six laterals to target the C sands to the north and south of 1C-23. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail at 13445' MD. The existing perforations will be squeezed with cement and the 3-1/2" tubing tail will be 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 C-sand perforations in this manner. Following the cement squeeze Nabors CDR3-AC will drill a pilot hole to 13620' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 13590' MD. All 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 3750 psi in 1C-14A, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3105 psi. CTD Drill and Complete 1C-23 Laterals: April 2017 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3'/2" tubing tail at 13445' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill D nipple out to 2.80" 5. Perform fill cleanout down to 13620' MD 6. Cement squeeze the A-sand perforations up to the holes in the tubing tail. 7. RU Slick-line: Tag top of cement and pressure test cement. 8. Prep site for Nabors CDR3-AC and set BPV. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1C-23A Lateral (C3/C4 sand - Southwest) a. RIH and mill 2.80" cement pilot hole down to 13620' MD b. Set a 3-1/2" monobore whipstock at 13590' MD. c. Mill 2.80" window at 13590' MD. d. Drill 3" bi-center lateral to TD of 16600' MD. e. Run 2%" slotted liner with an aluminum billet from TD up to 14000' MD. 3. 1C-23AL1 Lateral (C3/C4 sand - Southwest) a. Kick off of the aluminum billet at 14000' MD. b. Drill 3" bi-center lateral to TD of 16475' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 13660' MD. 4. 1 C-23AL2 Lateral (C3/C4 sand - North) a. Kick off of the aluminum billet at 13660' MD. Page 1 of 2 4/5/2017 • b. Drill 3"center lateral to TD of 15000' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 13800' MD. 5. 1C-23AL2-01 Lateral (C3/C4 sand - North) a. Kick off of the aluminum billet at 13800' MD. b. Drill 3" bi-center lateral to TD of 14925' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 13640' MD. 6. 1 C-23AL3 Lateral (C3/C4 sand - Southwest) a. Kick off of the aluminum billet at 13640' MD. b. Drill 3" bi-center lateral to TD of 16600' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 13690' MD. 7. 1C-23AL3-01 Lateral (C3/C4 sand - North) a. Kick off of the aluminum billet at 13690' MD. b. Drill 3" bi-center lateral to TD of 15000' MD. c. Run 2%" slotted liner with a deployment sleeve up into the tubing tail at 13500' MD. 8. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR3-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 4/5/2017 • • 1C-23 Proposed CTD Schematic Modified by MSC 4-7-,g•�„. DS-nipple at 486'(2.875”min ID) 16"62#H-40 shoe 3-1/2"9.3#L-80 EUE-Mod 8rd Tubing to surface at 121'MD 3-1/2"Camco 1"KBMM gas lift mandrels at 3537',6295,8214', 9-5/8"40#L-80 shoe 9922',and 11,475 MD at 8894'MD 3-1/2"Camco 1.5"MMM gas lift mandrel at 13,350'MD W-nipple at 13,395'MD(ID=2.812") Baker KBH-22 anchor seal assembly at 13,436'MD Baker SB-3 permanent packer at 13,437'MD(3.0"ID) D-nipple at 13,497 MD .,,.i (2.75"min ID,milled out to 2.80"for CTD) --_—� 3-1/2"tubing tail at 13,504'MD Planned Top of 5 r Cement 13,440'MD r C-sand perfs 13,537'-13,587'MD =� (to be cemented) 7"26#L-80 shoe at 13,960'MD • 0 • • 1C-23 Proposed CTD Schematic Modified. DS-nipple at 486'(2.875"min ID) 116"62#H-40 shoe 3-1/2"9.3#L-80 EUE-Mod Brd Tubing to surface lat 121'MD 3-1/2"Camco 1"KBMM gas lift mandrels at 3537',6295',8214', 9-5/8"40#L-80 shoe 9922',and 11,475'MD at 8894'MD 3-1/2"Camco 1.5"MMM gas lift mandrel at 13,350'MD W-nipple at 13,395'MD(ID=2.812") Baker KBH-22 anchor seal assembly at 13,436'MD Baker SB-3 permanent packer at 13,437'MD( ) D-nipple at 13,492'MD (2.75"min ID,rn:.cc out to 2.80"for CTD) ---= 3-1/2"tubing tail at 13,504'MD C-sand perfs 1a23AL3-01 wpot 13,537'-13,587'MD „ TO 6 15,000'MD (to be cemented) „ �Linerr to 13,503'MD n.aes �r--� ” p0 _-- 1C-2341.3 wp01 -=,-----I — -.....,. ________________________________1 TD• 16,600'MD — -1 ���///�` Linar top�13,690'MD ___ 1 G23AL2 wp01 / _ TD�15,000'MD KOP @ 13,590'MD • _________ _- Liner top013,800'MO _ -- - __ ___"'_'�____w. � 1 C-2341.2-01 wp01 ., _____________________________ TD TD®14,925'MD Liner top-13,640'MD 1C-23AL1 wp01 7 TO 0 16,475'MD .- --'- Liner top 0 13,660'MD_ 7"26#L-80 shoe IC-23Awp04 at 13,960'MD TD©16,600'MD �_ ___ Liner top 014,000'MD • • — 0 0 opo po 3.,to. o o a M O . 0 o.p( O0 oN" C Cl- 20 _ O N - 7 � C ih 3co d ao� Jv a a_© o0 oQ.ho co • 3oa' Q�,1Q to op1 2 N�,`�O J 0.Q N V Q Q<- 0 3 o. V O O v N Q(��O C 0 J N V N M J vi tc, • oaC.-H-J N lJC I �I'J T1s U0 C <..- O r� 0 0 J.1 II �; it <-1.-J I ,I I U C I I 11 11 II II —F J 1 1 ' 11 I I " I I I I I I 11 11 I II I I I 11 ;I II II I I 11 I II i1 I 1 1 �1 11 I� I I _ I I 11 11 tl 11 N ' " II 11 �, 11 00 I I I 11 11 11 it ' II I1 11 II 0 1 1 1 ' 11 I I I N 0 , ,i i I i 1 '' CO a II 1 11 - '1 11 11 11 I1 F-- Q I I I I I I I I I U M M Zo CO 1 I I 1 I I I I I I I as I1 11ii`CM MIIII ; 1 1IIC V 5Q11I I 11 " II(/1 M LQ11II 11 to II i �'Q t��. �' I I 11• '� (13 CI • Ui11•_ T ' 11It II CE T I11 CBN _ 1 ; II " II..n. � � � � Q ' � II Q Id ' It lE a::. a � N to N Q1iiICC - II 63 YO 1 1 111L -� Q U _ , I j /11 :',I 11• tli �µ. O v o Q Oii i I' 1`�" r0) ccQc W O tIJ ' li1ii. II `.. W G QG co 11 i1t ;I �] 2 2 L N o -r.,., 1 " j1 1i w YTo i0 Lo C co N CO i �� �� ii �� ii M co O V �— M C V i I ii 11 li ii MI O O N N Q ' I I I '' tI ,' .__I 0C r U N Q 1 11 II I I l L 'O Ili = M C t t l 1 It 1 1 It N co -/\ C �(6l N c7 m co E �t Ii tt d V V Q Y cn I 11 11 11 a.Lc) C N N N N N N CLI': (V 1 II.1 i i t`t U) N C Y 1 .E N t t t It ttt Q (,) ch rcrn ch CO CO Q ch ; I • N`'I jrSs e `\t 1!Fti:: 11,3," :' . LI N C U 4, ri CU NE 7 \ I L CO I/H Q o N t NCI M co O CO o fl 1 N Q o op aF- O N Q JQ � M I- CO d Clt CO CL 0 I v v CJ N Q) N CO N CO M 0 c0 LC) W r to is KUP PROD • 1C-23 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ft613) Act Btm(ftKB) Conocolfidliln 500292294200 KUPARUK RIVER UNIT PROD 67.14 9,137.57 13,975.0 ..• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-23,1/172015 7 32:04 AM SSSV:NIPPLE 50 12/16/2013 Last WO: 40.02 5/21/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 13,555.0 1/10/2015 Rev Reason:GLV C/O,PULL PLUG& hipshkf 1/17/2015 __.............................................................. _ CATCHER,TAG HANGER;30.0 l? f I Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - CONDUCTOR 16 15.062 34.0 121.0 121.0 62.58 H-40 WELDED ii[ Casing Description SURFACE OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread 95/8 8.835 33.3 8,894.4 4,573.0 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtJLen(I...Grade Top Thread i PRODUCTION 7 6.276 38.0 13,960.0 6,711.6 26.00 L-80 BTC-MOD wlaala. irn n..Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibt t( Grade Top Connection TUBING 31/2 2.992 30.0 13,504.2 6,515.8 9.30 L-80 EUE8RDMOD .".....n..as.Completion Details CONDUCTOR;34.0-121.0 a Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn _ (In) 8 30.0 30.0 0.12 HANGER FMC GEN IV 5M HANGER 3.500 NIPPLE;486.2 4862 485.8 5.80 NIPPLE CAMCO DS NIPPLE 2.875 13,394.8 6,469.7 65.28 NIPPLE CAMCO W NIPPLE ' 2.812 13,436.0 6,487.0 65.11 SEAL ASSY KBH-22 ANCHOR SEAL ASSEMBLY 2.992 13,436.9 6,487.4 65.11 PACKER BAKER SB-3 PERMANENT PACKER 2.937 13,492.3 6,510.8 64.95 NIPPLE CAMCO D NIPPLE w/NO GO PROFILE 2.750 13,503.3 6,515.4 64.93 SOS BAKER SHEAR OUT SUB 3.015 GAS LIFT;3,537.1-1 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 13,537.0 13,587.0 6,529.7 6,551.0 C-4,1C-23 6/6/1999 4.0 (PERF 2.5'HSD,180 phasing, GAS LFT;6.295.4 ® =/-90 deg orient Mandrel Inserts St ae on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn GAS LIFT;8,214.2 c��-� t 3,537.1 2,333.2 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,250.0 1/9/2015 l 2 6,295.4 3,495.2 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,281.0 1/9/2015 __ 3 8,214.2 4,291.7 CAMCO KBMM 1 GAS LIFT OV BK 0250 0.0 1/8/2014 4 9,922.0 4,999.2 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 6/6/2012 5 11,474.7 5,647.1 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 6/6/2012 6 13,349.6 6,450.9 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0'12/5/2014 Notes:General&Safety End Date Annotation SURFACE;33.3-8,894.4 - 8/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;9,9220Ini GAS UFT;11,474.7 GAS LIFT;13,349.6 NIPPLE;13,394.8 SEAL ASSY;13,436.0 PACKER;13,436.9 ..zZ. I I NIPPLE;13,4923 t a SOS;13,503.3 IPERF;13.537.0.13587.0 PRODUCTION;38.0-13,90.0 • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend" boxes are also checked, cross out that erroneous entry and Q 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 /4then 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, they 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, they 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, they 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 Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • Loepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Friday, April 07, 2017 10:10 AM To: Loepp, Victoria T (DOA) Subject: 1C-23 Plugging/PTD Schematics Attachments: 1C-23 Post Plugging Schematic.pdf; 1C-23 PTD Schematic.pdf Victoria, please find attached the proposed schematics for 1C-23 after plugging with cement and after the CTD project. Please let me know if you have any questions or need any further information. Thanks, Mike Callahan CTD Engineer ConocoPhillips Alaska ATO 660 Office: (907) 263-4180 Cell: (907) 231-2176 1 3-1 ro • • Oy C I:: T x0 Q, in Q Q L ti: ti -. N O i � � � : Y O .3 5 r v u N °.' E > V a 0 E O y O a N O O >, ra Y r6 L {-J -6 41ra O 'O a � a h` Wr W p . . ,, Q E Oa cs p .1,4° Ooh C7 " m J .4. 0 N Z N _C rl, U (n Q ri OJ Q CO s 0 16 f6 CV f4 E Y -0 O • = @ C 2 0, a • F N N N N 0 Y O Zp 2 ,_, 'D m p C y - Eu ii ,, O C C O v c0 0u Cl p p p p J J J J a W W W w v y L v o S- IT IL T. T. �, N N 16 a _a > -c _N .� Q Q Q Q N v) C 4- w O m �) Z Z Z Z co a) N �O N �$! LL LL LL IT. cc .-. -0 O > Qj L v V ° vY 'u t c p ~ i ' z t C ra a o o • , Q C a Ln a a 41 ;h+ O s - Jo e- - o W a ' � _J 4 •� v t o I? Gil v � "' a W o > 3 :. 206 N doh o N. le we le x xCCI 3 Lir Q in GA OA ^. o v '..-011110"rf mcerece E W W W W _ W > > > > t Q 2' E. 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U 1 z c oCO - c>a • G p z a P. c Ct a 4-, 0 0 Q v atn = a u 1.4 173 mmL O C p - LI- pJ d W J N J CO 0 0 COU . CI" \ cCC �.i Jv � O a >— '0 .9 apr, Z � 1 m N3 � 3 �g Mz � , Z '...Villt"1111 wecrecc 0111 a 4J w W W w W > > > > a z YYYY p a' Q Q Q E ti Q w Q Q Q Q O a a a a a Y Y Y Y • L LLI ti pp O C=I w rn O X in V r r-- ii N 0 0 0 0 E GD O o 0 0 o a) o O o o d u to N n .co 00 > O O _ 0 > co D D o > c z w n a LLI Q0 IX u (13 O E 1, Cr o 0 0 0 ++ o - 0 0 0 o Q N.et N CV N N . N 0 V a Cl a 4 _ Q O CO O O N N O N Et - N N N N N L n o6 o) o) o8 c 0 a Q N N N N 0 O� O O O O I.. 0 0 00 N141 VI N Q 'O O = R Eu c y to a W '^ E E ppv ro 9 ~ d d ^ Q M n O el4'' cu c d a z i, h0 Z N N ++ E +�+ d a O N r N Z d O LI +, n O Tie ca 4 c 3 =• af6, E E • • v°\,''') - 0 -24III-1F3 WELL LOG 1_46 02:2_ TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. R EC E I Y F V/ 5m+� DATA LOGGED "3/2./201-( ,i. K. BENDER MAR 01 2017 To: AOGCC AOGCC Makana Bender !�1 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED APR 0 5201z 1) Caliper Report 14-Feb-17 1C-23 1 Report /CD 50-029-22942-00 2) Jewelry Log 14-Feb-17 1C-23 Color Log /CD 50-029-22942-00 Signed : 1212Alta..0.0...4) 6. iteeet Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(WMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D.\Achive sWasterTempl ateri I es\Templates\Di stribut ion\Transmittals heetsT onocoPhi II i ps_Tran smit.docx r °P‘. °'&4\ .2-6 2\ Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-23 Log Date: February 14, 2017 Field: Kuparuk Log Na: 14814 State: Alaska Run No.: 1 API No. 50-029-22942-00 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE 8RD MOD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 13,484 Ft. (MD) Pipe Description: 7 inch 26 lb. L-80 BTC-MOD Top Log Interval: 13,484 Ft. (MD) Pipe Use: Production Casing Bottom Log Interval: 13,550 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is correlated to the Schlumberger Jewelry Log dated June 5, 1999. During logging operations, the caliper temporarily stopped recording from—10,572 feet to —10,862 feet, resulting in a loss of data over this interval. This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to be in good to poor condition, with a maximum recorded wall penetration of 46% in a line of corrosion in joint 251 (7,862 ft). Additional wall penetrations ranging from 20% to 46% wall thickness are recorded in 64 of the 446 joints logged. Recorded damage appears as a line of pits and line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate the 7 inch casing logged appears to be in good condition with respect to internal corrosive and mechanical damage outside of the perforation interval logged. No significant wall penetrations or areas of cross-sectional wall loss are recorded outside of the perforation interval throughout the casing logged. The caliper recordings indicate oval deformation in the perforation interval, restricting the I.D. to 5.47 inches in joint 3 (13,546 ft). No other significant I.D. restrictions are recorded throughout the casing logged. A graph illustrating the minimum recorded diameters on a joint-by-joint basis across the casing logged is included in this report. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : Description Percent Wall Penetration Line Corrosion 46 251 7,862 Ft. (MD) Line of Pits 46 231 7,230 Ft. (MD) Line Corrosion 45 253 7,913 Ft. (MD) Line of Pits 45 238 7,459 Ft. (MD) Line Corrosion 45 247 7,725 Ft. (MD) 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 9%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalvsisCo>memorvlog.com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907) 659-2314 • I 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS : Outside of the perforation interval, no significant wall penetrations (> 15%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS : Description Minimum Recorded Diameter Oval Deformation at Perforation Interval 5.47 inches 3 13,546 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. T. Leckband C. Waldrop E. Zemba Field Engineer(s) ProActive Diagnostic Services, Inc. / P.O. Box 1369,Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalysis(amemorylog,com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907) 659-2314 • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-7.0'- 13,484.6') Well: 1 C-23 Pipe 2 7. in (13,484.6'-13,550.0') Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: February 14, 2017 ■ Approx.Tool Deviation . Approx.Borehole Profile 1 -4 50 1,547 100 3,089 GLM 1 150 4,682 GLM 2 el 6,235 ii 7 C Z _ 0 250 — 7,814 iv GLM3 0 300 9,394 GLM 4 MIMI 350 = 10,977 GLM 5 400 12,555 m GLM 6 3 13,541 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=3 Perforations • PDS Report Overview tit _ Body Region Analysis Well: 1C-23 Survey Date: February 14,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD 2.992 in. -7 ft. 13,484 ft. Penetration(%wall) Damage Profile(%wall) 400 Penetration body owl Metal loss body 0 50 100 0.1 300 -- 47 200 100 97 GLM 1 (10:30) 0 0 to 20 to 40 to over 144 20% 40% 85% 85% Number of joints analyzed(total=446) 381 49 16 0 194 GLM 2 (7:00) Damage Configuration(body) 241 j 150 GLM 3 (8:00) L— 288 100 GLM 4(8:30) 335 50 GLM 5 (10:30) 382 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total= 129) GLM 6(1:00) 18 0 111 0 0 Bottom of Survey=427.4 • • TR-S. PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. ; Pen. Metal Min. Damage Profile No. (Ft.) Upset Body ' % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 -7 0 0.02 8 0 2.90 Pup Lt. Deposits. • 1 -4 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 1.1 31 0 0.04 17 4 2.92 Pup Shallow Line Corrosion.Lt. Deposits. ■ 1.2 39 0 0.05 19 4 2.93 Pup Shallow Line Corrosion.Lt. Deposits. ■ 2 48 0 0.04 15 5 2.91 Shallow Line of Pits.Lt. Deposits. ■ 3 79 0 0.03 11 2 2.90 Lt.Deposits. i■ 4 111 0 0.03 11 3 2.91 Lt.Deposits. ■ 5 143 0 0.04 14 3 2.92 Lt.Deposits. ■ 6 174 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 7 205 0 0.04 14 3 2.93 Lt.Deposits. ■ 8 236 0 0.03 12 2 2.91 Lt.Deposits. ■ 9 266 0 0.04 15 2 2.91 Shallow Line of Pits.Lt. Deposits. ■ 10 298 0 0.03 12 2 2.92 Lt.Deposits. • 11 329 0 0.03 13 2 2,91 Lt.Deposits. ■ 12 360 0 0.03 11 2 2.92 Lt.Deposits. ■ 13 391 0 0.04 15 3 2.93 Shallow Line of Pits. ■ 14 422 0 0.03 11 2 2.93 Lt.Deposits. 14.1 453 0 0 0 0 2.86 CAMCO DS NIPPLE 15 455 0 0.03 11 3 2.92 Lt.Deposits. ■ 16 487 0 0.03 11 2 2.90 Lt.Deposits. ■ 17 518 0 0.03 12 2 2.93 Lt.Deposits. ■ 18 549 0 0.03 13 2 2.91 Lt.Deposits. ■ 19 580 0 0.03 13 2 2.92 Lt.Deposits. • 20 612 0 0.03 11 2 2.92 Lt.Deposits. 21 643 0 0.02 7 2 2.91 Lt.Deposits. 22 674 0 0.03 11 2 2.91 Lt.Deposits. ■ 23 706 0 0.03 13 3 2.92 Lt.Deposits. ■ 24 737 0 0.04 15 2 2.93 Shallow Pitting. Lt Deposits. • 25 768 0 0.03 13 3 2.92 Lt.Deposits. 26 800 0 0.03 10 2 2.93 27 831 0 0.03 12 2 2.92 Lt.Deposits. ■ 28 862 0 0.03 11 3 2.93 ■ 29 893 0 0.04 14 4 2.91 Lt.Deposits. a 30 924 0 0.03 12 2 2.92 Lt.Deposits. ■ 31 955 0 0.03 11 2 2.91 Lt.Deposits. ■ 32 987 0 0.03 13 2 2.90 Lt.Deposits. 33 1018 0 0.02 9 4 2.92 Lt.Deposits. 34 1048 0 0.04 14 3 2.91 Lt.Deposits. ■ 35 1080 0 0.04 17 4 2.94 Shallow Line of Pits. ■ 36 1111 0 0.04 15 4 2.91 Shallow Pitting. Lt Deposits. ■ 37 1142 0 0.04 14 3 2.92 Lt.Deposits. ■ 38 1173 0 0.04 _ 16 4 2.93 Shallow Line of Pits.Lt. Deposits. ■ 39 1203 0 0.04 16 5 2.93 Shallow Line of Pits. ■ 40 1235 0 0.03 12 5 2.94 ■ 41 1266 0 0.03 13 2 2.94 ■ 42 1297 0 0.03 11 3 2.92 Lt.Deposits. ■ 43 1329 0 0.05 18 4 2.93 Shallow Line Corrosion. Lt. Deposits. ■ 44 1360 0 0.04 14 4 , 2.94 ■ 45 1392 0 0.03 13 2 2.94 ■ 46 1423 0 0.04 14 3 2.95 IPenetration Body Metal Loss Body Page 1 • PDS ReportTabulation,4-if titoin Joint T abu at on Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 47 1455 0.04 0.04 16 6 2.93 Shallow Pitting. ■ 48 1485 0 0.04 14 4 2.94 ■ 49 1516 0 0.04 17 3 2.95 Shallow Line of Pits. ■ 50 1547 0 0.04 15 7 2.93 Shallow Pitting. Lt Deposits. ■ 51 1579 0 0.04 15 4 2.95 Shallow Pitting. ■ 52 1608 0 0.04 15 5 2.95 Shallow Pitting. ■ 53 1639 0 0.04 14 4 2.95 ■ 54 1668 0 0.04 15 3 2.93 Shallow Line of Pits.Lt. Deposits. ■ 55 1699 0 0.03 13 4 2.95 ■ 56 1731 0.04 0.04 15 5 2.97 Shallow Line of Pits. ■ 57 1761 0.04 0.04 15 5 2.96 Shallow Line of Pits. ■ 58 1792 0 0.04 17 5 2.95 Shallow Pitting. ■ 59 1827 0 0.03 11 2 2.99 ■ 60 1855 0 0.04 14 4 2.95 ■ 61 1887 0.05 0.04 16 4 2.96 Shallow Line of Pits. ■ 62 1917 0 0.03 13 4 2.96 ■ 63 1948 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 64 1979 0 0.04 15 4 2.96 Shallow Line of Pits. ■ 65 2011 0 0.03 12 2 2.95 ■ 66 2042 0 0.04 14 4 2.94 ■ 67 2073 0 0.04 16 5 2.95 Shallow Line of Pits. ■ 68 2104 0 0.04 16 4 2.95 Shallow Line of Pits. ■ 69 2135 0 0.03 12 3 2.95 ■ 70 2166 0.05 0.04 16 5 2.95 Shallow Line Corrosion. ■ 71 2198 0.05 0.05 19 7 2.91 Shallow Line Corrosion. Lt. Deposits. 72 2229 0 0.04 14 4 2.95 ■ 73 2258 0.04 0.04 14 4 2.95 ■ 74 2289 0 0.04 15 5 2.95 Shallow Line of Pits. ■ 75 2321 0 0.03 13 4 2.94 ■ 76 2352 0 0.03 13 4 2.92 Lt.Deposits. ■ 77 2383 0.04 0.04 16 5 2.93 Shallow Line of Pits. ■ 78 2415 0 0.03 13 4 2.95 ■ 79 2445 0 0.03 11 3 2.95 ■ 80 2473 0 0.04 16 5 2.95 Shallow Line of Pits. ■ 81 2505 0 0.03 13 4 2.94 ■ 82 2536 0.05 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 83 2567 0 0.03 13 3 2.96 ■ 84 2598 0 0.03 10 4 2.95 ■ 85 2629 0 0.04 14 5 2.95 ■ 86 2659 0 0.04 15 4 2.96 Shallow Pitting. ■ 87 2689 0 0.03 13 5 2.95 ■ 88 2720 0 0.03 13 3 2.96 ■ 89 2751 0 0.04 14 3 2.95 ■ 90 2781 0 0.03 13 5 2.95 91 2813 0 0.03 10 2 2.95 92 2845 0 0.02 7 3 2.95 93 2874 0.04 0.03 12 2 2.96 ■ 94 2906 0 0.05 19 6 2.96 Shallow Line of Pits. ■ 95 2936 0.04 0.04 14 5 2.95 • 96 2967 0.04 0.04 14 4 2.93 Penetration Body Metal Loss Body Page 2 • • S PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen, Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 97 2996 0 0.04 15 4 2.94 Shallow Line of Pits. ■ 98 3026 0 0.03 13 5 2.95 • 99 3059 0 0.03 12 3 2.96 ■ 100 3089 0.04 0.04 16 5 2.93 Shallow Pitting. ■ 101 3120 0 0.03 13 3 2.94 • 102 3152 0 0.03 12 3 2.95 ■ 103 3183 0.04 0.04 14 2 2.94 ■ 104 3214 0 0.04 14 4 2.92 Lt.Deposits. ■ 105 3245 0 0.04 14 4 2.95 ■ 106 3277 0 0.04 14 4 2.95 ■ 107 3308 0 0.04 14 4 2.94 ■ 108 3339 0 0.03 13 3 2.95 ■ 109 3371 0.05 0.04 14 5 2.95 • 110 3401 0.05 0.03 13 3 2.93 ■ 111 3432 0 0.03 10 4 2.94 ■ 112 3463 0 0.05 19 5 2.95 Shallow Line of Pits. ■ 112.1 3494 0 0.03 12 2 2.89 Pup Lt. Deposits. 112.2 3504 0 0 0 0 2.88 GLM 1 (LATCH @ 10:30) 112.3 3509 0 0.03 11 3 2.94 Pup ■ 113 3520 0 0.04 15 2 2.95 Shallow Pitting. ■ 114 3552 0 0.04 14 5 2.95 u 115 3582 0 0.03 11 3 2.96 ■ 116 3613 0 0.03 12 4 2.95 ■ 117 , 3645 0 0.04 15 3 2.94 Shallow Pitting. ■ 118 3676 0 0.05 18 4 2.94 Shallow Line Corrosion. ■ 119 3707 0 0.03 10 3 2.96 • 120 3739 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 121 3770 0 0.03 11 2 2.95 ■ 122 3801 0 0.04 16 5 2.95 Shallow Line of Pits. ■ 123 3832 0.06 . 0.04 14 3 2.95 . ■ 124 3864 0,04 0.03 13 4 2.96 • 125 3895 0 0.04 15 2 2.95 Shallow Line of Pits. ■ 126 3926 0.05 0.04 15 2 2.95 Shallow Pitting. ■ 127 3958 0.05 0.04 14 3 2.97 ■ 128 3988 0.04 0.04 15 5 2.96 Shallow Line of Pits. 129 4020 0 0.03 10 2 2.93 r 130 4047 0 0.03 13 4 2.96 ■ 131 4079 0 0.04 15 4 2.94 Shallow Line of Pits. ■ 132 4111 0 0.04 17 5 2.98 Shallow Line of Pits. ■ 133 4142 0 0.03 10 2 2.95 ■ 134 4172 0 0.03 13 3 2.95 ■ 135 4204 0 0.03 11 5 2.96 136 4235 0 0.03 11 2 2.98 ■ 137 4266 0 0.03 13 4 2.95 • 138 4297 0.04 0.03 11 3 2.97 • 139 4329 0 0.04 14 4 2.95 ■ 140 4360 0 0.03 11 2 2.94 141 4389 0 0.03 10 3 2.95 ■ 142 4435 0 0.04 14 4 2.95 ■ 143 4467 0 0.04 15 5 2.94 Shallow Pitting. I Penetration Body Metal Loss Body Page 3 4110 PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 144 4497 0.04 0.04 15 4 2.98 Shallow Line of Pits. ■ 145 4528 0 0.04 14 3 2.94 ■ 146 4557 0 0.03 13 2 2.96 ■ 147 4590 0 0.03 10 2 2.96 148 4620 0 0.02 8 3 2.96 149 4651 0 0.05 18 4 2.97 Shallow Line of Pits. ■ 150 4682 0 0.03 11 3 2.95 ■ 151 4713 0 0.04 15 4 2.94 Shallow Line of Pits. ■ 152 4744 0 0.03 12 3 2.94 ■ 153 4773 0 0.03 13 5 2.94 • 154 4804 0 0.03 12 4 2.95 ■ 155 4835 0 0.03 13 2 2.94 ■ 156 4867 0 0.03 11 2 2.93 ■ 157 4899 0 0.03 11 4 2.95 ■ 158 4928 0 0.03 11 4 2.93 159 4960 0 0.02 9 4 2.94 160 4991 0 0.03 12 3 2.95 ■ 161 5023 0 0.03 11 3 2.95 ■ 162 5055 0 0.03 13 4 2.95 ■ 163 5085 0 0.03 13 3 2.97 ■ 164 5116 0 0.04 14 4 2.95 ■ 165 5148 0 0.04 15 4 2.94 Shallow Pitting. ■ 166 5180 0 0.04 14 3 2.95 167 5210 0 0.02 9 2 2.97 U 168 5240 0 0.03 11 5 2.97 a 169 5270 0 0.03 13 3 2.96 ■ 170 5302 0 0.03 10 5 2.95 ■ 171 5333 0 0.03 13 4 2.95 ■ 172 5364 0 0.04 16 4 2.93 Shallow Line of Pits. ■ 173 5393 0 0.03 12 6 2.94 a 174 5425 0 0.03 12 4 2.95 ■ 175 5457 0 0.04 14 4 2.94 ■ 176 5488 0.04 0.03 13 3 2.95 ■ 177 5519 0 0.03 13 3 2.95 ■ 178 5550 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 179 5581 0 0.03 11 3 2.94 ■ 180 5613 0 0.04 14 4 2.97 ■ 181 5645 0.08 0.04 15 6 2.95 Shallow Line of Pits. • 182 5676 0 0.03 10 4 2.95 ■ 183 5706 0 0.04 14 4 2.92 Lt.Deposits. ■ 184 5738 0 0.03 11 3 2.95 . ■ 185 5769 0 0.03 11 2 2.94 ■ 186 5799 0 0.04 16 5 2.95 Shallow Line of Pits. ■ 187 5830 0 0.03 13 2 2.94 ■ 188 5862 0 0.03 10 2 2.94 189 5893 0 0.03 10 2 2.93 Lt.Deposits. ■ 190 5925 0 0.04 14 4 2.94 ■ 191 5956 0 0.04 15 4 2.95 Shallow Line of Pits. ■ 192 5987 0 0.03 11 2 2.94 193 6019 0 0.03 10 3 2.95 IPenetration Body Metal Loss Body Page 4 • • 11111 Vii, _ PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 194 6049 0 0.03 12 6 2.90 Lt.Deposits. ii 195 6081 0.10 0.03 13 3 2.93 196 6112 0 0.03 10 2 2.96 197 6141 0 0.04 14 4 2.95 • 198 6173 0 0.04 15 4 2.95 Shallow Pitting. • 199 6205 0 0.04 14 2 2.96 200 6235 0 0.03 10 3 2.95 200.1 6267 0.05 0.05 19 6 2.95 Pup Shallow Line Corrosion. 200.2 6277 0 0 0 0 2.93 GLM 2(LATCH © 7:00) d 200.3 6283 0.04 0.05 19 5 2.94 Pup Shallow Line Corrosion. ■ 201 6293 0.08 0.09 35 4 2.94 Line of Pits. um, 202 6324 0 0.08 30 4 2.95 Line of Pits. Elmo 203 6355 0 0.08 30 6 2.94 Line of Pits. sm2 204 6387 0 0.07 27 6 2.95 Line of Pits. tim 205 6418 0.05 0.07 28 4 2.94 Line of Pits. um 206 6449 0 0.09 35 4 2.93 Line of Pits. simm 207 6480 0.08 0.09 35 6 2.94 Line of Pits. ioti 208 6511 0.04 0.07 26 5 2.95 Line of Pits. .•• 209 6542 0.04 0.07 27 4 2.94 Line of Pits. •• 210 6574 0.04 0.06 . 23 4 2.96 Line of Pits. EN 211 6604 0.06 0.07 26 3 2.95 Line of Pits. No 212 6637 0 0.06 25 4 2.95 Line of Pits. .. 213 6668 0 0.07 28 3 2.92 Line of Pits. Lt.Deposits. ■o 214 6700 0 0.06 25 3 2.93 Line of Pits. sin 215 6729 0 0.08 30 4 2.94 Line of Pits. mtinr 216 6760 0 0.07 29 4 2.95 Line of Pits. Em! 217 6792 0 0.06 25 4 2.93 Line of Pits. •• 218 6824 0.04 0.07 29 4 2.95 Isolated Pitting. EN 219 6855 0.06 0.09 35 4 2.94 Line of Pits. Emu 220 6885 0.06 0.09 36 4 2.94 Line of Pits. mum 221 6916 0.06 0.08 33 6 2.95 Line of Pits. momi 222 6946 0.06 0.08 32 4 2.94 Line of Pits. Elm 223 6977 0 0.08 32 5 2.94 Line of Pits. u.N 224 7009 0.07 0.09 34 7 2.92 Line of Pits. Lt.Deposits. um. 225 7039 0.04 0.10 40 4 2.93 Line of Pits. Nil 226 7069 0.04 0.10 39 5 2.95 Line of Pits. NEN 227 7100 0.07 0.08 31 5 2.94 Line of Pits. .mu 228 7130 0 0.10 37 4 2.94 Line of Pits. ••••229 7162 0.07 0.10 39 4 2.94 Line of Pits. NNE 230 7193 0.05 0.10 39 6 2.94 Line Corrosion. Nom 231 7223 0.07 0.12 46 5 2.94 Line of Pits. owl 232 7254 0.05 0.09 35 4 2.95 Line of Pits. mem 233 7285 0.06 0.10 40 4 2.94 Line of Pits. Nom 234 7316 0.07 0.08 32 9 2.94 Line Corrosion. iim 235 7348 0.07 0.10 39 6 2.94 Line of Pits. ME. 236 7378 0.09 0.08 33 4 2.94 Line of Pits. um 237 7409 0.06 0.10 41 4 2.94 Line of Pits. ammo 238 7440 0.05 0.11 45 5 2.93 Line of Pits. Lt.Deposits. NEI 239 7470 0 0.07 28 6 2.92 Line of Pits. Lt.Deposits. Imo' 240 7501 0.08 0.09 35 4 2.93 Line of Pits. IPenetration Body Metal Loss Body Page 5 • • pi 4_4. 0 PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 241 7532 0.08 0.08 31 4 2.93 Line of Pits. Lt.Deposits. Ems 242 7564 0.07 0.09 36 7 2.94 Line of Pits. =NI 243 7595 0.04 0.09 36 6 2.91 Line of Pits. Lt.Deposits. nue 244 7627 0.06 0.09 34 5 2.94 Line Corrosion. Imo 245 7658 0.08 0.08 33 5 2.95 Line Corrosion. mom 246 7690 0 0.09 34 7 2.92 Line Corrosion. Lt.Deposits. mem 247 7719 0.04 0.11 45 4 2.94 Line Corrosion. Emi 248 7750 0.08 0.10 39 7 2.93 Line Corrosion. min 249 7782 0.08 0.09 37 6 2.94 Line Corrosion. HIM 250 7814 0.05 0.11 43 6 2.93 Line Corrosion. Lt.Deposits. Immo 251 7844 0 0.12 46 6 2.92 Line Corrosion. Lt.Deposits. mom 252 7876 0.09 0.10 37 6 2.93 Line Corrosion. Lt.Deposits. .m.id 253 7907 0.05 0.12 45 6 2.91 Line Corrosion. Lt.Deposits. n... 254 7938 0.08 0.11 44 7 2.92 Line Corrosion. Lt.Deposits. =mei 255 7968 0.05 0.10 41 6 2.93 Line Corrosion. Lt.Deposits. mom 256 8000 0.08 0.11 43 7 2.94 Line Corrosion. nium 257 8030 0.07 0.10 41 6 2.94 Line Corrosion. MIMI 258 8061 0.04 0.11 44 6 2.92 Line Corrosion. Lt.Deposits. mo 259 8093 0.04 0.10 39 7 2.91 Line Corrosion. Lt.Deposits. imn' 260 8124 0.08 0.11 42 5 2.92 Line Corrosion. Lt.Deposits. MIIIIMMI 261 8155 0.07 0.11 44 7 2.92 Line Corrosion. Lt.Deposits. 1 261.1 8186 0 0.03 12 4 2.92 Pup Lt. Deposits. 261.2 8196 0 0 0 0 2.91 GLM 3(LATCH @ 8:00) 261.3 8201 0 0.03 12 4 2.95 Pup li 262 8212 0 0.08 30 4 2.93 Line of Pits. Nim 263 8243 0 0.06 23 4 2.95 Line of Pits. No 264 8274 0.04 0.06 23 6 2.94 Line of Pits. 1 265 8304 0.04 0.04 14 4 2.94 • 266 8335 0 0.04 14 3 2.93 Lt.Deposits. 267 8367 0 0.04 14 3 2.94 • 268 8398 0 0.03 11 3 2.95 • 269 8428 0 0.03 13 4 2.93 Lt.Deposits. • 270 8461 0.04 0.03 13 3 2.91 Lt.Deposits. • 271 8491 0 0.03 13 2 2.94 • 272 8522 0 0.06 . 23 3 2.93 Isolated Pitting. Lt.Deposits. • 273 8552 0 0.04 14 7 2.93 Lt.Deposits. i 274 8583 0 0.03 11 3 2.93 Lt.Deposits. • 275 8616 0 0.03 13 5 2.93 i 276 8644 0.09 0.04 14 4 2.94 • 277 8677 0 0.03 11 2 2.91 Lt.Deposits. • 278 8707 0 0.03 11 2 2.93 • 279 8738 0 0.03 11 4 2.92 Lt.Deposits. ii 280 8769 0 0.03 10 4 2.93 • 281 8800 0 0.04 15 4 2.90 Shallow Pitting. Lt Deposits. 282 8831 0 0.02 7 2 2.92 Lt.Deposits. 283 8863 0 0.03 10 2 2.97 • 284 8893 0 0.03 11 2 2.94 • 285 8924 0 0.04 14 3 2.91 Lt.Deposits. 11 286 8955 0 0.02 9 2 2.93 r 287 8986 0 0.03 13 2 2.94 IPenetration Body Metal Loss Body Page 6 • 0 III 41-144- OIL PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 288 9018 0 0.02 9 2 2.95 289 9049 0 0.03 11 2 2.93 290 9081 0 0.03 11 2 2.95 291 9112 0 0.03 13 3 2.94 292 9144 0 0.03 11 4 2.92 Lt.Deposits. 293 9176 0 0.02 9 2 2.93 Lt.Deposits. C 294 9207 0 0.02 9 3 2.91 Lt.Deposits. 295 9238 0 0.02 8 3 2.93 296 9268 0 0.02 9 3 2.93 297 9299 0 0.03 13 3 2.94 m 298 9331 0 0.03 13 5 2.93ll 299 9361 0 0.02 9 2 2.93 Lt.Deposits. 300 9394 0 0.03 11 4 2.90 Lt.Deposits. • 301 9424 0 0.04 14 2 2.92 Lt.Deposits. 302 9457 0 0.03 11 2 2.94 • 303 9486 0 0.04 14 4 2.93 Lt.Deposits. 304 9519 0 0,03 13 2 2.93 305 9551 0 0.03 12 3 2.95 M 306 9581 0 0.03 11 3 2.94 • 307 9611 0 0.03 12 3 2.94 as 308 9643 0 0.02 8 2 2.92 Lt.Deposits. • 309 9672 0 0.03 11 5 2.91 Lt.Deposits. 310 9705 0 0.03 13 4 2.94 311 9735 0 0.02 9 2 2.94 312 9768 0 0.04 14 2 2.91 Lt.Deposits. No 313 9798 0 0.02 9 3 2.92 Lt.Deposits. • 314 9830 0 0.03 11 2 2.94 • 315 9860 0 0.03 11 3 2.95 • 315.1 9894 0 0.03 13 0 2.93 Pup 315.2 9901 0 0 0 0 2.89 GLM 4(LATCH C 8:30) 315.3 9907 0 0.04 15 6 2.88 Pup Shallow Line of Pits.Lt. Deposits. 316 9919 0 0.02 9 3 2.93 Lt.Deposits. 317 9950 0 0.04 14 3 2.94 r 318 9981 0 0,04 14 2 2.94 r 319 10011 0 0.03 13 4 2.93 320 10044 0 0.02 9 2 2.94 321 10074 0 0.02 9 2 2.91 Lt.Deposits. r 322 10105 0 0.03 13 4 2.89 Lt.Deposits. 323 10137 0 0.03 12 3 2.93 Lt.Deposits. 324 10169 0 0.03 12 3 2.93 Lt.Deposits. a 325 10199 0 0.03 13 3 2.93 Lt.Deposits. M• 326 10230 0.04 0.03 13 4 2.94 327 10260 0 0.02 9 2 2.92 Lt.Deposits. 328 10290 0 0.03 10 2 2.92 Lt.Deposits. • 329 10323 0 0.03 10 3 2.91 Lt.Deposits. • 330 10351 0 0.03 13 3 2.93 Lt.Deposits. m 331 10384 0 0.02 9 2 2.94 1111 332 10415 0 0.02 9 4 2.94 • 333 10447 0 0.03 13 3 2.94 334 10478 0 0.02 9 2 2.94 r IPenetration Body Metal Loss Body Page 7 • PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 335 10509 0 0.02 8 2 2.92 Lt.Deposits. 336 10541 0 0.02 9 3 2.92 Lt.Deposits. 337 10571 0 0 0 0 2.93 Temporary Tool Malfuction 338 10604 0 0 0 0 2.95 Tempo rary Tool Malfuction 339 10635 0 0 0 0 2.96 Temporary Tool Malfuction 340 10666 0 0 0 0 2.96 Tempo rary Tool Malfuction 341 10699 0 0 0 0 2.96 Temporary Tool Malfuction 342 10729 0 0 0 0 2.96 Temporary Tool Malfuction 343 10760 0 0 0 0 2.96 Temporary Tool Malfuction 344 10790 0 0 0 0 2.96 Tempo rarvTool Malfuction 345 10823 0 0 0 0 2.96 Temporary Tool Malfuction 346 10853 0.04 0.03 12 2 2.94 Temporary Tool Malfuction 347 10882 0.04 0.04 14 4 2.92 Lt.Deposits. 348 10916 0 0.02 9 2 2.92 Lt.Deposits. 349 10947 0 0.03 10 4 2.93 Lt.Deposits. 350 10977 0 0.03 13 4 2.92 Lt.Deposits. 351 11010 0 0.03 12 3 2.91 Lt.Deposits. 352 11041 0 0.03 10 4 2.90 Lt.Deposits. 353 11071 0 0.03 11 3 2.93 Lt.Deposits. 354 11102 0 0.02 7 2 2.93 Lt.Deposits. • 355 11132 0 0.03 11 4 2.90 Lt.Deposits. 356 11163 0 0.02 9 3 2.93 357 11194 0 0.04 14 5 2.92 Lt.Deposits. 358 11225 0 0.03 11 4 2.90 Lt.Deposits. 359 11258 0 0.03 10 2 2.91 Lt.Deposits. 360 11289 0 0.03 11 4 2.90 Lt.Deposits. 361 11319 0 0.03 13 2 2.92 Lt.Deposits. 362 11351 0 0.03 11 4 2.92 Lt.Deposits. 363 11382 0 0.02 9 2 2.95 364 11414 0 0.03 13 2 2.91 Lt.Deposits. • 364.1 11445 0 0.04 14 6 2.88 Pup Lt. Deposits. 364.2 11455 0 0 0 0 2.86 GLM 5(LATCH @ 10:30) 364.3 11462 0 0.03 11 2 2.94 Pup ■ 365 11472 0 0.03 12 3 2.91 Lt.Deposits. 366 11503 0 0.02 8 3 2.92 Lt.Deposits. 367 11534 0 0.03 12 2 2.90 Lt.Deposits. 368 11566 0 0.03 13 4 2.90 Lt.Deposits. 369 11597 0 0.03 13 2 2.92 Lt.Deposits. 370 11626 0 0.03 11 2 2.90 Lt.Deposits. • 371 11657 0.04 0.03 13 5 2.94 372 11689 0 0.03 11 3 2.91 Lt.Deposits. 373 11719 0 0.04 14 3 2.90 Lt.Deposits. 374 11749 0 0.03 13 3 2.90 Lt.Deposits. 375 11781 0 0.04 14 2 2.88 Lt.Deposits. 376 11811 0 0.03 13 5 2.89 Lt.Deposits. 377 11842 0 0.03 13 2 2.87 Lt.Deposits. 378 11872 0 0.03 10 2 2.91 Lt.Deposits. • 379 11903 0 0.03 11 3 2.89 Lt.Deposits. 380 11934 0 0.03 11 3 2.90 Lt.Deposits. 381 11965 0 0.02 9 2 2.90 Lt.Deposits. • IPenetration Body Metal Loss Body Page 8 • • 1101 PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 382 11997 0 0.03 12 3 2.91 Lt.Deposits. 383 1202 7 0 0.02 9 2 2.91 Lt.Deposits. 384 12058 0 0.03 13 4 2.88 Lt.Deposits. ■� 385 12090 0 0.02 9 2 2.90 Lt.Deposits. r 386 12120 0 0.04 14 3 2.90 Lt.Deposits. ■ 387 12152 0 0.03 13 4 2.90 Lt.Deposits. ■ 388 12183 0 0.03 13 4 2.91 Lt.Deposits. 389 12213 0 0.03 10 2 2.89 Lt.Deposits. 390 12245 0 0.03 13 2 2.89 Lt.Deposits. ■ 391 12275 0 0.04 14 3 2.89 Lt.Deposits. ■ 392 12306 0 0.03 13 4 2.87 Lt.Deposits. ■ 393 1233 7 0 0.03 11 4 2.92 Lt.Deposits. ■ 394 12368 0 0.03 11 4 2.89 Lt.Deposits. ■ 395 12399 0 0.03 11 4 2.91 Lt.Deposits. ■ 396 12430 0 0.04 14 2 2.92 Lt.Deposits. ■ 397 12460 0 0.04 14 5 2.89 Lt.Deposits. ■ 398 12492 0 0.03 12 4 2.89 Lt.Deposits. ■ 399 12523 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 400 12555 0 0.03 13 3 2.90 Lt.Deposits. 401 12585 0 0.02 9 3 2.90 Lt.Deposits. 402 12617 0 0.03 10 4 2.94 403 12648 0 0.03 13 4 2.91 Lt.Deposits. ■ 404 12679 0 0.03 12 2 2.91 Lt.Deposits. 405 12710 0 0.02 9 4 2.89 Lt.Deposits. 406 12741 0 0.03 13 2 2.89 Lt.Deposits. • 407 12772 0 0.03 13 3 2.91 Lt.Deposits. ■ 408 12803 0.08 0.03 13 2 2.90 Lt.Deposits. ■ 409 12835 0 0.03 11 2 2.90 Lt.Deposits. ■ 410 12864 0 0.03 11 2 2.89 Lt.Deposits. 411 12893 0 0.03 10 3 2.91 Lt.Deposits. 412 12924 0 0.03 11 2 2.93 Lt.Deposits. ■ 413 12955 0 0.03 11 3 2.90 Lt.Deposits. 414 12985 0 0.02 9 2 2.92 Lt.Deposits. 415 13015 0 0.02 9 3 2.89 Lt.Deposits. 416 13046 0 0.02 9 2 2.89 Lt.Deposits. ■( 417 13077 0 0.03 10 2 2.89 Lt.Deposits. ■� 418 13109 0 0.04 14 2 2.92 Lt.Deposits. • 419 13140 0 0.04 14 3 2.90 Lt.Deposits. 420 13171 0 0.02 9 3 2.90 Lt.Deposits. 421 13202 0 0.03 11 4 2.91 Lt.Deposits. ■ 422 13234 0 0.03 11 5 2.92 Lt.Deposits. ■ 423 13264 0 0.03 11 3 2.90 Lt.Deposits. ■ 424 13296 0 0.03 13 3 2.92 Lt.Deposits. ■ 424.1 13325 0 0.03 12 2 2.95 Pup 424.2 13331 0 0 0 0 2.83 GLM 6(LATCH @ 1:00) 424.3 13340 0 0.03 11 4 2.94 Pup ■ 425 13346 0 0.03 13 3 2.90 Lt.Deposits. 425.1 13377 0 0 0 0 2.80 CAMCO W NIPPLE 426 13379 0 0.03 13 4 2.90 Lt.Deposits. ■ 426.1 13410 0 0.03 11 4 2.89 Pup Lt. Deposits. Penetration Body Metal Loss Body Page 9 • • PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Tubing 2.992 in. 0.254 in. -7 ft. 13,484 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 426.2 13418 0 0 0 0 2.97 BAKER SB-3 PERMANENT PACKER 426.3 13425 0 0.03 13 5 2.91 Pup Lt. Deposits. 427 13433 0 0.04 14 3 2.88 Lt.Deposits. 427.1 13464 0 0.03 11 3 2.87 Pup Lt. Deposits. 427.2 13474 0 0 0 0 2.74 CAMCO DN NIPPLE 427.3 13475 0 0.03 10 3 2.94 Pup 427.4 13484 0 0 0 0 2.92 BAKER SHEAR OUT SUB IPenetration Body Metal Loss Body Page 10 • • PDS Cross Report Sections p os Sect o s Well: 1C-23 Survey bate: February 14,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: C.Waldrop Cross Section for Joint 251 at depth 7,861 .500 ft. Tool speed= 52 Nominal ID=2.992 ...a., Nominal OD=3.5 Remaining wall area=95% r ` Tool deviation=68° 1 Finger= 15 Penetration=0.118 in. Line Corrosion 0.12 in.=46%Wall Penetration HIGH SIDE=UP 111:a.S. PDS Report Cross Sections Well: 1C-23 Survey Date: February 14,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE 8RD MOD Analyst: C.Waldrop Cross Section for Joint 231 at depth 7,230.350 ft. Tool speed=54 Nominal ID=2.992 Nominal OD=3.5 _ u Remaining wall area=95% Tool deviation=64° _ _ Finger= 15 Penetration=0.116 in. Line of Pits 0.12 in.=46%Wall Penetration HIGH SIDE=UP • • kS, Minimum Diameter Profile Well: 1C-23 Survey Date: February 14,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 6.276 inches Minimum Measured Diameters (in.) 1.75 2 3 4 5 6 13,485 1 I I I — 13,500 i r E 2 C a' - a. I 0 I - 113,541 1 3 1 • • PDS Report Overview S► Body Region Analysis Well: 1C-23 Survey Date: February 14,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf L-80 BTC-MOD Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 BTC-MOD 6.276 in. 13,485 ft. 13,550 ft. Penetration (%wall) Damage Profile(%wall) 10 UMW Penetration body mol Metal loss body 0 50 100 1 8 — - 6 4 2 0 0 to 20 to 40 to over 2 <-.m 20% 40% 85% 85% Number of joints analyzed(total=3) 1 0 0 0 Damage Configuration(body) 10 8 3 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total= 1) 1 0 0 0 0 Bottom of Survey=3 = Perforations 0 • ill 4-410.. PDS Report Joint Tabulation Sheet Well: 1C-23 Survey Date: February 14, 2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf L-80 BTC-MOD Casing 6.276 in. 0.362 in. 13,485 ft. 13,550 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 1 13485 0.06 0.05 15 6 6.22 Shallow Pitting. F ; :IMII 2 13500 0.26 0.66 100 10 5.91 Perforations Lt.Deposits. 3 13541 0 0.25 70 6 5.47 Perforations Oval Deformation. I Penetration Perforations Body Metal Loss Perforations 'Penetration Metal Loss Body Page 1 i Ct":14.S. PDS Report Cross Sections Well: 1C-23 Survey Date: February 14,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10019107 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf L-80 BTC-MOD Analyst: C.Waldrop Cross Section for Joint 3 at depth 13,545.659 Tool speed= 40 Nominal ID=6.276 Nominal OD= 7 Remaining wall area=N/A ��, • Tool deviation=66° 1 Minimum I.D.=5.473 in. Oval Deformation in Perforation Interval Minimum I.D.=5.47 in. HIGH SIDE= UP KUP PROD • 1C-23 ConocoPhillips m Well Attributes Max Angle&MD TD Alaska,InC. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) C ty 500292294200 KUPARUK RIVER UNIT PROD 67.14 9,137.57 13,975.0 ••• • Comment 1-125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-23,1/17/2015 T3204 AM SSSV:NIPPLE 50 12/16/2013 Last WO: 40.02 5/21/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 13,555.0 1/10/2015 Rev Reason:GLV 0/0,PULL PLUG& hipshkf 1/17/2015 HANGER;30.0 CATCHER,TAG Casing Strings l'-. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread !rs CONDUCTOR 16 15.062 34.0 121.0 121.0 62.58 H-40 WELDED y � Coning ACEDescription OD(in) ID(In) Top OMB) Set Depth(ftKB) Set Depth(ND)...Wt/Len 0...Grade Top Thread 95/8 8.835 33,3 8,894.4 4,573.0 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.0 13,960.0 6,711.6 26.00 L-80 BTC-MOD 'Tubing Strings Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)I...Wt(Ib/ft) Grade Top Connection TUBING I 31/21 2.992 30.01 13,504.2 6,515.81 9.301 L-80 I EUE8RDMOD � F .-,--Completion Details CONDUCTOR;34.0-121.0 p - Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(7 Item Des Com (in) 111 30.0 30.0 0.12 HANGER FMC GEN IV SM HANGER 3.500 NIPPLE;486.2 486.2 485.8 5.80 NIPPLE CAMCO DS NIPPLE 2.875 13,394.8 6,469.7 65.28 NIPPLE CAMCO W NIPPLE 2.812 1 I 13,436.0 6,487.0 65.11 SEAL ASSY KBH-22 ANCHOR SEAL ASSEMBLY 2.992 13,436.9 6,487.4 65.11 PACKER BAKER SB-3 PERMANENT PACKER 2.937 13,492.3 6,510.8 64.95 NIPPLE CAMCO D NIPPLE w/NO GO PROFILE 2.750 13,503.3 6,515.4 64.93 SOS BAKER SHEAR OUT SUB 3.015 GAS LIFT;3,537.1 Perforations&Slots Shot Den Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date t) Type Com 13,537.0 13,587.0 6,529.7 6,551.0 C-4,1C-23 6/6/1999 4.0 IPERF 2.5"HSD,180 phasing, GAS LIFT;6,295.4 _/-90 deg orient Mandrel Inserts s ari on Top(TVD) Valve Latch Port Size TRO Run --y N. Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com GAS LIFT;8,214.2 f t i '1 3,537.1 2,333.2 CAMCO KBMM 1 GAS LIFT GLV BK 0.156 1,250.0 1/9/2015 2 6,295.4 3,495.2 CAMCO KBMM 1 GAS LIFT GLV BK 0.188 1,281.0 1/9/2015 3 8,214.2 4,291.7 CAMCO KBMM 1 GAS LIFT OV BK 0.250 0.0 1/8/2014 4 9,922.0 4,999.2 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 6/6/2012 5 11,4747 5,647.1 CAMCO KBMM 1 GAS LIFT DMY BK 0.000 0.0 6/6/2012 6 13,349.6 6,450.9 CAMCO MMM 1)/2 GAS LIFT DMY RK 0.000 0.0 12/5/2014 Notes:General&Safety End Date Annotation SURFACE,333-e 894 a-... 8/13/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,9,922.0 f L l GAS LIFT;11,474.7 GAS LIFT;13,349.6 1-1 NIPPLE;13,394.8 SEAL ASSY;13,436.0 PACKER;13,436.9 I-- NIPPLE; -NIPPLE;13,492.3 SOS;13,503.3 IPERF;13,537.0-13,587.0 - PRODUCTION;38.0-13,960.0 - • STATE OF ALASKA RECEIVED , ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 1 3 2015 REPORT OF SUNDRY WELL OPERATIONS _�jC 1.Operations Performed Abandon I- Repair well F Plug Perforations [ Perforate r Other(✓G �1 , Alter Casing E Pull Tubing E Stimulate-Frac r Waiver E Time Extension F 01-- Change Approved Program f Operat.Shutdown fl Stimulate-Other r Re-enter Suspended la 2 Operator Name. 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen f Exploratory f 199-034 3.Address: 6.API Number: Stratigraphi r Service F P.O. Box 100360,Anchorage,Alaska 99510 50-029-22942-00 7.Property Designation(Lease Number): 8.Well Name and Number. ADL0028242 KRU 1C-23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11 Present Well Condition Summary: Total Depth measured 13975 feet Plugs(measured) 13492 true vertical 6718 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 13437 true vertical 0 feet (true vertical) 6487 Casing Length Size MD TVD Burst Collapse CONDUCTOR 87 16 121 0 0 0 SURFACE 8861 12 8894 0 0 0 PRODUCTION 13922 7 13960 0 0 0 Perforation depth: Measured depth: 13537 to 13587 SP��1N�G j��i ![�1� True Vertical Depth' 6530 to 6551 SCANNED Tubing(size,grade,MD,and TVD) 3 5, L-80, 13503 MD,6515 TVD Packers&SSSV(type, MD,and TVD) PACKER-BAKER SB-3 PERMANENT PACKER @ 13437 MD and 6487 TVD 12 Stimulation or cement squeeze summary. Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data 011-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory fl Development E Service F Stratigraphic E X 16.Well Status after work Oil F Gas 1 WDSPL r Daily Report of Well Operations GSTOR E WINJ [ WAG E GINJ E SUSP f SPLUG 1-- 17. 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O Exempt NA Contact MJ Loveland/Martin Walters Email n1878@conocophillips.com Printed Name Martin Walters J Title WI Proj Supvisor G��� �J ✓���/(, Signature / Phone:659-7403 Date 1/6/15 ori- 1/21 J l s RBDMS JAN 1 3 2015 f� Form 10-404 Revised 10/2012 4r e �f Submit Orig nal Only RECEIVED ConocoPhillips Alaska JAN 13 2015 P.O. BOX 100360 A G nV C ANCHORAGE,ALASKA 99510-0360 January 6, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc.'s well 1C-23 (PTD #199-034) for seal welding starter head. Please call me or MJ Loveland at 659-7043 if you have any questions. Sincerely, iyuk 60c& Martin Walters ConocoPhillips Well Integrity Projects Supervisor 1C-23 DESCRIPTION OF WORK COMPLETED SUMMARY • Date Event Summary 12/16/14 Prep and secure well for starter head repairs. 12/29/14 Seal weld starter head. 01/04/15 Perform surface casing integrity test with Little Red Servive to 1,660 psi with no signs of leaks. ) i ;a3 (/). (4n uM/ ! � O 0. —Y• „, , r... if// :I1Ji , «; 0 a)O 0U ±O C f A.'. C E ..0 U , y VI . ' �,. ..rte_-_ .��.-.__ . - ..,r.;, .. ,, ... - • \ ,+ $ .' ' i + - ya 4 D r ± 5 ,I4'. - f z 1 s� '" �t .teaf F t IP"' _ I Y a _ '' G ` _ k 4 ;, ` D34-} `to'� WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. - "September 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED F Lb 2 2.015 RE: Gas Lift Survey/Bottom Hole Pressure Survey: 1C-23 Run Date: 8/27/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C-23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22942-00 Gas Lift Survey/Bottom Hole Pressure Survey Log 1 Color Log 50-029-22942-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 4/19 Signed: OiLA I XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by' Bevedy Mildred Daretha~owell Date: ~. / '"7 [] TO RE-SCAN Notes: Re-Scan ned by: Bevedy Mildred Daretha Nathan Lowell Date: Isl y' . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Jan 2, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECEIVED JAN 0 7 2009 Alaska Oil ili Gas Cons. Commission Anchorage p3~ 1~1~~ ~3 t ~~ ~~~~~~ JAN t 20G Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Similarly, It was noticed In August 2007 that 5 wells on DS 1 C had similar cement and sealant treatments. These wells were inadvertently omitted from the 10-404 submitted at that time for other work being performed. These wells are included here. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Kl ' ConocoPhillips Well Integrity Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-09 183-104 11" na 11" na 1.70 12/7/2008 1 F-14 183-146 18" na 18" na 2.00 12/7/2008 1 F-17 196-047 8" na 8" na 1.70 12/7/2008 1 F-19 196-052 8" na 8" na 1.70 12/7/2008 1 F-20 196-053 6" na 6" na 1.00 12/7/2008 1C-111 201-928 5' 9" 0.50 18" 8/27/2007 21.00 8/29/2007 1 C-13 198-011 32' 10" 4.00 18" 8/27/2007 17.00 8/29/2007 1 C-14 206-001 14' 6" 2.00 18" 8/27/2007 9.00 8/29/2007 1 C-21 205-034 38' 10" 4.00 18" 8/27/2007 8.60 8/29/2007 C-23 4l9-034 10' 10" 1.50 18" 8/27/2007 23.00 8/29/2007 Ms. Wendy Mahan AOGCC Second Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the second quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 5 CDI-19 33933 100 0 34033 Open, Freeze Protected ,,~ 1C-25 34836 100 0 34936 Open, Freeze Protected 7- CD1-40 32777 100 0 32877 Open, Freeze Protected 1 C-23 34470 100 0 34570 Open, Freeze Protected 5-' 1C-18 0 0 0 0 Open, Freeze Protected ~' CD1-35 217 100 0 317 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Doug Chester Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files 199-034-0 KUPARUK RIV UNIT 1C-23 50- 029-22942-00 Roll gl: Start: Stop Roll #2: S. tart Stop MD 13975 -- TVD 06718 "'Completion ~~e.' 5/21/9--~- Completed Status: 1-OIL PHILLIPS ALASKA INC Current: L DGR/EWR4-MD L DGR/EWR4-TVD R SRVY RPT R SRVY RPT T Name Interval D 9057~''''~-' 5,6 , SPERRY MPT/GR/EWR4/CNP/SLD OH / L DGR/CNP/SLD-MD ~[~AL 8910-13975 OH L DGR/CNP/SLD-TVD C/FINAL 4579-6718 OH 8910-13975 --~ OH ,E~f/~'' 4579-6718 ~ OH ~~RRY, A 748.98-13975. OH ~Y 0-7117 ST1 OH Sent Received T/C/D 10/12/99 10/19/99 11/4/99 11/4/99 11/4/99 11/4/99 11/4/99 11/4/99 11/4/99 11/4/99 6/9/99 6/17/99 6/9/99 6/17/99 Tuesday, May 01,2001 Page 1 of 1 1C-23 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 12/4/99: RIH & tagged PBTD at 13876' MD. 12/8/99: MIRU & PT equipment. Pumped a 'C' Sand Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforation interval located at: 13537 - 13587' M D Pumped Breakdown: a) 325 bbls 20# Linear Gel, followed by b) Shutdown. ISIP @ 1352. Resumed pumping Scour Stage: c) 150 bbls 50# Crosslinked Pad Scour Stage, w/last 40 bbls containing I ppa proppant, followed by d) 170 bbls Flush @ 20 bpm, followed by e) Shutdown. Resumed pumping Data Frac: f) 100 bbls Crosslinked Gel, followed by g) Shutdown. ISIP @ 1582. Resumed pumping Frac Treatment: h) i) J) k) Placed a total of 56,400 lbs of proppant into the formation. 12/10/99: Performed a CT proppant fill cleanout to 13750' MD. 119100: RIH & tagged fill at 13615' MD. 140 bbls Pad, followed by Slurry stages, w/proppant concentrations ramped in stages at 1 to 10 ppa, followed by Flush stage, followed by Shutdown. Rigged down. Returned the well to production and obtained a valid well test. [:] IR I LLI r~ I~ ~; E FtL/I r" Ec; WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 .! q November 04, 1999 RE: MWD Formation Evaluation Logs 1C-23, AK-MM-90114 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1C-23: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22942-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22942-00 2"x 5"MD Neutron & Density Logs: 50-029-22942-00 2"x 5" TVD Neutron & Density Logs: 50-029-22942-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia gl(~)d 0 4 1999 AI~ 0il & 6as Cons. Oommi~ion An~ora~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Anmdar b~.jectiou during the third quarter of 1999. h(1) h(2) ! h(3) Total for Previous ] New Well Name ! Volume Volume i Volume Quarter I Total I Total 1C-25 I 520 100 ~ 0 620 I 34316 I 34936 c -40 t l i 20079 100 [ 0 20179 [ 12171 I 32350 CD1-01 t 4905 100 ] 0 5005 0 5005 I 1C-23 i 24865 100 i 0 24965 ~ 9605 34570 CD1-23 i ! 16079 100 0 16179 0 16719 CD1-37 I 17173 100 ! 0 17273 0 17273 CD1-39 ! ] 3917 100 i 0 I 4017 0 4017 1D-12 ', 4305 100 ~ 0 [ 4405 [ 0 , 4405 q9o 51 99- .n4. - 99- .~ ~, * 99-.6 3 - qg- 8o - Total Volumes into Annuli for which b~jection Authorization Expired during the quarter Well Name 1D-09 Total h(1) Volume 32540 Total h(2) Volume 100 Total h(3) Volume 0 Total Volume Injected 32640 Status of Annulus Open, Freeze Protected 2N-337A 30539 100 0 30639 Open, Freeze Protected 2N-313 ~ 32758 100 I 0 32858 Open, Freeze Protected 2N-321A ' 27507 100 ' 0 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Gas Cons. C0mrntsston Anch0ra~e CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental' Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two 0 I::t I I_1-- I I~ (~ WELL LOG TRANSMI'IT~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 12, 1999 1 C-23, AK-MM-90114 1 LDWG formatted Disc with verification listing. API#: 50-029-22942-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPY OF THE TRANSMFUFAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 REC"':- ' '"" Date:',~, , 9 1999 Gas Cong. Commmmon Sign 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company TONY KNOWLES, GOv~.~,~.- . ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRI~'E · MNCItORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 TELECOPY: (907)276-7542 August 11, 1999 Paul Mazzolini Drilling Team Leader ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River well 1 C-23 ~' ?'' ~ 3 ~ Annular Disposal - Request to Exceed Volume Limitation under 20 AAC 25.080(d)(1) Dear Mr. Mazzolini' The Commission has reviewed your August 4, 1999 request to dispose a volume of drilling waste greater than 35,000 barrels through the annular space of well 1C-23. An exception to 20 AAC 25.080(d)(1) will allow AAI to inject the remainder of drilling waste from well 1C-26 into the annulus of well 1C-23. The remaining volume is estimated at less than 10,000 barrels. There are currently no other wells permitted for annular disposal on 1C pad. AAI is nearing the end of the lC pad's work scope. Upon completion of well 1C-26, no additional wells are anticipated on the pad. It is therefore reasonable to allow additional disposal into well 1 C-23, and eliminate the spill risks incurred by handling and transporting the waste to another pad for disposal. The additional fluids generated from drilling of the 1 C-26 well may be injected into the 1C-23 annulus. David W Jotil~n ~ Commissioner ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 4, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Subject: 1C-23 (Permit No. 99-34/399-092) Request for Waiver Dear Mr. Commissioner: ARCO Alaska, Inc. is respectfully requesting an exception dispensation for injection volumes into the 1C-23 annulus. The initial annular injection approval, dated 5/28/99 provided for a maximum injected volume of 35,000 bbls. Since that time, Pool 6 has injected 32,570 bbls of fluid from drilling operations on wells 1C-27 and 1C-26 into the 1C-23 annulus. We are presently at TD in well 1C-26 and also at the end of ARCO's lC pad work scope and do not foresee additional injection requirements for other well work in the near future. The purpose of this request is to allow for injection of the remaining volumes from 1C-26 (estimated to be less than 10,000 bbls additional volume) to 1C-23. There are no other currently permitted annular injection wells on lC pad. This request is for a total injection volume of 45,000 bbls into the 1C-23 annulus. If acceptable, please expedite approval of this request. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini -~/~ ~ Drilling Team Leader AAI Drilling PM/skad ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 1999 Dear Ms. Mahan: ~o. Please find reported below volumes injected into surface casing by production casing annuli during the second quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the second quarter of 1999. Annular hijection during the second quarter of 1999: h(1) h(2) I h(3) ~ Total for Previous New Well Name Volume Volume] Volume Quarter Total Total 1C-15 34380 100 0 32195 16795 48990 2L-313 3779 100 0 3879 8654 12533 CDI-19 33933 100 0 34033 0 34033 1C-25 34216 100 0 34316 0 34316 CD1-40 12071 100 0 12171 0 12171 1C-23 9505 100 0 9605 ~ 0 9605 Total Volumes into Annuli for ,vtzich Injection Authorization Expired during the quarter Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus 1 D- 10 35473 100 0 35573 Open, Freeze Protected 2N-323 32696 100 0 32796 Open, Freeze Protected 2N-343 17895 100 0 17995 Open, Freeze Protected 2N-329 9 100 0 109 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Ms. Wendv Mahan AOGCC Second Quarter 1999 Annular Injection Report Page Two CC: Mike Zanghi Paul Mazzolini Randy Thomas Kupamk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION o~~C~i WELL COMPLETION OR RECOMPLETION REPORT AND L 1. Status of well Classification of Service Well lan, Oil [] Gas [] Suspended [] Abandoned [] Service [] 4/aRl,,.~. 2. Name of Operator 7. Permit Number -' Co~ ARCO Alaska, Inc. 99-34 3. Address 8. APl Number - P. O. Box 100360, Anchorage, AK 99510-0360 ~; ';:r-:; ;;~:'~:'¢;~¢'-~ .... ~ .... 50-029-22942 4. Location of well at surface :, r-~--~':"' ; ~~~ 9. Unit or Lease Name 1660' FNL, 1277' FWL, Sec. 12, T11N, R10E, ,M !~~~ ~~ Kuparuk River Unit At Top Producing Interval ~: VE~iFiE[~ ~..~ lO. Well Number 278' FNL, 2293' FWL, SEC 8, T11 N, R11 E, UM ~. ~.~ 10-23 At Total Depth "~ ''- .......... ' .... 11. Field and Pool 235' FNL, 2587' FEL, SEC 8, T11N, R11E, UM Kuparuk River Field 5. ElevationRKB 95in feetfeet(indicate KB, DF, etc.) 6. Lease DesignationADL 28242and SerialALK No.2292 Kuparuk River Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~15. Water Depth, if o~hore 16. No. of Completions April 29, 1999 May 17, 1999 May 21, 1999~ ~A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickn~s of Permafrost 13975' MD/6718' TVD 13870' MD/6673' TVD YES ~ No ~~ ~A feetMD 2268' MD 22. Type Electric or Other Logs Run G~Res 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD . CASING SIZE ~. PER ~. GRADE TOP BOSOM HOLE SIZE CEME~ING RECORD' AMOUNT PULLED 16" 62.5¢ R-3 Surface 115' 24" 9 cu yds High Ear~ 9.625" 40~ L-80 Su~ace 8894' 12.25" 126o sx AS III, 345 sx Class G 7" 26~ L-80 Suffa~ 13960' 8.5" 300 sx Cla~ G 24. Perforations open to Production (MD + TVD of Top and BoSom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 13504' 13437' 13577'-13587' MD 6547'-6551' TVD 4 spf 13537'-13577' MD 6530'-6547' TVD 4 spf 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST 0RiG,NAi Date First Production Method of Operation (Flowing, gas li~, etc.) ~ June 7, 1999 Flowing Date of T~t Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 6/25/1999 12.0 Test Period > 558 162 19 176~ 292 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL G~VI~ - APl (corr) 200 0 24-Hour Rate > 1092 319 38 24 28. CORE DATA Brief d~cription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS NAME Top Kuparuk C BoSom Kuparuk C Top Kuparuk A BoUom Kuparuk A MEAS. DEPTH 13530' 13810' 13975' 13975' TRUE VERT. DEPTH 6527' 6647' 6718' 6718' 30. FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with die~ 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call William Lloyd 265-6531 Signed ~- ~. 0~ Title Drilling Engineering Supervisor Date Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 6/28/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-23 WELL_ID: AK0021 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER I/NIT SPUD:04/29/99 START COMP: RIG:POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22942-00 04/28/99 (D1) TD: 115'(115) SUPV:D.BURLEY 04/29/99 (D2) TD: 1140'(1025 SUPV:D.BURLEY 04/30/99 (D3) TD: 2673'(1533 SUPV:D.BURLEY 05/01/99 (D4) TD: 5204'(2531 SUPV:D.BURLEY MW: 8.6 VISC: 245 PV/YP: 26/46 DRILLING 12-1/4" HOLE FROM 230' APIWL: 7.8 Move rig to well 1C-23. NU diverter system. Accepted rig @ 1500 hrs. Test diverter. Held prespud safety meeting. UPCOMING OPERATIONS:DRILL AHEAD. MW: 9.1 VISC: 155 PV/YP: 46/53 DRILL AHEAD FROM 1500' APIWL: 6.8 Held prespud meeting. Drill from 115' to 1140'. UPCOMING OPERATIONS:WIPER TRIP, DRILL AHEAD. MW: 10.1 VISC: 120 PV/YP: 45/41 DRILLING 12-1/4" HOLE FROM 3518' APIWL: 6.2 PJSM. Drill from 1140' to 1267' Encountered hydrates at 1200'. CBU. Drill from 1267' to 2204'. Circ hole clean, mud weight to 10.1 ppg, monitor well, stable. Wiped hole to 463', pulled through numerous tight spots from 2100' to 1546' Backreamed from 729' to 640', initial packoff problem, lost 15 bbls before good circ established, circ hole clean, gravel and sand at shakers. Pulled from 640' to 463', no problems. RIH, reamed tight spots from 909' to 999' and from 1366' to 1460' Drill from 2204' to 2673' UPCOMING OPERATIONS:DRILL AHEAD, WIPER TRIP. MW: 10.2 VISC: 118 PV/YP: 45/50 DRILL AHEAD FROM 5310' APIWL: 5.8 PSJM. Drill from 2673' to 5204'. Pumped low/high vis sweeps, large increase in cuttings when sweeps came back. Circ clean, monitor well, stable, pumped dry job. Hole swabbing. UPCOMING OPERATIONS:DRILL AHEAD, TRIP FOR BIT. Date: 6/28/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/02/99 (D5) MW: 10.0 VISC: 102 PV/YP: 39/42 APIWL: 5.0 TD: 6670' (1466) SLIDING ~ 7000' SUPV:D.BURLEY / SCOTT REYNOLDS Drill from 5204' to 6137' Change shaker screens. Starting to experience survey problems. High pressure spike shutting down tool. Drill from 6137' to 6231' High pressure surge during survey is shutting down tool. Adjust pump speed to compensate for pressure surge so survey was obtainable. drill from 6231' to 6418' High pressure surges shutting down survey tool after tool starts sending data. Start control drilling from 6418' to 6670'. UPCOMING OPERATIONS:WIPER TRIP. DRILL TO SURFACE HOLE TD. 05/03/99 (D6) MW: 10.2 VISC: 105 PV/YP: 37/38 APIWL: 5.2 TD: 7117' ( 447) SIDETRACK CONFIRMED @ 1840' BY SURVEY. WORKING LEFT TO AVOI SUPV:D.BURLEY / SCOTT REYNOLDS Drill from 6670'-7117' Pump lovis/Hivis sweep. Monitor well, static. Small amount of hydrates. TOOH. Tight spot 3329'-3360'. Work thru tight spot from 1643' Swap out bits. RIH to 1554', tag obstruction. Work thru tight spot from 1554' to 1832' UPCOMING OPERATIONS:DRILL AHEAD--AGAIN!!! 05/04/99 (D7) MW: 10.1 VISC: 108 PV/YP: 43/42 APIWL: 5.0 TD: 3516'( 0) CIRC & COND ~ 3516' W/ HOLE OPENER SUPV:FRED HERBERT / RICK OVERSTREET Cycle MWD to get signal for survey. Orient to high side and attempt to work thru bridge ~ 1832' Sidetracked hole @ 1832'. 2nd KOP ~ 1850'. Drilling 12.25" hole from 1850' to 3516'. Circ & condition for wiper trip. T00H. Tight 8 1720'. Pump out from 1720'to 1177'. TIH, bridge ~ 1383' Attempt to work thru bridge w/no success. UPCOMING OPERATIONS:TOH FOR DRILLING ASSY, TIH & DRILL AHEAD. 05/05/99 (D8) MW: 10.1 VISC: 115 PV/YP: 39/48 APIWL: 4.8 TD: 4731' (1215) CIRC & COND FOR TRIP. MOTOR LOCKED UP SUPV:FRED HERBERT / RICK 0VERSTREET RIH w/hole opener. Ream and wash from 1380' to 1565' Drill from 3516'- 4731' UPCOMING OPERATIONS:DRILL AHEAD. 05/06/99 (Dg) MW: 10.1 VISC: 137 PV/YP: 37/48 APIWL: 4.8 TD: 4731'( 0) DRILLING AHEAD ~ 5543' SUPV:FRED HERBERT / RICK 0VERSTREET Drilling from 4731' to 5508' Mud motor locked up. Circ and condition. POOH, tight ~ 4549' Hard reaming from 4255'-4220'. CBU. POOH. RIH w/bit #4. UPCOMING OPERATIONS:DRILLING AHEAD. Date: 6/28/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 05/07/99 D10) MW: 10.1 VISC: 122 PV/YP: 38/48 APIWL: 4.8 TD: 7167' 2436) MONITOR WELL, WIPER TRIP SUPV:FRED HERBERT / RICK OVERSTREET RIH, bridge @ 4777' Wash & ream from 4777' to bttm. Drilling 12.25" hole from 5508' to 6067' Bit balling or hard stringer work thru same. Drilling 12.25" hole from 6067' to 7167' UPCOMING OPERATIONS:WIPER TRIP, DRILL AHEAD 05/08/99 Dll) MW: 10.0 VISC: 118 PV/YP: 34/46 APIWL: 4.8 TD: 8420' 1253) DRILLED TO TD - 8910' TVD = 4579' SUPV:FRED HERBERT / RICK OVERSTREET Drilling from 7167' to 8420' UPCOMING OPERATIONS:CIRCULATE & CONDITION HOLE. POH, RUN HOLE OPENER. 05/09/99 D12) MW: 10.1 VISC: 115 PV/YP: 35/42 APIWL: 5.0 TD: 8910' 490) CIRCULATING AND CONDITIONING HOLE FOR TRIP OUT. SUPV:FRED HERBERT / RICK OVERSTREET Drill from 8420' to 8910'. Circulate and condition for trip. TOOH, tight spot, ream thru from 818' to 548' RIH w/hole opener. UPCOMING OPERATIONS:POOH W/HOLE OPENER AND RUN 9-5/8" CASING. 05/10/99 (D13) MW: 10.0 VISC: 111 PV/YP: 37/ 0 APIWL: 5.0 TD: 8910' ( 0) RUNNING 9-5/8" CASING. SUPV:FRED HERBERT / RICK OVERSTREET Run 9-5/8" casing, worked through tight spot ~ 1935' to 1940' UPCOMING OPERATIONS:FINISH RUNNING 9-5/8" CASING AND CEMENT. 05/11/99 (D14) MW: 10.0 VISC: 56 PV/YP: 23/25 TD: 8910' ( 0) NU BOPE SUPV:FRED HERBERT / SCOTT REYNOLDS Run 9-5/8" casing to 8893' Pump cement. UPCOMING OPERATIONS:TEST BOPE, MU BHA. APIWL: 5.8 05/12/99 (D15) MW: 8.5 VISC: 40 PV/YP: 9/10 APIWL: 9.4 TD: 8910'( 0) CHANGE OUT MUD FOR LOT SUPV:FRED HERBERT / SCOTT REYNOLDS ND diverter. NU BOPE and test to 300/3000 psi. Wash from 8370' to 8465' UPCOMING OPERATIONS:LOT, DRILL AHEAD Date: 6/28/99 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 4 05/13/99 (D16) MW: 9.1 VISC: 44 PV/YP: 14/17 APIWL: 6.2 TD:10740' (1830) WIPER TRIP SUPV:FRED HERBERT / SCOTT REYNOLDS Wash down from 8465'-8760'. Drill from 8760'-8767' Drill cement from 8767'-8812', drill float collar, drill cement from 8814' to 8890', drill float shoe, clean rat hole from 8892' to 8910', drill 20' new hole to 8930'. FIT to 14 ppg EMW. Drill from 8930' to 10740' UPCOMING OPERATIONS:DRILL AHEAD 05/14/99 (D17) MW: 9.1 VISC: 45 PV/YP: 13/16 APIWL: 5.2 TD:12022' (1282) DRILLING AHEAD, DEPTH ~ 0600 HRS, 12400' SUPV:FRED HERBERT / SCOTT REYNOLDS Drilling 8.5" hole from 10740' to 10993'. POOH to shoe, swabbing. Pump out from 9870' to 9580' Circ hi density, barofiber sweep around. Lots of sand & fractured shale on bttms up. Drilling 8.5" hole from 10740' to 12022' UPCOMING OPERATIONS:DRILLLING, OPEN HOLE LOT 05/15/99 D18) MW: 9.2 VISC: 47 PV/YP: 16/17 APIWL: 4.6 TD:13050' 1028) TRIP OUT TO PICK UP NUKE TOOLS SUPV:FRED HERBERT / SCOTT REYNOLDS Short trip from 12022' to 10900' Hole not taking proper fill. Pump and ream out from 11650'-11090' Circulate around hi-dens baro-fiber sweep. Fractured shale & good load of sand returned. Drill from 12022' to 13050'. Pump hi-dens Baro-fiber sweep and CBU once. Monitor well, static. Hole not taking proper fill, hole swabbing. Pump and ream out of hole from 12678' to 11740'. Perform LOT, 12.3 ppg EMW. UPCOMING OPERATIONS:RIH, DRILL TO TD, RUN 7" CSG. 05/16/99 D19) TD:13050' 0) SUPV:SCOTT REYNOLDS MW: 10.7 VISC: 48 PV/YP: 20/21 APIWL: 4.6 DRILLLING AHEAD @ 13397' MD, 6473' TVD. K1 MARKER ~ 13230' Monitor well, static. RIH to 13050'. Circulate while bringing mud weight up to 10.7 ppg. UPCOMING OPERATIONS:DRILL TO TD, SHORT TRIP TO SHOE. 05/17/99 (D20) TD:13975'(925) SUPV:SCOTT REYNOLDS MW: 10.7 VISC: 50 PV/YP: 22/24 POOH TO RUN CASING APIWL: 3.8 Weight mud up to 10.7 ppg. Drill from 13050' to 13975' circulate hi-den barofiber sweep and 2 BU circulations. Observe well, static. Hole took proper fill. UPCOMING OPERATIONS:DOWNLOAD MWD, RU GBR, CHANGE UP RAMS TO 7", RUN 7" CSG. Date: 6/28/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 05/18/99 (D21) TD:13975'( 0) SUPV:R.W. SPRINGER MW: 10.8 VISC: 57 PV/YP: 26/31 RUNNING 7" CASING APIWL: 4.0 Pump fiber sweep. PJSM. Install test plug. Test rams. PJSM. Run 7" casing. UPCOMING OPERATIONS:RUN CASING, CEMENT, WIRELINE GUAGE RING 05/19/99 (D22) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD:13975' ( 0) REINSTALL VBR RAMS, RIGGING UP HALLIBURTON SLICKLINE F/GUAGE SUPV:- R.W. SPRINGER Continue to run 7" casing. Hit bridge @ 13200' Circulate open hole volume while working casing, wash thru bridge. Run 7" casing to TD @ 13960'. Pump cement. UPCOMING OPERATIONS:RUN COMPLETION 05/20/99 (D23) TD:13975'( 0) SUPV:R.W. SPRINGER MW: 0.0 VISC: 0 PV/YP: 0/ 0 DISPLACING TO CLEAN SEAWATER APIWL: 0.0 Observe well ~ annulus, flowing back - 1" stream slowly declining. Set packoffs, install tbg hanger and test to 3000 psi. PJSM. Run completion assy and 3.5" tubing. UPCOMING OPERATIONS:FINISH COMPLETING, RELEASE RIG & MOVE TO 1C-27 05/21/99 (D24) TD:13975'( 0) SUPV:R.W. SPRINGER MW: 8.5 VISC: MOVED TO 1C-27 0 PV/YP: 0/ 0 APIWL: 0.0 Run 3.5" tbg. Set pkr. Freeze protect tubing. ND BOPE. NU tree and test to 5000 psi. Release rig ~ 2100 hrs. 5/21/99. UPCOMING 0PERATIONS:MIX MUD & SPUD ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT '~, K1(1C-23(W4-6)) WELL JOB SCOPE JOB NUM'BER " 1 C-23 DRILLING SUPPORT-CAPITAL 0518991702.9 DATE DAILY WORK UNIT NUMBER 06/05/99 PERFORATE 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 NOI NO SWS-ELMORE SCHUDEL FIELD AFC# CC# Signed ESTIMATE 999320 230DS10CG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 250 PSI 800 PSI 1000 PSI 1000 PSII 0 PSII 0 PSI DAILY SUMMARY RAN JWELRY LOG & PERFORATED 13577'-13587', 4 SPH, 180 PHASED ,+/- 90 LSH. I TIME LOG ENTRY 11:30 MIRU SWS 2128 ELMORE. TGSM. PT 3000#. 12:50 RIH W/SWIVEL,WTBAR,12" X 1.9" ROLLER,WTBAR,CCL-GR(CPLT). OAL=28.2'. 14:14 14:20 CHECK UP WEIGHT AT 13200' (1200#). CONTINUE RIH. LU TIE IN PASS FROM TD-13300'. TAGGED AT 13866'. POOH 15:25 AT SURFACE, RU GUN 1. 15:45 RIH W/GUN 1. SWIVEL,WTBAR, ROLLER,CCL, MPD,10' X 2.5" HSD 4SPF, 180 PHASED, +/- 90 DEG ORIENTATION FLSH, OAL=31'. 17:10 LU, CHECK TI AT SHORT JTS. 17:25 BLED TBG TO 100 PSi AS PER PROCEDURE. PERFED 13577-13587'. PRESSURE INCREASED TO 600# AFTER FIRING. RAN UP & DOWN HOLE IN 7" LINER TO REMOVE ANY BURRS FROM GUN BEFORE POOH. 18:30 AT SURFACE, RD FOR THE NIGHT. CONTINUE JOB TOMORROW. 19:30 RDMO. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT ,, K1(1C-23(W4-6)) WELL JOB SCOPE JOB NUMBER 1 C-23 DRILLING SUPPORT-CAPITAL 0518991702.9 DATE DAILY WORK UNIT NUMBER 06/06/99 PERFORATE 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 6 YES YES SWS-ELMORE SCHUDEL FIELD AFC# CC# Signed ESTI MATE 999320 230 DS 10CG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 800 PSI 800 PSI 750 PSI 750 PSII 500 PSII 500 PSI DAILY SUMMARY IPERFORATED REMAINING 40' OF ZONE, 13537'-13577'. PERFS COMPLETE. 2.5" HSD, 4 SPF, 180 PHASED, ORIENTED +/- 90 BEG LSH.[Perf] LOG ENTRY TIME 08:00 MIRU SWS 2128 ELMORE, TGSM, PT 3000#. STARTED LATE DUE'TO SAFETY IN MOTION CLASS. 09:30 RIH W/SWIVEL,2.125" X 12" ROLLER, CCL,MPD, 20'× 2.5" GUN, 4 SPF, 180 PHASED, ORIENTED +/- 90 FLSH. OAL= 35.1' 11:18 CHECK UP WEIGHT AT 13275 (1170#), TI TO JEWELRY (CORRECT 1'), RIH TO 13650. 11:30 ATTEMPT TO BD WHP, WELL PRESSURE RECOVERS VERY QUICKLY, SI WELL AND CONTINUE W/PERFING 13557'-13577'. WHP AT 900 PSI. 11:40 PUH TO PERF 13557'-13577'. GOOD SHOT INDICATION AT SURFACE, RUH & RIH IN CASING TO REMOVE BURRS BEFORE PUH THROUGH TBG TAIL. POOH. 13:00 RIH W/GUN 2, 20' X 2.5" HSD, 4 SPF, 180 PHASED, ORIENTED +/- 90 DEG FLSH. 14:15 TI AT SHORT JTS. RIH TO 13650'. 14:23 PU TO PERF 13537'-13557'. CYCLE UP/DOWN IN CASING TO REMOVE BURRS. POOH. 15:30 AT SURFACE, BD LUB BEGIN RD, RELEASE RADIO SILENCE. 16:30 RDMO. 09-Jun-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1C-23 ST1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 7,117.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 1999 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C, Slot 1C-23 1C-23 Job No. AKMM90114, Surveyed: 17 May, 1999 SURVEY REPORT ORIGINAL RECEIVED 9 June, 1999 ~ ' ' ,,:UN 1 7 1999 Alaska Oil & Gas Cons. Commission Your Ref: API-500292294200 And~orage Surface Coordinates: 5968578.72 N, 562283.96 E (70° 19' 28.8460' N, 149° 29' 41.8511" W) Kelly Bushing: 95.20ft above Mean Sea Level sper',r~-sur~ D R I L. L. I N I~ S E R V I C E S Survey Ref: svy8614 Prudhoe Bay Unit Measured Depth (ft) Incl. 1748.98 1832.oo 184o.66 1935.78 2029.69 2118.77 2213.54 2305.72 2399.79 2493.03 2586.23 2680.68 2774.51 2869.11 2962.42 3056.34 3148.83 3242.63 3335.97 3430.46 3526.09 3617.57 3712.17 3804.52 39Ol.36 51.530 55.576 56.000 59.830 62.710 63.220 63.97O 65.040 66,130 66.010 65.580 65.150 65.270 66.530 66.450 65.870 65.380 64.880 64.450 63.870 64.520 66.050 65.800 65.440 64.970 Azim. 80.440 82.488 82.690 84.71o 83.080 82.330 81.7oo 80.580 8o.o7o 78.320 79.220 79.390 79,680 81.99o 82.860 83.280 84.890 86.71o 86.840 87.33o 86.440 83.460 83.370 83.600 84.370 Sperry-Sun Drilling Services Survey Report for lC-23 Your Ref: API-500292294200 Job No. AKMM90114, Surveyed: 17 May, 1999 Sub-Sea Depth (ft) 1453.31 1502.63 1507.5o 1558.02 1603.16 1643.65 1685.79 1725.47 1764.35 1802.17 1840.39 1879.76 1919.10 1957.73 1994.95 2o32.91 2o71.09 2110.54 2150.48 2191.66 2233.29 2271.55 231o.14 2348.26 2388.87 Vertical Depth (ft) 1548.51 1597.83 1602.70 1653.22 1698.36 1738.85 1780.99 1820.67 1859.55 1897.37 1935.59 1974.96 2014.30 2052.93 2090.15 2128.11 2166.29 2205.74 2245.68 2286.86 2328.49 2366.75 2405.34 2443.46 2484.O7 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) 91.48 N 101.36 N 102.28 N 111.10 N 119.87 N 129.94 N 141.74 N 154.56 N 168.95 N 184.93 N 201.48 N 217.42 N 232.89 N 246.63 N 257.91 N 268.28 N 276.96 N 283.20 N 287.94 N 292.27 N 296.95 N 304.28 N 314.18 N 323.72 N 332.94 N 608.31 E 5968675.25 N 562891.49 E 674.34 E 5968685.67 N 562957.43 E 681.44 E 5968686.66 N 562964.53 E 761.53 E 5968696.13 N 563044.54 E 843.39 E 5968705.58 N 563126.33 E 922.10 E 5968716.31N 563204.95 E 1006.15 E 5968728.80 N 563288.90 E 1088.36 E 5968742.30 N 563371.00 E 1172.80 E 5968757.40 N 563455.32 E 1256.51 E 5968774.07 N 563538.89 E 1339.89 E 5968791.32 N 563622.13 E 1424.25 E 5968807.95 N 563706.35 E 1508.01E 5968824.12 N 563789.99 E 1593.26 E 5968838.57 N 563875.12 E 1678.08 E 5968850.55 N 563959.84 E 1763.35 E 5968861.62 N 564045.03 E 1847.15 E 5968871.00 N 564128.74 E 1932.01E 5968877.94 N 564213.56 E 2016.24 E 5968883.39 N 564297.74 E 2101.17 E 5968888.42 N 564382.64 E 2187.14 E 5968893.81 N 564468.56 E 2269.90 E 5968901.82 N 564551.26 E 2355.70 E 5968912.44 N 564636.97 E 2439.27 E 5968922.68 N 564720.46 E 2526.70 E 5968932.62 N 564807.81 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100ft) 5.262 5.262 4.410 3.424 0.943 0.990 1.597 1.259 1.720 0.994 0.484 0.308 2.597 0.859 0.741 1.672 1.839 0.478 0.771 1.079 3.399 0.278 0.451 0.870 Vertical Section (ft) Comment 614.94 681.68 688.84 769.40 851.73 931.o7 lO15.94 lO99.1o 1184.67 1269.71 1354.48 144o.16 1525.2o 1611.48 1697.o4 1782.95 1867.17 1952.16 2036.34 2121.16 2207.05 2290.08 2376.45 2460.56 2548.46 TIE-ON SURVEY WINDOW POINT Continued... 9 June, 1999 - 8:43 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-23 Your Ref: API-500292294200 Job No. AKMM90114, Surveyed: 17 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 3993.09 4085.56 4179.97 4273.16 4368.33 4462.22 4556.81 4650.48 4745.07 4837.20 4931.15 5024.43 5117.o7 521o.18 53o2.12 5396.97 5488.93 5583.40 5677.65 5770.18 5864.41 5955.49 6049.74 6143.58 6236.80 66.550 65.500 65.490 64.630 63.960 65.080 65.440 65.240 64.990 64.290 63.690 66.160 65.850 65.140 64.490 62.800 62.910 65.070 66.080 65.650 65.250 64.600 64.870 66.320 65.370 Azim. 83.19o 83.750 83.440 83.480 83.67o 83.520 83.470 83.290 83.250 82.330 83.540 84.54o 83.870 84.020 83.850 84.400 84.500 84.o7o 83.220 82.41o 82.750 82.970 82.880 82.230 82.12o Sub-Sea Depth (ft) 2426.53 2464.11 2503.26 2542.56 2583.84 2624.23 2663.81 2702.90 2742.70 2782.16 2823.36 2862.89 2900.56 2939.18 2978.31 3020.41 3062.37 3103.79 3142.77 3180.60 3219.75 3258.35 3298.58 3337.35 3375.50 Vertical Depth (ft) 2521.73 2559.31 2598.46 2637.76 2679.04 2719.43 2759.01 2798.10 2837.90 2877.36 2918.56 2958.09 2995.76 3034.38 3073.51 3115.61 3157.57 3198.99 3237.97 3275.80 3314.95 3353.55 3393.78 3432.55 3470.70 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (fi) (ft) (fi) 342.00 N 2609.85 E 5968942.37 N 564890.88 E 351.61 N 2693.79 E 5968952.68 N 564974.74 E 361.20 N 2779.16 E 5968962.97 N 565060.02 E 370.82 N 2863.11 E 5968973.29 N 565143.89 E 380.42 N 2948.32 E 5968983.60 N 565229.02 E 389.87 N 3032.55 E 5968993.75 N 565313.17 E 399.61 N 3117.90 E 5969004.19 N 565398.44 E 409.42 N 3202.46 E 5969014.71 N 565482.91 E 419.48 N 3287.68 E 5969025.47 N 565568.04 E 429.92 N 3370.27 E 5969036.60 N 565650.55 E 440.31 N 3454.06 E 5969047.68 N 565734.25 E 449.07 N 3538.09 E 5969057.14 N 565818.20 E 457.62 N 3622.29 E 5969066.39 N 565902.32 E 466.56 N 3706.54 E 5969076.02 N 565986.50 E 475.35 N 3789.27 E 5969085.50 N 566069.15 E 484.05 N 3873.81E 5969094.90 N 566153.62 E 491.96 N 3955.26 E 5969103.49 N 566235.00 E 500.42 N 4039.73 E 5969112.65 N 566319.40 E 509.92 N 4125.02 E 5969122.86 N 566404.60 E 520.48 N 4208.80 E 5969134.12 N 566488.29 E 531.55 N 4293.79 E 5969145.89 N 566573.19 E 541.80 N 4375.64 E 5969156.82 N 566654.96 E 552.30 N 4460.23 E 5969168.02 N 566739.45 E 563.38 N 4544.96 E 5969179.80 N 566824.09 E 574.96 N 4629.23 E 5969192.08 N 566908.25 E Alaska State Plane Zone 4 Kuparuk lC Dogleg Vertical Rate Section (°/100fi) (ft) Comment 2.084 2632.09 1.263 2716.58 0.299 2802.48 0.924 2886.97 0.727 2972.72 1.202 3057.47 0.384 3143.37 0.276 3228.50 0.267 3314.31 1.180 3397.56 1.322 3481.99 2.820 3566.45 0.741 3651.07 0.777 3735.78 0.727 3818.96 1.856 3903.93 0.154 3985.74 2.323 4070.61 1.350 4156.42 0.924 4240.86 0.537 4326.57 0.746 4409.06 0.299 4494.29 1.669 4579.75 1.025 4664.79 Continued... 9 June, 1999 - 8:43 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-23 Your Ref: API-500292294200 Job No. AKMM90114, Surveyed: 17 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6331.18 65.240 82.800 3414.93 3510.13 6425.96 65.760 82.720 3454.23 3549.43 6519.42 64.960 82.900 3493.20 3588.40 6614.74 64.470 83.250 3533.91 3629.11 6709.49 64.990 83.530 3574.36 3669.56 6803.16 65.120 82.880 3613.86 3709.06 6897.64 65.310 82.190 3653.47 3748.67 6990.69 64.410 81.260 3693.00 3788.20 7086.72 64.820 81.900 3734.17 3829.37 7181.93 64.720 81.860 3774.75 3869.95 7275.55 65.180 81.860 3814.39 3909.59 7368.01 66.420 81.480 3852.30 3947.50 7462.29 65.890 81.710 3890.41 3985.61 7557.41 64.930 82.170 3929.99 4025.19 7652.38 65.490 83.010 3969.81 4065.01 7745.80 67.040 83.260 4007.41' 4102.61 7838.59 66.680 83.280 4043.88 4139.08 7931.78 65.590 83.680 4081.58 4176.78 8025.16 65.880 82.870 4119.96 4215.16 8119.60 66.320 82.690 4158.22 4253.42 8213.81 65.890 82.670 4196.38 4291.58 8307.77 65.240 82.490 4235.24 4330.44 8400.40 65.260 82.140 4274.03 4369.23 8493.85 66.120 81.010 4312.50 4407.70 8587.77 65.440 81.040 4351.03 4446.23 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 586.21 N 4714.23 E 5969204.04 N 566993.16 E 597.08 N 4799.79 E 5969215.62 N 567078.63 E 607.71 N 4884.07 E 5969226.95 N 567162.82 E 618.10 N 4969.63 E 5969238.05 N 567248.29 E 627.97 N 5054,74 E 5969248.62 N 567333.32 E 638.02 N 5139.08 E 5969259.37 N 567417.57 E 649.16 N 5224.13 E 5969271.22 N 567502.52 E 661.28 N 5307.48 E 5969284.03 N 567585.77 E 673.98 N 5393.31 E 5969297.44 N 567671.49 E 686.15 N 5478.57 E 5969310.32 N 567756.65 E 698.16 N 5562.53 E 5969323.02 N 567840.50 E 710.38 N 5645.97 E 5969335.93 N 567923.84 E 722.98 N 5731.28 E 5969349.25 N 568009.04 E 735.11 N 5816,92 E 5969362.08 N 568094.57 E 746.23 N 5902.41 E 5969373.91 N 568179.98 E 756.45 N 5987.32 E 5969384.84 N 568264.79 E 766.45 N 6072.05 E 5969395.54 N 568349.44 E 776.13 N 6156.72 E 5969405.92 N 568434.03 E 786.10 N 6241.27 E 5969416.59 N 568518.49 E 796.95 N 6326.92 E 5969428.15 N 568604.05 E 807.92 N 6412,36 E 5969439.84 N 568689.39 E 818.97 N 6497.18 E 5969451.59 N 568774.12 E 830.22 N 6580.55 E 5969463.53 N 568857.39 E 842.70 N 6664.79 E 5969476.71 N 568941.53 E 856.06 N 6749.39 E 5969490.77 N 569026.02 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 0.669 4750.54 0,554 4836.78 0.874 4921.73 0.612 5007.92 0.610 5093.60 0.644 5178.53 0.693 5264.30 1,324 5348.52 0.738 5435.25 0.112 5521.36 0.491 5606.16 1.393 5690.47 0.605 5776.68 1.101 5863.16 0.996 5949.38 1.677 6034.89 0.388 6120,21 1.234 6205.43 0,850 6290,56 0.497 6376.90 0.457 6463.03 0.713 6548.58 0.344 6632.69 1.436 6717.83 0.725 6803.43 Continued... 9 June, 1999 - 8:43 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-23 Your Ref: API-500292294200 Job No. AKMM90114, Surveyed: 17 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 8680.14 8774.77 8828.20 8952.28 9046.38 9137.58 9233.45 9327.48 9422.37 9514.18 9610.41 9702.81 9798.45 9888.84 9985.90 10081.58 10174.65 10267.81 10362.53 10457.25 10552.40 10646.15 10741.76 10832.08 10926.31 65.710 65.820 65.400 65.000 66.350 67.140 64.340 63.360 63.510 65.690 66.930 66.030 66.040 66.270 65.380 64.700 65.020 65.500 64.860 66.710 66.550 65.800 65.230 65.000 64.560 Azim. 80.710 80.500 80.700 80.620 83.050 84.380 85.190 86.730 85.330 83.030 82.930 83.400 82.610 82.840 82.370 81.500 83.090 83.350 83.680 82.350 83.190 82.380 81.200 81.930 81.850 Sub-Sea Depth (ft) 4389.22 4428.07 4450.13 4502.17 4540.94 4576.95 4616.34 4657.78 4700.22 4739.60 4778.26 4815.14 4853.98 4890.52 4930.27 4970.65 5010.19 5049,18 5088.94 5127.79 5165.53 5203.40 5243.03 5281.04 5321.19 Vertical Depth (ft) 4484.42 4523.27 4545.33 4597.37 4636.14 4672.15 4711.54 4752.98 4795.42 4834.80 4873.46 4910.34 4949.18 4985.72 5025.47 5065.85 5105.39 5144.38 5184.14 5222.99 5260.73 5298.60 5338,23 5376.24 5416.39 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 869.40 N 6832.43 E 5969504.80 N 569108.94 E 883.48 N 6917.57 E 5969519.59 N 569193.95 E 891.43 N 6965.57 E 5969527.94 N 569241.89 E 909.71N 7076.72 E 5969547.14 N 569352.88 E 921.88 N 7161.58 E 5969560.01N 569437.65 E 931.05 N 7244.87 E 5969569.87 N 569520.85 E 939.00 N 7331.90 E 5969578.54 N 569607.81 E 944.95 N 7416.09 E 5969585.19 N 569691.95 E 950.83 N 7500.76 E 5969591.77 N 569776.57 E 959.25 N 7583.25 E 5969600.88 N 569858.99 E 970.02 N 7670.71 E 5969612.37 N 569946.35 E 980.10 N 7754.83 E 5969623.16 N 570030.39 E 990,75 N 7841.57 E 5969634.52 N 570117.04 E 1001.22 N 7923.58 E 5969645.67 N 570198.96 E 1012.61N 8011.39 E 5969657.79 N 570286.67 E 1024.78 N 8097.28 E 5969670.67 N 570372.45 E 1036.07 N 8180.77 E 5969682.66 N 570455.85 E 1046.06 N 8264.78 E 5969693.34 N 570539.78 E 1055.77 N 8350.20 E 5969703.76 N 570625.11 E 1066.28 N 8435.94 E 5969714.99 N 570710.76 E 1077.28 N 8522.59 E 5969726.70 N 570797.31 E 1088.05 N 8607.67 E 5969738.17 N 570882.30 E 1100.47 N 8693.79 E 5969751.31 N 570968.32 E 1112.49 N 8774.84 E 5969764.00 N 571049.26 E 1124.51 N 8859.23 E 5969776.73 N 571133.55 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOff) (ft) Comment 0.437 6887.48 0.233 6973.70 0.857 7022.32 0.328 7134.87 2.756 7220.59 1.595 7304.37 3.020 7391,72 1.802 7476.00 1.329 7560.75 3.280 7643.65 1.292 7731.77 1.080 7816.49 0,755 7903.89 0.345 7986.56 1.018 8075.10 1.088 8161.83 1.584 8246.08 0.574 8330.69 0.746 8416.65 2.335 8503.03 0.828 8590.37 1.125 8676.13 1.272 8763.12 0.776 8845.03 0.473 8930.27 Continued... 9 June, 1999 - 8:43 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-23 Your Ref: API-500292294200 Job No. AKMM90114, Surveyed: 17 May, 1999 Prudhoe Bay Unit Measured Depth (ft) 11021.32 11115.33 11208.66 11301.55 11393.62 11486.67 11580.81 11673.38 11767.55 11859.67 11953.68 12046.41 12140.62 12235.96 12327.96 12421.15 12514.43 12609.60 12701.82 12793.60 12889.53 12981.58 13076.62 13171.20 13264.81 66.130 65.73O 65.090 64.060 65.060 64.650 63.510 63.250 65.890 65.980 65.340 65.340 64.810 64.290 63.860 63.470 64.580 65.270 64.520 63.930 63.270 64.060 64.190 66.100 65.600 Azim. 83.380 82.550 82.13o 82.690 84.490 84.590 84.240 85.090 85.15o 85.520 85.540 84.280 85.260 85.390 84.560 84.720 82.970 81.49o 80.940 80.85o 80.300 81.63o 82.970 83.13o 83.77o Sub-Sea Depth (ft) 5360.82 5399.16 5438.00 5477.88 5517.43 5556.97 5598.12 5639.60 5680.03 5717.60 5756.34 5795.03 5834.74 5875.71 5915.93 5957.27 5998.13 6038.46 6077.59 6117.50 6160.15 6200.99 6242.47 6282.22 6320.52 Vertical Depth (ft) 5456.02 5494.36 5533.20 5573.08 5612.63 5652.17 5693.32 5734.80 5775.23 5812.80 5851.54 5890.23 5929.94 5970.91 6011.13 6052.47 6093.33 6133.66 6172.79 6212.70 6255.35 6296.19 6337.67 6377.42 6415.72 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1135.61 N 8944.86 E 5969788.53 N 571219.08 E 1146.12 N 9030.05 E 5969799.75 N 571304.18 E 1157.43 N 9114.15 E 5969811.76 N 571388.19 E 1168.51 N 9197.31 E 5969823.53 N 571471.25 E 1177.79 N 9279.93 E 5969833.49 N 571553.79 E 1185.80 N 9363.78 E 5969842.20 N 571637.57 E 1194.04 N 9448.04 E 5969851.14 N 571721.77 E 1201.74 N 9530.44 E 5969859.52 N 571804.10 E 1208.97 N 9615.17 E 5969867.45 N 571888.77 E 1215.81 N 9699.01 E 5969874.99 N 571972.54 E 1222.49 N 9784.40 E 5969882.37 N 572057.88 E 1229.96 N 9868.34 E 5969890.55 N 572141.75 E 1237.75 N 9953.42 E 5969899.04 N 572226.76 E 1244.77 N 10039.22 E 5969906.77 N 572312.50 E 1252.01 N 10121.64 E 5969914.70 N 572394.86 E 1259.82 N 10204.79 E 5969923.19 N 572477.95 E 1268.81 N 10288.16 E 5969932.88 N 572561.23 E 1280.47 N 10373.57 E 5969945.25 N 572646.54 E 1293.22 N 10456.09 E 5969958.68 N 572728.96 E 1306.30 N 10537.70 E 5969972.44 N 572810.45 E 1320.37 N 10622.46 E 5969987.21 N 572895.10 E 1333.32 N 10703.94 E 5970000.84 N 572976.46 E 1344.78 N 10788.67 E 5970013.00 N 573061.10 E 1355.16 N 10873.86 E 5970024.09 N 573146.20 E 1364.91N 10958.72 E 5970034.54 N 573230.97 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 2.207 9016.61 0.912 9102.44 0.799 9187.30 1.235 9271.19 2.073 9354.32 0.451 9438.52 1.256 9523.16 0.868 9605.88 2.804 9690.86 0.380 9774.90 0.681 9860.47 1.235 9944.69 1.098 10030.08 0.559 10116.09 0.936 10198.78 0.446 10282.26 2.064 10366.10 1.584 10452.29 0.976 10535.76 0.649 10618.36 0,859 10704.21 1.553 10786.65 1.276 10872.16 2.025 10957.97 0.821 11043.39 Continued... 9 June, 1999 - 8:43 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-23 Your Ref: API-500292294200 Job No. AKMM90114, Surveyed: 17 May, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13358.95 65.420 84.280 6359.54 6454.74 1373.82 N 11043.92 E 5970044.16 N 573316.10 E 13452.22 65.050 83.740 6398.61 6493.81 1382.66 N 11128.15 E 5970053.70 N 573400.25 E 13544.46 64,830 83.500 6437.68 6532.88 1391.95 N 11211.19 E 5970063.67 N 573483.21 E 13639,55 64.620 83.490 6478,28 6573.48 1401.69 N 11296.62 E 5970074.12 N 573568.56 E 13734.38 64.680 83.720 6518.88 6614,08 1411,23 N 11381.79 E 5970084.37 N 573653.64 E 13827.97 64,350 84.260 6559.15 6654.35 1420.08 N 11465.81 E 5970093.92 N 573737.59 E 13888.27 64.260 83.930 6585.30 6680.50 1425.67 N 11519.86 E 5970099.95 N 573791.59 E 13975.00 64.260 83.930 6622.96 6718.16 1433.93 N 11597.54 E 5970108.86 N 573869.20 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.529 0.659 0.335 0.221 0.228 0.629 0.515 0.000 11129.04 11213.72 11297.27 11383.25 11468.94 11553.41 11607.74 11685.85 PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 82.952° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13975.00ft., The Bottom Hole Displacement is 11685.85ft., in the Direction of 82.952° (True). Continued... 9 June, 1999 - 8:43 - 7- DrillQuest Sperry-Sun Drilling Services Survey Report for lC-23 Your Ref: API-500292294200 Job No. AKMM90114, Surveyed: 17 May, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C Comments Measured Depth (fi) 1748.98 1832.00 13975.OO Station Coordinates TVD Northings Eastings (~) (~) (~) 1548.51 91.48 N 608.31E 1597.83 101.36 N 674.34 E 6718.16 1433.93 N 11597.54 E Comment TIE-ON SURVEY WINDOW POINT PROJECTED SURVEY 9 June, 1999 - 8:43 - 8 - DrillQuest 09-Jun-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1C-23 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 1,748.98' MD 1,832.00' MD 13,975.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, "¢ RECE VED JUN 1 7 1999 William T. Allen Survey Manager Oil & Gas Cons, Commission Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C, Slot 1C-23 1C-23 ST1 Job No. AKMM9014, Surveyed: 3 May, 1999 SURVEY REPORT 9 June, 1999 Your Reft A P1-500292294170 ORIGINAL RECEIVED JUN 17 1999 Alaska Oil & Gas Cons. Commission A~h0rage Surface Coordinates: 5968578.72 N, 562283.96 E (70° 19' 28.8460" N, 149° 29' 41.8511" W) Kelly Bushing: 95.20fl above Mean Sea Level D R I L L, I N Q S lB R V I C: lil 5 Survey Ref: svy8612 A HAI,I,IBI~R'I'~iN CO~.IPA~rY Sperry-Sun Drilling Services Survey Report for 1C-23 ST1 Your Ref: API-500292294170 Job No, AKMM9014, Surveyed: 3 May, 1999 Prudhoe Bay Unit Measured Depth (ft) 0.00 159,17 191.39 284.16 373,42 463.79 552.07 641.61 725.50 813.74 908.00 991.95 1091.12 1 185.54 1276.48 1372.47 1462.99 1562.13 1655.60 1748.98 1844.20 1936.90 2026,64 2120.57 2214.39 Incl. o.ooo 0.620 0.300 0.850 3.o7o 5.530 6.6oo 9.830 14.470 18.33o 20.270 24.330 29.40o 34.140 37.21o 39.970 43.81o 47.550 49.590 51.530 57.490 60.450 65.650 64.71o 64.13o Azim. o.ooo 147.66o 168.98o 23.770 49.7oo 41.49o 70.89o 85.750 9o.27o 87.320 87.36o 87.61o 82.460 80.080 81.28o 81.23o 80.660 81.11o 79.820 80.440 83.330 82.540 83.19o 82.260 82.16o Sub-Sea Depth (ft) -95.20 63.97 96.19 188.95 278.16 368.27 456.07 544.69 626.68 711.32 800.27 877.93 966.38 1046.63 1120.50 1195.52 1262.89 1332.15 1394.00 1453.31 1508.58 1556.36 1597.02 1636.45 1676.95 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (fi) (ft) 0.00 0.00 N 0.00 E 159.17 0.73 S 0.46 E 191.39 0.96 S 0.57 E 284.15 0.57 S 0.89 E 373.36 1.59 N 2.98 E 463.47 6.41 N 7.72 E 551.27 11.26 N 15.33 E 639.89 13.51 N 27.82 E 721.88 14.00 N 45.45 E 806.52 14.59 N 70.34 E 895.47 16.04 N 101.46 E 973.13 17.43 N 133.28 E 1061.58 21.48 N 177.86 E 1141.83 29.09 N 226.96 E 1215.70 37.66 N 279.29 E 1290.72 46.76 N 338.46 E 1358.09 56.28 N 398.14 E 1427.35 67.51 N 468.16 E 1489.20 79.13 N 537.26 E 1548.51 91.48 N 608.31 E 1603.78 102.35 N 685.03 E 1651.56 112.12 N 763.85 E 1692.22 122.05 N 843.19 E 1731.65 132.84 N 927.76 E 1772.15 144.31 N 1011.60 E 5968578.72 N 562283,96 E 5968578.00 N 562284,43 E 5968577.77 N 562284,54 E 5968578.16 N 562284.86 E 5968580.33 N 562286.93 E 5968585.20 N 562291.62 E 5968590.11N 562299.19 E 5968592.46 N 562311.66 E 5968593.09 N 562329.29 E 5968593.90 N 562354.18 E 5968595.60 N 562385.29 E 5968597.25 N 562417.09 E 5968601.67 N 562461.63 E 5968609.69 N 562510.67 E 5968618.69 N 562562.93 E 5968628.29 N 562622.02 E 5968638.30 N 562681.62 E 5968650.11 N 562751.54 E 5968662.30 N 562820.55 E 5968675.25 N 562891.49 E 5968686.75 N 562968.11 E 5968697.18 N 563046.85 E 5968707.76 N 563126.11E 5968719.25 N 563210.59 E 5968731.42 N 563294.33 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.390 0.36 1.110 0.44 1.196 0.81 2.616 3.16 2.799 8.47 3.673 16.63 4.288 29.31 5.642 46.86 4.474 71.63 2.058 102.68 4.838 134.42 5.621 179.15 5.192 228.82 3.462 281.81 2.875 341.66 4.263 402.06 3.786 472.94 2.415 542.96 2.140 615.00 6.728 692.47 3.275 771.90 5.830 851.86 1.345 937.12 0.626 1021.74 Continued... 9 June, 1999 - 8:39 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-23 ST1 Your Ref: API-500292294170 Job No. AKMM9014, Surveyed: 3 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 2308.23 2400.56 2493.68 2588.09 2681.93 2775.66 2873.35 2962.92 3059.68 3152.79 3246.58 3337.95 3435.71 3523.93 3616.33 3715,71 3807.29 3898.11 3993.35 4084.79 4179.18 4271.99 4369.79 4464.45 4558.34 64.660 65.330 65.040 65.650 65.640 65.120 65.090 65.380 64.950 64.960 65.540 64.860 65.080 65.470 65.080 64.890 66.020 66.060 65.680 65.590 65.720 64.700 65.150 66.540 65.850 Azim. 82.090 82.070 81.19o 82.090 8o.710 81.440 81.8oo 81.72o 81.070 80.730 80.570 82.120 81.94o 81.190 80.520 78.750 79.060 80.610 82.230 82,890 83.140 83.530 85,620 86.020 85.880 Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 1717.51 1756.54 1795,62 1835.00 1873.70 1912.75 1953.87 1991.39 2032.03 2071.45 2110.72 2149.04 2190.40 2227.30 2265.95 2307.98 2346.02 2382.90 2421.84 2459.57 2498.48 2537.39 2578.84 2617.58 2655.47 1812.71 155.90 N 1095.43 E 1851.74 167.43 N 1178.31 E 1890.82 179.74 N 1261.93 E 1930.20 192.21N 1346.82 E 1968.90 204.99 N 1431.34 E 2007.95 218.21 N 1515.52 E 2049.07 231.13 N 1603.18 E 2086.59 242.78 N 1683.68 E 2127.23 255.92 N 1770.50 E 2166.65 269.26 N 1853.79 E 2205.92 283.10 N 1937.84 E 2244.24 295.58 N 2019.83 E 2285.60 307.87 N 2107.55 E 2322.50 319.62 N 2186.82 E 2361.15 332.96 N 2269.68 E 2403.18 349.16 N 2358.26 E 2441.22 365.19 N 2440.01E 2478.10 379.84 N 2521.70 E 2517.04 392.81 N 2607.64 E 2554.77 403.59 N 2690.23 E 2593.68 414.05 N 2775.59 E 2632.59 423.83 N 2859.28 E 2674.04 432.20 N 2947.46 E 2712.78 438.49 N 3033.60 E 2750.67 444.56 N 3119.29 E Global Coordinates Northings Eastings (ft) (fi) 5968743.71 N 563378.06 E 5968755.93 N 563460.84 E 5968768.92 N 563544.35 E 5968782.10 N 563629.14 E 5968795.59 N 563713.55 E 5968809.50 N 563797.61E 5968823.15 N 563885.17 E 5968835.47 N 563965.56 E 5968849.33 N 564052.27 E 5968863.36 N 564135.45 E 5968877.89 N 564219.38 E 5968891.06 N 564301.27 E 5968904.07 N 564388.89 E 5968916.48 N 564468.05 E 5968930.51N 564550.80 E 5968947.44 N 564639.25 E 5968964.15 N 564720.86 E 5968979.47 N 564802.42 E 5968993.16 N 564888.25 E 5969004.63 N 564970.75 E 5969015,79 N 565056.02 E 5969026.27 N 565139.62 E 5969035.37 N 565227.73 E 5969042.38 N 565313.81 E 5969049.16 N 565399.45 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.569 1106.36 0.726 1190.03 0.913 1274.53 1.081 1360.32 1.340 1445.78 0.899 1530.95 0.336 1619.55 0.334 1700.87 0.754 1788.66 0.331 1872.97 0.638 1958.09 1.710 2041.01 0.280 2129.58 0.890 2209.69 0.782 2293.58 1.625 2383.50 1.272 2466.62 1.560 2549.51 1.603 2636.40 0.665 2719.69 0.278 2805.69 1.163 2889.94 1.990 2978.47 1.518 3064.71 0.747 3150.48 Continued... 9 June, 1999 - 8:39 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-23 ST1 Your Ref: A PI-500292294170 Job No. AKMM9014, Surveyed: 3 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 4651,15 4745.69 4838.65 4935,55 5023,39 5118.68 5208,14 53oo.71 5396.26 5488.07 5585.76 5676.96 5772.60 5868.85 5960.11 6054.66 6143.48 6246.46 6335.07 6430.78 6528.50 6618.Ol 6707.83 6803.65 6895.99 65.710 66.1 O0 66.410 66.830 66.64O 66.190 65.960 65.240 63.690 64.050 63.700 63.690 65.480 65.350 64.600 64.090 63.610 64.500 65.780 66.080 66.000 65.520 65.650 66.450 66.190 Azim. 86.710 86.270 85.210 84.540 84.88O 84.650 84.550 83.770 82.570 81.200 80.670 80,060 82.740 83.600 84.000 84.580 84.990 86.030 84.980 84.730 83.340 84.060 83.980 82.230 83.740 Sub-Sea Depth (ft) 2693.55 2732.14 2769.58 2808.03 2842.73 2880.85 2917.13 2955.37 2996.56 3O37.O0 3080.01 3120.43 3161.48 3201.52 3240.13 3281.06 3320.21 3365.26 3402.51 3441.55 3481.24 3517.99 3555.11 3594.01 3631.10 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) (ft) 2788.75 2827.34 2864.78 2903.23 2937.93 2976.05 3012.33 3050.57 3091.76 3132.20 3175.21 3215.63 3256.68 3296.72 3335.33 3376.26 3415.41 3460,46 3497.71 3536.75 3576.44 3613.19 3650.31 3689.21 3726.30 450.03 N 3203.75 E 455.32 N 3289.89 E 461.64 N 3374.74 E 469.58 N 3463.33 E 477.02 N 3543.68 E 484.99 N 3630.65 E 492.69 N 3712.06 E 501.26 N 3795.92 E 511.51N 3881.52 E 523.15 N 3963.12 E 536.96 N 4049.73 E 550.65 N 4130.34 E 563.55 N 4215.74 E 573.96 N 4302.64 E 582.89 N 4384.85 E 591.37 N 4469.65 E 598.62 N 4549.05 E 605.86 N 4641.37 E 612.17 N 4721.51E 620.00 N 4808.55 E 629.28 N 4897.36 E 638,24 N 4978.49 E 646.76 N 5059.83 E 657.28 N 5146.76 E 667.61 N 5230.69 E 5969055.33 N 565483.86 E 5969061.33 N 565569.96 E 5969068.35 N 565654.75 E 5969077.03 N 565743.27 E 5969085.14 N 565823.56 E 5969093.83 N 565910.46 E 5969102.20 N 565991.80 E 5969111.47 N 566075.59 E 5969122.43 N 566161.10 E 5969134.74 N 566242.60 E 5969149.28 N 566329.10 E 5969163.63 N 566409.58 E 5969177.24 N 566494.88 E 5969188.37 N 566581.69 E 5969197.98 N 566663.82 E 5969207.17 N 566748.55 E 5969215.07 N 566827.89 E 5969223.08 N 566920.14 E 5969230.05 N 567000.23 E 5969238.61 N 567087.20 E 5969248.63 N 567175.93 E 5969258.26 N 567256.98 E 5969267.46 N 567338.25 E 5969278.69 N 567425.09 E 5969289.72 N 567508.93 E Alaska State Plane Zone 4 Kuparuk I C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.829 3234.95 0.592 3321.07 1.096 3406.04 0.769 3494.92 0.416 3575.57 0.521 3662.84 0.277 3744.57 1.093 3828.84 1,979 3915.05 1.396 3997.47 0.605 4085.13 0.600 4166.82 3.148 4253.17 0.824 4340.69 0.913 4423.37 0.772 4508.56 0.681 4588.24 1.254 4680.73 1.801 4761.03 0.394 4848.35 1.302 4937.63 0.909 5019.23 0.166 5101.00 1.866 5188.56 1.524 5273.12 Continued... 9 June, 1999 - 8:39 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-23 ST1 Your Ref: API-500292294170 Job No. AKMM9014, Surveyed: 3 May, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 6990.26 65.960 82.120 3669.33 3764.53 678.21 N 5316.20 E 7117.00 65.960 82.120 3720.96 3816.16 694.08 N 5430.86 E Global Coordinates Northings Eastings (ft) (ft) 5969301.03 N 567594.35 E 5969317.85 N 567708.87 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOft) (fi) Comment 1.590 5359.29 0.000 5475.03 PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 82.717° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7117.00ft., The Bottom Hole Displacement is 5475.03ft., in the Direction of 82.717° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (.) (ft) 7117.00 3816.16 694.08 N 5430.86 E PROJECTED SURVEY 9 June, 1999 - 8:39 - 5 - DrillQuest STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 95 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of Well at surface 8. Well number 1659' FNL, 1277' FWL, Sec. 12, T11N, R10E, UM 1C-23 At top of productive interval 9. Permit number/approval number 241' FNL, 2339' FWL, Sec. 8, T11 N, R11 E, UM 99-34 At effective depth 10. APl number 50-029-22942 At total depth 11. Field / Pool 225' FNL, 2314' FWL, Sec. 8, T11 N, R11 E, UM Kuparuk River Field / Kuparuk River Pool 12. Present well condition summar Total depth: measured 13975 feet Plugs (measured) true vertical 6718 feet Effective depth: measured 13870 feet Junk (measured) true vertical 6673 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 33' 16" 9 cu yds High Early 128' 128' Surface 8799' 9.625" 126o sx AS III, 345 sx Class G 8894' 4575' Production 13865' 7" 300 sx Class (3 13960' 6712" Perforation depth: measured N/A '.JRIGI" L,,; true vertical N/A Anch0rags ,~ & Tubing (size, grade, and measured depth 3.5", 9.3#, 8rd EUE @ 13504' Packers & SSSV (type & measured depth) Baker SB-3 perm. Pkr. @ 13437', No SSSV 13. Attachments Description summary of proposal__ Detailed operations program ~ BOP sketch__ 14. Estimated date for commencing operation 15. Status of well classification as: May 26, 1999 16. If proposal was verbally approved Oil __X Gas~ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call William Lloyd265-6531 Signed r~~.~ ,1~ ~ Title: Drillin§EngineedngSupervisor Date Chip Alvo . Prepared by Sharon All, up-Drake FOR COMMISSION USE ONLY Oo. ,,io.so, ,,rova.: [ Plug integrity __ BOP Test __ Location clearanc~ __ Mechanical Integrity Test__ Subsequent form required 10- .R'. _~¥ _1~'~ _~ ~vi¢l~ ~,r~.~j¢l~:/. u,.~glna, i Signed, , ,,,,~Y oo¢! App_r.0__v_?_.d by order of the Commission ._.:;, ~.1. - n e.,.~ ..... Commissioner Date ~O O: . =,-,,,-,, ~n.z~n.~ n,~v nR/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 25, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORI6 !AL Subject: lC-23 (Permit No. 99-34) Sundry Application for Annular Injection Dear Mr. Commissioner: Enclosed is a sundry request for annular injection for KRU lC-23. Attached to this request are several formation integrity/leak-off tests run at various times during the drilling operations. The test dated 5/13/99 represents the formation integrity test at the shoe of the surface casing. The test dated 5/15/99 represents data gathered on the open-hole section from 8930' md (surface casing shoe depth) to 13,050' md. The final test dated 5/21/99 represents data gathered on the 7" production casing x 9-5/8" surface casing annulus after the 7" production casing had been run and cemented. The data from the last test was obtained in order to indicate the expected break down and pump-in capability of the annulus for injection purposes. Based upon the satisfactory information gathered from these tests, approval for annular injection is requested. Pool 6 is currently drilling on lC-27 with one additional well on C-pad yet to drill (APD forthcoming). The annulus we are currently injecting into (lC-25) has accepted 23,781 bbls as of midnight, 5/24/99. We anticipate reaching the approved capacity of 35,000 bbls by 5/29/99. In order to avoid requesting dispensation for injection volumes above the approved capacity, ARCO Alaska, Inc. respectfully requests expedited approval of this sundry for injection into the 1C-23 annulus. If you have any questions or comments, please contact me at 265-6830, or Bill Lloyd at 265- 6531. Sincerely, Randy Thomas Kuparuk Drilling Team Leader AAI Drilling CASING TEST and FORMATION INTEGRITY TEST Well Name: lC-23 Date: 5/13/99 Reason(s) for test: Supervisor: Scott Reynolds [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Hole Depth: Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 8,894' TMD 4,579' TVD Mud Weight: 8.6 ppg Length of Open Hole Section: 8,930' TMD 4,588' TVD 36' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,350 psi + 8.6 ppg 0.052 x 4,588' EMW for open hole section = 14.3 ppg Pump output = 0.0846 bps Fluid Pumped = 3.8 bbl 3,200 3,100 3,000 2,900 2,800 2,700 2,600 2,500 2,400 2,300 2,200 2,100 2,000 1,900 1,800 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 1 O0 psi 0 psi __--e..-. LEAK-OFF TEST --~CASING TEST -- ........ ~::~ ........ LOT SHUT IN TIME _ ~,~-CASING TEST SHUT IN TIME- _ -- ~ TIME LINE _ ~~ 1 5 9 13 17 21 25 29 33 37 41 45 49 53 57 61 65 STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ' ................ '- ............... ~= ................ '~ , ................ ~ ............... -~ ................. 0 stks 0 psi 5 stks 150 psi 0 stks 0 psi i ................ i. ............... i. ................ .~ i ................ & ............... .~ ................. ................... _2. 9_ .s_ _t.k_ .s_ ..... __6_3__°___P__S_L_. .................... _2._5__s__t.k_.s_ ..... __8_0__0___p__s_L_, 30 stks 975 psi i ................ i. ............... I. ................ ................... _3..5_.s__tk_.s_ .... J__,_~_g_9__p__s_!_~ .................... _4.9__s__tk_?___~_j,~9__o_P_~!_, .................... f..5_.s__tk_.s_ .... & _S_ _5_ _O_ _p_ .s_ ! _ . ! i ................ i,= ............... i. ................ i ................................ r ................ '1 i ................ ~= ............... .i. ................ i ' , i ................ [. ............... i. ................ i i i i SHUT IN TIMEI SHUT IN PRESSURE 3.0 min 0.0 min i 1,350 psi ' ................ i. ............... i. ................ j .__J_._9_.m. Ln___[ ................. J_ _, _t _5. 9_ _p_ .s_ L ] 2.0 min ~ 1,120 psi j _._3_._9_m_Ln_._L ................. J_.,)._tg_?_~Lj .... S...o___m_Ln_ .................. L&.o__~_.o_.p_.s_Lj , 5.0 min I 1,050 psi ! ................ }. ............... i. ................ j .__.7_..9_..m_Ln___i ............... L.._~Z.o__p__s_L_~ 9.0 mJn ................ L ............... i--.-~A°-_P-_S_L_j ,._Z]_._o____m_Ln__L ............... L_.gJ.o__P_.s_L_j 3.0 mini 1 : 900 psi j ,._LE..o__._m_Ln__L ............... L _..9_o..o__ _p__s_[ ._,,' i ................ 4. ............... .~ ................. i ................ + ............... + ................. ................ ................................................. ................ · r ................................. SHUT IN TIME SHUT IN PRESSURE ................ ~. .................................. ___o__._o___mj~ ....................... .o__p~! ..... .0 _.J_ ........................................... 2.0 4.0 min ................ _._5.:_o___mj_n_ .................................... 8.0 min 7.0 min 8.0 min 9.0 min 15.0 min ................ T ............... ~ ................. t 20.0 min i ' ................ 25.0 min ................ 30.0 min J NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-23 Date: 5/15/99 Reason(s) for test: Supervisor: Scott Reynolds [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 8,894' TMD Hole Depth: 4,579' TVD Mud Weight: 9.2 ppg Length of Open Hole Section: 13,050' TMD 6,326' TVD 4,156' EMW: Leak-off Press. + Mud Weight = 1,030 psi + 9.2 ppg 0.052 x TVD 0.052 x 6,326' EMW for open hole section = 12.3 ppg Pump output = 0.0846 bps Fluid Pumped = 8.5 bbl 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi __ -- -- ~.-"k,~,_ I ~ LEAK-OFF TEST ~ -'~CASING TEST ....... ?,i ......... LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME : TIME LINE STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................ .- ............... .- ................ ..~ , ................ -r ............... .~ ................. ..................... _0_ _s_ _t_k_ ?_ ........ _0__p_?_[ .......................... _0___s_t._k?__ ........ _0___p.s__i ...... 4 stks 300 psi ................ ~. ............... t. ................ J i ................ .~ ............... .t ................. ................... ._S__s__t_k__s_ ...... ._3.5__0__.p_.sj___. 12 stks 440 psi ................................ r ................ -1 ................... _l_.6__s__t_k__s_ ..... _ _5.0_.0__ .p_.s_i__ _, .................... _2_ _O_ _s_ Lk_ _s_ ..... _ _s.s_.o.__p_.s_i_ _ _. ................... ._2_.S_.s__tk__s_ ..... _.6_°__°._.P_.S_L., ................... _~..0_.s__t_k__s_ ..... Z_o__o__p_?_L_. ................... _~_.6__s__t_k__s_ ..... __7_S__0__p_.s_L_. .................... _~_.O_.s__tk__s_ ..... __s&°_P__S_L_. .................... _4__5__s__tk__s_ ..... __s~_o.__p__s_L_' 50 stks 920 psi ................ i ................................. ................... .s..s_.s__t.k_.s. ..... ._~_0_.p__s_L_i ................... _6.o_.s__t~_s_ .... _l_ , _o_ _o_ _o_ p_ _s_ U .................................................. .................... _6_.S_.s_!~.s. .... J_,_o__~..o__p__sj_j .................................................... ............... ~- ............... ~. ................ i 70 stks 960 psi i .................................................. .................... _s__o_.s__~_s_ ..... __~_o__o_p__s_[ ..................................................... ................... ?__0_ .s_ .t.k_ ?_ ..... . _8_8_ _0. _ p_ _s_ [ ..................................................... .................. _Eo_o__.s_!.k..s. .... __8.0__0__p__s.[ ..................................................... SHUT IN TIME I SHUT IN PRESSURE ................ · .................................. · . i 0.0 mm 0 ~)s~ 1.0 min "E~-~i~ ................................... ~., ............................... i ................ i I. S.UT,. T,ME S.UT,. P.ESSURE -'E~'~i;~--f ............... i ................. [ 4.0 min ',, 5;.0 min , , 7.0 min ~ [ 8.0 min , 9.0 min , ................ .L ............... J. ................. ~.-J-°-:9---m-'-n--t ................................. 15.0 min: ................................................. 20.0 minj ................ ,i, ............... .e ................. i.__2_Eg___m_Ln._: .................................. 30.0 min ' ................................................ 1.0min : 650 psi .___2_._9_..m_Ln_ .................. ~_.._6.2.~_P__S_L.. i- ._._Eg_..m_Ln_ .................. L__._6~_P__S.L_. .... _4_._9_. .m_ Ln_ .................. i__._6J.O._p._s_L_. .... .Eg_..m_!.~_ .................. L__.?.?~_P.~L_, .___~_:9___m_!_n___~ ............... i___?_o__o_,__s_L_. 7.0 min i : 600 psi ............... ,._ J__O....o_..m. Ln._L ............... L____6.o_.o.__p_~L_. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-23 Date: 5/21/99 Reason(s) for test: Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC X 7" 26# L-80 BTC-MOD ANNULUS Casing Setting Depth: 8,894' TMD Hole Depth: 13,975' TMD 4,579' TVD 6,718' TVD Mud Weight: 10.3 ppg Length of Open Hole Section: 5,081' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 650 psi + 10.3 ppg 0.052 x 6,71 8' EMW for open hole section = 12.2 ppg Pump output = 0.0580 bps Fluid Pumped = 5.3 bbl · 700 psi 600 psi 500 psi ~ 400 psi M.I ~. 300 psi 200 psi 1 O0 psi 0 psi 0stk 4stk 8slk 12 16 20 24 28 32 36 40 44 48 52 56 60 64 68 72 76 80 84 88 92 96 100 104 108 112 lt6 120 dk sfk sfk sfk stk slk sfk sfk sfk stk slk sfk stk stk stk stk stk stk slk sfk stk stk sfk sfk slk stk dk stk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR LOT STROKES PRESSURE 4 stks 175 psi i ................ t. ............... i. ................ ................... ..Es__t_k_~ ...... __2~_O__p_~i___i ................ r___~..2_.s__t_k__s. ..... __2_9__0___p__s_L_i .................... _~.?__s__t_k__s_ ..... __~_2__E__p__s_L_i .................... _2..O_.s__t_k__s_ ..... ._3_5__O_p__s_i___~ 24 stks 390 psi i ................ i_ ............... i. ................ j ................... _2._S_.s__t_k__s_ ..... __4J_S___p__s_[__~ 32 stks 445 psi .................... _3..6_.s__t_k..s... 475 psi .................... _4..O_.s__t_k__s_ ..... __4_8__5__p__s_L_. 44 stks 515 psi ................... _4.E .s__t_k._s_ ..... __s_5__0_._P..S_L_,' 52 stks 575 psi ~ ................... _5__6__s__t_k__s_ ..... __s_9__5__e_s_i___! 60 stks 605 psi ~ ................... ?__4._s_.t_k__s_ ..... __6_2__o___p_.s_L_, ~ ................... _6__8__s__t_k__s_ ..... __6~_O__.p_.s_[__,~ 72 stks 640 psi ~ i ................ I- ................................ 76 stks 650 psi i i ................ h ................................ .4 80 stks 650 psi i ................ i. ............... i. ................ ................... _~__4__s__t_k_.s_ ..... __6.5_.0_..p_.s_L_.' ................... _Es_ _s__t_k_ _s_ ..... _?.5_°_p__s_L _ 92 stks 650 psi f SHUT IN TIME SHUT IN PRESSURE .... .o...9_..m_Ln_ .................. L___.6__5_9_.p__s_L__, .__J_..9_._m_Ln. .................. i.___5_5__o__p__s_L_ 2.0 min ~ 500 psi __.3_..9_..m_Ln_ .................. L ___5_o_.o__ .p_.s_L _, .... .4_..9_._m_Ln___L ............... L__._~_o__.p__s.L_ 5.0 min : 425 psi .__.Eg___m_Ln___, ................ i__._4j_o_._p__s_[__. 7.0min : : 410 psi FOR CSG TEST STROKES PRESSURE ! ................................................ ~. .~ .................................................. ................................................ ! ................ + ............... + ................. i SHUT IN TIME SHUT IN PRESSURE 0.0 rain gN/A ~.0 2.0 rain ~.0 4.0 5.0 min ~.0 rain .................................................. 7.0 rain 8.0 ~.0 rain ~0.0 min ~ ~5.0 mia ~ ...............................r ri ................................ ~ 71 ................ 8.0 min i i 405 psi 20.0 min i ............................................... =1 i ................................ 9.0 min : j 400 psi 25.0 min ~ 10.0 m~n .... ~ 400 ps~ :"'~"l~i~-T ............... t ................. ................ L ............... I. ................ j J. .t i ................................................ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Casing Detail 9.625" Surface Casina WELL: 1C,23 ARCO Alaska, Inc. DATE: 05/10/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOPS Above RKB 9 5/8" Landing Joint (Jr. #230 oa=38.49') 33.35 FMC GEN IV- Kuparuk 9 5/8" Csg Hgr 1.25' up 2.00 33.35 jts205-229 9 5/8", 40.0#, L-80 BTC (25 jts) . 969.53 35.35 TAM 9 5/8" Port Collar 2.62 1004.88 its. 3-204 9 5/8", 40.0#, L-80 BTC (202 its) 7806.47 1007.50 Gemeco Float Collar 2.37 8813.97 its 1-2 9 5/8", 40.0#, L-80 BTC (2 its) 75.57 8816.34 Gemeco Float Shoe 2.48 8891.91 Casing shoe @ 8894.39 T.D. @ 8910' leaving 15.61' of rathole 50 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2 over stop collars and over casin~l collars on Jts. 3-49 and over collar of it. 227 Run 1 ROTCO Rigid Straight Blade Centralizer on joints 204 and 205. Joint 230 will be used as the landing joint . · Remarks: String Weights with Blocks: 350k Up, 110k Dn, 70k Blocks. Ran 229 oints of casing: Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: Fred Herbert / Rick Overstreet ARCO Alaska, Inc. Cementing Details Well Name: lC-23 Report Date: 05/11/99 Report Number: 14 Rig Name: Pool 6 AFC No.: AK0021 Field: Centralizers State type used, intervals covered and spacing Comments: Ran 1 bowsprlng per joint for the first 49 joints & 1 across the collar of joint 227. Ran I rigid Rotco straight blade'on either side of the Port Collar on stop rings in the center of the joints. Mud Weight: PV(pdor cond): PV(after cond): I YP(pdor cond): YP(afler cond): Comments: 10.0 40 23I 54 25 Gels before: Gels after. Total Volume Circulated: 24/44 10/16 3468 bbls Wash 20 Type: Volume: Weight: Comments; ARCO 20 8.5 Spacer 100 Type: Volume: Weight: Comments: ARCO Spacer 100 10.5 Lead Cement 1012 Type: I Mixwtrtemp: No. of Sacks:t Weight: Yield: Comments: ASIII 70 1260 10.7 4.44 Additives: Class 'G' w/50% D124, 9.0% D44, 0.4% D46, 30% D53, 1.5% S1, 1.5% D79 TallCement 73 Type: I Mixwtrtemp: I No. ofSacks: I Weight: Yield: Comments; GI I 170 345 15.8 1.17 Additives: Class 'G' w/1% S1, 0.2% D46, 0.3% D65 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8 bpm 16 bpm 350 Lost returns w/390 bbls of Reciprocation length: Reciprocation speed: Str. Wt. Down: displacement pumped. N/A N/A 100 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 638 645 Calculated top of cement: CP: Bumped plug: Floats held: S u da ce Date: 5/11/99 Ye s Yes '13me:21:40 Remarks:Casing went to bottom wilh only I bridge (1941'). Down weight was 95k to 100k. After getting on bottom we were unable to recip, casing. Circulated & conditioned mud with full returns thru out. Contaminated mud & cement (10.5) at surface 270 bbl$ into displacement. 10.6+ cement back with 340 bbls of displacement pumped. Lost returns @ 390 bbls into displacement. Continued with job bumped plug w/645 bbls of displacement (7. bbls Over). Final circulating pressure was 1980 psi @ 3 bpm. Cement Company: I Rig Contractor: I Approved By: DS POOL Fred Herbert / Scott Reynolds ALASKA OIL AND GAS CONSERVATION COMMISSION April 6, 1999 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99501-0360 Re: Kuparuk River Unit 1C-23 ARCO Alaska, Inc. Permit No: 99-34 Sur Loc: 1659'FNL, 1277'FWL, Sec. 12, T1 IN, R10E, UM Btmhole Loc. 197'FNL, 2576'FEL, Sec. 8, T1 IN, R11E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrit3' Test (FIT). Cementing records, FIT data, and an)' CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1C must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ! Robert N. Chris enson, P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Deparlment of Fish & Game, Habitat Section w/o encl. Depamncnt of Environmental Conservation v,'/o encl. ARCO Alaska, Inc. "- ' Post Office Box 100360 Anchorage, Alaska 99510-0360 March 25, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 9950:1-3192 Re: Application for Permit to Drill: KRU ;1C-23 Surface Location: :1659' FNL ;1277' FWI_ Sec ;12 T;1;1N R;1OE, UM Target Location: 241' FNL, 2339' FWL Sec. 8, T11N~ R11E, UM Bottom Hole Location: 197' FNL, 2576' FEL Sec. 8, TllN, R11E, UM Dear Commissioner Christenson, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from :1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of :1C pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" production casing string and 3-:1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following' :1) 2) 3) 4) 5) 6) Form 10-40:1 Application for Permit to Drill per 20 AAC 25:005 (a). Fee of $ :100 payable to the State of Alaska per 20 AAC 25.005 (c) (:1). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (:1) and (b) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) ARCO does not anticipate the presence of H2S in the formations to be ... ~,... encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Robert Christenson Application for Permit to Drill - 1C-23 Page 2 10) Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned.The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Technologist (20 AAC 25.070) Sharon AIIsup-Drake, Drilling 263-4612 2) Geologic Data and Logs IVleg Kremer, Geologist (20 AAC 25.071) 265-6460 The anticipated spud date for this well is April 7, 1999. If you have any questions or require further information, please contact Bill Lloyd at (907) 263-6531 or Chip Alvord at (907) 265-6 WiHiarLfl B. Llogd~ Senior Drilling I~'~gin( CC; Kuparuk 1C-23 Well File Chip Alvord ATO-1200 M.] Loveland NSK6 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type ofwork: Drill [] Redrill [] I lb. Type ofwell. Exploratory [] StratigraphicTestEi Development Oil [] Re-entry [] Deepen []I Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 95 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-036( ADL 28242 ALK 2292 Kuparuk River Pool 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.0251) 1659' FNL, 1277' FWL, Sec. 12, TI 1N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 241' FNL, 2339' FWL, Sec. 8, T11 N, R11 E, UM 10-23 #U-630610 At total depth 9. Approximate spud date Amount 197' FNL, 2576' FEL, Sec. 8, T11N, R11E, UM April 7, 1999 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 197' @ TD feetI lC-02 16.2' @ 400' feet 2560 14004 ' MD / 6720 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300 MD Maximum hole angle 65 Maximum surface 2698 psig At total depth (TVD) 3202 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Weld 40' 95' 95' 135' 135' 230 sx AS I 12.25" 9.625" 40# L-80 BTC 8795' 95' 95' 8890' 4574' 1240 sx AS Ill, 340 sx Class G 8.5" 7" 26# L-80 BTC-M 13909' 95' 95' 14004' 6720' 260 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production Liner :'~ il ':i;~' :i'~'~ ~: ~:'-'J/ {i" !;:~ O~/G//~4 / Perforation depth: measured · true vertical 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.O50 requirements [] 21. I hereby cedify that the foregoing is true and correct to the best of my knowledg6 Questions? Carl William Lloyd 265-655 Signed~/~J~'-~-f~ */ Commission Use Onl~ "., . I'"e oover,e,er Z~ 50-(3~,~-- .,~-.'~-. ~,~,~ I-- .~ ~"¢ If°r°therrequirements Conditions of approval Samples required [] Yes J~ No Mud Icg required [] Yes [] No Hydrogen sulfide measures ,~ Yes [] No Directional survey required [] Yes [] No Required working pressure forBOPE [] 2M; [] 3M; [] ~ [] 10M;• [] Other: ORIGINAL SIGNED-BY by order of Approved by ~obli~rt N ~hri_~fCn._~ort Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in tri[~licate - ~ ARCO Alaska, Inc. ~--~ DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 1C-23 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 100- 120' Drill out to TD 9.5- 11.0 ppg 6-20 5-20 35-50 10-20 15-40 7-15 9.5-10 +10% 2-6 4-8 <6 through Kup 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Hud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Haximum anticipated surface pressure (HASP) while drilling the production hole is calculated using a surface casing leak-off of :~3.5 ppg EMW (0.70 psi/ft) and a gas gradient of O.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of :[,357 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. HASP = (4,574 ft)(0.70- 0.11) = 2,698 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of lC pad are expected to be N3,400 psi (0.53 psi/R). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.6 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6,455'. Target (Kuparuk C4) (3400+150)/(0.052'6455)=10.6. Well Proximity Risks: The nearest well to 1C-23 is 1C-02. The wells are 16.2' from each other at a depth of 400' HD. Drilli.g Area Risks: Drilling risks in the ~-C-23 area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) , ARCO Alaska, Inc. ~- .... Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1.C-23 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. ]:f isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 1.C-23 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) ~ (0.052) ~ (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (4,574') + 1,500 psi Max Pressure = 4,354 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 19-5/8' 40 L-80 3 BTC 3,090 psi NA 5,750 psi !4,888 psi '7' 26 L-80 3 LTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 31/2''* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951. psi 10,160 psi 8,636 psi * if needed Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). . . ARCO Alaska, Inc. Drill and Case Plan for 1C-23 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 8890' MD/4574' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Make up 8 1/2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to Base HRZ at +13179' MD/6374' TVD · Perform a second LOT and determine an acceptable kick tolerance · If kick tolerance is acceptable, 8 1/2" hole will be drilled to TD · If kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and R]:H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 10242' MD/6693' TVD · Condition hole and mud for casing 14. Run and cement 3 1/2" 9.3# LB0 EUE Liner 15. Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 16. Run and land 3 1/2" tubing with gas lift completion 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig Completed 1C-23 FMCPrudh°eGenV b][- ~ ~-~ 9-5/8 x 51/2 x 31/5 L_ll I ':':':~ I I~ :i:i:i :.:.:.~ -_... .-.-.-, . .'~'~-~.~...~ ::::::" .;.:.:, '.:.:. :-:-:.: -:-::: 2.87 CAMCO DS .;.;.;, .:::::""" nip[:)le at 500' + MD 9-5/8" PORI Collar ::::::: !ii:: Standard Grade, BTC :.:.:.:i!iiiii:':':':!!i!!!iiiiii!i i:!:!:!.' .' .' ~ i ~ al ,:.:.:. -.-.-. '-'-'.' -- ~ :':':' !:!:!:i ~ :::::: ',::;::: "'"" :':':' C 81/2" Hole }~' ~ ~ Baker 3.5" x 7" SAB-3 P .... ::::::: 13,438' MD 3Y2" 9.3 ppf L-80 8rd EUE "-2..'::::: 3½"x 1" side pocket GLM Base of permafrost at 2,268' MD / 1,795' TVD 12-1/4" Hole 9-5/8" 40 ppf L-80 BTC Surf. Csg. 8,890' MD / 4,574' TVD 7" 26 L-80 BTC Mod Csg 14,004' MD / 6,720' TVD Camco 3¼"x 1-1/2" sid6 pocket GLM :::::;: · :.:.:. :.:.:.: !:i:i:i I I'~ .:,:.:. · · · i:i:i:i ::::::: CAMCO 2.75" · . · !:i:!:i / !:!:!:! [ nipple · :.:.:- .:.:.:. :.:.:.: , ::::::: 13,498' MD · , · ::::::: :;:;:;: ::::::: 3-1/2" Slimhole Completion 3/25/99 Dr l and set Casing All Depths are RKB Pool Rig 6 1C-23 FMC Prudhoe Gen IV 9-5/8 x 7 9-5/8 ................ Mandrel Hanger Base of permafrost at 2,268' MD / 1,795' TVD 12-1/4" Top of West Sak at 7,401' MD / 3,949' TVD Base of West Sak 8,413' MD / 4,374' TVD 9-5/8" 40 ppf L-80 BTC SUrface Casing 8,890' MD / 4,574' TVD 8-1/2" Hole Weatherford Gemoco 7" Float Collar and Float Shoe · , . 16" Conductor Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 1,001' MD/1,000' TVD Mud Weight in Surface hole: 10.0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Production hole 9.1 to 10.0 ppg 7" 26 L-80 BTC Mod Csg Completion Type 2 3/25/99 ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT ~---J MANUAL GATE V KILL LINE L 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / 1 / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom b 1 3" 5,000 psi WP Shaffer GATE VALVE 1~/hydraulic actuator CHOKE LINE 13-5/8" 5,000 psi WP ,~~ DRILLING SPOOL LI w/two 3" 5M psi WP outlets I ISINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. Diverter Schematic Pool #6 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. Pad 1C 23 slot #23 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 23 Version#5 Our ref : prop2301 License : Date printed : 25-Mar-99 Date created : 30-Jun-97 Last revised : 25-Mar-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 28.846,w149 29 41.851 Slot Grid coordinates are N 5968578.722. E 562283.968- Slot local coordinates are 1660.00 S 1277.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath GMS <0-7780'>,,1.Pad 1C GMS <0-7615'>.,2,Pad 1C PMSS <0 - 8095'>,,18,Pad 1C PMSS <O-9390'>,,15,Pad 1C PMSS <O-10980'>,,14,Pad 1C PMSS <0 - 11918'>,,16,Pad 1C GMS <0-7575'>,,4,Pad 1C PMSS <0-17089'>,,12,Pad 1C PMSS <0 - 10969'),,17,Pad 1C MSS <O-7000'>,,9GI,Pad 1C PGMS <0-9002'>,,lOGI,Pad 1C GMS <0-9600'>, 8,Pad 1C GMS <0-9784'>, 7,Pad 1C GMS <0-10243'> ,6,Pad 1C GMS <0-7753'>, 5,Pad 1C GMS <0-9700'>, 3,Pad 1C PMSS <0-8677'>, 13,Pad 1C Unknown Data,,WS1,Pad 1C PMSS <O-11300'>,,11,Pad 1C MMS <6948-7570'>,,WS~24,Pad lC Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 11-Mar-99 18-Dec-98 22-Feb-99 17-Dec-98 18-Mar-98 8-Jan-99 18-Dec-98 7-Jan-98 2-Dec-98 2-Jan-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 1-Dec-98 2-Nov-98 19-Mar-97 17-Dec-97 97 16 323 35 133 438 254 754 761 6 786 2 631 9 736 4 615 0 495 3 373 9 135 4 471.1 7678.8 772.6 2857.8 8 800.0 800.0 2 400.0 400.0 I 100.0 475.0 i 740.0 740.0 9 800.0 800.0 7 600.0 600.0 7 475.0 475.0 0 491.7 1950.0 100.0 100.0 300.0 300.0 0.0 322.2 0.0 13960.0 466.7 13320.0 475.0 475.0 475.0 475.0 475.0 475.0 466.7 466.7 530.0 530.0 322.2 322.2 11480.0 11480.0 600 6OO 1200 1800 _C 2400 $000 i ,. 5600 ~ 4200 4800 54OO 6000 6600 7200 CreeJ~:l by f~nch D~3f.e ph3Jted: 25-Mcr-1999 Plot Reference is 25 Version ~5. Coordi'nateg ore Jn flit reflrenc~l slo'J J~23. ARCO Alaska, Inc. Structure : Pad 1C Well : 23 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 0 800 1600 2400 5200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ESTI MATE D SURFACE LOCATION: 1659' FNL, 1277' FWL SEC. 12, TllN, RIOE tEST. RKB ELEVATION: 95' KOP 3'OOBegin Build/Turn to Target. ~9.12 8.64 24.46 DLS: 4.00 deg per 40.30 4B.2~ 0.21 EOG Bose Permafrost TARGET LOCATION: 241' FNL, 2339' FWL SEC. 8, T11N, R11E TD LOCATION: 197' FNL, 2576' FEL SEC. 8, T11N, R11E AVERAGE ANGLE 65.19 DEG West Sak Bose West Sok 9 5~9B0 Casing Camp SS 82.76 AZIMUTH 11340' (TO TARGET) ***Plane of Proposal*** C5( Target - TOD C2 'Top C 1 ~op Bx Sbole~. /u - k.,aslng ~'T i i i i i i i i i I i I i i i i I i i i i i i i i i ii I i i i i i I i i i i i i i 0 600 1200 1800 2400 5000 5600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 Vertical Section (feet) -> Azimuth 82.76 with reference 0.00 N, 0.00 E from slot #25 5200 2400 160~. ' 800 800 Created by finch Dote plotted: 2.~-Mor-1999 Plot Referenco ie 25 Vem~on C~rdrnates ore in flit re~lrlnce ITru. V. rtlco, D.p~h ...... I ARCO Alaska, Inc. Stru~=fure: Pad 1C Well : 25 Field : Kuparuk River Unit Looatlon : North Slope. Alaska Point KOP Begin Build/Turn to 0 EOC Base Permafrost Top West Sok Bose West Sok 9 5/8 Casing C90 Comp SS C60 C40 C50 C20 Base HRZ K- 1 Marker Target - Top C4 Top C5 Top C2 Top C1 Top B Shale TD - Casinq Pt PROFILE MD Inc 300.00 466.66 2024.75 2268.12 7400.53 841 3.19 8889.73 8939.77 9204.26 11134.27 11832.41 12702.11 12995.18 13178.65 13340.68 13598.00 13681.41 1 3740.98 13829.14 1 3879.1 8 14003.08 COMMENT Dir TVD 0.00 0.00 300.00 5.00 29.00 466.45 65.19 85.09 1692.86 65.19 85.09 1795.00 65.19 83.09 3949.00 65.19 83.09 4374.00 65.19 85.09 4574.00 65.19 85.09 4595.00 65.19 85.09 4706.00 65.19 83.09 5516.00 65.19 83.09 5809.00 65.19 83.09 6174.00 65.19 85.09 6297.00 65.19 83.09 6374.00 65.19 83.09 6442.00 65.19 85.09 6549.99 65.19 85.09 6585.00 65.19 83.09 661 0.00 65.19 83.09 6647.00 65.19 85.09 6668.00 65.19 85.09 6720.00 DATA North 0.00 6.36 166.92 193.48 753.63 864.15 916.16 921.62 950.48 1161.12 1237.32 1332.24 1364.22 1384.25 1401.93 1430.01 1439.12 1445.62 1455.24 1460.70 1474.22 East 0.00 3.52 820.62 1059.92 5664.65 6577.14 7006.55 7051.64 7289.96 9029.06 9658.15 10441.82 10705.90 10871.25 11017.25 11249.09 11 524.25 11 577.95 11 457.57 11502.46 11614.10 V. Sect 0.00 4.50 855.12 1056.02 5714.47 6653.61 7066.15 7111.57 7351.63 9105.41 9757.08 10526.46 10792.47 10959.00 11106.06 11 559.62 11415.55 11469.40 11549.42 11594.85 11707.29 Deg/lO0 0 ~0 5:L}O 4.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O. nO O.uO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 c=te~ ~ ~;~ch For: LLOYD D~=t. plott~l: 25-Uor-lggg Plo~ Relerence ;e 25 Ve~1on ~5. C~rd~notla ore Jn flit rlllren~ al~ ~25. True Vertical Depths 0~[~, ARCO Alaska, Inc. SJruolure: Pad 1C Well: 2:5 Field : Kuparuk River Unit Looatlon : Norlh Slope, Alaska East (feet) -> 280 320 360 400 440 4BO 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 10B0 1120 440 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I /~ 2100 400 / 400 2000 360 520 280 240 I 200 ~ 160 ',4--- k,. 120 0 Z 80 4O 1200 5400 1300 / 1900 / ~3oo 1800 1700 3100~, / / ./ 1600 3400 3300 2300 15001300 1400 .... e-.-- .... 500 2400 1800 1500 ~ ~ 2900 1400__ ._. ~ -- ~ 2800 ~ 2700 260( 2500 2500 2400 1800 1900 1700 1600__ 3000 700 ~ ~ 2000 2100 2200 1500 1600 1700 o 1200 ----~ ~--~---~ ....... 2000 40 120 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ii i i i i 280 520 360 400 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1120 East (feet) -> 440 400 560 320 280 240 200 160 120 80 40 40 80 120 /x I Z o Creoted by finch For: LLOYD Oote plotted: 2~-Mar-lgg9 Plot Reference ;e 25 Vera~on C~rd[natea are in felt reference al~ ~25. True Vertical Depths ore. EM. RKB (Pool ARCO Alaska, Inc. Structure: Pad lC Well: 23 Field : Kuparuk River Unit Looatlon : North Slope, Alaska 180 160 140 120 100 40 20 20 40 1 O0 East (feet) -> 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ?ooo /900 ~0~ 1100 500 320 340 I I I I 1300 360 380 I I 180 160 140 120 100 80 60 40 700 .--' '"' / 2500~ ,. ~roo ,- ~2oo _.1300 _ _ - ...... ~ .... 2o 500~_~ "F-'oO0 /800 1200...... _ -- -- -- -- 2200 ~5ou, ~5oo ,400 _ -- -- ~ - ~~°2~oo _ _ _ ~ / 500 -- --- 'i 1~o ~ ~ o~.~-_ ............. [ 1700 ~ .~900 ~ ~ ~ I ~ ~ ~ ~ gOO .~ 20 ~ 1800 ~ ~ 700 ~_ 1 900 800 ~'~ ~uu J 600~500 1700 X ~ ~ 700 300 1600 60 X ~ 2000 J 900 80 ~ ~ I 1000 ~ , ~ ~ ~ ~ ~ , , ~ , , , , , ,, , 100 4~ 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 500 520 540 560 580 East (feet) -> Z O b~, ti,ch For: LLOYD Dote plott~d: 25-1dar-1999 Plot Reference i~ ARCO Alaska, Inc. Structure: Pad 1C Well: 25 Fleld: Kuparuk River Unit Looatlon : North Slope, Alaska 900 8OO 700 600 500 400 300 ~_ 200 o ~:~ Z 100 1 O0 200 300 40O East (feet) -> 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 /J / .¢ 3700 1700 2500 4 51 O0 5500 5900 2500 4700 . ....° 5100 ~ 1700 ,~, ..~2100 2300 ....... 2100 2500 2700 2900 5100 5500 3500 e.-.-. ~ .--, 2300 -- --"--- -- 2500 29O0 800 gOO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 East (feet) -> 900 . ., 800 7OO 600 500 400 I 300 Z 0 ---i- 200 ~ oo ~ lO0 200 300 400 c~tl~ ~ .~ For: LLOYD I~{i plo{~d: 2§-Mar-1999 Plot Reference J~ 25 Ve~on ~3. C~rd~nateB ora }n flit referencl sl~ ~25. True Vertical Depth~ ~~E~. RKB (Pool ~6).~ ARCO Alaska, Inc. Sfruoture: Pod 1C Well: 23 Field : Kuporuk River Unit Loooflon : North Slope, Alaska East (feet) -> 2600 2800 5000 5200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 2.000 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ,?.000 18oo ......~'~oo ...~oo 18oo ~oo ~00 16O0 4500 1000 4~o~ ..... 5900 ~ ~ 800 5700 ~ ~ ~ ~ ~ 3500~ ~ ~ ~ ~oo _~-~- ~oo 2900 ~ ~ ~ ~ ~ ~ 270~ _ ~ ~ ~ ~ 400 200 5500 5700 5900 61 O0 6300 3700 3900 4100 4500 4500 4700 4900 5100 5500 _-- ~ ~ ~ ~ ~_ ~ ~__ ~ 200 0 0 ~ ~ -- -- j~O 5500 5700 200 -- -- ~ -- -- 5900 ...... 41oo 43oo 200 -- ~ ....... 4500 .... 4700 4900 -- ~ 5100 -- ~ ~ ~ 5300 .... ~ 5500 400 ~ -- ~ ~ ~ ~ ~ 5700 5900 400 600 600 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 Eosf (feet) -> 1000 soo 600 400 I Z 0 4800 4400 4000 3600 3200 2800 I 2400 -4'-- ~_ 2000 "~ 1600 0 Z 1200 IC,~tld ~/ iinch For: LLOYD Do~.l plo~t~d: 25-Mar-1999 Plot Reference ~e 25 Veteran ~5. C~rd~no[ee ore ;n felt referen~ al~ ~23. True Vertical Depths o~E~. RKB (Pool 800 400 400 800 ARCO Alaska, Inc. Sfruofure: Pad 1C Well: 23 Field : Kuparuk River Unit Loooflon : North Slope, Alaska East (feet) -> 4000 4400 4800 5200 5600 6000 5400 6800 7200 7600 5000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 I [ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~7 O~O490/~0 51 O0 ~~~00 / 6700 6500~~ /-"%500 5900~ 6500 5700 ~ 4~00 ~ ~ 5700 4900 5100~ 4500 4700 ~ .,.,e ~~ 4300~ ~_ ~ 4100 ~ ,._ ~ 50% 700_ _ 900_ _ 5500 ~ ~ ~ 3500 /4700--- '5500 4500 4900 5500 5700 6100 .~..6500[~-~_ 67O0 6500 ..~ r'~ 5900 61oo~ .,.. ~ ~65°° .~ ~ ~ 5700 .... ~ '-' ~ 5500 5300 ~=_._, 4100 4500 4500 4700 4900 5100 5500 5500 5700 5900 6100 6300 ~ .--~ '"'~ -- ~ "' --. % i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i I i i l 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 9600 10000 10400 10800 11200 11600 12000 12400 4800 4400 40aa 36O0 5200 2800 2400 2000 1600 1200 800 400 400 800 A I Z 0 c~ ~ ~.e. For: LLOYD DO~ pkA'ted: 2.ff,-Mor-1999 r~e v~ O~. are rKerm~ RC0 Alaska, In ........... Structure : Pad lC Well : 23 Field : Kuparuk River Unit Looafion : North Slope, 320 330 340 TRUE NORTH 350 0 10 30 4O 310 2100 50 60 29O 70 280 80 270 260 300 90 500 100 250 240 110 120 230 .2'2 0 '" Z 2300~ 2 1 0 / t200 / 130 190 140 150 160 180 170 All depths shown ore Measured depths on Reference Well Normal Plane Travelling Cylinder- Feef~ .? WELL PERMIT CHECKLIST COMPANY ~. _./-/ ~ WELL NAME ,/~'~L~ /'~_.-~_~ PROGRAM: exp dev ~ redrll "~ serv wellbore seg ann. disposal para req I/ FIELD & POOL ///'~',~ INIT CLASS /~)~,,' //-o~// GEOL AREA '~'~::~ UNIT# ~¢'~'~./~::~:::~ ON/OFF SHORE (~3//,~ ADMINISTRATION ENGINEERING APPR_ DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique. well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. 13OPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~__~,,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N N (~N ¥ ~ ®N GEOLOGY Permit can be issued w/o hydrogen sulfide measures ..... Y N/Y N Data presented on potential overpressure zones ....... ~N .,~ Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. /Y N Contact name/phone for weekly progress repods [exploratory o~.y] Y N 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan ,,~qnt2cd. a~ (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. N GEOLOGY: ENGINEERIng: UIC/Annular COMMISSION: N N Comments/Instructions: c:\msoffice\wordian\diana\checklist 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. Sperry-Sun Drilling Services LIS Scan Utility Fri Oct 08 13229241 1999 Reel Header Service name ............. LISTPE Date ..................... 99/10/08 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 99/10/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: 'API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 5 AK-MM-90114 M. HANIK F. HERBERT RECEIYED OCT 9 1999 soo29229 2oo SPERRY-SUN DRILLING SERVICES 08-OCT-99 MWD RUN 6 A/{-MM- 90114 M. HANIK F. HERBERT 12 llN 10E 1660 1277 .00 95.20 60.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 115.0 12.250 9.625 8891.0 8.500 13975.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-4 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 5 IS DIRECTIONAL WITH DUAL GAMMA P_AY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 6 IS DIRECTIONAL WITH DUAL GAMMA P~AY (DGR),ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STA]~ILIZED LITHO-DENSITY (SLD) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM D. SCHWARTZ FOR M. KREMER OF ARCO ALASKA, INC. ON 06/02/99. 6. MWD RUNS 1 - 6 REPRESENT WELL 1C-23 WITH AN API# 50-029-22942-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13975'MD (6718'TVD) . SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS LITHOLOGY, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" MUD WEIGHT: 10.7 PPG MUD SALINITY: 350 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE ROP GR FET RPD RPM RPS RPX NCNT FCNT NPHI PEF DRHO RHOB $ BASELINE CURVE FOR SHIFTS: Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH 8850 0 8859 5 12982 0 12982 0 12982 0 12982 0 12982 0 12990 0 12990 0 12990 0 12999.0 12999.0 12999.0 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 13975.0 13932.5 13905.0 13905.0 13905.0 13905.0 13905.0 13912.0 13912.0 13912.0 13921.5 13921.5 13921.5 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 5 8910.0 13050.0 6 13050.0 13975.0 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OFIMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR ROP RPX RPS RPM RPD FET NPHI FCNT 'NCNT RHOB DRHO PEF Min 8850 33 06 0 17 1 69 1 83 1 98 2 07 0.4 24.85 443 2014 1.57 -0.14 4.43 Max Mean Nsam 13975 11412.5 10251 516.85 135.44 10147 2879.38 202.605 10251 51.66 4.11173 1847 44.29 4.36785 1847 40.03 4.61593 1847 34.63 4.72738 1847 39.64 3.7863 1847 81.76 54.762 1845 760 580.133 1845 3409 2487.15 1845 3.3 2.40599 1846 0.5 0.0562622 1846 17.55 7.55518 1846 First Reading 8850 8859.5 8850 12982 12982 12982 12982 12982 12990 12990 12990 12999 12999 12999 Last Reading 13975 13932.5 13975 13905 13905 13905 13905 13905 13912 13912 13912 13921.5 13921.5 13921.5 First Reading For Entire File .......... 8850 Last Reading For Entire File ........... 13975 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3IW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 8850.0 GR 8859.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN/ROLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13049.5 12998.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAbIMARAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 15-MAY-99 INSITE 3.2. (UPGPJtDE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 13050.0 8910.0 13050.0 63.3 67.1 TOOL NUMBER P1305HG6 8.500 8.5 LSND 9.10 45.0 9.0 300 5.2 .000 .000 .000 42.3 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined A~sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8850 13049.5 10949.8 8400 8850 GR 39.86 516.85 139.841 8278 8859.5 ROP 0.17 2172.85 219.105 8400 8850 Last Reading 13049.5 12998 13049.5 First Reading For Entire File .......... 8850 Last Reading For Entire File ........... 13049.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX NCNT FCNT NPHI GR PEF DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 12982.0 12982.0 12982.0 12982.0 12982.0 12990.0 12990 0 12990 0 12998 5 12999 0 12999 0 12999 0 13050.0 SURFACE SOFTWARE VERSION: DOWN/COLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMARAY SLD STABILIZED LITHO DEN CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : STOP DEPTH 13905.0 13905.0 13905.0 13905.0 13905.0 13912.0 13912.0 13912 0 13932 5 13921 5 13921 5 13921 5 13975 0 17-MAY-99 INSITE 3.2. (UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 13975.0 13050.0 13975.0 64.2 66.1 TOOL NUMBER P1307HRNLG6 P1307HRNLG6 P1307HRNLG6 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3~TURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REM3LRKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 10.70 48.0 9.0 350 4.6 2.500 .247 3.400 3.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 6 FT/H 4 1 68 4 2 GR MWD 6 API 4 1 68 8 3 RPX MWD 6 OHMM 4 1 68 12 4 RPS MWD 6 OHMM 4 1 68 16 5 RPM MWD 6 OHMM 4 1 68 20 6 RPD MWD 6 OHMM 4 1 68 24 7 FET MWD 6 HOUR 4 1 68 28 8 NPHI MWD 6 PU-S 4 1 68 32 9 FCNT MWD 6 CNTS 4 1 68 36 10 NCNT MWD 6 CNTS 4 1 68 40 11 RHOB MWD 6 G/CM 4 1 68 44 12 DRHO MWD 6 G/CM 4 1 68 48 13 PEF MWD 6 BAP~N 4 1 68 52 14 48.2 First Name Min Max Mean Nsam Reading Last Reading DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF 12982 3 26 33 06 1 69 1 83 1 98 2 07 0.4 24.85 443 2014 1.57 -0.14 4.43 13975 2879 38 258 95 51 66 44 29 40 03 34 63 39 64 81 76 760 3409 3.3 0.5 17.55 13478.5 127. 726 115.95 4. 11173 4.36785 4.61593 4.72738 3.7863 54.762 580.133 2487.15 2.40599 0. 0562622 7.55518 1987 1851 1869 1847 1847 1847 1847 1847 1845 1845 1845 1846 1846 1846 12982 13050 12998.5 12982 12982 12982 12982 12982 12990 12990 12990 12999 12999 12999 13975 13975 13932.5 13905 13905 13905 13905 13905 13912 13912 13912 13921.5 13921.5 13921.5 First Reading For Entire File .......... 12982 Last Reading For Entire File ........... 13975 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/10/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/10/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/10/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Ms. Wendy Mahan AOGCC Second Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the second quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-19 33933 100 0 34033 Open, Freeze Protected 1C-25 34836 100 0 34936 Open, Freeze Protected 7- CD1-40 32777 100 0 32877 Open, Freeze Protected 1C-23 34470 100 0 34570 Open, Freeze Protected ~-' 1C-18 0 0 0 0 Open, Freeze Protected CD1-35 217 100 0 317 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Doug Chester Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree ~~.~) Sharon Allsup-Drake Well Files
