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194-012
• • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas El SPLUG❑ Other ❑ Abandoned 0' Suspended❑ 1b.Well Class: 20na,C 25.105 20AAC 25.110 Development 2 • Exploratory❑ GINJ E WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 7/1/2017 194-012/317-227 • 3.Address: 7.Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 1/27/1994 50-029-22442-00 • 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Nafne and Number: Surface: 1285'FNL, 1737'FEL,Sec 25,T13N, R83, UM 2/2/1994 KRU 3M-28 Top of Productive Interval: 9. Ref Elevations: KB:6e 17.Field/Pool(s): 901'FNL,572'FEL,Sec 34,T13N, R8E, UM GL:27 BF: Kuparuk River Field/Kuparuk River Oil Pool • Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 998'FNL,821'FEL,Sec 34,T13N, F8E, UM SURFACE 25524 ' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 506131 y- 6016213 Zone- 4 13240/6284 ALK 2655 TPI: x- 496742 y- 6011316 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 496493 y- 6011219 Zone- 4 N/A 1800/1688 5.Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 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 SCANNED JAN 1 8 2015 N/A 23. CASING, LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENtING RECORD PULLED 16 62.5 H-40 41 121 41 121 24 222 sx ASI CMT 9.625 36 L-80 41 6065 41 3398 12.25 1250 sx ASIII,650 sx G 120 sx ASI CMT TOP JOB 7 26 L-80 2191 13222 1974 6272 8.5 250 x Class G CMT 24.Open to production or injection? Yes ❑ No 2 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number; Date Perfd): N/A N/A N/A Perforations Plugged: `,O f,LF 1O' 914-12938 MD 6066-6082 TVD 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. DATF Was hydraulic fracturing used during completion? Yes❑ No ❑ -}1, RECEIVED Per 20 AAC 25.283(i)(2)attach electronic and printed information VFPIP f) DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED JUL 1 8 2017 43.5'to Surface 3 bbls 15.6 ppg Arctic Set 1 27. AOGCC 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-Hour Rate - VTL i/a//d Form 10-407K�Rei 1 5/2017! ��� CONTINUED ON PAGE 2 I JI!I 1 8 2017 Submit ORIGINIAL on I I i RBDMS V� vL • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No l 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 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1800 1688 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,Schematic Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontolooical 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: G.L.Alvord Contact Name: Jill Simek Authorized Title: Alaska Drilling Manager Contact Email: Jill.Simek(cilc . Authorized Contact Phone: 263-4131 Signature: Date: 1(.1(2-047 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 • • • SUNDRY NOTICE 10-407 ConocoPhillips Welent l 3M-28 Plug and Abandonm July 12, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3M-28, commencing operations on June 3, 2017 and completing the Plug and Abandonment on July 1, 2017. The tree was removed and cement was tagged at 43' 5" from the top of the tubing head adaptor. A top job was performed to bring cement to surface, then the wellhead was removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. ik i'''''•° per ', ,"' '- x- , � '' 7.,,,-,,,,,k, .-...:. , ;.it,t.i,,,, , ,:t,_,,0%, ::„. .„. . ., . , -, ,,,,,,,,,,,,* . ,---,-,,z,, 7-. ,,,,,,. .,-, .. .., .., ��`' ,'kms �- s_ ,4-moN44.,*,''..t".'.,,,-,;,:::1, ' '' ",- 4" '' ; ' t `' ,,,,,,,,:.:- .,„ it, ; i . t m • • ,P > ,,itz."''''" -' -°'4. . •., ',4 ,,,--. ..."' •- '.-- . "t--.4t:j sem. ' ,„ � P g 3 Y t4 i ' t ''',',-;:11:.4,4 J11,,„ ,,Into ��:.:• • • P&A Work Summary EVENT_DATE EVENT_TEXT 5/30/2017 Distributed signed (5-22-17)10-403 sundry#317-203 for P&A of 3M-28. 6/3/2017 (P&A) PREP Initial Casing Pressure=0 psi Verified 0 psi in the surface casing. Let casing breath for 1 hour. Removed 1502 valves from OA valve.Adjusted jewelry on adjacent wells 02 and 01 to have clearance of excavation. Final Casing Pressure=0 psi 6/11/2017 (MISC) REMOVE TREE, IA&OA CASING VALVES-COMPLETED. INSTALLED FLANGE ON TOP OF THA, IA&OA CASING VALVES-COMPLETED.TAGGED TOP OF CEMENT @ 43'5" FROM TOP OF THA. Initial casing pressure=0. FL @ SF. Top of cement @ 43'5"from top of THA. Removed OA companion nipple and casing valve. Installed 2" bull plugs. Removed IA casing valve. Installed flange. Removed tree. Installed flange with needle valve on THA. Final casing pressure=0 6/14/2017 Good morning Victoria, CPAI recently received the 10-403 approval (Sundry#317-227)to continue the post-rig abandonment of 3M-28(PTD#194-012). We are currently scheduling and working the logistics to finish the abandonment. For scheduling purposes, I wanted to obtain clarification on the 60-day timeframe to final abandonment mentioned on the rigas approved 10-403(Sundry#317-203). Do the 60-days start when the new sundry(Sundry#317-227)was approved? Or did the 60-days start at another time,and if so,could you please clarify the start date for our knowledge? Rachel, 60 days from Sundry approval date. Thanx, Victoria 6/15/2017 (P&A) : Performed Cement Top Job(Complete). Initial Casing pressure=0. FL @ 44". TOC @ 43.5'. Removed flange from THA. Utililized vac truck&removed all fluid from wellbore. Pumped^'3 bbls 15.6 ppg AS1 cement into wellbore taking returns from down spout from OA nipple,good cement returns to surface. New TOC @ 43". Re-installed flange on THA. Final casing pressure=0. J • • 6/16/2017 (P&A) : Excavate well,Welders cut&removed grade beams&Conductor Standing Plate. Initial Casing Pressure=0. Removed flange from THA,TOC @ 49.5"w/4.5"of fluid on top. Replaced flange. Remove annulus jewelry from adjacent wells(IA from well#2,OA from well#1)&installed alemites (casing valves left closed &flagged). Roads&Pads excavation to^'45". AES welders cut&removed grade beams&Conductor Standing Plate. Cleaned up work area, placed barriers. • Final Casing Pressure= N/A. 6/17/2017 Request sent to AOGCC for witness of P&A. 6/17/2017 (P&A) : Finished Well Excavation,Set Shoring Box&Stairs, Erect Scaffold Around Wellhead. Initial casing pressure=N/A. Vacc'ed water from excavation. Roads& Pads dug initial hole for shoring box. Utilized crane&set shoring box,set sump&r/u vac truck. Roads& Pads excavated &built egress. Utilized crane&set stairs. Scaffold crew set scaffold around wellhead. Laded thermal blankets on excavation slopes. Cleaned up work area,set up barriers. Final casing pressure=N/A. 6/18/2017 (P&A) : Cut Windows in 30"&16"Casing,Chipped Cement, Installed thread "0" let on 9.625". Initial Casing pressure=0. Welded cut 4 windows in 30"casing,chipped extremely hard cement. Welder installed thread "0" let on 16"casing,drilled into 16", no LEL's. Welded cut 2 windows in 16"casing,chipped cement,welder installed thread "0" let on 9.625" casing,drilled into 9.625",no LEL's. Final Casing pressure=0. 6/19/2017 Cut and remove 3M-28 Wellhead stub(17'-9"approx weight 10,500 lbs)THA,30"sleeve, 16" conductor and 9 5/8". Wellhead removal and installation of Marker plate. AOGCC(JEFF JONES) WITNESSED post wellhead removal. KDTH norm tested wellhead stub and removed from location. Welded Marker plate on stub that remained abandoned in place. 6/20/2017 Pulled shoring box and stairs. Roads and Pads backfilled P&A excavation. 6/21/2017 Took final P&A pictures. 7/1/2017 Notify State asking for P&A site clearance. State man Brian Bixby witness and approved P&A site. 7/1/2017 Sent pictures&info to town engineer Jill for final P&A. ,r• . KUP OD 3M-28 ConocoPhallip5 a , Well AttribiW Max Angle& D TD Alaska.lac, Wellbore API/UWI Field Name Wellbore Status ncl('') MD(ftKB) Act Btm(ftKB) EftnOcutiftillrps 500292244200 KUPARUK RIVER UNIT PROD 71.86 4,004.49 13,240.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 3M-28,7/18/2017 1,42.56 PM SSSV: 180 12/4/2015 Last WO: 2/5/1994 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,940.0 4/6/2016 Rev Reason:P8A WELL pproven 7/17/2017 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 45.0 123.5 123.5 62.50 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...'Grade 'Top Thread SURFACE _ 95/8_ 8.921 45.0 6,064.9 3,397.7 36.00 L-80 BTC I1,1. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(060) Set Depth(TVD)...Wt/Len(I...Grade Top Thread it Original Production 7 6.276 2,191.0 13,222.1 6,272.2 26.00 L-80 BTC R-3 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) r) Des Com Run Date ID(in) �® 188.0 188.0 0.42 Fish Parted string mill and DP stuck side by side in the 9- 5/12/2017 4.000 y� 5/8"casing(see camera run#9 in the well folder). O. cement Plug;45.0 MT L 2,982.0 2,325.0- 69.52 Sand(20/40 20/40 mesh sand 5/8/2017 0.000 na - mesh) CONDUCTOR;45.0-1235 '6";,44..3e:30 3,041.0 2,345.7 69.47 WLS RBP Wire line set RBP 5/7/2017 0.000 Hesitation Cement Squeeze; N ss.0 ftKB . k'Pei 12,645.0 I 5,896.1 I 53.55 G Lock-Set Model G lock-set RBP 5/5/2017 0.000 " f4 RBP • irl`nom 3 Perforations&Slots qP Shot . : Dens ,?a Top(TVD) Btm(TVD) (shots/ �, Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com iz' 12,914.0 12,938.0 6,065.8 6,081.8 A-1,3M-28 4/21/1994 4.0 IPERF 41/2"Csg Gun i Cement Plug;75.7 ftKB " " )' Cement Squeezes Top(TVD) Btm(TVD) Fish;188.0 `-.4 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 69.0 180.0 69.0 180.0 Cement 5/16/2017 Perform Surface casing hole squeeze.Test lines to Squeeze 1000 psi. Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS cement,40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat AS1 cement,5 bbls water @ 2.6 bpm,200 psi.140 psi trapped pressure.Bleed off to 0 psi.Bled back 2.5 bbls.Blow down cmt.line.Lay down circ valves.POOH to 129'MD.Rig up circ lines. Rig up to pump second stage of squeeze.Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS1 cement, 40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat AS1 cement,1.3 bbls water @ 3 bpm,230 psi 79.8 195.0 79.7 195.0 Cement Plug 5/22/2017 Pump 3 bbls water at 2 bpm,110 psi.Test lines to Sand Izo/4o meshp,z saz o 1000 psi.Batch up and pump 10 bbls 14.5 ppg Mudpush w/dye at 2 bpm,110 psi.Clean cement tubs and batch up and pump 29.4 bbls 15.7 ppg AS1 cement at 2 bpm,125 psi.Cement to surface at 24 bbls cement away.Cement returns at 15.2 ppg.CIP at wLs ReP.3.04.0 24:00 hrs. 45.0 79.8 45.0 79.8 Cement Plug 6/15/2017 CEMENT TOP JOB-3 bbls 15.6 ppg AS1 cement into wellbore taking returns from down spout from OA nipple,good cement returns to surface. New TOC @ 43"from THA 1 Notes:General&Safety End Date Annotation 11/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 6/11/2017 NOTE:REMOVE TREE,IA 8 OA CASING VALVES 6/15/2017 NOTE:P&A-WELL CEMENTED TO SURFACE 6/18/2017 NOTE:CUT WINDOWS IN 30"8 16"CASING,CHIPPED CEMENT,INSTALLED THREAD"0"LET ON 9.625" • SURFACE,45 0-6,064 9- t 6/19/2017 NOTE:Wellhead removal and installation of Marker plate.AOGCC(JEFF JONES)WITNESSED post wellhead 6/19/2017 NOTE:REMOVE WELLHEAD STUB(17-9".)WELD COVER PLATE.PREP FOR BACKFILL. 6/20/2017 NOTE:REMOVED SUMP,STAIRS,SHOREBOX.RBP BACKFILLED EXCAVATION G tock-set Raw.12 s45 0-H (PERF;12.014.0-12,930.0 -- Original Production;2,191.0- 13,2221 • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission kit( TO: Jim Regg (I DATE: July 1St 2017 P. I. Supervisor FROM: Brian Bixby SUBJECT: P&A Site Inspection Petroleum Inspector KRU 3M-28 Conoco Phillips Alaska Inc. PTD 194-012; Sundry 317-227 7/01/17: The surface abandonment of this well was not witnessed by AOGCC due to schedule conflicts. CPAI is required to document the cutoff depth, cement to surface and marker plate installation with photographs attached to the sundry report that will be filed after the date of this inspection. I stopped by location and took picture. The abandoned well excavation was backfilled; the above-ground flowlines associated with KRU 3M-28 were left in place. The well site was clean - photo below. it '�a �� 30, -11111 • • • • 2017-0701_Location_KRU 3M-28_bb.docx SCANNED AUG Page 1 of 1 z���. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7e4g Z/Z2i/i.7 DATE: 6/20/2017 P. I. Supervisor FROM: Jeff Jones SUBJECT: Surface Plug & Abandon Petroleum Inspector Kuparuk River Unit 3M-28 ConocoPhillips Alaska Inc.(CPAI) PTD 1940120 / Sundry 317-227 June 19, 2017: I travelled to CPAI's KRU well 3M-28 to inspect the surface cement plug and abandon. On my arrival, I met with CPAI representative Roger Mouser and we discussed the P & A procedures. I then inspected the excavation and well head casing cut off. The well casing strings were cut off 4+ feet below original grade and a 3/8" steel plate with the required information was bead welded to the outermost casing string, meeting AOGCC requirements. Summary: I witnessed the successful surface abandonment of CPAI's well 3M-28 in . the Kuparuk River Unit. Attachments: Photo of Marker Plate SCANNED JUL 1 72017, r,,. M'" # - .a. . -,,4,, ? + ,-.h a '4„ ,} .of ; f . 4 ill .t.kg is#1.4 rP , l' .; '' .( ' i .1 ) , -...,E0 ,AN,c.., - ti , , .... , , , . , , „ k k _... 4 .--• : . ;•••,,,s,„''' ‘.. '4--.;. ... 4, . 16# V. , a l 4Y.` 'N b 2017-0619_Surface Abandon KRU 3M-28_jj.docx Page 1 of 1 • PTD 1 q +— o i -2- Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Wednesday,June 14, 2017 8:27 AM To: NSK Well Integrity Supv CPF3 and WNS Subject: RE:3M-28 (PTD# 194-012)Abandonment Clock Clarification Rachel, 60 days from Sundry approval date. Thanx, Victoria From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent:Wednesday,June 14,2017 8:22 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:3M-28(PTD#194-012)Abandonment Clock Clarification Good morning Victoria, CPAI recently received the 10-403 approval(Sundry#317-227)to continue the post-rig abandonment of 3M-28(PTD# 194-012). We are currently scheduling and working the logistics to finish the abandonment. For scheduling purposes, I wanted to obtain clarification on the 60-day timeframe to final abandonment mentioned on the rig's approved 10-403 (Sundry#317-203). Do the 60-days start when the new sundry(Sundry#317-227)was approved? Or did the 60-days start at another time,and if so,could you please clarify the start date for our knowledge? Thank you, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED AUG 0 7 2017: • • • OF T� Alaska Oil and Gas gw�\����yy,�s� THE STATE Of TTAsKA Conservation Commission � 333 West Seventh Avenue 1W\717- GOVERNOR BILL WALKER Anchorage, AlasMainka 2079 .3433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer swop °' 1 ' !`. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool,KRU 3M-28 Permit to Drill Number: 194-012 Sundry Number: 317-227 Dear Ms. Simek: 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, iag14.44k_ Cathy '. Foerster Chair DATED this /2 day of June,2017. RBDMS EA. JUN 1 3 2017 • • C RECEIVED STATE OF ALASKA JUN 01 2917 ALASKA OIL AND GAS CONSERVATION COMMISSION 12.11 APPLICATION FOR SUNDRY APPROVALS AG 7 20 AAC 25.280 1.Type of Request: Abandon 0, Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development p 194-012 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22442-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3M-28 - Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25524 ` Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,240' . 6,284' ` 13222 • 6272 ‘ 0 12645,3041,80(cement) 188 Casing Length Size MD ND Burst Collapse Conductor 80' 16" 121' 121' Surface 6,024' 9.625 6,065' 3,398' Production 11,031' 7" 13,222' 6,272' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12914-12938 . 6066-6082 N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER=NONE N/A SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic U '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development i]. Service ❑ 14.Estimated Date for 6/5/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned D, 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well Integrity Engineer Contact Email: Jill.Simek@conocophillips.com Contact Phone: (907)263-4131 Authorized Signature: �� Date: //No l COMMISSION USE ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: li -221 Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance [9 14 a�' c4,-24.1. Other: P/-u' d o L/ -r v t 4 5 I cl I- a/-r "21' Post Initial Injection MIT Req'd? Yes ❑ No ErK Spacing Exception Required? Yes ❑ No 27 Subsequent Form Required: /O —'i b C/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: --/2..._-/7 1943 q3-/ - 777���""`�*���� 66%7 V a 4,17.l 17 aieOR1 1 A ' RBi�iVi� �� JUN 1 3 2017 G J y Submit Form and Form 10-403 Revised 4/2017 r v d i is valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska JUN 01 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC 24 May 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7t'Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon Kuparuk River Unit well 3M-28(PTD#: 194-012). 3M-28 is a Kuparuk producer,originally drilled and completed in 1994.In early 2016 the well failed a tubing integrity fluid level test and diagnostics discovered a deep tubing leak. A tubing patch was attempted but failed;additional testing found more tubing leaks which would require a rig workover to repair.The well was identified as a CTD candidate in early 2017 and a workover began on April 21,2017. During the workover,subsidence damage was discovered around 200'KB.During the subsidence repair, tools were lost downhole and attempts to retrieve the tools or push them further down hole were unsuccessful. Due to the lost fish,the wellbore became inaccessible for further workover efforts. Two Retrievable Bridge Plugs have been set inside the production casing and represent the primary isolation from the reservoir.The lower plug is set at 12,650'KB and is a Baker G-Lock RBP.It was pressure tested from above to 1,000 psi.The plug is held in place with slips and is rated to 10,000 psi (greater than casing burst).The second plug is set at 3,042'KB and is a Wireline Set RBP.It was also pressure tested to 1,000 psi from above and has 50'of sand on top.The plug is also held in place with slips and is rated to 6,000 psi.KWF at 12.5 ppg was left in between both plugs.The well was displaced to seawater above the top plug and a No Flow test was performed to ensure competency.A cement plug was then pumped from approximately 150' KB to surface. Top of Cement was tagged at 79.7'KB. 3M-28 no longer has utility due to the lost access to the wellbore and the inability to return it to production. Per this procedure,a P&A will be performed by pumping a cement top-off job,followed by excavation and removal of wellhead and tree.t/ If you have any questions or require any further information,please contact me at 263-4131. Sincerely, ill imek 1 Integrity Engineer 'AI Drilling and Wells ✓� • ConocoPhillips 3M-28 P&A Permit to Drill #: 194-012 The objective of the proposed 3M-28 P&A is to perform a cement top job, excavate 4 feet below original tundra level, remove the wellhead/tree and cellar, and backfill with gravel/fill to ground level. Proposed P&A: Excavation / Final P&A: 1. Receive Rig Handover from Doyon 14. Confirm well status. 2. Ensure all pressure is bled off the system. 3. Remove the tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 5. Cut off the wellhead/casing string at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface. AOGCC witness and photo document required 7. Send the casing head w/stub to materials shop. °hoto document. 8. Weld 1/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC VVitnes Kequirea. ConocoPhillips 3M-28 PTD # 194-012 API # 50-029-22442-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. . 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. hoto document final location condition after ail work is compieteo. Is KUP PROD • 3M-28 • ConocoPhillips Well Attributes Max Angle&MD TD Alaska inc. a Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ftKB) "Crn000vtrBl(s f 500292244200 KUPARUK RIVER UNIT PROD 71.86 4,004 49 13,240.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-28,5/311201711:1142 AM SSSV 180 12/4/2015 Last WO 2/5/1994 VertigaIsCham40c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,940.0 4/6/2016 Rev Reason:SUSPEND WELL pproven 5/31/2017 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 41.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 41.0 6,064.9 3,397.7 36.00 L-80 BTC i Casing Description Original Production OD(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 7 6.276 2,191.0 13,222.1 6,272.2 26.00 L-80 BTC R-3 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Incl ../� Top(ftKB) (ftKB) 1°) Des Com Run Date ID(in) Mil 188.0 188.0 0.42 Fish Parted string mill and DP stuck side by side in the 9- 5/12/2017 4.000 5/8"casing(see camera run#9 in the well folder). 2,982.0 2,325.0 69.52 Sand(20/40 20/40 mesh sand 5/8/2017 0.000 CONDUCTOR;41.0-121.0 -. mesh) hi 3,041.0 2,345.7 69.47 WLS RBP Wire line set RBP 5/7/2017 0.000 ,,, ,,,',..,N"."*'` 12,645.0 5,896.1 53.55 G Lock-Set Model G lock-set RBP 5/5/2017 0.000 �.as���+�--.` RBP Fish;188.0 s a Perforations&Slots �� z` Shot Pv Dens Wll'inkitle0 Top(ND) Btm(ND) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com Cement Plug;79.7 fete g' 12,914.0 12,938.0 6,065.8 6,081.8 A-1,3M-28 4/21/1994 4.0 IPERF 41/2"Csg Gun Hesitation Cement Squeeze; . Cement Squeezes 390.0#00 I Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 390.0 1,332.0 390.0 1,291.0 Cement Squeeze 5/16/2017 Perform Surface casing hole squeeze.Test lines to 1000 psi.Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS cement,40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat AS1 cement,5 bbls water @ 2.6 bpm,200 psi.140 psi trapped pressure.Bleed off to 0 psi.Bled back 2.5 bbls.Blow down cmt.line.Lay down circ valves.POOH to 129'MD.Rig up circ lines. Rig up to pump second stage of squeeze.Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS1 cement, 40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat ASI cement,1.3 bbls water @ 3 bpm,230 psi Sand(20/40 mesh),2,982 o y ;,,,,, 79.8 390.0 79.7 390.0 Cement Plug 5/22/2017 Pump 3 bbls water at 2 bpm,110 psi.Test lines to 1000 psi.Batch up and pump 10 bbls 14.5 ppg ki.....,. Mudpush w/dye at 2 bpm,110 psi.Clean cement tubs and batch up and pump 29.4 bbls 15.7 ppg AS1 WLS RBP',3,041.0 cement at 2 bpm,125 psi.Cement to surface at 24 bbls cement away.Cement retums at 15.2 ppg.CIP at 24 00 hrs. Notes:General&Safety End Date Annotation 11/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;41.0-6,064.9-+ I- G Lock-Set Rep;12,645.0 fil- PERE;12,914.0-12,93B.0- Original Production;2,191.0- 13,2221 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned ❑ SuspendedE 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 5/24/2017 , 194-012/317-186/317-203 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 1/27/1994 50-029-22442-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1285'FNL, 1737'FEL,Sec 25,T13N,R8E,UM 2/2/1994 KRU 3M-28 Top of Productive Interval: 9. Ref Elevations: KB:68 17. Field/Pool(s): 901'FNL,572'FEL,Sec 34,T13N,R8E,UM GL:27 BF: Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 998'FNL,821'FEL,Sec 34,T13N,R8E,UM 3041/2346 ADL 25524 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 506131 y- 6016213 Zone- 4 13240/6284 ALK 2655 TPI: x- 496742 y- 6011316 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 496493 y- 6011219 Zone- 4 N/A 1800/1688 5.Directional or Inclination Survey: Yes ❑ (attached) No E 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 RECEIVED JUN. 0 7 2017 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.5 H-40 41 121 41 121 24 222 sx ASI CMT 9.625 36 L-80 41 6065 41 3398 12.25 1250 sx ASIII,650 sx G, 120 sx ASI CMT TOP JOB 7 26 L-80 2191 13222 1974 6272 8.5 250 sx Class G CMT 24.Open to production or injection? Yes ❑ No III 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): N/A N/A N/A 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No E scpti��� JAN 1 8 2,0 j a Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 79-195 MD 29.4 bbls 15.7 ppg,AS1 cement 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A WELL SUSPENDED 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-Hour Rate /� Form 10-407Revised 5/2017 V TL !/•2/ / CONTINUED ON PAGE 2Submit ORIGINIAL only 111-.11 thou►� Aff1 RBDMS L�' JUN 1 6 2017 . • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 2 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1800 1688 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A information,including reports,per 20 AAC 25.071. Formation @ TPI- N/A Formation at total depth: N/A 31. List of Attachments: Daily Operations Summary,Cement Report,Schematic 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.oer 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Na : G.L.Alvord Contact Name: Andrew Beat Authorized Titl: Ak Drilling Man ger Contact Email: Andrew.T.Beat cop.com Authorized , 4-1r 1 Contact Phone: 265-6341 Signature: ;cock,— Date: 6-1. 1 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 TVD 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 • • Cement Detail Report `I" &Wells 3M-28 ConocoPhillips String: Cement Plug Job: RECOMPLETION,4/21/2017 14:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 5/22/2017 23:00 5/22/2017 00:00 3M-28 Comment Pump 3 bbls water at 2 bpm, 110 psi.Test lines to 1000 psi. Batch up and pump 10 bbls 14.5 ppg Mudpush w/dye at 2 bpm, 110 psi.Clean cement tubs and batch up and pump 29.4 bbls 15.7 ppg AS1 cement at 2 bpm, 125 psi.Cement to surface at 24 bbls cement away.Cement returns at 15.2 ppg.CIP at 24:00 hrs. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Cement Plug 79.8 195.0 Yes 5.4 No No Q Pump!nit(bbl/m...Q Pump Final (bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 2 2 174.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Suspension Cement 0.0 177 AS1 29.4 Plug Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 0.93 3.54 15.70 0.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 6/7/2017 • • 'Kit Operations Summary (with Timelog Depths) e.st 3M-28 Conoco;Phillips a.£xk Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 4/17/2017 4/17/2017 3.00 MIRU MOVE OTHR P Prep Doyon Rig 14 for move from 06:00 09:00 KCC to 3M Pad 4/17/2017 4/17/2017 0.25 MIRU MOVE SFTY P Held PJSM with crew on moving from 09:00 09:15 KCC to 1A pad -having to shut down for Airplane travel to Kuparuk. 4/17/2017 4/17/2017 8.75 MIRU MOVE MOB P Road rig from KCC to 1A-Pad access 09:15 18:00 4/17/2017 4/17/2017 1.00 MIRU MOVE WAIT P Wait on CPAI field change out 18:00 19:00 4/17/2017 4/17/2017 0.50 MIRU MOVE MOB P Back Doyon 14 out on to spine road 19:00 19:30 4/17/2017 4/17/2017 2.50 MIRU MOVE MOB T Trouble shoot front steering arm, 19:30 22:00 Clean organize rig floor and pipe shed. RU NES cats to assist in pulling Doyon 14 to the high side of the road, RD cats. 4/17/2017 4/18/2017 2.00 MIRU MOVE MOB P Move Doyon 14 from 1A Pad access 22:00 00:00 to Oliktok Y 4/18/2017 4/18/2017 0.50 MIRU MOVE WAIT P Allow traffic to pass while checking 00:00 00:30 move system. 4/18/2017 4/18/2017 9.50 MIRU MOVE MOB P Move Doyon 14 from Oliktok Y to 10 00:30 10:00 Pad and stage there while Doyon Crews attend IFC training at KDTH 4/18/2017 4/18/2017 5.50 MIRU MOVE SFTY P the 2 Doyon 14 Crews attended IFC 10:00 15:30 training at KDTH 4/18/2017 4/18/2017 3.50 MIRU MOVE WAIT P Continue to Prep rig for commission 15:30 19:00 while waiting for CPAI field change out 4/18/2017 4/18/2017 4.50 MIRU MOVE MOB P Move Doyon 14 from 1Q Pad to CPF 19:00 23:30 3 4/18/2017 4/19/2017 0.50 MIRU MOVE WAIT P Allow traffic to pass 23:30 00:00 4/19/2017 4/19/2017 7.00 MIRU MOVE MOB P Road rig from CPF 3 to 3M Pad 00:00 07:00 4/19/2017 4/19/2017 1.00 MIRU MOVE RURD P Pull Rear Booster tires 07:00 08:00 4/19/2017 4/19/2017 6.00 MIRU MOVE RURD P Transport essential equipment fro 08:00 14:00 Milne Point to 3M Pad. Install 13-5/8 5M BOPE stack and rack back in cellar. Spot and set rig mats around well. 4/19/2017 4/19/2017 0.25 MIRU MOVE SFTY P PJSM on pulling rig over well 14:00 14:15 4/19/2017 4/19/2017 5.25 MIRU MOVE MOB P Pull rig over well and shim up,had to 14:15 19:30 set up matting for pulling turning yoke 4/19/2017 4/19/2017 1.00 MIRU MOVE MOB P Skid rig in drilling position over cellar 19:30 20:30 area. 4/19/2017 4/20/2017 3.50 MIRU MOVE RURD P RU floor lines-Mud,Kill and Choke 20:30 00:00 lines. Mud bucket drain line, Mud/Gas separator line,steam and air lines. RU beaver slide and prep pits for taking on fluid. Slide drag chain into place. RU drag chain and check torque on choke manifold flanges. Page 1/39 Report Printed: 6/1/2017 • • IV 0 Operations Summary (with Timelog Depths) 3M-28 /lips Rig: DOYON 14 Job: RECOMPLETION Time Log StartDepth Start Time End Time Dur(hr) Phase Op Code Activity Code Tune P-T-X Operation (ftKB) End Depth(ftKB) 4/20/2017 4/21/2017 24.00 MIRU MOVE RURD P Continue to take sea water,RU drag 00:00 00:00 chainlnstall High Pressure line from CM to Poor Boy Degasser. Spot slop tank and RU chute. Clean and organize floor,install mouse hole and fill boiler#1 with water. Move bleed trailer away from well. Set up Tioga heaters to cellar,check mud pumps and lines. Change out fittings on Hyd. Super choke. RU test pump manifold and lines. Service and grease Choke manifold. Move fluid in pits,verify no leaks in valve system. Stage up pressure on boiler#1. Meg Top drive and Draw works traction motors. Clean ship Master/split bushings to Tuboscope for MPI. NU to test CM manifold. Remove and replace rubber stripping on scalper shakers. Test CM system to 4,600 psi-good test.RU chart recorder and body test all choke manifold valves at 250/5,000 psi for 5 minute intervals. Fill Koomey N2 Bottles with N2,along with pulsation dampeners. Replace wear strips on shaker#2. Move fluid around in pits for totco pit monitoring system calibration. RU Totco recorders around the rig. CDhange out the Hydraulic Super choke actuator and calibrate th3e open close gauge on the panel. 4/21/2017 4/21/2017 6.00 MIRU MOVE RURD P Continue to Test CM valves. Blow 00:00 06:00 down CM and RD test equipment. Remove 1502 integral flange from Choke hose in cellar,install target"90" and install to the choke line on the BOP stack. Change out savor sub to "New"HT 38,spot and RU LEPD fuel tank. Setup SAA/RAA stations. 4/21/2017 4/21/2017 4.50 MIRU MOVE RURD P Install grabber dies on top drive. 06:00 10:30 Change out McDonnell valve on Boiler #1,Calibrate gas detectors, Install Koomey hoses to BOPE. 4/21/2017 4/21/2017 3.50 MIRU MOVE RURD P PJSM,RU circulating hoses to tree 10:30 14:00 and flow back tank,charge up MP#1 and#2 Pulsation Dampeners.Continue to charge Koomey N2 Bottles. 4/21/2017 4/21/2017 2.50 MIRU WELCTL MPSP P PJSM, Begin well work. RU 14:00 16:30 Lubricator and pull Type H BPV. SITP =1,200 psi,SICP=1,300 psi. RD Lubricator and RU to circulate Page 2/39 Report Printed: 6/1/2017 s • `w Operations Summary (with Timelog Depths) i 3M-28 Conoct Phillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/21/2017 4/21/2017 5.50 MIRU WELCTL KLWL P PJSM,Test lines to 3,500 psi-good 16:30 22:00 test. line up pump @ 2 BPM at 1480 psi,while holding 1,200 psi back pressure, Increase PR to 3 bpm @ 1,630 psi while maintaining 1,200 psi on the IA. Pumped total of 110 BBLS. -shut down and empty kill tank. Continue with well kill at 3 bpm @ 1,600 psi on tbg while maintaining 1,200 psi on the IA. for 457 bbls 4/21/2017 4/21/2017 1.00 MIRU WELCTL OWFF P Monitor well for 30 minutes 1,100 psi 22:00 23:00 SIP calculate 125 psi over balance- equivalent to a 12.5 ppg 4/21/2017 4/22/2017 1.00 MIRU WELCTL PRTS P Perform positive pressure test on 23:00 00:00 TBG/IA to 2,500 psi-30 stks to pressure up. Loss 600 psi in 15 minutes. 4/22/2017 4/22/2017 6.00 MIRU WELCTL RURD P While conditioning KWF,installed 00:00 06:00 bales,handling equipment,for 3-1/2 TBG and 4"DP. Service top drive and fill compensator to 900 psi with N2. Plumb in 2-N2 back up bottles on Koomey. Load and Strap HT 38 DP in pipe shed. Quadco continue to install equipment in Mud Shack,Company mans and Tool Pusher office. 4/22/2017 4/22/2017 1.50 MIRU WELCTL RURD P Begin to install 2-7/8 x 5 in the LPR's 06:00 07:30 and continue to load 4"HT-38 DP inn the pipe shed. 4/22/2017 4/22/2017 2.50 MIRU WELCTL SEQP P PJSM,Test surface mud lines to 07:30 10:00 3,500 psi,Change out 2"Demco bleeder Bonnet 0-ring and 4"Stand pipe Bonnet 0-ring. Blow down Top drive. Sim-Ops=Load 250 bbls of 12.7 ppg WBM spike fluid. 4/22/2017 4/22/2017 2.00 MIRU WELCTL RURD P Continue to load pits with 12.7 ppg 10:00 12:00 WBM Spike fluid while continuing to load 4"HT-38 DP in to the pipe shed. Loosen UPR and Blind Ram Doors. 4/22/2017 4/22/2017 0.50 MIRU WELCTL COND P Blend KWF from 12.4 ppg to 12.5 ppg 12:00 12:30 4/22/2017 4/22/2017 2.00 MIRU WELCTL KLWL T PJSM,Kill well with 12.5 ppg WBM for 12:30 14:30 KWF,pumped 1 bbl and pressured up to 1,400 psi. SWI,bled off pressure. Found low torque valve at flow back tank frozen. Thaw line. PT to 3,500 psi-good test. Page 3/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) 02 14 3M-28 ConocPhitlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operdtlpn (ftKB) End Depth((KB)' 4/22/2017 4/22/2017 2.00 MIRU WELCTL KLWL P Establish circulation @ 1 bpm @ 14:30 16:30 1,500 psi while holding 1,450 psi back pressure on the casing side. increase rate to 1.5 bpm @ 1,500 psi while holding 1,400 psi back pressure on the casing side.then 2 bpm @ 1,400 psi while holding 1,375 psi and 3 bpm @ 1,320 psi while holding 1,350 psi back pressure on the casing. Pumped a 103 bbls at 510 psi at 3 bpm while holding 830 psi back pressure. Pumped 350-bbls at 510 psi while holding 300 psi back pressure. Final pressures were SITP=0 psi,SICP= 400 psi. 368 bbls returned to kill tank 4/22/2017 4/22/2017 1.00 MIRU WELCTL OTHR T Had to wait 30 minutes for 16:30 17:30 hydrocarbons to releaqse from fluid. Tie into tank and had a leak at the suction line -15 gallons reported and cleaned up. 4/22/2017 4/22/2017 0.50 MIRU WELCTL SFTY P Held Pre spud with CPAI,along with 17:30 18:00 CPAI expectations. 4/22/2017 4/22/2017 1.50 MIRU WELCTL OTHR P Pull fluid from kill tank in order to finish 18:00 19:30 circulation of surface to surface 4/22/2017 4/22/2017 1.50 MIRU WELCTL KLWL P Circulate at 5 30 spm while holding 19:30 21:00 500 psi back pressure on the casing side.4,000 stks=600 psi,4,400 stks =700 psi.5,000 stks=800 psi against FO Choke. 5,227 stks FCP 830 psi. Mud wt in=12.4 ppg w/12.1 ppg out. SWI and blow down lines to kill tank. - flush kill to tank with fresh water and blow down 2nd round. 4/22/2017 4/22/2017 1.50 MIRU WELCTL RURD P Move fluid around in pits to take light 21:00 22:30 returns. RU cellar to take returns through cmt line to pits. 4/22/2017 4/22/2017 1.00 MIRU WELCTL CIRC P Circulate at 6 bpm @ 2,200 psi 12.4 22:30 23:30 ppg in 12.3+out. needed to bump up wt-shut down and SWI. 4/22/2017 4/23/2017 0.50 MIRU WELCTL COND P Get weight off of Vac truck 12.5 ppg. 23:30 00:00 Begin filling pits with 12.5 fluid. 4/23/2017 4/23/2017 0.50 MIRU WELCTL COND P Continue to take on 12.5 ppg spike 00:00 00:30 fluid. 4/23/2017 4/23/2017 1.00 MIRU WELCTL OWFF P Monitor well for flow-static 00:30 01:30 4/23/2017 4/23/2017 1.00 MIRU WELCTL RURD P Blow down and rig down circulating 01:30 02:30 lines in cellar area. 4/23/2017 4/23/2017 0.25 MIRU WHDBOP MPSP P Tee bar in 3"HP-BPV 02:30 02:45 4/23/2017 4/23/2017 0.25 MIRU WHDBOP SFTY P PJSM on ND of the tree. 02:45 03:00 4/23/2017 4/23/2017 0.50 MIRU WHDBOP OTHR P Cameron checked bleed screw for 03:00 03:30 bleeding off adapter void 4/23/2017 4/23/2017 1.00 MIRU WHDBOP NUND P Nipple Down tree and remove old 03:30 04:30 studs and nuts. 4/23/2017 4/23/2017 1.00 MIRU WHDBOP OTHR P inspect lock down screws,check 3-1/2 04:30 05:30 TBG threads in tbg hanger with X-O. 10 RH turns,Install DSA LDS=2-1/2" IN and 3-1/2"OUT. Page 4/39 Report Printed: 6/1/2017 • • 0 ''' `' Operations Summary (with Timelog Depths) tz .t 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr). Phase _ Op Code: Activity Code Time P-T-X Operation (ftKB); End Depth(ftKB) 4/23/2017 4/23/2017 0.25 MIRU WHDBOP SFTY P Hold PJSM on NU and BWM 05:30 05:45 operations. 4/23/2017 4/23/2017 10.00 MIRU WHDBOP NUND P NU 7-1/16"x 11"5M Adapter spool. 05:45 15:45 NU 11"x13-5/8"DSA,NU Bell Nipple and kill line. Install Blind Rams, Install 3-1/2"x 6"VBR's in UPR's. Obtain RKB measurements,Annular=15.87- ft,UPR's=19.98-ft,Blind Rams= 21.78-ft Mud Cross=24.45-ft,LPR's= 26.82-ft. ULDS=30.30-ft. LLDS= 32.20 and Grd Level=33.28-ft. 4/23/2017 4/23/2017 2.25 MIRU WHDBOP RURD P PJSM,RU test equipment,Function 15:45 18:00 BOPE Rams and Fill BOPE Stack. Shell Test BOPE to 250/3,500 psi. Notify AOGCC ready for test. 4/23/2017 4/23/2017 1.75 MIRU WHDBOP RURD P Change Bladder in#2 on accumalator. 18:00 19:45 Continue to RU TIW Valves and X-O's for BOP test. 4/23/2017 4/24/2017 4.25 MIRU WHDBOP BOPE P 24 hr Notification was given to 19:45 00:00 AOGCC @ 07:45 hrs on 4-19-17. Conduct Initial BOP test at 250/3,500 psi with 3-1/2 and 4"Test joints. Witnessed by Chuck Scheve w/ AOGCC Conduct Tests 1 thru 7 w/3-1/2"Test joint. Test 1 Annular,CM 1, 12, 13, 14. 3"Demco (Secondary Kill line valve in pits) Test 2 Upper Rams(3-1/2 x 6"VBR's),Upper IBOP,HCR Kill and CM 9 and 11 Test 3 Upper Rams(3-1/2 x 6"VBR's),Lower IBOP,Manual Kill Test 4 Upper Rams(3-1/2 x 6"VBR's),CM 4, 6,7 and 4"HT 38 FOSV Test 5 CM 2 and 4"HT-38 Dart Valve Test 6 CM 3 and 3-1/2 EUE FOSV Test 7 Lower Rams(2-7/8 x 5") Page 5/39 Report Printed: 6/1/2017 Operations Summary (with Timelog Depths) 0 i 3M-28 ConocciPhiiilps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)'.:: 4/24/2017 4/24/2017 3.50 MIRU WHDBOP BOPE P 24 hr Notification was given to 00:00 03:30 AOGCC @ 07:45 hrs on 4-19-17. Conduct Initial BOP test at 250/3,500 psi with 3-1/2 and 4"Test joints. Witnessed by Chuck Scheve w/ AOGCC Continue with Test 8 Blinds Conduct Test 9 thru 13 w/4-1/2 Test Joint Test 9 Lower Rams(2-7/8 x 5") Test 10 Upper Rams(3-1/2 x 6"VBR's)and HCR Choke Test 11 Annular and Manual Choke Test 12 Hydraulic Choke(1,500 psi)bleed off Test 13 Adjustable Choke(1,500 psi)bleed off Koomey Draw Down System Pressure 3,100 psi PSI after Closure=1,800 psi 200 PSI Attained =54 seconds Full PSI Attained=192 seconds N2 Bottles AVG=6 @ 2,220 psi 4/24/2017 4/24/2017 1.50 MIRU WHDBOP RURD P RD test equipment and suck fresh 03:30 05:00 water from stack 4/24/2017 4/24/2017 0.50 MIRU WHDBOP MPSP P Verify no pressure below plug and pull 05:00 05:30 test plug with Dry rod. 4/24/2017 4/24/2017 2.50 COMPZN RPCOMP RURD P RU Camco Spooling unit,Doyon 05:30 08:00 Double stack power tongs,3-1/2 YT Elevators. MU 10-ft x 3-1/2 EUE 8rd pup jt to the 30-ft landing joint. Screw into TBG hanger. 4/24/2017 4/24/2017 1.50 COMPZN RPCOMP RURD P Change out bell bolts 08:00 09:30 4/24/2017 4/24/2017 0.50 COMPZN RPCOMP PULL P Un land TBG hanger @ 70k,continue 09:30 10:00 to PU to 140k and pipe pulled free. UP wt=105K,SO wt=68K 4/24/2017 4/24/2017 2.00 COMPZN RPCOMP CIRC P Establish circulation and circulate 500 10:00 12:00 bbl's @ 8 bpm @ 1,540 psi and establish 12.5 ppg in and out. 4/24/2017 4/24/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for flow-static 12:00 12:30 4/24/2017 4/24/2017 4.50 COMPZN RPCOMP PULL P POOH laying down 3-1/2 Tbg and 12,738.0 10,782.0 12:30 17:00 spooling 1980-ft of.25"control line, rercovered 26 of 33 SS bands,from estimated depth of 12,738-ft @ 105k UP wt,68K SO wt. 4/24/2017 4/24/2017 0.50 COMPZN RPCOMP RURD P RD Camco spooling unit and Norm 26 10,782.0 10,782.0 17:00 17:30 SS bands and control line. 4/24/2017 4/25/2017 6.50 COMPZN RPCOMP PULL P Continue to POOH from 10,782-ft to 10,782.0 7,428.0 17:30 00:00 7,428-ft PU wt=75K SO wt=65K Page 6/39 Report Printed: 6/1/2017 • • O;,.. { Operations Summary (with Timelog Depths) t 3M-28 CssnocoPhiHips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/25/2017 4/25/2017 10.00 COMPZN RPCOMP PULL P Continue to POOH from 7,428-ft to 7,428.0 0.0 00:00 10:00 surface and Recovered Cut Joint. Holes in Jts 320,368,and 396.Jts from 318 to 396 had corrosion visible on couplings. Cut jt=14.87-ft of 31.72=16.85-ft left in hole. 4/25/2017 4/25/2017 2.00 COMPZN RPCOMP RURD P Rigged down Tubing tools.Cleared 0.0 0.0 10:00 12:00 Rig Floor and Rigged up to Pick up BHA. 4/25/2017 4/25/2017 1.00 COMPZN RPCOMP BHAH P Moved BHA Components to Rig Floor. 0.0 0.0 12:00 13:00 4/25/2017 4/25/2017 2.50 COMPZN RPCOMP BHAH P Made up BHA#1 (5-3/4 OS and 0.0 309.0 13:00 15:30 Extension with 3-1/2 Grapple)and RIH to 309-ft 4/25/2017 4/26/2017 8.50 COMPZN RPCOMP PULD 'P RIH w/BHA#1 from 309-ft while 309.0 7,004.0 15:30 00:00 picking up(Doyon owned) 212 jts of 4"HT-38 Drill Pipe from the pipe shed to7,004-ft Upwt=115K,SOwt= 75K 4/26/2017 4/26/2017 5.75 COMPZN RPCOMP PULD P RIH w/BHA#1 from 309-ft while 7,004.0 12,691.0 00:00 05:45 picking up(Doyon owned) 4"HT-38 Drill Pipe from the pipe shed from 7,004' to 12,691-ft Up wt=200K, SO wt=75K 4/26/2017 4/26/2017 0.25 'COMPZN RPCOMP CIRC P SPR Pump 1 30 SPM 160 psi.40 12,691.0 12,691.0 05:45 06:00 SPM 300 psi.Pump 2 30 SPM 230 psi,40 SPM 320 psi. 4/26/2017 4/26/2017 2.00 COMPZN RPCOMP CIRC P Circulate 670 bbl's @ 6 bpm @ 2,610 12,691.0 12,691.0 06:00 08:00 psi w/27%F/O,till mud wt was balanced at 12.5 ppg 4/26/2017 4/26/2017 0.75 COMPZN RPCOMP FISH P Engage TOF @ 12,722-ft swallow 12,691.0 12,769.0 08:00 08:45 TBG stub to 12,726-ft,PU 25K OWS of 195K,set back 10k below string wt. Pull 80k over string wt 4X's and pulled seals from PBR @ 12,760-ft 4/26/2017 4/26/2017 1.50 COMPZN RPCOMP CIRC P Circulate 440 bbl @ 6 bpm @ 1,570 12,760.0 12,760.0 08:45 10:15 psi with 27%F/O Mud wt In=12.5 ppg and Mud Wt out=12.6 ppg 4/26/2017 4/26/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow-Static 12,760.0 12,760.0 10:15 10:30 4/26/2017 4/26/2017 0.50 COMPZN RPCOMP CIRC P Pump 30 bbl 13 ppg dry job @ 6 bpm 12,760.0 12,760.0 10:30 11:00 @ 1,250 psi and chase with 14 bbls of 12.5 ppg to clear surface lines. Blow down Top Drive. 4/26/2017 4/26/2017 6.00 COMPZN RPCOMP TRIP P PJSM,POOH from 12,760-ft to 309-ft 12,760.0 309.0 11:00 17:00 4/26/2017 4/26/2017 0.25 COMPZN RPCOMP OWFF P Monitor well for flow in preparation to 309.0 309.0 17:00 17:15 pull BHA 4/26/2017 4/26/2017 1.75 COMPZN RPCOMP BHAH P Pull Fishing BHA#1 and recovered 309.0 0.0 17:15 19:00 16.85-ft of 3-1/2 TBG stub,6.07-ft of 3 -1/2 TBG pup jt,and 12.80-ft of 80-40 seal assembly. Along with 1 SS Band. approximately 6 SS bands remain. Break down overshot and lay down. Clear and clean rig floor. Bring BHA #2 components to rig floor. Page 7/39 Report Printed: 6/1/2017 • S w Operations Summary (with Timelog Depths) 0 3M-28 Ccrnoccyy i /hips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/26/2017 4/26/2017 1.00 COMPZN RPCOMP BHAH P MU BHA#2(3-1/4"Itco Spear w/ 0.0 309.0 19:00 20:00 3.947"Grapple)and RIH to 309.93-ft 4/26/2017 4/27/2017 4.00 COMPZN RPCOMP TRIP P Continue to RIH w/BHA from 309-ft to 309.0 8,364.0 20:00 00:00 8,364-ft PU wt=138K,SO wt=65K 4/27/2017 4/27/2017 2.50 COMPZN RPCOMP TRIP P Continue to RIH w/Fishing BHA#2 8,364.0 12,629.0 00:00 02:30 from 8,364-ft to 12,629-ft UP wt= 205K SO wt=75K 4/27/2017 4/27/2017 2.50 COMPZN RPCOMP SLPC P Slips and cut 66-ft of 1-1/8"Drill line. 12,629.0 12,629.0 02:30 05:00 Service draw works and brakes. Inspect HT-38 savor sub. Adjust Crown o Matic. 4/27/2017 4/27/2017 0.50 COMPZN RPCOMP TRIP P RIH from 12,629-ft to 12,740-ft UP wt 12,629.0 12,740.0 05:00 05:30 =205K SO wt=75K Estimated PBR @ 12,746-ft. 4/27/2017 4/27/2017 1.00 COMPZN RPCOMP CIRC P Circulate and condition hole @ 8 bpm 12,740.0 12,740.0 05:30 06:30 @ 3,100 psi with 30%return flow MW in 12.5 ppg MW out 12.5 ppg 4/27/2017 4/27/2017 0.50 COMPZN RPCOMP CIRC P Obtain Parameters: UP wt=195K, 12,740.0 12,740.0 06:30 07:00 SO wt=75K SPR's @ 12,740-ft MD,5936-ft TVD MW=12.5 PPG OA PSI=240 PSI MP#1 30/40 SPM=920/1140 PSI MP#2 30/40 SPM=880/1160 PSI 4/27/2017 4/27/2017 0.50 COMPZN RPCOMP FISH P Wash down from 12,740-ft to top of 12,740.0 12,783.0 07:00 07:30 packer at 12,745-ft,continue to engage spear to 12,783-ft and set down 10K. Pull 55k OSW of 195K and fire off jars,re-set jars and Pull 60K OSW,Set jars off and straight pull to 300K -Packer pulled free. Circulate while running in the hole. Monitor well for flow for 5minutes- static. 4/27/2017 4/27/2017 1.50 COMPZN RPCOMP CIRC P Circulate 740 bbl's at 8 bpm @ 3,600 12,783.0 12,783.0 07:30 09:00 psi with 30%return flow, MW in= 12.4+ppg MW out=12.4+ppg. 4/27/2017 4/27/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for flow for 15 minutes - 12,783.0 12,783.0 09:00 09:30 Static. Pump 30 bbl dry job with 13.0 ppg Spike fluid. Blow down Top Drive. 4/27/2017 4/27/2017 6.50 COMPZN RPCOMP JAR P PJSM,Prepare to POOH and Pulled 12,783.0 12,783.0 09:30 16:00 over 55k and set jars off. Continue to jar on Packer -Not able to jar free. Circulate while attempting to work packer free and seen 2705 units of gas at surface. Continue to attempt to work packer free. 4/27/2017 4/27/2017 1.00 COMPZN RPCOMP OTHR P Conduct post jarring derrick inspection 12,783.0 12,783.0 16:00 17:00 while circulating @ 7 bpm at 2,980 psi with 29%return flow 4/27/2017 4/27/2017 1.00 COMPZN RPCOMP JAR P Continue to Attempt to jar packer free 12,783.0 12,783.0 17:00 18:00 at 115K OSW with 180K straight over pull of 195K. Pulled free with 7K drag 4/27/2017 4/27/2017 1.00 COMPZN RPCOMP CIRC P Circulate 363 bbls @ 8 bpm @ 3,600 12,783.0 12,723.0 18:00 19:00 psi with 29%return flow. Complete Post jarring inspection. Page 8/39 Report Printed: 6/1/2017 s • `w' Operations Summary (with Timelog Depths) .3 3M-28 co hill®ps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code. Time P-T X Operation (ftK6) End Depth(ftKB) 4/27/2017 4/27/2017 0.50 COMPZN RPCOMP OWFF T Monitor well for 15 minutes -static. 12,723.0 12,723.0 19:00 19:30 Pump 24 BBL 13.0 ppg Dry Job and chase with 14 bbl. Blow down Top drive. 4/27/2017 4/27/2017 2.00 COMPZN RPCOMP TRIP T POOH from 12,723-ft to 11,870-ft 12,723.0 11,870.0 19:30 21:30 while monitoring via Trip tank. PU wt 225K. Calculated displacement for 10 stds=5 bbls and actual was 3 bbls. - Calc hole fill 2.7 bbls per 5 stds.shy by 1.5 bbls 1 st 5 stds and 1.0 bbl 2nd 5 stds. 4/27/2017 4/27/2017 0.50 COMPZN RPCOMP CIRC T PJSM,Bull head 5 bbl's down IA at 1 11,870.0 11,870.0 21:30 22:00 bpm @ 2390 psi -let sit. Lost 200 psi in 10 minutes. Bleed back and recover 2.75 bbl's -blow down kill line. 4/27/2017 4/27/2017 1.00 COMPZN RPCOMP TRIP T Run back in hole with 5 stands to 11,870.0 12,250.0 22:00 23:00 12,250-ft with 3.9 bbl displacement 4/27/2017 4/28/2017 1.00 COMPZN RPCOMP CIRC T Circulate 342 bbl's @ 4 bpm @ 1180 12,250.0 12,250.0 23:00 00:00 psi with 20%return flow. Mud wt In= 12.3+Mud wt out=12.3 ppg. 4/28/2017 4/28/2017 0.50 COMPZN RPCOMP CIRC T Continue circulate @ 4 bpm @ 1340 12,250.0 12,250.0 00:00 00:30 psi with 20%return flow. Mud wt In= 12.3+Mud wt out=12.3 ppg. 4/28/2017 4/28/2017 0.50 COMPZN RPCOMP COND T Monitor well for flow via trip tank while 12,250.0 12,250.0 00:30 01:00 conditioning pits from 12.3+ ppg to 12.5 ppg 4/28/2017 4/28/2017 2.00 COMPZN RPCOMP CIRC T Circulate surface to surface with 12.5 12,250.0 12,250.0 01:00 03:00 ppg MW @ 4 bpm @ 1340 psi with 19%return flow 4/28/2017 4/28/2017 0.25 COMPZN RPCOMP OWFF T Monitor well for flow-Static, Blow 12,250.0 12,250.0 03:00 03:15 down Top drive. 4/28/2017 4/28/2017 1.00 COMPZN RPCOMP TRIP T POOH w/5 stands w/o hole fill from 12,250.0 11,776.0 03:15 04:15 12,250-ft to 11,776-ft. Took 2 of 2.7 bbl's to fill hole. Pulled 1 more stand and swabbed back 1.7 bbls. 4/28/2017 4/28/2017 0.75 COMPZN RPCOMP TRIP T RIH from 11,776-ft to 12,723-ft 11,776.0 12,723.0 04:15 05:00 4/28/2017 4/28/2017 1.00 COMPZN RPCOMP WASH T Circulate and reciprocate at 4 bpm @ 12,723.0 12,723.0 05:00 06:00 1300 psi from 12,628-ft to 12,723-ft. 4/28/2017 4/28/2017 5.50 COMPZN RPCOMP PMPO T Pump out of the hole @ 3 bpm @ 750 12,723.0 10,354.0 06:00 11:30 psi while pulling at a rate of 6-ft per minutes. With 5 Stds out 11.8 bbl's over displacement.Continue to Pump out of the hole while slowing pump rate and increasing trip rate to minimize the losses from 12,273-ft to 10,354-ft. 4/28/2017 4/28/2017 0.75 COMPZN 'RPCOMP OWFF T Moniutor well for flow for 10 minutes- 10,354.0 10,354.0 11:30 12:15 Static. Strap all pits while circulating @ 1.5 bpm @ 500 psi. 4/28/2017 4/28/2017 8.25 COMPZN RPCOMP PMPO T Continue to Pump out of the hole from 10,354.0 5,521.0 12:15 20:30 10,354-ft to 5521-ft @ 1.5 bpm @ 450 psi Page 9/39 Report Printed: 6/1/2017 • • 0 „ Operations Summary (with Timelog Depths) Int 3M-28 Conocx Phitiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/28/2017 4/29/2017 3.50 COMPZN RPCOMP TRIP T POOh on elevators from 5521-ft to 5,521.0 309.0 20:30 00:00 309-ft monitoring hole fill via trip tank -Cal=2.8 Actual=3.2 bbl's per 5 Stds. 53.8 BBIs total losses to formation today. Accumulative losses=83.8 bbl's 4/29/2017 4/29/2017 0.25 COMPZN RPCOMP OWFF T Monitor well for flow @ BHA-Static 309.0 309.0 00:00 00:15 4/29/2017 4/29/2017 2.25 COMPZN RPCOMP BHAH T POOH with BHA#2 from 309-ft. 309.0 0.0 00:15 02:30 Recovered 13.34-ft PBR,and 2.38-ft of the FHL Packer mandrel. Parted at Wicker thread and bottle necked down to 2-15/16"on ID. Pictures are in the well folder on the S drive. Lay down fish and fishing tools. Clean and clear rig floor. 4/29/2017 4/29/2017 1.75 COMPZN RPCOMP OTHR T Notify town engr. Discuss options. 0.0 0.0 02:30 04:15 4/29/2017 4/29/2017 1.00 COMPZN RPCOMP BHAH T PU,MU Fishing BHA#3 with tools on 0.0 0.0 04:15 05:15 location,waiting for mill assemebly and spear to arrive. 4/29/2017 4/29/2017 3.75 COMPZN RPCOMP WAIT T Waited on Mills to Mill up Packer. 0.0 0.0 05:15 09:00 4/29/2017 4/29/2017 1.00 COMPZN RPCOMP BHAH T Made up Mills on BHA. 0.0 317.0 09:00 10:00 4/29/2017 4/29/2017 3.50 COMPZN RPCOMP TRIP T RIH from 317'to 5,695'Drill Pipe Over 317.0 5,695.0 10:00 13:30 Flowing, Monitor well static-MW out -11.9+ppg MW in 11.9 ppg 4/29/2017 4/29/2017 0.50 COMPZN RPCOMP CIRC T Pump 20 bbl's of 12.6 ppg @ 5 bpm 5,695.0 5,695.0 13:30 14:00 @ 710 PSI with 22% return Blow Down Top drive 4/29/2017 4/29/2017 4.00 COMPZN RPCOMP TRIP T Continue to RIH f/5,695-ft to 12,731- 5,695.0 12,731.0 14:00 18:00 ft. Monitor well displacement by TT. UP wt-195K,SO wt-80K Cal.Displacement=78.41 bbl's Actual Displacement-74.75 bbls,Lost 3.6 bbls during trip 4/29/2017 4/29/2017 3.50 COMPZN RPCOMP CIRC T Circulate and reciprocate @ 8 bpm @ 12,731.0 12,731.0 18:00 21:30 2,660 psi from 12,774-ft to 12,745-ft while ROT @ 91 rpm's @ 106K ROT wt. 15 minute mud checks Mud wt in 12.3+PPG and out 12.2 PPG,Mud wt in 12.5+PPG and out 12.6 PPG,Mud wt in 12.3+PPG and out 12.3 PPG,Mud wt in 12.6+PPG and out 12.9 PPG, Mud wt in 12.5+PPG and out 12.4 PPG, 4/29/2017 4/29/2017 0.25 COMPZN RPCOMP CIRC T Obtain Parameters: UP wt=225K, 12,731.0 12,731.0 21:30 21:45 SOwt=65K SPR's @ 12,731-ft MD,5954-ft TVD MW=12.5 PPG OA PSI=560 PSI MP#1 30/40 SPM=920/1100 PSI MP#2 30/40 SPM=900/1120 PSI Page 10/39 Report Printed: 6/1/2017 • • ` Operations Summary (with Timelog Depths) 0 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 4/29/2017 4/30/2017 2.25 COMPZN RPCOMP MILL T Wash down from 12,731-ft to 12,785- 12,731.0 12,786.0 21:45 00:00 ft. Circulating at 3 bpm @ 950 psi. Come on line with Rotary @ 90 rpm @ 16.8K free torque. ROT wt=106K. Begin rotating on FHL packer attempting free up and chase down hole. Tag up 12,785-ft and clean out to 12,786-ft as of 23:00 hrs. With 34 bbl loss. 4/30/2017 4/30/2017 3.00 COMPZN RPCOMP MILL T Mill on Pkr from 12,785-ft to 12,786-ft 12,786.0 12,823.0 00:00 03:00 while Circulating at 3 bpm @ 950 psi. Come on line with Rotary @ 90 rpm @ 16.8K free torque. ROT wt=106K. Begin rotating on FHL packer attempting free up and chase down hole with 48 bbl loss,Broke free and chase to 12,823-ft. 4/30/2017 4/30/2017 1.00 COMPZN RPCOMP CIRC T Circulate bottoms up @ 8 bpm @ 12,823.0 12,823.0 03:00 04:00 2008 psi and reciprocate while rotating @ 90 rpm with 14.8 Free torque. 4/30/2017 4/30/2017 0.25 COMPZN RPCOMP OWFF T OWFF Static. 12,823.0 12,823.0 04:00 04:15 4/30/2017 4/30/2017 0.75 COMPZN RPCOMP WASH T Washed down pushing Packer from 12,823.0 12,970.0 04:15 05:00 12,731'to 12,927'3 BPM 970 psi. 4/30/2017 4/30/2017 1.00 COMPZN RPCOMP TRIP T POOH with pump 1.5 BPM 590 psi 12,970.0 12,541.0 05:00 06:00 from 12,970'to 12,541'UW 210K 4/30/2017 4/30/2017 1.00 COMPZN RPCOMP TRIP T POOH with pump 1.5 BPM 590 psi 12,541.0 12,447.0 06:00 07:00 from 12,541'to 12,447'UW 200K 4/30/2017 4/30/2017 0.25 COMPZN RPCOMP SVRG T Service top drive 12,447.0 12,447.0 07:00 07:15 4/30/2017 4/30/2017 14.50 COMPZN RPCOMP TRIP T POOH with pump 1.5 BPM 590 psi 12,447.0 349.0 07:15 21:45 FCP 190 from 12,447'to 349' 4/30/2017 4/30/2017 0.25 COMPZN RPCOMP OWFF T Monitor well for 15 minutes-static 349.0 349.0 21:45 22:00 4/30/2017 5/1/2017 2.00 COMPZN RPCOMP BHAH T POOH w/BHA#3,clean boot baskets 349.0 0.0 22:00 00:00 -recover 15 lbs of metal shavings. Clear and clean rig floor 5/1/2017 5/1/2017 0.50 COMPZN RPCOMP BHAH T Clear Rig Floor. 0.0 0.0 00:00 00:30 5/1/2017 5/1/2017 1.00 COMPZN RPCOMP BHAH T Washing mud off Rig Floor from Wet 0.0 0.0 00:30 01:30 Trip. 5/1/2017 5/1/2017 1.50 COMPZN RPCOMP RGRP T Changed Dies in Pipe Grabber on Top 0.0 0.0 01:30 03:00 Drive. 5/1/2017 5/1/2017 0.50 COMPZN WHDBOP RURD T Pumped out Stack for BOP Test. 0.0 0.0 03:00 03:30 5/1/2017 5/1/2017 0.50 COMPZN WHDBOP RURD T Pulled Wear Bushing. 0.0 0.0 03:30 04:00 5/1/2017 5/1/2017 3.00 COMPZN WHDBOP RURD T Set Test Plug and RU to test BOP. 0.0 0.0 04:00 07:00 Fill stack and choke with fresh water. Page 11/39 Report Printed: 6/1/2017 O 0 0 Operations Summary (with Timelog Depths) 3M-28 Cc nacrs hitlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 5/1/2017 5/1/2017 7.00 COMPZN WHDBOP BOPE T 24 Hr Notice was give to AOGCC at 0.0 0.0 07:00 14:00 13:56 hrs on 4-30-17 and witness was waived by Brian Bixby at 14:18 on 4- 30-17. 1.Lower rams with 4"Test Jt. 2.Annular,Valves 12,13,14,Upper IBOP,3"Demco 3.Upper pipe rams Valves 9,11,Lower IBOP,Kill HCR Valve 4.Valves 5,8,10,4"HT-38 FOSV, Manual Kill 5.CM Valves 4,6,7,4"HT-38 Dart 6.Valve 2,3-1/2"8rd FOSV 7.Blinds,Valve 1,3 8.Lower Rams with 3-1/2"test Jt. 9.Annular,Choke HCR 10.Upper Rams,Manual Choke Koomey Draw Down System Pressure 3,050 psi PSI after Closure=1,800 psi 200 PSI Attained =47 seconds Full PSI Attained=190 seconds N2 Bottles AVG=6 @ 2,150 psi 5/1/2017 5/1/2017 6.00 COMPZN WHDBOP BOPE T Change out lower IBOP and savor 0.0 0.0 14:00 20:00 sub. Wire tie Tq ring and install 5"Bell Guide Retest LOWER IBOP RETEST @ 250/3500 psi-Good Test 5/1/2017 5/1/2017 0.50 COMPZN WHDBOP RURD T RD test equipment,BLow down choke 0.0 0.0 20:00 20:30 and kill lines. Remove Fresh water from BOP stack. 5/1/2017 5/1/2017 0.50 COMPZN WHDBOP RURD T Pull test plug and install 6-5/16"Wear 0.0 0.0 20:30 21:00 ring,RILDS 5/1/2017 5/1/2017 0.50 COMPZN RPCOMP BHAH T PU,MU and RIH w/BHA#4(Spear w/ 0.0 309.0 21:00 21:30 3.001"grapple)to 309-ft 5/1/2017 5/2/2017 2.50 COMPZN RPCOMP TRIP T RIH w/BHA#4 from 309-ft to 3,152-ft 309.0 3,152.0 21:30 00:00 UP wt=80K,DN wt=65K filling pipe every 20 stands. 5/2/2017 5/2/2017 6.00 COMPZN RPCOMP TRIP T Continue to TIH with BHA#4-spear 3,152.0 11,207.0 00:00 06:00 assembly from 3152'MD to 11207' MD(PU=185K and SO=75K)filling the DP every 20 stands. Actual fill 69 bbls-Calculated fill 66.6 bbls=2.4 bbl.loss. Page 12/39 Report Printed: 6/1/2017 • i =' Operations Summary (with Timelog Depths) 3M-28 C:orioco hitbps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/2/2017 5/2/2017 1.50 COMPZN RPCOMP TRIP T Continue to TIH from 11207'MD to 11,207.0 12,818.0 06:00 07:30 12818'MD(PU=210K and SO= 80K)filling the DP every 20 stands. Actual fill 69 bbls-Calculated fill 66.6 bbls=2.4 bbl.loss. 5/2/2017 5/2/2017 0.50 COMPZN RPCOMP WASH T Circulate and wash down from 12818' 12,818.0 12,912.0 07:30 08:00 MD to 12912'MD at 5 BPM=3390 psi. 5/2/2017 5/2/2017 1.00 COMPZN RPCOMP CIRC T Circulate and condition the mud to 12,912.0 12,912.0 08:00 09:00 12.5 ppg in/out at 5 BPM=3690 psi while reciprocating the DP 30'. 5/2/2017 5/2/2017 0.25 COMPZN RPCOMP OWFF T Observe the well for flow for 10 12,912.0 12,912.0 09:00 09:15 minutes and the well is static. Blown down the top drive. 5/2/2017 5/2/2017 1.75 COMPZN RPCOMP SLPC T While monitoring the well on the trip 12,912.0 12,912.0 09:15 11:00 tank slip and cut 54'of drilling line. 5/2/2017 5/2/2017 0.50 COMPZN RPCOMP SVRG T Service the top drive and calibrate the 12,912.0 12,912.0 11:00 11:30 block height. 5/2/2017 5/2/2017 1.50 COMPZN RPCOMP FISH T PU and MU working joint of DP from 12,912.0 12,881.0 11:30 13:00 the pipe shed. Obtain fishing parameters. Pump#1 SPR: 3 BPM= 1820 psi and 4 BPM=2700 psi. Pump#2 SPR:3 BPM=1760 psi and 4 BPM=2680 psi. With the pumps on at 4 BPM=2510,PU=190K and SO =80K. With the pumps off PU=210K and SO 83K. SO with the pumps on at 4 BPM to tag at 12923'MD with 7K down. Slow the pumps down to 1 BPM=840 psi,engage the grapple, pull 25K over several times,and the fish was free. Lay down work joint of drill pipe. 5/2/2017 5/2/2017 1.50 COMPZN RPCOMP CIRC T Check SPR at 3 BPM and pressure 12,881.0 12,881.0 13:00 14:30 increased to 2150 psi. Circulate bottoms up at 3 BPM=2160 psi staging the pumps up to 4 BPM= 3350 psi. 5/2/2017 5/2/2017 0.50 COMPZN RPCOMP OWFF T Observe the well for flow for 30 12,881.0 12,881.0 14:30 15:00 minutes and the well is static. 5/2/2017 5/3/2017 9.00 COMPZN RPCOMP PMPO P Pump out of the hole standing back 12,881.0 7,266.0 15:00 00:00 the DP at 1 BPM=930 psi from 12881'MD to 7266'MD at midnight. 5/3/2017 5/3/2017 9.50 COMPZN RPCOMP PMPO P Continue to pump out of the hole 7,266.0 310.0 00:00 09:30 standing back the DP at 1 BPM=930 psi from 7266'MD to 310'MD. 5/3/2017 5/3/2017 3.00 COMPZN RPCOMP BHAH P Lay down the crossover and 310.0 0.0 09:30 12:30 intensifier. Rack back three stands of 4-3/4"DCs. Lay down recovered packer with spear assembly 5/3/2017 5/3/2017 1.50 COMPZN RPCOMP BHAH P Clean and clear the rig floor. Send 0.0 0.0 12:30 14:00 Baker fishing tools off the rig floor. 5/3/2017 5/3/2017 1.00 COMPZN RPCOMP RURD P Bring the completion running 0.0 0.0 14:00 15:00 equipment to the rig floor. 5/3/2017 5/3/2017 0.50 COMPZN RPCOMP RURD P MU wear ring pulling tool to a joint of 0.0 0.0 15:00 15:30 DP,pull the wear ring,and RD the wear ring pulling tool. 5/3/2017 5/3/2017 2.50 COMPZN RPCOMP RURD P RU 3-1/2"tubing elevators and power 0.0 0.0 15:30 18:00 tubing tons. Page 13/39 Report Printed: 6/1/2017 • • 0 Operations Summary (with Timelog Depths) 1. 3M-28 conoccP'hitilps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code. Activity Code Time P-T-X Operation (ftKB)'. z End Depth(ftKB) 5/3/2017 5/3/2017 1.50 COMPZN RPCOMP RURD P Bring the tubing hanger,two 10'pups 0.0 0.0 18:00 19:30 and nipple to the rig floor. Count the tubing in the pipe shed and place the jewelry in running order. 5/3/2017 5/3/2017 0.25 COMPZN RPCOMP SFTY P PJSM for running completion with rig 0.0 0.0 19:30 19:45 crew,Doyon pipe running services, and Baker. 5/3/2017 5/3/2017 0.75 COMPZN RPCOMP PUTB P PU and MU mule shoe and tandem 0.0 196.0 19:45 20:30 wedges assemblies. RIH on 3-1/2" EUE 8d tubing to had tag at 196'MD. Attempted to work past tight spot but were unsuccessful. 5/3/2017 5/3/2017 0.50 COMPZN RPCOMP WAIT X Notified town engineer and discussed 196.0 196.0 20:30 21:00 options. 5/3/2017 5/3/2017 0.50 COMPZN RPCOMP PULL X POOH and lay down 3-1/2"tubing and 196.0 0.0 21:00 21:30 tandem wedge assemblies. 5/3/2017 5/3/2017 0.50 COMPZN RPCOMP RURD X Wash off and RD the 3-1/2"power 0.0 0.0 21:30 22:00 tongs and elevators. 5/3/2017 5/3/2017 0.50 PROD1 WELLPR RURD X Mobilize drift assembly to the rig floor. 0.0 0.0 22:00 22:30 5/3/2017 5/3/2017 0.50 PROD1 WELLPR RURD X MU wear ring running tool to a joint of 0.0 0.0 22:30 23:00 DP,install the wear ring,and lay down the wear ring running tool and joint of DP. 5/3/2017 5/4/2017 1.00 PROD1 WELLPR BHAH X PU and MU BHA#5-drift assembly 0.0 187.0 23:00 00:00 and tagged at 187'MD with 5K down. 5/4/2017 5/4/2017 0.25 PROD1 WELLPR BHAH X Lay down 1 DC. PU and MU working 187.0 180.0 00:00 00:15 joint of 4"DP with crossover. 5/4/2017 5/4/2017 0.75 PROD1 WELLPR MILL X Obtain parameters. PU=45K,SO= 180.0 218.0 00:15 01:00 50K,Rotating weight at 60 RPM= 45K,and free torque=0 ft-lbs. Work tight spot from 187'to 218'MD at 5 BPM=200 psi,60 RPM,4-5K down, and torque=3-4K ft-lbs. 5/4/2017 5/4/2017 1.50 PROD1 WELLPR MILL X Turn off the pumps and stop rotating. 218.0 180.0 01:00 02:30 Attempt to drift through tight spot but still unable to get past 187'MD. Continue to work the tight spot from 187'to 218'MD at 5 BPM=200 psi, 60 RPM,4-5K down,and torque=3- 4K ft-lbs. 5/4/2017 5/4/2017 0.25 PROD1 WELLPR TRIP X Turn off the pumps and stop rotating. 180.0 187.0 02:30 02:45 Attempt to drift through tight spot but still unable to get past 187'MD. Discuss options with Baker Fishing shop. 5/4/2017 5/4/2017 0.75 PROD1 WELLPR TRIP X Rotate through tight spot to 216'MD 187.0 874.0 02:45 03:30 continue to RIH taking 5K on the first stand and then TIH to 874'MD on elevators with no indication of tight spots. 5/4/2017 5/4/2017 0.50 PROD1 WELLPR TRIP X TOOH with BHA#5-drift assembly 874.0 187.0 03:30 04:00 from 874'to 187'MD. Had to rotate the string mill through the tight spot. 5/4/2017 5/4/2017 1.25 PROD1 WELLPR BHAH X Lay down BHA#5. 187.0 0.0 04:00 05:15 5/4/2017 5/4/2017 0.75 PROD1 WELLPR BHAH X PU and MU BHA#6-drift assembly 0.0 143.0 05:15 06:00 #2. RIH 1 stand of DP to 143'MD. Page 14/39 Report.Printed: 6/1/2017 • • 0"' Operations Summary (with Timelog Depths) 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/4/2017 5/4/2017 1.00 PROD1 WELLPR TRIP X Continue to TIH with BHA#6 from 143.0 48.0 06:00 07:00 143'MD to tag at 187'MD with 5 K down. POOH with BHA#6. 5/4/2017 5/4/2017 0.50 PROD1 WELLPR BHAH X Lay down BHA#6-drift assembly#2 48.0 0.0 07:00 07:30 5/4/2017 5/4/2017 0.25 PROD1 WELLPR BHAH X PU and MU BHA#7- stack washer 0.0 5.0 07:30 07:45 assembly(largest OD=4-15/16"). 5/4/2017 5/4/2017 0.50 PROD1 WELLPR TRIP X TIH with BHA#7 to 226'MD with no 5.0 5.0 07:45 08:15 indication of the tight spot. TOOH with BHA#7. 5/4/2017 5/4/2017 0.25 PROD1 WELLPR BHAH X Lay down BHA#7- stack washer 5.0 0.0 08:15 08:30 assembly(largest OD=4-15/16"). 5/4/2017 5/4/2017 0.50 PROD1 WELLPR SVRG XT RU to change out upper IBOP,gather 0.0 0.0 08:30 09:00 tools,and pup joint. 5/4/2017 5/4/2017 0.50 PROD1 WELLPR BHAH X PU and MU BHA#8-tandem string 0.0 15.0 09:00 09:30 mill assembly. 5/4/2017 5/4/2017 0.50 PROD1 WELLPR TRIP X TIN with BHA#8 to tag at 187'MD 15.0 15.0 09:30 10:00 with 5K down,set 10K down to 190' MD. PU with minimal drag and TOOH. 5/4/2017 5/4/2017 0.50 PROD1 WELLPR BHAH X Lay down BHA#8-tandem string mill 15.0 0.0 10:00 10:30 assembly. 5/4/2017 5/4/2017 2.50 PROD1 WELLPR WAIT X Wait for RBP's to arrive from 0.0 0.0 10:30 13:00 Deadhorse. SimOps: Clean and clear the rig floor. Inspect the top drive. Check the accumulators pressures. Found one bad accumulator. Bleed the pressure off the top drive and lock out/tag out the top drive. Change out the bad accumulator. Finish top drive inspection. 5/4/2017 5/4/2017 4.00 PROD1 WELLPR WAIT X Continue to wait for RBP's to arrive 0.0 0.0 13:00 17:00 from Deadhorse. SimOps:Continue to clean the rig floor and organize the lockers. 5/4/2017 5/4/2017 1.50 PROD1 WELLPR RURD X RBP's on location. Bring the RBP's to 0.0 0.0 17:00 18:30 the rig floor and check the equipment. 5/4/2017 5/4/2017 0.50 PROD1 WELLPR BHAH X PJSM. PU and MU Model G Lock-set 0.0 20.0 18:30 19:00 RBP. 5/4/2017 5/5/2017 5.00 PROD1 WELLPR TRIP X TIH with RBP(it took 3K to get the 20.0 5,326.0 19:00 00:00 RBP past 187'MD)to 5326'MD at midnight(PU= 100K and SO=70K). 5/5/2017 5/5/2017 5.50 PROD1 WELLPR TRIP X Continue to TIH with Model G Lock- 5,326.0 12,650.0 00:00 05:30 set RBP from 5326'to 12650'MD(PU =200K and SO=80K). 5/5/2017 5/5/2017 0.25 PROD1 WELLPR CIRC X Line up and break circulation. 12,650.0 12,650.0 05:30 05:45 5/5/2017 5/5/2017 0.25 PROD1 WELLPR MPSP X Set the G Lock-set RBP at 12650'MD 12,650.0 12,615.0 05:45 06:00 (center of element). Release from RBP and stand back 1 stand to 12615' MD. 5/5/2017 5/5/2017 1.00 PROD1 WELLPR RURD X RU test equipment and purge lines 12,615.0 12,615.0 06:00 07:00 free of air. 5/5/2017 5/5/2017 1.00 PROD1 WELLPR PRTS X Pressure up on the DP and IA to 1000 12,615.0 12,615.0 07:00 08:00 psi(took 20 strokes and 2 bbls to pressure up)for 30 minutes-good test. Bleed the pressure off(bleed back 2.5 bbls). OA pressure remained at 30 psi during the test. Page 15/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) , .,'''Z 0 3M-28 r cd hillips t�xeka Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time p-T-X Operation (EKB) End Depth(ftKB) 5/5/2017 5/5/2017 0.50 PROD1 WELLPR RURD X RD and blow down testing equipment. 12,615.0 12,615.0 08:00 08:30 5/5/2017 5/5/2017 4.00 PROD1 WELLPR CIRC X Obtain circulating parameter: PU= 12,615.0 12,615.0 08:30 12:30 192K,SO=83K,and rotating weight= 104K. Circulate and condition the well to 12.5 ppg WBM at 8 BPM=2400 psi while rotating at 40 RPM= 11K ft-lbs free torque and reciprocating the DP 90'. Increased the pump rate to 11.2 BPM=3400 psi and increase rotation to 60 RPM. SimOps: Line up the OA to the cutting box and open the OA to the cutting box to allow the OA to vent. 5/5/2017 5/5/2017 0.50 PROD1 WELLPR OWFF X Observe the well for flow for 30 12,615.0 12,615.0 12:30 13:00 minutes and the well is static. SimOps: Lay down working joint of DP,blow down the top drive,and line up to the trip tank. 5/5/2017 5/5/2017 2.00 PROD1 WELLPR TRIP X TOOH on elevators from 12615'to 12,615.0 9,771.0 13:00 15:00 9771'MD(PU=210K and SO=70K). 5/5/2017 5/5/2017 0.50 PROD1 WELLPR SFTY X Kick while tripping drill. Crew 9,771.0 9,771.0 15:00 15:30 response time 169 seconds. Conducted AAR. 5/5/2017 5/5/2017 1.00 PROD1 WELLPR TRIP X Continue to TOOH on elevators from 9,771.0 8,338.0 15:30 16:30 9771'to 8338'MD(PU=155K and SO=60K). 5/5/2017 5/5/2017 0.50 PROD1 WELLPR RURD X Bring the storm packer to the rig floor 8,338.0 8,338.0 16:30 17:00 and inspect. 5/5/2017 5/5/2017 0.25 PROD1 WELLPR BHAH X PU and MU the storm packer with 8,338.0 8,338.0 17:00 17:15 crossovers. 5/5/2017 5/5/2017 0.50 PROD1 WELLPR MPSP X RIH with the storm packer to 95'MD 8,338.0 8,338.0 17:15 17:45 (PU=135K and SO=73K). Make a 1/2 turn to the left,SO,and set the storm packer. Attempt to release from the storm packer but unable to. Release the storm packer and POOH to inspect. 5/5/2017 5/5/2017 0.75 PROD1 WELLPR OTHR XT Inspected the storm packer and found 8,338.0 8,338.0 17:45 18:30 the twin thread safety joint torqued up. Replace the shear screws in the equalizing valve. 5/5/2017 5/5/2017 0.50 PROD1 WELLPR MPSP X MU the storm packer,RIH,and set the 8,338.0 0.0 18:30 19:00 storm packer at 103'MD(center of element). Release from the storm packer,POOH and lay down the twin thread safety joint. 5/5/2017 5/5/2017 0.50 PROD1 WELLPR PRTS X RU to PT. PT the storm packer to 0.0 0.0 19:00 19:30 1000 psi for 10 minutes(good test). 5/5/2017 5/5/2017 2.50 PROD1 WELLPR NUND X PJSM. Drain the BOP stack. Blow 0.0 0.0 19:30 22:00 down the kill,choke,and hole fill. ND the BOP stack and set back on the stump. ND the 11"x 7-1/16"DSA. Pull the wear ring. 5/5/2017 5/5/2017 1.50 PROD1 WELLPR NUND X PJSM. ND the IA valve on the tubing 0.0 0.0 22:00 23:30 spool. BOLDS. Break every other nut on the tubing spool with the nut splitter and remover. Loosen the remaining bolts and remove. No casing growth. Remove the tubing spool. Page 16/39 Report Printed: 6/1/2017 • • =' Operations Summary (with Timelog Depths) 0 < 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/5/2017 5/6/2017 0.50 PROD1 WELLPR BHAH X PU and MU the 7"casing spear. 0.0 0.0 23:30 00:00 5/6/2017 5/6/2017 0.25 PROD1 WELLPR BHAH X Finish MU the 7"casing spear and 0.0 0.0 00:00 00:15 crossovers. 5/6/2017 5/6/2017 1.75 PROD1 WELLPR CUTP X Spear the 7"casing and PU to 275K to 0.0 0.0 00:15 02:00 remove the 7"casing slips/pack-off. Stretched the casing 11-1/2". SO to 235K,install the new slips/pack-off, land the 7"casing with 50K in the slips and RILDS. 5/6/2017 5/6/2017 1.25 PROD1 WELLPR CUTP X PJSM. RU the Wachs cutter and cut 0.0 0.0 02:00 03:15 off the excess 11-1/2"of casing. 5/6/2017 5/6/2017 0.25 PROD1 WELLPR RURD X Bring the new tubing spool into the 0.0 0.0 03:15 03:30 cellar 5/6/2017 5/6/2017 1.25 PROD1 WELLPR NUND X NU the new tubing spool. 0.0 0.0 03:30 04:45 5/6/2017 5/6/2017 0.25 PROD1 WELLPR PRTS X PT pack-off and void to 3000 psi for 0.0 0.0 04:45 05:00 10 minutes(good test). 5/6/2017 5/6/2017 4.00 PROD1 WELLPR NUND X NU the 11"x 7-1/16"DSA and NU the 0.0 0.0 05:00 09:00 BOP stack. 5/6/2017 5/6/2017 3.50 PROD1 WELLPR BOPE X RU to shell test the BOP stack. Install 0.0 0.0 09:00 12:30 the test plug and fill the stack with fresh water. Close the blind rams and PT to 250/3500 psi for 5 minutes each (good tests). Open the bland rams. Change out the air boot rubbers on the riser,pull the test plug and install the wear ring. Close blind rams and PT the casing to tubing head break against the storm packer to 250/1000 psi for 5 minutes each(good test). RD testing equipment. 5/6/2017 5/6/2017 0.50 PROD1 WELLPR BHAH X PU and MU the storm packer 0.0 10.0 12:30 13:00 retrieving tool and crossover 5/6/2017 5/6/2017 1.00 PROD1 WELLPR MPSP X TIH to the top of the storm packer at 10.0 8,447.0 13:00 14:00 95'MD. Engage the storm packer, open the equalizing valve,observe the well for flow and the well is static. Release the storm packer and TOOH. 5/6/2017 5/6/2017 0.50 PROD1 WELLPR BHAH X Lay down the storm packer and 8,447.0 8,338.0 14:00 14:30 crossover 5/6/2017 5/6/2017 1.50 PROD1 WELLPR PRTS X RU pressure testing equipment. PT 8,338.0 8,338.0 14:30 16:00 the 7"casing to 1000 psi for 5 minutes (good test). Bleed off the pressure and RD/blow down the testing equipment. 5/6/2017 5/6/2017 0.25 PROD1 WELLPR BHAH X PU and MU tandem 6-1/8"string mill 8,338.0 8,350.0 16:00 16:15 assembly. 5/6/2017 5/6/2017 0.50 PROD1 WELLPR TRIP X TIH with tandem 6-1/8"string mill 8,350.0 8,350.0 16:15 16:45 assembly to tag at 186'MD with 10K down. TOOH. 5/6/2017 5/6/2017 0.25 PROD1 WELLPR BHAH X Lay down tandem 6-1/8"string mill 8,350.0 8,338.0 16:45 17:00 assembly. 5/6/2017 5/6/2017 4.00 PROD1 WELLPR CIRC X Circulate and condition the WBM at 9 8,338.0 8,338.0 17:00 21:00 BPM=1600 psi. Blow down the top drive. SimOps: Clean and clear the rig floor Page 17/39 Report Printed: 6/1/2017 • 41) Kit 0Operations Summary (with Timelog Depths) .111 3M-28 Conoc®PhBBlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/6/2017 5/7/2017 3.00 PROD1 WELLPR TRIP X TOOH from 8338'to 1564'MD at 8,338.0 1,564.0 21:00 00:00 midnight. 5/7/2017 5/7/2017 0.75 PROD1 WELLPR TRIP X Continue to TOOH from 1564'MD to 1,564.0 13.0 00:00 00:45 G lock-set running tool. 5/7/2017 5/7/2017 0.75 PROD1 WELLPR BHAH X Lay down G lock set running tool. 13.0 0.0 00:45 01:30 Clean and clear the rig floor. 5/7/2017 5/7/2017 0.50 PROD1 WELLPR RURD X Bring WLS RBP and setting tools to 0.0 0.0 01:30 02:00 the rig floor. 5/7/2017 5/7/2017 1.00 PROD1 WELLPR BHAH X PJSM. PU and MU WLS RBP and J 0.0 22.0 02:00 03:00 hydraulic setting tool. Drain the BOP stack. 5/7/2017 5/7/2017 2.00 PROD1 WELLPR TRIP X TIH with WLS RBP to 3055'MD. 22.0 3,045.0 03:00 05:00 5/7/2017 5/7/2017 0.25 PROD1 WELLPR CIRC X Break circulation at 1 BPM=140 psi 3,045.0 3,045.0 05:00 05:15 and 2 BPM=160 psi. 5/7/2017 5/7/2017 0.50 PROD1 WELLPR MPSP X Drop 1-7/16"setting ball,PU to setting 3,045.0 3,041.0 05:15 05:45 depth,and pump the ball to seat at 2 BPM=160 psi.. Pressure up to 2000 psi and PU 10K set the WLS RBP at 3042.83'MD(center of element)and the top of the RBP is at 3040.48'MD and continue to pressure up to 2300 psi to release from the RBP. 5/7/2017 5/7/2017 0.25 PROD1 WELLPR OWFF X Observe the well for flow for 15 3,041.0 3,041.0 05:45 06:00 minutes and the well is static 5/7/2017 5/7/2017 0.25 PROD1 WELLPR RURD X Blow down the top drive. 3,041.0 3,041.0 06:00 06:15 5/7/2017 5/7/2017 1.75 PROD1 WELLPR TRIP X TOOH with J hydraulic setting tool. 3,041.0 15.0 06:15 08:00 5/7/2017 5/7/2017 0.50 PROD1 WELLPR BHAH X Lay down the setting tool and offload 15.0 0.0 08:00 08:30 from the rig floor. 5/7/2017 5/7/2017 0.50 PROD1 WELLPR RURD X RU to test the WLS RBP/7"casing. 0.0 0.0 08:30 09:00 5/7/2017 5/7/2017 0.50 PROD1 WELLPR PRTS X Close the blind rams,PT the 0.0 0.0 09:00 09:30 RBP/casing to 250 psi for 5 minutes (good test),and PT to 2500 psi for 10 minutes(good test). Bleed off the pressure. 5/7/2017 5/7/2017 0.50 PROD1 WELLPR RURD X Blow down and RD testing equipment. 0.0 0.0 09:30 10:00 5/7/2017 5/7/2017 0.25 PROD1 WELLPR BHAH X PU and MU DP mule shoe pup joint. 0.0 6.0 10:00 10:15 5/7/2017 5/7/2017 1.75 PROD1 WELLPR TRIP X TIH with the DP mule shoe pup joint to 6.0 3,038.0 10:15 12:00 3038'MD(PU=75K and SO=65K). SimOps: Continue to offload WBM and clean the pits. 5/7/2017 5/7/2017 4.00 PROD1 WELLPR RURD X Continue to offload WBM and clean 3,038.0 3,038.0 12:00 16:00 the pits. SimOps: Service the top drive,load the 7"solid body rams into the cellar, and mix up the spacer pill for the displacement. 5/7/2017 5/7/2017 1.00 PROD1 WELLPR DISP X Displace the well from 12.3 ppg WBM 3,038.0 3,038.0 16:00 17:00 to 8.5 ppg seawater. Pump 11.1 ppg 64 vis spacer pill followed by 202 bbls of 8.5 ppg seawater. Page 18/39 Report Printed: 6/1/2017 S • 0Operations Summary (with Timelog Depths) . Operations 3M-28 CotxxoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/7/2017 5/7/2017 0.50 PROD1 WELLPR TRIP X TOOH from 3038'to 2845'MD. Blow 3,038.0 2,845.0 17:00 17:30 down the top drive. 5/7/2017 5/7/2017 5.00 PROD1 WELLPR CIRC X RU the sand hopper onto the DP and 2,845.0 2,845.0 17:30 22:30 dump 1500 lbs of 20/40 mesh sand down the DP. Allow sand to settle for 1 hour. SimOps: MP2's and housekeeping. 5/7/2017 5/7/2017 0.50 PROD1 WELLPR TRIP X TIH to from 2845'to 3007'MD and did 2,845.0 2,845.0 22:30 23:00 not see the top of sand. TOOH to 2845'MD. 5/7/2017 5/7/2017 0.50 PROD1 WELLPR CIRC X Bring the pump up to 1 BPM and the 2,845.0 2,845.0 23:00 23:30 pressure slowly increased indicating the DP was plugged with sand. Pressure increased to 295 psi then the sand plug cleared. Pump 9 bbls at 1 BPM=60 psi. 5/7/2017 5/8/2017 0.50 PROD1 WELLPR CIRC X Allow the sand to settle. 2,845.0 2,845.0 23:30 00:00 5/8/2017 5/8/2017 0.50 PROD1 WELLPR CIRC X Continue to allow the sand to settle. 2,845.0 2,845.0 00:00 00:30 5/8/2017 5/8/2017 0.50 PROD1 WELLPR TRIP X TIH and tag the top of sand at 2982" 2,845.0 2,982.0 00:30 01:00 MD with 4K down. 5/8/2017 5/8/2017 1.00 PROD1 WELLPR TRIP X TOOH with DP mule shoe pup joint 2,982.0 0.0 01:00 02:00 and lay down. 5/8/2017 5/8/2017 3.50 PROD1 WELLPR BOPE X PJSM for changing rams. Drain the 0.0 0.0 02:00 05:30 BOP stack,pull the wear ring,and install the test plug. Change the lower pipe rams to 7"solid body rams. SimOps: Clear ice from the derrick. 5/8/2017 5/8/2017 2.50 PROD1 WHDBOP RURD X RU BOPE testing equipment. 0.0 0.0 05:30 08:00 Page 19/39 Report Printed: 6/1/2017 o • =' Operations Summary (with Timelog Depths) 1. 0 3M-28 Ptitltps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation MB) End Depth(EKE) 5/8/2017 5/8/2017 9.00 PROD1 WHDBOP BOPE X Conduct weekly BOPE test: test 3- 0.0 0.0 08:00 17:00 1/2"x 6"VBR's(upper pipe rams)to 250/3500 psi with 3-1/2"and 4"test joints;test 7"solid body ram(lower pipe rams)to 250/3500 psi with 7"test joint;test annular to 250/3500 with 3- 1/2",4"and 7"test joints;conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Jeff Jones via email on 5/7/17 at 16:29 hours. Tests: 1) 7"solid body ram(lower pipe rams) with 7"test joint and 4"FOSV (Passed) 2) Annular with 7"test joint,HCR choke 16, HCR kill 22,4"Dart valve (Passed) 3) 3-1/2"x 6"VBR's(upper pipe rams)with 3-1/2"test joint,choke valves 1, 12, 13&14(Passed) 4) Annular with 3-1/2"test joint,choke valves 9&11 (Passed) 5) Choke valves 5,8&10(Passed) 6) Choke valves 4,5&7,3-1/2" FOSV(Passed) 7) Choke valve 2(Passed) 8) Manual kill 22,Manual choke 15 (Passed) 9) Choke valve 3&20(kill line in the pits)(Passed) 10) Blind rams(Passed) 11) Upper IBOP(Passed) 12) Lower IBOP(Passed) 13) Annular with 4"test joint(Passed) 14) 3-1/2"x 6"VBR's(upper pipe rams)with 4"test joint(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=3050 psi Accumulator Pressure After Closer= 1750 psi Pressure Gain of 200 psi=44 seconds Full System=190 Seconds Average N2(6 Bottles)=2150 psi 5/8/2017 5/8/2017 1.00 PROD1 WHDBOP RURD X RD and blow down BOPE testing 0.0 0.0 17:00 18:00 equipment. Pull the test plug and install the wear ring. 5/8/2017 5/8/2017 1.00 PROD1 WELLPR RURD X RU to run completion to attempt to 0.0 0.0 18:00 19:00 drift through the tight spot in the 7" casing. Page 20/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) oz r1c 3M-28 Ccot'hiliips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/8/2017 5/8/2017 2.50 PROD1 WELLPR PUTB X PU and MU upper/lower tandem 0.0 0.0 19:00 21:30 wedge assemblies. RIH on 3-1/2" tubing to tag at 196'MD(same as previous attempted completion run). MU crossovers and screw in the top drive.Continue to push the assembly in the hole with the top drive with drag increasing up to 10K. POOH and lay down the tandem wedge assemblies. 5/8/2017 5/8/2017 1.00 PROD1 WELLPR RURD X RD completion running equipment. 0.0 0.0 21:30 22:30 5/8/2017 5/8/2017 0.75 PROD1 WELLPR ELOG X Spot Pollard E-line unit and RU. MU 0.0' 0.0 22:30 23:15 CBL 5/8/2017 5/9/2017 0.75 PROD1 WELLPR ELOG X RIH with CBL to tag at 2860'WLM. 0.0 0.0 23:15 00:00 5/9/2017 5/9/2017 1.00 PROD1 WELLPR ELOG X Log with the CBL from 2853'WLM 0.0 0.0 00:00 01:00 back to surface. 5/9/2017 5/9/2017 1.50 PROD1 WELLPR ELOG X Lay down the CBL and MU the PDS 0.0 0.0 01:00 02:30 40-arm caliper. Function test the caliper. 5/9/2017 5/9/2017 0.50 PROD1 WELLPR ELOG X RIH with 40-arm caliper to 2853'WLM. 0.0 0.0 02:30 03:00 5/9/2017 5/9/2017 2.00 PROD1 WELLPR ELOG XT Attempt to activate the caliper arms 0.0 0.0 03:00 05:00 but the tool is not responding. Trouble shoot. Unabale to get the caliper arms to deploy. POOH and trouble shoot. MU new caliper,function test and RIH to 2807'WLM. 5/9/2017 5/9/2017 1.00 PROD1 WELLPR ELOG X Log from 2807'WLM back to surface 0.0 0.0 05:00 06:00 with the 40-arm caliper. 5/9/2017 5/9/2017 1.00 PROD1 WELLPR ELOG X Rig down Pollard Wireline 0.0 0.0 06:00 07:00 5/9/2017 5/9/2017 0.50 PROD1 WELLPR RURD X Pull mousehole and wear bushing. 0.0 0.0 07:00 07:30 Blow down choke and kill lines.Pull riser. 5/9/2017 5/9/2017 3.50 PROD1 WELLPR NUND X ND BOPE.Remove C-bowl tubing 0.0 0.0 07:30 11:00 spool w/11"adapter.OA open to kill tank. Install cement cross w/13 5/8" spacer spool. 5/9/2017 5/9/2017 4.00 PROD1 WELLPR NUND X NU BOPE.Install kill line and riser. 0.0 0.0 11:00 15:00 5/9/2017 5/9/2017 0.50 PROD1 WELLPR BOPE X Rig up to test kill line connection.Test 0.0 0.0 15:00 15:30 connection to 250/3500 psi for 5 min. ea. 5/9/2017 5/9/2017 0.50 PROD1 WELLPR BOPE X Rig up and perform BOPE body/flange 0.0 0.0 15:30 16:00 test.250/1000 psi for 5 min ea. Required 2 bbls to pressure to 1000 psi.Bled back 2 bbls. 5/9/2017 5/9/2017 0.50 PROD1 WELLPR BOPE X Rig down test equip and blow down 0.0 0.0 16:00 16:30 lines. 5/9/2017 5/9/2017 1.50'PROD1 CSGRCY TRIP X Make up 5 1/2"MSC w/2 1/4"cutters. 0.0 1,709.0 16:30 18:00 RIH to 1709'MD. 5/9/2017 5/9/2017 1.00 PROD1 CSGRCY TRIP X RIH f/1709'MD t/2161'MD. Monitor 1,709.0 2,161.0 18:00 19:00 displacement via trip tank. 5/9/2017 5/9/2017 1.00 PROD1 CSGRCY CPBO X Obtain parameters.PU=70k 50=65K. 2,161.0 2,191.0 19:00 20:00 Locate upper collar at 2169'MD. Locate lower collar at 2212'MD. PJSM.Space out to make cut at 2191' MD.Conduct PJSM on casing cut. Page 21/39 Report Printed: 6/1/2017 tat`- Operations Summary (with Timelog Depths) 0 3M-28 ConocoPt titlip Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time PT-X Operation (ftKB) End Depth(ftKB)'. 5/9/2017 5/9/2017 0.50 PROD1 CSGRCY CPBO X Cut 7"26#casing at 2191'MD. 2,191.0 2,191.0 20:00 20:30 80rpm,2-4K tq,3 bpm,290 psi13% FO.At 5.5 bpm,910 psi.23%FO.As casing was cut pressure dropped to 390 psi. 5/9/2017 5/9/2017 0.75 PROD1 CSGRCY CIRC X Close annular.Confirm circulation 2,191.0 2,191.0 20:30 21:15 from IA thru OA to flow back tank at 1 bpm w/90 psi. Pump 1.5 bbls with good returns 5/9/2017 5/9/2017 0.75 PROD1 CSGRCY OWFF X Blow down lines.Monitor well.PJSM 2,191.0 2,191.0 21:15 22:00 on TOH. 5/9/2017 5/9/2017 1.00 PROD1 CSGRCY TRIP X POOH f/2191'MD to surface.Monitor 2,191.0 0.0 22:00 23:00 displacement via trip tank.Lay down MSC. 5/9/2017 5/10/2017 1.00 PROD1 CSGRCY CIRC X PJSM.Displace arctic pack to flow 0.0 0.0 23:00 00:00 back tank.Test LRS lines to 3500 psi. Shut blind rams.Pump 130 bbls diesel w/LRS at 5 bpm and 500 psi down IA taking returns up OA. 5/10/2017 5/10/2017 1.50 PROD1 CSGRCY ELOG X Lay down the CBL and MU the PDS 0.0 0.0 00:00 01:30 40-arm caliper. Function test the caliper. 5/10/2017 5/10/2017 2.50 PROD1 CSGRCY CIRC X Continue to displace arctic pack to 0.0 0.0 00:00 02:30 flow back tank. RD LRS and displace diesel with 290 bbls of 140°F fresh water at 5 bpm at 290 psi taking returns to Tank#28. Monitor well, Blow down line to 5/10/2017 5/10/2017 1.00 PROD1 CSGRCY BHAH X Mobilize BHA to rig floor.PJSM Make 0.0 0.0 02:30 03:30 up spear assy.Drain stack.Spear 7" casing.Set down 5K. 5/10/2017 5/10/2017 1.50 PROD1 CSGRCY PULL X PJSM. BOLDS.PU 120K to free pipe. 0.0 0.0 03:30 05:00 PU=110K.ND bottom flange on cement cross.POOH from 2191'MD to 2160'MD.Pull 7"packoff and slips. 5/10/2017 5/10/2017 1.00 PROD1 CSGRCY RURD X NU cement cross. Inflate air boots.RU 0.0 0.0 05:00 06:00 8 5/8"dbl stack power tongs. 5/10/2017 5/10/2017 1.50 PROD1 CSGRCY SEQP X Rig up to test flange on cement cross. 0.0 0.0 06:00 07:30 Test to 250 psi f/10 min. 5/10/2017 5/10/2017 0.50 PROD1 CSGRCY CIRC X Circulate down IA taking OA returns to 0.0 0.0 07:30 08:00 flow back tank.Circ 8.5 ppg seawater at 4.5 bpm w/250 psi.Monitor well f/ 10 mins.Blow down lines. 5/10/2017 5/10/2017 0.50 PROD1 CSGRCY RURD X Lay down 4"DP single and X-O's.Lay 2,191.0 2,089.0 08:00 08:30 down 7"cut joint with spear engaged. Change out elevators. 5/10/2017 5/10/2017 5.50 PROD1 CSGRCY PULL X POOH laying down 7"casing 2096' 2,089.0 0.0 08:30 14:00 MD to surface.Cal disp=21 bbls Act disp=26.5 bbls.Recovered 16 Rotco centering guides,49 full jts, 1 upper cut jt @ 36.11'and 1 lower cut jt @22.5'. 5/10/2017 5/10/2017 2.50 PROD1 CSGRCY RURD X Clean rig floor and tools and 0.0 0.0 14:00 16:30 equipment of arctic pack.Lay down power tongs.Mobilize BHA equipment to rig floor. Install 9 1/16"wear ID wear bushing. Page 22/39 Report Printed: 6/1/2017 I -' Operations Summary (with Timelog Depths) #.;.. 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKB) 5/10/2017 5/10/2017 3.50 PROD1 CASING BHAH X Make up tandem string mill BHA.Tag 0.0 187.0 16:30 20:00 up at 187'MD.Lay down 1 DC and pick up 1 jt 4"DP.Make up TD. 5/10/2017 5/10/2017 1.50 PROD1 CASING MILL X Establish parameters.PU=60K, 186.0 187.0 20:00 21:30 SO=53K Rot=55K,60 rpm,2-4K free tq,5 bpm,60 psi,30%FO,. Mill 186' MD t/187'MD 5/10/2017 5/10/2017 0.50 PROD1 CASING BHAH X PJSM-POOH and lay down upper 187.0 10.0 21:30 22:00 string mill and dbl pin X-O. 5/10/2017 5/10/2017 0.50 PROD1 CASING BHAH X RIH w/single string mill BHA.Tag 10.0 182.0 22:00 22:30 w10K at 182'MD 5/10/2017 5/10/2017 0.75 PROD1 CASING MILL X Mill f/182'MD t/186'MD.5 bpm,60 182.0 186.0 22:30 23:15 psi,30%FO,60-80 rpm,2-4K tq,4-5K WOB, PU=60K,SP=53K,Rot=55K. Lost all returns. 5/10/2017 5/11/2017 0.75 PROD1 CASING OWFF XT Monitor well adding seawater from trip 186.0 186.0 23:15 00:00 tank. Pump 30 bbls down well. Consult with workover engineer and drilling superintendent 5/11/2017 5/11/2017 1.25 PROD1 CASING MILL X Mill 7"casing f/182'MD t/186'MD,50 182.0 186.0 00:00 01:15 rpm,5-8K tq,5-9K WOB, 1 bpm w/40 psi.Gained partial returns after 42 bbls pumped. 5/11/2017 5/11/2017 0.25 PROD1 CASING OWFF X Monitor well at 176'MD.Fluid level 186.0 176.0 01:15 01:30 dropping below wellhead.Blow down TD. 5/11/2017 5/11/2017 1.50 PROD1 CASING WAIT XT Wait on seawater.Pump 10 bbls 176.0 176.0 01:30 03:00 seawater every 30 mins.No returns. Pumped 70 bbls. 5/11/2017 5/11/2017 1.00 PROD1 CASING BHAH X PJSM-POOH.Lay down BHA.Add 20 176.0 0.0 03:00 04:00 bbls seawater every 30 mins. 5/11/2017 5/11/2017 1.50 PROD1 CASING TRIP X PJSM-MU 6 3/8"bullnose and x-o. 0.0 0.0 04:00 05:30 RIH on 4"DP.Tag up at 187'MD.Set down 5K.Continue to add 20 bbls seawater every 30 mins..POOH f/ 187'MD.Lay down bullnose and x-o. 5/11/2017 5/11/2017 1.50 PROD1 CASING TRIP X Make up 5.27"OD stack washer tool 0.0 0.0 05:30 07:00 on drill pipe.RIH and stack out at 188' MD.Set down 5K.POOH and lay down stack washer.Continue to add 20 bbls seawater every 30 mins. 5/11/2017 5/11/2017 0.50 PROD1 CASING SVRG X Service rig. 0.0 0.0 07:00 07:30 5/11/2017 5/11/2017 2.00 PROD1 CASING BHAH X Reposition milling BHA on rig floor. 0.0 0.0 07:30 09:30 Mobilize UHT tongs to rig floor,Load and strap 10 jts 9.3#3 1/2"EUE tubing in pipe shed. 5/11/2017 5/11/2017 1.50 PROD1 CASING WAIT XT Wait on wireline. 0.0 0.0' 09:30 11:00 5/11/2017 5/11/2017 1.00 PROD1 CASING RURD X Install dutch riser.Mobilize wire line 0.0 0.0 11:00 12:00 tools and equipment to rig floor. 5/11/2017 5/11/2017 1.00 PROD1 CASING ELOG X Rig up wireline. 0.0 0.0 12:00 13:00 5/11/2017 5/11/2017 1.50 PROD1 CASING ELOG X RIH w/camera assy to 174'WLD. 0.0 0.0 13:00 14:30 Observe damaged casing.POOH with camera assy. 5/11/2017 5/11/2017 0.50 PROD1 CASING ELOG X Rig down wire line sheaves 0.0 0.0 14:30 15:00 Page 23/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) ; 3M-28 Cooco nnPtaitiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/11/2017 5/11/2017 1.00+PROD1 CASING RURD X Remove dutch riser.Rig up UHT 0.0 0.0 15:00 16:00 tongs. Mobilize crossovers to rig.floor. 5/11/2017 5/11/2017 0.50 PROD1 CASING ELOG X Rig up wire line sheaves. 0.0 0.0 16:00 16:30 5/11/2017 5/11/2017 1.00 PROD1 CASING PULD X Pick up 3 1/2"L-80 EUE 9.3#tubing 0.0 189.0 16:30 17:30 with a collar on bottom pin.Stack out at 189'MD.PU=40K SO=42K 5/11/2017 5/11/2017 0.50 PROD1 CASING OTHR X Make up X-o's on 3 1/2"tubing.MU 189.0 217.0 17:30 18:00 TD. RIH f/189'MD t/217'MD. Required 2-3K push weight.Void 9 5/8"casing with rig air.Break out TD and X-O's, 5/11/2017 5/11/2017 2.00 PROD1 CASING RURD X Change out 11'elevator links to 15'. 217.0 217.0 18:00 20:00 Make up X-O's and pump in sub.Hook up cement hose. 5/11/2017 5/11/2017 1.50 PROD1 CASING ELOG X RIH w/camera on wire Iine.Set tubing 217.0 172.0 20:00 21:30 on depth at 187'MD, 185'MD, 183' MD, 181'MD, 176'MD and 172'MD. Wireline monitoring optics during movement. 5/11/2017 5/11/2017 1.50 PROD1 CASING ELOG X Rig down cement hose.Pull camera 172.0 187.0 21:30 23:00 assy into top tubing jt.Break out top jt. and lay down PDS camera assy. 5/11/2017 5/12/2017 1.00 PROD1 CASING PULD X Lay down 7 jts 3 1/2"tubing. 187.0 0.0 23:00 00:00 5/12/2017 5/12/2017 2.50 PROD1 CASING RURD X Clear rig floor,RD 15-ft Elevator links, 0.0 0.0 00:00 02:30 RU 11-ft Elevator links,RD 4.5"UHT Power Tongs,Housekeeping-clear and clean work area. RD eline.while waiting for camera diagnostics-plan forward. 5/12/2017 5/12/2017 1.00 PROD1 CASING BHAH X PJSM,PU,MU and RIH w/BHA#15- 0.0 190.4 02:30 03:30 (4.75"OD DC's w/Mule shoe for drift run)to 188--ft and tag up w/12k dn, Turn pipe 1/4 of turn to right and work down to 190-ft 5/12/2017 5/12/2017 0.50 -PROD1 CASING BHAH X POOH w/BHA#15 190.4 0.0 03:30 04:00 5/12/2017 5/12/2017 1.50 PROD1 CASING BHAH X PU,MU and RIH w/BHA#16 6-1/8" 0.0 184.0 04:00 05:30 OD string mill w/5"OD mule shoe to 184-ft. 45K Up wt,47K Dn wt,48K ROT wt. 5/12/2017 5/12/2017 0.50 PROD1 CASING MILL X Mill from 183-ft to 183-ft Rotating at 50 184.0 184.0 05:30 06:00 rpm's with 1K TQ with 3-5K WOM 5/12/2017 5/12/2017 1.00 PROD1 CASING BHAH X POOH w/BHA#16 from 184-ft-Mule 184.0 0.0 06:00 07:00 shoe showed all the rotating action and mill was untouched. 5/12/2017 5/12/2017 1.50 PROD1 CASING BHAH X Clean and clear tools while bending 1 0.0 208.0 07:00 08:30 jt 3-1/21F DP to a 2°Bend at tool jt pin. PU,MU and RIH w/ BHA#17(4.75" OD Bull nose on the bottom of the 2° Bent joint,6-1/8"OD String mill)to 199-ft,PU and Turn 1/4 turn to the right and slack off to 208-ft.with 14k set down wt. Make a high visc slick pill,work pipe up down thru the kinks. Page 24/39 Report Printed: 6/1/2017 ,i4 Operations Summary (with Timelog Depths) 0 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Cade Time P-T-X Operation (ftKB) End Depth(ftKB) 5/12/2017 5/12/2017 2.50 PROD1 CASING MILL X Begin milling at 208-ft with Bull nose 208.0 221.0 08:30 11:00 (Mill at 173.5-ft)at 40 rpm's w/1k free tq,continue to mill down to 221-ft with Bull Nose(Mill Depth 187-ft)w/5k WOM with 3-4K tq-lost torque. 5/12/2017 5/12/2017 2.00 PROD1 CASING BHAH XT POOH with BHA#17-found to have 221.0 0.0 11:00 13:00 parted the shank 2.4-ft above the mill leaving a 4"OD x 6'long stub for recovery with short catch OS. TOF @ 184-ft. Found bad pin DC#1 (29.91 -ft)-lay down for recut and inspection. and replace with(30.89-ft). Clean and clear rig floor while transporting equipment from Dead Horse. 5/12/2017 5/12/2017 0.25 PROD1 CASING BHAH XT PU,MU and RIH w/BHA#18 to 55-ft 0.0 55.0 13:00 13:15 5/12/2017 5/12/2017 0.75 PROD1 CASING TRIP XT RIH with BHA#18 to 185-ft-attempt 55.0 55.0 13:15 14:00 to engage OS-seen overpull-POOH to 55-ft. 5/12/2017 5/12/2017 0.25 PROD1 CASING BHAH XT PULL BHA to surface-no fish,Re run 55.0 55.0 14:00 14:15 back with same. 5/12/2017 5/12/2017 0.25 PROD1 CASING TRIP XT RIH w/BHA#18(run 2)to 185-ft, 55.0 185.0 14:15 14:30 Attempt to engage-seen overpull 5/12/2017 5/12/2017 0.50 PROD1 CASING TRIP XT POOH to BHA#18(run 2)to 55-ft, 55.0 185.0 14:30 15:00 Attempt to engage-seen overpull 5/12/2017 5/12/2017 0.25 PROD1 CASING BHAH XT POOH and inspect-no fish,dressup 55.0 0.0 15:00 15:15 cut lip. 5/12/2017 5/12/2017 0.50 PROD1 CASING BHAH XT 'RIH w/BHA#19 to145-ft. 0.0 145.0 15:15 15:45 5/12/2017 5/12/2017 1.00 PROD1 CASING TRIP XT Trip in BHA#19 to 184-ft and work 145.0 186.0 15:45 16:45 down to 186-ft POOH to 145-ft 5/12/2017 5/12/2017 0.50 PROD1 CASING BHAH XT POOH with BHA#19 -found that we 186.0 0.0 16:45 17:15 had engage over stub by.30",Seen chatter but was from current hole conditions. Call out for 4-11/16"and 4 -5/8"Grapple,Box tap,Sizing shoes 5/12/2017 5/12/2017 0.50 PROD1 CASING BHAH XT Remove cutlip from OS and RIH with 0.0 145.0 17:15 17:45 same BHA#19 to 145-ft. Checking mid breaks due to LH rotation while manipulating the overshot 5/12/2017 5/12/2017 0.25 PROD1 CASING TRIP XT Checking mid breaks due to LH 145.0 181.0 17:45 18:00 rotation while manipulating the overshot. Engage Fish at 186-ft and push to 191-ft set down 10K. Pull over 10K,allow jars to bleed. Contiue to POOH from 227-ft to 181-ft. 5/12/2017 5/12/2017 0.50 PROD1 CASING BHAH XT POOH w/OS and No Fish 181.0 0.0 18:00 18:30 5/12/2017 5/12/2017 1.00 PROD1 CASING WAIT XT Wait on 4 11/16"Grapple. 0.0 0.0 18:30 19:30 Page 25/39 Report Printed: 6/1/2017 • Operations Summary (with Timelog Depths)0114 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/12/2017 5/12/2017 0.50 PROD1 CASING FISH XT Make 4 11/16"grapple on short catch 0.0 0.0 19:30 20:00 overshot.RIH and tag up at 188'MD with 3-4K WOB.PU=44K SO=47K. Set down 5-7K WOB with weight dropping off to 191'MD at 10K WOB. Pick up with 5K overpull.RIH and set down 10K WOB.POOH to surface with no fish.Observed arctic pack inside and on the exterior of overshot. 5/12/2017 5/12/2017 2.50 PROD1 CASING RURD XT Clear rig floor of uneeded tools. Rig up 0.0 0.0 20:00 22:30 to pick up 3 1/2"tbg. 5/12/2017 5/13/2017 1.50 PROD1 CASING PULD XT PU 3 1/2 EUE 9.3#L-80.Tag up at 0.0 0.0 22:30 00:00 190'MD w/2K wt. RU head pin.While making up head pin w/chain tongs pipe rotated and moved down hole. Work pipe down to 205'MD rotating with chain tongs.PJSM.POOH standing back tubing.Observe 15' arctic pack on last joint of tubing. 5/13/2017 5/13/2017 1.00 PROD1 CASING ELOG X Install Dutch Riser.Change out 0.0 0.0 00:00 01:00 elevators to 4" 5/13/2017 5/13/2017 2.50 PROD1 CASING ELOG X PJSM-Rig up Pollard wireline.MU 0.0 0.0 01:00 03:30 PDS downhole camera.RIH to 30' MD.Camera lens fogged up.POOH and clean lens.RIH with camera to 179'WLM.POOH with wireline and LD PDS camera. 5/13/2017 5/13/2017 1.00 PROD1 CASING ELOG XT Consult with engineer. Perform 0.0 0.0 03:30 04:30 housekeeping 5/13/2017 5/13/2017 0.50 PROD1 CASING ELOG X Rig down wireline and Dutch Riser. 0.0 0.0 04:30 05:00 5/13/2017 5/13/2017 1.00 PROD1 CASING TRIP X PJSM-Rig up to run 3 1/2"tbg. 0.0 200.0 05:00 06:00 Change out bent jt. Install collar on jt. #1 to act as WLEG.RIH and tag at 190'MD w/2K weight.Rotate down to 200'MD. 5/13/2017 5/13/2017 1.00 PROD1 CASING OTHR X Pick up to 186'MD and make up X- 200.0 186.0 06:00 07:00 O's and kelly up to TD.RIH and tag at 192'MD.Pick up to 186'MD. Break out TD and X-o's.Lay down jt.#7. 5/13/2017 5/13/2017 2.00 PROD1 CASING ELOG X Rig down 11'elevator links,rig up 15' 186.0 186.0 07:00 09:00 Iinks.Rig up wireline sheave in derrick.Make up X-O's for wireline.Rig up fresh water truck and filtration unit.RIH w/wireline to 100'WLD. 5/13/2017 5/13/2017 1.00 PROD1 CASING ELOG X Pump 5 bbls seawater down tbg.RIH 186.0 186.0 09:00 10:00 w/wireline to 186'WLD.POOH with wireline 5/13/2017 5/13/2017 2.50 PROD1 CASING ELOG X Rig down pump-in sub.Pick up(2)10' 186.0 205.0 10:00 12:30 3 1/2"tbg pump jts.RIH to 205'MD. Make up pump-in sub and wireline X- O's.Pump 8 bbl hi-vis sweep,chase with 15 bbls seawater displace with fresh water.from filtration unit..Sim- ops/RIH w/wireline to tbg tail. Page 26/39 Report Printed: 6/1/2017 Operations Summary (with Timelog Depths) Oz 3M-28 conocophiturrs ,.fskm Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/13/2017 5/13/2017 2.00 PROD1 CASING ELOG X Set tbg on depth at 185'MD and then 205.0 161.0 12:30 14:30 161'MD.RIH w/wireline at each station to evaluate casing. Blow rig air down tubing to evacuate water from well bore. 5/13/2017 5/13/2017 1.00 PROD1 CASING ELOG X Pull wireline up into bg.Lower tbg to 161.0 188.0 14:30 15:30 198'MD.POOH w/wireline.Rig down wireline X-O's and pup jt.Blow rig air down tubing at 198'MD 5/13/2017 5/13/2017 1.00 PROD1 CASING PULD X Rig up and POOH with 3 1/2"tbg 188.0 0.0 15:30 16:30 f/188'MD.Last joint was slightly bent. Break out lower collar(WLEG)and lay down jt. 5/13/2017 5/13/2017 1.00 PROD1 CASING ELOG X Rig down wireline sheave from derrick 0.0 0.0 16:30 17:30 and rig down wireline tools 5/13/2017 5/13/2017 0.50 PROD1 CASING RURD X Disconnect long elevator link bolts and 0.0 0.0 17:30 18:00 prep to cut drilling line 5/13/2017 5/13/2017 2.50 PROD1 CASING SLPC X PJSM-Slip and cut drilling line.Cut 0.0 0.0 18:00 20:30 52'of line. 5/13/2017 5/13/2017 1.00 PROD1 CASING RURD X Change out 15'elevator links to 11' 0.0 0.0 20:30 21:30 links. 5/13/2017 5/13/2017 0.50 PROD1 CASING BHAH X PJSM-Mobilize BHA tools to rig floor. 0.0 34.0 21:30 22:00 MU bullnose,and 1 bent jt.of 3 1/2" DP. 5/13/2017 5/13/2017 1.50 PROD1 CASING TRIP X RIH w/DP.Tag at 208'MD w/8K down 34.0 240.0 22:00 23:30 weight..PU=40K SO=44K.Rotate down to 218'MD.5-8K wob, 1-5 rpm, 1K tq, Pump 19 bbl hi-vis pill.Con't to RIH f/218'MD t/240'MD.5 rpm, 1-5K wob, 1K tq.Pump 15 bbls seawater. Blow down top drive.Fluid level at wellhead. 5/13/2017 5/14/2017 0.50 PROD1 CASING TRIP X POOH f/240'MD t/200'MD 10-25K 240.0 0.0 23:30 00:00 drag.Con't POOH f/200'MD w/normal drag. 5/14/2017 5/14/2017 0.50 PROD1 CASING BHAH X Mobilize BHA#23 to rig floor. 0.0 0.0 00:00 00:30 5/14/2017 5/14/2017 2.00 PROD1 CASING BHAH X PJSM-MU BHA#23.to 195'MD. 0.0 205.0 00:30 02:30 PU=50K SO=52K Rot=53K,30rpm, 1K free tq. RIH and tag at 205'MD w/10K down weight. 5/14/2017 5/14/2017 4.00 PROD1 CASING MILL X Mill f/207'MD t/220'MD.30 rpm, 1-3K 205.0 220.0 02:30 06:30 tq, 1-7K WOM.Pump 12 bbls seawater 1 bpm,40 psi to displace hi- vis pill from surface lines. Pump 1 bbls seawater every 15 min.to keep stand pipe from freezing.At 215'MD pump 150 bbls seawater @ 5 bpm,60 psi,54%FO to clear mill.30 bph loss rate.Continue to pump 2 bbls seawater every 15 mins. 5/14/2017 5/14/2017 1.50 PROD1 CASING BHAH X POOH w/BHA#23.Stand back 6 1/4" 220.0 0.0 06:30 08:00 DC's.Lay down 4"DP single,XO, jar/bumper sub.Bent joint twisted off below tool jt.leaving 31.4'of fish WI TOF at 188'MD. 5/14/2017 5/14/2017 0.50 PROD1 CASING BHAH X Clean and clear rig floor. 0.0 0.0 08:00 08:30 5/14/2017 5/14/2017 2.00 PROD1 CASING ELOG X Install Dutch Riser.Rig up wireline. 0.0 0.0 08:30 10:30 Page 27/39 Report Printed: 6/1/2017 • Operations Summary (with Timelog Depths) mkt 3M-28 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/14/2017 5/14/2017 1.50 PROD1 CASING ELOG X RIH w/40 finger caliper tool and log 0.0 0.0 10:30 12:00 from 185'WLM to surface.The caliper recordings indicate an interval of severe buckling from-169'WLM to 185'WLM(end of log).A large hole is recorded in the area of buckling from -174'WLM to-176'WLM,with additional holes from mill damage in the vicinity of the largest hole.The caliper recordings also indicate a possible I.D.restriction from what appears to be deformed pipe at the bottom of the large hole at 176'WLM. 5/14/2017 5/14/2017 0.75 PROD1 CASING ELOG X Rig down Dutch riser and wireline. 0.0 0.0 12:00 12:45 5/14/2017 5/14/2017 2.75 PROD1 CASING WAIT XT Wait on 2 3/8"rams,test joint and 2 0.0 0.0 12:45 15:30 3/8"WTS-6 pipe.Sim-ops/Work on MP2's clear floor. 5/14/2017 5/14/2017 1.00 PROD1 CASING RURD XT Blow down choke and kill lines.Pull 0.0 0.0 15:30 16:30 wear bushing,install test plug. Pull mousehole 5/14/2017 5/15/2017 7.50 PROD1 CASING WAIT XT Rig up and change out choke and kill 0.0 0.0 16:30 00:00 HCR valves while waiting on equipment 5/15/2017 5/15/2017 2.00 COMPZN CASING BOPE X PJSM-Change out lower pipe rams 0.0 0.0 00:00 02:00 from 7"to 2 7/8"solid body rams 5/15/2017 5/15/2017 2.50 COMPZN WHDBOP RURD X Rig up to test BOPE.Change out 0.0 0.0 02:00 04:30 valve on test pump.Pull test plug and remove bull plug from port.Set test plug. 5/15/2017 5/15/2017 8.50 COMPZN WHDBOP BOPE X Perform weekly BOPE test.Test#1- 0.0 0.0 04:30 13:00 Annular w/3 1/2"test joint/CV's 1,12, 13, 14,KV 20,upper IBOP.Test#2- CV's 9, 11, Lower IBOP,upper VBR's w/3 1/2 test jt.Kill HCR.Test#3-CV's 5,8, 10,4"FOSV valve.Test#4-CV's 4,6,7,4"dart valve.Test#5-CV 2. Test#6-Choke HCR,3 1/2"EUE FOSV.Test#7-Manual choke and kill valves.Test#8-CV 3.Test#9-Super and manual chokes. 1500 psi bleed off.Test#10-Blind rams.Test#11- Lower rams w/2 3/8"test jt.Test#12- Annular w/2 3/8"test jt.Test#13- Upper VBR's w/4"test jt..Test#14- Annular w/4"test jt.All tests 250 psi low/3000 psi high.Test witnessed by AOGCC rep Lou Laubenstein. Koomey Draw Down System Pressure 3,000 psi PSI after Closure=1,725 psi 200 PSI Attained =37 seconds Full PSI Attained=181 seconds N2 Bottles AVG=6 @ 2,160 psi 5/15/2017 5/15/2017 1.00 COMPZN WHDBOP RURD X Rig down test equip.Clear rig floor. 0.0 0.0 13:00 14:00 Set 9 1/16"ID wear bushing. 5/15/2017 5/15/2017 1.00 COMPZN CASING RURD X Rig up to run 2 3/8"WTS-6 tubing. 0.0 0.0 14:00 15:00 Page 28/39 Report Printed: 6/1/2017 Operations Summary (with Timelog Depths) 3M-28 Co coPhitilps R�xska Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/15/2017 5/15/2017 1.00 COMPZN CASING PULD X MU 2 3/8"mule shoe.Single in hole w/ 0.0 196.0 15:00 16:00 2 3/8"tubing.Tag at 196'MD.Pump 18 bbls hi-vis sweep. 5/15/2017 5/15/2017 1.00 COMPZN CASING WAIT XT Consult w/engineer. 196.0 196.0 16:00 17:00 5/15/2017 5/15/2017 1.00 COMPZN CASING PULD X POOH.Lay down 2 3/8"tubing. 196.0 0.0 17:00 18:00 5/15/2017 5/15/2017 3.50 COMPZN CASING OTHR X RU 7"elevators.PU 1 jt 7"casing. RU 0.0 0.0 18:00 21:30 sand hopper.Dump 6600#20/40 frac sand down wellbore. 5/15/2017 5/16/2017 2.50 COMPZN CASING PULD X Rig up to PU 2 3/8"tubing.Make up 0.0 161.0 21:30 00:00 mule shoe.and RIH picking up 2 3/8" tubing.Tag frac sand at 54'MD.Pump 10 bbls.seawater from trip tank down hole and allow to percolate through sand.RIH and tag at 56'MD.Pump another 5 bbls down hole and allow to percolate 5 mins.RIH to 98'MD.PU and inspect mule shoe for sand plug. RIH and tag at 118'MD.Pump 4 bbls seawater and allow to percolate 5 mins.RIH and tag at 186'MD.POOH to 161'MD.Pump 3 bbls seawater down tubing to ensure it is clear. 5/16/2017 5/16/2017 2.00 COMPZN CASING RURD X Rig up to pump cement.Mix 30 bbl 161.0 161.0 00:00 02:00 citric acid pill.RU SLB cementers. Blow down cement line. 5/16/2017 5/16/2017 0.50 COMPZN CASING RURD X Take citric acid pill onto vac truck.Rig 161.0 161.0 02:00 02:30 up water and washup vac trucks to SLB cement unit. 5/16/2017 5/16/2017 2.50 COMPZN CASING CMNT X Perform Surface casing hole squeeze. 161.0 129.0 02:30 05:00 Test lines to 1000 psi. Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS cement,40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat AS1 cement, 5 bbls water @ 2.6 bpm,200 psi. 140 psi trapped pressure.Bleed off to 0 psi.Bled back 2.5 bbls.Blow down cmt.line.Lay down circ valves.POOH to 129'MD.Rig up circ lines. Rig up to pump second stage of squeeze.Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS1 cement,40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat AS1 cement, 1.3 bbls water©3 bpm, 230 psi 5/16/2017 5/16/2017 0.50 COMPZN CASING PULD X POOH and lay down 2 3/8"tubing. 129.0 0.0 05:00 05:30 5/16/2017 5/16/2017 1.50 COMPZN CASING WWWH X Make up stack washing tool and wash 0.0 0.0 05:30 07:00 out BOPE w/20 bbls citric acid pill. Function rams.Blow down choke and kill lines. Blow down TD. 5/16/2017 5/16/2017 1.00 COMPZN CASING BOPE X Blow down side entry sub.Pull wear 0.0 0.0 07:00 08:00 ring.Set test plug. 5/16/2017 5/16/2017 2.00 COMPZN CASING BOPE X Change out lower pipe rams to 7"solid 0.0 0.0 08:00 10:00 body rams. 5/16/2017 5/16/2017 1.00 COMPZN CASING BOPE X Rig up test equipment and 7"test jt. 0.0 0.0 10:00 11:00 Page 29/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) 0 3M-28 CortocdPhitlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X: Operation (ftKB) End Depth(ftKB) 5/16/2017 5/16/2017 1.00 COMPZN CASING BOPE X Test 7"rams and annular w/7"test jt. 0.0 0.0 11:00 12:00 250/3000 psi for 5 min each. 5/16/2017 5/16/2017 0.50 COMPZN CASING BOPE X Blow down kill line,Service break 0.0 0.0 12:00 12:30 XO's on test jt.Rig down test equip. 5/16/2017 5/16/2017 0.50 COMPZN CASING BOPE X Pull test plug.Install 9 1/16"ID wear 0.0 0.0 12:30 13:00 ring. 5/16/2017 5/16/2017 3.00 COMPZN CASING BHAH X Mobilize BHA equip.to rig floor.Make 0.0 0.0 13:00 16:00 up BHA#26.Tag cement at 38'MD. POOH and stand back DC's 5/16/2017 5/16/2017 1.00 COMPZN CASING BHAH X BHA XO's packed off with cement. 0.0 0.0 16:00 17:00 Clean XO's.MU 8 1/2"mill tooth bit on DP. 5/16/2017 5/16/2017 3.00 COMPZN CASING DRLG X RIH and tag cement at 38'MD.Drill 38.0 175.0 17:00 20:00 cement f/38'MD t1175.6.5 bpm, 140 psi,50 rpm,0 tq,29%FO.Circ 3 hole volumes.6.5 bpm,140 psi,27%FO. 5/16/2017 5/16/2017 0.50 COMPZN CASING TRIP X Blow down TD.POOH.Lay down BHA 175.0 0.0 20:00 20:30 #27. 5/16/2017 5/16/2017 2.00 COMPZN CASING BHAH X PJSM-Make up BHA #28.Tag at 0.0 0.0 20:30 22:30 160'MD.PU=60K 50=52K.Pump 2 bbls seawater and drillstring pressured to 700 psi w/no returns.Attempt to unplug drillstring. 5/16/2017 5/16/2017 1.00 COMPZN CASING BHAH XT POOH w/BHA#28.Mill and lower DC 0.0 0.0 22:30 23:30 plugged w/cement residue.Clear mill and DC. 5/16/2017 5/17/2017 0.50 COMPZN CASING WASH X RIH w/BHA#28 to 160'MD.Establish 0.0 160.0 23:30 00:00 parameters.PU=60K SO=52K,3 bpm, 120 psi,23%FO.4 bpm=140 psi 25%FO.6 bpm=360 psi,25%FO. 5/17/2017 5/17/2017 0.50 COMPZN CASING WASH X Wash down to 165'MD w/2K WOB. 160.0 165.0 00:00 00:30 Continue to wash down to 170'MD. Tag w/12K weight.PU to 165'MD. 5/17/2017 5/17/2017 1.00 COMPZN CASING MILL X Mill f/165'MD t/170'MD. 10K WOB, 165.0 170.0 00:30 01:30 50-60 rpm,6 bpm,370 psi,26%FO. Pump 5 bbl hi-vis sweep at 167'MD. 5/17/2017 5/17/2017 1.00 COMPZN CASING CIRC X Pump 5 bbl hi-vis sweep at 170'MD.. 170.0 170.0 01:30 02:30 Chase w/150 bbls seawater @ 10 bpm,890 psi.30%FO.Displace well w/filtered(3 micron)fresh water. Pump 38 bbls fresh water at 6 bpm, 320 psi,25%FO.Monitor well.Blow down TD. 5/17/2017 5/17/2017 0.50 COMPZN CASING BHAH X PJSM-POOH.Clean and clear rig 170.0 0.0 02:30 03:00 floor. 5/17/2017 5/17/2017 2.00 COMPZN CASING ELOG X PJSM-Rig up Pollard wireline w/PDS 0.0 0.0 03:00 05:00 downhole camera.RIH to 172.8'WLM. POOH and rig down wireline. 5/17/2017 5/17/2017 0.50 COMPZN CASING BHAH X PJSM-Make up BHA to 70'MD. 0.0 70.0 05:00 05:30 5/17/2017 5/17/2017 1.00 COMPZN CASING WAIT X Process downhole camera data.Blow 70.0 70.0 05:30 06:30 down choke and kill line. 5/17/2017 5/17/2017 1.00 COMPZN CASING BHAH X Make up BHA#29 to 168'MD.MU 4" 70.0 170.0 06:30 07:30 jt DP.Wash down and tag at 170'MD. 5 bpm, 190 psi. Page 30/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) 3M-28 ConocoMillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time'. End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/17/2017 5/17/2017 1.75 COMPZN CASING MILL X PU to 167'MD.Pump 5 bbl hi-vis 170.0 178.0 07:30 09:15 sweep.9 bpm,830 psi.Mill f/170'MD t/178'MD.9 bpm,50 rpm,2K tq, 10- 12K WOB,PU=50K SO=50K 5/17/2017 5/17/2017 0.50 COMPZN CASING REAM X Ream through 178'MD to 170'MD x2. 178.0 176.0 09:15 09:45 Wash down f/170'MD t/178'MD. 5BPM,230 psi.Pump 10 bbls hi-vis sweep at 176'MD.9 bpm,830 psi. 5/17/2017 5/17/2017 0.75 COMPZN CASING CIRC X Rig up and displace well to filtered 176.0 176.0 09:45 10:30 seawater.Pump 31 bbls at 4 bpm, 140 psi. 5/17/2017 5/17/2017 0.25 COMPZN CASING OWFF X Monitor well. Blow down lines on 176.0 176.0 10:30 10:45 filtration unit. 5/17/2017 5/17/2017 0.25 COMPZN CASING PULD X Lay down single jt.DP.BIow down TD. 176.0 169.0 10:45 11:00 5/17/2017 5/17/2017 0.50 COMPZN CASING BHAH X POOH and lay down BHA. 169.0 0.0 11:00 11:30 5/17/2017 5/17/2017 2.00 COMPZN CASING ELOG X PJSM-Rig up Pollard wireline w/PDS 0.0 0.0 11:30 13:30 downhole camera.RIH to 179.6'WLM. POOH and rig down wireline. 5/17/2017 5/17/2017 1.00 COMPZN CASING BHAH X Process downhole camera data/Make 0.0 165.0 13:30 14:30 up BHA#28 to 165'MD.PU single jt DP. 5/17/2017 5/17/2017 1.00 COMPZN CASING BHAH X LD single jt DP.Lay down BHA. 165.0 0.0 14:30 15:30 5/17/2017 5/17/2017 0.50 COMPZN CASING RURD X Rig up to pick up 3 1/2"tbg. 0.0 0.0 15:30 16:00 5/17/2017 5/17/2017 0.50 COMPZN CASING RURD X Work scope changed.Rig down tbg 0.0 0.0 16:00 16:30 equip. 5/17/2017 5/17/2017 0.50 COMPZN CASING BHAH X Change out bell mill to light bulb mill. 0.0 168.0 16:30 17:00 PU BHA#29 to 168'MD. 5/17/2017 5/17/2017 2.00 COMPZN CASING MILL X Make up single jt DP.PU=55K 168.0 183.0 17:00 19:00 SO=50K,Wash down to 178'MD.5 bpm,70 psi.Mill f/178'MD t/183' MD.7 bpm, 130 psi,60 rpm, 1-3K tq,7 -10K WOB 5/17/2017 5/17/2017 0.50 COMPZN CASING CIRC X Pump 10 bbls hi-vis sweep. Circ 114 183.0 183.0 19:00 19:30 bbls seawater @8.5 bpm, 160 psi, 27%FO.Displace well to fresh water @6 bpm,80 psi,25%FO.Pumped 63 bbls fresh water.Monitor well.Blow down TD. 5/17/2017 5/17/2017 0.50 COMPZN CASING BHAH X Lay down single jt.DP.LD BHA#29. 183.0 0.0 19:30 20:00 5/17/2017 5/17/2017 1.50 COMPZN CASING ELOG X PJSM-Rig up Pollard wireline w/PDS 0.0 0.0 20:00 21:30 downhole camera.RIH to 182'WLM. POOH and rig down wireline. 5/17/2017 5/17/2017 0.50 COMPZN CASING BHAH X Make up BHA#29 to 70'MD.POOH 0.0 0.0 21:30 22:00 f/70'MD. 5/17/2017 5/17/2017 1.00 COMPZN CASING WAIT X Process downhole camera data. 0.0 0.0 22:00 23:00 Consult w/engineer. 5/17/2017 5/18/2017 1.00 COMPZN CASING REAM X RIH w/BHA#29.Tag at 173'MD 0.0 173.0 23:00 00:00 w/10K weight.PU=55K SO=50K Rot=52K.PU to 168'MD and ream down w/60 rpm.Stall out at 173'MD w/3-4K tq.PU to 168'MD and ream down w/10 rpm.Stall out at 173'MD w/3K tq. Page 31/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) =v 3M-28 Phiiiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(EKE)' 5/18/2017 5/18/2017 0.50 COMPZN CASING CIRC X Circulate at 7 bpm,120 psi,24%FO. 173.0 173.0 00:00 00:30 Circulate total of 63 bbls.Blow down TD. 5/18/2017 5/18/2017 0.50 COMPZN CASING BHAH X POOH.Lay down lightbulb mill.Make 173.0 0.0 00:30 01:00 up 8 1/2"bell mill 5/18/2017 5/18/2017 1.00 COMPZN CASING BHAH X RIH w/BHA#30 to 169'MD. 0.0 169.0 01:00 02:00 5/18/2017 5/18/2017 3.50 COMPZN CASING BHAH X Wash and ream to 182'MD.7 bpm, 169.0 189.0 02:00 05:30 470 psi,26%FO.Mill f/182'MD t/188' MD.7 bpm,470 psi,26%FO,60 RPM,0-2K tq, 10-12K WOB, Pump 5 bbl hi-vis sweeps at 185'MD and 187' MD. At 188'MD WOB dropped from 12K to 3K w/60 rpm OK tq,Tag at 189' MD x2 w/no circulation and no rotation.Monitor well.Static.Blow down TD. 5/18/2017 5/18/2017 1.00 COMPZN CASING BHAH X POOH and lay down BHA 189.0 0.0 05:30 06:30 5/18/2017 5/18/2017 0.75 COMPZN CASING BHAH X Make up BHA#31 and RIH to 165' 0.0 190.0 06:30 07:15 MD.MU stand of DP.RIH and tag at 190'MD. 5/18/2017 5/18/2017 0.75 COMPZN CASING CIRC X Pick up to 188'MD.Break circulation, 190.0 189.0 07:15 08:00 3 bpm,40 psi,RIH and tag at 190' MD.Attempt to push fish downhole. Set 15K down weight.Pick up to 189' MD.Pump 5 bbl hi-vis sweep.Circ 113 bbls seawater @ 5 bpm,40 psi. Minimal sand/cement returns at surface. 5/18/2017 5/18/2017 0.50 COMPZN CASING BHAH X Monitor well.Static.POOH w/BHA 189.0 0.0 08:00 08:30 #31.Lay down bullnose. 5/18/2017 5/18/2017 0.50 COMPZN CASING TRIP 'X Make up BHA#32.5 3/4"empty 0.0 190.0 08:30 09:00 overshot. RIH on DP and tag up at 190'MD. 5/18/2017 5/18/2017 0.50 COMPZN CASING CIRC X Wash and ream f/190'MD t/195'MD. 190.0 197.0 09:00 09:30 7 bpm,50 psi, 10 rpm,OK tq,Pick up to 194"MD.Pump 10 bbl hi-vis sweep.Circulate 106 bbls seawater at 10 bpm,80 psi.Rotate down w/no pump to 197'MD.5K WOB. 5/18/2017 5/18/2017 0.50 COMPZN CASING TRIP X POOH w/BHA#32. 197.0 0.0 09:30 10:00 5/18/2017 5/18/2017 0.50 COMPZN CASING OTHR X Consult w/engineer. 0.0 0.0 10:00 10:30 5/18/2017 5/18/2017 0.50 COMPZN CASING BHAH X Install 3 1/2"plain control grapple in 0.0 193.0 10:30 11:00 overshot..RIH to 193'MD. 5/18/2017 5/18/2017 0.50 COMPZN CASING FISH X Attempt to engage bent jt fish.Tag up 193.0 197.0 11:00 11:30 at 195'MD.Pump 3 bpm,40 psi. Rotate down to 197'MD.Observe pressure increase fluctuating between 190-90 psi. 5/18/2017 5/18/2017 0.25 COMPZN CASING TRIP X POOH.No Fish. 197.0 0.0 11:30 11:45 5/18/2017 5/18/2017 0.25 COMPZN CASING TRIP X RIH w/same BHA.Tag up at 196'MD. 0.0 196.0 11:45 12:00 Page 32/39 Report Printed: 6/1/2017 .,,:::::,...,. ,iiii& 0 • Operations Summary (with Timelog Depths) 0 3M-28 ConocciPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(EKE) 5/18/2017 5/18/2017 0.75 COMPZN CASING FISH X Pump at 3 bpm,40 psi.Rotate down 196.0 198.0 12:00 12:45 at 5 rpm to 198'MD.Observe pressure increase fluctuating between 190-90 psi.Repeat 3x..Stage overshot at 198'MD w/5K down weight. 5/18/2017 5/18/2017 1.00 COMPZN CASING CIRC X Rig up filter unit.Displace well w/70 198.0 198.0 12:45 13:45 bbls fresh water filtered fresh water. 5/18/2017 5/18/2017 0.50 COMPZN CASING TRIP X Lay down single jt DP.Blow down TD. 198.0 0.0 13:45 14:15 POOH.Lay down overshot. 5/18/2017 5/18/2017 1.75 COMPZN CASING ELOG X PJSM-Rig up Pollard wireline w/PDS 0.0 0.0 14:15 16:00 downhole camera.RIH to 189'WLM. POOH and rig down wireline. 5/18/2017 5/18/2017 2.00 COMPZN CASING OTHR X Process downhole camera data. 0.0 0.0 16:00 18:00 Consult w/engineer. 5/18/2017 5/18/2017 0.50 COMPZN CASING BHAH X PJSM-Mobilize BHA to rig floor. 0.0 0.0 18:00 18:30 5/18/2017 5/18/2017 2.00 COMPZN CASING BHAH X Make up BHA#35 to 185'MD. 0.0 185.0 18:30 20:30 PU=47K SO=50K 5/18/2017 5/18/2017 1.00 COMPZN CASING FISH X Wash down f/185'MD t/186'MD.Tag 185.0 195.0 20:30 21:30 top of fish at 188'MD.Attempt to engage fish with grapple working between 183'MD and 195'MD. Consistently tag TOF at 188'MD but overshot is rolling off. 5/18/2017 5/18/2017 0.50 COMPZN CASING BHAH X Blow down TD.POOH.Lay down 195.0 0.0 21:30 22:00 oversize overshot. 5/18/2017 5/18/2017 0.50 COMPZN CASING BHAH X Make up BHA#36 to 188'MD 0.0 188.0 22:00 22:30 5/18/2017 5/18/2017 0.50 COMPZN CASING FISH X Orient in quadrants and attempt to 188.0 188.0 22:30 23:00 engage fish.PU=47K SO=50K. Disengage from TD and orient pipe with chain tongs.Overshot continues to roll off TOF. 5/18/2017 5/19/2017 1.00 COMPZN CASING BHAH X POOH and lay down BHA. 188.0 0.0 23:00 00:00 5/19/2017 5/19/2017 1.00 COMPZN CASING BHAH X Bend a joint of 3 1/2"DP 4°and allow 0.0 188.0 00:00 01:00 to cool.Make up BHA#37 to 188'MD. PU=47K 50=50K. 5/19/2017 5/19/2017 1.50 COMPZN CASING FISH X Set 8K down weight on fish.PU and 188.0 188.0 01:00 02:30 orient bend in quadrants attempting to engage fish.Circulating at 2.5 bpm,40 psi,23%FO.Overshot rolling off TOF. 5/19/2017 5/19/2017 0.50 COMPZN CASING BHAH X Blow down TD.POOH.Change out 188.0 0.0 02:30 03:00 overshot. 5/19/2017 5/19/2017 0.25 COMPZN CASING BHAH X Make up BHA#38 to 188'MD. 0.0 188.0 03:00 03:15 PU=47K 50=50K. 5/19/2017 5/19/2017 0.25 COMPZN CASING FISH X Set 8K down weight on fish.PU and 188.0 188.0 03:15 03:30 orient bend in quadrants attempting to engage fish.Overshot rolling off TOF. 5/19/2017 5/19/2017 0.50 COMPZN CASING BHAH 'X Blow down TD.POOH.Change out 188.0 0.0 03:30 04:00 overshot and bent jt.of 3 1/5"DP w/straight jt of 4"DP. 5/19/2017 5/19/2017 0.50 COMPZN CASING BHAH X Make up BHA#39 to 188'MD. 0.0 188.0 04:00 04:30 PU=47K SO=50K. Page 33/39 Report Printed: 6/1/2017 • • '= Operations Summary (with Timelog Depths) 3M-28 ConocoPhititpss Rig: DOYON 14 Job: RECOMPLETION Time Log, Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/19/2017 5/19/2017 0.50 COMPZN CASING FISH X Set 8K down weight on fish.PU and 188.0 188.0 04:30 05:00 orient bend in quadrants attempting to engage fish.Overshot rolling off TOF. 5/19/2017 5/19/2017 0.50 COMPZN CASING BHAH X Blow down TD.POOH.Change out 188.0 0.0 05:00 05:30 straight jt of 4"DP w/1°bent jt of 4" DP.. 5/19/2017 5/19/2017 1.00 COMPZN CASING BHAH X Make up BHA#40 to 188'MD. 0.0 188.0 05:30 06:30 PU=47K SO=50K. 5/19/2017 5/19/2017 0.50 COMPZN CASING FISH X Set 8K down weight on fish.PU and 188.0 188.0 06:30 07:00 orient in quadrants attempting to engage fish.Overshot rolling off TOF. Attempt to wash over TOF at 3 bpm. Pump 5 bbl hi-vis sweep and chase at 8 bpm w/70 psi. 5/19/2017 5/19/2017 0.50 COMPZN CASING BHAH X Blow down TD.POOH and lay down 188.0 0.0 07:00 07:30 BHA#40. 5/19/2017 5/19/2017 1.25 COMPZN CASING BHAH X Mobilize and make up BHA#41 (4 0.0 188.0 07:30 08:45 3/4"DC's and straight jt 4"DP)to 188' MD 5/19/2017 5/19/2017 0.50 COMPZN CASING FISH X Attempt to engage fish.Overshot 188.0 188.0 08:45 09:15 rolling off TOF.Circulate @ 3 bpm,50 psi. 5/19/2017 5/19/2017 0.75 COMPZN CASING BHAH X Blow down TD.POOH and change out 188.0 0.0 09:15 10:00 straight jt 4"DP w/1°bent jt 4"DP. 5/19/2017 5/19/2017 0.50 COMPZN CASING BHAH X Make up BHA#42 to 188'MD. 0.0 188.0 10:00 10:30 5/19/2017 5/19/2017 0.75 COMPZN CASING FISH X Tag TOF and rotate string with chain 188.0 188.0 10:30 11:15 tongs 2 full turns without dropping off. Make up TD.Beak circ 3 b9m,50 psi. No pressure increase observed from previous trip.Rotate pipe w/tq limit set at 1K.Overshot not falling off TOF. Set 4K down weight and stall TD. Pick up with no overpull. 5/19/2017 5/19/2017 0.50 COMPZN CASING BHAH X Begin to POOH w/BHA#42.Change 188.0 188.0 11:15 11:45 of work scope.RIH w/BHA#42 to 188' MD. 5/19/2017 5/19/2017 0.75 COMPZN CASING CIRC X Rig up and displace well w/70 bbls 188.0 188.0 11:45 12:30 filtered fresh water to prep for downhole camera run. 5/19/2017 5/19/2017 1.25 COMPZN CASING BHAH X POOH and lay down BHA#42.. 188.0 0.0 12:30 13:45 5/19/2017 5/19/2017 1.00 COMPZN CASING BHAH X Make up BHA#43 to 132'MD.Make 0.0 187.0 13:45 14:45 up space out pup jts.Cont to RIH w/4" DP to 187'MD. 5/19/2017 5/19/2017 1.25 COMPZN CASING ELOG X Rig up bail extensions,pump-in sub 187.0 187.0 14:45 16:00 and wireline. 5/19/2017 5/19/2017 1.75 COMPZN CASING ELOG 'X RIH w/downhole camera to 187'WLM. 187.0 182.5 16:00 17:45 Pick up drillstring to 184.5'MD and 182.5'MD. 5/19/2017 5/19/2017 0.25 COMPZN CASING FLOG X Slack off drillstring and tag at 188' 182.5 186.0 17:45 18:00 MD.PU to 186'MD.Stage camera at 186'WLM.Rig up to pump filtered fresh water. 5/19/2017 5/19/2017 1.00 COMPZN CASING ELOG X PJSM-Pump filtered fresh water @ 1.5 186.0 186.0 18:00 19:00 bpm/20 psi w/logging w/downhole camera f/192'WLM to 187'WLM. Page 34/39 Report Printed: 6/1/2017 Operations Summary (with Timelog Depths) 3M-28 oz Cortocc Phitttps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 5/19/2017 5/19/2017 1.50 COMPZN CASING ELOG X Rig down wireline and bail extensions. 186.0 186.0 19:00 20:30 Blow down TD. 5/19/2017 5/19/2017 1.00 COMPZN CASING BHAH X PJSM-POOH,stand back DC's 186.0 0.0 20:30 21:30 5/19/2017 5/20/2017 2.50 COMPZN CASING BHAH X Mobilize BHA equipment to rig floor. 0.0 165.0 21:30 00:00 Make up milling BHA #44 .t/165'MD. 5/20/2017 5/20/2017 1.00 COMPZN CASING MILL X Wash down from 165'MD to 183'MD. 165.0 183.0 00:00 01:00 5 bpm,90 psi.Tag at 183'MD. Attempt to ream through at 183'MD. Rot wt-50K,40 rpm,5-7K WOB,3-5k tq.Unable to mill off. 5/20/2017 5/20/2017 1.00 COMPZN CASING BHAH X POOH and change out light bulb mill 183.0 0.0 01:00 02:00 for bell mill. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X MU BHA#45 to 159'MD.PU=55K 0.0 159.0 02:00 02:30 SO=55K 5/20/2017 5/20/2017 0.50 COMPZN CASING MILL X Wash down f/159'MD t/183'MD.PU 159.0 183.0 02:30 03:00 t/176'MD and ream down to 183'MD. 30 rpm,7K WOB,2-4K tq. Experiencing pipe bounce and chatter. 5/20/2017 5/20/2017 1.00 COMPZN CASING BHAH X POOH.Lay down bell mill and make 183.0 0.0 03:00 04:00 up upper string mill. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X MU BHA#46 to 159'MD. 0.0 159.0 04:00 04:30 5/20/2017 5/20/2017 1.00 COMPZN CASING MILL X Wash down f/159'MD t/176'MD.2 159.0 183.0 04:30 05:30 bpm=40 psi. Ream down t/183'MD2- 3K tq 5K WOB. 5/20/2017 5/20/2017 1.00 COMPZN CASING BHAH X POOH.Change out string mill w/bell 183.0 0.0 05:30 06:30 mill. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X MU BHA#47 and tag up at 185'MD. 0.0 185.0 06:30 07:00 5/20/2017 5/20/2017 1.50 COMPZN CASING MILL X MU TD.Mill f/185'MD t/186'MD.1.5 185.0 186.0 07:00 08:30 bpm,40 psi,8%FO,50 rpm, 1-2K tq, 9-12K WOB,PU=53K SO=53K. 5/20/2017 5/20/2017 0.75 COMPZN CASING BHAH X POOH.Move one lower DC upstring. 186.0 0.0 08:30 09:15 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X MU BHA#48 and tag at 185'MD. 0.0 185.0 09:15 09:45 5/20/2017 5/20/2017 1.25 COMPZN CASING MILL X Ream down t/186'MD.MIII at 186' 185.0 186.0 09:45 11:00 MD. 1.5 bpm,40 psi,8%FO,50 rpm, 1-2K tq,9-12K WOB.Pump 5 bbl hi- vis sweep and chase at 7 bpm,480 psi. 5/20/2017 5/20/2017 0.75 COMPZN CASING BHAH X POOH.Inspect bell mill.Center nub 186.0 0.0 11:00 11:45 worn. 5/20/2017 5/20/2017 0.75 COMPZN CASING BHAH X Change out bell mill for light bulb mill. 0.0 186.0 11:45 12:30 MU BHA#49 and tag at 186'MD. 5/20/2017 5/20/2017 0.50 COMPZN CASING MILL X Unable to drift past 186'MD.Pump at 186.0 186.0 12:30 13:00 1 bpm,40 psi Rotate at 50 rpm,OK tq, 10K WOB for 3 mins.Weight is milling off. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X POOH.Change out light bulb mill to 186.0 0.0 13:00 13:30 concave mill. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X MU BHA#50 and tag at 186'MD. 0.0 186.0 13:30 14:00 Page 35/39 Report Printed: 6/1/2017 • • Operations Summary (with Timelog Depths) 0 ., ,, 3M-28 Ctidips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time-. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth MKS) 5/20/2017 5/20/2017 2.25 COMPZN CASING MILL X Mill at 186'MD.2.5 bpm,40 psi,8% 186.0 195.0 14:00 16:15 FO,60 rpm, 1-2K tq, 10-15K WOB, PU=53K SO=53K.At 186.5'MD tq steadied out at 2K.60 rpm,7 bpm, 180 psi, 10K WOB.At 189'MD WOB dropped to OK.Stop rotation Wash down to 195'MD. 5/20/2017 5/20/2017 0.50 COMPZN CASING CIRC X Wash and ream f/195'MD t/200'MD 195.0 170.0 16:15 16:45 w/minimal tq and WOB in open hole. Increase pump rate to 8 bpm.PU to 170'MD.CBU.Cement and formation on bottoms up. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X Monitor well.Static.POOH and 170.0 0.0 16:45 17:15 change our concave mill to light bulb mill. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X MU BHA#51 and tag at 186'MD. 0.0 186.0 17:15 17:45 5/20/2017 5/20/2017 0.25 COMPZN CASING 'REAM X Wash and ream f/186'MD t/200'MD. 186.0 200.0 17:45 18:00 2 bpm,60 rpm, 1K tq. 5/20/2017 5/20/2017 1.00 COMPZN CASING MILL X Mill down f/200'MD 60 rpm, 1.5K tq,2 200.0 215.0 18:00 19:00 -3K WOB.Metal shavings observed at shakers on bottoms up.WOB fell off at 208'MD and tq increased to 2.5K. Con't to mill to 213'MD.Tq gradually decreasing from 208'MD to 213'MD w/0 WOB.Stop rotary a 213'MD,PU to 210'MD,slack off with no rotary to 215'MD.Tag up with 15K down weight. 5/20/2017 5/20/2017 1.00 COMPZN CASING CIRC X Circ 10 bbl hi-vis sweep.Displace well 215.0 215.0 19:00 20:00 w/75 bbls filtered fresh water. 5/20/2017 5/20/2017 0.75 COMPZN CASING BHAH X POOH. 15K overpull at 174'MD. 215.0 0.0 20:00 20:45 Turn drill string 180° to right.PU and continue to POOH.Lay down light bulb mill.Mill worn 50%. 5/20/2017 5/20/2017 0.50 COMPZN CASING BHAH X Make up BHA#51 and RIH to 212' 0.0 212.0 20:45 21:15 MD. 5/20/2017 5/20/2017 0.25 COMPZN CASING ELOG X Rig up wireline. 212.0 212.0 21:15 21:30 5/20/2017 5/21/2017 2.50 COMPZN CASING ELOG X PJSM-Pump filtered fresh water @ 1.5 212.0 212.0 21:30 00:00 bpm/40 psi w/logging w/downhole camera f/214'WLM. 5/21/2017 5/21/2017 2.75 COMPZN CASING ELOG X Cont w/camera run#10 212.0 212.0 00:00 02:45 5/21/2017 5/21/2017 0.25 COMPZN CASING ELOG X Rig down wireline. 212.0 215.0 02:45 03:00 5/21/2017 5/21/2017 1.50 COMPZN CASING OTHR X Attempt to reenter 9 5/8"casing.with 215.0 215.0 03:00 04:30 1°bent 4"DP. Unable to reenter. 5/21/2017 5/21/2017 2.00 COMPZN CASING BHAH X Lay down space out pups.POOH and 215.0 0.0 04:30 06:30 lay down bent jt.Blow down choke and kill lines. 5/21/2017 5/21/2017 1.00 COMPZN CASING SVRG X Open TD grabber door,Clean and 0.0 0.0 06:30 07:30 inspect saver sub and grabber dies. Change out grabber dies.Sim- ops/Mobilize BHA#53 tools to rig floor. 5/21/2017 5/21/2017 1.00 COMPZN CASING BHAH X MU BHA#53 and tag at 186'MD. 0.0 186.0 07:30 08:30 Page 36/39 Report Printed: 6/1/2017 • • ,,� Operations Summary (with Timelog Depths) 0 0 3M-28 $,‘ utiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/21/2017 5/21/2017 0.50 COMPZN CASING REAM X Rotate drill string 45°and weight 211.0 227.0 08:30 09:00 dropped off.Con't RIH and tag at 211' MD.Wash and ream from 211'MD to 227'MD.5 bpm,580 psi,50 rpm,OK tq,. 5/21/2017 5/21/2017 1.00 COMPZN CASING MILL X Spot mill at 227'MD w/2 bpm,70 psi, 227.0 235.0 09:00 10:00 50 rpm,0 Tq.Attempt to wear groove in casing f/10 min.Slack off/not taking weight.Retry pumping with 1 bpm. Stop rotation. Pick up 3'and then slack off.Observe 5K tq w/3-5K WOB at 235'MD.Mill f/10 mins. Pick up and slack off w/o rotary.Set down w/5-7K WOB. 5/21/2017 5/21/2017 2.00 COMPZN CASING MILL X PU without rotary to 213'MD w/10K 235.0 242.0 10:00 12:00 overpull.Rot at 50 rpm,3-4K tq to allow upper mill to clean exit point in 9 5/8"csg.Stroke drill string between 213'MD and 235'MD without tagging up.Wash and ream from 213'MD to 238'MD. Mill f/10 min at 238'MD.Mill to 238.5'MD.Hard tag w/10K WOB. PU w/15K overpull.Slack off drill string and hard tag at 238.5'MD. Mill to 242'MD,50 rpm,OK tq, 1 bpm,40 psi. 5/21/2017 5/21/2017 0.75 COMPZN CASING CIRC X Pump 5 bbl hi-vis sweep.Chase 242.0 215.0 12:00 12:45 w/seawater at 5.5 bpm,700 psi. Black formation sand observed at shakers on bottoms up.Shut down pump and pick up drill string w/35K overpull. Slack off/pick up w/35-40K overpull. Pipe free at 40K overpull. Pick up to 215'MD 5/21/2017 5/21/2017 0.50 COMPZN CASING CIRC X Consult engineer.Rig up and displace 215.0 215.0 12:45 13:15 well w/90 bbls filtered fresh water.5 bpm @ 1100 psi. 5/21/2017 5/21/2017 1.25 COMPZN CASING BHAH X POOH and lay down BHA#53. 215.0 0.0 13:15 14:30 5/21/2017 5/21/2017 1.00 COMPZN CASING ELOG X Rig up wireline.RIH w/downhole 0.0 0.0 14:30 15:30 camera to 185'WLM.Wellbore fluid too murky to make out images.POOH w/wireline. 5/21/2017 5/21/2017 0.75 COMPZN CASING BHAH X Make up bent jt.RIH on BHA#54 to 0.0 195.0 15:30 16:15 195'MD. 5/21/2017 5/21/2017 0.50 COMPZN CASING RURD X PU space out pups and stage DP at 195.0 217.0 16:15 16:45 217'MD.MU pump in sub and install bail extensions. 5/21/2017 5/21/2017 0.50 COMPZN CASING ELOG X RU wireline.MU and test downhole 217.0 217.0 16:45 17:15 camera.RIH w/wireline. 5/21/2017 5/21/2017 2.00 COMPZN CASING ELOG X PJSM-Pump filtered fresh water @ 1.5 217.0 217.0 17:15 19:15 bpm/40 psi while logging w/downhole camera f/217'WLM t/188'WLM 5/21/2017 5/21/2017 1.25 COMPZN CASING ELOG X POOH and rig down wireline. 217.0 217.0 19:15 20:30 5/21/2017 5/21/2017 0.75 COMPZN CASING BHAH X POOH and lay down BHA#54 217.0 0.0 20:30 21:15 5/21/2017 5/21/2017 0.25 COMPZN CASING SVRG X Service rig. 0.0 0.0 21:15 21:30 5/21/2017 5/21/2017 0.25 COMPZN CASING RURD X Lay down wireline sheaves. 0.0 0.0 21:30 21:45 Page 37/39 Report Printed: 6/1/2017 Operations Summary (with Timelog Depths) �< r4 Conoco Phillips ps 3M-28 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftK6) 5/21/2017 5/22/2017 2.25 COMPZN CASING RURD X PJSM-Offload pipe shed of 7"casing, 0.0 0.0 21:45 00:00 3 1/2"tubing and 2 3/8"tubing. 5/22/2017 5/22/2017 3.00 COMPZN CASING RURD X Con't to unload pipe shed of 3 1/2" 0.0 0.0 00:00 03:00 tubing.Perform MP2's. 5/22/2017 5/22/2017 4.50 COMPZN CASING RURD X Break and lay down Baker fishing 0.0 0.0 03:00 07:30 tools.Lay down bail extensions,4"DP pup jts,3 1/2" tubing pup jts and tbg equipment. 5/22/2017 5/22/2017 1.00 COMPZN CASING PULD X Lay down 6 1/4" and 4 3/4"drill 0.0 0.0 07:30 08:30 collars. 5/22/2017 5/22/2017 9.50 COMPZN CASING PULD X Lay down 5307'of 4"DP via 0.0 0.0 08:30 18:00 mousehole. 5/22/2017 5/22/2017 1.00 COMPZN CASING RURD X PJSM-Rig up and pull wear bushing. 0.0 0.0 18:00 19:00 5/22/2017 5/22/2017 1.50 COMPZN CASING RURD X Mobilize and rig up tubing handling 0.0 0.0 19:00 20:30 tools. 5/22/2017 5/22/2017 0.50 COMPZN CASING PULD X PU and RIH to 195'MD w/2 3/8"PH-6 0.0 195.0 20:30 21:00 tubing. 5/22/2017 5/22/2017 0.50 COMPZN CEMENT RURD X Rig up cement lines. 195.0 195.0 21:00 21:30 5/22/2017 5/22/2017 0.50 COMPZN CEMENT CIRC X Circulate 40 bbls seawater.2 bpm,60 195.0 195.0 21:30 22:00 psi. 5/22/2017 5/23/2017 2.00 COMPZN CEMENT CMNT X Pump 3 bbls water at 2 bpm, 110 psi. 195.0 195.0 22:00 00:00 Test lines to 1000 psi. Batch up and pump 10 bbls 14.5 ppg Mudpush w/dye at 2 bpm, 110 psi.Clean cement tubs and batch up and pump 29.4 bbls 15.7 ppg AS1 cement at 2 bpm, 125 psi.Cement to surface at 24 bbls cement away.Cement returns at 15.2 ppg.CIP at 24:00 hrs. 5/23/2017 5/23/2017 0.50 COMPZN CEMENT CMNT X Flush the cement line back to SLB 195.0 195.0 00:00 00:30 cementers. 5/23/2017 5/23/2017 0.50 COMPZN CEMENT PULD X POOH laying down 2-3/8"DP from 195.0 0.0 00:30 01:00 195'MD to surface. 5/23/2017 5/23/2017 1.00 COMPZN CEMENT RURD X Function the pipe rams. Flush the 0.0 0.0 01:00 02:00 BOP stack,choke/kill line,and cement line. Flush the IA and OA valves. Suck out the cellar box. 5/23/2017 5/23/2017 0.50 COMPZN CEMENT RURD X RD and lay down 2-3/8"DP running 0.0 0.0 02:00 02:30 equipment. 5/23/2017 5/23/2017 5.25 COMPZN WELLPR PULD X PJSM. Lay down the DP in the derrick 0.0 0.0 02:30 07:45 using the mouse hole 5/23/2017 5/23/2017 0.50 COMPZN CEMENT TRIP X TIH and tag top of cement(TOC)at 0.0 80.0 07:45 08:15 79.75'MD witnessed by AOGCC inspector Brian Bixby.. 5/23/2017 5/23/2017 0.50 COMPZN CEMENT TRIP X TOOH and lay down two single joints 80.0 0.0 08:15 08:45 of DP. 5/23/2017 5/23/2017 1.00 COMPZN CEMENT PRTS X RU pressure testing equipment. PT 0.0 0.0 08:45 09:45 the cement plug and 7"casing to 500 psi for 30 minutes(good test) witnessed by AOGCC inspector Brian Bixby.. 5/23/2017 5/23/2017 0.50 COMPZN CEMENT OWFF X Observe the well for flow for 30 0.0 0.0 09:45 10:15 minutes and the well is static. 5/23/2017 5/23/2017 0.25 COMPZN CEMENT RURD X Blow down and RD pressure testing 0.0 0.0 10:15 10:30 equipment. Page 38/39 Report Printed: 6/1/2017 • 1111) Operations Summary (with Timelog Depths) 3M-28 ConocoPhitlips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 5/23/2017 5/23/2017 1.50 COMPZN WELLPR PULD X Continue to lay down the DP in the 0.0 0.0 10:30 12:00 derrick using the mouse hole. Leaving 1 stand in the derrick. 5/23/2017 5/23/2017 0.75 COMPZN WELLPR TRIP X MU stack washing tool and TIH to 77' 0.0 77.0 12:00 12:45 MD. 5/23/2017 5/23/2017 1.00 COMPZN WELLPR RURD X Build 16 bbls of 9.8 ppg brine in the 77.0 77.0 12:45 13:45 pill pit. 5/23/2017 5/23/2017 0.25 COMPZN WELLPR CIRC X Pump 16 bbls of 9.8 ppg brine at 2 77.0 77.0 13:45 14:00 BPM=40 psi. 5/23/2017 5/23/2017 0.25 COMPZN WELLPR PULD X Lay down the three joints of DP and 77.0 0.0 14:00 14:15 the stack washing tool. 5/23/2017 5/23/2017 0.25 COMPZN WELLPR RURD X Flush the stand pipe with seawater 0.0 0.0 14:15 14:30 and blow down the top drive. 5/23/2017 5/23/2017 1.50 COMPZN WHDBOP RURD X PJSM. Change the lower pipe rams 0.0 0.0 14:30 16:00 from 7"solid body to 2-7/8"x 5" VBR's. Cleanout the ram cavities of sand,metal,and cement debris. 5/23/2017 5/23/2017 7.00 COMPZN WHDBOP RURD X Open up the blind rams and cleanout 0.0 0.0 16:00 23:00 the ram cavities of sand,metal,and cement debris. Inspect the ram cavities,close the doors and tighten the bolts. Open up the upper rams and cleanout the ram cavities of sand, metal,and cement debris. Inspect the ram cavities,close the doors and tighten the bolts. 5/23/2017 5/24/2017 1.00 COMPZN WHDBOP NUND X PJSM. ND the BOP stack. 0.0 0.0 23:00 00:00 5/24/2017 5/24/2017 2.00 COMPZN WHDBOP NUND X Continue to ND the BOP stack and set 0.0 0.0 00:00 02:00 back on the stump. ND the DSA and cement cross. 5/24/2017 5/24/2017 2.75 COMPZN WHDBOP NUND X NU the tubing head,tubing head 0.0 0.0 02:00 04:45 adaptor,and the dry hole tree. 5/24/2017 5/24/2017 1.75 COMPZN WHDBOP PRTS X Fill the dry hole tree with diesel and 0.0 0.0 04:45 06:30 PT the dry hole tree to 500 psi for 10 minutes(good test). 5/24/2017 5/24/2017 1.50 DEMOB MOVE RURD P Continue to clean the pits. Lay down 0.0 0.0 06:30 08:00 the trees in the cellar. Remove steam heater in the cellar and trash pump. Blow down the rig steam and water lines. RDMO to 2K-04. Rig Released at 08:00 hours. Page 39/39 Report Printed: 6/1/2017 -"1, KUP PD 3M-28 ClonocoPhillips g Well AttributW Max Angle TD Alaska.hc. Wellbore APIIUWI Held Name Wellbore Status incl C) MD(ftKB) Act Btm(ftKB) Cono.oIilhips 500292244200 KUPARUK RIVER UNIT PROD 71.86 4,004.49 13,240.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-28,6/6/2017 712;08 AM SSSV 180 12/4/2015 Last WO: 2/5/1994 Vertical schemat c(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 12,940.0 4/6/2016 Rev Reason: SUSPEND WELL pproven 5/31/2017 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 41.0 121.0 121.0 62.50 H-40 WELDED Casing Description SOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WhLen(I...Grade Top Thread Il i SURFACE 9 5/8 8.921 41.0 6,064.9 3,397.7 36.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread Original Production 7 6.276 2,191.0 13,222.1 6,272.2 26.00 L-80 BTC R-3 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top)ND) Top Incl Top(ftKB) (ftKB) (7 Des Com Run Date ID(in) '" 188.0 188.0 0.42 Fish Parted string mill and DP stuck side by side in the 9- 5/12/2017 4.000 5/8"casing(see camera run#9 in the well folder). t' 2,982.0 2,325.0 69.52 Sand(20/40 20/40 mesh sand 5/8/2017 0.000 ,M mesh) CONDUCTOR;41.0-121.0 ` 3,041.0 2,345.7 69.47 WLS RBP Wire line set RBP 5/7/2017 0.000 Hesitation Cement Squeeze; 12,645.0 5,896.1 ' 53.55 G Lock-Set Model G lock-set RBP 5/5/2017 - 0.000 69 0 fIKB RBP Perforations&Slots Shot Den Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn if y i 12,914.0 12,938.0 6,065.8 6,081.8 A-1,3M-28 -4/21/1994 4.0 IPERF 4 1/2"Csg Gun r � Cement Plug,79.7 nKa � 7 "" Cement Squeezes Top(TVD) Btm(TVD) fish,188 0 �j Top)ftKB) Btm(ftKB( (ftKB) (ftKB) Des Start Date Com 1 ` 69.0 180.0 69.0 180.0 Cement 5/16/2017 Perform Surface casing hole squeeze.Test lines to Squeeze 1000 psi. Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS cement,40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat AS1 cement,5 bbls water @ 2.6 , bpm,200 psi.140 psi trapped pressure.Bleed off to 0 psi.Bled back 2.5 bbls.Blow down cmt.line.Lay down circ valves.POOH to 129'MD.Rig up circ lines. Rig up to pump second stage of squeeze.Batch up 15.7 ppg AS1 cement.Pump 5 bbls neat AS1 cement, 40 bbls AS1 cement w/2 ppb cemnet,5 bbls neat AS1 cement,1.3 bbls water @ 3 bpm,230 psi 79.8 195.0 79.7 195.0 Cement Plug 5/22/2017 Pump 3 bbls water at 2 bpm,110 psi.Test lines to Sand(20/40 mesh);z,9ez.o r 'a, 1000 psi.Batch up and pump 10 bbls 14.5 ppg Mudpush w/dye at 2 bpm,110 psi.Clean cement tubs and batch up and pump 29.4 bbls 15.7 ppg AS1 IN cement at 2 bpm,125 psi.Cement to surface at 24 WLS RBP;3,041.0 bbls cement away.Cement returns at 15.2 ppg.CIP at 24:00 hrs. Notes:General&Safety End Date Annotation 11/1/2009 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;41.66,0646- . G Lock-Set RBP;12,645.0 IPERF;12,914.612,936.0 Original Production;2,191.6 13,222.1 • • Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday,June 01, 2017 9:43 AM To: Loepp,Victoria T(DOA) Subject: 3M-28 RBP Test Charts Attachments: G Lock RBP Pressure Test 5-5-17.pdf;WLS RBP Pressure Test 5-7-17.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached are the charts from both RBP pressure tests as requested in the latest Sundry. I didn't think the rig had charted those pressure tests but 1 was wrong so we don't have to mess with Totco. Let me know if you have any questions. Thanks, Andrew (303)378-8881 1 1 HR ------- • 30m. ---_____ ____----- _ - _ -------ir--- -- --„,,,,,,,,,„--\\'''--;`•__------,_</_,,----------------- -- ----------: ___. -1-/-------- "--7-----Y---. ----- - ----- ------->"---:----- . .--- --- ->"-------r ----- -------- --- --i----- -- '._- -------- ------ ---- -..„ .„,,, '----., • -- '---. 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O\2. 2A21-17 WELL LOG TRANSMITTAL DATA LOGGED II. G/G/2017 PROACTIVE DIAGNOSTIC SERVICES, INC. M. K.BENDER RECEIVED To: AOGCC �� � �� Makana Bender 333 West 7th Avenue Suite 100 AO, sr-+t,C Anchorage, Alaska 99501 /`� ll��V VV (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 JUN 0 2.017 1) Caliper Report 14-May-17 3M-28 Report/CD 50-029-22442-00 2) Signed : f' 'a'n'd 6,4,441 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: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM a\Achives\MasterTemptateFiles\Templates\Di stribution\Transmittals heels\ConocoPhi I lips_Tran smit.docx IiiCEIVED • v°‘4 -°a- MAY 2 5 2017 111 Memory Multi-Finger Caliper AOGCC 00 Lir Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3M-28 Log Date: May 14, 2017 Field: Kuparuk Log No.: 15074 State: Alaska Run No.: 2 API No. 50-029-22442-00 Pipe Description: 9.625 inch 36 lb. L-80 BTC Top Log Interval: Surface Pipe Use: Casing Bottom Log Interval: 185 Ft. (MD) Inspection Type : Restriction Inspection COMMENTS : This report represents un-corrected E-Line Measured Depth. This log was run to assess the condition of the casing with respect to I.D. restrictions. The caliper recordings indicate an interval of severe buckling from-169 feet to 185 feet(end of log). A large hole is recorded in the area of buckling from-174 feet to-176 feet, with additional holes from mill damage in the vicinity of the largest hole. The caliper recordings also indicate a possible I.D. restriction from what appears to be deformed pipe at the bottom of the large hole at 176 feet. A 3-D log plot overlay of the centered and un-centered caliper recordings across the casing logged is included in this report. Cross- sectional illustrations across the holes, as well as the possible I.D. restriction are included in this report. While logging the severe buckling, the caliper was pushed far off-center resulting in several intervals of full- finger extension. As a result, the measured internal diameters are smaller than the actual diameters and accurate mapping of the shape of the inside of the pipe is impossible where the caliper fingers were fully extended and not touching the inside of the pipe wall. Cross-sectional illustrations of the caliper recordings highlighting the full-finger extension are included in this report. This is the second time a PDS caliper has been run in this well and the first time the 9.625 inch casing has been logged. R. Rupe&D. Sparks C. Waldrop R. Dolcater F ,�,, 'iE;�7 EngineF1 i1i y/,.r:��J ��,iC. . j ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • CVS PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3M-28 Date : May 14, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordings Across 9.625 Inch Casing. Nominal I.D./O.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) • 11.1111 8 inches 10 1ft:100ft 230° 0° 90° 180° 270° 0° 182° 0° 90° 180° 270° 0° Maximum I.D. I 8 inches 10 Minimum I.D. l I 8 inches 10 Maximum Radius 4 inches 5 Minimum Radius 4 inches 5 LJ • i — 30 35 a r ,. . •. IL —f 45 _ f y : .y . 50 E I i i "V- - 55 -- 65 p - - - 70--� • • j —_ 80• •• -477;..- --.2. r • — — 85 — s — -- _ 90 = t • 95 TT 100 - 14 105 4. ----- .:.__ 110 10.5 flu . ---+ 115 • • • • .- -----�—� — 120 -143 ii 4.4 "" -_ 11 125 _ ,. T ,. - — _• 130 .1..... ` -- :•T air -x `---' -- 135 — s — 140 : 145 "t- 411 • • — — 150 -•. • ::' i Ow- - .117 -.,c 155 ,w ::" , ---� .... - i J uAR s . .M 160 ._ r . x •;;';'''• 1111 . : 165 Large Hole - (174' to 176') __T x 170 .: 4 1 175 __- _ • ... 4.444 : . ..4444 ffi 180 , " as Minimum Radius 4 inches 5 Apparent Additional Mill Maximum Radius Mechanical Damage 4 inches 5 Minimum I.D. 1 8 inches 10 Maximum I.D. 8 inches 10 Nominal I.D./O.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 1-1 1C 8 inches 10 1ft:100ft 230° 0° 90° 180° 270° 0° 182° 0° 90° 180° 270° 0° • • PDS Report Cross Sections Well: 3M-28 Survey Date: May 14,2017 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: C.Waldrop Cross Section at depth 174.460 Tool speed= 27 Nominal ID=8.92111111111 Nominal OD=9.625 Remaining wall area= 53% Tool deviation=0° f 4� • Full-Finger Multiple Holes 100%Wall Penetration HIGH SIDE=UP Extension • • (t .. PDS Report Cross Sections Well: 3M-28 Survey Date: May 14,2017 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: C.Waldrop Cross Section at depth 174.877 Tool speed= 87 111011114 Nominal ID=8.921 Nominal OD=9.625 Remaining wall area= 29% 11141°. Tool deviation= 1° 4," N I • / % / i // 1 II1 lik 1. Large Hole With Heavy Wall Loss 100%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections l+i� 10.E Well: 3M-28 Survey Date: May 14,2017 Field: Kuparuk Tool Type: UW MFC 40 Ext. No.218451 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: C.Waldrop Cross Section at depth 1 75.670 - Tool speed= 27 .—_--�____ Nominal ID=8.921 Nominal OD=9.625 Remaining wall area= 39% Tool deviation=2° 4 Y Possible I.D. Restriction From jDeformed Pipe 1 / Large Hole With Additional Mill Damage 100%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections 1-111 OIL Well: 3M-28 Survey Date: May 14,2017 Field: Kuparuk Tool Type: UW MFC 40 Ext. No.218451 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: C.Waldrop Cross Section at depth 1 77.040 Tool speed= 27 Nominal ID=8.921 Nominal OD=9.625 j Remaining wall area= 57% Tool deviation=3° 1 I 1 V Full-Finger Extension Full-Finger Extension in Area of Severe Buckling HIGH SIDE=UP • • PDS Report Cross Sections Well: 3M-28 Survey Date: May 14, 2017 Field: Kuparuk Tool Type: UW MFC 40 Ext. No.218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C.Waldro. Cross Section at depth 183.250 Full-Finger Extension Tool speed= 27 Nominal ID=8.921 Nominal OD=9.625 Remaining wall area= 57% Tool deviation=2° N. Full-Finger Extension in Area of Severe Buckling HIGH SIDE= UP i ilk KUP PROD • 3M-28 i� PI'Uii. Conoco Q Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl 7) MD(ftKB) Act Btm(ftKB) cm0,4,.nps 500292244200 KUPARUK RIVER UNIT PROD 71.86 4,004.49 13,240.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-28,4/15/201711:37:13 AM SSSV:TRDP 180 12/4/2015 Last WO: 2/5/1994 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag.SLM 12,940.0 4/6/2016 Rev Reason:PULL CSV,SET PLUG& pproven 4/15/2017 CATCHER,GLV C/O,TRING SHOT 8 CHEM HANGER 37.0-. 1.- -uCasing Strings ---r..„._,,. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 -40 WELDED i'�11. J - J H Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread „,-.SURFACE 9 5/8 8.921 41.0 6,064.9 3,397.7 36.00 L-80 BTC CONDUCTOR;I1.0-121.0 Casing Description OD(In) ID tin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 38.9 13,222.1 6,272.2 26.00 L-80 BTC R-3 Tubing Strings Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(,..Wt(lb/ft) Grade Top Connection �n TUBING 31/2 2.992 37.0 12,799.2 5,991.1 9.30 L-80 EUE8rdABMOD SAFETYVLV;1,950.0 r11: Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com lin) 37.0 37.0 0.12 HANGER McEvoy Gen IV,3 1/2",5M Tubing Hanger w/L-80,EUE 2.992 8rd Tubing 1,950.0 1,805.9 41.17 SAFETY VLV CAMCO 3 1/2"TRDP-4E SSSV,5.25"OD,2.812"ID 2.812 111 12,759.8 5,966.2' 51.16 PBR Baker PBR w/10'stroke,5.875"OD bbl,3.00"ID 3.000 (sheared) GAS LIFT;3,971.5 - 12,773.4 5,974.8 50.91 PACKER Baker FHL Retr Pkr,65K#shear or rotational release 3.000 II3.00"ID I 12,788.7 5,984.4 50.64 NIPPLE CAMCO 3 1/2"D-Nipple,4.50"OD,2.750"ID,2.750" 2.750 Nogo profile 12,798.3 5,990.5 50.49 SOS BAKER 3 1/2"Shear Out Sub,4.50"OD(Sheared) 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl - Top(ftKB) (ftKB) (') Des Com Run Date ID(in) SURFACE,41.7-6.064.9--A 12,733.0 5,949.5 51.72 CUT TUBING STRING SHOT FROM 12,733'-12,743'RKB 4/11/2017 3.000 12,738.0 5,952.6 51.59 CHEM CUT CUT TUBING @ 12,738'RKB WITH 2-5/8" 4/11/2017 2.000 CHEMICAL CUTTER GAS LIFT;8,053.1 12,778.0 5,977.6 50.83 CATCHER 3"GS&RIG CATCHER SUB(OAL=125") 4/3/2017 0.000 12,788.0' 5,984.0 50.65 PLUG 2.75"CA-2 PLUG(29'GAL LIH) 4/3/2017 0.000 IPerforations&Slots I Shot Dens Top(TVD) Atm(TVD) (shots/f GAS LIFT;10,484.3g.•,.-_, Top(ftKB) Blm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,914.0 12,938.0 6,065.8 6,081.8 A-1,3M-28 4/21/1994 4.0 IPERF 4 1/2"Csg Gun Mandrel Inserts St ati . onN Top(ND) Valve Latch Port Sloe TRO Run GAS LIFT;11,805.7 Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (In) (pal) Run Date Com 1 3,971.5 2,671.5 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/2017 2 8,053.1 4,118.7 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/2017 - -. 3 10,484.3 4,992.6 Camco KBUG 1 GAS LIFT DMY 'BK 0.000 0.0 7/22/2018 4' 11,805.7 5,494.4 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/22/2016 ' 5 12,709.8 5,935.2 Cameo MMM 11/2 GAS LIFT OPEN 4/4/2017 Notes:General&Safety GAS LIFT,12,7098 End Date Annotation 11/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1 CUT TUBING;12,733.0 CHEM CUT;12,739.0 i PBR;12,759.8 1 PACKER;12,773.4 l MI ff CATCHER;12,778.0 _I�I t PLUG;12,788.0 ;�I/1(/'I� VALVE;12,788.0 ')(j�, NIPPLE;12,788.7 "'NNNfff!!l a SOS;12,798.3 (PERF;12,914.0-12,938.0 PRODUCTION;38.9-13,222.1 \g2\ •vt2 • (Las 2.4 G WELL LOG TRANSMITTAL I�. DATA LOO E PROACTIVE DIAGNOSTIC SERVICES, INC. /G/2Q1 M.K.BEND To: AOGCC RELIED Makana Bender 333 West 7th Avenue MAY 2 5 2017 Suite 100 Anchorage,Alaska 99501 (907) 793-1225 AOGCC 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 JUN 0 <12017, 1) Caliper Report 08-May-17 3M-28 Report/CD 50-029-22442-00 2) Signed : Q ' '�� !/��%�� '�' 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: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhi Ilips_Transmit.docx 1/4c)4-0k2. RftEIVED • 2:6/-4 G7 III MAY 2 5 2017 Memory Multi-Finger Caliper ill WO AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3M-28 Log Date: May 8, 2017 Field: Kuparuk Log No.: 15072 State: Alaska Run No.: 1 API No. 50-029-22442-00 Pipe Description: 7 inch 26 lb. L-80 BTC R-3 Top Log Interval: Surface Pipe Use: Casing Bottom Log Interval: 2,812 Ft. (MD) Inspection Type : Restriction Inspection COMMENTS : This caliper data is tied into the top of joint 1 at 32.74 feet(Driller's Depth)per the Casing Detail dated February 1, 1994. This log was run to assess the condition of the casing with respect to I.D. restrictions. The caliper recordings indicate an interval of axial displacement due to buckling with slight oval deformation from—187 feet to—196 feet. A 3-D log plot overlay of the centered and un-centered caliper recordings across the casing logged, as well as a close-up of the caliper recordings across the interval of axial displacement are included in this report. Although the two opposing bends do not present a significant I.D. restriction, it will cause assemblies of long length and/or large diameters trouble drifting through this interval. The remainder of the 7 inch casing logged appears to be in good condition with respect to internal corrosive and mechanical damage with no significant wall penetrations or areas of cross-sectional wall loss recorded. MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations(> 19%) are recorded throughout the casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (>4%)are recorded throughout the casing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the casing logged. R. Rupe C. Waldrop T. Wiese r i'H Fngirie x{s} ride,t(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@memorylog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • fits PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3M-28 Date : May 8, 2017 Description : Detail of Caliper Recordings Across Interval of Axial Displacement. Nominal I.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 5.5 inches 7,5•1ft:240ft 53° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° Maximum I.D. I I 5.5 inches 7.5 Minimum I.D. I I 5.5 inches 7.5 Maximum Radius 2.75 inches 3.75 Minimum Radius i 2.75 inches 3.75 Deviation I I 0 50 !. 4 t oar __.-_. Eil-'..; --- 160 MOM. I - 170 ::' .. [ 180 i ....... ............. 190 ... Mig 1 O. 200 '„ It ' ' ' 210 =,, 220 M.; . e ' 230 t,` 240 WO' .: • i cliIs PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3M-28 Date : May 8, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordings From Surface to 2,812 Feet. Nominal I.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 5.5 inches 7.5 1ft:900ft 38° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° Maximum I.D. I 5.5 inches 7.5 Minimum I.D. 5.5 inches 7.5 Maximum Radius 2.75 inches 3.75 Minimum Radius i 2.75 inches 3.75 Deviation 1 o 100 z ...:... ,„,,,:"..,, 100 .,z,:::,.al R — 150 I. 200 ` __-- 74 • :::i ; !111 -tF Mi9300 i . , -'.... ' --":".— tn , , , ., 350 F i 1 —i ; , ---- 400 k - • a I � �� 450 :,' I IMM 1 500 Iii ' s - - tani ' ___ . ! 1. 550 til . 110111=11 eI ■iw1 1111NEKIN. .. MEWL! 600 ■II ; 650 t IIII i .,... .Nim700 .. ". 750 800 . 3 t iMiliestJ ', �� � v 850 ... 1 fi , _ , , .. .. „.i , : - - LI 900 i M 950 JIM mi `.. -- 1000 Mir VII it 1050 Elf Eli= 0 0 �WMa IIIMMME r ����� 1150 EJ1 i ti ,-,,.'7: 1200 Eli , _ .. I•� . . 1250 :::: - . 1300 +\11 i;" r Till 1350 �S il ,f 1400 J!J —— '.. ilifil 1450o if♦ 1500 4. f : 1550 V- 11 W1 1600 Egaiii iiiiiMMMI 1650 ,,, 1700 i .'4 - jul_ I750 • • 1800 - - r 1850 = .Ti. .t:, ,:f '.— ___ 7. 1900 •_ f` - u. 1950 • f , �,, 1.:. 2000 — I. ,a :.1 2050 a :{ 1 } 2100 • 1 2150 - 2200 .. fn• I yt ..dye `�`, i-, - — 2250 ) 1—... 2300 t • 2350 — .- ' 2400 2450 • • o N.; s 1 _ ` ` -- 2500 r I _ 1 2550 2600 5 ill _ ,, .., 2650 „, • l .. . 2700 I 5. 4 41 --- 2750 ,11 A 2800 - 1. Deviation I I 0 100 Minimum Radius 2.75 inches 3.75 Maximum Radius • 2.75 inches 3.75 Minimum I.D. I I 5.5 inches 7.5 Maximum I.D. I 5.5 inches 7.5 Nominal I.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) • 5.5 inches 7.5 ft 1ft:90038° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° • . Correlation of Recorded Damage to Borehole Profile • Pipe 1 7. in (32.8'-2,811.8') Well: 3M-28 Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: May 8, 2017 . Approx.Tool Deviation ■ Approx.Borehole Profile 1 33 5 198 10 412 15 626 ■ 20 840 25 1,055 0111 ID 30 im 1,270 c Z - L c 35 I 1,482 a '0 0 40 I 1,697 45 1,914 50 2,128 II I 55 - 2,342 60 2,557 65 2,774 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=65 • • PIO PDS Report Overview 41-k. t_ Body Region Analysis Well: 3M-28 Survey Date: May 8,2017 Field: Kuparuk Tool Type: UW MFC 40 Ext. No.218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA No. of Fingers: 40 Pipe 7 in. 26 ppf L-80 BTC R-3 Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 BTC R-3 6.276 in. 33 ft. 2,812 ft. Penetration (%wall) Damage Profile(%wall) 80 ill ion Penetration body Elm Metal loss body 0 50 100 1 60 40 20 0 0 to 20 to 40 to over 20% 40% 85% 85% 26 Number of joints analyzed(total=65) 65 0 0 0 Damage Configuration(body) 10 8 6 4 51 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=6) 3 0 3 0 0 Bottom of Survey=65 • • __ PDS Report Joint Tabulation Sheet Well: 3M-28 Survey Date: May 8, 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 R-3 Casing 6.276 in. 0.362 in. 33 ft. 2,812 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 33 0 0.03 8 1 6.26 2 69 0 0.02 6 1 6.20 3 112 0 0.02 6 2 6.17 4 155 0.08 0.07 18 4 6.24 Axial Displacement. Slight Oval Deformation. ■ 5 198 0.07 0.07 19 4 6.24 Shallow Line of Pits. 6 240 0 0.02 6 1 6.20 7 283 0 0.04 10 2 6.18 8 326 0 0.03 9 1 6.20 9 368 0 0.04 10 3 6.21 s 10 412 0 0.04 12 2 6.20 ■ 11 454 0 0.04 11 2 6.24 12 498 0 0.02 6 2 6.20 13 541 0 0.04 10 2 6.21 14 584 0 0.03 9 2 6.21 15 626 0 0.04 11 2 6.20 ■ 16 670 0 0.04 11 2 6.20 ■ 17 712 0 0.04 11 3 6.20 18 756 0 0.03 8 3 6.18 19 798 0 0.04 11 3 6.20 20 840 0 0.03 9 2 6.25 21 883 0 0.03 9 2 6.17 22 926 0 0.04 10 3 6.20 i 23 970 0 0.05 13 4 6.22 ■ 24 1013 0 0.06 15 3 6.23 Shallow Line of Pits. 25 1055 0 0.04 10 3 6.23 26 1098 0 0.04 12 2 6.23 ■ 27 1141 0 0.04 12 3 6.19 ■ 28 1183 0 0.06 16 2 6.24 Shallow Pitting. 29 1227 0 0.02 6 1 6.18 30 1270 0 0.05 12 2 6.20 31 1311 0 0.02 6 2 6.19 ill 32 1355 0 0.04 11 2 6.21 ■ 33 1397 0 0.04 11 2 6.26 34 1439 , 0 0.02 6 2 6.21 35 1482 0 0.04 10 2 6.18 36 1525 0 0.04 10 3 6.18 37 1569 0 0.05 14 3 6.18 38 1610 0 0.03 9 2 6.26 39 1654 0 0.04 10 2 6.23 40 1697 0 0.03 7 2 6.20 41 1741 0 0.02 6 2 6.16 42 1785 0 0.03 9 2 6.24 43 1828 0 0.03 9 2 6.24 44 1870 0 0.03 8 2 6.24 45 1914 0 0.03 9 3 6.24 46 1958 0 0.03 9 2 6.22 47 2001 0 0.04 11 2 6.20 48 2043 0 0.03 9 2 6.17 49 2084 0 0.05 14 2 6.24 ■ 50 2128 0 0.06 16 2 6.20 Shallow Pitting. IPenetration Body Metal Loss Body Page 1 • • PDS Report Joint Tabulation Sheet Well: 3M-28 Survey Date: May 8, 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 R-3 Casing 6.276 in. 0.362 in. 33 ft. 2,812 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 51 2170 0 0.05 12 3 6.16 52 2214 0 0.05 13 3 6.18 53 2257 0 0.03 8 3 6.21 54 2299 0 0.03 7 2 6.22 55 2342 0 0.06 15 2 6.20 Shallow Pitting. 56 2384 0 0.02 6 1 6.27 57 2428 0 0.04 11 2 6.19 58 2472 0 0.04 12 3 6.21 59 2516 0 0.05 15 3 6.19 Shallow Line of Pits. 60 2557 0 0.05 14 2 6.27 61 2601 0 0.04 10 3 6.21 62 2644 0 0.04 11 2 6.18 63 2688 0 0.04 12 3 6.23 64 2731 0 0.04 11 2 6.23 65 2774 0 0.03 7 2 6.18 IPenetration Body Metal Loss Body Page 2 Drilling KUP PROD S 3M-28 ConocoPhillips swens Well Attributes Max Angle&MD TD Alaska,!TIC. Wellbore APIIUWI Field Name Wellbore Status Incl("I MD(ftKB) Act Btm(ftKB) ,.cn,,,.nPrrinps 500292244200 KUPARUK RIVER UNIT PROD 71.86 4,004.49 13,240.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M.20,411532017 1137,1 3 AM SSSV:TRDP 180 12/4/2015 Last WO: 2/5/1994 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,940.0 4/6/2016 Rev Reason: PULL CSV,SET PLUG& pproven 4/15/2017 CATCHER,GLV C/O,TRING SHOT&CHEM HANGER;37.0 I��SII 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 41.0 121.0 121.0 62.50 H-40 WELDED tilt'A�i1 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread ,,o SURFACE 95/8 8.921 41.0 6,064.9 3,397.7 36.00 L-80 BTC CONDUCTOR;41.0-121.0--4Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread PRODUCTION 7 6.276 38.9 13,222.1 6,272.2 26.00 L-80 BTC R-3 Tubing Strings Tubing Description (String Ma...I'D" I Top(ftKB) I Set Depth(ft..f Set Depth(TVD)(,..I Wt(Ib/ft) (Grade I Top Connection TUBING 3 1/2 2.992 37.0 12,799.2 5,991.1 9.30 L-80 EUEBrdABMOD SAFETY VLV;1,950.0 Completion Details ITop(ftKB) Top(TVD((ftKB) Top Incl(°) Item Des Com Nin)ominaI ID 37.0 37.0 0.12 HANGER McEvoy Gen IV,3 1/2",5M Tubing Hanger w/L-80,EUE 2.992 8rd Tubing 1,950.0 1,805.9 41.17 SAFETY VLV CAMCO 3 1/2"TRDP-4E SSSV,5.25"OD,2.812"ID 2.812 12,759.8 5,966.2 51.16 PBR Baker PBR w/10'stroke,5.875"OD bbl,3.00"ID 3.000 (sheared) GAS LIFT;3,971.5 12,773.4 5,974.8 50.91 PACKER Baker FHL Retr Pkr,65Ke shear or rotational release 3.000 3.00°ID 12,788.7 5,984.4 50.64 NIPPLE CAMCO 3 1/2"D-Nipple,4.50"OD,2.750"ID,2.750" 2.750 I Nogo profile 12,798.3 5,990.5 50.49 SOS BAKER 3 1/2"Shear Out Sub,4.50"OD(Sheared) 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(In) SURFACE;41.0-6.084.9--• 0 12,733.0 5,949.5 51.72 CUT TUBING STRING SHOT FROM 12,733'-12,743'ftKB 4/11/2017 3.000 I 12,738.0 5,952.6 51.59 CHEM CUT CUT TUBING @ 12,738'RKB WITH 2-5/8" 4/11/2017 2.000 CHEMICAL CUTTER GAS LIFT;8,053.1 12,778.0 5,977.6 50.83 CATCHER 3"GS&RIG CATCHER SUB(OAL=125") 4/3/2017 0.000 I 12,788.0 5,984.0 50.65 PLUG 2.75"CA-2 PLUG(29'OAL LIH) 4/3)2017 0.000 Perforations&Slots I Shot Dans (ehotsll GAS LIFT;10,484.3 Top(RTop(TVD) Btm(TVD( (ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date t) Type Com 12,914.0 12,938.0 6,065.8 6,081.8 A-1,3M-28 4/21/1994 4.0 (PERF 4 1/2"Csg Gun Mandrel Inserts St ati N MID) D) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Modal OD(in) Sore Type Type (in) (pal) Run Date Com GAS LIFT;11,505.] _. 1 3,971.5 2,671.5 Camco KBUG 1'GAS LIFT 'DMY BK 0.000 0.0 4/4/2017 2 8,053.1 4,118.7 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 4/4/2017 - 3 10,484.3 4,992.6 Camco KBUG 1 GAS LIFT 'DMY BK 0.000 0.0 7/22/2016 4 11,805.7 5,494.4 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/22/2016 5 12,709.8 5,935.2 Camco MMM 11/2 GAS LIFT OPEN 4/4/2017 Notes:General&Safety GAS LIFT;12,705.8 4Iaa End Date Annotation 11/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 CUT TUBING;12,733.0 CHEM CUT;12,738.0 1 PER;12,759.8 11 PACKER;12,773.4 - UI®I'f tit .11 I( l CATCHER;12,778.0 oI1414f PLUG;12,788.0 ��� VALVE;12,788.0-5 'rill" NIPPLE;12,788.7 4110 I SOS;12,798.3 • IPERF;12,914.0-12,938.0 PRODUCTION;38.9-13,222.1 • • CA.� NG /TUBING / LINER DETAIL ARCO ALASKA/Subsidiary of Atlantic Richfield WELL: 3M-28 DATE: 2!1/94 PAGE: 1 of 1 #ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 7" PRODUCTION CASING TOPS ABOVE RKB -11.00 LANDING JT. 43.74 -11.00 299 Jts. 7", 26#, L-80, BTC-MOD, R-3, CLASS A 12760.50 32.74 Marker Joint-7", 26#, L-80, BTC. (TOP20.62', BTM. 22.34') 41.80 12793.24 7 Jts. 7", 26#, L-80, BTC-MOD, R-3,CLASS A 294.51 12835.04 Davis Lynch 7"Float Cel!ar 1.35 13129.55 2' Jts 7",26#, L-80, BTC, R-3, Class A 83.51 13130.90 Davis Lynch 7" Float Shoe 1.52 13214.41 Shoe set @ 13215.93 RKB= 38.89 TD = 13240.00 PBTD= 13129.55 RATHOLE= 24.07 LANDING JT WILL BE JT#309. Marker jt. between#9 and#10. Bowspring centralizers in middle of jts#3->#9. Total of 7 run. ROTCO Rigid centralizers on#1  its yr/stop bands 10-12 ft. from ends. 17 ROTCO centering guides on its#; 258, 261,264,267,270, 273,276, 279,282,285,288, 291,294,297,300,303,308 TORQUE 7"26#, L-80, BTC MOD: (BASE OF TRIANGLE) CATS PAW PIPE DOPE ON BTC-MOD BAKERLOK TO TOP FLOAT COLLAR RAN: 308-JTS. 7", 26#, L-80, BTC- MOD, R-3, CLASS A 1- Marker Joint-7", 26#, L-80, BTC-MOD CLASS A SUPERVISOR: DC Lutrick/BJ Fontenot MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg <Q/l z,4 7 DATE: 5/23/2017 P. I. Supervisor r' 1 FROM: Brian Bixby SUBJECT: Plug Verification Petroleum Inspector KRU 3M-28 CPAI - PTD 1940120; Sundry 317-203 May 23, 2017: I arrived location and got up with Larry Hill (Company man for Doyon 14 Rig). Look at a sample of the cement they use and it was hard. Witnessed them tag the TOC @ 79 feet from the rig floor (46 feet from the top of pad level). Then witnessed them stack 10,000 pounds on top of the cement using drill pipe and the top drive. The drill pipe was starting to bend pretty good and the Larry Hill (company man) said it was fine to just go to 10,000 pounds. The pipe never moved with the 10K on it. The cement appeared to be good. Pulled the drill pipe out of the hole and closed the blind rams and witnessed them pressure up on the cement to 500 psi and held it for 30 minutes. The pressure test was charted and flat lined for 30 minutes. Attachments: none SCANNED ,1 X11 1 49, 2017-0523_Plug_V erification_KRU_3 M-2 8_bb.docx Page 1 of 1 • • .VOF T� 0,1, i/7 7,s., THE STATE Alaska Oil and Gas ��.;s�i�, of T �� ®® Conservation Commission AI,A��<`rl 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 nh Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Andrew Beat Sr. Wells Engineer ConocoPhillips Alaska, Inc. S�Ntk® `U �~ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-28 Permit to Drill Number: 194-012 Sundry Number: 317-203 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1/°;4t (—' Cathy . Foerster Chair • DATED this day of May, 2017. RBDMS w MAY 2 4 2017 • • RECEIVED STATE OF ALASKA MAY 1 9 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 07:17. S/E-,L! / 7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon J Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend Ef VI V ' Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ 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• 194-012 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,AK 99510 50-029-22442-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a ' KRU 3M-28 Will planned perforations require a spacing exception? Yes ❑ No .❑ / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025524 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: ;Effective Depth TVD: ',MPSP(psi): Plugs(MD): Junk(MD): 13240' 6284' 13222' • 6272' • • 3180 12650'&3042' 188' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface 6019' 9.625" 6063' 3397' Intermediate Production 13182' 7" 13221' 6271' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12914'-12938' 6066'-6082' 3.5" L-80 12799' Packers and SSSV Type: Packer(none) Packers and SSSV MD(ft)and TVD(ft): Packer(none) SSSV(none) SSSV(none) 12.Attachments: Proposal Summary ❑✓ Wellbore schematic O 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 5/21/2017 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended LI 16.Verbal Approval: Date: 572 z//7.- 'GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: `/je to r/'cr_. t.O rp p GINJ ❑ Op Shutdown ❑ Abandoned Q 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Andrew Beat Contact Name: Andrew Beat Authorized Title: Sr.Wells Engineer Contact Email: Andrew.______Cc_COP.Com Contact Phone: 265-6341 Authorized Signature: Date: Sit cl/10 iCOMM SIONSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Li Location Clearance ❑ F S '2i 0 t1 Other: Bop fic5 f fo 3vU(7 5 /y . .� / tcrn a fc p ) vg P�aGr zF.± aP ry ,�cd �� c r ,2 O �},¢C Z5-. 1 J Z (L ► � �1�avG1c l0rr�tir-C frc� t G1'tart3 fvr ho -tti R P5. Post Initial Injection MIT Req'd? Yes ❑ No LJ F;t�7 Cc, tf= �t ba t'Gd�"'1,'LI to be Cc vv'plc re-el Spacing Exception Required? Yes ❑ No li Subsequent Form Required: - �� Z W h r'� d a N S ��Cf 7 1,v <l rel,v1 Yt o�pru✓ted It.)-4a 3 • APPROVED BY Approved by: o /91.6,,,A4 COMMISSIONER THE COMMISSION Date: — �] SJ24i� ,�i 3.,. 7 V7L672Z//� l/ Submit Form and Form 10-403 Revised 4/2017 oArO�d BppjlC;�tlQn ig V$Jid for 12 months from the date of approval. Attachments in Duplicate RR G I N A L RBDMS k,k, MAY 2 4 2017 411 • ConocoPh i l l i ps Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 19 May 2017 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to Plug and Abandon Kuparuk Producer 3M-28(PTD#194-012).CPAI also requests a waiver from the perforation isolation requirements as stated in 20 AAC 25.112,specifically,establishing a mechanical plug within 50'of the perforations with a cement cap. These regulations were not met because at the time the plug was set,it was not intended to be an abandonment plug and was to be removed prior to the completion of the workover,Since setting the plug,operational difficulties have ✓ prohibited access and the opportunity to meet all requirements. 3M-28 was originally drilled and completed in 1994 as a Kuparuk producer.The well continued to produce until it failed a tubing integrity fluid level test in early 2016.Diagnostics were run and a deep tubing leak was discovered. Later in 2016 a patch was attempted but failed and additional testing found more tubing leaks deeming the well un- patchable.The well was identified as a CTD candidate in early 2017 and a workover began on April 21,2017. During the workover,subsidence damage was unexpectedly discovered around 200'MD.3M pad was not known for subsidence repairs and the estimated total subsidence at the time of the workover,22",was well below the range where subsidence damage is typically a concern,60+".Shortly after beginning the subsidence repair,the severity of the casing buckling became apparent when two different BHA's broke and were lost downhole.The cause of failure was cyclical fatigue driven by rotating pipe while it is bent. ire severity ofithe buckling prevented the traditional through casing repair method and the only option to regain access below the damaged zone was to attempt to mill straight through.A stiff milling assembly was used to mill from 165'-188' successfully.However,at 188'the top of the second lost fish was discovered.The necessary milling path to reenter casing was blocked by the fish and milling could not proceed without it removed.Attempts to retrieve the fish or push it further down hole continued for over 24 hours but ultimately were unsuccessful blocking any future access to the wellbore. 3M-28 no longer has utility for CPAI due to the lost access to the main wellbore and ultimately the inability to return it to production.Because of this,the approval to Plug and Abandon is requested.Currently,two Retrievable Bridge Plugs have been set inside the production casing and represent the primary isolation from the reservoir.The lower plug is set at 12,650'MD and is a Baker G-Lock RBP.It was pressure tested from above to 1,000 psi.The plug is held in place with slips and is rated to 10,000 psi(greater than casing burst).The second plug is set at 3,042' MD and is a Wireline Set RBP.It was also pressure tested to 1,000 psi from above and has 50'of sand on top.The plug is also held in place with slips an. is rate. to .,100 psi. ' 1i- at 12.5 ppg was left in between both plugs.The well was displaced to seawater above the top plug and a No Flow test was performed to ensure competency. --->The on-rig work scope to complete the P&A would be to cement from surface to at least 150'.The rig would move off and the remainder of the P&A process would occur off-rig. If you have any questions or require any further information,please contact me at 265-6341. Sincerely, Andrew Beat Senior Wells Engineer CPAI Drilling and Wells • • 3M-28 Rig Workover CTD Setup w/Subsidence (PTD#: 194-012) General Well info: Well Type: Producer MPSP: 3,180 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 3,787 psi/6,073' TVD(12.0 ppg EMW)measured on 04/01/2017 Wellhead type/pressure rating: McEvoy Gen IV,5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: Casing Test to Plug @ 12,650'MD PASSED—05/07/2017 MIT-OA PASSED—06/20/2013 RWO generated holes in surface casing to at least 188' Production Engineer: Alex Caldelas Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) P&A Procedure 1. RIH with tubing and tag TOF at—188'MD. 2. RU cementers and pressure test lines.Pump cement to establish a plug from at least 150'MD to surface. 3. Allow time for cement to harden and confirm top. � {� �� 20 t 4. RDMO. 1 • • ConocoPhillips SAND = 188' - Fish Stuck in Buckled 9-5/8" 3M-28 - Casing w/Sand Cap Casing Leak KRU Producer Current Well 2,191' KB - 7" Casing Cut Condition m 50'SAND 3,042' KB ) Baker WLS RBP Well Details: API: 50-029-22442-00 PTD: 194-012 Wellhead: McEvoy Gen IV 5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 121' MD 9-5/8"36#L-80 Surface to 6,064' MD 7"26#L-80 Production to 13,222' MD 13.5 ppg WBM 12,650' KB 0 Baker G-Lock RBP Kuparuk A Sand Perfs 12,914'-12,938' KB G � r Date: May 19,2017 Drawn By: Andrew Beat • • .>,>(>>, tslt >9.y. x- • >>?>>>.,), Cement Isolation Plug to at least 150' ConocoPhillips SAND 47 188' - Fish Stuck in Buckled 9-5/8" Casing 3M-28 Casing Leak KRU Producer Proposed P&A 2,191' KB ------ 7" Casing Cut 50' SAND 3,042KB ' Baker WLS RBP Well Details: API: 50-029-22442-00 PTD: 194-012 Wellhead: McEvoy Gen IV 5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 121' MD 9-5/8"36#L-80 Surface to 6,064' MD 3.5 7"26#L-80 Production to 13,222' MD ppg WBM -11( 411 oo1 12,650' KB Baker G-Lock RBP Kuparuk A Sand Perfs 12,914-12,938' KB Date: May 19,2017 Drawn By: Andrew Beat • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 MAY 1 9 2017 19 May 2017 AOC CC Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to Plug and Abandon Kuparuk Producer 3M-28(PTD# 194-012). 3M-28 was originally drilled and completed in 1994 as a Kuparuk producer.The well continued to produce until it failed a tubing integrity fluid level test in early 2016.Diagnostics were run and a deep tubing leak was discovered. Later in 2016 a patch was attempted but failed and additional testing found more tubing leaks deeming the well un- patchable.The well was identified as a CTD candidate in early 2017 and a workover began on April 21,2017. During the workover,subsidence damage was unexpectedly discovered around 200'MD.3M pad was not known for subsidence repairs and the estimated total subsidence at the time of the workover,22",was well below the range where subsidence damage is typically a concern,60+". Shortly after beginning the subsidence repair,the severity of the casing buckling became apparent when two different BHA's broke and were lost downhole.The cause of failure was cyclical fatigue driven by rotating pipe while it is bent.The severity of the buckling prevented the traditional through casing repair method and the only option to regain access below the damaged zone was to attempt to mill straight through.A stiff milling assembly was used to mill from 165'-188' successfully.However,at 188'the top of the second lost fish was discovered.The necessary milling path to reenter casing was blocked by the fish and milling could not proceed without it removed.Attempts to retrieve the fish or push it further down hole continued for over 24 hours but ultimately were unsuccessful blocking any future access to the wellbore. 3M-28 no longer has utility for CPAI due to the lost access to the main wellbore and ultimately the inability to return it to production.Because of this,the approval to Plug and Abandon is requested.Currently,two Retrievable Bridge Plugs have been set inside the production casing and represent the primary isolation from the reservoir.The lower plug is set at 12,650'MD and is a Baker G-Lock RBP.It was pressure tested from above to 1,000 psi.The plug is held in place with slips and is rated to 10,000 psi(greater than casing burst).The second plug is set at 3,042' MD and is a Wireline Set RBP.It was also pressure tested to 1,000 psi from above and has 50' of sand on top.The plug is also held in place with slips and is rated to 6,000 psi.KWF at 12.5 ppg was left in between both plugs.The well was displaced to seawater above the top plug and a No Flow test was performed to ensure competency. The on-rig work scope to complete the P&A would be to cement from surface to at least 150'.The rig would move off and the remainder of the P&A process would occur off-rig. If you have any questions or require any further information,please contact me at 265-6341. Sincerely, 4 Andrew Beat Senior Wells Engineer CPAI Drilling and Wells • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Monday, May 22,2017 10:30 AM To: Beat,Andrew T Subject: RE: KRU 3M-28(PTD 194-012, Sundry 317-203) Suspend with Plug to Surface Andrew, Cement to surface is required prior to moving the rig off location. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa�alaska.q ov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Monday, May 22,2017 9:54 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: KRU 3M-28(PTD 194-012,Sundry 317-203)Suspend with Plug to Surface Victoria, To confirm our previous discussion,we are required to cement the well to surface prior to moving the rig off location. Is that correct? Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, May 22,2017 8:31 AM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]KRU 3M-28(PTD 194-012,Sundry 317-203)Suspend with Plug to Surface 1 1111 • Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Monday, May 22, 2017 8:31 AM To: Beat,Andrew T Subject: KRU 3M-28(PTD 194-012, Sundry 317-203) Suspend with Plug to Surface Andrew, Verbal approval is granted to proceed with the suspension of this well as outlined in your submitted Sundry(PTD 194- 012,Sundry 317-203). The approved sundry will be available for pickup later today. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aa.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com) Sent: Monday, May 22,2017 6:05 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>;Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:3M-28 Weekend Update Victoria, Over the weekend we continued to attempt to retrieve the fish we found after a camera run but were unsuccessful. We decided to move forward milling with the hopes we would intersect the casing below the fish. We milled to 215' (top of fish was at 188')and our parameters changed indicating we may have re-entered the casing. We ran a camera and it told us two things,one was that where we thought we had ONE fish we actually had TWO. It appeared that our second fish broke twice and both pieces were wedged together blocking access downhole.The second thing the camera told us is that our change in milling parameters was NOT from re-entering the casing but from crossing into a very soft sand formation.We then milled from 215'all the way down to 243' before pulling out again with no signs of hitting casing. Also,while milling that section of sand,the hole kept packing off around our BHA making progress difficult. Our most recent camera run yesterday evening looked for any section in which we ran alongside the casing that we could target for re-entering but were unable to find anything. 1 • With our camera run results from last night,we are out of reasonable options torecover this well and moved into a • productive stand-by mode(rig crew doing miscellaneous tasks while waiting on orders).We are prepared to P&A this well and await your response to our request submitted Friday. I will check in with you again a little later this morning. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907) 265-6341 office 2 • • Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Monday, May 22, 2017 6:05 AM To: Loepp,Victoria T(DOA) Cc: Buck, Brian R;Senden, R.Tyler Subject: 3M-28 Weekend Update Victoria, Over the weekend we continued to attempt to retrieve the fish we found after a camera run but were unsuccessful.We decided to move forward milling with the hopes we would intersect the casing below the fish.We milled to 215' (top of fish was at 188')and our parameters changed indicating we may have re-entered the casing.We ran a camera and it told us two things,one was that where we thought we had ONE fish we actually had TWO. It appeared that our second fish broke twice and both pieces were wedged together blocking access downhole.The second thing the camera told us is that our change in milling parameters was NOT from re-entering the casing but from crossing into a very soft sand formation.We then milled from 215'all the way down to 243'before pulling out again with no signs of hitting casing. Also,while milling that section of sand,the hole kept packing off around our BHA making progress difficult. Our most recent camera run yesterday evening looked for any section in which we ran alongside the casing that we could target for re-entering but were unable to find anything. With our camera run results from last night,we are out of reasonable options to recover this well and moved into a productive stand-by mode(rig crew doing miscellaneous tasks while waiting on orders).We are prepared to P&A this well and await your response to our request submitted Friday. I will check in with you again a little later this morning. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office 1 • Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, May 19,2017 4:57 PM To: Loepp,Victoria T(DOA) Subject: RE:3M-28 (194-012) P&A Approval Request Attachments: 3M-28 P&A Letter Sub2.pdf Victoria, I'm sorry this took me so long.Attached is the cover letter with the requested revision. Let me know if I need more detail in my request. Thanks, Andrew From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, May 19, 2017 3:00 PM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]RE: 3M-28(194-012) P&A Approval Request Andrew, Please modify your cover letter to request a waiver from the relevant regulations for reservoir abandonment and plug placement and why(see 20 AAC 25.112). You can email that to me. Thanx, Victoria From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Friday, May 19,2017 2:07 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Braun, Michael(Alaska)<Michael.Braun@conocophillips.com> Subject:3M-28(194-012) P&A Approval Request Importance: High Victoria, As discussed on the phone,attached is the request for approval to P&A 3M-28 as described in the procedure. We still plan to continue working this well but there is a chance we will move to P&A by Sunday so we are requesting this approval in advance. I will drop off the needed copies this afternoon. Please let me know if there is anything more you need. Thanks, Andrew (303)378-8881 1 i • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, May 19,2017 2:11 PM To: Quick, Michael J (DOA);Schwartz, Guy L(DOA) Subject: FW: 3M-28 (194-012) P&A Approval Request Attachments: 3M-28 P&A Request Packet.pdf Importance: High Here is P&A request for 3M-28. Please review. Any comments? From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Friday, May 19,2017 2:07 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Braun, Michael(Alaska)<Michael.Braun@conocophillips.com> Subject:3M-28(194-012) P&A Approval Request Importance:High Victoria, As discussed on the phone,attached is the request for approval to P&A 3M-28 as described in the procedure.We still plan to continue working this well but there is a chance we will move to P&A by Sunday so we are requesting this approval in advance. I will drop off the needed copies this afternoon. Please let me know if there is anything more you need. Thanks, Andrew (303)378-8881 1 • ° Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Friday, May 19, 2017 10:04 AM To: Loepp,Victoria T(DOA) Cc: Buck, Brian R Subject: 3M-28 Update Follow Up Flag: Follow up Flag Status: Completed Victoria, Since yesterday,we ran in with a camera and were able to identify the top of our second fish at 188'. It is sanded in place inside the 9-5/8"casing.We spent the night trying to fish and are continuing to do so now. It is blocking our access below with the mills so we gain a lot by removing it or knocking it down and out of the way.We plan to continue this effort for at least the rest of the day. If we are successful,we will continue milling until we re-enter the straight casing below. Let me know if you have any questions. Thanks, Andrew (303)378-8881 1 S • • Loepp. Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Thursday, May 18, 2017 7:11 AM To: Loepp,Victoria T(DOA) Cc: Buck, Brian R Subject: 3M-28 Update Follow Up Flag: Follow up Flag Status: Flagged Victoria, Yesterday we had milled down to 178'and pulled out to run in with the camera.We didn't get great pictures but what we could see was expected so we picked up the mill again. We milled from 178'to 183' before another camera run.This time we got better pictures that showed us tracking the casing before getting into more open hole as expected.We continued milling from 183'to 188'with the last couple feet torqueing up as if we were milling on more casing.At 188' our weight fell off and we were able to wash down another foot.We are not sure if this because we re-entered the casing or if we are simply washing through soft permafrost so we are going to clean the hole and trip out for a different BHA.We will likely go back in with drill pipe and a bull nose to investigate and clean the well while we wait for the e-line crews(resting until 8 AM).Once they are up we will run another camera and see what we can see. Let me know if you have any questions. Thanks, Andrew (303)378-8881 1 • • Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Wednesday, May 17, 2017 4:49 PM To: Loepp,Victoria T (DOA) Cc: Brooks, Phoebe L(DOA) Subject: FW: Doyon 14 BOP Test on 3M-28 Follow Up Flag: Follow up Flag Status: Flagged See note below. Spoke with Andrew and Brian this afternoon as well. The 3000psi test pressure was rig decision since they were able to set a test plug in the tubing. As noted below, since the rig was still in the subsidence repair part of the workover,they were only required to test to 250psi. 3000psi test is ok. I will attach this email series to the report along with the test charts which I requested from CPAI. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236orjim.regg@alaskago . From: Beat,Andrew T [mailto:Andrew.T.Beat@conocophillips.com] Sent:Wednesday, May 17, 2017 3:54 PM To: Regg,James B (DOA)<jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Doyon 14 Company Man<doyon14cm@conocophillips.com>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>;Andrew Honea<ahonea@doyondrilling.com> Subject: Doyon 14 BOP Test on 3M-28 Jim, Regarding the BOP test that was performed on 5/15/17 by Doyon 14,the high pressure was limited to 3,000 psi for a few reasons. First, CPAI sees this particular test on 3M-28 as going above the requirements for BOP testing due to the extensions that were granted by the AOGCC.Therefore, we see the test pressure being up to the operator's discretion.Also, we have two,tested mechanical plugs set below our zone of work, isolating us from the pressure that is driving the 3,500 psi requirement. Second,we are still in the subsidence repair portion of the procedure that was submitted with the sundry so we do not have 7"tied back and do not have our tubing head installed. Our interpretation of the required test pressure while 1 performing the subsidence repair was only 250 psi as stated in Step 5 and that we would not be required to test to 3,500 • psi again until we had the 7"tied back and our tubing head re-installed.We see our test to 3,000 psi as going above what was required by the Sundry. Lastly,without the tubing head on,we do not have a flange rated to higher than 3,000 psi.We gain the 5,000 psi rating through the tubing head which had to be removed in order for us to pull 7"casing and drift our milling BHA's during the subsidence repair. Please let me know if you have a different interpretation on what is required or would like to discuss. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office 2 • • Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Wednesday, May 17,2017 2:13 PM To: Loepp,Victoria T(DOA) Cc: Buck, Brian R Subject: 3M-28 Operations Update Follow Up Flag: Follow up Flag Status: Flagged Victoria, Since we met yesterday,we RIH and tagged the top of cement at 38' MD.We milled the cement inside the 9-5/8"casing down to 175' MD and changed over to our stiff casing milling BHA. We RIH with the milling BHA and tagged high at 165' MD,likely due to the stiffness of the BHA and the beginning of the buckle in the casing.We milled from 165'to 170'and POOH.We ran in with a camera on E-line to take pictures to check our progress.The images were not very good but we could see casing so we knew we were still on track. Right now we are continuing with our milling and plan to stop at 178' MD for another camera run. Let me know if you have any questions. Thanks, Andrew (303)378-8881 1 • LOFTfJ 4.p ��)I/j, 8 THE STATE Alaska Oil and Gas gfALASKA Conservation Commission s _ 333 West Seventh Avenue Anchorage, Alaska 99501-3572 *h , GOVERNOR BILL WALKER g Main: 907.279.1433 OF ALASl‘l* Fax: 907.276.7542 www.aogcc.alaska.gov Andrew Beat Sr. Wells EngineerE� �1?'` ` l'R ConocoPhillips Alaska, Inc. ���N� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-28 Permit to Drill Number: 194-012 Sundry Number: 317-186 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Ai /24.444._ Cathy,'. Foerster Chair DATED this 11 day of May, 2017. RBDMS hr r 1 b 2017 • • RECEIVED MAY 0 8 2097 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AGC C APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate D Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Q Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development J. 194-012 3.Address: Stratigraphic LiService ❑ 6.API Number: P.O.Box 100360,Anchorage,AK 99510 50-029-22442-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? n/a = KRU 3M-28 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL025524 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TV.{�.. MPSP(psi): Plugs(MD): Junk(MD): Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 121' 121' Surface 6019' 9.625" 6063' 3397' Intermediate Production 13182' 7" 13221' 6271' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12914'-12938' 6066'-6082' 3.5" L-80 12799' Packers and SSSV Type: Packer(Baker FHL) Packers and SSSV MD(ft)and TVD(ft): Packer(12773'!5975') SSSV(none) SSSV(none) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development D. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Vi'�r �a G 5/8/2017 OIL .r Y ` e - n /9r//� . WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date./—% GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 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. Authorized Name: Andrew Beat Contact Name: Andrew Beat Authorized Title: Sr.Wells Enginee"......r-E-r Contact Email: Andrew.T.BeataCOP.Com Contact Phone: 265-6341 Authorized Signature: Date: 540 I q- COMM! SIGN USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 317- rgte Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ 144;c (lb j .t .te Other: 0 0 p re-.5 f fc 35-6)C, 7) 4..; t /4--�hvlr-rY�JrL c/tv) fGrte'S � t� Z5—DU F Post Initial Injection MIT Req'd? Yes ❑ No Err y C l 2 Spacing Exception Required? Yes ❑ No [ ' Subsequent Form Required: !C)- iv RBDMS `'� A I U 101 APPROVED BY Approved by: tty ial COMMISSIONER THE COMMISSION Date:5.1( /7 OPRolieGliNnAt.for Snbmn Form ane ��{ ''�orm 10.403 Revised 4/2017 12 months from the date of approval. Attachments in Duplicate • • 3M-28 Rig Workover CTD Setup w/Subsidence (PTD#: 194-012) Current Operations: BOPE testing.Well is fully de-completed with two plugs set downhole as barriers. Remaining Scope of Work: Repair subsided casing,cleanout well,and install a new single packer completion. I General Well info: Well Type: Producer MPSP: 3,180 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 3,787 psi/6,073'TVD(12.0 ppg EMW)measured on 04/01/2017 Wellhead type/pressure rating: McEvoy Gen IV,5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: Casing Test to Plug @ 12,650'MD PASSED—05/07/2017 MIT-OA PASSED—06/20/2013 Production Engineer: Alex Caldelas Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Workover Procedure 1. Finish BOPE testing. 2. RU E-Line and perform CBL to find clean 7"casing for cut.RD E-Line. 3. RIH with mechanical cutter on DP.Cut 7"at depth found from CBL. 4. ND BOPE.ND tubing head. 5. NU BOPE to casing head.Shell test BOPE to 250 psi to test connection between stack and casing head. a. Two mechanical barriers established downhole.Casing cut will prevent a full BOPE test to intial pressures. 6. POOH with damaged 7"casing. 7. MU mill assembly and dress 9-5/8"casing to regain necessary drift ID. 8. RIFT with new 7"casing and tie into casing cut. 9. Pump cement to cover 7"casing from cut to surface. 10. ND BOPE.Land 7"casing in slips and cut off excess. 11. NU tubing head.NU BOPE and test to 250/3,500 psi. 12. MU and RIFT with RBP retrieval tool.Pull upper RBP and POOH. 13. MU and RIH with RBP retrieval tool.Pull lower RBP and POOH. 14. MU cleanout assembly and cleanout to PBTD. 15. RIH with 3-1/2"single packer completion including Tandem Wedges. 16. RU E-Line and correlate packer depth to ensure set depth is accurate.Set WRP in tubing tail.RD E-Line. 17. Move packer depth if needed.Pressure up tubing to set packer. 18. Shear out of PBR. Space out and MU tubing hanger.Circulate corrosion inhibited fluid in the IA from the PBR to surface.Land the tubing hanger,RILDS. 19. PT the tubing.IJold pressure on tubing and pressure test IA and chart.Bleed tubing pressure quickly to shear the SOV. 20. Pull the landing joint,install BPV. 21. ND BOPS. 22. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug. 23. Freeze protect well with diesel. Set BPV. 24. RDMO. 1 • • , • • 3M-28 +ConocoP it ips RU Producer CTD Setup w/ Surface to 2,000' KB Subsidence Repaired 7" Casing with Baker Sealing li Overshot and Cemented to Surface PROPOSED MP COMPLETION Well Details: Nis API:50-029-22442-00 PTD: 194-012 6 Wellhead: McEvoy Gen IV 5M OM — Camco 3-W x 1-1/2" MMG GLM's Casing/Tubing Details: 16"62.5#H-40 Conductor to 121' MD 9-5/8"36#L-80 Surface to 6,064' MD MD 7"26#L-80 Production to 13,222' MD 3-1/2" 12.6#L-80 Tubing to 12,964'MD / ', 1-- 1_ t 1 Baker Retrievable Packer and PBR Mb OM ¢ 5g 4 ® 2.81" D-Nipple Upper Tandem Wedge 4 N. ..,., 2.81"X-Nipple 4 Lower Tandem Wedge 2.81"X-Nipple Kuparuk A Sand Perfs 12,914'-12,938' KB G Date: May 8,2017 I Drawn By: Andrew Beat • • Bettis, Patricia K (DOA) From: Beat, Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, May 9, 2017 9:21 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 3M-28 (PTD 194-012): Sundry Application Patricia, I apologize, I missed that whole row. Total Depth: 13,240' MD/6,284'ND Effective Depth: 13,222' MD/6,272'ND MPSP: 3,180 psi No plugs or junk in the whole. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303) 378-8881 cell (907) 265-6341 office From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Tuesday, May 09, 2017 9:13 AM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]KRU 3M-28 (PTD 194-012): Sundry Application Good morning Andrew, On Form 10-403, Box 11,total depth (MD and ND), effective depth (MD and ND), plugs and junk information were not provide. Please provide this information as soon as possible via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@ alaska.gov. 1 • • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday, May 9, 2017 9:13 AM To: Andrew.T.Beat@conocophillips.com Subject: KRU 3M-28 (PTD 194-012): Sundry Application Good morning Andrew, On Form 10-403, Box 11,total depth (MD and TVD), effective depth (MD and TVD), plugs and junk information were not provide. Please provide this information as soon as possible via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • PF As of 17:00 hours we are still unable to drift through the tight spot at 187' MD with 6-1/8" string mills even though we have stretched the production casing back into tension. We have a G lock-set RBP set at 12650' MD(center of element)that has a passing positive pressure test to 1000 psi for 30 minutes and KWF=12.5 ppg WBM in the hole. Plan Forward: 1. Circulate and condition the WBM at 8355' MD. 2. TOOH with G lock-set RBP running tool and lay down. 3. PU, MU and TIH with WLS RBP on 4" DP to 3000' MD. Set the RBP and TOOH with the setting tool. 4. PT the WLS RBP to 1000 psi for 10 minutes. 5. PU, MU and TIH with mule shoe DP pup joint on 4" DP to just above the WLS RBP. 6. Circulate the well from 12.5 ppg WMB to seawater. 7. Dump 100'of 20/40 mesh sand on top of the WLS RBP and TOOH. 8. RU E-line and run CBL to determine the TOC. RD E-line. 9. TIH with MSC and cut the 7"casing above TOC. 10. ND the BOP stack and ND the tubing head. 11. NU the BOP stack to the casing head. PT the break to 250/1000 psi (I did not see any SCL in the anncomm database). 12. Spear the 7"casing,circulate out the Arctic pack,and POOH laying down 7"casing. 13. PU, MU and TIH with string mill to the top of the cut 7" casing. TOOH 14. PU, MU,and TIH with casing dress-off assembly. Dress-off the top of the cut 7"casing and TOOH. 15. PU, MU,and RIH with 7"casing patch with cementing stage collar on 7" 26#casing. 16. Engage the 7"casing patch onto the 7"casing stub and pull into tension. 17. Cement the 7"x 9-5/8" annulus to surface. WOC. 18. Split the stack and install he 7" casing slips. Land the 7"casing. Cut off the excess casing and set the BOP stack on the stump. 19. Install the pack-off and NU the tubing head. 20. NU the BOP stack and shell test BOP stack. 21. PT the casing to 2500 psi. 22. PU, MU and TIH with ROB. Clean debris off sand. cleanout sand down to the top of the WLS RBP,and TOOH. 23. PU, MU and TIH with WLS RBP retrieving tool. Swap the well over to 12.5 ppg WBM, release the WLS RBP,and TOOH. 24. PU, MU and TIH with G lock-set RBP retrieving tool to the top of the RBP. Circulate and condition the WBM. Release the RBP and TOOH. 25. Back on original procedure to do a cleanout run or run completion. • Loepp. Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, May 09, 2017 8:43 AM To: Loepp,Victoria T(DOA) Subject: RE: Sundry Submission for 3M-28(194-012) Victoria, The hard copies should have been delivered yesterday afternoon.We will be ready to cut casing this afternoon so let me know if there is any additional information needed for approval. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, May 08, 2017 12:12 PM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]Re:Sundry Submission for 3M-28(194-012) We will need two hard copies submitted to our offices today. Thanx, Victoria Sent from my iPhone On May 8,2017, at 11:47 AM, Beat,Andrew T<Andrew.T.Beat@conocophiliips.com>wrote: Victoria, As Ron informed you over the weekend,we are preparing to perform an unplanned subsidence repair on 3M-28.Attached is the 10-403, a general procedure,and a proposed schematic of the final completion for your review. Please let me know if you need anything else or have any questions. We are currently testing BOPE and plan to cut the casing sometime tomorrow. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907) 265-6341 office 1 • , Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Sunday, May 07, 2017 12:50 PM To: Loepp,Victoria T(DOA) Subject: RE: Kuparuk Producer 3M-28 (PTD 194-012) Victoria, We have a BOP test coming up so we should be good until Monday. I just wanted to give you a heads up what is happening and did not want to blind side you Monday morning. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-1592 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Sunday, May 07, 2017 12:36 PM To: Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]Re: Kuparuk Producer 3M-28(PTD 194-012) Monday is fine for the 10-403. Let me know if/when a verbal approval is needed. Thanx, Victoria Sent from my iPhone On May 7, 2017,at 12:03 PM, Phillips, Ron L<Ron.L.Phillips@conocophiliips.com>wrote: Victoria, Good afternoon Victoria. During the workover on the Kuparuk Producer 3M-28(PTD 194-012)we encountered subsidence damage to the production casing at a level great enough to require a repair. This was not part of the original job scope. Here is an outline of the original job scope with the problem and repair in red: 1. MIRU 2. Test BOPE 3. Pull existing 3-1/2"single packer completion 4. Perform a clean out run in 7"casing(At this point we could not drift past 187' MD. We speared and stretched the 7" casing and still could not drift.) 5. Subsidence repair: Run cement bond log, cut and pull 7" casing @ "'1800. Drift 9-5/8" casing and rerun new 7" casing and cement to surface. 6. Back to the original job scope: run 3-1/2" completion. 7. RDMO 1 • Attached is the detailed subsidence procedure for the repair and original schematic.At the completion of this,we will return to the original job scope. Do you have any concerns or are you ok with us proceeding ahead on this path? Is Monday ok for the 10-403 or do you want to see the sundry sooner?Of course a quick response would be greatly appreciated due to the unexpected subsidence repair requirement. Please let me know if you have any questions. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-1592 <3M-28 Subsidenc PF from D14 CM.DOCX> <3M-28 Existing Schematic.pdf> 2 Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, May 09, 2017 4:16 PM To: Loepp,Victoria T(DOA) Subject: Re: [EXTERNAL]Re:Sundry Submission for 3M-28 (194-012) Follow Up Flag: Follow up Flag Status: Flagged Thank you. S`AN%E® (v,it } Andrew From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent:Tuesday, May 9,2017 4:15:31 PM To:Beat,Andrew T Subject: [EXTERNAL]Re:Sundry Submission for 3M-28(194-012) Andrew, Verbal approval is granted to proceed as outlined in the submitted 10-403. Thanx, Victoria Sent from my iPhone On May 9,2017,at 3:32 PM, Beat,Andrew T<Andrew.T.Beat@conocophillips.com>wrote: Victoria, Any update on the Sundry approval for 3M-28?We will be ready to cut casing shortly. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From: Beat,Andrew T Sent:Tuesday, May 09,2017 8:43 AM To: 'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject: RE:Sundry Submission for 3M-28(194-012) Victoria, 1 • • The hard copies should have been delivered yesterday afternoon.We will be ready to cut casing this afternoon so let me know if there is any additional information needed for approval. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Monday, May 08, 2017 12:12 PM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]Re:Sundry Submission for 3M-28(194-012) We will need two hard copies submitted to our offices today. Thanx, Victoria Sent from my iPhone On May 8, 2017,at 11:47 AM, Beat,Andrew T<Andrew.T.Beat@conocophillips.com>wrote: Victoria, As Ron informed you over the weekend,we are preparing to perform an unplanned subsidence repair on 3M-28.Attached is the 10-403,a general procedure,and a proposed schematic of the final completion for your review. Please let me know if you need anything else or have any questions. We are currently testing BOPE and plan to cut the casing sometime tomorrow. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office <3M-28_Sundry_Schematic.pdf5 <3M-28 General Procedure.pdf5 <3M-28 10-403.pdf5 2 • • Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Sunday, May 07, 2017 12:50 PM To: Loepp,Victoria T(DOA) Subject: RE: Kuparuk Producer 3M-28 (PTD 194-012) Follow Up Flag: Follow up Flag Status: Flagged Victoria, We have a BOP test coming up so we should be good until Monday. I just wanted to give you a heads up what is happening and did not want to blind side you Monday morning. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-1592 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Sunday, May 07,2017 12:36 PM To: Phillips, Ron L<Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]Re: Kuparuk Producer 3M-28 (PTD 194-012) Monday is fine for the 10-403. Let me know if/when a verbal approval is needed. Thanx, Victoria Sent from my iPhone On May 7,2017,at 12:03 PM, Phillips,Ron L<Ron.L.Phillips@conocophillips.com>wrote: Victoria, Good afternoon Victoria. During the workover on the Kuparuk Producer 3M-28(PTD 194-012)we encountered subsidence damage to the production casing at a level great enough to require a repair. This was not part of the original job scope. Here is an outline of the original job scope with the problem and repair in red: 1. MIRU 2. Test BOPE 3. Pull existing 3-1/2"single packer completion 4. Perform a clean out run in 7"casing(At this point we could not drift past 187' MD. We speared and stretched the 7" casing and still could not drift.) 1 110 5. Subsidence repair: un cement bond log, cut and pull 7" casing-1800. Drift 9-5/8"casing and rerun new 7" casing and cement to surface. 6. Back to the original job scope: run 3-1/2" completion. 7. RDMO Attached is the detailed subsidence procedure for the repair and original schematic.At the completion of this,we will return to the original job scope. Do you have any concerns or are you ok with us proceeding ahead on this path? Is Monday ok for the 10-403 or do you want to see the sundry sooner?Of course a quick response would be greatly appreciated due to the unexpected subsidence repair requirement. Please let me know if you have any questions. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-1592 <3M-28 Subsidenc PF from D14 CM.DOCX> <3M-28 Existing Schematic.pdf> 2 • • WELL LOG TRANSMITTAL#903636611 To: Alaska Oil and Gas Conservation Comm. January 12, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 h DATA LOGGED Anchora g e Alaska 99501 RECEIVED M.2 (0�z, K.BENDER FEB 032017 RE: EM Pipe Xaminer: 3M-28 AO G C C Run Date: 10/30/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3M-28 Digital Data(LAS), Digital Log file, Casing Inspection Report 1 CD Rom 50-029-22442-00 EM Pipe Xaminer(Processed Log) 1 color log 50-029-22442-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 sumo UN 3 201 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:PJA/2-12~-, —e,p;eat • • • .-° C a) a) Nto U .Q /y l • ` ❑ p Q cW a) 3' r WVW > X 03 03 3 0 Z c.) Q ti Cr W _it_1111 N 0 ci) _ . O - a.) ..c I— Y Zco H > � p5 0 ooY (..)il ,..) '') > 4-, ra I- Oc .o 73 W 03 DCD v Q lt cm " c -0 `, a m O J CO CO CO CO CO m CO CO O ra O a) E . J y Q H. O C C C C C0 C C C C �n L 0C -I-, c F G W '� '7 , 7 M —) - — Q N N Z... 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They are available in the original file and viewable by direct inspection. i~ q -0[ ~.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: Beve~Vincent TO RE-SCAN Nathan Lowell Date: 'f"'~ '""~-'-~ ~si ~ Notes: Re-Scanned by: Bevedy. Dianna Vincent Nathan Lowell Date: ~si oN oP- BEFORE P E RH i T DATA .... AOGCC Indlvzeua!'- ~'" Well ,,-~,gica] PI.~,~ezia!s Inven+~o~y T DATA_PLUS 6065~i3240, OH-CDR/CDN COMP DATE"04/2i/94 01/27-04/22/94 :9-13240, GCT 0.00~13240 L 10~e0-129e0~ _~ L 595~'-13 u 230 L 5950-13200 L 12400-13210 L 10590-13020 Are dry,.~'~i~ch s~,~,-~es ~ required? yes ~~received? Page' i Date' 10/13/95 RUN DATE_RECVD CMPS 05/31/94 05/09/94 05/09/94 03129/94 05/09/94 1 03/08/94 CMPS 05/i}1/94 CMPS 05/31/94 CMPS 05/31/94 1 03/08/94 Was the well cored? Are well tests required?Ss ~Received? ~. ~ ~ ~ , . ~ · ~,~i is in compz!ance /v Initial COMMENTS ~!ysis -~, description r .~i ~i yes nc) ye= y 6: S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO;q REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well __ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1285' FNL, 1737' FEL, SEC.25, T13N, RSE, UM At top of productive interval 901' FNL, 572' FEL, SEC.34', T13N, RSE, UM At effective depth 949' FNL, 693' FEL, SEO.34, T13N, RSE, UM At total depth 998' FNL, 821' FEL, SEC.34, T13N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 1 3240' feet Plugs (measured) 6284' feet 1 3130' feet Junk (measured) 621 0' feet 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3M-28 9. Permit number/approval number 94-12 10. APl number 50-029-22442 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 13. 14. Casing Length Size Cemented Structural Conductor 80' 1 6" 222 SX ASI Surface 5925' 9-5/8" 1250 SX AS III & Intermediate 650 SX CLASS G Production 13168' 7" 250 SX CLASS G Liner Perforation depth: measured 12914'-12938' true vertical 6065'-6081' Tubing' (size, grade, and measured depth) 3-1/2" 9.3# L-80@ 12799' Packers and SSSV (type and measured depth) PKR: BAKER FHL @ 12773' SSSV: Camco TRDP-4E @ 1950' Stimulation or cement squeeze summary A Sand Frae Intervals treated (measured) 12914'-12938' Treatment description including volumes used and final pressure Pumped 236 Mlbs Propant@ perfs. Max Press of 7200psi. Prior to well operation Subsequent to operation Measured depth True vertical depth 121' 121' 5966' 3375' 13209' 6213' RECEIVED Gas Cons. Commission Tubing Pressure 750 350 30 165 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 0 .,-- 0 0 2587 5583 26 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. J~ ~ Title Wells Superintendent Form 10-404 Rev 06/15/88 Date ,"/'~,'~Y~;~,,~ SUBMIT I~ DUPLICATE ARCO Alaska, Inc. ,k Subsidiary of Atlantic Richfield Company WELL JM-2$ DATE '7-~1- 9¥ DAY $ TIME 0700 08~0 ~0~I /033 IOqS' / o ~zt !1o$ ///~ //~0 /131 //ql DESCRIPTION OF WORK "A" ~#~ f:~e - PB~ (~) [~T TAG (R~)- DATE /&/~q' ~ /3,~aq' ~-~-q~ LOG ENTRY KUPARUK RIVER UNIT WELL SERVICE REPORT [AFC/CC# - SCA# [Ft~LI) COST EST. ]ACCUMULATF.~ COST ISSSV TYPE / STATUS' . Pu/n/~ lid/381S. ~Et~y- ZL G~V ~ ff ~P/z/ T~E,- J6Oo/Jqo0 7% 3qgZ/JdTO. ~nur~owm IgIP- /657 Pu~ ~y- xL~W /lq ~1. ~W~O . ~a/~8 Pu~ /0 ~ G~y-xzg~ /~ 8~1. ~ ~ ~P~ ~- ~oo/ ~ ~- ~8/~. Pu~P /~ ~ ~z~y-~zSW /qd88/.~ ~0 BPM TP- 6Wo¢/~t~ ¢"- 34/0. wtCHECK TI-Hg BLOCK IF SUMMARY IS CONTINUE~ ON BACK Weather R_~ort ITemp. t Chill Factor ARCO Alaska, Inc. Date: May 27, 1994 Transmittal #: 9096 RETURN TO: ARCO Alaska, Inc. Attn' Sarah Bowen Kuparuk Operations File Clerk ATe- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. /3M-28 qq~i~ (, 3M-28 X3M-28 CDR DDNR Very-Enhanced Resistivity TDTP Acknowlodged: DISTRIBUTION: D&M 1/30-2/3, 94 5950-13200 1/30-2/3, 94 5950-13230 1/30-2/3, 94 12400-13210 05,24,.94 6100-6450 ('"~'.~/3 ~-2-~-~ ~Date: Drilling Catherine Worley(Geology) ~'~'~ NSK State of Alaska (+Sepia) Bob Ocanas ARCO Alaska, Inc. Date: May 27, 1994 Transmittal #: 9097 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-28 ,.//LIS Tape and Listing: 05-03-94 CDR/CDN-2 Bit Run with QRO Processing LIS Tape and Listing: 05-05-94 3H-26 ,/" 3 Pass CNTG Receipt Acknowledged: .,,"~'/ ("'"'~'~~ DISTRIBUTION: Bob Ocanas State of Alaska STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIb~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS [~] SUSPENDED E~ ABANDONED [] SERVICE 2 Name of Operator C) R ! ~,~ i!~j~L 7 Permit Number ARCO Alaska, Inc 94-12 3 Address ~ ! 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22442 4 Location of well at surface... 9 Unit or Lease Name 1285' FNL, 1737' FEL, SEC 25, T 13N, R 8E, UM ~ : "~'-:!' ;:'h'~ ~ ' ~ KUPARUK RIVER At Top P reducing Interval ! ~~... ,i i~~ 10 Well Number At Total Depth 11 Field and Pool ~ :~ ~ ~'!~ KUPARUK RIVER 998' FNL, 821' FEL, SEC 34, T 13N, R 8E, UM .~-----,~-- ......... 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 68', PAD 27' GL ADL 25524 ALK 2655 12 Date27_Jan_94Spudded 13 Date 03-Feb-94T'D' Reached 14 04/21/94(COMp)Date Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No. of 1 Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set'1 21 Thickness of permafrost 13240' MD, 6284' TVD 13130' MD, 6210' TVD YES xL~ NO L~I 1950, feet MDI 1800' APPROX 22 Type Electric or Other Logs Run LWD LOGS, USIT, CBT, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16. 62.5# H-40 SURF 121' 24" 222 SX ASI CMT 9.625 47#/36# L-80/J-55 SURF 6065' 12.25" 1250 SX ASIII, 650 SX G 120 SX ASI CMT TOP JOB 7. 26# L-80 SURF 13216' 8.5" 250 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.3# L-80 12799' 12773' 12914'-12938'4 SPF MD 6065'-6081' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD I~ FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE l~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA RECEIVED MAY -9 1994 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 12880' 6043' BASE KUPARUK C 12887' 6047' TOP KUPARUK A 12887' 6047' BASE KUPARUK A 12989' 6116' 31. LIST OF ATTACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO ALASKA INC. DAILY OPERATION PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3M-28 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25524 ALK 2655 50-029-22442 94-12 ACCEPT: 01/26/94 11:30 SPUD: 01/27/94 06:30 RELEASE: 04/21/94 07:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 01/27/94 ( 1) PARKER 245 TD: 121' ( 121) 01/28/94 (2) PARKER 245 TD: 2040' (1919) 01/29/94 (3) PARKER 245 TD: 5205' (3165) 01/30/94 ( 4) PARKER 245 TD: 6085' ( 880) 01/31/94 ( 5) PARKER 245 TD: 6720'( 635) ND ANN TO REPLACE SAME MW: 9.4 VIS: 58 MOVE RIG F/3M-24 TO 3M-28. ACCEPT RIG @ 2330 HRS 01/26/94. NU DIVERTER SYSTEM. ATTEMPT TO TEST DIVERTER. ANNULAR WOULD NOT CLOSE COMPLETELY. SEALS IN ANNULAR FAILED. ND RISER & ANNULAR TO REPLACE ANNULAR. DRILL 12.25" HOLE MW: 9.5 VIS: 56 CONT TO ND ANN & DIVERTER SYSTEM. CUT CELLAR DOOR W/WELDER & REMOVE. CHANGE OUT ANNULAR. REPLACE CELLAR DOOR. NU DIVERTER SYSTEM & FUNCTION TEST. ONE DIVERTER VALVE NOT OPERATING CORRECTLY, WASH GRAVEL F/VALVE & RETEST SAME. FILL SYSTEM W/WATER & CHECK F/LEAKS. ALL OK. NU RISER & FLOWLINE. PU DC'S & STAND BACK IN DERRICK. PU BHA. ORIENT MWD & GYRO TOOLS. DRILL 12.25" HOLE F/121'-2040' GYRO SURV AS NEEDED. DRILL 12.25" HOLE MW:10.0 VIS: 50 DRILL 12.25" HOLE F/2040'-2408' LAST 160' DRILLED WAS VERY CHOPPY-MOTOR STALLED DUE TO HIGH TORQUE. CBU. MIX & PMP DRY JOB. POOH. CHANGE OUT BIT & MOTOR. ORIENT MWD TOOLS & MU BHA. TEST MWD @ HWDP. SERV TOP DRIVE. CONT RIH. DRILL 12.25" HOLE F/2408'-5205' FORM CONT TO DRILL CHOPPY W/HIGH TORQUE F/2408'-2460'. RUN 9-5/8" CSG MW:10.0 VIS: 42 DRILL 12.25" HOLE F/5205'-6085' CBU. SHORT TRIP TO HWDP. SERV TOP DRIVE. TIH. CIRC & COND MUD. POOH. RU TO RUN 9-5/8" CSG. HOLD PRE-JOB SAFETY MEETING. REPAIR HYDRAULIC PMP ON STABBING BOARD. RUN 80 JTS 9-5/8", 36#, J-55 BTC CSG TO 3200'. BREAK CIRC & CBU. CIRC @ 7 BPM W/FULL RETURNS. RUN 9-5/8", 47#, L-80 CSG. DRILL 8.5" HOLE 9-5/8"@ 6064' MW: 8.6 VIS: 31 FIN RUNNING 9-5/8" CSG. RUN TOTAL OF 66 JTS 47# L-80 & 80 JTS 36# J-55. SHOE SET @ 6065'_ CIRC & COND MUD_ RU DOWELL. CMT W/1250 SX ASIII @ 12.0 PPG FOLLWED BY 650 SX CLASS G @ 15.8 PPG. BUMPED PLUG TO 2500 PSI-FLOATS HELD. ONLY PARTIAL RETURNS-NO CMT TO SURF. DO TOP JOB W/120 SX ASI CMT. TEST BOPE & CSG. DRILL PLUGS, FLOAT, CMT, SHOE, & 10' NEW FORM TO 6095'_,5 PERFORM FORM TEST TO 12.5 PPG EMW. DRILL 8.5" HOLE F/609 -6720' RECEIVED MAY --(:3 1994 Alaska Oil & Gas Cons. Commission Anchorage WELL: 3M-28 API: 50-029-22442 PERMIT: 94-12 PAGE: 2 02/01/94 ( 6) PARKER 245 TD:l1880' (5160) 02/02/94 ( 7) PARKER 245 TD:12609' ( 729) 02/03/94 ( 8) PARKER 245 TD:13114' ( 505) 02/04/94 ( 9) PARKER 245 TD:13240' ( 126) 02/05/94 (10) PARKER 245 TD:13240' ( 0) 02/06/94 (11) PARKER 245 TD:13240' ( 0) 02/11/94 (12) DOWELL TD:13240 DRILL 8.5" HOLE 9-5/8"@ 6064' MW: 9.2 VIS: 35 DRILL 8.5" HOLE F/6720'-7987' DRILL F/7987'-11880' SERV RIG & TOP DRIVE. TIH 9-5/8"@ 6064' MW:ll.6 VIS: 39 DRILL 8.5" HOLE F/11880'-12609'. CIRC, LOSS OF 40 BBLS W/PUMPING. HOLE DEAD W/PUMP OFF. PUMPED PILL, TOH, LOST 28 BBLS TOH, RETRIEVE RA SOURCE, DN LOAD LWD, LD BHA. CUT 160' DRILL LINE. PU #4 BHA, ANADRILL TOOLS, LOAD SOURCE, TIH SLOW, ADDING 30#/BBL LCM, FILL PIPE @ 3982'. TIH 9-5/8"@ 6064' MW:ll.6 VIS: 47 TIH T/7543' . CIRC LCM @ 7543'-5-1/2 BPM-MONITOR. TIH SLOWLY. SERV TOP DRIVE. TIH T/9950' FILL PIPE-REAM F/12500'-12609' FOR LWD LOGS. DRILL ~.5" HOLE F/12609'-13114' TIH 9-5/8"@ 6064' MW:ll.6 VIS: 57 DRILL 8.5" HOLE F/13114'-13240'. CBU. SHORT TRIP T/9-5/8" SHOE. SERV TOP DRIVE. TIH SLOW-FILL PIPE @ 10536'. CIRC & COND @ 13240' DROP SURV-PMP SLUG-STD 6 BACK IN DERRICK-LD S-135 DP-TOOH W/G-RETRIEVE SURV @ HWDP-LD HWDP. ROUGH CUT 7" CSG 9-5/8"@ 6064' MW:ll.6 VIS: 56 LD BHA. PU 8" DC OUT OF DERRICK & LD. PULL WEAR BUSHING & RU TO RUN 7" CSG. HOLD SAFETY MEETING. RUN 7" CSG-CHECK FLOAT & SHOE. CIRC W/241 BBLS @ 6400' RUN 7" CSG. CIRC @ 10140' FOR 20 MIN-LOST 20 BBL. RUN 7" CSG TO 13221' CIRC & COND HOLE. LOST 300 BBLS MUD-PIPE STUCK-UNABLE TO RECIP. FLUSH CMT LINES W/WATER-TEST TO 4000#-PMP 20 BBL. DROP BTM PLUG-PMP 50 BBL SPACER-DROP 2ND PLUG-PMP 48 BBLS 15.8 PPG CMT-DROP TOP PLUG-DISPLACE CMT TO SHOE W/504 BBLS 11.6# BRINE. DID NOT BMP PLUG-CIP @ 0230 HRS. MONITOR RETURN FLOW. PU BOPS-SET SLIPS W/280K. RIG RELEASED 7"@13215' MW: 0.0 VIS: 0 ROUGH CUT 7" ND BOPS. MAKE FINAL CUT ON 7", NU TREE. TEST TO 3000 PSI FOR 15 MIN. FREEZE PROTECT W/208 BBLS WATER FOLLOWED BY 100 BBLS DIESEL. LD 270 JTS DP OUT OF DERRICK. SERVICE RIG & TOP DRIVE. RIG RELEASED @ 1900 HRS 02/05/94 FOR PREP TO MOVE TO 3H PAD. 7"@13215' PERFORM ARCTIC PACK RECEIVED MAY --9 1994 A~aska Oil & Gas CoDs. Commission Anchorage WELL: 3M-28 API: 50-029-22442 PERMIT: 94-12 PAGE: 3 04/20/94 (13) NORDIC 1 TD:13240 PB:13129 TESTING BOPE 7"@13215' MW: 0.0 MOVED RIG F/3G PAD TO 3M PAD. ATTEMPTED TO MOVE OVER WELL. UNABLE TO APPROACH DUE TO SPACING. ACCEPTED RIG @ 2400 HRS 4 /19/94. REMOVED TREE STANDS FROM OFFSET WELLS. MOVED OVER WELL. LEVELED RIG. ND DRY HOLE TREE. SET TEST PLUG. NU BOP. TEST BOP TO 3000 PSI. WITNESSING OF BOP TEST WAIVED BY JOHN SPAULDING OF AOGCC. 04/21/94 (14) NORDIC 1 TD:13240 PB:13129 RUN 3-1/2" COMP ASSY 7"@13215' MW: 0.0 FIN TEST BOPE TO 3000 PSI. RETRIEVE TEST PLUG. PRESS TEST 7" CSG TO 3500 PSI F/30 MIN. RU SWS. TEST LUB TO 1500 PSI. PERF 'A' SAND W/4 SPF USING 4-1/2" CSG GUN: 12914'-12938'. RU & RAN COMP ASSY ON 205 JTS 3-1/2" L-80 MOD EUE 8RD TBG. LOADED PIPE SHED W/ADDITIONAL 3-1/2" TBG. DRIFTED, STRAPPED & INSTALLED SEAL RINGS. 04/22/94 (15) NORDIC 1 TD:13240 PB:13129 RELEASE RIG 7"@13215' MW: 0.0 SERV RIG. CONT TO RIH W/3-1/2" COMP ASSY. MU SSSV & ATTACH CONTROL LINE. RAN 397 JTS 3-1/2" L-80 8RD MOD TBG & 33 SS BANDS. MU TBG HGR & ATTACH C LINE, TEST SAME. LAND TBG & RILDS. PRESS TBG TO 2500 PSI TO SET PKR & TEST TBG. BOLDS. PU & SHEAR PBR W/25K# OVER STRING WT & 1700 PSI ON TBG. RELAND & RILDS. PRESS ANN & TBG TO 2500 PSI & HOLD F/15 MIN TO TEST CSG & PKR ELEMENTS. INCREASE TBG PRESS TO 3000 PSI & HOLD F/15 MIN TO TEST PBR SEALS. ALL OK. INCREASE TBG PRESS TO 3900 PSI & SHEAR BALL F/SOS. CLOSE SSSV & SET BPV. ND BOPE. NU TREE. TEST PACKOFF TO 5000 PSI. PULL BPV & TEST PUG. TEST TREE TO 250/5000 PSI. PULL TEST PLUG & OPEN SSSV. FREEZE PROTECT & SECURE. RELEASE RIG @ 1900 HRS 04/21/94. SIGNATURE: ~~ent ) (dril~g RECEIVED MAY -~9 1994 Alaska Oil & Gas Cons. Commissio~ Anchorage SUB. SURFACE DIRECTIONAL SURVEY [~]UIDANCE [~]ONTINUOUS ~lOOC RECEIVED MAY --9 1994 .~i~$ka. 0il & Gas Cons. Commission Anchorage Company Well Name Field/Location ARCO ALASKA, INC. 3N-28 (1285' FNL,1737' FEL,SEC 25, T13N,R8E,UN) KUPARUK, NORTit SLOPE, ALASKA Job Reference No. 94079 Logc3ed By: WARNER/JOHNSON Date 2Z-FEB-94 Computed By; SINES SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3M - 28 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 02-21-94 ENGINEER: WARNER/JOHNSON METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVA-FURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 62 DEG 41MIN WEST COMPUTATION DATE' 1-MAR-g4 PAGE 1 ARCO ALASKA, INC. 3M - 28 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY' 02-21-94 KELLY BUSHING ELEVATION' 68.00 ET INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN -68 O0 32 O0 132 O0 232 O0 331 89 431 43 531 36 630 44 728 46 824 0 0 N 0 0 E 0 6 S 82 16 E 0 23 S 40 9 E 0 21 S 15 18 E 99 I 1 S 60 10 W 89 4 5 S 76 15 W 43 7 3 S 81 2 W 36 9 31 S 79 35 W 44 13 25 S 76 39 W 46 18 44 S 74 26 W 0 O0 100 O0 200 O0 3OO O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 100 O0 200 O0 300 O0 399 99 499 599 698 796 892 918 12 21 46 60 22 23 93 23 6 17 25 23 69 27 49 63 31 35 38 34 11 09 34 13 57 35 2O 51 38 54 S 72 56 W S 72 24 W S 71 19 W S 69 11W S 66 32 W S 65 45 W S 66 OW S 65 20 W S 64 19 W S 64 35 W ENGINEER' WARNER/JOHNS 986 12 O0 1078 60 1010 O0 1170 93 1102 O0 1262 17 1194 O0 1351 69 1283 O0 1438 63 1370 O0 1522.38 1454 O0 1605.09 1537 O0 1687.57 1619 O0 1767.51 1699 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 O0 1842 81 1774 81 43 14 38 1845 36 1911 42 1972 20 2029 84 2079 28 2124 31 2161 88 2194 66 2228 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -0 06 0 O1 -0 05 0 38 4 68 13 71 27 49 46 23 73 31 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 1913 O0 1979 O0 2040 O0 2097 O0 2i47 O0 2192 O0 2229 O0 2262 O0 2296 107 67 145 13 183 05 223 59 267 95 317 24 371 78 427 91 484 41 544 42 S 64 48 W 38 46 41 S 64 40 W 680 36 50 37 S 65 18 W 755 42 53 51 S 64 40 W 835 20 57 13 S 64 18 W 917 84 61 25 S 64 17 W 1003 28 65 55 S 63 12 W 1093 31 70 1 S 62 52 W 1185 88 70 23 S 63 7 W 1280 66 70 7 S 63 28 W 1374 610 14 92 97 08 33 50 O3 9O 10 21 S 63 37 W 1468 O2 65 3O O4 68 29 99 53 95 47 3000 O0 2331 28 2263.28 69 28 S 63 40 W 1561 S 63 53 W 1655 S 63 58 W 1749 S 63 52 W 1842 S 63 57 W 1936 S 63 59 W 2O29 S 64 3 W 2123 S 63 57 W 2216 S 63 58 W 2310 O0 2366 O0 2401 O0 2436 O0 2471 O0 2506 O0 2541 O0 2576 O0 2612 O0 2647 37 2298.37 69 26 39 2333.39 69 37 16 2368.16 69 40 19 2403.19 69 26 29 2438.29 69 22 18 2473.18 69 46 46 2508.46 69 6 07 2544.07 69 9 42 2579.42 69 28 3100 3200 3300 3400 3500 3600 3700 3800 3900 0 O0 0 O1 0 O1 0 O0 0 O1 0 O3 0 O3 0 O2 0 O4 0 O5 0 O0 N 0 04 S 0 52 S 0 96 S 1 63 S 2 96 S 4 67 S 6 99 S 11 O8 S 18 09 S 0 O0 E O09 E 0 26 E 0 55 E 0 41 E 3 74 W 13 02 W 27 33 W 46 31 W 73 17 W 0 O0 N 0 0 E 0 0 1 1 4 13 28 47 75 10 S 65 58 E 58 S 26 46 E 10 S 29 56 E 69 S 14 13 E 77 S 51 40 W 83 S 70 16 W 21 S 75 39 W 62 S 76 33 W 37 S 76 7 W 0 05 0 03 0 O1 0 O1 0 02 0 03 0 03 0 O2 0 O1 0 O2 27.98 S 106 74 W 110 34 S 75 19 W 39.32 S 143 51.25 S 179 65.08 S 218 81.75 S 259 101.91S 304 124.24 S 354 147.33 S 405 171.42 S 456 197.28 S 510 04 W 148 56 W 186 04 W 227 36 W 271 43 W 321 28 W 375 52 W 431 67 W 487 86 W 547 34 S 74 38 W 73 S 74 4 W 55 S 73 23 W 94 S 72 30 W 03 S 71 30 W 43 S 70 40 W 46 S 70 2 W 78 S 69 26 W 63 S 68 53 W 0 O3 0 O4 0 O4 0 04 0 03 0 04 0 04 0 O4 0 03 0 O1 225.38 S 570 31 W 613.23 S 68 26 W 255 75 S 634 287 320 356 393 433 475 518 561 5O S 7O2 90 S 774 42 S 848 79 S 926 45 S 1006 85 S 1088 69 S 1172 03 S 1256 29 W 683.91 S 68 2 W 36 W 758.92 S 67 44 W 15 W 838.02 S 67 29 W 37 W 920.20 $ 67 13 W 06 W 1006.31 S 66 58 W 35 W 1095.73 S 66 42 W 97 W 1188.40 S 66 24 W 86 W 1282.44 S 66 9 W 92 W 1376.45 S 65 57 W 0 O1 000 0 O0 0 O0 0 O0 0 oo o oo o O1 0 oo o oo 602 79 S 1340 93 W 1470 19 S 65 48 W 644 685 727 768 809 850 891 932 973 41S 1424 80 S 1508 O0 S 1593 19 S 1677 41S 1761 56 S 1845 51S 1929 54 S 2013 82 W 1563 84 W 1657 07 W 1751 19 W 1844 26 W 1938 46 W 2032 59 W 2125 55 W 2219 69 S 2097.55 W 2312 77 S 65 40 W 39 S 65 33 W 11 S 65 28 W 74 S 65 23 W 35 S 65 19 W 04 S 65 15 W 59 S 65 12 W O1 S 65 9 W 53 S 65 6 W COMPUTATION DATE' 1-MAR-94 PAGE 2 RCO ALASKA, INC. M - 28 UPARUK ORTH SLOPE, ALASKA DATE OF SURVEY' 02-21-94 KELLY BUSHING ELEVATION' 68.00 FT ENGINEER' WARNER/JOHNS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN .000 O0 2680 43 2612 43 71 50 100 ,200 .300 ,400 500 ,600 .700 ~800 ~900 O0 2711 O0 2'743 O0 2774 O0 2806 O0 2839 O0 2872 O0 2907 O0 2942 O0 2978 86 2643 26 2675 92 2706 96 2738 52 2771 93 2804 23 2839 18 2874 04 2910 86 71 39 26 71 40 92 71 23 96 71 13 52 70 43 93 70 14 23 69 40 18 69 20 04 68 37 S 64 53 W 2404.81 S 65 3 W 2499.67 S 65 19 W 2594.52 S 65 12 W 2689.28 S 65 8 W 2783 92 S 65 2 W 2878 39 S 64 46 W 2972 57 S 64 46 W 3066 44 S 64 46 W 3160 07 S 64 38 W 3253 36 0 01 0 02 0 O1 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 01 1014 35 S 2182 73 W 2406 91 S 65 4 W 1054 1094 1134 1173 1213 1253 1293 1333 1373 64 S 2268 45 S 2354 13 S 2441 91S 2527 77 S 2612 77 S 2698 85 S 2783 75 S 2867 69 W 2501 88 W 2596 04 W 2691 01W 2786 75 W 2880 O9 W 2975 04 W 3069 82 W 3162 59 S 2952.24 W 3256 84 S 65 4 W 78 S 65 4 W 64 S 65 5 W 37 S 65 5 W 92 S 65 5 W 17 S 65 5 W 10 S 65 4 W 80 S 65 3 W 14 S 65 3 W ;000 O0 3015.09 2947 09 67 53 ;lO0 ;200 ;300 ;400 ;500 ;600 ;700 ;800 ~900 O0 3053.65 2985 O0 3091.55 3023 O0 3127 15 3059 O0 3163 88 3095 O0 3200 36 3132 O0 3235 84 3167 O0 3271 96 3203 O0 3305 79 3237 O0 3338 78 3270 65 66 54 55 69 15 15 68 47 88 68 4 36 69 20 84 68 58 96 69 8 79 70 37 78 69 53 S 64 23 W 3346 19 S 64 7 W 3438 S 63 50 W 3530 S 63 46 W 3624 S 63 38 W 3717 S 63 15 W 3810 S 63 11W 3903 S 63 34 W 3997 S 63 53 W 4091 S 63 37 W 4185 43 93 36 36 45 94 18 26 65 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0.01 0.01 1413 56 S 3036 08 W 3349 02 S 65 2 W 1453 1494 1535 1576 1618 1660 1702 1743 1785 65 S 3119 29 S 3202 52 S 3286 73 S 3369 32 S 3452 51S 3536 37 S 3619 93 S 3704 62 S 3788 18 W 3441 30 W 3533 17 W 3627 55 W 3720 85 W 3813 28 W 3906 61W 3999 O3 W 4094 28 S 65 1W 79 S 64 59 W 22 S 64 57 W 21 S 64 55 W 28 S 64 53 W 73 S 64 51W 95 S 64 49 W 03 S 64 47 W 74 W 4188.43 S 64 46 W 5000 O0 3373.70 3305.70 69 14 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3410.18 3342.18 68 13 O0 3446.99 3378.99 68 25 O0 3484.78 3416.78 67 27 O0 3523.51 3455.51 67 8 O0 3562.11 3494.11 67 51 O0 3598.48 3530.48 68 53 O0 3634.59 3566.59 '68 47 O0 3671.05 3603.05 68 25 O0 3707.87 3639.87 68 23 S 63 25 W 4279.35 S 62 53 W 4372.45 S 62 47 W 4465.43 S 62 I8 W 4558.0I S 61 49 W 4650 20 S 61 47 W 4742 44 S 61 37 W 4835 57 S 61 4 W 4928 80 S 60 30 W 5021 87 S 60 10 W 5114 76 ' 0.01 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 01 0 O1 1827.45 S 3872 59 W 4282 11 S 64 44 W 1869.50 S 3955 1911.95 S 4038 1954.69 S 4120 1997.89 S 4201 2041.66 S 4283 2085.61 S 4365 2130.34 S 4447 2175.84 S 4528 2221.88 S 4609 65 W 4375 38 W 4468 50 W 4560 95 W 4652 15 W 4744 28 W 4837 10 W 4931 35 W 5023 12 W 5116 18 S 64 42 W 11 S 64 4O W 63 S 64 37 W 73 S 64 34 W 87 S 64 31W 92 S 64 28 W 03 S 64 24 W 97 S 64 20 W 71 S 64 16 W 7000 O0 3744.73 3676.73 68 23 7100 72OO 7300 7400 7500 7600 7700 7800 79O0 O0 3781.58 3713.58 68 21 O0 3818.35 3750.35 68 49 O0 3854.09 3786.09 69 15 O0 3889.34 3821.34 69 27 O0 3924.29 3856.29 69 33 O0 3959.31 3891.31 69 24 O0 3994.61 3926.61 69 19 O0 4029.75 3961.75 69 27 O0 4064.82 3996.82 69 33 S 60 6 W 5207 63 S 59 58 W 5300 S 61 20 W 5393 S 61 50 W 5486 S 61 42 W 5580 S 61 29 W 5674 S 61 19 W 5767 S 61 lO W 5861 S 61 4 W 5954 S 60 56 W 6048 49 40 79 35 03 68 21 80 40 0 O0 000 0 O1 0 O1 o O1 0 oo 0 O0 o oo 0 O0 0 O0 2268 17 S 4689.74 W 5209 44 S 64 11 W 2314 2360 2404 2449 2493 2538 2583 2628 2674 60 S 4770.27 W 5302 72 S 4851.03 W 5394 89 S 4933.31 W 5488 20 S 5015.74 W 5581 75 S 5098.16 W 5675 59 S 5180.40 W 5768 60 S 5262.43 W 5862 76 S 5344.43 W 5955 17 S 5426.34 W 6049 16 S 64 7 W 95 S 64 3 W 27 S 64 1 W 78 S 63 58 W 39 S 63 56 W 97 S 63 54 W 43 S 63 51W 95 S 63 49 W 49 S 63 46 W ARCO ALASKA, INC. 3M -'28 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE: 1-MAR-94 PAGE 3 DATE OF SURVEY: 02-21-94 KELLY BUSHING ELEVATION: 68.00 FT' ENGINEER: WARNER/JOHNS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000,00 4099 63 4031.63 69 41 8100.00 4134 8200.00 4169 8300.00 4204 8400 O0 4240 8500 O0 4275 8600 O0 4311 8700 O0 4347 8800 O0 4382 8900 O0 4418 36 4066.36 69 44 39 4101.39 69 22 79 4136.79 69 5 47 4172,47 69 15 97 4207,97 69 13 50 4243.50 69 7 O1 4279,01 69 13 61 4314.61 69 7 02 4350,02 69 27 S 60 51 W 6142.11 S 60 47 W 6235.83 S 60 33 W 6329.44 S 60 23 W 6422.89 S 60 13 W 6516.23 S 59 55 W 6609.61 S 59 42 W 6702.98 S 59 24 W 6796'.32 S 59 15 W 6889.60 S 59 10 W 6982.95 0 O0 0 O0 0 O0 0 O0 0 01 0 01 0 O0 0 O0 0 O0 0 O0 2719 77 S 5508 25 W 6143 12 S 63 43 W 2765 2811 2857 29O3 2950 2997 3044 3092 3140 51S 5590 42 S 5671 53 S 5753 81S 5834 47 S 5915 46 S 5996 84 S 6076 56 S 6157 43 S 6237 11W 6236 75 W 6330 12 W 6423 27 W 6516 27 W 6610 08 W 6703 67 W 6796 01W 6890 35 W 6983 78 S 63 41W 31 S 63 38 W 69 S 63 35 W 96 S 63 32 W 28 S 63 29 W 56 S 63 26 W 83 S 63 23 W 05 S 63 20 W 33 S 63 17 W 9000 O0 4453 14 4385.14 69 24 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 4488 41 4420.41 69 18 O0 4523 82 4455.82 69 17 O0 4559 32 4491 32 69 8 O0 4594 66 4526 66 69 25 O0 4629 87 4561 87 69 18 O0 4665.89 4597 89 68 44 O0 4702.14 4634 14 68 40 O0 4738.61 4670 61 68 27 O0 4775.82 4707 82 68 6 10000 O0 4812 99 4744 99 68 15 10100 10200 10300 10400 10500 10600 10700 10800 10900 O0 4849 O0 4886 O0 4923 O0 4960 O0 4997 O0 5034 O0 5070 O0 5107 O0 5144 74 4781 74 68 20 62 4818 62 68 22 77 4855 77 68 20 81 4892 81 68 20 76 4929 76 68 22 58 4966 58 68 26 97 5002 97 .68 57 O0 5039.00 68 38 48 5076.48 67 37 S 58 58 W 7O76 40 S 58 56 W 7169 S 58 53 W 7263 S 58 45 W 7356 S 58 40 W 7449 S 58 46 W 7543 S 59 51W 7636 S 59 39 W 7729 S 60 32 W 7822 S 63 16 W 7915 77 09 36 68 04 18 26 25 05 S 63 4 W 8007 89 S 63 2 W 8100 S 62 47 W 8193 S 62 37 W 8286 S 62 22 W 8379 S 62 10 W 8472 S 61 56 W 8565 S 61 45 W 8658 S 61 30 W 8751 S 61 6 W 8844 89 84 68 56 49 45 59 86 54 0 O0 0 O0 0 O0 0 O0 0 oo 0 O0 0 O1 0 O1 0 O0 0 02 o Ol 0 O0 0 O0 0 O1 0 O0 0 O0 0 O0 0. O0 0.01 0.01 3188 56 S 6317 67 W 7076 71 S 63 13 W 3236 3285 3333 3382 3430 3478 3525 3572 3615 85 S 6397 16 S 6477 58 S 6557 15 S 6637 92 S 6717 24 S 6798 22 S 6878 18 S 6958 O1S 7041 81W 7170 90 W 7263 87 W 7356 81W 7449 70 W 7543 09 W 7636 58 W 7729 99 W 7822 32 W 7915 02 S 63 10 W 29 S 63 7 W 52 S 63 3 W 80 S 63 0 W 12 S 62 57 W 24 S 62 54 W 30 S 62 52 W 27 S 62 50 W 08 S 62 49 W 3656 95 S 7124 14 W 8007 91 S 62 50 W 3699 3741 3784 3827 3870 3913 3957 4002 4046 15 S 7207 50 S 7289 18 S 7372 11S 7454 37 S 7536 98 S 7618 93 S 7701 31S 7783 69 S 7864 02 W 8100 76 W 8193 21W 8286 58 W 8379 82 W 8472 93 W 8565 06 W 8658 11W 8751 50 W 8844 92 S 62 50 W 87 S 62 5O W 71 S 62 5O W 59 S 62 49 W 51 S 62 49 W 48 S 62 49 W 61 S 62 48 W 87 S 62 47 W S5 S 62 46 W 11000 O0 5183 02 5115.02 66 44 1110o 11200 11300 11400 11500 11600 11700 11800 11900 oo 5223 O0 5263 O0 5304 oo 5342 oo 5380 oo 5417 oo 5454 O0 5491 O0 5528 30 5155 30 65 59 98 5195 49 5236 71 5274 21 5312 63 5349 68 5386 48 5423 37 5460 98 66 3 49 66 23 71 68 1 21 68 2 63 68 13 68 68 16 48 68 19 37 68 16 S 60 15 W 8936 76 S 59 28 W 9028 S 59 8 W 9119 S 60 49 W 9210 S 62 8 W 9303 S 61 46 W 9395 S 61 35 W 9488 S 61 29 W 9581 S 61 11W 9674 S 61 0 W 9767 17 37 64 04 73 45 32 26 17 00l 00l 0 01 o Ol 0 O2 00l 000 0 O0 0 O0 o O0 4091 79 S 7945 O0 W 8936 77 S 62 45 W 4137 4184 4230 4274 4318 4362 4406 4451 4496 81S 8024 43 S 8102 91S 8181 44 S 8262 06 S 8344 06 S 8426 39 S 8507 31S 8589 31S 8670 12 W 9028 68 W 9119 40 W 9210 91W 9303 71W 9395 34 W 9488 96 W 9581 38 W 9674 70 W 9767 18 S 62 43 W 37 S 62 41W 64 S 62 39 W 04 S 62 39 W 74 S 62 38 W 45 S 62 38 W 32 S 62 37 W 27 S 62 36 W 18 S 62 35 W COMPUTATION DATE: 1-MAR-94 PAGE 4 ARCO ALASKA, INC. 3M - 28 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 02-21-94 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: WARNER/JOHNS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SDUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEE'I- FEET DEG MIN 12000 O0 5565.78 5497 78 67 47 12100 12200 12300 12400 12500 12600 12700 12800 12900 O0 5604.36 5536 O0 5649.73 5581 O0 5700.19 5632 O0 5754.22 5686 O0 5810.76 5742 O0 5868.94 5800 O0 5928.60 5860 O0 5990.98 5922 O0 6055.96 5987 36 65 44 73 60 45 19 58 7 22 56 8 76 55 4 94 53 51 60 52 29 98 50 28 96 48 38 S 60 30 W 9859 85 S 60 2 W 9952 02 S 59 56 W 10040 98 S 59 36 W 10127 20 S 60 10 W 10211 21 S 60 1 W 10293 61 S 60 0 W 10374 85 S 62 34 W 10455.'06 S 66 11 W 10533.16 S 68 45 W 10608.87 0 O1 0 O1 0 04 0 O4 0 02 0 O2 0 02 0 O2 0 03 0 O3 4541.94 S 8751 44 W 9859 87 S 62 34 W 4587.71S 8831 4632.37 S 8908 4675.84 S 8983 4718.42 S 9055 4759.48 S 9127 4800,18 S 9197 4838,99 S 9267 4872.70 S 9338 4901,58 S 9408 54 W 9952 60 WlO041 19 W10127 76 W10211 29 W10293 70 W10374 94 W10455 42 W10533 71 W10608 04 S 62 33 W 02 S 62 32 W 25 S 62 30 W 28 S 62 29 W 69 S 62 28 W 94 S 62 26 W 16 S 62 26 W 25 S 62 27 W 93 S 62 29 W 13000.00 6123.28 6055.28 47 53 13100.00 6190.35 6122.35 47 53 13200.00 6257.42 6189.42 47 53 13240,00 6284.25 6216,25 47 53 S 68 27 W 10682.79 S 68 27 W 10756.58 S 68 27 W 10830.38 S 68 27 W 10859.90 0. O0 O. O0 0. O0 0. O0 4927.67 S 9478.43 W10682.82 S 62 32 W 4954.93 S 9547.42 W10756.60 S 62 34 W 4982.18 S 9616.40 W10830.39 S 62 37 W 4993.09 S 9644.00 W10859.91 S 62 38 W COMPUTATION DATE: 1-MAR-94 PAGE ARCO ALASKA, INC. 3M - 28 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 02-21-94 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: WARNER/JOHNS INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH 7RUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 0.00 0.00 1000.00 986.12 918 2000.00 1842.81 1TT4 3000.00 2331.28 2263 4000.00 2680.43 2612 5000.00 3015.09 2947 6000.00 3373.70 3305 7000.00 3744.73 3676 8000.00 4099.63 4031 9000.00 4453.14 4385 -68 O0 0 0 12 21 46 81 43 14 28 69 28 43 71 50 09 67 53 70 69 14 73 68 23 63 69 41 14 69 24 N 0 0 E S 72 56 W 107 S 64 48 W 610 S 63 37 W 1468 S 64 53 W 2404 S 64 23 W 3346 S 63 25 W 4279 S 60 6 W 5207 S 60 51W 6142 S 58 58 W 7076 0 O0 67 14 O2 81 19 35 63 11 40 0 O0 0 O5 0 O3 0 O1 0 O1 0 O1 0 O1 0 O0 0 O0 0 O0 0 O0 N 27 225 602 1014 1413 1827 2268 2719 3188 0 O0 E 98 S 106 38 S 570 79 S 1340 35 S 2182 56 S 3036 45 S 3872 17 S 4689 77 S 5508 56 S 6317 0 O0 N 0 0 E 74 W 110 31W 613 93 W 1470 73 W 2406 08 W 3349 59 W 4282 74 W 5209 25 W 6143 67 W 7076 34 S 75 19 W 23 S 68 26 W 19 S 65 48 W 91 S 65 4 W O2 S 65 2 W 11 S 64 44 W 44 S 64 11W 12 S 63 43 W 71 S 63 13 W 0000.00 4812.99 4744.99 68 15 ,1000.00 5183.02 5115.02 66 44 ,2000.00 5565.78 5497.78 67 47 ,3000.00 6123.28 6055.28 47 53 ,3240.00 6284.25 6216.25 47 53 S 63 4 W 8007.89 S 60 15 W 8936.76 S 60 30 W 9859.85 S 68 27 W 10682.79 S 68 27 W 10859.90 0.01 0.01 0.01 0. O0 0. O0 .3656.95 S 7124.14 W 8007.91 S 62 50 W 4091.79 S 7945.00 W 8936.77 S 62 45 W 4541.94 S 8751.44 W 9859.87 S 62 34 W 4927.67 S 9478.43 W10682.82 S 62 32 W 4993.09 S 9644.00 W10859.91 S 62 38 W COMPUTATION DATE: 1-MAR-94 PAGE 6 krco ALASKA, INC. ~M - 28 <UPARUK ~ORTH SLOPE, ALASKA DATE OF SURVEY' 02-21-94 KELLY BUSHING ELEVATION' 68.00 FT ENGINEER' WARNER/JOHNS INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 0 O0 68 O0 168 O0 268 O0 368 O0 468 05 668 37 669 24 770 84 874 25 0 O0 68 O0 368 O0 268 O0 368 O0 468 O0 568 O0 668 O0 768 O0 868 O0 -68.00 0 0 N 0 0 E 0.00 0 7 S 59 8 E 100.00 0 25 S 21 0 E 200.00 0 15 S 27 55 E 300.00 0 28 S 14 18 W 400.00 3 4 S 73 24 W 500.00 6 0 S 80 26 W 600.00 8 53 S 80 58 W 700.00 I2 9 S 77 13 W 800.00 17 33 S 74 50 W 0 O0 -0 O1 0 O2 -0 08 0 O1 2 74 10 32 22 79 39 98 65 44 0 O0 0 01 0 01 0 O0 0 O0 0 O2 0 O3 0 O2 0 O3 0 O5 0 O0 N 0 03 S 0 32 S 0 80 S 138S 2 44 S 4 lOS 6 175 9 628 15 95 S 0 O0 E 0 03 E 0 14 E 0 50 E 0 70 E I 83 W 9 49 W 22 46 W 40 03 W 65 42 W 0 O0 N 0 0 E 0 0 0 1 3 10 23 41 67 04 S 39 23 E 35 S 24 I3 E 94 S 31 59 E 55 S 27 2 E 05 S 36 49 W 34 S 66 38 W 30 S 74 39 W 17 S 76 29 W 33 S 76 18 W 980.52 1088.52 1068 1196.82 1168 1306.45 1268 1418.49 1368 1534.70 1468 1655.15 1568 1776.10 1668 1900.63 1768 2034.92 1868 968 O0 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 21 22 O0 22 28 O0 23 3 O0 25 34 O0 28 26 O0 32 45 O0 34 12 O0 34 44 O0 38 56 O0 44 33 S 73 7 W S 72 29 W S 71 22 W S 69 2 W S 66 5 W S 65 49 W S 65 46 W S 64 33 W S 64 35 W S 64 36 W 100 63 140 81 181 82 226 35 276 65 335 69 402 72 470 70 544 82 634 29 0 O5 0 03 0 O1 0 O1 0 O2 0 O3 0 O3 0 01 0 02 0 O3 25 89 S 38 5O 66 85 109 136 165 197 235 99.89 W 103.19 S 75 28 W O0 S 138.86 W 143.96 S 74 42 W 86 S 178.38 W 185.48 S 74 5 W 07 S 220 63 W 230 31 S 73 20 W 25 S 267 34 W 280 60 S 72 19 W 49 S 321 28 W 339 42 S 71 11 W 90 S 382 56 W 406 32 S 70 19 W 50 S 444 30 W 474 12 S 69 34 W 45 S 511 22 W 548 02 S 68 53 W 71 S 592 16 W 637 35 S 68 18 W 2182 23 1968.00 1900 O0 50 9 2347 2543 2815 3104 3390 3676 3960 4278 4585 53 2068.00 2000 56 2168.00 2100 23 2268 O0 2200 64 2368 O0 2300 91 2468 O0 2400 27 2568 O0 2500 71 2668 O0 2600 29 2768 O0 2700 41 2868 O0 2800 O0 55 13 O0 63 25 O0 70 21 O0 69 26 O0 69 25 O0 69 6 O0 71 9 O0 71 27 O0 70 22 S 65 12 W 742 32 S 64 25 W 873 76 S 63 47 W 1042 09 S 63 10 W 1294 44 S 63 41 W 1565 99 S 63 53 W 1834 17 S 64 5 W 2101 37 S 64 41 W 2367.56 S 65 14 W 2668.72 S 64 48 W 2958.85 0 O4 0 03 0 04 0 03 0 oo 0 O0 0 01 0 01 0 O0 0 O0 281.78 S 689 95 W 745 27 S 67 47 W 337.55 S 809 410.69 S 960 525.17 S 1185 646.33 S 1428 764.44 S 1669 881.81S 1909 998.49 S 2149 1125.51 S 2422 1247.92 S 2685 09 W 876 77 W 1044 66 W 1296 71W 1568 55 W 1836 66 W 2103 O0 W 2369 36 W 2671 67 W 2961 68 S 67 21W 87 S 66 51W 76 S 66 7 W 11 S 65 4O W 24 S 65 24 W 42 S 65 13 W 64 S 65 5 W 06 S 65 5 W 44 S 65 5 W 4872 34 2968.00 2900 O0 68 50 5136 5411 02 3168 5688 91 3268 5983 91 3368 6256 03 3468 6515.77 3568 6791.72 3668 7063.16 3768 7339.34 3868 61 3068 O0 3000 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 oo 3800 O0 67 0 O0 68 0 oo 68 50 O0 69 21 O0 67 40 O0 68 15 O0 68 25 oo 68 23 O0 69 19 S 64 43 W 3227.60 S 63 59 W 3472.10 S 63 38 W 3727.58 S 63 31W 3986.82 S 63 25 W 4264.30 S 62 28 W 4517.37 S 61 56 W 4757.06 S 60 31W 5014.18 S 60 1 W 5266.28 S 61 45 W 5523.58 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0 O1 0.00 0.01 1362 56 S 2928.94 W 3230.37 S 65 3 W 1468 1581 1697 1820 1935 2048 2172 2297 2422 39 S 3149.47 W 3474.95 S 65 0 W 27 S 3378.71 W 3730.43 S 64 55 W 75 S 3610 33 W 3989 59 S 64 49 W 71 S 3859 13 W 4267 06 S 64 45 W 85 S 4084 49 W 4520 02 S 64 38 W 57 S 4296 04 W 4759 48 S 64 30 W 04 S 4521 65 W 5016 29 S 64 21 W 47 S 4740 62 W 5268 O0 S 64 9 W 29 S 4965 73 W 5525 04 S 64 0 W COMPUTATION DATE: 1-MAR-94 PAGE 7 krco ALASKA, INC. 3M - 28 <UPARUK ~ORTH SLOPE, ALASKA DATE OF SURVEY: 02-21-94 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: WARNER/JOHNS INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE -ZASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEP1-H DEG MIN DEG MIN 7624 68 3968 O0 3900 O0 69 22 79O9 9196 9477 8759 9O42 9324 9605 9879 0149 10 4068 06 4168 53 4268 09 4368 16 4468 39 4568 81 4668 03 4768 64 4868 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 69 34 O0 69 23 O0 69 13 O0 69 5 O0 69 21 O0 69 12 O0 68 45 O0 68 5 O0 68 23 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOLFFH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 61 18 W 5790.77 S 60 57 W 6056.93 S 60 33 W 6325.75 S 59 58 W 6588.63 S 59 16 W 6851.45 S 58 55 W 7115.77 S 58 44 W 7379.10 S 59 50 W 7641.59 S 63 17 W 7895.60 S 62 54 W 8147.04 0 O0 0 O0 0 O0 0 O1 0 O0 0 O0 0 O0 0 O1 0 02 0 O0 2549 68 S 5200 67 W 5792 04 S 63 53 W 2678 2809 2939 3073 3208 3345 3480 3606 3720 31S 5433 61S 5668 95 S 5897 02 S 6124 92 S 6351 40 S 6577 96 S 6802 26 S 7023 12 S 7248 79 W 6058 54 W 6326 09 W 6589 17 W 6851 47 W 7116 35 W 7379 77 W 7641 95 W 7895 13 W 8147 O1 S 63 46 W 63 S 63 38 W 31 S 63 30 W 93 S 63 21W O6 S 63 12 W 24 S 63 2 W 65 S 62 54 W 63 S 62 49 W 07 S 62 50 W 0419 44 4968 O0 4900 O0 68 18 0691 0961 1209 1467 1735 2005 2236 2424 2598 76 5068 55 5168 90 5268 46 5368 97 5468 86 5568 94 5668 61 5768 41 5868 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 68 53 O0 67 19 O0 66 4 O0 67 55 O0 68 16 O0 67 44 O0 60 1 O0 55 46 O0 53 50 2763.69 5968.00 5900.00 51 6 2918.19 6068.00 6000.00 48 30 3066.68 6168.00 6100.00 47 53 3215.78 6268.00 6200.00 47 53 3240.00 6284.25 6216.25 47 53 S 62 19 W 8397 63 S 61 46 W 8650 S 60 42 W 8901 S 59 5 W 9128 S 61 53 W 9365 S 61 29 W 9614 S 60 29 W 9865 S 59 50 W 10073 S 60 13 W 10231 S 60 0 W 10373 9O 39 4O 57 72 27 05 58 57 S 64 59 W 10505.08 S 68 38 W 10622.43 S 68 27 W 10731.99 S 68 27 W 10842.03 S 68 27 W 10859.90 0 O0 0 O0 0 O1 0 O1 0 02 0 O0 0 O1 0 O5 0 02 0 02 0.03 0.03 0. O0 0. O0 0. O0 3835 49 S 7470 58 W 8397 65 S 62 49 W 3954 4074 4189 4303 4422 4544 4648 4728 4799 30 S 7694 33 S 7914 07 S 8110 81S 8318 35 S 8537 61S 8756 48 S 8936 55 S 9073 54 S 9196 29 W 8650 21W 8901 44 W 9128 13 W 9365 32 W 9614 16 W 9865 37 W10073 45 W10231 59 W10373 92 S 62 48 W 40 S 62 46 W 40 S 62 41W 58 S 62 39 W 73 S 62 37 W 29 S 62 34 W 09 S 62 31W 65 S 62 28 W 66 S 62 26 W 4861.09 S 9312.81 W10505.17 S 62 26 W 4906.54 S 9421.42 W10622.49 S 62 29 W 4945.85 S 9524,43 W10732.02 S 62 33 W 4986.48 S 9627.29 W10842.03 S 62 37 W 4993.09 S 9644.00 W10859.91 S 62 38 W COMPUTATION DATE: I-MAR-94 PAGE 8 ARCO ALASKA, INC. 3M - 28 KUPARUK NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a GCT LAST READING BASE KUPARUK a PBTD 7" CASING DATE OF SURVEY: 02-21-94 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: WARNER/JOHNS INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1285' FNL A 1737' FEL, SEC25 T13N R8E MEASURED DEPTH BELOW KB I'VD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOLFFH EAST/WEST 6065 O0 12880 O0 12887 O0 12887 O0 12980 O0 12989 O0 13130 O0 13216 O0 13240 O0 3397 18 6042 78 6047 38 6047 38 6109 25 6115 90 6210.47 6268.15 6284.25 3329 18 5974 78 5979 38 5979 38 6041 25 6047 90 6142 47 6200 15 6216 25 1854 71S 4896 11S 4898 04 S 4898 04 S 4923 42 S 4924 68 S 4963 11S 4986 55 S 4993 09 S 3926 71W 9394 70 W 9399 61W 9399 61W 9464 24 W 947O 85 W 9568 11W 9627 44 W 9644.00 W ARCO ALASKA, INC. 3M - 28 KUPARUK NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD COMPUTATION DATE: 1-MAR-94 PAGE 9 DATE OF SURVEY: 02-21-94 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: WARNER/JOHNS ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION : 1285' FNL & 1737' FEL, SEC25 T13N R8E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 12880.00 12887.00 12887.00 12989.00 13130.00 13240.00 6042 78 6047 38 6047 38 6115 90 6210 47 6284 25 5974 78 5979 38 5979 38 6047 90 6142 47 6216 25 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4896.11S 4898.04 S 4898.04 S 4924.68 S 4963.11S 4993.09 S 9394 70 W 9399 61W 9399 61W 947O 85 W 9568 11W 9644 O0 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 13240.00 6284.25 6216.25 10859.91 S 62 38 W COMPANY ARCO ALASKA, INC. FIELD 3M - 28 WELL KUPARUK COUNTRY USA RUN I DATE LOGGED 02-21-94 REFERENCE 94079 All interpretations are opinions based on inferences from elecffical or o~er measurements and we cannot, and cio not guarantee the accuracy or correctness of any nterpretations, and we shall not, except in the case ol: gross or willuII negligence on our par~. be liable or responsible for any loss, costs, damages o~ expenses incurred or sustained by anyone resulti.ng from any nterp~reta§on, ~made by a,r~ of .o. ur officers,.age, n.~ or employees.. 'l'h~e ,se in. te, rpretatio~s are also subject to our g~eneral/arms atto g, or~ tions as se[ ou[ in our curren[ pnce ~:~cneoule. WELL: 3H-28 ' .(1285' FNL,1737' FEL,SEC 25,T13N,R8E,UR) HORIZONTAL PROJECTION NORTH 6000 4000 2000 -2000 -4000 -6000 -8000 .SOUTH - 1OOOO R~F 9407~ SCALE = 1 / 2000 IN/F'r "'i'?'?!" i'7'i'i"I'??'?!"F'i'?!"'!"!'"i'"~-?"i"?i .... {i"i'"i ?'i ?i' ?'?'?'? 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'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-. :. -12000 -10000 -8000 -6000 -4000 -2000 0 2000 4000 EAST ,.WELL- 31,1-28 (1285' FNL,1737' FEL,SEC 25,T13N,R8E,UH) VERTICAL PROJECTION 63.0 -2000 0 0 2000 4000 6000 8000 10000 12000 14000 24.3.0 PROJECTION ON VERTICAL PLANE 63.0 - 243.0 SCALED IN VERTICAl. DEPTHS HORIZ SCALE = 1 / 2000 IN/FT ARCO Alaska, Inc. Date: March 25, 1994 RETURN TO: Transmittal #: 9046 ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage_., AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-28 Directional Survey 02-21-94 Acknowledged: DISTRIBUTION; 94O79 D&M State of Alaska (2 copies) Off ~ ~as Oon~. AnChorage ARCO Alaska, Inc. Date: March 04, 1994 Transmittal #: 9021 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-28 Ultrasonic Imager-USlT 02-21-94 ~ 10590-13020 5'¢ 3M-28 Cement Bond Log CBT 02-21-94 ¢..\ 10590-12990 _5 Receipt Acknowledge: DiSTRiBUTiON: Drilling state 'of AlaSka(+sepia) ALASKA ~)IL AND GAS CONSERVATION ~OMMI~SION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 21, '1994- A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3M-28 ARCO Alaska, Inc. Permit No: 94-12 Sur. Loc. 1285'FNL, 1737'FEL, Sec. 25, T13N, R8E, UM Btmhole Loc. 1000'FNL, 843'FEL, Sec. 34, T13N, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincere ly, Russell A. Douglass Commi s s ioner BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic [] Development Oil X Test Re-Entry [-] Deepen I'-1 Service r-] DevelopmenlGas r=l Single Zone X Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25524, ALK 2655 4. Location of well at surlace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1285' FNL, 1737' FEL, SEC. 25, T13N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 884' FNL, 623' FEL, Sec. 34, T13N, R8E, UM 3M-28 #U-63061 0 At total depth 9. Approximate spud date Amount 1000' FNL, 843' FEL, Sec. 34, T13N, R8E, UM 1/22/94 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3M-01 13209' MD 843'@ TD feet 9.8' @ 550' MD feet 1 920 6213' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400 feet Maximum hole angle 68.89° Maximum sudace 1998 psig At total depth (TVD) 3275 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cemenl Hole Casing Weight Grade Coupling Length MD TVD MD TV• (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 47.0# L-80 BTC 2684' 41' 41' 2725' 2208' 770 Sx Arcticset III & HF-ERW 600 Sx Class G 12.25" 9.625" 36.0# J-55 BTC 3241' 2725' 2208' 5966' 3375' 8.5" 7" 26.0# L-80 BTCMOE 13168 41' 41' 13209' 621 3' 150 SxClass G HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented ,~e~l~r~,d/,(~,,,p~J;~ True Vertical depth L. EI VEIJ Conductor Surface Intermediate Production JAN '1 4- 1994 Liner - Perforation depth: measured Ai~Ska, 0It & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25,050 requiremenls X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~CommissionTitleuse OnlyArea Drilling! En,ineer Date Permit~.Number-- IAPI number IAppr°val date/--(~J "" ~7'/ [other requirements ~'~'/-/'.?~ 50- 4~Z- ¢- ~:__~ ?_'_ ,-~.:.,/' ~'7/ -~, See cover letter for Conditions of approval Samples required ~ Yes J~ No Mud Icg required [-1 Yes [] No Hydrogen sulfide r-1 Yes ~ No Directional survey required ,~ Yes F~ No measures Required working pressure for BOPE [] 2M ~ 3M ~ 5M [] 1OM [] 15M Other: ORIGINAL SIGNED BY by order of _Approved_ by RUSSELL A. DOUGLASS Commissioner the commission Dale / / '-z-,/)/ Form 10-401 Rev. 7-24-89 Sdbmit in triplicate · . o . . . o o · 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M-28 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (5966')according to directional plan. Run and cement 9-5/8" casing (cement to surface). No cement bond logs to be run in 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (13209') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED JAN I 4 1994 A!a. ska 0it & Gas Cons. C0mrnissi0n Anchorage. DRILLING FLUID PROGRAM Well 3M-28 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids' Spud to 9-5/8" surface casing 9.0-10.5 15-25 15-35 5O-8O* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.7 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1998 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-28 is 3M-01. As designed, the minimum distance between the two wells would be 9.8' @ 550' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED JAN 'i 4- 19,94- (~ii & Gas Cons. Commission ,Anchorage Created by : jones For: S BRADLEY !Date plotted : 13-Jan-94 iPlot Reference is 28 Version #1. Coordinates ore in feet reference slot #28. ',True Vertical Depths ore reference wellhead. Baker Hughes INTEQ ALASKA Inc. · , Structure : Pod 5M Well : 28 Field : Kuparuk River Unit Location : North Slope, Alosko < - - We st sco, ,: 99C-0 9550 8800 8250 7700 7150 6600 6050 55C~0 4950 4400 3850 3500 2750 2200 1650 I lO0 550 0 550 I I I I I I I I ! I I I I I I I I I I I I I I I I I I I I I ] I I I I I I I I TD LOCATION: ] 1000' FNL, 845' FEL SEC. 34, T!3N, RBE S 62.68 DEG W // 10632' (TO ~IARGET) /// ***PLANE OF PR..'OS.~L**, ~ I SlJRFACE LOCATION: . . . TARGET LOCATION: 884' FNL 623' FEL SEC. 54, T15N, RBE 7 0 .J RKB EL~'A~OH: 68' 550 J T. 3.00 KOP 1¥D=400 TMD=400 DEP:O I ~ 8.82 13EGIN TURN TO TARGET z, Jo=633 TMD=653 OEP=13 -~ ~ 14.54 ~,1oo_] ~ 20.42 5 DEG / ~00' DOGLEG , \ 32.3o '% 38.27 TARGET 'FVD:6004 TMD=12884 DEP:10632 SOUTH ~879 WEST 9646 c, 0 .. 5~ RECEIVED ~ 44.25 13/ PERMFROST 'PJD=1718 TMD:1847 OEP:506 '%.. 50.25 '-,. 56&i? '~6-2e?'~.18,..,. EOC T'FD--°'"O-':', --=_, ,~ T~'40-272~, - ~ ~nEP= 192:%_ ~ 252 ~..__ T/ UGNU SNDS TVD=2218 TMD=2753 BEP=I ~'~ T/ W SAK SNDS TVD=2905 TMD=4669 DEP=5059 ~ B/ ¥,' SA]< SNDS TVD=3218 TMD=5530 OEP:5842 ~ 9 5/8" CSG pT TVD=5375 TMD=5966 DEP=4249 K--la PCD=3493 TMD=6294 DEP=4555 , -,..,~ MAXIMUM ANGLE 66.89 EgG K-5 T'VD=4958 TMD=IO..,07 DEP=8299~--.. BEGIN ANGLE DROP TVD=5526 TMD=11940 DEP=9822 "~'-~.... 68.00 DROP 2 OEO, / 100' "~ 60.00 TARGET ANGLE ~AR~ET - T/ ZONE C (gOD) ?VD=6004 TMD:I2884 DEP:I0632 .,-~::-x52'00 T/ ZONE A T~D=fiOO7 TMD=12889 DEP=10635.'~"~~F B/ KUP SNDS TVD=6084 TMD=13009 DEP=10727 50 DEG T~) / 7" CSG PT TVD:6213 TMD=IS209 DEP:tOOO0 11o0 16500 C 22OO 2750 I _58,50 ,JAN 1 4- ]994 A!aska Oil & 6as Oons. 6ommission Anchorage 6609~ I I I I I I ! I I ! I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 0 550 1100 1650 22C~) 2750 33r00 --~aSO 4400 49['/0 5500 6050 6600 7150 7700 8250 880'3 93~M) 9900 10450 11000 Scole 1 : 275.00 Yerfic~l Secflon on 242.68 ozimuth with reference 0.00 Iq, 0.00 E from slo] #28 450 400 350 300 250 200 150 1 O0 50 0 I I I I I I I I I I I I I I I I I I ARC 0 ALASKA, fl~ld : Kul~ruk River Unit I.oc~on : North Slope, AIo.ko] 1300 11 1500 7O ~00 1300 5O 200 150 lO0 5O 5O _ 100 _ 150 _ 200 Casing Design / Cement Calculations 13-Jan-94 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3M-28 5,966 ft 3,375 ft 13,209 ft 6,213 ft 4,669 ft 12,884 ft 6,0O4 ft 3200 psi ::::?:?::::?:?:?:?:?:::::::?:::?:?:?:?::::?:?:?:?:?:?:?:?:?:?::?:::?:?:?:?:?:?:::?:::?:?:?:?:?:?:::?::::::: ** See Page 4 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,375 ft {(13.5'0.052)-0.11}*TVDshoe =! 1,998 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 3,200.0 ppg 6,004 ft 150 psi 10.7 PPgl Surface lead: Surface tail: Top West Sak, TMD = 4,669 ft Design lead bottom 500 ft above the Top of West Sak = 4,169 ft Annular area = 0.3132 cf/If Lead length * Annulus area - 1,306 cf Excess factor - 15% Cement volume required - 1,502 cf Yield for Permafrost Cmt - 1.94 Cement volume required -I 770 sxI TMD shoe -- 5,966 ft (surface TD - 500' above West Sak) * (Annulus area) = 563 cf Length of cmt inside csg = 80 ft Internal csg volume - 0.4110 cf/If Cmt required in casing - 33 cf Total cmt = 596 cf Excess factor = 15% Cement volume required = 685 cf Yield for Class G cmt = 1.15 Cement volume required =[ 600 sx] ,IA, I'! 'i Z!. 99t¥ Anchorag~ Casing Design / Cement Calculations 13-Jan-94 Production tail: TMD = 13,209 ft Top of Target, TM D = 12,884 ft Want TOC 500' above top of target - 12,384 ft Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 144 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing - 17 cf Total cmt = 161 cf Excess factor = 15% Cement volume required = 185 cf Yield for Class G cmt = 1.23 Cement volume required =[ 150 sx TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air - Length * (Wt/ft) Buoyancy = Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy Tension (Pipe Body) Design Factor Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/f0 = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length: Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 1086000 lb 5,966 ft 47.00 Ib/ft 280402.0 lb 45131.4 lb 235270.6 lb 1161000 lb 5,966 ft 47.00 Ib/ft 280402.0 lb 45131.4 lb 235270.6 lb 4,91 604000 lb 13,209 ft 26.00 Ib/ft 343434.0 lb 55578.3 lb 287855.7 lb 667000 lb 13,2O9 ft 26.00 Ib/ft 343434.0 lb 55578.3 lb 287855.7 lb 2.31 Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor :1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =L Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 13-Jan-94 687O psi 1998.0 psi 3.41 7240 psi 6967 psi 2875 psi 4091 psi 1.8J 4750 psi 0.558 Ib/ft 947 psi 5.0] 5410 psi 0.558 Ib/ft 3467 psi 1.61 RECEIVED Casing Design/Cement Calculations 13-Jan-94 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength 1 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb Body Strength 1086000 lb 916000 lb 564000 lb 715000 lb Collapse 4750 psi 3090 psi 2020 psi 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength 1 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb Body Strength 604000 lb 415OOO Jb Collapse 5410 psi 4320 psi Burst 7240 psi 4980 psi Commission 20" -'UPARUK RIVER DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSi DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION EDF 3/10/92 ~ ,,.i "i /; .r~r.t~ , .~/' i'! . -,' i';~ :) .; I I 4 I L _ I II ' -~"~ 13 $/8 $000 BOP $? CK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSi REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO'I-I'OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8" - 5000 PSi SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13--5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR iTEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ~.~? ..... /7' ,. ~/'~.~ y. ~ ~ "8~ ........ ' /? .,./' ~?~ / ~'¢'Cz' 'E9 thru -]:3] :~" ; '- [~0 & 13] ' ' [14 thru 2 (4) Casg (5) BOPE [23 thru Company YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. ',~ . .. 3. Is well located proper distance from property line ................... ~. .. 4 Is well located proper distance from other wells... .//<" 5. Is sufficient undedicated acreage available in this pop . 6. Is well to be deviated & is wellbore plat included. . 7. Is operator the only affected party ................................... , , , 8. Can permit be approved before 15-day wait ............................ Lease & Well ~ ~d~L' NO e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22 23 24. 25. 26 27 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all kno~ productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on ]0-403 ............. Is adequate well bore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams $ descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...... ~ ......... Is presence of H2S gas probable ...................................... ,/ (6) Other .. ,.,..: ,. /~':?/ 29. [29 thru 31] 30. 31. C ~ - ~',C--- /'P (7) on~.act," :_ ,'"'~, ~'. ',.'--'~ 32. [32] (8) Addl 33. geology' engineering: DWJ ~I- RAD ~ ! -z o - ~,,~ ..... TAB~ ff~o/~f ' rev 6/93 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ' Additional remarks' MERIDIAN' UM~ SM WELL TYPE:- Exp~~ Inj Red ri 1 1 Rev 0 --I 'TZ 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. FIEI~D NA~E : KUPAR[]K RIVER BOPOUGH : NORT~ SLOPE STATE ; ALASKA REvE~E~CE ~0 : 04046 RECEIVED MAY 3 1 1994 Alaska 0il & Ems 0ohs. Commission Anchorage IS wade v'ert~ficatiop ListJnq .-hlu~berger AlasKa ComputJnq Center 994 12: 35 SERVICE NAME : EOIT D,~TE : Q4105/ 3 OPI~IN : FbIC REE!. ~A~E : 94046 CONTINU~T!DM ~ : PPEVIOOS ~E~]L ~ CO~E~T : ARC{] ALASKfi~, INC,,~UPARUK RIVER U~IT, 3M-28,50-0~9-2244~-00 **** TAPE SERVICE ~M~] : D~TE ~ 04/05/ 3 OPI~I~ : FLIC TApF NA~E : 04046 CONTINU~TIOM # PREVIOUS TAD~ CO~ENT : ~R(,O aLASKA, INC,,~.UPARUR RIVED UNIT, 3M-28,50-029-22442-00 MWD/~ a.l.) LOGS OPE~ATO~: TAP~ CR~i~ATION DA.T~; jOB DATa JOB ~sLiH6ER: I:OC, G '~' ' SUR~AC[C !,OChTlON TaW~S~ilP: FNL: ESL: FWL: KELLY DERRIC~ FLOOP GROU~D W~L!, ChSI~IG R~]CORD ~ST STPi~G 2ND STPlNG 3M~28 500292244200 ARCO ALASKA INC, SCHi, U~i, BERGE~ ~ELL SERVICES BIT RUN ~ .. 046 NICHObS BIT RUN 3 5 13N 8~ 1285 1737 68.00 68,00 ~7.O0 OPEN ~OLE CISING DRILLERS SIT SIZE (I~,~) SIZE (I~l) DEPT~I (FT) '~.';~ ........ ;~[ .... ~.065.0 PAGE~ iS Wave Yerii]lcation t, istinrj 4-MAY-!994 1.2:35 .'htumberger Alaska Comput~n. Center ~RD STRIWG DRO[)~JCTION STRING RWM~RKS: **~*~********* RUN 1 *************** R~S RP ..0 B.[ : 68 90 ~T NOS RP TO ~IT~ 127,79 FT ~-o 9;'0 BlT: 65 73 FT GR T(] 6IT: 76 15 FT L)EN TO BiT: 1~9.10 FT NE'~T TO ~IT: 136,0g FT DPlLLFD INTERVA~: 6065-~260g FT ************** RUN ~ RGo RP TO BIT: 29.8l FT. NDS .RP TO BIT: 52,29 ,}:{MS TO giT: 26.64 FT, ~Fi.jT T0 BIT: 60.5~ F HOL, R ~l',iGbR AT TIll 51,00 PEG ~ 13 240 PT, TD W~:LL ~ 10:58 F~JB 3,1994 .... ' Fi[ID ~i'[IGHT = !i.b V?GCOSIT'Y= B6.:O = LIS FORMAT DATA LTS FOR~.~AT nATA PAGE' **** FILM NEADFR **** FILF NA~!E SFRVICE : FbTC VFR$ION : nOlCnl D~T~ : 04/05/ 3 M~X RFC SIZ~ : !.024 FTL~ TYPE : L~S? FI!,,E Oe~th shiite~ and cl~POed curves~ all bit runs merged. DFP~H I~C~E~E~T: 0.5000 FIL~ SL.{U~ARY !,DWG TOOT, C()D~: STgRT D~;PTH STOP DEPTH ................. .... i ......... CDP 60 3214,0 [8 Tape Verification Listina :hlumbefger Alask:a Co~'putln~ Center ~-MAY-19g4 12:35 # gASELI N 12906,0 12867,5 ~27.5 5 ~27~7,0 12742,5 ~ '.269 J, 0 ~2623,5 ~ 2561,0 2503,0 ~2492,5 2485 0 ...... ~ 244! 5 12409,5 J2387,0 2376,5 2346.0 ~2~97,5 1221. o 5 . fol. 2,0 ~ 1868 5 6085,0 13! Sa, 0 CURVE F[)R SHIFTS: (;iq [)ATB, (~4EASU~ED DEPTF~) E Il) E P T H CED DATA !;DWG .TOOL C l~ P ..... -. .... E~UiVAI,EMT U~$MIrTED 12904.5 ~2866,5 ~2794,5 ~2765,0 12741,0 1.2689,5 1~620,5 ~558,5 ~2543.0 12506,0 ~2496,5 !.2a86,5 12481,5 J_24.~J,O 12408.5 12387,5 ~2379,5 !.2350.5 ~2298.5 12~3.0 !206~,0 12020.5 !19i6,0 11~86,5 !1~73,5 !.1869.5 i1761,0 ~1728,0 1162!'0 !1768,5 11090.5 !0n97.0 1076q,5 10748.0 106,0 TOP ~2609.0 BASE PAGE: IS Tape Verification Lis[inq :hl~]mberger AlasKa Computi. nq Center 4-MAY-1994 !2:35 # 6085,0 12609.0 2609, o 13188.0 THk; D~PTH ADJ!.!$TME[~T8 SHOWN ABOVE REFLECT THE MWD GR TO T~.~7 CET/GR [)A~E[) 21-FEB-!994. ALL OTHER CURVES WERE CARRIE[~ WITH THF. J GR SWIFT TNiS FILE CONTAINS THE VERY , " ~ .... , ' ~s'r~v 'r E~H~,NCED OR~ PR3C~,~SSED I Y DAT~ ~ITH 2' AVERAGE, T}'{E GRCH,CET I8 INCLU~E~ IN THIS FILE, LIS Ff3~MAT DATA ** PATA FORMAT SPECIFICATID~! RECORD ** ** SET ~YPE - 64EB ** TY Piti REPR C0t)E VALUE 6 P 0 2 66 3 73 5 66 b 7~ 7 65 S 68 9 65 11, 6~ 12 68. 13 66 !4 65 15 66 0 b.h 0 68 1 0,5 ~T !,5 ~T 68 1 0 m~mmmm~mmmmmm~mmmm~mmm~mmmm~mm ** SET mYDE - CHAM ** N~; 5 .... RV UNiW KER ICM APl .. I AP1 AP FILE N .. MB SI REPR PR C SS ID ORDER ~ LOG TYPE CLASS MOD NUMB SA~P ELEM CODE .................... ........ .... ........ .......... T ........... " ...... '"'"'" DFpT FT 59 _ 00 0 0 0 I 4 68 0000000000 RWO~ ~W~ G/C3 5995~0 O0 O00 O0 0 1 1 !. 4 68 0000000000 DDHO .Wg GIC3 KggLgO O0 gO0 O0 0 1 PFF ~P BN/F 599590 O0 OOO O0 0 1 C~b~? ~D iN 599590 O0 000 O0 O ! ~ 1 NDHT M~D P~)-S 590500 OO 000 0O 0 1 R~ ~wn OHM~ 5905~0 uO o0o O0 0 1 ! ! DFP ~D OHM~~ 590500 00 Vpp g~Q OgM~ 599590 O0 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 O00OO00000 68 0000000000 68 0000000000 nO00000000 iS Tape V'eriiicatJon Listino :hlumherger AlasKa Computinq Cent, er 4 ? ~ 4 !2: -~iY-, 99 35 PAGE: AM ~RV U~'! I T SE ID ..n. RD ¥'PA ~WD OBM~ 599 RDp ~w'D FD}'iP ~9~ G~ a~D GAP! 599 NCNT ~.~ ~ D CPS 599 FCNT ~WD CPS 599 F~T ~WD MP 599 G~C~{ CET GAPI 599 V!C~: a APl A I FILE NUB NUB IZE REPR PROCE .... ER ~ i,0(; TYPE CL.~SS ~OD NU~g S~.~P ELEg CODE (HE.X) 590 O0 000 00 0 I 1 1 4 68 0000000000 5~0 00 000 00 0 1 ! 1 4 68 0000000000 500 O0 000 O0 0 I ! 1 4 68 0000000000 590 O0 000 00 0 I ! ~. 4 68 0000000000 590 O0 000 O0 0 I 1 ! 4 68 0000000000 500 O0 000 O0 0 I 1 I 4 68 0000000000 590 00 000 00 0 I 1. !. 4 68 0000000000 ** [)iT! ** D~PT. 13237,000 C~LM.M~D -999.250 DED.ffWD -999,~50 GP,~WD -999.250 G~C~.CET -999,250 PFPq' 13000,000 DEP'~WO 2,757 G~.~wn 98,089 GPC".CET 70.376 DFPW. 12000,000 C~LM.~WD 9,007 DE~.UWD 5,1~2 GP.~WD i03.6~8 GRC~.CET 70.485 D~PT. CaLN.~WD 8.950 DE~.~WD 3,790 g~ UWD 74,272 GPC~CET 48.455 DFpT. 10000.000 C~L~.M~P 8.705 DEP.~WB 4.o40 GP,~WD 1!3.179 GPCn.CET -999.250 DFPT. ooo0.000 C~LN.~WD 8.o]O DEP,,~D 3,047 GP.5~WB 110.831 G~C~.CET -999.250 RHOS,MWD -999.250 DRNO,MWD -999.250 PEF.~WD NPHI.MWD -999,~50 RA.MWD -999.~50 RP.MWD VPP MWP -q99,~50 VRA,~WD -q99,~50 ROP,~WD NCNT' 5 .MWD -999,~ 0 FCNT,MWD !3~39.000 FET.MWD VF~P.~WD 2,799 VRA,MWD 2.698 ROP,MWD NCNT,MWD 305.438 FCNT.MWD 13002'000 FET,~WD ~HOB.NWD 2.592 DRHO,MWD 0.04:7 PEF.MWD N'PHI }.~WO 29.400 PA,MWD 5 1.24 RP VPP'MWD -999,250 VRA,MWD -999~250 ROP~WD ~CNT' . .~W[) 305.9i4 FCNT.MWD !1997,500 FET.~WD PHOB.~WD 2.503 DRHO.MWD 0 032 PEF.UWD NP~I aW9 37,000 PA.MWD 3;996 RP,~D 'VRP.~iwD -999.250 VRA.NWD -999 250 ~OP,~WD NCDJT.MWD 290.833 FCNT.MWD 10994:000 FET.~WD RHOB.MWO 2.454 DRHO.NWD 0.024 PEF.MwD NPHI,MWD 34.600 PA,MWD 3.938 RP.UWD VPP.~WD -099.250 VRA,MWD -999.~50 ~OP.MWD ~C~T.MWD 286.~05 FCNT.MWD 9994.500 FET.M~D PHO~{.MWD 2.~23 DRHO.MWD -0 010 PEF.MWD upwI.?!wD 41.450 PA.MWD 3~072 RP.mWD vPP.~WD -999.250 VRA.MWD -999.250 ROP.~WD MCNT.~WD 266.010 FCNT.MWD 8994.500 FET.NwD -999'250 - 999 ,' 250 24,977 -999 ' 250 4,796 2 787 28 595 0,873 2.984 965 9OO 3 024 3!710 328 691 0,221 2.988 4 094 446i505 0 272 3.483 4.204 11.8.726 0.328 Tape Verification L,i. stlnQ :hlumherqer AlasKa ComputinQ Center 4-~AY-t994 12:35 DF. PT. ~000.000 ~HO!~.MWD , ~'~ 0 3,i22 v~p MWD GP.uWD. : 148.107 NCNT'~WD... GRCN. CET -909. 250 DEPT. 7000. 000 RHC)B. MWD C a. bN' ~:W D 8,659 ¢,:P~ i. MW[) D E ~, ~ ~ D .4. b ~ I v ~ p. M~ w D GR,~W~ 97.007 'sC~;~T. MWb (;~C~~.CET -909.2 .... 0 DEPT. 6000.000 ?HOB.~WD CaLN.~WD 9.3!7 ~PHI.~WQ DE~.~WD -999.250 V~P.~WD G~.MWD 50.340 NCMT.MWD G~CM.CET -999.250 C~L~'.. .~v~D -999.250 NPHI. M~D G~. (~] w n - 9 o 9,250 ~.~ C N T. N w D G~CU, ET -909.250 2.~93 DR~O.MWD ~2. 400. PA.MWD 4:o2g FeN 2.328 DRMO.MWD 37.550 }~.A,~WD '999.250 VRA.~WD ~77.25g FCNT.~WD '999.250 VRA.MWD 229,2i5 FCNT,MWD -999 250 DRHO.MWD -999:250 rA"~WD . ~ -999.~50 VRA. M .D - 999 . 250 F C N T . M W D 0,008 PEF.~WD ~'845 ~P.,mWD -999.250 ROP,mWD 7994.500 FET,mwD 0. n ! 3 p E F. ~4 ~ D 4.864 RP.~WD -999.250 ROP.~WD 6994.500 FET.MWD -0.3'86 PEF.M~D -999.250 RP.MWD ;99g,250 ROP,~D 994.500 FET.~WD .-099.250 PEF.mWD 999.250 RP'MWD -999..250 ROP.mW¢ 5934.000 FET,~i~D 3.483 3,33! 472.734 0,184 3..009 4,565 325.293 0.277 .999' ~999,250 -999,250 999~250 "999,250 -999,250 ** END OF DATA **** FILE TRAIt, E~ **** FILE NAmE :EOIT ,Onl SERVIC~ : V~RSi~N ~ 001C0t D~T~ : 94/05/ 3 M~X R~C S!Z~ = 1024 FTLF TYPE LaST vILE **** FTLE ~!EAI)ER **** FILE ~A~E SERVICE : FL!C VERSION : OO~CO1 DATE : o4Iu5/ 3 MaX RFC S~ZE : !024 FILE TYPE : LO L~ST FILE FILE RAW Curves and ioq aeader data for each bit run in separate files. made Yer].ficatIon. Listing: :hlumberqer Alaska COmptltir~g Center 4-~AY-1994 17:]5 BIT P[~N NU~BEP: DEPT~{ INCPE~EMT: 0,5000 F!L~ StJ~RY LDWG TOOL CODE START 59 33,5 5~33,5 LOG ~EADER DAT~ DATE LOGGED: $OFTWAPE: SURFACE SOFTWARE DOWMHOLE SDFTWAPE VERSIOn!: DA~A TYPE (ME~O~Y or REAL-TIME): TD DPlLLER ~OP LOG INTEPVAL BOTTO~ LOG I~TERVAL {ET): HOLE INCLINATION (DEG) MAXIMUM ANGLE: STOP DEPTH !,2607.5 TOOL STRi~.IG (TOP TO BOTTON) V[ii'~DOP TOOL COD~ TOO!~ TYPE CP, R R~SISTIV!TY CON NEUTRON/POROSJTY ~t,.3REHOLE A~,~D CAS!N~ DATA ODEM HOLE BIT 8!Z~7.~ g[J[) TYP~: Mt~D VISCOSITY (8) ~D P~: FLUID bOSS (C~): M~XIM!IM RECORDED TE~PERATURF (DEGF): RESISTiViTY (OH~,~t4) AT TEMPERATURE (DEGF): Mt, lO AT ~!EASiJPED TE~'PKRATURF ~[]D a'[~ ~X' CIRCULATING 'fF~qPERATURE : uUO FILTRATE AW utjn CAKE AT ~,iE[!TPUM TOOL ~ATRIX DEt'.~$ I TY: HOLE CO~R~CTIO;~ (!~): 03-FES-94 FAST 2,4 NE~OR'Y 6065,0 13240,0 69,5 TOOL NUMBER RGS05 NDSO~:9 8.500 6065.0 !l,6O 36,00 ~0,00 !50.0 1.760 1.470 2.65 87.0 87.0 PAGE: 7 IS Tare Ver, ifIcatl, on l, istino :blt,~mberger AlasKa Computln6 Center 4-MAY-!994 1~:35 # ***** RUN DP[LbED IMTMRVAL 6065 - 12609 FT DRII,bED INTERVAl,, ~.260q - !,3240 MT HObF ANGEL AT T~ : 51,00 BEG ~T 13240 FT M~.XIMI!M MOLE AMGLE = 69,51 DEG AT 7327 FT TD WELL AT 10:5~ FEB 3, 1994 $ b~S FORMAT DATA PAGE: ** DATA FOR,~4AT 8PFiCIf'ICATION RECUPD ** ** SET TYPE; - 64EB ** T. REP CODE, . UE 1. 66 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 9 68 0,5 9 65 FT 1~ 66 16 12 68 13 66 0 la 65 FT 15 66 68 16 66 1 0 66 1 mm~mm~mmmmmmmmmm~mmmm~mm##~m SFRv L!-, SE~VICE P AP! AP APT FII,E UgB NIl. B SIZE REPR ROCES8 ID ~RDE~ ~ LOG TYPE Cb~SS ~OD NUmB SA~P ELEM CODE (HEX) DEPT FT 59~590 00 000 O0 0 2 I 1 4 68 RwO~ I,W1 G/C3 599590 O0 0CO 00 0 9 1 i 4 68 DP~I !:W~ p!.l 59°590 O0 00~ O0 0 2 1 1 4 6~ D~O ~,~! G/C3 5995~0 no OOO 00 0 ? 1 1 4 68 Pg~' t,~l B~/~ 59q590 O0 On(, O0 0 2 1 1 4 68 DC~T,, b~! I~ 5995~0 oO 000 O0 0 2 1 1 4 68 TNpN [,~1 PU 599590 O0 0o0 O0 0 2 1 1 4 6a ATR [.Wl OMMu 5905gO 00 0O0 n0 0 ~ 1 1 4 68 PSR LW! 0~4~ 5995o0 O0 OeO O0 0 2 1 1 4 6~ DWR L~I OgMU 59q5q0 O0 000 O0 0 2 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS ?ave VerifJcatlon Listtno :hlumberger AlasKa ComputtnO Center 4-~AY-! 994 12:35 PAGE: 9 ID ~RDER # LOG TY ROp~ [,9 F/H~ 59 90 O0 G~ !,WI GAPI 599590 OO O0 HENa LW1 CPS 5905~0 O0 OO ~EF~ ;.,~1 CPS 5995~0 O0 O0 TAB LW~ HR 59g590 O0 O0 TABD bW! H~ 599590 O0 O0 ;....... .......... ;..- .... .-.-;. ..... ................. , . O0 0 2 i 68 0000000000 0 O0 0 ~ 1 I 4 68 0000000000 0 O0 0 2 1 1 4 68 0000000000 0 O0 O ~ i i 4 68 0000000000 0 O0 0 2 1 i 4 68 0000000000 0 O0 0 2 1 1 4 68 0000000000 DEPT. 12~07,500 PE~.I,~! -909.25~ DC~h,LW DSP"LW1 -999.250 DER,LW DFPT. !ICO0.O00 ~i'iOB.L~! PE~'.LW1 3.072 DCAh. LWI PSP.LW1 4,104 DER,DWI HWNA.I~%~I 293.177 HEFA'LWI D~p~. 10000,000 R~OD.LWl PEP.!,W~ 3.956 DCAb. LWl PS~.LWI 4.31~ DER.DWI HvNa.L~! 2~6.143 HEFA.LWl DEPT. 9000.000 PPO~.bk!l PEF.[,~I 3.442 DC~b.bWl DSP.L~I 5.667 DER.I~W! hFF!~.L~I 2~9.934 HEFA.LWI DEPT. R000.OOu P~OB.LWI vEF.!>~ 3.363 DC~L.LWl PS~.L~I 2.787 D~R.LWl H~Na,T.,~I 259.275 ~EV&.bwI DEF.!,~!. 3.093' DCIL.LWi DSP.T,W~ 4.877 {)FR.DWl HVN~.!.,~ 276.~67 HfFA.bW! 2,529 DPNI.LWI 0,5!4 TI:~iPH.LW1 5.126 ROPE'bWl 12000'500 u;'AB.bwl 2 516 DPHI 0.460 TNPH,LW! 4,074: ~UPE.bWl 11000,500 TAB.DWi 2.489 DPHI,DWl 0,289 TNPH,LW1 4.266 ROPE,DWi !.0000.500 TAB,LW1 2,426 DP~i. LWI 0,280 TNPM,DWI 4.574 ROPE,LW1 9000.500 TAB.DWl 2,280 DPHI.UW! 0.103 TNPH,bWl 2.674 ROPE.bWl 8000.500 T~B,LW1 2.32~ DPHI.DWl 0.153 TNPH,bWl 4.897 ROPE.DWI 7000.500 TaB.LW1 2,23] OPMI.bWl 0.881 T~iPH,hW! -g90,250 ~OPE,LWl 6000.500 TAB.DWI -999 ~50 DRHO.LW~ -999:50 AT~.LWl 41!.408 G~,LWl '999,250 TABD.LW1 7,300 DRHO.LW1. 8.100 DRHO 31.350 338,613 GR,LWl 0,350 TABD,LWl 9.750 440,897 GR,LWl 0,~72 TABD,bWl 1~.550 DRHO.LW! 35,950 124.390 GR.I, Wl 0.319 TABD.L~! 2~.450 46.800 AT~.LWl 448.047 GR.LWl 0.189 TABD.LW1 19.550 37'.900 ~TP.LWl 194.947 G~.LWI 0.275 TA~D.L~I 25.~50 54.050 gT~.LW! -999.250 G~.LWl -999.250 TABD.Lhl -999,,250 -999,250 -999,250 -999,250 0'022 5 014 102 177 I. 63 0,030 4~013 86'797 0,518 0.039 4,169 I13.212 0.442 0,020 3290 96:418 0.583 0.004 130,445 0,008 4,941 102,096 0,412 -0 401 -999:250 49,308 -999,250 Tape Verit~,,cat!on Listinq :hlU~berger AlasKa Computing Cente~' 4-MAY-~994 12:35 DFPT. 5933.50,) PEF,LW! -999,~50 H~N,~,. LW i, -999.250 NEFA, L~I -999,250 DRHO.LWl -999.250 ATR.LWl -999.250 G~.LW1 -999.250 IABD,LW! -999'250 -999,.250 %999; 999. 250 **** FILE TRAILER FIL~ NA~E : ~D!T .002 $~RViCE : ~L!C VERSION ~ O0!C01 DAT~ : 94/05/ 3 MaX REC SIZE : ~074 FILF TYPE : LAS? ~iLE **** FILE F!LF NA~E : EDIT ,003 V~RSION : O0~COI D~TF : 94/05/ 3 ~aX R~C S!Z~ : 1.02~ FILF TYPE ~ST FILE; FIbw NUmBeR 3 RaW MaD Curves amd Ioq header data tot each bit run In separate BTT RUN N!!~BEP: DFPTH !NCPE~E~T: 0.5000 FILW SUgMARY LDWG TOO[., C[!DE START DEPTH ~; ............ 1 ~;~q.O. CU~ 1.2600,o LOG HEADER DATA DATE LOGGED: SUFTWARE~ StJRFACE D~WNHULE SOrTWAPE VERSIOn: DATA TYPE TD DPlI, LER TOP LOG TNWEPVAL STOP DEPTH !3238, ~323g,5 03-FE0-94 FAST 2,4 ~EMORY 13~40.0 6065.o files. ~$ Ia,ne Veri,~lcation Listin, Q :hlumberger A18s~a COmput!n~ Center 4-~AY-~994 12:35 nOT~ON LOG I!~T~¥A~, (FI): BIT ~OTATI~G SPEED ~INtMUM A~GLE: TDO!~ STRinG [~OP TO BOTTOH) V~DOR TUDL CO~E TOOL TYPE C R ~E,;>IST! Ty CDN f~UTRON/POROSITY S RORE~ObE AND C~SI~ DATA OPEN UO!,,,E BIT SIZE DRILLERS C~8ING DE;PT~ (FI): ~{')REHOLE CONDITIONS ~UD TYPE: ~t!D D~NSIT¥ (LB/G): ~!,.!D VISCOSITY ~UD pH: ~UD C~LORID~S (~P~): FLUID LOSS ~!XI~Ua RECORDED TEMPERATURE (DEGF): RESISTI¥ITY (O}i~) AT TEMPERATURE (DEGF): ~UD AT ~ASURED TE~PER~THRE (MT): MUD AT ~aX C!RCULA~ING TEMPERATURE uUD FILTRATE AT ~UD CAKE AT ~EUTP{]~ TOOb ~AT~IX DE~SITY: HOLE CORRECTION (IN): R?MSRKS: TORL STAb.,'bOFF (tM): 13~40.0 69.5 TOOL NUMBER NDS049 5OO 11,60 36,00 ~50,0 !,760 1,470 SANDSTONE 2.65 1,000 DPlf,LED I.~3T~RVA[.; 6065 - 12609 FT ***** a~.I~ 2 ***** DPII.,LFD I~t'.IfERVAI, 12609 - 13240 FT HUGE A~'~GEL ~T TD = 51,00 DEL ~'1.~ 13240 FT ~,'~AXIMUa ~i~'~La Af,JGI, g = 69.51 DEL AT 7327 PT ID w~;LL AT ]015R FEB 3, !994 S bls FORMAT DATA 87.0 87.O PAGE: 11 verification l:ist, f no :hlumberger Alaska Computir~q Center 4-~A¥-1994 12:35 PAGE: ** DATA F~RMAT .... TYPE R~PR CODE V~bUE 1 66 0 2 66 0 3 73 4 66 5 66 6 73 7 65 8 68 0.5 9 65 vT i! 66 12 68 !3 66 14 65 VT 15 66 6B i6 66 0 66 1 ** $gT ORDE DVpT FT 5995 RHO~ I,W2 G/C3 5995 DPHI Lw? P~) 5995 DP}lO I.,W? G/C3 5905 PEF l,~? BNt~ 5995 DCA!., I,~ IM 5995 TMP~ 1,,~ pU 5995 ATR L~? ()H~ 5995 PSa L~? ROPF t, W2 F/H~ GP Lw? GAPI }i~N~ LW~ CPS Pt~F~ !,W2 CPS T~B LWP HP TABm L~? HP 599500 no 599590 O0 599590 Om 59~500 O0 590590 OC 599590 599590 O0 59950%~ O0 m~#~mmmmmmmmmmm~mmmmmmmmm--~~m~mm~mmmmmmm~mmm~mm#mmm~ 000 O0 O 3 1 i 4 68 0000000000 00o O0 0 3 1 I 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 000 oo 0 3 1 1 4 68 0000000000 00o 00 0 3 1 1 4 68 0000000000 OOO O0 0 3 1 I 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 000 O0 0 3 1 I 4 68 0000000000 000 O0 0 3 1 I 4 68 0000000000 '000 O0 0 3 1 1 4 6~ 0000000000 000 O0 0 3 1 1 4 68 0000000000 00o O0 0 3 I 1 4 6~ 0000000000 000 oo 0 3 1 1 4 68 0000000o0o 000 O0 o 3 I I 4 68 0000000000 00() O0 0 3 1 1 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 mmmmmmm.mmmmmmmmmmmmmm.mmmimmmmmmmmmmImmmmmmmmmmmmmmmMmN 12 ** D .IA DFpT. 13238,500 PEV.LW2 -999.250 PS~.I.,N? -909.250 NVNa.L~2 -999.250 RHgi~.LW2 -099.250 DPHI.bW2 -999.250 DRt-iO.LW2 -999.250 DCAb. L~2 -099o~50 TNPI,i.~W2 -999.250 ATR,LW2 -999o250 DER.LW2 -999.250 ROPE.DW2 24.977 GR.LW2 -999.250 ).tEWA.bW2 13239.000 TAb.bW2 -999.250 TABD.LW~ -999.250 Tame VerI. f~ica!:ioD !~istinQ .'hlumberqer AlasKa Computinq Center 4-~A¥-1994 12:35 PAGE: 1.3 p~pT 13000 000 ~i4'~B i,W2 ~ 489 DPHI.LW2 LW~ 4.664 DC~L.LW2 0.~30 ,TNPH.~W2 PE~.,~ 2'773 D~R LW2 ~.732 ~OPE.LW2 Da0 HEFA'LW2 ~3000 500 TA.B,LW2 HENI.I.,WP 3o7. . . D;;PT 12609.00(3 RFiOB. bW2 2.311 DP~II.LW2 PEF'I~%~,!2. 8.956 DC/~L.LW2 0 542,.. T~PH.,LW2 bW2 3. 075 ROPE'LW2 PS~ ~., ;~; ~ 3.265 DER. ~.iFNa~I W~ 269.583 ~EFA.LW2 12609.500 TAB.:LW2 END OF DATA ~,:~25 TABD,LW~ 0.01.9 2:;665 96,581 1,686 .046 822 2t-4 '952 **** FILE TRAILER **** F!bF' MA~E : gD!':i' ' ,On3 SERviCE :FLI(: VER~IO~,~ : 00lC01 D~:T~ : 94/05/ 3 ~aX RFC SIZE FILF TYPE : LO **** TAPE TRAILER SERVICE NA~E : EDIT DATE : q4f05/ 3 O~!GIN : FLIC TaPE NA~E : ~4046 C~NTINU~TI05t # : ~ PREVIOUS ~A~E COMmEnT : ARCO ALASKA. I~!C.,KUPARDK ~IYE~ llNIT, 3M-28.50-029-29442-00 [)ATE : ~4!05/ 3 OPIClN : ~LIC CnNTINtJATIOM # : P~EVIOUS ~EEL CO~*E~T : bRCO Al~hSKa, It~C.,KODARUK RIVER [lb!IT, 3M-25,50-029-2~442-00
